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Home My WebLink About184-032 rt5-a-k- 032 U r C 2 1 • 2-r, o5 BAKER AOGC( PRINT DISTRIBUTION LIST HUGHESPlease sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska) Inc. Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME 12-29 900 E. Benson Blvd. /25/201(y M.K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska LOG DATE November 25,2015 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE December 21,2015 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #UI-NHIN I b #OF COPIES #OF COPIES #OF COPIES 4 1 BP North Slope. 0 1 0 I 0 0 ROA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. SCA" J U L 2 5 2016 r,� Anchorage,Alaska 99508 1^A fd 2 ConocoPhillips Alaska Inc. 0 1 1 I 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 1 I 0 I 0 Attn:Lynda M.Yaskell and/or Lisa Boggs i 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 1 1 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Donald Surles TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: 0 6 5 0 0 • P66( (z-5 Pr6 ► e3 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Rv,�l 510,413 Sent: Wednesday, May 29, 2013 12:24 PM 71 To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; AK, OPS EOC Specialists; AK, OPS Prod Controllers; Dos Santos, Higino W; Regg, James B (DOA); Schwartz, Guy L (DOA); G GPB FS1 Drillsites Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Holt, Ryan P; Weiss, Troy D Subject: OPERABLE: Producer 12 -29 (PTD# 1840320) Passing TIFL All, Producer 12 -29 (PTD #1840320) passed a TIFL on 05/28/2013 after the well was placed on production. The passing TIFL confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GIN Cloba: Wells SCANNED Mg 3 0 273 Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator @bp.com From: AK, D &C Well Integrity Coordinator Sent: Thursday, May 16, 2013 1:58 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC 'C TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Do d A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; AK, OPS EO pecialists; AK, OPS Prod Controllers; Dos Santos, Higino W; 'jim.regg @alaska.gov'; 'Schwartz, Guy L (DO' , G GPB FS1 Drillsites Cc: AK, D &C DHD Well Integrity Engineer; Climer, Laurie A; Walker, Greg (D: • ; Grey, Leighton (CH2M Hill) Subject: UNDER EVALUATION: Producer 12 -29 (PTD# 1840320) IA abov OASP All, Producer 12 -29 (PTD# 1840320) was found to have IA press '- above MOASP on 05/13/2013 with the TBG /IA /OA = 2220/2230/410 psi. The well had been shut in temporaril due to field optimization. At this time the well is classified as Under Evaluation for further investigation. Plan forward: 1. DHD: TIFL once well is put back onlin. 2. WIE: Further diagnostics as neede'. The wellsketch and TIO plot have beefs attached for reference. Please call with any questions., • • r Z - Z� Regg, James B (DOA) t rho �zo From: AK, D &C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator @bp.com] Sr1 (9(i 3 Sent: Thursday, May 16, 2013 1:58 PMy To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; AK, OPS EOC Specialists; AK, OPS Prod Controllers; Dos Santos, Higino W; Regg, James B (DOA); Schwartz, Guy L (DOA); G GPB FS1 Drillsites Cc: AK, D &C DHD Well Integrity Engineer; Climer, Laurie A; Walker, Greg (D &C); Grey, Leighton (CH2M Hill) Subject: UNDER EVALUATION: Producer 12 -29 (PTD# 1840320) IA above MOASP Attachments: 12 -29 wellsketch.pdf; 12 -29 TIO 5- 16- 13.docx All, Producer 12 -29 (PTD# 1840320) was found to have IA pressure above MOASP on 05/13/2013 with the TBG /IA /OA = 2220/21,0/410 psi. The well had been shut in temporarily due to field optimization. At this time the well is classified as Under Evaluation for further investigation. Plan forward: 1. DHD: TIFL once well is put back online 2. WIE: Further diagnostics as needed. - _ 5CP The wellsketch and TIO plot have been attached for reference. P ZZ 3Op. Please call with any questions. 3v , 6 , 0Zo ps: Regards, /0 ° — 3z,GA SCANNED MAY 2 0 2013 Laurie Climer kce "�sh'�� (4 /Ie,nalc :.lack Disi,r(w) BP Alaska - Well Integrity Coordinator Gtm G rgaru?a1 C'eri .. L WIC Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator PBP.com 1 PBU12 -29 PTD# 1840320 5/16/2013 TIO Pressures Plot 4.000 3.000 - Tbp IA 3.000 - -A -OA OOA OOOA On 1.000 - i • • 16tt 03 3 0223 f3 02113 0309/13 0 1 16/13 03233 03 06 13 0413 04113ri3 OU2Q t3 04,27,`73 053413 DV"! • TREE= CNV • 4 WELLHEAD = FMC' 1 2-29 SAFETY NOTES: m5 H -1/2" CROME TBG & NIPPLES*** ACTUATOR = OTIS KB. ELEV = 71' BF. ELEV r I I KOP = 2950 I ' / Max Angle = 45° @ 6200' Datum MD = - 10373' ti 1256' 9-5/8" HES ES C6MENTER Datum ND = 8800' SS 4, 20" CONDUCTOR, 91.5#, FI-40, ID = 19124" 110' 1279' 1-19-5/8" BKR ECP I I 19-5/8 BOWEN CSG PATCH H 1299' 1-- 201 8' H5-1/2" HES X NIP, ID = 4562' 19-5/8" CSG, 47#, L-80 HY D 563, ID = 8..681" H 1303' GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2518' FA ST MO WD DEV TYPE VLV LATCH PORT DATE 4 3521 3499 20 WAG DOME RK 16 11/08/10 3 6518 5776 45 WIG SO RK 20 11/08/10 2 8405 7177 38 A/TAG DMY RK 0 10/23/10 ' Minimum ID = 2.871" @ 10438' 1 9387 79;; 31 MUG MAY RK 0 10/23/10 3-1/2" DUAL CHECK FLOAT SHOE I 9550 H5-11T HES X NIP, ID = 4.562" I 0 CI. 9582' —19-5/8" X 5-1/2" HES TNT PKR, 10 = 4791" 5-1/2" TBG, 17#, 13CR-80 VAM TOP FIC, - 9679' II 1 9615' H5-1/2" HE,S X NIP, ID = 4.562" I 9679' 1-11:1/2" WLEG, ID = 4.892" 1 .0232 bpf, ID = 4,892" 9797' H9-5tr X 5-1/2" BKR 513-3A HY D PKR, ID = 4.850" il I F21 erl 9818' H7-5/8" X 4-112" X0, ID = 3,958" I 3-3/4' BKR DEPLOY SLV w/ GS, --I 9910' 9852' I-IT' BOT HY D LNR HGR w /TIEBACK, ID = ? I CTM, ID = 3.00" I TOP OF 3-1/T LNR, C, = 2 i .992" 9913' 9908' 1-1 OTIS XN NIP, 10=3.725" I l , 1 /3 kri 4-1/2" TBG, 12.6 #, L80, 9920' • 9921' 4-1/2" WLEG (BEHIND LNR) el P 0152 bpf , ID = 3.958" . . , 4 9921' HELMD TT LOGGED 05/05/91 I : I e 9-5/8" CSG, 47#, L-80, ID = 8681' H 10164' ; 4 ' 04 mlyr-- otrior,.. -- . A 3-1/2" LNR, 9.3#, L-80, I 10437' 11 : I A .0087 bpf, ID = 2.992" ■ 1 ' , 1 r A PERFORATION SUMMARY REF LOG: BHCS ON 04/13/84 PP P 4 0/ w 10438' I-13-1/2" DUAL CHECK F-SHOE, ID = 2,871" I ANGLE A T TOP PERF: 30° @ 10471' Note: Refer to Production DB for historical pert data SIZE SPF I INTERVAL - Opn/Sqz DATE I r 3-3/8 4 10370 - 10450 S 09/16/03 r 3-318 4 10471 - 10486 0 12/22/92 F 3-3/8 4 10488 - 10496 0 12/22/92 I I PE/TO 10655' r • V TAvAvAy4 ■ . V T ri I T LNR, 29#, L-80, .0371 bpf ID = 6.184" H 10778' I DATE I REV BY COM - PAENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/17/84 AUDI 4 ORIGINAL COMPLETION 12/20/10 MB/JMD ADDED SSSV SAFETY NOTE WELL: 12-29 09/16/93 S-16 3-1/2" SCAB LNR SET 01 /12/11 PJC CONDUCTOR CORRECTION PERMIT No: '1 840320 87121/01 D-16 RWO 02/09/11 MB/JMD REMVD SSSV SAFETY NOTE API No: 50-029-21087-00-00 10/23/10 D-16 RWO SEC 17, T1ON, R15E, 1328' FSL II 104' FWL 11/11/10 DB/JMD DRLG DRAFT CORRECTIONS 11/14/10 MBM/PJC GLV C/O (11/08/10) :1' Exploration (Alaska) STATE OF ALASKA RECEN40 ALAS•IL AND GAS CONSERVATION COMMI•N JAN 2 7 2U1' REPORT OF SUNDRY WELL OPERATIONS Mvig Cif g o.s. Doris. C % fission 1. Operations Performed: ?A,gCAt? gS ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ® Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number. BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 184 -032 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 ` 50 -029- 21087 -00 -00 7. Property Designation: 8. Well Name and Number. ADL 028330 '' PBU 12 - 9. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 10778 feet Plugs (measured) None true vertical 9222 feet Junk (measured) None Effective depth: measured 10735 feet Packer. measured 9797 feet true vertical 9185 feet true vertical 8348 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 2517' 13 -3/8" 2517' 2517' 4930 2670 Intermediate 10162' 9 -5/8" 10162' 8680' 6870 4760 Production Liner 926' 7" 9852' - 10778' 8398' - 9222' 8160 7020 Scab Liner 528' 3-1/2" 9910' - 10438' 8451' - 8928' 10160 10530 Perforation Depth: Measured Depth: 10471' - 10496' True Vertical Depth: 8957' - 8979' Tubing (size, grade, measured and true vertical depth): 5 ", 17# 13Cr - 9679' MD 8243' TVD 5-1/2" x 4 -1/2 ", 17# x 12.6# 13Cr -80 x L80 9797' - 9921' MD 8348' - 8461' TVD Packers and SSSV (type, measured and true vertical depth): 9-5/8" x 5-1/2" HES TNT Packer 9587 MD 8157' TVD 9-5/8" x 5-1/2" BKR SB-3A HYD Packer 9797' MD 8348' TVD 11. Stimulation or cement squeeze summary: JAN Intervals treated (measured): Et) JAN 3 Z 011 Treatment description including volumes used and final pressure: Cut and pull tubing from 9644'. Cut and pull 9-5/8" casing from 1302'. Run 9-5/8" (47 #, L -80 tieback to surface. Cement w/ 103 Bbls Class 'G' w/ Gas -Blok (578 cu if / 495 sx). Clean out and run new Chrome tubing. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 20 Subsequent to operation: 50 1936 857 220 1500 _ 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ® Daily Report of Well Operations 4 18 Development ❑ Service ❑ Exploratory ❑ Stratigraphic ® Well Schematic Diagram 15. Well Status }, ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 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 Bjork, 564 -5683 y 71v Printed Name Sondra Stewman Title Drilling Technologist 31 5 , r I Prepared By Name/Number. Siitnature - t - I ,., Phone 564 - 4750 Date -; i -/ / Elizabeth Barker, 564 -4628 Form 104 Revised 07 /2009R8DMS JAN 2 8 4 " ` / Zfi' j Submit Original Only • • 12 -29 Well History Date Summary 2- Oct -2010 T /I /O = 0/0/200 Barriers tested to 500 psi (passed) Lubricator tested to 500 psi low and 3500 psi high (passed) Set 6" CIW J BPV w/ 1 -2' ext @ 104" Tree cap tested to 500 psi upon completion (passed) note: swab valve leaks by from top side. Pre RWO 3- Oct -2010 T /I /O = BPV /0/180. Temp = SI. Bleed IAP & OAP. AL & flowline disconnected. OA FL @ 100'. Bled OAP from 180 psi to 0+ psi in 45 min. Bled IAP from 10 psi to 0 psi in 15 sec. Monitored for 30 min, Final WHPs BPV /0/0 +. 3- Oct -2010 T /I /O = BPV /0 +/180. Temp = SI. WHPs (eval high OAP). AL and FL disconnected. Unable to check SV & WV due to no scaffolding. 4- Oct -2010 T /I /0= na/0 /0. Temp =SI. WHPs (pre rig). No well house, flowline, or scaffolding. BPV set in tbg. 11- Oct -2010 T /I /0= 0/0/0; Rigged up lubricator to tree with TWC and setting tool (tree cap was already pulled); Tested lubricator against MV 250 psi low and 3500 psi high for 5 min each (Passed); Set 6 -3/8" CIW "J" TWC #419 thru tree for Doyon 16 decompletion; 1 -2' ext used, tagged at 102 "; Tested TWC to 250 psi low and 3500 psi high above and below for 10 min each test (Passed as second barrier and ensure TWC holds); Shut in MV and rigged down lubricator; No problems 11- Oct -2010 T /I /O = 0/0/0 Tested down on Master & SSV to 500 psi to verify barriers (passed) Rigged up lubricator with pulling tool and tested to 500 psi low & 3500 psi high (passed) Pulled 6" CIW J BPV w/ 1 -2' ext. @ 100" 13- Oct -2010 T /I /0= Vac /0/0; RKB= U.L. 21.6', B.R. 15.25; R/U lubricator & tool string to stack; Tested to 250 psi low & 3500 psi high for 5 min each (Passed); Pulled 6 -3/8" CIW "J" TWC thru stack; 1 -5' + 1- 2' + Centralizer used, tagged @ 120 "; Blind rams S /I; RDMO; No Problems 23- Oct -2010 T /I /0= 0/0/0 R/U lubricator & tested (each time, including barriers) passed all tests; Set 6" CIW TWC #419 @ 112" thru stack w/2 -5', 1 -3' ext. & 5' centralizer, RKB 22.60' + 4'; N /D -N /U tree; Pulled 6" CIW TWC #419 thru tree @ 112" w/1 -2' ext.; Post N /D -N /U tree; Set 6" CIW BPV #406 @ 112" w/1 -2' ext.; Doyon 16 R/D M/O Page 1 of 1 • • AS Kg Common Well Name: 12 -29 AFE No YP Event Type: MOBILIZATION (MOB) Start Date: 10/9/2010 End Date: X4- 00QP2 -E: (150,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/24/2010 17:30 - 00:00 6.50 MOB P PRE PJSM FOR WORKING ON BOPE. -B /O AND UD BOPE. - REMOVE STABBING BOARD -UD SAVER SUB. - REMOVE IBOP ON TOP DRIVE. 9/25/2010 00:00 - 06:00 6.00 MOB P PRE MOB RIG -PJSM. REMOVE UPPER & LOWER IBOP -PJSM. INSTALL REAR BOOSTERS. - PJSM. REMOVE TOP DRIVE SERVICE LOOP & KELLY HOSE. -PJSM. BRIDLE UP, R/D TORQUE TUBE PINS. CLEAR FLOOR TO UD DERRICK. -PJSM UD DERRICK & SECURE TO DERRICK STAND. 06:00 - 06:30 0.50 MOB P PRE PREP RIG FOR MOVE. -P_JSM WITH SECURITY AND TOOL SERVICES 06:30 - 16:00 9.50 MOB P PRE MOVE RIG FROM B -04 TO DS-12 - WITH TOOL SERVICE AND SECURITY ESCORT -MOVE TO EAST GAURD SHACK. 16:00 - 18:00 2.00 MOB P ® PRE WAIT ON RIG MATTS AROUND EAST GAURD SHACK. 18:00 - 22:30 4.50 MOB P PRE PJSM. MOVE RIG AROUND EAST GAURD SHACK. -CONT. MOVE TO DS-12 22:30 - 00:00 1.50 MOB P PRE CONTINUE TO SPOT RIG ON DS12 FOR SUMMER MAINTENANCE. - PJSM ON UNSTRINGING AIR TUGGERS. - PJSM ON PREPAIRING DERRICK FOR REMOVAL 10/10/2010 18:00 - 00:00 6.00 MOB P PRE -PJSM. BRING AIR SLIPS TO RIG FLOOR. CONTINUE TO TROUBLESHOOT TOP DRIVE LINK TILT. - 1930 -HRS, PJSM. MOVE AND SPOT RIG OVER WELL. SHIM UNDER RIG AS NEEDED. -OA = 100 -PSI, IA = 0 -PSI TUBING = 0 -PSI - 2100 -HRS, SPOT PUMP MODULE - 2200 -HRS, SPOT GENERATOR MODULE AND FUEL TRAILER. - 2300 -HRS, RU CIRCULATING LINES AND SECOND ANNULUS VALVES. 10/11/2010 00:00 - 00:30 0.50 MOB P PRE -PUMP STEAM THROUGH LINES TO ENSURE THERE IN NO ICE PLUG IN THE LINES. -BLEED OFF OA TO 0 -PSI. -FILL PITS WITH 8.5 -PPG 120 - DEGREE SEAWATER 00:30 - 03:00 2.50 MOB P PRE -PJSM. RU DSM LUBRICATOR. - PRESSURE TEST AGAINST THE MASTER TO 500 -PSI TO VERIFY DOUBLE BARRIER FOR BREAKING CONTAINMENT. CHART FOR 5 -MIN - 0200 -HRS, PRESSURE TEST THE LUBRICATOR AGAINST THE SSV TO 250 -PSI LOW AND 3500 -PSI HIGH. CHART FOR 5 -MIN EACH. -PULL BPV. WELL ON A SMALL VAC. -STAND BACK DSM LUBRICATOR. * * ** *ACCEPT RIG AT 0300 - HRS * * * * * * * * * * * ** Printed 1/19/2011 10:42:47AM • • - _ - � p er tion�`Summa Report j �� g: Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/11/2010 03:00 - 05:30 2.50 KILLW I DECOMP RU CIRC:UI ATINA LINFS - PRESSURE TEST CIRCULATING LINES WITH FRESH WATER TO 5000 -PSI. - 0330 -HRS, TROUBLESHOOT DEMCO VALVE LEAKING. - REPLACE SEAL IN DEMCO VALVE AND RETEST LINES. GOOD TEST. 05:30 - 06:00 0.50 KILLW r DECOMP HOLD PJSM ON CIRCULATING OUT FREEZE PROTECTION WITH RIG CREW, BP WSL AND CH2MHILL TRUCKPUSHER AND DRIVERS. - DISCUSS SPILL POTENTIAL, RETURNING TO i RWO OPERATIONS AFTER MAINTENANCE, SITE CONDITIONS AND POSITIONS OF PEOPLE. 06:00 - 06:30 0.50 KILLW DECOMP DOUBLE CHECK ALL LINES AND CONNECTIONS. -REMOVE FRESH WATER FROM RIG SLOP TANK TO BE ABLE TO RECOVER DIESEL FOR ARCTIC PACK CIRC OUT AND TO MORE ACCURATELY MONITOR RETURN VOLUMES. 06:30 - 10:45 4.25 KILLW P 1 DECOMP LINE UP AND DISPLACE DIESEL FROM TUBING WITH 120 - DEGREE 8.5 -PPG SEAWATER AT 3.5 -BPM WITH 130 -PSI. -TOOK 10 -BBLS TO GET RETURNS (FILLING 1 LINES AND GAS BUSTER). - RETURNS CLEAN UP AFTER 58 -BBLS PUMPED. -SHUT DOWN AND LINE UP TO CIRCULATE DOWN THE TUBING WITH RETURNS OUT THE IA AND THROUGH THE CHOKE AND GAS BUSTER. -PUMP 20 -BBL SAFE SURF 0 SWEEP AND CHASE AT 4 -BPM WITH 120 -PSI. - CRUDE RETURNS SEEN FROM OA NEAR END OF CIRCULATION. - ONCE SOAP SWEEP RETURNS, TAKE RETURNS BACK TO PITS. NO LOSSES. - MONITOR WELL - STATIC. 10:45 - 11:30 0.75 KILLW P -_ DECOMP BLOW DOWN CIRCULATING LINES AND RD CIRC HEAD. 11:30 - 13:30 2.00 DHB P DECOMP PU DSM LUBRICATOR. -TEST LUBRICATOR AGAINST MASTER VALVE TO 250 -PSI LOW AND 3500 -PSI HIGH. HOLD AND CHART EACH TEST FOR 5- MINUTES. GOOD TESTS. -DSM SET 6" TYPE J TWC. 13:30 - 16:45 3.25 DHB P DECOMP TEST BELOW TWC TO 250 -PSI FOR 5- CHARTED MINUTES. GOOD TEST. -TEST BELOW TWC TO 1000 -PSI FOR 10- CHARTED MINUTES. GOOD TEST. -HAD TO USE TEST PUMP TO ISOLATE FROM POTENTIAL LEAK PATHS ON CELLAR CIRCULATION MANIFOLD. -TEST ABOVE TWC TO 250 -PSI FOR 5- CHARTED MINUTES. GOOD TEST. - TEST ABOVE TWC TO 3500 -PSI FOR 10- CHARTED MINUTES. GOOD TEST. Printed 1/19/2011 10.44:23AM = 1111Otth America - ALASKA BP' ^� ag of Opar4tjon Summary Report 3 Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:45 - 17:15 0.50 DHB P DECOMP RD DSM LUBRICATOR. -BLOW DOWN AND RD LINES. 17:15 - 20:00 2.75 BOPSUR P DECOMP ND TREE AND ADAPTER FLANGE. -CLEAN AND INSPECT HANGER. THREADS GOOD, 7 1/2- TURNS, 8 -1/2" STICKUP. -CLEAN CELLAR EQUIPMENT AREA 20:00 - 00:00 4.00 BOPSUR P DECOMP PJSM. NU BOPE -CHANGEOUT WILLIS VALVE ON MUD MANIFOLD. 10/12/2010 00:00 - 02:30 2.50 BOPSUR P DECOMP NU BOPE. - 0045 -HRS, NOTIFY AOGCC BOB NOBLE 1 -HR PRIOR TO BOPE TEST, WILL BE PRESENT DURING TEST. -FILL LINES WITH FRESH WATER. - 0130 -HRS, PRESSURE TEST HIGH PRESSURE MUD LINE AND KELLY HOSE, TO 5000- PSI. NOT ABLE TO GET A PRESSURE TEST, LEAKS AT THE TOP DRIVE SWIVEL PACKING. -RU BOPE TEST EQUIPMENT. 02:30 - 06:30 4.00 BOPSUR P DECOMP PRESSURE TEST 3- PREVENTER BOPE: ANNULAR, BLIND SHEARS, MUD CROSS, AND 3 -1/2" X 6" VBR'S. -TEST TO 250 -PSI LOW AND 3500 -PSI HIGH FOR 5 -MIN EACH CHARTED. Q(�� -TEST THE 3 -1/2" X 6" VBR WITH 5 -1/2" AND 4" TEST JOINT. l -TEST THE ANNULAR WITH 4" TEST JOINT. -TEST THE GAS SENSOR ALARMS FOR H2S AND COMBUSTIBLE AT THE DRILLERS CONSOLE SENSOR. -TEST WITNESSED BY AOGCC REP BOB NOBLE, BP WSL JOSH DRURY. -3-1/2" x 6" VBRS LEAK WHEN TESTING WITH 5 -1/2" TEST JT. 06:30 - 09:30 3.00 BOPSUR P DECOMP HOLD PJSM ON CHANGING OUT 3 -1/2" X 6" VBRS. - REMOVE AND REDRESS 3 -1/2" X 6" VBRS - RUBBER SEALS ON RAMS DAMAGED. - INSTALL REDRESSED 3 -1/2" X 6" VBRS. 09:30 - 10:00 0.50 BOPSUR P DECOMP TEST RAM DOOR SEALS TO 250 -PSI LOW AND 3500 -PSI HIGH. -HOLD AND CHART EACH TEST FOR 5- MINUTES. -GOOD TEST. 10:00 - 13:00 3.00 BOPSUR P DECOMP TEST 3 -1/2" X 6" VBRS WITH 4" AND 5 -1/2" TEST JTS. -HOLD AND CHART EACH TEST FOR 5- MINUTES. - PERFORM ACCUMULATOR TEST. 1 13:00 - 14:00 1.00 BOPSUR P DECOMP BLOW DOWN LINES AND RD BOPE TEST EQUIPMENT. 14:00 - 16:30 2.50 BOPSUR P DECOMP R/U DUTCH RISER & DSM LUBRICATOR, TST. 250LOW /3500HIGH 5MIN. EA. PULL TWC, ZERO PSI BELOW, R/D LUBRICATOR, EQ. 16:30 - 17:00 0.50 PULL P DECOMP DRAIN STACK -M /U HANGAR XO TO LANDING JOINT. 17:00 - 19:00 2.00 PULL P DECOMP PJSM R/U IA OPEN TO SLOP TANK - FMC REP. BOLDS -PULL HANGAR FREE A 180K -LBS WITH BLOCKS. Printed 1/19/2011 10 :44:23AM iikao America ALASKA BFI Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42:29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 21:00 2.00 PULL P DECOMP MONITOR WELL 15MIN, STATIC - CIRCULATE WELLBORE @ 10BPM. 220PS1. WITH 8.5 -PPG SEAWATER. - MONITOR 10MIN. STATIC 21:00 - 22:30 1.50 PULL P DECOMP BREAK. & UD HANGER, XO, -CHANGE OUT ELAVATORS, -M/U FLOOR VALVE WITH XO. 22:30 - 00:00 1.50 PULL P DECOMP PULL AND UD 5 -1/2" 17# L -80 VAM TUBING -PULL AND LD TUBING FROM 9644' TO 9600' -P /U WEIGHT 180K -LBS 10/13/2010 00:00 - 09:30 9.50 PULL P DECOMP PI11 1 AND UD 5 -1/2" 17# L -80 VAM TUBING FROM 9600" CONTINUE TO PULL AND LD 5 -1/2" 17# L -80 VAM TUBING FROM 4000' TO SURFACE -LD HANGAR, 4 PUPS, 294 FULL JOINTS, 5 GLM, 1 X NIPPLE, AND CUT JOINT = 9.42' WITH 5 -1/4" O.D. FLARE 09:30 - 10:30 1.00 PULL P DECOMP CLEAN & CLEAR RIG FLOOR 10:30 - 12:00 1.50 PULL P DECOMP PJSM -BEGIN R/U SWS USIT LOGGERS 12:00 - 15:00 3.00 PULL P DECOMP PJSM PRIOR TO ALL OPS -M /U USIT LOG TOOLS RIH TO 2757', LOG TO SURFACE -TOP OF CEMENT AT 1369'. -PLAN TO MAKE CUT AT 1300', 10' BELOW COLLAR. 15:00 - 15:30 0.50 PULL P DECOMP R/D SCHLUMBERGER E -LINE SHEAVES/TOOLS 15:30 - 16:30 1.00 PULL P DECOMP DERRICK INSPECTION -CLEAR ICE 16:30 - 17:00 0.50 BOPSUR P DECOMP INSTALL WEAR RING I.D.= 8 -3/4" 17:00 - 18:00 1.00 PULL P DECOMP RIG SERVICE. SERVICE ROUGHNECK, DRAW WORKS 18:00 - 21:30 3.50 DHB P DECOMP P/U M/U RBP WITH RUNNING TOOL, -RIH WITH SINGLE JOINTS OF 4" XT -39 DP FROM PIPE SHED. 21:30 - 22:00 0.50 DHB P DECOMP SET RBP. -P /U 62K -LBS, S/O 65K -LBS - BOTTOM OF RBP @ 1453, TOP OF RRP AT 1444'. -PU 2' FOR PERFORMING OVERPULL, NEVER PULLED OVER STRING WEIGHT. S/O AND STACKED WEIGHT VERIFYING RBP SET. WENT THROUGH MOTION OF RELEASEING FROM RBP. P/U 5' TO VERIFY SET THEN WENT DOWN AND IMMEDIATLY TOOK WEIGHT, STACKED 25K -LBS. WENT THROUGH MOTION TO RELEASE SLIPS AND THEN P/U AND REPOSITION RBP. ATTEMPT TO RESET BUT HAD NO SIGNS OF RESET. -PLAN TO POH AND VERIFY SLIPS ARE NOT PACKED OFF WITH PARIFIN. 22:00 - 00:00 2.00 PULL P DECOMP BLOW DOWN TOP DRIVE. -PJSM. SLIP AND CUT DRILL LINE. -CUT OFF ' OF DRILL LINE DUE TO TO MUCH BEING ON SPOOL. 10/14/2010 00:00 - 01:00 1.00 PULL P DECOMP RIG SERVICE. ADJUST BRAKES, GREASE DRAW WORKS. ADJUST KELLY HOSE. Printed 1/19/2011 10:44:23AM KA 157- A t�r�� Am PrlCO AL�#S ' � �� 4 ��, - of 1� ® A Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42:29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 02:00 1.00 DHB P DECOMP POH RACKING BACK DP. -POH WITH RUNNING TOOL. DO NOT HAVE RBP ATTACHED. -PLAN TO RIH AND RETRIEVE RBP 02:00 - 12:30 10.50 DHB P DECOMP CLEAN AND INSPECT RBP RUNNING / RETRIEVAL TOOL RIH WITH DP IN STANDS TO 1440'. - 0230 -HRS, CONTINUE TO RIH WITH SINGLE JOINTS OF DP FROM THE PIPE SHED. -0415-HRS, CONTINUE TO RIH WITH DP FROM PIPE SHED FROM 2890'. -RIH TO 9600'. P/U WEIGHT 172K -LBS, S/0 152K -LBS; 12:30 - 13:30 1.00 DHB N DPRB DECOMP BREAK. CIRCULATION. PUMP AT 4 -BPM. 180 -PSI. WASH DOWN. -TAG RBP @ 9640' CONFIRM LATCH UP. -PUMP DRY JOB 13:30 - 20:00 6.50 DHB N DPRB DECOMP POOH FROM 9640' TO 8791', RECONFIRM RBP LATCH - CONTINUE TO POOH WITH THE RUNNING TOOURBP -RBP ELEMENT AND SLIPS IN GOOD CONDITION. -SLIP SEGMENTS PACKED WITH SEAL -TIGHT COMPOUND. PULLED SEVERAL PIECES OFF THE TOP AND OUT OF THE SLIPS RANGING FROM 1" LONG TO 1' LONG. 20:00 - 20:30 0.50 DHB N DPRB DECOMP R/D, UD RBP & RUNNING TOOL 20:30 - 21:00 0.50 DHB N DPRB DECOMP P/U M/U BAKER SCRAPER TOOLS -M /U 8 -1/2" BIT, SCRAPER 21:00 - 22:30 1.50 DHB N DPRB DECOMP RIH WITH 9 -5/8" CASING SCRAPER TO 1632' -WORK SCRAPER SEVERAL TIMES ACROSS RBP SETTING DEPTH 22:30 - 23:00 0.50 DHB N DPRB DECOMP M/U TOP DRIVE. BREAK CIRCULATION PUMP 20 -BBL HI-VIS SWEEP © 12 -BPM, 400 -PSI. ROTATE @ 3ORPM - THROUGHOUT CIRCULATION NOTICED A LARGE AMOUNT OF PIECES OF SEAL -TIGHT ACROSS THE SHAKERS. RETURNS CLEANED UP AFTER SWEEP RETURNED TO SURFACE. 23:00 - 00:00 1.00 DHB N DPRB - DECOMP POOH FROM 1632' RACKING BACK DP. 10/15/2010 00:00 - 00:30 0.50 DHB N DPRB _ DECOMP LD CASING SCRAPER BHA. .. - SCRAPER LOOKED CLEAN WHEN PULLED. 00:30 - 02:30 2.00 DHB N DPRB DECOMP CLEAR RIG FLOOR. -PJSM. MU RBP -RIH WITH RBP TO 1439'. -P /U 60K -LBS, S/0 65K -LBS. -TOP OF RBP SET AT 1430'. VERIFY SET WITH 12K -LBS OVERPULL AND S/0 17K -LBS. 02:30 - 03:30 1.00 DHB P DECOMP RU PRESSURE TEST EQUIPMENT. - PRESSURE TEST RBP TO 250 -PSI LOW FOR 5 -MIN CHARTED. - PRESSURE TEST TO 3500 -PSI HIGH FOR 10 -MIN CHARTED. BOTH TESTS GOOD. -BLOW DOWN LINES. Printed 1/19/2011 10:44:23AM 011I('CIC AAS �® B I P 41 Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 07:00 3.50 DHB P DECOMP RU SAND HOPPER. -DUMP 44 -SACKS (2200 #1 OF 20/40 MESH RIVER SAND. DUMP SACK AT 3 -MIN PER SACK. TOP OF SAND AT APROX. 1380' -FLUSH DP @ 1 -BPM, 20 -PSI -B /D T/D 07:00 - 07:30 0.50 DHB P DECOMP POOH -L/D RBP RETRIEVAL TOOL 07:30 - 10:00 2.50 PULL P DECOMP PJSM. -kW Q -5 /R" STRINh la1TTFR & RIH TA(; TIP _. OF SANE Qi 1`i75' -P /U 65K -LBS., S/O 65K -LBS. - LOCATE CASING. COLLAR @ 1329' & 1290' 3 -BPM @ 40 -PSI - POSITION KNIVES @•1300' FOR CUT 10:00 - 11:00 1.00 PULL P DECOMP PJSM -R /U LRS & PT LINES © 2200 -PSI 11:00 - 12:00 1.00 PULL P DECOMP CUT 9 -5/8" CSG. a 1300'. CUT 60 -RPM WITH 4K LBS` OF TORQUE © 7 -BPM WITH C s)'' 840-PSI G -SAW PREASURE DECREASE & TORQUE SPIKE 12:00 - 17:00 5.00 PULL P DECOMP -PUMP 52 -BBLS OF 80 DEG. DIESEL @ 3 -BPM WITH 1000 -PSI, CHASE WITH 14 -BBLS OF 9.8 -PPG BRINE 2 3 -BPM WITH 770 -PSI, SHUT IN AND SOAK FOR 1HR. -R/D LRS - 1330 -HRS, PUMP 25 -BBLS @ 2 -BPM WITH 500 -PS, 251 -BBLS 120 - DEGREE 9.8 -PPG BRINE @ 6.5 -BPM WITH 2000 -PSI, FOLLOWED BY SAFE - SURF -O SWEEP @ 2 -BPM WITH 1440 -PSI, -CHASE SWEEP © 2 -BPM WITH 1440 -PSI, -PUMP 120 - DEGREE 8.5 -PPG SEAWATER @ 5 -BPM WITH 1970 -PSI. PUMP UNTIL CLEAN SEAWATER SEEN @ SURFACE - PERFORM AFTER ACTION REVIEW WITH ALL HANDS INVOLVED WITH CIRC. AND CUTTING OF CSG. - MONITOR O.A.. NO FLOW -OPEN BAG & CBU @ 5 -BPM WITH 380 -PSI 17:00 - 18:30 1.50 PULL P DECOMP MONITOR WELL, NO FLOW B/D T/D POOH FROM 1300' TO 716.95' RACKING BACK - FROM 716.95' TO 48.19' LID DP IN PIPE SHED TO ENSURE ENOUGH ROOM ON RIG FLOOR TO USE 9 -5/8" CASING POWER TONGS. -1 in Cl1TTFR RHA 18:30 - 20:00 1.50 PULL P DECOMP CLEAN OUT THE BOPE STACK WITH JOHNNY WACKER © 11 -BPM WITH 100 -PSI, -B /D T/D -PUMP OUT STACK, B/D KILL & CHOKE, -PULL WEAR RING 20:00 - 00:00 4.00 PULL P DECOMP PJSM, N/D BOP'S & TUBING SPOOL, - REMOVE CSG. SPOOL PACK OFF -PJSM , N/U NEW TUBING SPOOL & BOP'S, FUNCTION CSG. SPOOL LOCK DOWNS IN & OUT (WORKS GOOD), BOTH CSG. & TUBING SPOOL MEASUREMENT: OUT= 4 -3/4 ", IN= 3 -3/4" 10/16/2010 00:00 - 01:00 1.00 PULL P DECOMP NU TUBING SPOOL TO BOPE STACK. Printed 1/19/2011 10:44:23AM � a ri Ai AS r •e ` 16 pe rnnr ia ° epc Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 02:45 1.75 PULL P DECOMP RU 9 -5/8" CASING SPEAR. - 0130 -HRS, SPEAR CASING. - 0200 -HRS, PJSM. LIFT BOPE. PULL CASING FREE WITH 90K -LBS. PULL EMERGENCY SLIPS. - LOWER BOPE STACK AND BOLT UP TO CASING SPOOL. -RU 9-5/8" CASING POWER TONGS. 02:45 - 03:30 0.75 PULL P DECOMP LD CASING SPEAR. ■ -LD CUT JOINT OF CASING. -MU XO FOR CIRCULATING. 03:30 - 04:30 1.00 PULL P DECOMP CIRCULATE CASING AND OA. - RECIPROCATE PIPE WHILE CIRCULATING PUMP 40 -BBL SAFE- SURF -O PILL FOLLOWED BY 170 -BBLS OF 1'20- DEGREE 8.5 -PPG SEAWATER. . -PUMP AT 9 -BPM WITH 60 -PSI PUMP PRESSURE -PJSM FOR LD CASING. RD CIRCULATING EQUIPMENT. 04:30 - 05:00 0.50 PULL P ® DECOMP R/D CIRCULATION EQUIPMENT -B /D T/D 05:00 - 07:30 2.50 PULL P DECOMP -POH LD 9 -5/8" 46# CASING FROM 1300' TO SURFACE - AVERAGE BO 30 -40K -LBS - BOTTOM CUT LENGTH JOINT = 10.67', TOP CUT CUT JOINT LENGTH = 27.09', PUP JOINT= 15.32' -30 FULL JOINTS RECOVERED, NO STABILIZERS RECOVERED 07:30 - 09:00 1.50 RIGD P DECOMP R/D CASING EQUIPMENT -CLEAN RIG FLOOR - INSTALL WEAR RING 09:00 - 09:30 0.50 PULL P DECOMP RIG SERVICE 09:30 - 12:00 2.50 PULL P DECOMP MOBILIZE & M/U 9 -5/8" DRESS OFF BHA. SEE BHA #4 - DRESSOFF SHOE, WASHPIPE, INNER MILL, BOOT BASKET, SCRAPER, FLOAT SUB, BUMPER JAR, DRILL COLLARS -P /U DRILL COLLAR FROM PIPESHED -RIH TO 984' P/U 60K -LBS., S/O 55K -LBS. 12:00 - 13:30 1.50 PULL P DECOMP CONTINUE RIH TO 1270', GET PARAMETERS P/U 68K -LBS, S/O 72K -LBS., 6 -BPM WITH 200 -PSI, 2K -LBS FREE TORQUE, ROT 70K -LBS, -TAG CUT Cgs 1300' ATTEMPT TO ROTATE OVER 9 -5/8" STUMP (NO GO), - DISCUSS OPTIONS WITH BAKER 13:30 - 14:30 1.00 PULL P ■- DECOMP PJSM -B /D T/D -POOH FROM 1300' TO 315' 14:30 - 16:30 2.00 PULL P ■- DECOMP MONITOR WELL -STAND BACK 4 -3/4" DRILL COLLAR -PJSM, BREAK DOWN OVERSHOT 16:30 - 17:00 0.50 PULL P DECOMP PJSM, M/U 12 -1/4" X 10 -3/4" WASHOVER SHOE. SEE BHA #5. DRESSOFF SHOE, WASHPIPE, INNER MILL, BOOT BASKET, FLOAT SUB, BUMPER JAR, DRILL COLLARS Printed 1/19/2011 10:44:23AM Orth America - ALASKA - BP :` ' 0 O 9T tion Summa Re ort Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 000P2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 20:00 3.00 PULL P DECOMP PJSM, RIH TO 1265', P/U 62K -LBS., 5/0 70K -LBS., 6 -BPM WITH 210 -PSI, FREE TORQUE 1 -1/2K, ROT WIEGHT 70K -LBS, 60 -RPM, ON BOTTOM TORQUE 2 -3K -LBS WEIGHT ON BIT 5 -8K -LBS, DRESS OFF TOP OF 9 -5/8" STUMP 1.5', TO 1301.5' -WORK OVER -SHOT OVER CASING STUMP TO VERIFY STUMP DRESSED OFF 20:00 - 20:30 0.50 PULL P DECOMP PUMP HI -VIS SWEEP @ 8 -BPM WITH 370 -PSI 20:30 - 22:00 1.50 PULL P DECOMP MONITOR WELL, B/D/ T/D -POOH FROM 1301.5' TO 310' - MONITOR WELL, STAND BACK DRILL COLLARS. 22:00 - 00:00 2.00 PULL P DECOMP L/D 9 -5/8" DRESSOFF ASSEMBLY BHA #5 -BOOT BASKET FILLED WITH METAL SHAVINGS. -M /U 9 -5/8" DRESSOFF ASSEMBLY #6 -DRESSOFF SHOE, WASHPIPE, INNER MILL, BOOT BASKET, FLOAT SUB, BUMPER JAR, DRILL COLLARS -RIH TO 1265' 10/17/2010 00:00 - 00:30 0.50 PULL P DECOMP TAG 9 -5/8" CASING STUMP AT 1301.5'. -P /U 62K -LBS., 5/0 70K -LBS., 6 -BPM WITH 210 -PSI, FREE TORQUE 1 -1/2K, ROT WIEGHT 70K -LBS, 60 -RPM, ON BOTTOM TORQUE 2 -3K -LBS WEIGHT ON BIT 5 -8K -LBS, DRESS OFF TOP OF 9 -5/8" STUMP .5', TO 1302' -WORK OVER -SHOT OVER CASING STUMP TO VERIFY STUMP DRESSED OFF 00:30 - 02:30 2.00 PULL P DECOMP POH RACKIG BACK FROM 1302'. STAND BACK COLLARS. LD DRESS -OFF BHA. -BOOT BASKET WAS EMPTY. -PULL WEAR RING. 02:30 - 03:00 0.50 CASING P DECOMP RU 9 -5/8" CASING HANDLING EQUIPMENT. 03:00 - 03:30 0.50 CASING P -_ DECOMP PJSM ON RUNNING CASING WITH BAKER COMPLETIONS 03:30 - 06:00 2.50 CASING P DECOMP RUN 9 -5/8" CASING L -80 47# HYDRIL 563. -BAKER LOC ALL CONNECTIONS BELOW THE ES- CEMENTER. -MU TO OPTIMUM TORQUE OF 15,800 FT -LBS. -USE JET LUBE SEAL GUARD ON ALL HYDRIL 563 THREADS -USE STABBING GUIDE ON ALL JOINTS. - INSTALL 1- FREE - FLOATING CENTRALIZER PER JOINT ABOVE THE ES- CEMENTER. 06:00 - 07:30 1.50 CASING P ■- DECOMP L FROM HYDRIL TO BUTTRESS LANDING JOINT - CHANGE TO LONG BALES 07:30 - 08:00 0.50 CASING P DECOMP RIH TO 1298'. - ROTATE PATCH DOWN TO 1301' -P /U 94K -LBS, SET DOWN 50K -LBS ON 9 -5/8" CASING STUMP, P/U 30K -LBS. OVER, SET DOWN 50K -LBS., P/U TO 30K -LBS. OVER, SET BACK DOWN, P/U TO 150K -LBS. OVER, S/0 TO 100K -LBS OVERPULL Printed 1/19/2011 10:44:23AM -10 _ � merica ,'ALASKA � P 3 � of Ai ` :�� i 3 O ion Summary R � ` 3 E -- Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 08:30 0.50 CASING P DECOMP R/U & TEST CASING TO 1000 -PSI CHARTED s "} FOR 10 MIN., - INCREASE TO 1200 -PSI LET STABILIZE, - INCREASE TO 1400 -PSI LET STABILIZE, - INCREASE TO 1600 -PSI SAW INFLATION VALVE OPEN ON ECP. -PREASSURE UP TO 2000 -PSI , CLOSE ECP 1 it VALVE -HOLD 2000 -PSI & TEST CASING FOR 10"'�'� CHARTED MIN. 08:30 - 09:30 1.00 CASING P DECOMP PREASSURE UP TO OPEN EZ- CEMENTER, CEMENTER OPENED AT 3100 -PSI - CIRCULATE 5 -BPM @ 1070 -PSI -PUMP 10 -BBL DRY JOB 09:30 - 11:00 1.50 CASING P DECOMP M/U XO FOR CEMENT HEAD -R/U CEMENT HEAD &CIRCULATION EQUIPMENT 11:00 - 12:00 1.00 CASING P DECOMP PUMP HEATED SEAWATER 5 -BPM @ 1250 -PSI - SEAWATER AT 95 DEGREES GOING IN, 80 DEGREES COMING OUT 12:00 - 12:30 0.50 CASING P DECOMP PJSM WITH SCHLUMBEGER, TRUCK DRIVERS, RIG CREW, TOOL PUSHER, WSL TO PUMP CEMENT 12:30 - 13:00 0.50 CASING P DECOMP - PRESSURE TEST SCHLUMBERGER CEMENT LINE TO 4000 -PSI, -PUMP 103 -BBLS 15.8PPG YIEI D 1 17- . CUFT /SK - CEMENT @ 5 -BPM WITH 1230 -PSI, `. -DROP PLUG & CHASE WITH 8.5PPG a SEAWATER WITH RIG PUMP AT 750 -PSI @ 4.5 -BPM TAKING RETURNS THROUGH O.A. TO ARCTIC TANK. -FCP 800 -PSI @ 2 -BPM, -BUMP PLUG @ 91.7 -BBLS AWAY. BUMP PLUG AT 2110 -PSI. ES- CEMENTER CLOSE @ 1500 -PSI -22 -BBLS CEMENT TO SURFACE. _ -CIP @ 13:07 HRS. 13:00 - 14:00 1.00 CASING P DECOMP FLUSH O.A. LINE & BOP'S WITH CONTAMINANT PILL, B/D ALL LINE'S 14:00 - 19:30 5.50 CASING P DECOMP AFTER ACTION REVIEW WITH CREW, PJSM -SPLIT TUBING SPOOL FROM CASING SPOOL & SET EMERGENCY SLIPS WITH 100K -LBS OVER STRING WEIGHT. - C/O O.A. VALVE, CUT 9 -5/8" WITH WACHS - CUTTER. CUT JOINT 9.53' IN THE HOLE. -R /D CEMENT HEAD, ALL CASING HANDLING EQUIPMENT, LONG BAILS, R/U SHORT BAILS 19:30 - 20:30 1.00 CASING P DECOMP M/U PACKOFF RUNNING TOOL & SET PACKOFF IN CASING SPOOL 20:30 - 22:00 1.50 CASING P DECOMP PJSM -N/ :.•' • _ ► ••• 22:00 - 23:00 1.00 CASING P DECOMP TEST PACKOFF TO 250 -PSI FOR 5 -MIN, 3800 -PSI FOR 30 -MIN CHARTED. GOOD TEST. -LOST 75 -PSI FIRST 15 -MIN AND 10 -PSI THE SECOND 15 -MIN. 23:00 - 00:00 1.00 CASING P DECOMP MOBILIZE DRILL OUT ON RIG FLOOR -R/U BOP TEST EQUIPMENT TO TEST TUBING SPOOUBOP BREAK Printed 1/19/2011 10:44:23AM f 16" O VE' tt tifik 17ary 1 .. Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/18/2010 00:00 - 01:00 1.00 CASING P DECOMP PRESSURE TEST BREAK BETWEEN TUBING _ SPOOI AND ROPF STACK �ar - PRESSURE TEST 250 -PSI LOW AND 3500 -PSI HIGH FOR 5 -MIN EACH CHARTED. -PULL TEST PLUG. - INSTALL WEAR RING. 01:00 - 02:30 1.50 CASING P DECOMP MU DRILL OUT BI-IA. SEE BHA #7 8 -1/2" BIT, BOOT BASKETS, BUMPER SUB, OIL JAR, PUMP -OUT SUB, DRILL COLLARS -0130-HRS, RIH WITH 21- JOINTS OF DP FROM THE PIPE SHED. CONTINUE IN HOLE FROM DERRICK TO 1200'. 02:30 - 06:30 4.00 CASING P DECOMP OBTAIN PARAMETERS. -P /U 70K -LBS, S/O 65K -LBS. R/O 67K -LBS AT 60 -RPM. 1.5K FREE TORQUE. PUMP AT 6 -BPM WITH 270 -PSI - CONTINUE IN HOLE TO 1231', TAG CEMENT STRINGERS. -TAr. SOl Ifl (FMFNT AT 1741' DRILI WITH, 3 -5K WOB, 6 -BPM WITH 270 -PSI. -TAG PLUG AT 1260'. BEGIN DRILLING WITH 3- 6K -WOB. -PUMP TWO 20 -BBL HI-VIS SWEEPS -RR0KF THROI K;H f:FMENT tg'l 1261' -WORK THROUGH EZ- CEMENTER 3X 06:30 - 08:00 1.50 CASING P DECOMP WASH & ROTATE DOWN TO SAND -TAG SANE @ 1380' WITH 1 -BPM 40 -PSI, -WASH & ROTATE DOWN TO 1386' -PUMP 20 -BBL HI-VIS SWEEP , CHASE OUT OF HOLE @ 8 -BPM 430 -PSI 08:00 - 08:30 0.50 CASING P DECOMP PUMP 10 -BBL DRY JOB - MONITOR WELL -B /D T/D -POOH FROM 1371' TO 320' 08:30 - 09:30 1.00 CASING P DECOMP STAND BACK DRILL COLLARS & R/D DRILL OUT BHA -CLEAN OUT JUNK BASKETS, APROXIMATELY 3 -GAL. RECOVERED CEMENT, ALUMINUM SHAVINGS, AND A FEW LARGE PIECES OF ALUMINUM 09:30 - 10:00 0.50 CASING P DECOMP M/U RCJB BHA #8 RCJB, (4) JUNK BASKETS, SCRAPER, BUMPER JAR, OIL JAR, PUMP OUT SUB 10:00 - 12:30 2.50 CASING P DECOMP RIG SERVICE -B /D KILL LINE & CHOKE MANIFOLD LINE, MANUALS BACK UP ON WELL -R &R DRILLERS CONSOLE AIR PURGE PER SAFETY AUDIT -R &R #2 MUD PUMP 12:30 - 14:00 1.50 CASING P DECOMP RIH WITH REVERSE CIRCULATION SUB/(4) JUNK BASKETS TO 1381' 14:00 - 16:30 2.50 CASING P DECOMP -M /U T/D BREAK, CIRCULATE @ 1 -BPM, 40 -PSI -STAGE PUMPS UP TO 8 -BPM, 900 -PSI, 60 -RPM 2 -3K -LBS TORQUE -P /U 74K -LBS S/O 73K -LBS, -TAG @ 1385'. -WASH SAND TO 1400' @ 8 -BPM 1200 -PSI, P/U DROP 1.9" BALUROD, CIRCULATE HI-VIS SWEEP 16:30 - 18:00 1.50 CASING P DECOMP POOH FROM 1400' STAND BACK DRILL PIPE/COLLARS Printed 1/19/2011 10:44:23AM 4 11 'tfifJl LAS P =01 416, _ zap QperatraTeSummary Repo t e , Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 19:00 1.00 CASING P DECOMP UD BHA CLEAN BOOT BASKETS, - .5GAL METAL DEBRIS RECOVERED. LARGE PIECES OF RING AND SLEEVE. 1LARGE BRASS PIECE. 19:00 - 19:30 0.50 CASING P DECOMP M/U RCJB BHA #2 JUNK BASKET RUN. SEE BHA #9 -RCJB, (4) JUNK BASKETS, BUMPER JAR, OIL JAR, PUMP OUT SUB 19:30 - 20:00 0.50 CASING P DECOMP RIH TO 1400' 20:00 - 21:30 1.50 CASING P DECOMP M/U T/D WASH DOWN TO 1410' @ 2 -BPM 100- 1300PSI, DROP 1.96" CIRCULATION SUB BALL/ROD -PUMP 20 -BBL 111-VIS SWEEP 21:30 - 23:00 1.50 CASING P DECOMP POH FROM 1410' -2 PIECES OF RING AND 1 PIECE OF BRASS FOUND IN RCJB. -ABLE TO VERIFY THAT PIECES OF THE ES-CEMENTER RING WERE RECOVERED. - NOTHING WAS IN ANY OF THE BOOT BASKETS. 23:00 - 00:00 1.00 CASING P DECOMP LD BHA. 10/19/2010 00:00 - 01:00 1.00 CASING P DECOMP RU TEST EQUIPMENT. - PRESSURE TEST CASING AND PATCH TO 250 -PSI LOW FOR 5 -MIN AND 3500 -PSI HIGH FOR 30 -MIN CHARTED. GOOD TEST. -RD TEST EQUIPMENT. 01:00 - 02:00 1.00 DHB P DECOMP P/U RBP RETRIEVAL TOOL RIH TO 1350'. 02:00 - 02:30 0.50 DHB P DECOMP OBTAIN PARAMETERS. -P /U 67K -LBS, S/O 72K -LBS. 8 -BPM WITH 360 -PSI -RIH AND TAG RBP AT 1435'. -LATCH AND CIRCULATE HI VIS SWEEP. SHAKERS LOADED WITH SAND. CONTINUED CIRCULATING UNTIL RETURNS WERE CLEAN 02:30 - 04:00 1.50 DHB P DECOMP PULL AND RELEASE RBP. -NO FLOW. -CLOSE ANNULAR AND CIRCULATE THROUGH GAS BUSTER AND CHOKE. CIRCULATE AT 3 -BPM WITH 80 -PSI. - CIRCULATE BOTTOMS UP. NO GAS SEEN AT SURFACE. -FLOW CHECK. NO FLOW -B /D TOP DRIVE. 04:00 - 05:00 1.00 DHB P DECOMP POH RACKING BACK DP. -LD RBP AND RETRIEVAL TOOL. 05:00 - 06:30 1.50 CLEAN P DECOMP MU 5 -1/2" TUBING DRESS -OFF BHA. SEE BHA #10 06:30 - 11:00 4.50 CLEAN P DECOMP RIH WITH DRILL PIPE FILLING DRILL PIPE EVERY 20 STANDS, TO 9607' -DRESS OFF PACKER SETTING DEPTH FROM 9450' TO 9575' 4 TIMES WITH SCRAPER. 11:00 - 12:00 1.00 CLEAN P DECOMP OBTAIN PARAMETERS P/U 190K -LBS S/0 160K -LBS, ROTATION 175K -LBS, FREE TORQUE 5K -LBS 6 -BPM @ 530 -PSI -WASH DOWN, TAG STUMP AT 9642' DRESS OFF WITH 5K -LBS WOB TO 9644', 6 -BPM @ 610 -PSI Printed 1/19/2011 10:44:23AM • Oe 11� ��EE P116 � v r Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 14:00 2.00 CLEAN P DECOMP P/U TO 9623' WORK OVER STUMP (3) TIMES, ALL OK -PUMP 20 -BBL HI-VIS SWEEP, SS @ 8 -BPM, 960 -PSI, 60 -RPM RECP. PIPE 30' -MONITOR WELL 5 -MIN. STATIC -PUMP DRY JOB, BLOW DOWN RACK BACK 1 STAND OF DP 14:00 - 16:00 2.00 CLEAN P DECOMP PJSM ■ HANG BLOCKS, CUT /SLIP 87' DRILL LINE - INSPECT /SERVICE DRAW WORKS 16:00 - 18:00 2.00 CLEAN P DECOMP POOH FROM 9607' TO 5689' 18:00 - 19:00 1.00 CLEAN N RREP DECOMP REPAIR IRON ROUGHNECK. THE SWITCH WHICH OPENS AND CLOSES THE JAWS. -FOUND THE SWITCH CAME LOOSE - REPAIRED. 19:00 - 20:00 1.00 CLEAN P DECOMP POOH FROM 5689' TO 4925'. 20:00 21:00 1.00 CLEAN P DECOMP MONITOR WELL. - STATIC - MONITORED WELL DUE TO TRIP SHEET BEING OFF BY 3 BBLS. - PERFORM DERRICK AND TOP DRIVE INSPECTION. 21:00 - 22:30 1.50 CLEAN P DECOMP POOH FROM 4925' TO BHA. -STAND BACK DC IN DERRICK. 22:30 - 23:30 1.00 CLEAN, P DECOMP L/D BHA. -FLUSH BOP STACK. 23:30 - 00:00 0.50 BOPSUR P ` DECOMP R/U TO TEST BOPE. -BEGIN TESTING BOPs. -AOGCC REP, JEFF JONES WAIVED WITNESS AT 0620 HRS 10/19/2010 10/20/2010 00:00 - 06:00 6.00 BOPSUR P DECOMP TEST BOPE. -TEST ALL BOPE EQUIPMENT TO BP AND AOGCC REGS. n -TEST TO 250 PSI LOW AND 3500 PSI HIGH (� FOR 5 MINS. EACH -TEST WITH 4" AND 5 -1/2" TEST JOINTS. TEST ANNULAR WITH 4" TEST JOINT. -TEST WITNESSED BY WSLAND DOYON TOUR PUSHER. 06:00 - 06:30 0.50 BOPSUR P ■- DECOMP C TE KILL -R/D TEST EQUIPMENT UIPPMENT ENT - INSTALL WEAR RING 06:30 - 07:00 0.50 CLEAN P DECOMP RIH WITH 4 -3/4" DRILL COLLARS & LD / DC 07:00 - 09:00 2.00 CLEAN P ■- DECOMP MOBILIZE AND M/ JUNK ENT BHA & 2 -7/8" HANDLING EQUIPMENT, EQUIPMENT, , P/U P/U 2 -7/8" FROM PIPESHED 09:00 - 11:30 2.50 CLEAN P DECOMP RIH WITH DRILL PIPE TO 4734' 11:30 - 12:00 0.50 CLEAN P DECOMP RIG SERVICE 12:00 - 14:00 2.00 CLEAN P -_ DECOMP CONTINUE TO RIH WITH DRILL PIPE FROM 4734' TO 9703' Printed 1/19/2011 10:44:23AM Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 000P2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 17:00 3.00 CLEAN P DECOMP MAKE UP TOP DRIVE AND BREAK CIRCULATION. - OBTAIN PARAMETERS. -2 BPM AT 500 PSI. -PUW OF 183K SO OF 150K -TAG TOP OF FISH AT 9763' STOPPED - CIRCULATING. SET DOWN 15K OVER. -P /U WITH 37K OVER AT 220K. PULL 15' UP WITH 27K OVER AT 210K WHEN WEIGHT DROPPED OF TO 190K. CONTINUE TO POOH TO TOOL JOINT. SET BACK STAND AND DROPPED BALL TO OPEN CIRC SUB. -WELL WENT ON VAC. - FILL ANN TAKING 140 BBLS SHOWING AN INITIAL LOSS RATE OF 168 BPH THEN ONCE FILLED LOSSES SLOWED TO 98 BPH. A TTEMPT TO OPEN! CIRC SUB. - CIRC SUB WAS NOT PUT INTO BHA AND LEFT ON, RIG FLOOR. BALL SET DOWN IN XO 0F2 -7/8" PLUGGING DP. 17:00 - 19:30 2.50 CLEAN P DECOMP MONITOR LOSS RATE. - MAINTAIN CONTINUOUS HOLE FILL WITH LOSSES AT 90 BPH. - -BUILD 20 BBLS HI-VIS SWEEP WITH FLO -VIS AT 2.5 PPB. -CLOSE ANN. PREVENTER AND PUMPED HI-VIS INTO ANNULUS AT 2.6 BPM AND INITIAL PRESSURE OF 140 PSI. PRESSURE INCREASED TO 230 PSI WHEN 20 BBLS WAS PUMPED. CHASED HI-VIS WITH 10 BBLS SEAWATER TO CLEAR LINES AND PUSH DOWN ANN. AS NOT TO FLUSH OUT WHEN HOLE FILL WAS TURNED ON. -THE HI-VIS SHOULD TAKE —6 HOURS TO FALL TO PERFS AT 90 BPH LOSS RATE. 19:30 - 00:00 4.50 CLEAN P DECOMP POOH LAYING DOWN DRILL PIPE TO 6358' WET. - MAINTAIN CONSTANT HOLE FILL. -1930 hrs - LOSS RATE OF 90 BPH. - 2030 hrs - LOSS RATE OF 78 BPH. -2100 hrs - LOSS RATE OF 84 BPH. -2130 hrs - L/R OF 84 BPH. -2200 hrs - L/R OF 76 BPH. -2230 hrs - L/R OF 72 BPH. -2300 hrs - UR OF 60 BPH MONITOR WELL AND CHECK AGAIN AT 78 BPH. WELL LOSING FLUID. -2330 hrs - L/R OF 68 BPH. - 0000 hrs - UR OF 84 BPH. - LOSSES TO WELL TODAY OF 884 BBLS 8.5 PPG SEAWATER. Printed 1/19/2011 10:44:23AM I E per ation Sum yep ©rt 3 = E €E Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/21/2010 00:00 - 06:30 6.50 CLEAN P DECOMP POOH FROM 6358' TO BHA WET. - MAINTAIN CONTINUOUS HOLE FILL. -0030 hrs - UR OF 74 BPH. -0100 hrs - UR OF 72 BPH. 0130 hrs - L/R OF 72 BPH. -0200 hrs - L/R OF 72 BPH. -Q230 hrs - L/R OF 72 BPH. -0300 hrs - L/R OF 73 BPH. -0330 hrs - UR OF 54 BPH. MONITOR WELL. LOST A TOTAL OF 525 BBLS SINCE HI-VIS WAS PLACED, IN THE ANN. A CALCULATED 548 BBLS FOR PILL WAS TO REACH PERFS. LOSS RATE SHOULD SLOW. -0430 hrs L/R OF 42 BPH. 56 JOINTS LEFT TO L /D. -0500 hrs - UR OF 42 BPH. 06:30 - 07:00 0.50 CLEAN P DECOMP R/U 2 -7/8" HANDLING EQUIPMENT. -LJD 2 JOINTS OF 2-7/8" PAC DP. -MAINTAIN CONTINUOUS HOLE FILL. 07:00 - 10:00 3.00 CLEAN P DECOMP UD BHA. -10' OF 5 -1/2" TBG JOINT WAS PULLED FROM THE WELL. - DISCUSS OPTIONS WITH RWO SUPERINTENDANT. -HOLD PJSM FOR CHANGE OF SCOPE. - MAINTAIN CONTINUOUS HOLE FILL. 10:00 - 10:30 0.50 CLEAN P DECOMP M/U TOP DRIVE TO 2 -7/8" PAC. TURN 1 TURN TO RIGHT. -P /U 2 -5K OVER BLOCK WT. AND PULL 60' OF PAC DP OUT OF CUT 5 -1/2" TBG CUT JOINT. - MAINTAIN CONTINUOUS HOLE FILL. 10:30 - 11:00 0.50 CLEAN P DECOMP L/D 5 -1/2" CUT JOINT. 11:00 - 12:00 1.00 CLEAN P DECOMP R/U AND UD 2 -7/8" PAC DP AND XOs. - MAINTAIN CONTINUOUS HOLE FILL THROUGH OUT ALL OPERATIONS. -FLUID LOST FOR 12 HOURS = 638 BBLS 8.5 PPG SEAWATER. 12:00 14:00 2.00 CLEAN P ■- DECOMP JOINTS, 3 S, COMPLETE PL OF TE 5-1/2" SEAL A SS 2 PUPS Y. JOINTS, COMPLETE SAL AY. - MAINTAIN CONTINUOUS HOLE FILL. 14:00 - 14:30 0.50 CLEAN P ._ DECOMP CLEAR AND CLEAN RIG FLOOR. - MAINTAIN CONTINUOUS HOLE FILL. 14:30 - 18:30 4.00 RUNCOM P RUNCMP R/U TO RUN 5 -1/2" 13 CR VAM TOP COMPLETION. -PJSM FOR RUNNING COMPLETION AS PER RUNNING TALLY, 30 SEC JT, TQ TURNED, USING JET LUBE SEAL GUARD FOR DOPE, BAKER LOC ALL CONNECTIONS BELOW PACKER. - MAINTAIN CONTINUOUS HOLE FILL. 18:30 - 19:00 0.50 RUNCOM P ■- RUNCMP WITH 1 VAM TO TBG. -P/ -P /U RIH WITH WLEG, WLEG, JOINT A NT A, XN ASSY. - MAINTAIN CONTINUOUS HOLE FILL. 19:00 - 19:30 0.50 RUNCOM P RUNCMP SERVICE RIG. - INSPECT STABBING BOARD, DRAW WORKS AND SLIPS. - MAINTAIN CONTINUOUS HOLE FILL. Printed 1/19/2011 10:44:23AM I je LA A s = g )f 1 I 1 i� trf Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 23:30 4.00 RUNCOM P RUNCMP CONTINUE TO RIH AS PER RUNNING TALLY. -P /U AND RIH WITH TNT PACKER, HOLD A TOOLBOX WITH FLOOR HANDS ON OPERATION OF TNT PACKER. -RIH WITH X NIPPLE, 3 JTS 5 -1/2 ", GLM #1, GLM #2. - CONTINUE TO RIH PER TALLY TO 2025'. - MAINTAIN CONTINUOUS HOLE FILL. 23:30 - 00:00 0.50 RUNCOM P RUNCMP HOLD AAR ON R/U TO RUN COMPLETION. - DISCUSSED LONG RIG UP TIME AND DISCOVERED THAT THERE WERE FITTINGS MISSING AND HOSES THAT WERE MISPLACED FROM RIG MAINTENANCE WHICH INCREASED RU TIME. - MAINTAIN CONTINUOUS HOLE FILL THROUGHOUT ALL OPERATIONS. LOSSES FOR THE PAST 12 HRS = 596 BBLS 8.5 PPG SEAWATER. -AVERAGE LOSS RATE OF 52 BPH FOR DAY. 10/22/2010 00:00 - 05:00 5.00 RUNCOM P RUNCMP PJSM CONTINUE TO RIH WITH 5 -1/2" 17# 13 CR VAM TOP COMPLETION. -RIH FROM 2025' TO 9679' - MAINTAIN CONTINUOUS HOLE FILL LOSING 42 BPH. -0230 hrs - UR OF 62 BPH. RIH WITH GLM #3. -0400 hrs - L/R OF 60 BPH RIH @ 32 JOINTS HOUR AVERAGE. -0415 hrs - JOINT # 114 RIH 4944'. -0500 hrs - RIH TO 5479' 05:00 - 05:30 0.50 RUNCOM P RUNCMP HOLD WELL CONTROL DRILL. - DISCUSS HOW DRILL WENT AND WHAT _ COULD BE IMPROVED IN AAR. 05:30 - 11:30 6.00 RUNCOM P RUNCMP CONTINUE TO RIH WITH 5 -1/2" 17# 13 CR VAM TOP COMPLETION. -RIH FROM 6479' TO 9651'. 11:30 - 12:30 1.00 RUNCOM P RUNCMP R/U TO LAND TUBING. - CHANGE ELEVATORS. -R/D COMPENSATOR. - M /U LANDING JOINT TO HANGER. - M /U HANGER TO TBG. _ -DRAIN STACK. 12:30 - 13:30 1.00 RUNCOM P RUNCMP LAND TBG HANGER UP WEIGHT 185K DOWN WEIGHT 157K. - RILDS. TBG LANDED AT 9679.34'. DROP BALL AND ROD. B/O LANDING JOINT. -FILL TBG. CLOSE BLIND RAMS. 13:30 - 16:30 3.00 RUNCOM P RUNCMP PJSM - LINE UP ON IA. - PUMP 260 BBLS OF 120 DEGREE SEAWATER WITH CORROSION INHIBITOR AT 5 BPM AND 580 PSI. -SWAP TO RIG PITS AND PUMP 150 BBLS HOT SEAWATER AT 5 BPM AND 760 PSI. -SWAP AND PUMP DOWN TUBING PRESSURING UP TO 3500 PSI IN 27 STROKES TO SET PACKER - HOLD FOR 30 CHARTED MIN. GOOD TEST. -BLEED TUBING DOWN TO 1500 PSI. -SWAP TO PUMP DOWN ANN. PRESSURING UP TO 3500 PSI IN 64 STROKES AND HOLD FOR 30 CHARTED MIN. GOOD TEST. Printed 1/19/2011 10:44:23AM � y ortli Am r1� # BP t X 15 o �perat� on ` Summary `R.epc Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 000P2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) NPT NPT Depth Phase Description of O Date From - To firs Task Code Operations p P P (hr) (ft) 16:30 - 17:00 0.50 RUNCOM P RUNCMP BLEED DOWN ANN. AND TBG TO 0 PSI. -LINE UP TO ANN. SIDE AND PRESSURE UP TO SHEAR OUT THE DCR AT 2550 PSI AND 40 STROKES. -PUMP BOTH WAYS TO CONFIRM GOOD SHEAR. - GOOD. 17:00 - 18:00 1.00 RUNCOM P RUNCMP BLOW DOWN PUMP #2 -P /U DUTCH RISER AND DSM LUBRICATOR. TEST LUBRICATOR ON TOP TO 1500 PSI ROLLING TEST - GOOD. -SET TWC 'AND TEST FROM ABOVE TO 3500 PSI FOR 5 CHARTED MIN. GOOD TEST. -TEST TWC 'FROM BELOW TO 1000 PSI FOR 5 CHARTED MIN. GOOD TEST. 18:00 - 18:30 0.50 RUNCOM P RUNCMP P/U AND B/D DSM LUBRICATOR -P /U DUTCH RISER. -BLOW DOWN CHOKE LINES. 18:30 - 22:30 4.00 BOPSUR P RUNCMP PJSM FOR N/D. -N /D BOPE. BARRIERS ARE TWC AND BALL AND ROD ON RHCM WITH KILL WEIGHT FLUID. -P /U ADAPTER SPOOL. 22:30 - 00:00 1.50 WHSUR P ® WHDTRE PJSM. -N /U AND TEST ADAPTER FLANGE. 10/23/2010 00:00 - 00:30 0.50 WHSUR P WHDTRE CONTINUE TO TEST ADAPTER FLANGE TO 5000 PSI FOR 30 CHARTED MIN. GOOD TEST. 00:30 - 02:00 1.50 WHSUR P WHDTRE PJSM -N /U 7 -1/6" X 6 -3/8" TREE. 02:00 - 04:00 2.00 WHSUR P , WHDTRE PRESSURE TEST TREE TO 5000 PSI AND CHART. - FILLED TREE WITH DIESEL. -USED DIESEL TO TEST TREE TO 5000 PSI FOR 10 CHARTED MIN. GOOD TEST. -TEST MASTER AND SWAB VALVES TO 5000 PSI FOR 5 MIN EACH. GOOD TEST. 04:00 - 07:00 3.00 WHSUR P WHDTRE P/U DSM LUBRICATOR. -DUMP SSV AND SHUT MASTER VALVE. -TEST LUBRICATOR TO 300 PSI LOW AND 3500 PSI HIGH. GOOD TEST. -OPEN SSV AND MASTER VALVE. - ATTEMPT TO PULL TWC. -DUMP SSV AND CLOSE MASTER VALVE. -BREAK OFF DSM LUBRICATOR AND DID NOT RECOVER TWC. RETRIEVAL TOOL FULL OF GREASE. -M /U TO TREE AND RETEST AND REPEAT RETRIEVING TWC. 07:00 - 07:30 0.50 WHSUR P -_ WHDTRE PJSM ON FREEZE PROTECTING WITH LITTLE RED. 07:30 - 10:00 2.50 WHSUR P WHDTRE PRESSURE TEST LRS LINES TO 3500 PSI. -PUMP 150 BBLS OF 80 DEGREE DIESEL DOWN IA. - PUMPED AT 1.5 BPM WITH 100 PSI AT START OF CIRC AND ENDING AT 375 PSI. 10:00 - 11:30 1.50 WHSUR P -_ WHDTRE U -TUBE WELL. -U -TUBE DIESEL FROM IA TO TUBING. 11:30 - 12:00 0.50 WHSUR P WHDTRE P/U DSM LUBRICATOR. Printed 1/19/2011 10:44:23AM rth America - ALASKA - SF? ag 1 t € �- � E 3 3fi. T 31 Operation Summary Report s Common Well Name: 12 -29 AFE No Event Type: WORKOVER (WO) Start Date: 10/10/2010 End Date: X4- 00QP2 -E: (3,224,000.00 ) Project: Prudhoe Bay Site: PB DS 12 Rig Name /No.: DOYON 16 Spud Date/Time: 7/7/2001 12:00:OOAM Rig Release: 10/23/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292108700 Active Datum: 42 : 29 3/31/1984 00:00 @71.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 14:00 2.00 WHSUR P WHDTRE PJSM ON TESTING LUBRICATOR. -DUMP SSV AND CLOSE MASTER VALVE. -TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. - GOOD TEST. -OPEN SSV AND MASTER VALVE. -SET BPV. 14:00 - 15:00 1.00 WHSUR P WHDTRE TEST BPV FROM BELOW. - PRESSURE TEST BPV TO 1000 PSI FROM BELOW FOR 10 CHARTED MIN. -GOOD TEST. 15:00 - 18:00 3.00 WHSUR P WHDTRE SECURE WELL. BLOW E O WE IN CELLAR. PULL SLOP TANK. - REMOVE DOUBLE ANNULAR VALVES. - RELEASE RIG AT 1800 HOURS. IC I Printed 1/19/2011 10:44:23AM TREE = e CM/ WEL L HEA D = _ FMC • SAFETY N WELL REQUIRES A SSSV, 1 2-29 KB. ELEV ---------“ BF. ELEV = KOP = 2950' I V r 4 v ■ 1 Max Angle = 45° @ 6200' 1#■ '4•4 ... 4- /lei 1256' H9-5/8" HES ES CEMENTER I Datum MD = 10373' 14 p. ., • I Datum TVD = 8800 SS PA., A., 1279' H 9-5" BKR ECP 120" CONDUCTOR, 91.5#, H-40, ID = 19.124" 1 110' P _ /8 I 19-5/8" BOWEN CSG PATCH 1 1299' H5-1 ID 19-5/8" CSG, 47#, L-80 HY D 563, ID = 8 681" 1-1 1303' 2018' /2" HES X NIP, = 4.562' GAS LIFT MANDREL 1 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2518' 1 ST MD TVD DEV 1Y PE V LV LATCH PORT DATE 4 3521 3499 20 MMG DOME RK 16 11/08/10 3 6518 5776 45 WIG SO RK 20 11/08/10 2 8405 7177 38 IVIVIG DMY RK 0 10/23/10 Minimum ID = 2.871" @ 10438' 1 9387 7988 31 MVIG DMY RK 0 10/23/10 3-112" DUAL CHECK FLOAT SHOE I 9550' 1-15-1/2" HES X NIP, ID -- 4.562" I o o 9582' H 9-518" X 5-1/2" HES TNT PKR, ID = 4.791" 9615' H5-1/2" HES X NIP, ID = 4.562" 5-1/2" TBG, 17#, 13CR-80 VAM TOP HC, --1 9679" I 1 9679' H5-1 / 2" WLEG, ID = 4.892" 1 .0232 bpf, ID = 4.892" 9797' 1-19-5/8" X 5-1/2" BKR SB-3A HY D PKR, ID = 4,850" 1 0 0 I 9818' H7-5/8" X 4-1/2" X0, ID = 3.958 r I /82 3-3/4" BKR DEPLOY SLV w/ GS, 9910' L El 9852' H T BOT HY D LNR HGR w /TIEBACK, ID = ? I CIM, ID = 3 00" 1 1TOP OF 3-1/2" LNR, CTM, ID = 2,997 1-L 9913' ll I 9908' H4-1/7 OTIS XN NIP, ID = 3.725" 4-112" TBG, 12.6 #, L80, —1 9920' 1 jrA A 'I 1. 1 9921' 1-14-112" WLEG (BEHIND LNR) 1 .0152 bpf , ID = 3 958" t• 41 41 •• 14 I 9921' 1-1ELIVID TT LOGGED 05/05/91 1 41 9-5/8" CSG, 47#, L-80, ID = 8.681' 1-1 10164' 14 1 4' N 11 •1 • 3-1/2" LNR, 9.3#, L-80, --1 10437' 14 11 *1 • 0087 bpf, ID = 2.992" 14 14 14 1 , 41 1 44 PERFORATION SUMMARY 14 41 41 REF LOG: BHCS ON 04/13/84 ! ' 0A v. 10438' —13-1/2" DUAL CHECK F-SHOE, ID - - 2.871" I ANGL E AT TOP PERE 30° @ 10471' Note. Refer to Production DB for historical perf data SIZE SPF INTERVAL Op n/Sgz DATE 1 ' r 3-3/8 4 10370 - 10450 S 09/16/03 '3-3/8 4 10471 - 10486 0 12/22/92 r3318 4 10488 - 10496 0 12/22/92 1 1 PBTD --1 10655' W4'0'0'0 4444444* 44444441 7" LNR, 29#, L-80, .0371 bpf, ID - 6.184" H 10778' teette.t.e DATE - REV BY CONVENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 04/17/84 AUDI 4 ORIGINAL COMPLETION 12/20/10 MB/JMD A DDED SSSV SA FEN NOTE WELL: 12-29 09/16/93 S-16 3-1/2" SCAB LNR SE 01/12/11 PJC CONDUCTOR CORRECTION PERMIT No: '1840320 07/21/01 D-16 RWO API No: 50-029-21087-00-00 10/23/10 D-16 RWO SEC 17, TiON, R15E, 1328' FSL & 104' FWL 11/11/10 DB/JMD DRLG DRAFT CORRECTIONS 11/14/10 MBM/PJC GLV C/O (11/08/10) BP aploration (Alaska) 12/17/10 Schkinkepgr NO. 5667 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2038 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job if Log Description Date BL Color CD NK-65A BCRD-00064 RST . 05 Ca 10/21/10 a , 1 G-09B 11649989 MCNL REDO -- yin! - tillMill 09111/07 ti , a 71111111M 1 06-24A BCRD-00068 MEOW • # .. IIIIGINCIIIIIMillffiY)5M0 i 01-06A BCRD-00063 ii, 10129/10 IMMINtaWiga I G-298 AWJI-00113 pinwmframfg 10/06/10 1 if yjp".M.11 1 W-37A BD88-00048 MCNL 09/12110 1 liejli nil i 1 05-07 BBKA-00077 LDL A ie A 1111=1111111M.11. 1 12-29 B5JR-00067 USIT i , dr •- X 4 mi min a m 4. i immil 1 ( 17-16 , K-126 K-128 BL65-00002 MEM PROD PROFILE _, , a yzrz.,4 % Elm a g no BBSK-00036 PROD PROFILE "' ....,. e 411 11/12J10 1 BCUE-00094 MEM PROD PROFILE .._ • 1-Mreilli 11/22/10 iai in Winp 1 ROW , 1 1 • a 1 K-128 BCUE-00094 MEM PROD PROFILE .f'it Ifr5Ep77I 1 III 12-04A B5JN-00066 Enultrirr:cellOMEINIMINRIMMIESEMIWeNinillaain 1 09-25 AY II-00048 EIZEIE=07211 - 0 - ANiffirEZMWMIIIMIE=MIIMINIIIP_MW 1 06-02 BBKA-00075 EIREIMICZ744-ar MIEKIIMIII•1111111111E 1 18-13B BCZ2-00028 SCMT dC)1 - ,5---4 11/07/10 00 4„, ; 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center L1R2-1 2525 Gambell Street Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 X44414 kik MO i 4 ..O • 0... • ;\ \ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS RECEIVED 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ L TITS Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Ext en s io n ^ Change Approved Program ^ Operat. Shutdown ^ ~' Q . rtn Perforate ^ Re-enter 8~9Ar4Y~l~~ ~~• COR711NSSIOn 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to D Name: Development Q Exploratory ^ 184-0320 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-21087-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028330 PBU 12-29 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10760 feet Plugs (measured) None feet true vertical 9206.69 feet Junk (measured) None feet Effective Depth measured 10498 feet Packer (measured) 9797 true vertical 8980 feet (true vertical) 8348 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2489 13-3/8" 72# L-80 SURFACE - 2517 SURFACE - 2517 4930 2270 Intermediate 10138 9-5/8" 47# L-80 SURFACE - 10162 SURFACE - 8680 6870 4760 Production 926 7"29# L-80 9852 - 10778 8398 - 9221 8160 7020 Liner 528 3-1/2" 9.3# L-80 9910 - 10438 8450 - 8928 10160 10530 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# LL-80 SURFACE - 9763 SURFACE - 8318 Packers and SSSV (type, measured and true vertical depth) 9-5/8" BKR SB-3A 9797 8348 12. Stimulation or cement squeeze summary: Intervals treated (measured): {y Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 98 4614 3435 201 Subsequent to operation: SI 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development 0 Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-139 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 5/26/2010 12-29 184-032 PFRF ATTAC_HMFNT u • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12-29 11/30/84 PER 10,370. 10,426. 8,868.24 8,917.76 12-29 11/30/84 PER 10,440. 10,450. 8,930.03 8,938.78 12-29 11/30/84 PER 10,458. 10,478. 8,945.76 8,963.16 12-29 12/10184 APF 10,492. 10,502. 8,975.29 8,983.94 12-29 12/25/89 SQZ 10,370. 10,502. 8,868.24 8,983.94 12-29 12/29/89 SQZ 10,370. 10,502. 8,868.24 8,983.94 12-29 1/7/90 APF 10,478. 10,482. 8,963.16 8,966.63 12-29 1/8/90 RPF 10,440. 10,450. 8,930.03 8,938.78 12-29 1/8/90 RPF 10,458. 10,478. 8,945.76 8,963.16 12-29 1/8/90 RPF 10,492. 10,502. 8,975.29 8,983.94 12-29 6/3/92 SQZ 10,370. 10,502. 8,868.24 8,983.94 12-29 6/12/92 RPF 10,492. 10,500. 8,975.29 8,982.21 12-29 6/12/92 APF 10,482. 10,490. 8,966.63 8,973.56 12-29 6/12/92 RPF 10,474. 10,482. 8,959.69 8,966.63 12-29 9/28/92 SQZ 10,370. 10,502. 8,868.24 8,983.94 12-29 10/4/92 RPF 10,474. 10,490. 8,959.69 8,973.56 12-29 10/4/92 RPF 10,492. 10,500. 8,975.29 8,982.21 12-29 12/22/92 RPF 10,458. 10,472. 8,945.76 8,957.95 12-29 1/12/01 BPS 10,131. 10,141. 8,651.82 8,660.9 12-29 1/14/01 SPS 10,074. 10,131. 8,600.03 8,651.82 12-29 7/31/01 SPR 10,074. 10,131. 8,600.03 8,651.82 12-29 8/1/01 BPP 10,131. 10,141. 8,651.82 8,660.9 12-29 8/10/01 FIL 10,428. 10,502. 8,919.51 8,983.94 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ • 12-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/25/2010 T/I/O = 750/280/260. Temp = SI. T & IA FL's (Pre slickline). AL is connected & SI @ casing valve, ALP @ 1960 psi. TBG FL @ 2622' (61 bbls). IA FL @ 8695' (381 bbls). ~ SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 4/26/2010 "**WELL SHUT IN ON ARRIVAL"** (gel treatment/pre seal tite) SET 4 1/2" WHIDDON CATCHER SUB ON DEPLOYMENT SLEEVE @ 9877' ~ SLM. PULLED T2-DGLV FROM STA#5 (2982' MD). PULLED T2-LGLV's FROM STA# 4 (3778' MD), STA#3 (683T MD), &STA#2 (8462' MD). ~ PULLED T2-OGLV FROM STA# 1 (9614' MD). I SET RM-DGLV IN STA#5 (2982' MD). SET RM-LGLV IN STA#4 @ 3778' MD). ' SET RM-DGLV IN STA#3 (6837 MD). SET RM-DGLV AT STA#2 (8462' MD). j***CONT. ON 04/27/10 WSR*** 4/27/2010 T/I/0= 200/1990/600. Temp= 90 . Assist w/ POP, monitor and bleed OAP as heeded (Eval Seal-Tite). AL online @ 1960 psi. IA FL @ 3778' (sta # 4). OA FL @ 570' (bbls). See Log for Details. Continued on 4-28-10 AWGR's WSR. 4/27/2010 ***CONT. FROM 04/26/10 WSR"*" (gel treatment/pre seal tite) 9SET RM-DGLV IN STA#1 (9604' SLM/9614' MD) PULLED EMPTY 4-1/2" WHIDDON CATCHER SUB @ 9877' SLM j POP WELL & CONFIRMED FLOWING BEFORE RIG DOWN 4/28/2010 ***WELL LEFT FLOWING, DSO WALK THROUGH UPON DEPARTURE**** ; T/I/O = 220/1960/470. Temp = 100. 24-hour monitor. Measure OAP BUR while online (Eval for Sealtite). AL is connected & online. Monitor & bleed OA as i ' needed through day (See log for details). Continued on 4-29-10 AWGR's WSR. ~~ 4/29/2010 T/1/0=230/1960/500. Temp=hot. Monitor OAP, measure BUR while on line. AL is on line. Integral installed on IA. Continue to monitor OAP and bleed as needed. (see log for details). Continued from 4-28-10 AWGR's WSR. ~ i4 ...~..~._.......~..~v_~~_.__. 4/30/2010 ,~_ T/I/0=220/1960/220. Temp=Hot. Monitor OAP, measure BUR while on line. IAL=online. IA has Intergral installed. Continue Monitor from 12-29-10 (see AWGRs from 12-29-10). Bled OAP multiple times & decreased ALP OAP for ~BUR(see log for details). Job in progress. 4/30/2010 ~T/I/0=220/1960/220. Temp=Hot. Monitor OAP, measure BUR while on line. AL=online. IA has Intergral installed. Continue Monitor from 12-29-10 (see AWGRs from 12-29-10). • • 5/1/2010T/I/O = 200/1970/120. Temp = 107*. Monitor OAP, measure BUR while on line. AL=online. IA has Intergral installed. Continue Monitor from 4-30-10. Bled OAP multiple times to monitor OAP BUR (see log for details). Shift change w/ nights 5-1-10. Seal-Tite to mist IA with gly-flo, will maintain OA open bleed throughout misting operation. 5/2/20101T/I/O=200/1970/45. Temp=72*. Monitor OAP BUR (bleed as needed). Monitor jOAP continue from 5-1-10 WAGR's (see log for details). 5/2/2010~T/I/O= 200/1500/400. Temp= 84" Monitor OAP BUR while on line. (post Seal- Tite mist treatment). Continue to monitor BUR on OA post Seal-Tite mist treatment. See log for details. **Job in Progress*" 5/2/2010 5/3/2010' T/I/0=200/1970/45. Temp=72*. Monitor OAP BUR (bleed as needed). Monitor OAP continue from 5-1-10 WAGR's (see log for details). T/1/0=220/1910/340. Temp=84*. Assist w/ SealTit misting treatment, monitor OAP BUR while on line (seal tite). Misted 42 gallons of SealTite Gly-Flo down the IA w/ gas. Continue to monitor OAP BUR post seal tite mist treatment. Job in progress from 5-2-10 see log for details. • ~.. _ .~ _~ 5/3/2010~T/IA/OA= 220/1900/340 Temp=hot PPPOT-IC (PASS) (Assist Seal-tite) 5/4/2010 PPPOT-IC : RU 1 HP BT onto IC test void 0 psi. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment, did not cycled LDS "ET style" all were in good visual condition. !T/I/O = 210/1320/140 Temp = 84*. Monitor OA BUR (Bleed as needed post sealtite). Continued from night shift. **See log for details"*. 5/4/2010'T/I/O=200/1300/160 Temp=S/I Freeze protect FL/TBG (Repair IAxOA Comm) Pumped 5 bbl neat meth spear & 53 bbls crude down TBG. Pumped 5 bbl neat meth spear, 85 bbls crude & 5 bbl neat meth cap down F/L. DSO & PE notifed. ~DHD on location upon departure, FWP=0/1300/160 **Tags hung. IA & ~ OA=OTG** 5/5/2010' (Continued from day shift) TIO=vac/1260/160. SI. Monitor OAP BUR (bleed as needed post seal tite). Continue to monitor OAP BUR (see log for details). Monitor pressures for 1.5 'hrs with no change. Final WHPs=vac/1260/160 **Job Complete"* SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP 5/5/2010 T/I/O = VAC/1280/160. Temp = 80*. WHPs (eval post sealtite). Checked iWHPs @ 0730. OAP unchanged overnight. iSV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. • 5/5/2010T/I/O = VAC/1280/160. Temp = 80*. WHPs (post sealtite). Checked WHPs @ 1230. WHPS unchanged since this morning. SSV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 5/5/2010 T/I/O = VAC/1230/160. Temp = 40*. WHPs (eval post Sealtite). (18:54 PM) Well SI @ wing valve. IAP decreased 50 psi since 12:30 PM. SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. i i 5/6/2010IT/I/O=Vac/1220/160. Temp=SL WHP's (eval post-Sealtite). WHP's checked @ =12:01 pm. Unchanged since 18:54 hrs on previous days monitor. SSV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. 5/7/2010 T/I/O = Vac/1210/150. Temp = SI. WHPs (eval post sealtite). Monitored at 08:18 a.m. IAP & OAP decreased 10 psi since yesterday. SV, WV =Closed. SSV, MV =Open. IA, OA = OTG. NOVP. ~~~ "'^~~ T/i/O=Vac/1200/160. Temp=S1. WHPs (eval post sealtite) hrs. No change in WHPs since yesterday. SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. Monitor at 0700 5/10/2010 5/15/2010 T/I/0= 220/2050/660. Temp= Hot. Assist Ops with POP, 24-48 hr monitor (post seal-tite). Continued from 5/14/10. IA FL @ 3778' sta # 4 so. OA FL @ 1085'. Monitor OAP till 3 am as per PE. SI well and bleed IAP from 2050 psi to 480 psi in 40 min. Bleed OAP from 860 psi to 200 psi. Monitor for 30 min. IAP remained unchanged. OAP remained unchanged. Final WHPs= 800/480/200. See log for details. DSO SI in well @ manifold building. SV= Closed. WV, SSV, MV= Open. IA, OA= OTG. NOVP. FLUIDS PUMPED BBLS 1 DIESEL 15 METH 138 CRUDE 154 Total 5/13/2010 T/I/O = VAC/1180/165. Temp=S1. OART (post seal-tite treatment). AL is SI @ casing valve, ALP=1980 psi. IA FL @ 450' (20 bbls). OA FL @ 1185' (180 bbls). Bled OAP from 165 psi to 80 psi in 45 min. OA FL unchanged. Job terminated until arrival of open top tank. Job incomplete. Final W HPs=VAC/1180/80. SV,WV=Closed. SSV,MV=Open. IA,OA=OTG. NOVP. T/I/0= 300/1980/120. Temp= SI. Assist Ops POP, 24-48 hr monitor (post Sealtite). IA FL @ 3778' STA #4 DOME (166 bbls). OA FL @ 1085' (63 bbls). DSO P.O.P. @ 1100 hrs. ** Job in progress*" (see log for details) cont. on 5-14-10 (WSR) 5/14/2010~T1O=240/1960/310. Temp=97°. Assist Ops with POP, 24-48 hr monitor (post ~sealtite). Continued from 5/13/10 to monitor and bleed OAP as neccessary. ** Isee log for details**. Job in progress. , ~~~ EE = 5-1/8" FMC GEN 3 WELt_HE3aD = ,,,,,,,,,,,,,,, T...,.,,,.,,,,,,,. FMC ACTUATOR= AXELSON KB. ELEV = 71' BF. ELEV = KOP = 2950' Max Angle = 45 @ 6200' Datum MD = 10374' Datum TV D = 8800' SS 1 ~ ~~ ~ SAFETY NOTES: 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2517' Minimum ID = 2.871" @ 10438' 3-1/2" DUAL CHECK FLOAT SHOE ~~5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID=4.892" i-i 9763' 7" BOT LNR HGR W/ TIEBACK ~ 9852' 3-3/4" BKR DEPLOY SLV W/ GS, CTM, ID = 3.00" 9910' TOP OF 3-112" LNR, CTM, ID = 2.992" 9913' 4-1/2" TBG, 12.6 #, L80, .0152 bpf, ID = 3.958" 9920' 9-518" CSG, 47#, L-80, ID = 8.681" 10162' 3-1 /2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" i~ 1 PERFORATION SUMMARY REF LOG: BHGS ON 04/13/84 ANGLEATTOPPERF: 28 @10370' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10370 - 10426 S 11 /30/84 3-3/8" 4 10440 - 10450 S 01 /08!90 3-3/8" 4 10458 - 10478 S 11 /30!84 3-3/8" 4 10458 - 10478 S 01 /08190 3-3/8" 4 10458 - 10472 O 12/22/92 3-3/8" 4 10474 - 10482 S 06112!92 3-3(8" 4 10470 - 10486 O 10(04(92 3-3/8" 4 10478 - 10482 S 01107/90 3-318" 4 10482-10490 S 06/12/92 3-3/8" 4 10492-10502 S 01(08/90 3-3/8" 4 10492 - 10500 S 06!12/92 3-3/8" 4 10488 - 10496 O 10/04/92 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" i-~ 10778' 5-1/2" HES X NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2982 2979 10 OTIS-LB DMY T-2 0 04/27/10 4 3778 3734 27 OTIS-LB DOME T-2 12 04!27/10 3 6837 6002 44 OTIS-LB DMY T-2 0 04/27/10 2 8462 7223 37 OTIS-LB DMY T-2 0 04127!10 1 9614 5185 28 OTIS-LB DMY T-2 0 04/27110 9763' ~ TOP OF SEAL ASSY, ID = 4.892" 9773' - 5-1/2"' HES XN NIP, ID = 4.455" 9797' 9-5/8" BKR SB-3A PKR, ID = 4.850" 9818' 7-518" X 4-1/2" XO, ID = 3.958" 9908' -14-1/2" OTIS XN NIP, ID = 3.725" 9921' 4-1/2" WLEG (BEHIND LNR 9921' -~MD TT LOGGED 05105/91 1043$' i-i 3-1/2" DUAL CHECK F-SHOE, ID = 2.871" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/17/84 ORIGINAL COMPLETION 04/29/10 CJWPJC GLV GO (04/27/10) 09116!93 CT UNIT 3-112" SCAB LNR SET 07121101 CH/KAK RWO 08/03/01 AD/TP REMOVEIBP/SAND TOP 06/18/09 KNGTLH SOZ PERF CORRECTIONS 08(24/09 TAQ/PJC GLV CORRECTIONS PRUDHOE BAY UNIT WELL: 12-29 PERMIT No: 1840320 API No: 50-029-21087-00 SEC 17, T10N, R15E, 1328' FSL & 104' FWL BP Exploration (Alaska) • • S~~Q~~ 0~ Q~Q~~{Q /~..M..E«w.a.~. David Reem Engineering Team Leader ~ ~ ';~~~ I`V~~ `, L{ `~f~k,fi BP Exploration (Alaska), Inc. P.O. Box 196612 ~ ~?)~ Anchorage, AK 99519-6612 ~(~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-29 l~ ~ Sundry Number: 310-145 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. 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 ~ day of May, 2010. Encl. Sincerely, Daniel T. Seamount, Jr. Chair ,'~ O STATE OF ALASI(A ~ "~,~ ~ C~p _ (~/ 0 ~ ~ ALASK~L AND GAS CONSERVATION COMMIS~N j 6 /b ~.~ APPLICATION FOR SUNDRY APPROVAL ~QY Q ~ 2010 20 AAC 25.280 ~ _e~-.- 1. Type of Request: ^ Abandon ^ Plug for Redrill ^ Perforate New Pool -®Repair Well ^ Change Approved ^ Suspend ^ Plug Perforations ^ Perforate - ®Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate - ®Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. - ®Development ^ Exploratory 184-032 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-0612 50-029-21087-00-00 _ 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 12-29- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028330 ' Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. `PRESENT WELL CONDITION SUMMARY ' Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10778' - 9222' - 10735' 9185' 10498' None Casin Len Size MD TVD Burst Colla Structural Conductor 2 ' 7 Surface 517' 13-3/ " 17' 2 17' 4 30 2 70 Intermediate 1 162' 9-5/8" 101 2' 86 6 7 47 0 Production Liner 2 ' 7" 5 ' - 1 77 ' 839 ' - 222' 1 0 7020 Scab Liner 8' 3-112" 910' - 1 43 ' 451' - 8928' 101 1 30 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10458' - 10496' 8946' - 8979' S-1/2", 17# x 4-1/2", 12.6# L-80 9921' Packers and SSSV Type: 9-5/8" Baker'SB-3A' packer Packers and SSSV 9797' / 8348' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 17, 2010 , ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Bork 564-5683 Printed Nam avid Ree Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ,5' C' Z~/d Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: No 'ty Commission so that a representative may witness ~ /~ ,~1([~~ Sundry Number: 3 V + i ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance - ~. 35oa PTA ,~~P~sf ~ r- Other: 7 54O s c. ~n n ~-~K / eg ~' ~ H~`'~..~ * G. P Subsequent Form Required: / ~ . [10 G/ APPROVED BY / a /` (~ ~ / Approved By: COMMISSIONER THE COMMISSION Date 6 Forrn 10-403 Revi~c9'~`DNIrS MAY 10 ~ / O Submit In Duplicate ORIGINAL -5~ ~~ ~~ -~/~ C~ by GP~~~.8: 12-29 Rig Workover (Repair IA x OA communication) C~ Scope of Work: Pull 5-'h" L-80 completion. Run USIT log to find TOC, cut and pull 9-5/8" casing as deep as possible. Tie back 9-5/8" casing and cement to surface. Test casing to 3,500 psi. Run 5-~h" 13Cr-80 completion. Engineer: David Bjork MASP: 2,386 psi Well Type: Producer Estimated Start Date: May 17th, 2010 Pre-Rig Work Reauest: S 1 Set 5-Yz" PXN plug at 9,773'. Dump 10' of sluggits on top of PXN. Set junk catcher on to of slu its. F 2 CMIT-T x IA to 3500 si for 30 minutes. MIT-OA to 1000 si for 30 minutes. E 3 Power Jet cut 5-'/z" L-80 tubing at -9,644' MD, ~10' down first full joint below the GLM at 9,614. Reference tubin tall dated 7/21/01 . F 4 Circulate well with clean seawater and freeze rotect to 2000'. F 5 CMIT T x IA to 500 si for 10 minutes ost cut. W 6 Check all lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 7 Set a BPV in the tubin han er. Proposed Procedure 1. MIRU. ND tree. NU and test BOPE (consisting of annular, 3-1/2" x 6" VBRs, blind/shear) to 250 psi ~ low/3,500 psi high. Circulate out freeze protection and circulate seawater. ° 2. Pull and LD tubing string to the cut. 3. RU wireline and run USIT from -3000' to surface. 4. Run 9-5/8" RBP and set --100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Dump ~50 ft of sand on RBP. Plote: VBRs will not be changed to 9-5/8" as there are two p(~ tested barriers to the reservoir. 5. Mechanically cut 9-5/8" casing in 1 st full joint above top of cement. Pull casing through stack. Dress' stub in preparation of casing overshot. 6. Run in with 9-5/8", 47#, L-80 casing and tie-in to dressed stub. 7. Cement new 9-5/8" casing to surface. , 8. Drill out 9-518" float equipment. 9. Cleanout above 9-5/8" RBP. Test tieback to 3500 psi for 30 minutes. Pull 9-5/8" RBP: 10. Test the casing to 3,500 psi. 11. Dress 5-'h" tubing stub 12. Recover 5-'/z"junk catcher 13. Run 5-'/z" 13Cr-80 stacked packer completion - 14. Displace the IA to packer fluid and set the packer. 15. Test tubing and IA to 3500 psi for 30 charted minutes. Freeze protect to 2,200' MD. 16. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. I TREE = 5-1/8" FMC GEN 3 WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 71' BF. ELEV _ KOP = 2950' Max Angle = 45 @ 6200' Datum MD = 10374' Datum TV D = 8800' SS ~ 12-29 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2517' E- Minimum iD = 2.871" @ 10438' 3-1/2" DUAL CHECK FLOAT SHOE 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~-j 97f33' 7" BOT LNR HGR W/ TIEBACK ~ 9$52' 3-3/4" BKR DEPLOY SLV W/ GS, CTM, ID = 3.00" 9910' TOP OF 3-1/2" LNR, CTM, ID = 2.992" 9913' 4-1/2" TBG, 12.6 #, L80, .0152 bpf, ID = 3.958" 9920' 9-518" CSG, 47#, L-80, ID = 8.681 " 10162' ~~3-112" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" i-j 10437' PERFORATION SUMMARY REF LOG: BRCS ON 04/13/84 ANGLE AT TOP PERF: 28 @10370' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-3/8" 4 10370 - 10426 S 11 /30/84 3-3/8" 4 10440 - 10450 S 01/08/90 3-3/8" 4 10458 - 10478 S 11 /30/84 3-3/8" 4 10458 - 10478 S 01 /08/90 3-3/8" 4 10458 - 10472 O 12/22/92 3-3/8" 4 10474 - 10482 S 06/12/92 3-3/8" 4 10470 - 10486 O 10/04/92 3-3/8" 4 10478 - 10482 S 01 /07190 3-3/8" 4 10482 - 10490 S 06/12/92 3-3/8" 4 10492 - 10502 S 01 /08/90 3-3/8" 4 10492 - 10500 S 06/12/92 3-3/8" 4 10488 - 10496 O 10/04/92 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 10778' SAFETY NOT 2000' ~ 5-1/2" HES X NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2982 2979 10 OTIS-LB DMY T-2 0 04/27110 4 3778 3734 27 OTIS-LB DOME T-2 12 04/27/10 3 6837 6002 44 OTIS-LB DMY T-2 0 . 04/27/10 2 8462 7223 37 OTIS-LB DMY T-2 0 04/27/10 1 9614 5185. 28 OTIS-LB DMY T-2 0 04/27/10 9763' H TOP OF SEAL ASSY, ID = 4.892" 9773' 5-1/2" HES XN NIP, ID = 4.455" 9797' 9-5/8" 8KR SB-3A PKR, iD = 4.850" 9$1 $' 7-5/8" X 4-1/2" XO, ID = 3.958" { 990$' ]- ~4-1/2" OT1S XN NIP, ID = 3.725" 9921' 4-1i2" WLEG (BEHIND LNR) 9921' ELMD TT LOGGED 05/05/91 1043$' ~--~ 3-1/2" DUAL CHECK F-SHOE, ID = 2.871" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/17/84 ORIGINAL COMPLETION 04/29/10 CJWPJC GLV GO (04/27!10) 09116/93 CT UNIT 3-112" SCAB LNR SET 07/21/01 CWKAK RWO 08/03/01 AD/TP REMOV E IBP/SAND TOP 06/18/09 KNGTLH SOZ PERF CORRECTIONS 08/24/09 TAQ/PJC GLV CORRECTIONS PRUDHOE BAY UNIT WELL: 12-29 PERMfT No: 1840320 API No: 50-029-21087-00 SEC 17, T10N, R15E, 1328' FSL 8 104' FWL BP Exploration {Alaska} TREE _ ~ 5-1/8" FMC GEN 3 WELLHEAD= -!~~~ ACT~AT_OR --- KB. ELEV _ -- AXELS^?i - -- BF. ELEV = -- -- KOP = 2950' Max Angle= 45 @ 6200' _ Datum MD = Datum TV D = 10374' 8800' SS 9-5/8" Bowen Casing Patch - 2400' 9-5/8" 47#, L-80, Hydril 563, ID=8.681" 2450' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2517' 5-1/2" 17f. i3Cr-80, VamTo HG --_ 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~-~ 97fi3' SAFETY NOTE . 2,000' S-1/2" HES X NIP, ID = 4.562" GAS LIFT M4NDRELS ST MD ND DEV TYFE VLV LATCH PORT DATE 4 3522 3550 3 6552 5800 2 8434 7200 1 9362 7966 9,4$$' 5-1/2" HES X NIP, ID = 4.562" 9,519' 9-5/8"x 5-1/2" HES TNT Pkr - 9,553' 5-112" HES X NIP,ID = 4.562" x,627' 9-5/8" X 5-112" UNI;;UEOVERSHOT ~ '!' 9773' -~5-1/2" HES XN NIP, ID = 4.455" 9797' 9-5/8" BKR SB-3A PKR, ID = 4.850" 7" BOT LNR HGR W/ TIEBACK 9$52' 9818' 7-5/8" X 4-1/2" XO, ID = 3.958" 3-3/4" BKR DEPLOY SLV W/ GS, CTM, ID = 3.00" ~-1 9910, TOP OF 3-112" LNR, CTM, ID = 2.992" 9913' 4-1/2" TBG, 12.6 #, L80, .0152 bpf, ID = 3.958" 9920' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-{ 101 3-1/2" LNR, 9.3#, L-80, .0087 bpf, !D = 2.992" ~-j 10437' # 12-29 PROPOSED 9-5/8" HES ES Cementer - 2360' 9-5/8" BKR ECP - 2380' PERFORATION SUMMARY REF LOG: BRCS ON 04!13/84 ANGLE AT TOP PERF: 28 @ 10370' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10370 - 10426 S 11 /30/84 3-3/8" 4 10440 - 10450 S 01/08/90 3-3/8" 4 10458-10478 S 11/30/84 3-318" 4 10458-10478 S 01/08/90 3-3/8" 4 10458 - 10472 O 12/22/92 3-3/8" 4 10474 - 10482 S 06/12!92 3-3/8" 4 10470 - 10486 O 10/04/92 3-3/8" 4 10478 - 10482 S 01 /07/90 3-3/8" 4 10482 - 10490 S 06/12/92 3-3/8" 4 10492-10502 S 01/08/90 3-3/8" 4 10492 - 10500 S 06/12/92 3-3/8" 4 10488-10496 O 10/04/92 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 077$' 9908' H4-1/2" OTIS XN NIP, ID = 3.725" 9921' -~4-1/2" WLEG (BEHIND LNR) 9921' ELMD TT LOGGED 05/05/91 10438' H 3-1/2" DUAL CHECK F-SHOE, ID = 2.871" Minimum ID = 2,871" @ 10438' 3-1 /2" CUAL CHECK FLOAT SHOE DATE REV 8Y COMMENTS DATE REV BY COMMENTS 04/17/84 ORIGINAL COMPLETION 04/29!10 CJWPJC GLV GO (04/27/10) 09/16/93 CT UNIT 3-112" SCAB LNR SET 07/21/01 CH/KAK RWO 08/03/01 AD/TP REMOVEIBP/SAND70P 06/18/09 KNGTLH SOZ PERF CORRECTIONS 08/24/09 TACUPJC GLV CORRECTIONS PRUDHOE BAY UNf)• WELL: 12-29 PERMfT No: 1840320 API No: 50-029-21087-00 SEC 17, T10N, R15E, 1328' FSL & 104' FWL BP Exploration (Alaska) • • Taylor Wellman Well Integrity Engineer . , , ,{.~-_: ~ ~' ~ ~~ BP Exploration (Alaska), Inc. ~` °~ ` ~^ ~~~ P.O. Box 196612 ~~ Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-29 Sundry Number: 310-139 Dear Mr. Wellman: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ?day of April, 2010. Encl. ~~~~S~ AND GAS CONSERVAT ON COMMISSI ~/40 ~D ~~~ /D APPLICATION FOR SUNDRY APPROVALS ~~'v APR 2 ~ 2~1ll - 20 AAC 2s.2so 1. Type of Reques : A ando ~~ppPlug for Redrill ^ Perforate New Pool ^ Repair Well ^ ~ Change Approved Program ^ '~ Dl~ ~ ~kp "1~(ug Pertorations ^ Perforate ^ PuII Tubing ^ Time Extension ^ Operat~?1'~~n ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ ^ Other: SealTite 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development a Exploratory ^ 184-0320 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21087-00-00 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: Spacing Exception Required? Yes ^ No ^ PBU 12-29 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028330 - PRUDHOE BAY Field / PRUDHOE OIL Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10778 ' 9992 ~' 10498 8980 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 110 20" surtace 110 surtace 110 Surface 2489 13-3/8" 72# L-80 surface 2517 surface 2517 4930 2270 Production 10138 9-5/8" 47# L-80 surface 10162 surface 8680 6870 4760 Liner 926 7"29# L-80 9852 10778 8398 9221 8160 7020 Scab Liner 528 3-1/2" 9.3# L-80 9910 10438 8450 8928 10160 10530 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# L-80 URFACI 9763 Packers and SSSV Tvoe: 9-5/8" bkr SB-3A Packers and SSSV MD and ND (ftl: 9797 8348 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^/ - Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/28/2010 Oil ^~ - Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Wellman Printed Name Taylor Wellman Title Well Integrity Engineer Signatur Phone Date ~~`~ 659-5098 4/21/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O -~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: , ~ . Y~ y j APPROVED BY ~ r `\ COMMISSIONER THE COMMISSION Approved by: ~~~~/ ~~ ~ Date: ~' I/ ~ v Form 10-4 e s /2 p' "" K •' ~~ """ ~ R I G i ~I A L ~~ ~~? /v Submit in Du licate 12-29 184-032 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12-29 11/30/84 PER 10,370. 10,426. 8,868.24 8,917.76 12-29 11/30/84 PER 10,440. 10,450. 8,930.03 8,938.78 12-29 11/30/84 PER 10,458. 10,478. 8,945.76 8,963.16 12-29 12/10/84 APF 10,492. 10,502. 8,975.29 8,983.94 12-29 12/25/89 SQZ 10,370. 10,502. 8,868.24 8,983.94 12-29 12/29/89 SQZ 10,370. 10,502. 8,868.24 8,983.94 12-29 1/7/90 APF 10,478. 10,482. 8,963.16 8,966.63 12-29 1/8/90 RPF 10,440. 10,450. 8,930.03 8,938.78 12-29 1/8/90 RPF 10,458. 10,478. 8,945.76 8,963.16 12-29 1/8/90 RPF 10,492. 10,502. 8,975.29 8,983.94 12-29 6/3/92 SQZ 10,370. 10,502. 8,868.24 8,983.94 12-29 6/12/92 RPF 10,492. 10,500. 8,975.29 8,982.21 12-29 6/12/92 APF 10,482. 10,490. 8,966.63 8,973.56 12-29 6/12/92 RPF 10,474. 10,482. 8,959.69 8,966.63 12-29 9/28/92 SQZ 10,370. 10,502. 8,868.24 8,983.94 12-29 10/4/92 RPF 10,474. 10,490. 8,959.69 8,973.56 12-29 10/4/92 RPF 10,492. 10,500. 8,975.29 8,982.21 12-29 12/22/92 RPF 10,458. 10,472. 8,945.76 8,957.95 12-29 1/12/01 BPS 10,131. 10,141. 8,651.82 8,660.9 12-29 1/14/01 SPS 10,074. 10,131. 8,600.03 8,651.82 12-29 7/31/01 SPR 10,074. 10,131. 8,600.03 8,651.82 12-29 8/1/01 BPP 10,131. 10,141. 8,651.82 8,660.9 12-29 8/10/01 FIL 10,428. 10,502. 8,919.51 8,983.94 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE by ~ To: J. Bixby/C. Olsen GPB Well Ops Team Leaders From: Tiffany Quy /Taylor Wellman Well Integrity Project Engineers Subject: 12-29 Seal-Tite Misting Re-treatment PBWELTREE Please perform the following procedure(s): • April 21, 2010 Est. Cost: $50M IOR: 500 1. S Set DGLV in STA#1-4, Set LGLV in STA#5 (see procedure for full details 2. F Load IA to dee est LGLV Have DHD assist with FL shot 2. W Pump Seal-Tite misting treatment. Cameron to assist with IC void ressure monitorin . 3. D Perform DART Status: PAL Last Test 392 BOPD, 4460 BWPD, WC - 92% Max Deviation: 45° C«~ 6200'MD Min ID: 2.871"C~ 10,438' MD, 3-1/2" Dual Check F-Shoe Last TD Tag: 10498' MD 5/27/2005 (slm) Last Ops: Assist w/ POP -post Seal-Tite (0322-2010) Last Downhole Ops: Pull PX plug from tubing (9/05/09) Latest H2S value: 10 ppm (7/7/2009) Est. BHP: 3250 psi @ 8800' (2008) (7.12 ppg equivalent) Purpose: To complete the repair treatment for downhole communication from production casing to surface casing using a misted Seal-Tite procedure and sealants. History: 12-29 was drilled in 04/1984. The well had a RWO 01/1990 when the packer and tubing hanger failed (also had to fix top of 9-5/8 and 13-3/8"). A GSO squeeze was also done (12/25/1989) during that RWO. The well developed a 9-5/8" leak right after that RWO so had to have another RWO in 09/1990 to cut, pull, and replace the 9-5/8" again. The well was squeezed again on 06/03/1992 and 09/28/1992. On 09/18/1993 a CTU 3-1/2" scab liner was installed and cemented over the top perfs. A third RWO was done 07/2001 to install new tubing. The well used to be waivered, but that was canceled 01 /15/2006 since the annular pressures were not tracking. The well continued producing naturally until early fall 2009 when it would not flow after being shut in for a TAR. The well now requires gas lift to flow and has unmanageable IAxOA when on gas lift. ~ Well Integrity History > 01/11/06: Bled OAP to CLP -BUR negligible. > 01/15/06: IAxOA Waiver cancelled, OAP behavior does not follow IAP. > 08/08/09: PPPOT-IC Passed to 3500 psi > 08/14/09: Gas sample taken on IA & OA -results can not be found, need to resample > 08/31/09: TTP set @ 9773', MITT Passed, CMIT-TxIA Failed > 09/01/09: CMIT-TxIA Passed to 3000 psi > 09/05/09: Pull TTP from 9773' > 10/01/09: IA & OA gas samples indicate IAxOA comm > 12/02/09: PPPOT-T Passed to 5000 psi > 03/23/10: OA BUR 200 psi/hr This procedure will attempt to repair the IA x OA communication by flowing the well with gas lift managing the bleeds on the OA with DHD. Once the well is warmed sufficiently to establish a gas leak rate, the gas rate will be throttled by use of gas service choke and flow meter by DHD and aSeal-Tite technician. Once the gas lift rates can be sufficiently controlled, aSeal-Tite injection tool will be installed on the IA companion valve and be treated using, time-activated and , pressure-activated sealants from Sealtite commingled with the injected gas lift_ stream. Contact Gerald Murphy or Taylor Wellman at x5098 or harmony 2418 with any questions or comments. TIO Plot from 04/21/2009 until 04/21/2010 Walt 12-29 nuc Oih: t W( -~ rn~ I s a +- OA OOA ~ OOOA i On Page 2 of 7 • Operational Steps: Wellhead -DONE 1. PPPOT-T to 5000 psi -Done (12-02-09) 2. Install a companion valve on the IA with a tapped blind flange (1" NPT tapped hole) -Done (12-03-09) DHD -DONE 3. Monitor for pressure build up. -Done (03-22-10) Slickline and Operations 4. Pull LGLV's from STA #1-4 and set DGLV's. 5. Pull DGLV from STA #5 C~ 2982' MD and set LGLV. 6. Operations to POP well and monitor for flow. a. If well flows and begins to warm, RDMO Slickline unit. b. If well will not flow and cycles gas, pull the next deepest GLV and set a LGLV. c. Repeat this step until the well flows and begins to warm. Fullbore Pumping ' 7. Load the IA with crude up to the deepest installed LGLV. Operations and DHD 8. POP well and flow for 1-2 days to warm wellbore and establish IA x OA communication. a. DHD to be on location to monitor and record OA pressure build up and bleed as necessary with full gas lift rate applied to the well. b. Choke back the gas lift pressure to near the closure pressure of the GLV (contact GLE @x5863 or harmony 2405 to confirm the set pressure). Record an approximate gas lift rate. Continue to monitor and record OA pressure build up rates and well temperature. Seal-Tite and DHD 9. Rig up misting tool to IA valve. 10.Treat IA utilizing attached Seal-Tite procedure. a. Well to be shut in for 5 days to allow sealant to cure. b. Insure tubing and flowline are freeze protected during curing phase. DHD 11. Perform OART once well returns to production Page 3 of 7 • • Proposed Procedure Casing Leak Repair 12-29 Gas Lift Leak Prepared by Seal-Tite International April 8, 2010 Field: Prudhoe Bay Well: 12-29 Objectives Repair IA/OA communication Gas Lift Setup: In order to reduce annular volume, the gas lift system will be revised as follows: o Dummy all gas lift valves except the top station o Put well on production at maximum gas lift injection rate and determine if sufficient lift is available for well to produce and heat up. Monitor OA build rate to determine if leak is active. o If well does not produce adequately, remove the dummy from the next highest station and replace with a live valve. Repeat the above step to determine if the well will produce sufficient to activate the IA/OA leak. o Once the proper lift valve has been determined, insure that the IA is loaded with fluid to just below the lowest active valve. 2. Mist Injection Setup: In the first attempt, Well Test equipment was used to provide the reduced injection gas rates. For this attempt, a simplified setup will be used incorporating a sidestream taken off the gas lift manifold, a properly sized Merla adjustable choke, and a high pressure hose routed to a T on the sealant injection manifold. A drawing of the rig up is provided below. The adjustable injection quill will not be used due to problems on the first attempt - instead the nozzle will be located at a fixed position just upstream of the outer casing valve gate. Page 4 of 7 • Gas list IA ~r31ve (closed wh ile heating) Gaa if-nsar ~ \\` ~' ~ --- '/ Dua L~'dehrc~ Ydel l 2 1Q Infection cu 11 assembl•~ vYi th bleec "' ,gauge, an ~ gastie in pert rvJ blcck t %' ChJ G h case CAval•re with / rFS• na, ~F /~ f/ l,pstrearnlDorrnstream j•"CMG rose gau gee ~/ \ ~ ~ \, r ~ ~ ~- ~ ~ • Mcrla ch ol<c 3. Take pressure readings as follows: - Tubing Pressure - Inner Annulus - Outer Annulus Open ~Ise~~to tank 4. Locate the IC hanger test ports. Rig up pressure monitoring assembly on hanger void to ensure that hanger seals stay functional during the remaining procedure. (Periodic monitoring of the IC hanger void will be conducted to ensure hanger seal integrity. Continuous monitoring will not be required for the duration of the job). 5. R/U Seal-Tite atomizing assembly on wellhead. Test all equipment to full gas lift pressure for 15 minutes against closed casing valve. 6. Open "gas lift" casing valve and put well on production at optimum rate for maximum production. 7. R/U OA to a bleed tank and monitor returns. Ensure that IA/OA leak is active and the build up rate (BUR) is approximately 140 psi/hour. If the OA BUR is significantly less than this contact Seal-Tite prior to commencing pumping operations. Allow OA to build to 500 psi before bleeding, and bleed to 100 psi then close in again. Record BUR for a baseline data point. 8. The IA should be at full gas lift rate at this time, with injection pressure of +- 1800 psi. Page 5 of 7 9. Bleed OA to tank and leave on continuous bleed. 10. Close "Gas Lift" casing valve and open "Misting/Sidestream Gas Lift" casing valve. 11. Begin gas injection through sidestream system. Adjust Merla choke to provide a gas lift injection rate of +- 500 MSCFPD. NOTE: Previous testing indicates that once the gas lift injection rate drops below 1 MMSCFPD the well begins loading up. This testing also indicates that the well stays hot for several hours and the leak stays active at high rates for over 12 hours. This performance was confirmed in the first repair attempt. In order to maximum IA pressure, back pressure should be held on the tubing side as the gas lift rate is reduced. 12. Begin injection of surfactant through atomizing quill at a rate of 800 ml/min. Continue until a total of 20 gallons of surfactant has been injected (approximately 90 minutes). This is designed to coat the casing walls down to the leak depth and optimize sealant consumption. 13. Begin injection of sealant through atomizing quill at a rate of 800 ml/min, which should require injection pressure of +- 100 psi over IA pressure. Gas Lift rate should be maintained at +- 500 MSCFPD. 14.Continue to monitor OA pressure for signs that the sealant has reached the leak location. As soon as sealant activity is observed, or 2 hours of sealant injection (whichever comes first) proceed to the next step. 15. Reduce gas lift injection rate to +- 200 MSCFPD. Reduce sealant injection rate to 200 ml/min. 16.Once sealant activity is observed (as shown by a decrease in the OA BUR), continue sealant injection as per the above 200 ml/min rate until the OA can be bled to zero with no more than 5 psi buildup in 1 hour. Conduct bubble tests or similar every 15 minutes to ensure that OA PBU is continuing to reduce. 17.Once all signs point to complete elimination of IA gas feed-in to the OA, continue sealant and gas injection for an additional 30 minutes, then shut down pumping and shut in the well. At this time full gas lift pressure should be on the IA, and should not be bled down. 18. Continue to monitor the OA. Once OA pressure reaches 500 psi bleed to 100 psi and then close in again. Consult with STI office, continued sealant injection may be required. Once pressure is stabilized at no more than 500psi, shut down and rig down the sealant atomizing quill. NOTE: If stopping Gly-Flo injection for longer than 15-20 minutes and prior to final shut down, flush atomizing quill with 2 gallons of diesel to prevent blockage of the quill. Page 6 of 7 19. Allow sealant to cure for 5 days with well shut in. Do not bleed down IA. During this curing period monitor the OA pressure and if pressure reaches 700 psi, bleed OA to 400 psi then shut in and resume OA pressure monitor. 20. After 5 days, prepare to resume IA injection, do not bleed OA unless required for operational/safety purposes. 21. Begin slowly applying gas lift pressure at +- 250 MSCFPD until normal gas lift pressure is reached. Over the course of 10 hours, .slowly increase gas lift injection rate until normal gas lift injection rate is achieved. 22.If no signs of IA / OA communication are observed, R/U wireline and restore gas lift valves to pre-job status. 23. Return well to normal operations. DNC updated 4/8/10 Page 7 of 7 = 5-118" FMC GE ELLHEAD = FMC ACTUATOR =_ AXELSON ~ KB, ELEV-= 71' BF. ELEV = KOP = 2950' Max Angle = 45 @ 6200' Datum MD = 10374' Datum TVD = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" I- 2517' Minimum ID = 2.871" @ 10438' 3-1 /2" DUAL CHECK FLOAT SHOE ~ 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 7" BOT LNR HGR W/ TIEBACK ~ 9$52' 3-314" BKR DEPLOY SLV W/ GS, CTM, ID = 3.00" 9910' TOP OF 3-1/2" LNR, CTM, ID = 2.992" 9913' 4-112" TBG, 12.6 #, L80, .0152 bpf, ID = 3.958" 9920' 9-518" CSG, 47#, L-80, ID = 8.681" 10162' 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" I--I 10437' PERFORATION SUMMARY REF LOG: BHCS ON 04/13/84 ANGLE AT TOP PERF: 28 @ 10370' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10370 - 10426 S 11/30/84 3-3/8" 4 10440 - 10450 S 01/08/90 3-318" 4 10458 - 10478 S 11 /30/84 3-318" 4 10458 - 10478 S 01!08/90 3-318" 4 10458 - 10472 0 12!22!92 3-3/8" 4 10474 - 10482 S 06!12/92 3-3/8" 4 10470 - 10486 O 10/04/92 3-3/8" 4 10478 - 10482 S 01/07/90 3-318" 4 10482 - 10490 S 06!12!92 3-3/8" 4 10492 - 10502 S 01/08/90 3-3/8" 4 10492 - 10500 S 06/12/92 3-3/8" 4 10488 - 10496 O 10/04192 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1077$' 12-29 ~ 3-112" DUAL CHECK F-SHOE, ID = 2.871" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 04/17/84 ORIGINAL COMPLETION 09/16!93 CT UNIT 3-112" SCAB LNR SET 07/21!01 CWKAK RWO 08/03/01 AD1TP REMOVE IBP/SAND TOP 06/18/09 KNGTLH SOZ PERF CORRECTIONS 08!24/09 TAOIPJC GLV CORRECTIONS PRUDHOE BAY UNIT WELL: 12-29 PERMff No: "1840320 API No: 50-029-21087-00 SEC 17, T10N, R15E, 1328' FSL & 104' FWL BP Exploration {Alaska) SAFETY NOTES: 2000' ~-~ 5-112" HES X NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2982 2908 11 OTIS-LB DMY T-2 0 07(26101 4 3778 3662 27 OTIS-LB DOME T-2 16 08/26101 3 6837 5931 44 OTIS-LB DOME T-2 16 08/26/01 2 8462 7151 38 OTIS-LB DOME T-2 16 08/26(01 1 9614 8113 27 OTIS-LB SO T-2 24 08/26/01 9763' TOP OF SEAL ASSY, ID = 4.892" 9773' S-1/2" HES XN NIP, ID = 4.455" g7g7' 9-5/8" BKR SB-3A PKR, ID = 4,850" 9818' 7-5/8" X 4-112" XO, ID = 3.958" 990$' ~ 4-1 /2" OTIS XN NIP, ID = 3.725" 9921' 4-1/2" WLEG (BEHIND LNR) gg21' ELMD TT LOGGED 05105!91 NOT OPERABLE: 12-29 (PTD #1840) IAxOA comm unmanageable post ~1-Tite treatment Page 1 g~~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com) ~~~, 3I ~~ ~) c Sent: Thursday, March 25, 2010 3:37 PM To: NSU, ADW Well Integrity Engineer; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, F~1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Walls Opt Eng; GPB, Optimization Engr, GPB, EOC Specialists; GPB, FS2 DS Operators; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: Cooper, Katrina N; Quy, Tiffany; Wellman, Taylor T Subject: NOT OPERABLE: 12-29 (PTD #1840320) IAxOA comm unmanageable post Seal-Tite treatment All, Producer 12-29 (PTD #1840320] as recently treated with Seal-Tite to mitigate the IAxOA communication. The IAxOA communication remains unmanageable by bleeds post treatment. a well has been reclassified as Not Operable and will remain shut-in until future remedial work is conducted. ~'~ Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday,' February 18, 2010 12:41 PM To: GPB, Area Mgr East (FSi/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)' Cc: Cooper, Katrina N; Quy, Tiffany; Wellman, Taylor T; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 12-29 (PTD #1840320) POP for Treatment for IAxOA Communication All, Well 12-29 (P7D #1840320) has confirmed IAxOA communication when online. Now that the flowline has been thawed, the well is ready to be put on production in preparation for aSeal-Tie treatment to attempt to mitigate the IAxOA communication. While online, Operators and DHD will work together to monitor and maintain the OA pressure. The well has been reclassified as Under Evaluation so that the well may be returned to production to prepare for the Seal-Tite treatment. Please POP the well when convenient. Thank you, ,,Anna ~u6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Rhone: (907} 659-5'102 3/31/2010 UNDER EVALUATION: 12-29 (~D #1840320) POP for Treatment for I~OA Commu... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.c~] ( / Sent: Thursday, February 18, 2010 12:41 PM ~' ~I ~ ~ l ~ ~ To: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators; Regg,. James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: Cooper, Katrina N; Quy, Tiffany; Wellman, Taylor T; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 12-29 (PTD #1840320) POP for Treatment for IAxOA Communication All, Well 12-29 (PTD #1840320) has confirmed IAxOA communication when online.. Now that the flowline has been thawed, the well is ready to be put on production in prepara ion or a Seal-Tie treatment to attempt to mitigate the IAxOA communication. While online, Operators and DHD will work together to monitor and maintain the OA pressure. The well has been reclassified as Under Evaluation so that the well may be returned to production to prepare for the Seal-Tite treatment. Please POP the well when convenient. Thank you, Anna Dude, ~.~. (alt Torin Roschinger) Well Integrity Coord'enator GPB Wells Group ` > , ~~;~~+ °~ ~ ~ 3W Phone: {907) 659-5102 t~:.7.5°+~~~ Pager: {907) 659-5100 x1154 2/19/2010 Schlumberger 5~#'t.\j~Ji~ED ':~, u RECEIVED OCT 1 6 2006 NO. 3990 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: .~ Oil &: Gas Cons. Commission Anchorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 }~zl-03d Field: Prudhoe Bay C Well Job# Lo!! Description Date BL Co or D 12·29 11072867 INJECTION PROFILE 07/07/05 1 Z-19A 11212887 US IT 09/12/06 1 MPH·14 11414383 LDL 09/21/06 1 Z-23B 40010787 OH EDIT OF MWD/LWD 09/04/04 2 1 P-27 40010459 OH EDIT OF MWD/LWD OS/21/04 2 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 10/12/06 . . FW: 12-29 Cancel Waiver e e fìï1J~ \ cß4- 032-- Subject: FW: 12-29 Cancel Waiver From: "NSU, ADW Wen Integrity Engineer" <NSUADWWe1lIntegrityEngineer@BP.com> Date: Sun, 15 Jan 2006 16:16:28 -0900, T¿~ ít.d~~~erg;R Steven" <Steÿt .RÔ$Sberg@BP.coffi~:li'm' reg~admin.stat~.;ill<:. ..." wirttdlLau~ert@admin.state.ak.u "NŠ:u,ADW w~i Opera{onsSupervisor" ;f" ..'..': <N~d»DWWell0perationsSµ e: sor@ßP.col1l;::"~"GPB, W~l~s Op{Eng",.}*. ..... <GPBWellsOptEng@a;p "B, Optimi'···· n <dPBOptimizatiQn~~gr@]3P.com>, "GPB,::FS1!SIP/STP' GPBFSITL ··...c·· PB, FSI :ijß'" ." Lêäd" '. <GPBfSlDSOpsLead . , ,,,(JPB, FSI :d§12 r"<GPBF§'Ì. 2(i)perator ". ~~;æi~~?œ22;;r~~;B:~~~ Paul A:i::!::~l~!:!Du~:" ..... Anµa}:':" <Anna.Dube(@BP.com;¡r, "Frazi , Niëholå~B" <Nicþolas.F~ier@:B,P.c,~m>, "Holt, RyaitP:1 (V:$C~)" 4'yan.Holt@BP.com~, "H't~h' Andrea (VECOtlhugha4@BP.co~, "Jqþ.r1son, Roland D (VEtO)'~<Joþ.r1sRD2@BP.c01n>, "Tf-utt,Ely Z. (VECO}~;<lucke~@BP.com>, "~:çOLLUM, ~ODY 0 (~Eçlr <fO~rMcCollum·'. '? "~orse, Kenh~.~VEf~~:';';.~MorseK'f@BP,cOI{t Parks,·:Kevm D tVECO) <ParksJ<D@BP...... Pmk·", Bruce M ('l~(!~:) <',1(>: <p¡.nks~ßM@BP.com>, "Winslo~~:iJack L." <LYbnsw.·· ..~bm>· ... '}.~ Hello all. The waiver for well 12-29 has been canceled and the well reclassified as a Normal well. Review of the TIO plot indicates no recent history of IAxOA communication. Wellhead MAASP's are revised to IAlOA::: 2000/1000 psi. Lead Operator: Would you please ensure any waiver related signage is removed from the wellhouse. Please call if you have any questions. Joe 659-5102 From: NSU, ADW WI Tech Sent: Sunday, January 15, 2006 2:56 PM To: NSU, ADW Well Integrity Engineer Subject: 12-29 Recommend Cancel Waiver Hello, I have reviewed the TIO and events history of well 12-29. The IAxOA communication appears to have been mitigated, and has subsequently passed TIFL and MIT-OA. I recommend that we cancel the waiver and return to normal. lof2 1/18/2006 4:34 PM FW: 12-29 Cancel Waiver Please contact me with any c~rns. e Thanks, Cody McCollum Well Integrity Tech Office: 659-5524 Pager: 659-4326 # 786 20f2 1/18/20064:34 PM Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Z-15 l'3ð'- V!,? L5-17A 1 r>,í -)...l3 DS 04-26 I \Y S-- J/'" S-14A ').. -.j t.; - 0"1 t G-27 I g{¡¡-/riD DS 05-20B ~ t....¡ .. 1...3 ~ E-37A Á (¡ ç - út 7--... D-29 I :f .>-- 1. Y.3 L2-28 Ii: j- - C 3 ~.- C-13A ì q 7 - I L; J OWDW-SW/\J C·-.J. 3Y 06-08A ¡9r-1 q J 12-29 /3'1 - t3 CL C-19BÀ(¡ !,:- \ìt r' G-27 j XI \s ~ I ç<.z¡ F-02A ~ Ù ~;; .. (: 'vi <.f 03-33B )O:)--61~ MPK-22 ¡~A (,.j- - ü.:l ~ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 11084273 11075898 11072873 10893047 10942221 10942220 10928640 11084274 11076453 11075900 10893096 11062628 11072867 10928632 10942221 10928630 10913011 10893106 JI SC/~NNEC\ SEP 0 t"/2005 Log Description PPROF W/DEFT/GHOST/CALlPER MEM PPROF W/DEFT/GHOST PRODUCTION PROFILE LEAK DETECTION LOG MEM PPROF & IPROF MEM INJECTION LOG MEM PPROF, IPROF & WARMBACK RST RST MCNL RST -BORAX CHANNEL DETECTION LOG RST RST MCNL MCNL MCNL US IT PDC-GR USIT ~ .t~\- Date 07/08/05 07/03/05 07/30/05 10/17/04 06/29/05 06/26/05 06/14/05 07/09/05 07/27/05 07/05/05 03/24/05 05/17/05 07/07/05 05/12/05 06/29/05 05/08/05 03/19/05 04/20/05 08/30/05 NO. 3460 t ø' tf~·· O·~ d-c Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD ~ i 31 J. ) íJ~.2ï{ i 3).) r í 31). (¡; j 31;1 7 J:?2,J...8 j.5 ). 2Ji j ~ À 3t 131.3; l"v). J 'J- '_7 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 995"g3-~JÓ8 r1 .~." ., ATTN: Beth .,/ ì¡~/ d/ I~) . / . Ifè ,"" J r/ Received by: ~ ~,>"LA. / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _X Alter casing _ Repair well _X Other_X(RWO) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~ie, AK 99519-6612 4. Location of well at surface 3951' FNL, 5175' FEL, Sec. 17, T10N, R15E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service__ (asp's 697689, 5931662) 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 12-29 At top of productive interval 273' FNL, 2954' FWL, Sec. 17, T10N, R15E, UM At effective depth At total depth 89' FNL, 2801' FEL, Sec. 17, T10N, R15E, UM (asp's 699800, 5935397.5) (asp's 699947, 5935586) 9. Permit number / approval number 184-32 10. APl number 50-029-21087 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 110' 20" Surface 2489' 13-3/8" Production 10138' 9-5/8" Liner 926' 7" Scab Liner 528' 3-1/2" 10778 feet Plugs (measured) 9222 feet 10498 feet Junk (measured) 8980 feet Cemented 1850# Poleset 1700 Sx PFE & 400 Sx PFC 500 Sx Class G & 300 Sx PFC 320 Sx Class G 13.5 bbls LARC Tagged PBTD @ 10498' SLM on 8/10/2001. Measured Depth True Ve~icalDepth 111' 110' 2517' 2517' 10162' 8680' 9852'-10778' 8398'-9221' 9910'-10438' 8450'-8928' Perforation depth: measured 10458' - 10472'; 10474' - 10490'; 10492' - 10500'. true vertical 8945' - 8957'; 8959' - 8973'; 8974' - 8983'. tubing (size, grade, and measured depth) 5-1/2", 17#, Chrome NVAM Tubing @ 9763' MD, Packers & SSSV (type & measured depth) 9-5/8" Baker SB-3A PACKER @ 9797' MD. 5-1/2" HES X Nipple @ 2011' MD. Anch- uns. urage C°~i$$ion 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation (7/06/2000) Subsequent to operation (8/16/2001) OiI-Bbl 1464 Representative Daily Average Production or Iniection Data Gas-Mcr Water-Bbl 27282 1619 337 694 1808 Casing Pressure Tubing Pressure 1234 378 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 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. Signedvern Coyner ~ ~ Title: AD&W Drilling Engineer Date Auqust 16, 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 12-29 DESCRIPTION OF WORK COMPLETED RIG WORKOVER Date Event Summary 1/03/2001: 1/12/2001: 1/14/2001: 1/17/2001' 1/23/2001- 1/30/2001 - 2/01/2001- 5/31/2001- 6/23/2001: 7/08/2001 - 7/21/2001: 7/25/2001 - 7/26/2001' 7/31/2001' 8/01/2001- 8/03/2001' 8/10/2001' 8/14/2001: RIH & pulled 3-3/8" IBP @ 9776' SLM. Tagged PBTD @ 10504' MD. RIH & set IBP in 3-1/2" Scab Liner. Center @ 10138'. Top @ 10131'. RIH & dumped sand ontop of the IBP. Made final tag on TOS @ 10076'. PT'd tubing. RIH & tagged TOS @ 10077'. RIH & cut the 5-1/2" tubing w/chem cutter @ 9762'. Circulated out tubing x IA w/1326 bbls of Seawater. FP'd w/Diesel. PPPOT-IC passed. Performed MITOA to 2000 psi - passed. Performed Rig Workover w/ Doyon 16. See Rig Summary attachments. RIH & tagged fill on IBP @ 10074'. Pulled dummied GLV's & installed new GLV design. MIRU CTU. PT'd equip. RIH w/CT Stinger. Tagged Fill @ 10097'. Performed FCO to IBP located @ 10131'. RIH & latched IBP. POOH w/IBP - rubber elements left in hole as fish. RD CTU. Made several attempts to fish IBP rubber elements - no recovery. Tagged PBTD @ 10511'. RIH & tagged PBTD @ 10498'. Placed well BOL @ 2119 hrs. Page I 12 29 ACTUATOR = AXELSON; KB F_LEV = 71'~ I KOP = 2950' Max Angle = 45 @ 6200' · 'b~'m"~"'= ~"o'~'z, , , I 2o~. I--I~-~,~"H~X,.~,o=,.~,~"I '~m'~'b' ~- 8~Ob'"SS I 13-3/8" CSG, 72#, L-80, ID = 12.347" I-~E~~ k GAS LIFT MANDRELS ~ ~ ~ ~ ~ v.v .A~C. ~,~ ~A~ 5 2982 2908 11 OTIS-LB DV T-2 0 07/26/01 b 4 3778 3662 27 OTIS-LB DOME T-2 16/64 07/26/01 Minimum ID 2.871" 10438' ~--~ 3 6837 5931 44 OTIS-LB SO T-2 20/64 07/26/01 3-1/2" DUAL CHECK FLOAT SHOE 2 8462 7151 38 OTIS-LB DV T-2 0 07/26/01 I 9614 8113 27 OTIS-LB DV T-2 0 07/26/01 I I I9753. I---} 5-1/2"HESXNNIPPLF~ID:4'455" I 5-112"TBG'17#'13CR'NVAM"O232bp['ID=4'892" I~ ~ ~ [ 9763' I'~TOPOFSEALASSY'ID=4'892" I I 7"BOTLNRHGRW/TI~ACKI--~ 98§2'I ~ ~'-"~ .0~S' I-I 7-5/8"X4-1/2"XO'ID=3'950"I ~-~/4" ~K~ ~_oY s,v w/~s, C~M, ,~ = ~.00" I--I 99~0' t- I T°P°F3-1'2" LNR'CTM"D=2'992" I---I 9913' I' I--" '~ I' 9908' I'~ 4-1/2" OTIS XN NIPPLE' ID = 3'725" I 9-5/8" CSG, 47#, L-80, ID = 8.681" I--~ 10162' J F~RFORATION SUMMARY I RF_F lOG: BHCS ON 04/13/84 Note: Refer to ~oduction DB for histodcal perf data SIZE SPF INTERVAL Opn/Sqz DATE · 3-3/8" 4 10370-10426 S 11/30/84 I I 3-3/8" 4 10440-10450 S 01/08/90 3-3/8" 4 10458-10478 S 11/30/84 ri 3-3/8,, 4 10458-10478 i s 01/08/90 3-3/8. 4 10458-10472 0 12/22/92 3-3/8,, 4 10474-10482 s 06/12/92 , I 3-3/8" 4 10474-10490 O 10/04/92 i 3-3/8" 4 10478-10482 S 01/07/90 : 3-3/8" 4 10482-10490 S 06/12/92 3-3/8" 4 10492-10502 S 01/08/90 3-3/8" 4 10492-10500 S 06/12/92 3-3/8" 4 10492-10500 O 10/04/92 ~,,~,29#,t.-80,0.0371b¢,lD=6.184" -~ 1077'8' I DATE REV BY COMM~ITS DATE ~ BY COMMBq'DS i F~UDHOE BAY UNrl' 04/17/84 ORIGINAL COMPLE-FION 07/21/01 CH/K~K RWO WELL: 12-29 09/16/93 CID SET 3-1/2" SCAB LNR 08/02/01 AD/-I'~ ~VE IBP/SAND TOP F~d~IT No: 184-032 ,, 12101100 SIS-MWH CONVfiR'rEDTO CANVAS AH No: 50-029-21087-00 01/03/01 SIS-I_G REVISION 1328' FSL & 104' ~NL, SEG. 17,'rlON,R15EUM 03127/01 [~qlTP CORR~TIONS I SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10370-10426 S 11/30/84 3-3/8" 4 10440-10450 S 01/08/90 3-3/8" 4 10458-10478 S 11/30/84 3-3/8" 4 10458-10478 S 01/08/90 3-3/8" 4 10458-10472 O 12/22/92 3-3~8" 4 10474-10482 S 06/12/92 3-3/8" 4 10474-10490 O 10/04/92 3-3/8" 4 10478-10482 S 01107/90 3-3~8" 4 10482-10490 S 06/12/92 3-3/8" 4 10492-10502 S 01/08/90 3-3~8" 4 10492-10500 S 06/12/92 3-3/8" 4 10492-10500 O 10/04/92 DATE REV BY COMMENTS DATE REV BY COMMENTS 04/17/841 ORIGINAL COMPLETION 07/21/01 CH/KAK RWO , 09/16/93 CTD SET 3-1/2" SCAB LNR 08/02/01 AD/-rP REMOVE IBP/SAND TOP ,, 12/01/00 SlS-MWH CONVERTEDTO CANVAS 01/03/01 SlS-LG REVISION 03/27/01 RN/TP CORRECTIONS Legal Well Name: 12-29 Common Well Name: 12-29 Event Name: WORKOVER Start Date: 7/5/2001 End Date: 7/21/2001 DATE TMD: :~ ~: :~ 7/8/2001 (fi:) FINISH R/U. ACCEPTED RIG @ 1800 HRS. PREP TO ClRC OUT DIESEL. 7/9/2001 (ft) CIRC OUT DIESEL, N/D TREE & N/U BOPE. 7/10/2001 (ft) TST BOPE, RPR VALVES, ATTMPT TEST BOPE 7/11/2001 (ft) ATTMPT'D TO TST CHK MAN, CHG'D OUT & RPR MANIFOLD VALVES 7/12/2001 (ft) RPR CHK MAN, PRSS TST CHK MAN, PULL 5-1/2" TBG 7/13/2001 (ft) POOH & L / D 5-1/2" TBG 7/14/2001 (ft) FINSH LID TBG, M/U & RIH w/FISH BHA, PULL FISH, CIRC 7/15/2001 (ft) POOH, L / D FISH, TST' WH & RAM, RIH w/RBP & PKR, PRSS TST'D CSG 7/16/2001 (ft) TST'D CSG, OK. RIH, ClRC TO CLN OUT PKR AND 9-5~8" CSG 7/17/2001 (fi:) CIRC HOLE. POOH & LDDP. LOAD & TALLY COMPLETION. R/U & RUN 5 1/2" T 7/18/2001 (ft) RIH & SPACE OUT COMPLETION. HEAT PKR FLUID 7/19/2001 (ft) LAND TBG. CLEAN UP SPILL. FREEZE PROTECT ATTEMPT TO TEST COMPLE 7/20/2001 (ft) TEST COMPLETION 7/21/2001 (ft) PJD EQUIP, SET TWC N/U & TEST TREE. SET BPV. RELEASE RIG Printed: 8/16/2001 10:40:37 AM Legal Well Name: 12-29 Common Well Name: 12-29 Spud Date: 7/7/2001 Event Name: WORKOVER Start: 7/5/2001 End: 7/21/2001 Contractor Name: DOYON Rig Release: 7/21/2001 Rig Name: Doyon 16 Rig Number: Date From- To Hours ActivitY Cod~P~ ~l~as-e-~ ~ ~ i ---- ~ ~ . .... ~ .... 7/8/2001 18:00 - 19:00 1.00 KILL P DECOMP HELD PJSM. TOOK ON SEAWATER TO RIG PITS. ACCEPTED RIG @ 1800 HRS, 7-8-01. 19:00 - 20:00 1.00 WHSUR P DECOMP HELD PJSM. P/U LUBRICATOR & PULL BPV. L/D LUBRICATOR. 20:00 - 21:00 1.00 WHSUR P DECOMP HELD PJSM. R/U TO CIRCULATE FREEZE PROTECTION OUT OF WELL. 21:00 - 23:30 2.50 WHSUB P DECOMP TESTED SURFACE EQUIP & LINES. HAD LEAK IN 4" DEMCO VALVE. REPAIRED SAME. 23:30 - 00:00 0.50 WHSUB P DECOMP OPENED WELL, WELL ON VACUUM. OUTER ANNULUS HAD 300 PSI. BLED OFF. STARTED CIRCULATING, BLANK OFF FLANGE LEAKING ON TREE. TIGHTENED SAME. 7/9/2001 00:00 - 01:00 1.00 WHSUR P DECOMP CIRCULATED DOWN TUBING TO DISPLACE DIESEL OUT :OF INNER ANNULUS. TOTAL SEAWATER PUMPED 124 BBLS, RATE 6 BPM @ 1,100 PSI. 01:00 - 02:30 1.50~ WHSUR P DECOMP CIRCULATED DOWN INNER ANNULUS TO DISPLACE DIESEL OUT OF TBG. TOTAL SEAWATER PUMPED 190 BBLS, RATE 6 BPM @ 1,100 PSI. (NOTE: TOOK ALL RETURNS DOWN FLOW LINE.) 02:30 - 03:00 0.50 WHSUR P DECOMP BLEW DOWN ALL LINES, R / D LINES FROM TREE. 03:00 - 04:30 1.50 WHSUR 3 DECOMP SET BPV & TESTED TO 500 PSI FROM BOTTOM SIDE. 04:30 - 05:30 1.00 WHSUR 3 DECOMP HELD PJSM. N ! D PRODUCTION TREE & INSTALLED BLANKING PLUG. 05:30 - 12:00 6.50 BOPSUF P DECOMP HELD PJSM. N / U BOPE. TURNED ANNULAR & ORIENTED HYDRAULIC OUTLETS. INSTALLED 3 1/2" X 6" VARIABLE RAMS IN TOP AND 3-1/2" SOLID RAMS IN THE BOTTOM. 12:00 - 00:00 12.00 BOPSUI; 3 DECOMP HELD PJSM. N / U BOPE & LOADED PIPE SHED w/3 1/2" DP. 711012001 00:00 - 05:00 5.00 BOPSUR ~ DECOMP HELD PJSM. A'I-rEMPTED TO TEST BOPE. BOPE NOT HOLDING PRESSURE. FLANGE LEAKING ON FLOW CROSS ON KILL SIDE, UNIBOLT CONNECTION LEAKING UPSTREAM FROM KILL VALVE, CHOKE MANIFOLD VALVE LEAK, CHART RECORDER MALFUNCTION. HUNTED DOWN LEAKS, TIGHTENED FLANGES, AND CLAMP SEALS, GREASED CHOKE MANIFOLD VALVES. REPLACED CHART RECORDER. 05:00 - 12:00 7.00 BOPSUF P DECOMP TESTED BOP STACK, ANNULAR PREVENTER, UPPER PIPE RAMS, CHOKE LINE & VALVES, HCR VALVE, KILL LINE AND VALVES. DART VALVE AND TIW VALVES. TESTED 250 PSI LOW, 3,500 PSI HIGH, HELD LOW TEST 5 MIN, HIGH TEST 10 MIN. ALL TESTS HELD w/NO LEAKS OR PRESSURE LOSS. TESTED PVT HIGH & LOW ALARMS, OK. PERFORMED ACCUMULATOR TEST, OK. TESTED H2S AND LEL GAS ALARMS, OK. 12:00 - 14:00 2.00 BOPSUF.P DECOMP REPAIRED VALVE #11 ON CHOKE MANIFOLD AND ATTEMPTED TO TEST. CHOKE MANIFOLD NOT HOLDING PRESSURE. HUNTED DOWN LEAK ON MANIFOLD. 14:00 - 17:00 3.00 BOPSUF N SFAL DECOMP HELD PJSM. REPLACED SUPER CHOKE ON MANIFOLD. 17:00 - 21:00 4.00 BOPSUF P DECOMP ATTEMPTED TO TEST CHOKE MANIFOLD, MANIFOLD NOT HOLDING PRESSURE. 21:00- 00:00 3.00 BOPSUIq ~ DECOMP TOOK VALVE #13 APART, REPAIRED AND REPACKED. GREASED ALL VALVES. Printed: 7/23/2001 11:09:26 AM Legal Well Name: 12-29 Common Well Name: 12-29 Spud Date: 7/7/2001 Event Name: WORKOVER Start: 7/5/2001 End: 7/21/2001 Contractor Name: DOYON Rig Release: 7/21/2001 Rig Name: Doyon 16 Rig Number: Date From - To Hours ActiVin: Code~/~tPT~ P~as~ -- - _' - ,,, 7/11/2001 00:00 - 02:00 2.00 BOPSUIq N SFAL DECOMP HELD PJSM. ATTEMPTED TO TEST CHOKE MANIFOLD. TEST PUMP LEAKING. 02:00 - 05:00 3.00 BOPSUI; N SFAL DECOMP REPAIRED MANIFOLD ON TEST PUMP. 05:00 - 07:00 2.00 BOPSUR N SFAL DECOMP ATTEMPTED TO TEST CHOKE MANIFOLD. MANIFOLD NOT HOLDING PRESSURE. 07:00 - 08:30 1.50 BOPSUR N SFAL DECOMP CIRCULATED SEAWATER THROUGH CHOKE MANIFOLD TO FLUSH AND CLEAN. 08:30 - 12:00 3.50 BOPSUR N SFAL DECOMP HELD PJSM. REMOVED VALVE BONNETS TO VISUALLY INSPECT LEAKS. ATTEMPTED TO TEST CHOKE MANIFOLD. MANIFOLD NOT HOLDING PRESSURE. IDENTIFIED LEAKING VALVES TO BE CHANGED OUT. 12:00 - 15:00 3.00 BOPSUF N SFAL DECOMP HELD PJSM. CHANGED OUT TWO VALVES ON CHOKE MANIFOLD. 15:00 - 17:00 2.00 BOPSUF N SFAL DECOMP ATTEMPTED TO PRESSURE TEST MANIFOLD, TEST FAILED. 17:00 - 00:00 7.00 BOPSUF;N SFAL DECOMP CHANGED OUT THREE MANIFOLD VALVES, REBUILT ~ VALVE. 711212001 00:00- 12:00 12.00 BOPSUF!N SFAL DECOMP HELD PJSM. FLANGED UP CHOKE MANIFOLD VALVES. FILLED AND FLUSHED MANIFOLD AND LINES w/WATER. ATTEMPTED TO PRESSURE TEST CHOKE MANIFOLD. PRESSURE TEST FAILED. 12:00 - 19:00 7.00 BOPSUF.N SFAL DECOMP HELD PJSM. WORKED ON CHOKE MANIFOLD VALVES. REPACKED VALVES AND TIGHTENED VALVE FLANGES. 19:00 - 21:30 2.50 BOPSUF.P DECOMP PRESSURE TESTED CHOKE MANIFOLD AND VALVES. 250 PSI LOW f/5 MIN, 3,500 PSI HIGH f/10 MIN, ALL TESTS HELD w/NO LEAKS OR PRESSURE LOSS. 21:30 - 22:00 0.50 WHSUR 3 DECOMP HELD PJSM. FMC PULLED BLANKING PLUG 22:00 - 23:00 1.00 WHSUR 3 DECOMP RIGGED UP DRILL SITE MAINTENANCE AND PULLED BPV. RIGGED DOWN DSM. 23:00 - 00:00 1.00 PULL 3 DECOMP HELD PJSM. M / U BAKER DOUBLE SPEAR w/PACK OFF TO ONE JT OF 3-112" DP. ENGAGED SPEAR THROUGH TUBING HANGER. BACKED OUT LDS. PULLED ON SPEAR TO 150,000~, NO MOVEMENT. WORKED SPEAR FROM 0~ TO 175,000~ TUBING MOVEMENT BEGAN AT 180,000~. SLOWLY PULLED TUBING HANGER TO FLOOR. WEIGHT UP 165,000~. NOTE: MEASUREMENT FROM RIG FLOOR TO BOTTOM OF TGB HGR - 21.00' 7/1312001 00:00 o 01:00 1.00 PULL P DECOMP HELD PJSM. R / D AND L / D BAKER SPEAR ASSEMBLY 01:00 - 02:30 1.50 PULL P DECOMP R / U TUBING TONGS AND 5-1/2" TUBING HANDLING EQUIPMENT, BROKE OUT AND L / D TBG HANGER 02:30 - 04:30 2.00 PULL P DECOMP CIRCULATED BOTTOMS UP. PUMP RATE 6 BPM, SPP 1,000 PSI. NO GAS TO SURFACE 04:30 - 05:00 0.50 PULL P DECOMP FLOW CHECK WELL, WELL STATIC 05:00-00:00 19.00 PULL P DECOMP POOHAND LID 5-1/2" 17# L-80TUBING. SPOOLED UP SSSV CONTROL LINE TO 2,210' AND CHEMICAL INJECTION LINE TO 9,690'. 7/14/2001 00:00 - 01:00 1.00 PULL P DECOMP HELD PJSM. FINISHED L / D TUBING FROM ClM TO CHEMICALLY CUT JT. CHEM CUT JT. = 13.53' 01:00 - 01:30 0.50 PULL 3 DECOMP R / D TUBING HANDLING EQUIPMENT, CAMCO LINE SPOOL AND CLEARED FLOOR. Pdnted: 7/23/2001 11:09:26 AM Legal Well Name: 12-29 Common Well Name: 12-29 Spud Date: 7/7/2001 Event Name: WORKOVER Start: 7/5/2001 End: 7/21/2001 Contractor Name: DOYON Rig Release: 7/21/2001 Rig Name: Doyon 16 Rig Number: Date From - To HOurs Acti~i~ COde~iPT ~haS~- ~ ..... _ ._ 7/14/2001 01:30 - 03:00 1.50 PULL P DECOMP HELD PJSM. M / U KELLY, UPPER & LOWER KELLY COCK & SAVER SUB 03:00 - 04:30 1.50 PULL P DECOMP PRESSURE TESTED KELLY, UPPER & LOWER KELLY COCK AND STAND PIPE, 250 PSI LOW - 5 MINUTES, 3,500 PSI HIGH - 10 MINUTES. ALL TESTS HELD w/NO LEAKS OR PRESSURE LOSS. 04:30 - 05:00 0.50 PULL P DECOMP RUN & SET WEAR BUSHING 05:00 - 06:00 1.00 PULL P DECOMP HELD PJSM. TIGHTENED KELLY HOSE AND CONNECTIONS AND PRESSURE TESTED, OK. 06:00 - 08:00 2.00 PULL P DECOMP HELD PJSM. MADE UP FISHING BHA-8-3/8" CUT LIP GUIDE, OVERSHOT w/5-1/2" BASKET GRAPPLE - OVERSHOT EXTENSION - TOP SUB - BUMPER SUB - 6-1/4" OIL JARS - 12-4-3/4" D.C. -ACCELERATOR JARS -XO. BHA LENGTH 414.89'. 08:00- 08:30 0.50 PULL P DECOMP SERVICED RIG. 08:30 - 20:00 11.50 PULL P DECOMP RIH w/BI-IA ON 3-1/2" DP. P / U AND DRIFTED 282 JTS FROM PIPE SHED - RIH to 9,365' 20:00 - 21:00 1.00 PULL P DECOMP INSTALLED MOUSE HOLE. DUG 5' OF RATHOLE IN CELLAR. 21:00 - 22:00 1.00 PULL P DECOMP P / U AND RIH w/LAST 12 JTS OF 3-1/2" DRIFTED DP FROM PIPE SHED. RIH to 9,747'. 22:00 - 22:30 0.50 PULL P DECOMP P / U AND M / U KELLY. TESTED MUD LINE TO 2,500 PSI. OK. ESTABLISHED PARAMETERS - SLACK OFF WEIGHT 125,000#, PICK UP WEIGHT 165,000~. 22:30 - 23:00 0.50 PULL 3 DECOMP ESTABLISHED PUMP PARAMETERS - 27 SPM, SPP 200 PSI. WASHED DOWN TO TOP OF FISH AT 9,762'. SWALLOWED TUBING STUMP, PRESSURE INCREASED TO 500 PSI, SHUT DOWN PUMP, HELD 500 PSI ON STRING. ENGAGED FISH w/15,000# SET DOWN WEIGHT. SLOWLY PULLED UP TO 195,000~, (30,000~ OVERPULL), SET OFF JARS. SLOWLY PULLED UP TO 235,000~, (70,000~ OVERPULL), SEAL ASSEMBLY CAME FREE, PRESSURE DROPPED TO 0 PSI. PULLED UP TO 9,742'. 23:00 - 00:00 1.00 PULL 3 DECOMP CIRCULATED BOTTOMS UP. PUMP RATE 6 BPM, SPP 1,200 PSI. 7/15/2001 00:00 - 01:00 1.00 PULL P DECOMP CIRCULATED BOTTOMS UP. HAD A SLIGHT SHOW OF GAS AT BOTTOMS UP. 01:00 - 01:30 0.50 PULL P DECOMP HELD PJSM. FLOW CHECKED WELL, WELL STATIC. 01:30 - 08:30 7.00 PULL P DECOMP POOH w/FISH. RECOVERED 25.5' OF CHEM CUT JT, 1 FULL JT OF TBG, 1 PUP JT, 1 XO, 1 BAKER LOCATOR, 1 SEAL ASSEMBLY. 100% RECOVERY. 08:30 - 10:00 1.50 PULL P DECOMP BROKE OUT AND L / D FISH. L / D BAKER FISHING TOOLS AND CLEARED FLOOR. 10:00-12:00 2.00 PULL P DECOMP HELDPJSM. P/UANDRIHw/12-4-3/4"DC, HALLIBURTON RTTS PACKERAND 1 STAND OF 3-1/2" DP. SET RTTS PACKER AT 94' 12:00 - 15:00 3.00 PULL iP DECOMP HOOKED UP BLEEDER TANK TO OAAND BLED OF PRESSURE FROM 400 PSI TO 0 PSI. 15:00 - 16:00 1.00 PULL P DECOMP CLOSED UPPER PIPE RAMS AND TESTED WELL HEAD TO 3,000 PSI. OK. OBSERVED OA, NO PRESSURE INCREASE. Printed: 7/23/2001 11:09:26 AM Legal Well Name: 12-29 Common Well Name: 12-29 Spud Date: 7/7/2001 Event Name: WORKOVER Start: 7/5/2001 End: 7/21/2001 Contractor Name: DOYON Rig Release: 7/21/2001 Rig Name: Doyon 16 Rig Number: Date From - To HourS: Activi~ Cod~P~ --Phase~.~ 7/15/2001 16:00 - 17:00 1.00 PULL P DECOMP REL~SED R~S PACKER AND POOH, M / U STORM VALVE. 17:00-18:00 1.00 PULL P DECOMP HELDPJSM. RIH w/ STORM PACKER AND SET AT 50'. BACKED OUT OF PACKER AND SET BACK DP. P / U TEST JT AND CLOSED LOWER PIPE ~MS. TESTED LOWER PIPE ~MS TO 250 LOW - 5 MINUTES, 3,000 PSI HIGH - 10 MINUTES, NO L~KS OR PRESSURE LOSS. 18:00 - 20:00 2.00 PULL P DECOMP L / D TEST JT, RIH w/DP AND REL~SE PACKER. POOH w/ PACKER AND UD SAME. 20:00 - 23:00 3.00 PULL P DECOMP HELD PJSM. M / U 9-5~8" RETRIEVABLE BRIDGE PLUG, XO, 10' 3-1/2 DP PUP JT, XO, R~S PACKER, R~S CIRCUITING VALVE, XO. RIH ON 12 - 4-3/4" DC AND 3-112" DP. SET RBP AT 2,805'. POOH TO 1,898' AND SET R~S PACKER. 23:00 - 23:30 0.50 PULL P DECOMP M / U TIW AND PUMP IN SUB. TESTED LINES TO 3,000 PSI, OK. 23:30 - 00:00 0.50 PULL P DECOMP PRESSURED UP TO 3,000 PSI AND TESTED INTERVAL FROM 1,898' TO 2,995'. OK. 711612001 00:00 - 00:30 0.50 P COMP HELD PJSM. PRESSURE TESTED INTERVAL FROM RBP AT 2,805' TO R~S PACKER AT 1,898'. TEST PRESSURE 3,000 PSI. HELD FOR 30 MINUTES, OK. 00:30 - 01:00 0.50 PULL P COMP POOH TO 1,612' AND SET R~S PACKER AT 1,610' 01:00 - 01:30 0.50 PULL P COMP PRESSURE TESTED INTERVAL FROM RBP AT 2,805' TO R~S PKR AT 1,610'. TEST PRESSURE 3,000 PSI. HELD FOR 30 MINUTES, OK. 01:30 - 02:00 0.50 PULL P COMP CLOSED UPPER PIPE ~MS AND PRESSURE TESTED THE BACK SIDE FROM SURFACE TO THE TOP OF THE R~S PACKER AT 1,610'. TEST PRESSURE 3,000 PSI, HELD FOR 30 MINUTES, OK. 02:00 - 02:30 0.50 PULL P COMP POOH TO 1,515' AND SET R~S PACKER AT 1,513'. 02:30 - 05:00 2.50 PULL P COMP PRESSURE TESTED INTERVAL FROM RBP AT 2,805' TO R~S PACKER AT 1,510'. TEST PRESSURE 3,000 PSI, HELD FOR 2-1/2 HRS. TOTAL PRESSURE LOSS 150 PSI. 05:00 - 06:00 1.00 PULL P COMP CLOSED UPPER PIPE ~MS. HELD 3,000 PSI ON DRILL PIPE AND PRESSURED UP TO 3,000 PSI ON BACK SIDE FROM SURFACE TO 1,510'. HELD FOR I HOUR w/200 PSI PRESSURE LOSS. 06:00 - 08:00 2.00 PULL P COMP BLED OFF PRESSURE FROM DRILL PIPE AND ANNULUS. REL~SED R~S PACKER. CLOSED UPPER PIPE ~MS AND PRESSURE TESTED FROM SURFACE TO RBP AT 2,805'. TEST PRESSURE 3,000 PSI. HELD TEST FOR 2 HOURS w/250 PSI PRESSURE LOSS. 08:00 - 10:30 2.50 PULL P COMP POOH w/R~S PACKER. 10:30 - 11:00 0.50 PULL P COMP BROKE OUT, CLONED UP AND L / D R~S PACKER. 11:00 - 13:00 2.00 PULL P COMP HELD PJSM. M / U RBP RETRIEVING TOOL AND RIH ON 3-1/2" DRILL PIPE. 13:00 - 13:30 0.50 PULL P COMP ~TCHED ONTO AND REL~SED RBP AT 2,805'. 13:30 - 15:00 1.50 PULL P COMP POOH w/RBP. BROKE OUT AND L / D RBP. 15:00 - 15:30 0.50 PULL P COMP HELD PJSM. R / U LI~LE RED OIL AND PUMPED DIESEL DOWN 13-318" x 9-5~8" OA. INITIAL PUMP ~TE 2 BPM AT 200 PSI. WITH 11 BBLS PUMPED PRESSURE INCR~SED TO 1,000 PSI. SHUT DOWN, PRESSURE HELD AT 1,000 PSI. BLED OFF PRESSURE AND R / D LI~LE RED. TOTAL Printed: 7123/2001 11:09:26 AM Legal Well Name: 12-29 Common Well Name: 12-29 Spud Date: 7/7/2001 Event Name: WORKOVER Start: 7/5/2001 End: 7/21/2001 Contractor Name: DOYON Rig Release: 7/21/2001 Rig Name: Doyon 16 Rig Number: Date From-To HOurs Activity Code Np.~~as~ ~ .... ~ .... ~ ' 7/16/2001 15:00 - 15:30 0.50 PULL P COMP DIESEL PUMPED 11 BBLS. 15:30 - 16:00 0.50 PULL P COMP HELD PJSM. R / U HALLIBURTON PUMP TRUCK TO 9-518" CASING. 16:00 - 17:30 1.50 PULL P COMP PUMPED 3 BBLS OF WATER TO CLEAR LINES OF AIR. SHUT IN VALVE AT WELLHEAD AND TESTED LINES TO 3,000 PSI FOR 5 MINUTES, OK. BLED OFF PRESSURE, OPENED VALVE AND ESTABLISHED CIRCULATION. CLOSED BLIND RAMS AND PRESSURED UP 9-5~8" CASING. PUMPED 4 BBLS AND INCREASED PRESSURE TO 3,000 PSI. SHUT DOWN PUMPS AND HELD 3,000 PSI ON 9-5~8" CASING FOR 30 MINUTES w/NO PRESSURE LOSS. 17:30 - 18:00 0.50 PULL 3 COMP RELEASED PRESSURE AND R 1D HALLIBURTON. 18:00 - 22:30 4.50 PULL ~ COMP HELD PJSM. M / U 3-1/2" MULE SHOE AND RIH ON 3-1/2" DRILL PIPE TO TOP OF 4-1/2" TAIL PIPE AT 9,815'. 22:30 - 00:00 1.50 PULL P COMP CIRCULATED 2 BOTTOMS UP AT 9,815'. PUMP RATE 7 BPM, SPP 1,600 PSI. 7/17/2001 00:00 - 02:00 2.00~ PULL P COMP CIRCULATE BOTTOMS UP 2 TIMES W/SEAWATER. 02:00 - 02:30 0.50 PULL P COMP PJSM MONITOR WELL. R/D CIRCULATING EQUIP. 02:30 - 05:30 3.00 PULL P COMP POOH & L/D 3 1/2" DRILL PIPE. 05:30 - 08:00 2.50 PULL P COMP LOAD & TALLY 5 1/2" COMPLETION STRING. 08:00 - 12:00 4.00 PULL P COMP CON'T POOH & LDDP. 12:00 - 15:00 3.00 PULL P COMP PJSM. RIH W/4 3~4" DC. POOH & L/D DC. 15:00 - 16:00 1.00 PULL P COMP P/U TEST JT & PULL WEAR RING. 16:00 - 18:00 2.00 PULL P COMP . PJSM. R/U CASING EQUIP TO RUN 5 1/2" COMPLETION. 18:00 - 20:00 2.00 PULL P COMP CLEAN RIG FLOOR. LOAD GLMS & PUPS. PREP TO RUN COMPLETION. 20:00 - 00:00 4.00 RUNCOI~ COMP PJSM. P/U SEAL ASSY& RUN 5 1/2" CR-13 AS PER PROGRAM. 711812001 00:00 - 19:30 19.50 RUNCOI~ COMP RIH W/5 1/2" COMPLETION STRING. DRIFT TBG EVERY 1500' W/4.56" DRIFT. RAN 9797' TBG. 19:30 -21:30 2.00 RUNCOI~ ~COMP R/U CIRCULATING HEAD. CIRCULATE DOWN & INTO ' RECEPTICLE.TAGGED TOP @ 9801' & PRESSURED UP. ;S/D PUMP & TAG LOCATOR @ 9813'. PULL OUT & L/D 2 JTS TBG. 21:30 - 22:00 0.50 RUNCOIt~ COMP M/U TBG PUPS & SPACE OUT STRING. RUN 4.56"DRIFT THRU TBG & PUPS. 22:00 - 00:00 2.00 RUNCOI~I~ COMP R/D DRIFT EQUIP. R/U HOTOILERS TO TIGER TANK & HEAT PKR FLUID. 7/19/2001 00:00 - 03:00 3.001 RUNCOr P COMP PJSM. M/U LANDING JT & HGR. DRAIN STACK. RIH & LAND HANGER. M/U ClRC EQUIP TO LANDING JT. P/U HANGER TO FLOOR. PREPARE TO CIRC. CLOSE HYDRIL. QUIK CONNECT ON CLOSING LINE S[LIT & SPRAYED HYDRAULIC FLUID AROUND CELLAR & SMALL AMT ON GROUND. 03:00 - 05:00 2.00 RUNCOr I~1 SFAL COMP REPAIR CLOSING LINE. REPORT & CLEAN UP SPILL. FUNCTION TEST DOPE. CHECK ALL LINES TO STACK. 05:00 - 07:00 2.00 RUNCOI~P COMP PJSM. REVERSE CIRC 429 BBLS 100 DEGREE INHIBITED PKR FLUID @ 5 BPM. 07:00 - 08:00 1.00 RUNCOI~ COMP R.U HOT OILER & PUMP 110 BBLS DIESEL FOR FREEZE PROTECTION. 08:00 - 10:00 2.00 RUNCOI~ COMP HOOK UP TO TBG & ALLOW DIESEL TO U-TUBE & EQUALIZE. Printed: 7/23/2001 11:09:26 AM Legal Well Name: 12-29 Common Well Name: 12-29 Spud Date: 7/7/2001 Event Name: WORKOVER Start: 7/5/2001 End: 7/21/2001 Contractor Name: DOYON Rig Release: 7/21/2001 Rig Name: Doyon 16 Rig Number: Date From - To Hours ACtivi~-COde-NP'F~ha~e~ 7/19/2001 10:00 - 11:30 1.50 RUNCOI~ COMP OPEN ANNULAR. DRAIN STACK & LAND TBG HANGER. RILDS. 11:30 - 12:00 0.50 RUNCOI~ COMP PRESSURE UP ANN TO 300 PSI & TEST W/TBG OPEN. 12:00 - 13:00 1.00 RUNCOI~ COMP PJSM CHECK VALVES & LINES, CON'T TEST IA. SLOW BLEED OFF. 13:00 - 16:30 3.50 RUNCOr~' COMP PRESS. TEST TBG TO 3000 PSI, BLED OFF 225 PSI IN 30 MIN. RE-TEST TBG LOST 225 PSI IN 30 MIN. FLUID FLOWING FROM ANN. 16:30 - 17:00 0.50 RUNCOI~ COMP R/U TBG TOOLS. BOLDS. 17:00 - 19:00 2.00 RUNCOI~ COMP PULL HANGER TO FLOOR. INSTALL ADDITIONAL 3.73' PUP IN TBG STRING. RE-LAND TBG HANGER W/25K DOWN VVT. RILDS. 19:00 - 00:00 5.00 RUNCOItl~ COMP BEGIN RE-TEST. PRESS UP TBG TO 3000 PSI, LOST 250 PSI IN 30 MIN. PRESSURE UP IA, LOST 650 PSI IN I HR. CON,T TO TEST IA. CALL FOR SLICK LINE EQUIP TO SET PLUG IN "XN" NIPPLE. / 7/20/2001 00:00 - 01:00 1.00 RUNCOItl~ COMP CON'T PRESSURE TEST. BLED OFF 75 PSI IN 1 HR. BRING IN W/L EQUIP. 01:00 - 03:30 2.50 RUNCO~ P COMP BLEED OFF PRESSURE. ON IA TEST. R/U WlRELINE EQUIP. INSTALL PUMP IN SUB, X/O, & TIW. PRESSURE TEST PACK OFF. & CONNECTIONS. TO 300 PSI. 03:30 - 04:30 1.00 RUNCO~ P COMP RIH & SET 'XN" PLUG IN PROFILE @ 9788'. :04:30 - 11:00 6.50 RUNCO~ I~ COMP PRESSURE TEST TBG TO 3000 PSI, BLED OFF 250 PSI, IN 30 MIN. STEADY STREAM FROM IA. BLEED OFF TBG. PRESSURE UP IA TO 3000 PSI, BLED OFF 200 PSI, IN 1 HR. W/STEADY DRIP OUT OF TBG. RELEASE PRESSURE & PRESSURE UP TBG TO 3500 PSI, BLED OFF 400 PSI IN 2 HRS..2 GPM FLOW FROM IA. RELEASE PRESSURE & PULL 'XN' PLUG. 11:00 - 12:00 1.00 RUNCOI~ COMP RIH & SET PLUG IN 'X' NIPPLE @ 2203'. POOH. 12:00 - 13:30 1.50 RUNCO~P COMP PRESSURE UP TBG TO 3000 PSI, LEAKING OFF. OBSERVED LEAK FROM BELOW HANGER IN X-OVER. (FOUND LEAK BY LOOKING IN ANN VALVE W/LITE) 13:30 - 14:00 0.50 RUNCOI~ COMP RIH & TAG PLUG TO INSURE PROPER SET. 14:00 - 15:00 1.00 RUNCOI~P COMP BOLDS. PULL HANGER TO RIG FLOOR & TEST TBG TO 500 PSI, X-OVER BELOW HANGER LEAKING. 15:00 - 17:00 2.00 RUNCOI~P COMP WAIT ON NEW HANGER. 17:00 - 18:30 1.50 RUNCOI~P COMP CHANGE OUT HANGER & RESPACE SAME. 18:30 - 19:00 0.50 RUNCOI~ COMP PRESSURE UP TBG & CHECK HANGER & X-OVER. TO 300 PSI, NO LEAKS. 19:00 - 19:30 0.50 RUNCOI~ COMP RE-LAND HANGER & RILDS. 19:30 - 22:00 2.50 RUNCOI~ COMP RIH & EQUALIZE PLUG. PULL 'X' PLUG. 22:00 - 23:00 1.00 RUNCOI~ COMP PRESSURE TEST IA TO 3000 PSI, TEST 30 MIN NO LEAK-OFF, TEST GOOD. 23:00 - 00:00 1.00 RUNCOI~ COMP PRESSURE TEST TBG TO 3000 PSI FOR 30 MIN, NO LEAK-OFF, TEST GOOD. 7/21/2001 00:00 - 01:00 1.00 RUNCOI~ COMP R/D WlRELINE EQUIP. 01:00 - 02:00 1.00 RUNCOI~ COMP L/D LANDING JT. 02:00 - 02:30 0.50 RUNCOI~ COMP SET TWC. 02:30- 03:00 0.50 RUNCOI~ COMP CLEAN RIG FLOOR. 03:00 - 09:00 6.00 RUNCOI~ COMP N/D BOPE, FLOW LINE & BELL NIPPLE. 09:00 - 11:30 2.50 RUNCOI~ COMP N/U ADAPTER FLANGE & TREE. WRONG BOLTS IN ADAPTER FLANGE. Printed: 7/23/2001 11:09:26 AM Legal Well Name: 12-29 Common Well Name: 12-29 Spud Date: 7/7/2001 Event Name: WORKOVER Start: 7/5/2001 End: 7/21/2001 Contractor Name: DOYON Rig Release: 7/21/2001 Rig Name: Doyon 16 Rig Number: __ 7/21/2001 11:30 - 16:00 4.50 RUNCOhl:) COMP CHANGE OUT STUDS IN ADAPTEWR SPOOL. N/U X-MAS TREE. TEST SAME TO 5000 PSI. 16:00 - 17:00 1.00 RUNCOI~I~ COMP M/U LUBRICATOR & PULL TWC & INSTALL BPV. 17:00 - 18:00 1.00 RUNCOI~I:' COMP INSATLL BLANK-OFF FLANGES & GAUGES. SECURE WELL. RELEASE RIG @ 1800 HRS, 7-21-01. RDMO. Printed: 7/23/2001 11:09:26 AM 8/24/95 GeoQuest NO. 9660 D.S. 15-33 95250 DUAL BURST TDT-P 950623 1 D.S. 5-36 ~ t 7 L~ PROD PROFILE 950731 1 I ' ' 'D.s. 7-33 DUAL BURST TDT-P 950729 I 1 D.S. 11-27 ' I~r~ cNTG 950730 I 1 D.S. 11-32 ~1~ ',,_'z~'[_. PERFREOORD ' 950730 ...... 1 1 D.S. 12-01~ "~-_~~ PRODLOG 950728 I 1 D.S. 12-12 ~ ~_'~ GAS LIFT SURVEY 950727 I 1 D.S. 12-28 ~ ~ ~ .~ I PRODPROFILE 950725 I 1 D.S. 13-3 _ pROD PROFILE 950731 I 1 D.S. 15-1 (~ O ~/,¢ DUAL BURST TDT-P 950726 1 1 D.S 15-13 ~ ~ ! .~..~tA, DUAL BURSTTDT-P 950727 I 1 D.S. 15-25 ' ~r~i;j~ _C3 ~ DUAL BURSTTDT-P 950725 I 1 D.S. 17-20 ~7-- 11-5'- PERFRECORD 950730 1 1 D.S. 18-02A /;r ¢'~ ¢ PERF RECORD 950726 1 1 D.S. 18-02A -I ~ ~) ~ PROD FLUID SAMPLER 950722 1 I £CEIVED. 4/a~ka 0ii & Gas C°mrrlis$ion S I G N E D Anchorage DATE: '4n'c ~eE;' ,o~/~.o,"wo~. Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 500 W. International Airport Road ~ Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99518-1199 ~ ~ Attn: Larry Grant ATTN: Sherrie r,,~/ \~U \ 3001 Porcupine Drive (~~ ~U ~~, Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk ARCO Alaska, Inc. Date: Feb 11, 1994 P.O. Box 100360,.._~..~tchorage, Transmittal #: 94021 AK Subject: From/Location: BHP Report John Degrey/ATO- 1529 Telephone: (907) 263-4310 To/Location: Distribution 30- 0'5 ~-5~ 5t-~ 80- q~ Sq-3z Well Log Date Tool Type Run, Scale i Contractor Number (M-D-Y) 1-9 12-17-92 BHP - t Camco / 1-14 8-11-92 BHP - I Camco ,, 1-14 8-11-92 BHP ' t Camco 2-2 1-10-93 BHP '1 Camco 2-13 2-12-93 BHP - i Camco 2-35 5-21-92 BHP Camco 3-15A 3-20-93 BHP Camco 3-20 12-18-92 BHP - Camco 4-7ST 5-17-92 BHP - Camco 4-14 1-9-93 BHP - Camco 4-29 12-28-92 BHP - Camco 4-42 4-27-92 BHP - Camco 5-9 2-21-93 BHP - Camco 5-16 2-21-93 BHP - ~ Camco 5-25 2-21-93 BHP - Camco 5-31 2-21-93 BHP - Camco 5-33 1-29-93 BHP Camco 5-35 1-29-93 BHP - Camco 5-36 1-29-93 BHP Camco 9-24 2-15-93 BHP - Camco 9-40 1-25-93 BHP - Carrx:~ 9-51 3-20-93 BHP - Camco 12-7A 12-6-92 BH P - Camco 12-7A 12-10-92 BHP - Camco 12-9 12-10-92 BHP - Camco 12-29 12-14-92 BHP - Camco 13-15 7-3-92 BHP - Camco 13-20 7-4-92 BH P - Camco 13-23A 7-4-92 BHP - Camco 13-32 7-3-92 BHP - I Camco 14-11 11-23-92 BHP -t Camco 16-19 10-19-92 BHP t Camco 16-21 10-19-92 BHPI Camco 16-30 9-28-92 BH P - Camco 17-3 12-12-92 BHP - Camco 17-10 11-8-92 BHP - Camco 17-11 2-8-93 BHP - Camco 17-20 12-21-92 BHP - Camco 17-21 12-21-92 BHP - Camco 18-15 6-14-92 BHP - Camco ARCO ~ Inc. Ii · Sul~l~ly of A~nllcRIcl~l~~ RECEIVED FE~ I ~. t994 Alaska Oi/ & ~as Cons. '~nChorage C°rr~ission STATE OF ALASKA ALASKA. . AND GAS CONSERVATION CC IlSSlON REPORT SUNDRY WELL OP i ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X ~ 6. Datum of elevati~'[~or KB) 71 RKB~.~ 7. Unit or Property ~-~ Prudhoe Bay Unit ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 1328' FSL, 104' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 272' FNL, 2313' FWL, Sec. 17, T10N, R15E, UM At effective depth 105' FNL, 2451' FWL, Sec. 17, T10N, R15E, UM At total depth ~,S~.~ 0[[ & ~'$ O0~lS, 88' FNL, 2465' FWL, Sec. 17, T10N, R15E, UM feet 8. Well number 12-29 9. Permit number/approval number 84-32 10. APl number 50 - 029-21087 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10778' feet 9222' feet Plugs(measured) Fill @ 10580' MD (9/28/93) Effective depth: measured 10580' feet true vertical 9050' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1850# Poleset 110' 110' Sudace 2489' 13-3/8" 1700 sx PF E & 400 sx PFC 2517' 2517' Production 10138' 9-5/8" 500 sx Class G & 300 sx PFC 10162' 8679' Liner 926' 7" 320 sx Class G 9852-10778' 8397-9221' Scab Liner 528' 3-1/2" 13.5 bbls LARC 9910-10438' 8449-8926' Perforation depth: measured 10458-10472'; 10474-10490'; 10492-10500' true vertical 8945-8957'; 8959-8973; 8974-8983' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9818' MD; 4-1/2", 12.6~, L-80, PCT @ 9921' MD Packers and SSSV (type and measured depth) 5-1/2", Otis HRQ @ 2210' MD; Baker SB-3A Pkr @ 9797' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Produ~ionorlniection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 1428 ~ 12991 379 -- 2489~" 2609 1045 -- Tubing Pressure 1627 355 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 t~''''-'''~'-~'~ ~ Title Engineering Supervisor Form 10-404~Rev 06/15/88 SUBMIT IN DUPLICATE ~ n~R/R WHR c.c.: SW. JWP 12-29 DESCRIPTION OF WORK COMPLETED CTU CONVEYED SCAB LINER INSTALLATION 9/14/93: MIRU & PT equipment to 4000 psi. RIH w/CT & fluid packed the wellbore w/Crude. Tagged bottom at 10655' MD, then pumped 29 bbls of Gelled Sand Slurry containing 5200 lbs 20/40 mesh sand, to place a sand plug across the open perforation intervals located at: 10458 - 10472' MD (Z4) 10474 - 10490' MD (Z4) 10492 - 10500' MD (Z4) Ref Log: BHCS 4/13/84. Made a final top of sand plug tag at 10454' MD. POOH w/CT. Rigged down. 9/15/93: RIH & tagged top of sand plug at 10449' MD. 9/16/93: MIRU CTU & PT equipment. Made up & RIH with a CT conveyed Scab Liner assembly, consisting of 17 joints of threaded +/- 30' x 3.5" OD, 9.3#, L-80 Liner, & 9.57' x 3.5" Pup joint w/3.5" Float Shoe w/dual check valves. Hung the liner assembly by a 3.8" OD No-Go Locator set in the XN Nipple at 9910' MD. Disconnected from assembly top & POOH w/CT. Rigged down. 9/18/93: MIRU CTU & PT equipment. RIH w/CT & fluid packed the wellbore w/Hot Seawater, then pumped 13.5 bbls of Latex Acid Resistive cement, down the CT & through the dual check valves, to cement the Scab Liner in position from 9910'- 10438' MD, while simultaneously isolating leaking squeezed perforation intervals located at: 10370 - 10426' MD (Z4: Sqz'd) 10440 - 10450' MD (Z4: Sqz'd) Ref Log: BHCS 4/13/84. Attained 750 psi maximum squeeze pressure, & held I hour. jetted cement from scab liner. POOH w/CT. Rigged down. Contaminated cement w/biozan & 9/21/93: RIH & tagged hard cement in the 3.5" liner at 10190' MD. 9/25/93: MIRU CTU & PT equipment. RIH w/CT mounted milling assembly & milled through hard liner cement down into the sand plug to 10460' MD. POOH w/milling assembly. Rigged down. 9/28/93: RIH w/CT & jetted biozan for a sand plug/fill cleanout to uncover the open perforation intervals (listed above). Jetted down to 10580' MD. POOH w/CT. Rigged down. Placed well on production & obtained a valid welltest. .~Jask~ Oil & Gas GonS, Anchorage ARCO Alaska, Inc. P.O~Box 100360 Anchorage. Alaska 99510 DATE: REFERENCE: ARCO CASED HOLE FINALS -11 1-24-93 -11 2-7-93 1-13 2-7-93 1-24A 2-20-93 ~'L--~~1-30 1-24-93 2-14 7-27-91 3-9 12-19-92 ~._~7J~[1.3-24 1-25-93 '3-32 4-25-92 ~3-32 4-25-92 *~-32 2-10-03 ~3-34A 2-~-~3 10-27-92 8-18-92 2-22-03 ., 3-1-92 %9-27 3-1-92 - 1 2-8-03 ~1-1 4-21-92 1-13A 3-8-93 1-10 4-14-92 1-18 4-14-92 ~12-4A 2-11-93 ~~t2-~ 2-~ ~-~3 12-2~ 12-22-92 ~14-1~ 4-24-92 ~~4-12 4-24-92 4-37 4-13-92 4-37 4-13-92 RECEIVED 6-21 7-23-92 PSGT Computed Results 6-21 7-23-92 PSGT 6-27 8-23-92 Perf Record 16-30 2-12-93 Perf Record ~ l~~17-21 12-20-92 Perf Record Please sign and return t~e att..ached co. py as receipt of data. RECEIVED BY '~__~_'__~__ .ff~ 8onya Wallace ATOo1529 ~a,~ Oil & Gas Cons, Commission Perf Record ~EJ~/)~,, HIS Perf Record Run 1. ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ T~ R~ 1. ~ H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1. ~' H~ PGST Computed Resets R~ 1. ~' H~ PSGT R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~* H~ T~ R~ 1. ~' H~ DSN R~ 1. ~* H~ T~ Boron ~Jection R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ PSGT Computed Resets R~ 1. ~' H~ ~GT 5 ~/~ R~ 1. ~' H~ ~ 10 ~/~ R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~* H~ PSGT Computed Resets R~ 1. ~' H~ PSGT R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ PSGT Com~uted Re~ts H~ 1. ~' HE8 PSGT R~ 1, ~' H~ Pe~ Reco~ R~ 1, ~' H~ Peal Reco~ R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ Peal Record R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ PSGT Computed Resets R~ 1. ~' H~ PSGT R~ 1. ~' H~ PSGT Computed Resets R~ 1, ~' H~ PSGT R~ 1, ~' H~ R~ 1, ~' H~ R~ 1, ~' H~ R~ 1, ~' H~ R~ 1, ~' H~ R~ 1, ~' H~ CENTRAL FILES CHEVRON # LUCILLE JOHNSTON EXXON PHH~.IPS MOBIL BPX STATE OF AIASKA * The correct apl# for 3-32 is 50~02g-21141-00. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HO[~. FINALS ~'q ---- 1-17 12-1-92 Prod Profile R~_m 1, 5" ~q-~z-. 3-9 12-4-92 Prod Profile . Run 1' 2"&5" ~1o~-3o18 12-5-92 InJ Profile Run 1, 5" · c~~ -*--3-34A 11-12-92 Temperature Run 1, 5" 'l I~ ~%--4o5 11-23-92 Jewelry Run 1, 5" ~ ~q. ~4-23 12-7-92 Leak Detect Run 1, 5" ct~~ ~6o12A 12-4-92 'GR/Collar Run 1, 5" ~qo ~9o19 11-21-92 InJ Profile Run 1, 5" 11-27-92 Prod Profile Run 1, 2'&5' '~1 .~9-26 ~Z~ ~9-28 12-7-92 Prod Profile Run 1, 5" ~_~ltl ~9-33 11-29-92 Prod Profile Run 1, 5" ~~12-29 11-20-92 Prod Profile R~m 1, 5" ~.i~13-32 12-11-92 InJ Profile Run 1, 5" ~~%/14-33 12-1-92 Prod Profile Run .1, 5" Please sign and return the attached copy as receipt of data. RECEIVED BY Have A Nice Dayl Sonya Wallace ATO-1529 Trans# 93039 C~Inco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON . MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALAS~ TEXACO * The correct well name for this log is 3-34A. ARCO ~lnqk_~; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-15-93 REFERENCE: ARCO CASED HOI.~ FINALS Please sign and return the attached copy as receipt of data~ RECEIVED BY__~_~~ Have A Nice llay! Sonya Wallace APPROVED__~ ATO-1529 Trans# 93032 Camco Camco Camco Camco Ca__mco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA Alaska 0il & Gas Goas. ~ommission ~ IAII- UP AL/-~I~/~ ALASKA . AND GAS CONSERVATION CC 41SSION REPORT SUNDRY WELL OPE'NATIONS ~ -- Stimul"'~-~'~- ~ Pe~orate~ Pull tubing AItercasing Repairwell O~er X 1. Operations performed: 2. Name of Operator ARCO Alaska~ Inc. Development X 71' RKB feet 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1328' FSL, 104' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 272' FNL, 2313' FWL, Sec. 17, T10N, R15E, UM At effective depth 105' FNL, 2451' FWL, Sec. 17, T10N, R15E, UM At total depth 88' FNL, 2465' FWL, Sec. 17, T10N, R15E, UM Exploratory Stral~graphic Service RE(E]VED APR ! 2 199- Alaska 0il .& Gas Cons. C0mm'tss~o~ ;Anchorage 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-29 9. Permit number/approval number 84-32 10. APl number 50 - 029-21087 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10778' feet 9222' feet Plugs(measured) PBTD @ 10670' MD (12/17/92) Effective depth: measured 10735' feet true vertical 9184' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1850# Poleset 110' 110' Surface 2489' 13-3/8" 1700 sx PF E & 400 sx PFC 2517' 2517' Production 10138' 9-5/8" 500 sx Class G & 300 sx PFC 10162' 8679' Liner 926' 7" 320 sx Class G 9852-10778' 8397-9221' Perforation depth: measured 10458-10472'; 10474-10490'; 10492-10500' true vertical 8945-8957'; 8959-8973'; 8974-8981' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9818' MD; 4-1/2", 12.6~, L-80, PCT Tail @ 9921' MD Packers and SSSV (type and measured depth) 5-1/2" Otis HRQ SSSV @ 2210' MD; Baker SB-3A packer @ 9797' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl · Gas-Md Water-Bbl Casing Pressure Prior to well operation 3597 25804 842 -- Subsequent to operation 532 9135 2416 -- Tubing Pressure 1352 3O7 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas --- Suspended .._. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ 7 :orm 10-404 Rev 06/15/88 .q7zt/1 KRF cc: SW. JWP Title Engineering Supervisor SUBMIT IN DUPLICATE 12-29 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZES & ACID ROPE BREAKDOWN TREATMENT 6/3/92: A CTU Cement Squeeze for Gas Shutoff was performed as follows: MIRU CTU & PT equipment to 4000 psi. RIH w/CT & fluid packed the wellbore w/hot Seawater, then squeezed the perforations at: 10440 - 1 10458 - 1 10478 - 1 10492 - I 0450' MD (Z4) 0478' MD (Z4) 0482' MD (Z4) 0502' MD (Z4) Ref Log: BHCS 4/13/84. Pumped 50 bbls of Latex Acid Resistive cement, squeezing the perforations (listed above). Placed 8 bbls of cement behind pipe at 3500 psi maximum squeeze pressure, & held for one hour. Contaminated cement w/biozan & jetted cement from wellbore to 10717' MD. POOH. Rigged down. 6/12/92: Reperforated: 10474 - 10478' MD (Z4) 10478 - 10482' MD (Z4) 10492 - 10500' MD (Z4) Ref Log: BHCS 4/13/84. Added perforations: 10482 - 10490' MD (Z4) Ref Log: BHCS 4/13/84. 7/22~92: Ran & set a 4900 psi Shear Disk in the 4.5" tubing at 9908' MD. 7~24~92: MIRU & PT equipment to 7500 psi. Pressured up on Shear Disk pumping 44 bbls of 1% KCl Water, & ruptured the Shear Disk at 4934 psi. Continued pumping a fullbore acid treatment consisting of 40 bbls Crude @ 20 bpm, followed by 25 bbls 50% Diesel/50% Xylene @ 20 bpm, followed by 30 bbls 15% HCl @ 10 bpm, followed by 50 bbls 6% HCI - 1.5% HF @ 10 bpm, followed by 150 bbls 2% NH4Cl, followed by Shutdown. ISIP @ 2229 psi. Resumed pumping 75 bbls 50% Diesel/50% Xylene @ 1.5 bpm, followed by 250 bbls Dead Crude @ 8 bpm, followed by Shutdown. Rigged down. 7/25~92: RIH & retrieved the ruptured shear disk from tubing tail. 9/28/92: A CTU Cement Resqueeze for Gas Shutoff was performed as follows: MIRU CTU & PT equipment to 4300 psi. RIH w/CT & fluid packed the wellbore w/hot Seawater, then pumped 28 bbls of latex acid resistive cement, squeezing the perforations (listed above). Placed 2 bbls of Latex Acid Resistive cement behind pipe at 3500 psi max squeeze pressure, & held for I hour. Contaminated cement w/biozan & jetted cement from wellbore to 10724' MD. POOH. Rigged down. 10/4/92: Reperforated: 10474 - 10490' MD (Z4) 10492 - 10450' MD (Z4) Ref Log: BHCS 4/13/84. 12/22/92: Added perforations: 10458 - 10472' MD (Z4) Ref Log: BHCS 4/13/84. Placed well on production & obtained a valid welltest. RECEIVED 1 1 99,3 Alaska Oil & Gas Cons. 6or~fr~iss~o~ ^r~chorag~ STATE OF ALASKA ALASKA '.. AND GAS CONSERVATION C( VIISSION 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1328' FSL, 104' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 272' FNL, 2313' FWL, Sec. 17, T10N, R15E, UM At effective depth 105' FNL, 2451' FWL, Sec. 17, T10N, R15E, UM At total depth 88' FNL, 2465' FWL, Sec. 17, T10N, R15E, UM 5. Type of Well Development X~ Exploratory Straligraphic 6. Datum of elevation(DF or KB) 71' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-29 9. Permit number/approval number 10. APl number 50 - 029 - 21087 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10778' feet 9222' feet Effective depth: measured 10735' feet true vertical 9184' feet Casing Length Size Structural Conductor 80' 20" Surface 2489' 13-3/8" Intermediate 10138' 9-5/8" Liner 926' 7" Plugs(measured) NONE Junk(measured) NONE Cemented 1850~ Poleset 1700 sx PF 'E' & 400 sx PF 'C' 500 sx Class G & 300 sx PF 'C' 320 sx Class G Measured depth 110' 2517' 10162' 9852'- 10778' True vertical depth 110' 2517' 8679' 8397'-9221' Perforation depth: measured 10458'-10472', 10474'-10500' true vertical 8945'-8957', 8959'-8982' Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tail @ 9921' Packers and SSSV (type and measured depth) OTIS 'HRQ' @ 2210', Baker 'SB-3A' pkr @ 9797' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure Fro ~ £ ~3~0 Alaska 0il & (~as C0r~s. Commission Anchorage 14. Prior to well operation Subsequent to operation Reoresentative Daily Averac~e Production orlniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 628 9529 1135 1500 951~ ~' 7570 1287 1945 Tubing PreSSure 1027 1242 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 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 ~ O.k/~~ Title Senior Operations Engineeer Form 10-404 Rev 06/15/88 // // cc: S. Wallace/DS Engr/J.'W. Peirce Date Z//~ SUBMIT IN DUPLICATE Daily Report of Operations DS12-29 12/22/92 MIRU HIS. PT. RIH w/GUN # 1. Shoot 10458-10472' MD. POOH. LD GUN # 1. All shots fired. Release well. RE( EIVED FEB t ~ 199) Anoho~g~ ARCO Alaska. Inc. P.O.Boz 10O36O Anchor~e, Alash 09510 DATK~ 13-18-02 REFERENCE: ARCO 1.s877o 2-18 3.20 ~3.33 ~ ~/~ (3-33 ~3-30 CASED HOLE 10-11.O2 1o-23-o2 lO-2-o2 11-6-02 11-12-02 lO-12.O2 11-?-02 lO-0.O2 10-0-02 11-eS.oS 11-12-02 lo.S-03 10-18.O3 11-8-03 1O.O.93 lo.I 1-02 lO-S-O2 lO-24-o2 32-?? e-18 11-13-o2 7-:38 &g -,/ ~/~' 8-0-01 o-28 ,~ ~/-.~? 0-24-02 o-28 J~'-2~ o.24-o2 ~o.2o 2-28-o2 ~o.2o 2-28-o2 ~/_/~) 11-SA ?/-/:'~- 11-11-02 12-8B . 10-13-02 12-20 13.20 a~-/~ ~-~o2 ~_~/[ 1~2 o-2s.o2 ~ - ~ l~z ~o-s~02 1~2 ~/-~ ~o.2~02 1&14 ~/-~ 10-22-02 1~2~r-~/~ ~o.22.o2 ?~_ ~g ~1~0 0-27.o2 ~0 10-I~02 l~311g~_ ~ 1o-12-o2 ~7-~s ~a~K ~o.o2 FINALS Leak Detect (flexstak) Run 1. 5"&10" Pert Record Ibm 1. 5" Pert Record Run 1. 5" Collar (IBP) Run 1. 5" Inj Profile (Step Rate) Run 1. 5" leak Detect(flexstak) Run 1. 5" Collar (IBP) Run 1. 5" GR/Collar Run 1.5" Prod Profile Run 1. 5" Collar (IBP) ibm 1. 5" Prod Profile Run 1. 5" Pert Record Run 1, IS' Leak Detect (flexotak) Run 1. 2"&5' Prod Profile ibm'l. 5" InJ Profile/PITS/Collar Run 1, 5" Prod Profile Rnn 1, 5" Per~ Record Run 1. 5" Pert Record Run 1. 5" PIT8 Run 10 5" Pert Record Run 1. 5" PaG/GR (Computed Re~ulta) ~ 1. 5" PaG/GR ~/ Run 1. 5" Leak Detect (flexstak) Run 1. 5" Set IBP Run 1, 5" Pert Record Run 1. 5" Collar Run 1, 5" Perf Record Run 1. 5" InJ Profile/PITS ~ Run 1. 5" Pert Record ~ Run 1. 5" Prod Profile (flexstik) Run 1. 5" PeIY Record Run 1. 5" Pert Record ibm 1. 5" Pert Record / B3m 1. 5" Prod Profile (flexstak) ~ Run 1. 5" InJ Profile/Temp// Run 1. 5" Perf Recird ~ Run 1. 5" GR/Collar / Run 1, 5" 8BL/GR/CCL ,'~ Run 1. 5" RECEIVED BT_~_~___~-.~.~ RECEIVED ATO-1530 the attached copy u receipt of data. m CEm'RAL r~u~ 5 0 1992 # MOB~, Camco HI.3 HIS Camco Camco Camco Camco Camco Camco C&mco Camco HIS Camco Camco Camco Camco HIS HIS Camco HIS HIS HIS HIS HIS Camco Camco HIS Camco HIS Camco HIS Camco HIS HIS HIS Camco Camco HIS Camco .Aw:choraGa ARCO .,Aln.~k;; Inc. P.O.Box 1001360 Anchorage, Alaska 99510 DATE: 9-18-92 REFERENCE: ARCO CASED 14-18 14-28 14-29 14 18-3 6-4-92 Peri Record R~n 1J, 5" 5-8-92 Peri Record R~m 1, 5" 5-29-92 Peri Record R~m 1, 5" 6-12-92 Peri Record R~m 1, 5" 7-2-92 Peri Record R~n 1, 5" 6-9-92 Peri Record R~m 1, 5" 6-9-92 Peri Record R~m 1, 5" 4-18-92 Peri Record R~_n 1, 5" 7-3-92 Peri Record R~ 1, 5" Have A Nice Da~ ~YE C E IV E D w ce OCT 0 5 1992 APPROVED_~ ATO- 1529 ~ns~ 9220~~~-- N~ 0il & Gas Cons. Commission ~chorage ~ CE~~ ~ ~ ~~ON D&M ~ EX~NSION E~~~TION ~ E~ON ~~ON ~ MOB~ # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO /0 ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-18-92 REFERENCE: ARCO CASED HOLE FINALS 1-24 8-18-92 8-18-92 8-8-92 8-9-92 8-13-92 8-14-92 8-15-92 11-13 8-17-92 8-14-92 16-28 8-10-92 8-17-92 Prod Profile R,,n 1, 5" Prod Profile Run 1, 5" Prod Profile (Flexstak) R,m 1, 5" Prod Profile R,m 1.5" em/cci., Prod Profile Leak Detect Temp Prod Profile R~m 1, 5" R~m 1, 5" R~m 1, 5" R~m 1, 5" R~m 1, 5" R~_r~ 1, 5" R!~n 1, 5" C~mco Camco Camco Camco Camco Camco Camco Cnmco Camco Camco Camco Please sign and retttrn~t~atta~Z co~ as receipt of data. ///. Sonya Wallace OCT 0 APPROVED ___ ATO- 1529 fil~ 0.il & 6as # CENTRAL ~ # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PtHLLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ARCO ALASKA, ]'NC. P~O. I.-':OX ~00S60 ~795 t 0 R E F' E Fi: [il N C E ' A R C 0 N A g N E T I ['- 8 - 9 t T D T - - 9 0 R U N 6-9t CNL.-GR~ 5-... 9 t C N 'f' - D ~ ~ o - ~- ~ R U N 3 9t D,.,N ~3-~5q RUN t 4'--9t CNI._--(;R ~:~ ~ 4-9t C [.~ L-. 6 Fi'. 8-9t DaN ~73-0~ RUN 2-..9 ~ CNI'.-.D F~7-$J RUN l' A P [il ( S ) W I T H L. I ,S' 1' I N (.; ( S ) JOB:~'?4762 JOB~:898i 9 d 0 B :.":. '? 4 '7 '? 4 JOB~:L66'?SS-9 UOB:~89835 UOB~:898S6 JOB:~L66'745-8 JC)B~:74862 I-'-'I..EASIE $:I:(:;N AN?;:IF'FUI'"<N~E AT'I'A(~FZD COF'Y AS Rti-'CEIF'T OF H A V Ii:.' A N ]: C E ):> A Y ! O C f 1 8 19 91 :5:ON YA WALL. ACE APPF;..'O YED ......... ....... f~'.. ,1,,, A I u-i 5 '') 9 ,,l,:s,,n Oil & Sas C;ons. 6ommission " ^nthomgo ']-R A N S 9 A'I'I...AS SCH FILS AI'I_A,S' ATLAS HLS SCH fl--II"' I'HE D I S T Fi: I B U T I 0 N :.': CENTI;:At_ FILES (CH) ~ PHILLIPS CHEVRON PB WELL F'ILEiS D & M R & D TAMi'iAS BROWN (OH/'GCT) ~: BPX :~ EXXON '-'~ S'fATE OF ALASKA NARAi'HON TEXACO MOBIL. CC)Fi:Fi:ECl'ED AF:'I4: I-"-'OF;: 2-3 IS 50-0':29--2"'"a077~ COI';:F;:I.:.'CTFD AF'IO F'OR 9-'S0 IS 50--029""2~4~ i. ARCO ALASKA, INC. F'.O. BOX iOOS60 ANCHORAGE, ALASKA 995"r9 .~ DATE' 8-i6-9i REFERENCE' ARCO CASED HOLE FINAI_S ~.. ,._o-3 7-26-c~, '2-2S 8-S-9~ S-2 TM 7-26-o ~S-S5 7-'25-9i 5--i S 7-7~0--9 t 9/-~5-32 8-3-9i 7-2 7-26-9i 7-i 7 7-3i -9i 7-29 7-Si -9i 9-2 8-i -9i 9-9 8-i -9i 9-i8 7-~-9t ~ 9-30 7-24-9 i 2-29 7-24-9 CNL-GR COLL. AR-PERF TUBING CUTTER ' F'FC-GR (PACKER SETTING) PFC COLLAR/PACKER CNL-GR COLLAR COLLAR-PERF TUBING CUTTER COi. LAR.-F'ERF COLLAR-F'ERF CNL-GR CNi_-GR RUN. i , _,~" RUN i , 5' RUN i , _,-~" RUN i , 5' RUN i, 5' RUN i , 5' RUN i , 5' RUN i , .5' RUN t, 5' RUN i , 5' RUN i , 5" RUN i, 5' RUN I, 5' RUN t, 5' PLEASE SIGN AND RETURN THE ATTACHED COPY AS REcEiPT OF i)AI'A~ F:ECEIVED BY ~_.~___ HAVE A NICE DAY! SON'fA WAI_LACE ATO-i 529 APPROVED TRAN$¢ 9 i A'f'L.A,? Al-LAS A'FL. AS Al t_A:~' A TLA ~ AI'LA.'£ A'f'LA :.5: ATLAS ATLAS ATLAS AT L A S ATLAS Al'LAS DISTRIBUT]iON CENTRAL FILES CHEVRON FXTENSION EXPLORAi"]] ON. EXXON HARATHON MOB I L PHILLIPS F'B WELL. FILES R & D BPX 2i'A'f'E OF ALASKA TEXACO :'~ "f'HE r,'ORRECTED AF'IO FOR ')--',_ .'5, IS ~':'0-029-200'77 ~* THE CORRECTED AP'I'~ FOR,~,9-30 'rS 50-':'}29-2t4ii ~ AU~ 1 9 1997 ;4laaka 0il. &AnchorageGaS COns. C°mraiss/oo ARCO ALA2KA, INC. F'.O. BOX t00Z60 ' ANCHORAGE, ALASKA 995t,3 DATE' 5-22-9t REFERENCE. ARCO CASED HOLE F!NALZ S-22 t 2-28-90 GR . ~-.~¢ 4-22-9t ~'RL '-'~ 6-7 t 2-5-9'3 TEMP/$F'INNER 7-28 5-4-9t LEAK DETECT. 9-5 i 2-i S-90 CORR GR 9-45 t 2-t 0-90 ' TEMP t~-_°-~'.,- t.-°-:)°-°(':',-.-. , w GR t 2-8B 5-i 2-9i VEF;TILOG i2-i8 5-S-9i F'ROD. PROFILE i2-29 5-5-9i PROD. PROFILE t4-iS 5-t -9t IN J, PROFILE t 6-6 5-6-9t COLLAR/F'ERF ' t 6-9A 5-5-9t CBT t6-9A 5-5-9t -- CET ' t 6-9A 5-6-9t F'ACKER REC 18-!t 5-4-9t GAS DETECTION RUN t, 5 RUN i, 5 RUN t , 5 RUN t, 5 RUN i , 5 RUN t , 5 RUN t, 5 RUN i ~ 5 RUN 2~ 5 RUN i, 5 RUN t,..,-~ RUN i, 5 RUN t, 5 RUN t , 5 F.'.~JN t, 5 · HR£' · Afl_AZ " HR'S " CAMCO " HRZ · HR.,. .1~' ¢' " H, .~ ! I_~-..'.. " CAMCO · CAMCO " CAMCO . · AI'!_AZ " $CH · ....... $CH " ' ::..;', ::' 2CH _ . · CAMCO PLEASE SIGN AND RETURN THE ATTACHED'COPY AS RECEIPT OF DATA.- ..................... RECEIVED BY. _ ~J _. HAVE A NICE DAY! SUNNY WALLACE AF'PRO~ED AT0-t529 'TRAN.$~ 9t~58 : DISTRIBUTION CENTRAL FILES ~ RHILLIPS- CHEVRON PB WELL FILE'"J D & M R & D EXTEN2ION EXPLORATION ~ BPX EXXON ~ 2TAI'E OF ALAS-'KA MARATHON TEX,~CO MOBIL THE AF'I$ FOR 5-~°0 I~'~ 50-029-22i 37 RECEIVED -. MAY 2 5 1991 . ....................... Alaska Oil & Gas Cons. oommj~' .mn_ .......... Anchorage STATE OF ALASKA . · ~ OIL AND GAS CONSERVATION COMMI~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate __ Plugging __ Perforate .., Alter casing X Repair well Pull tubing X Other.~X Workover 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development .~X ARCO Alaska. Inc. Exploratory _ 71' RKB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1328' FSL, 104' FWL, Sec. 17, T10N, R15E, UM 12-29 At top of productive interval 9. Permit number/approval number 272' FNL, 2313' FWL, Sec. 17, T10N, R15E, UM 84-32/90-605 At effective depth 10. APl number 105' FNL, 2451 FWL, Sec. 17, T10N, R15E, UM 50-029-21087 At total depth 11. Field/Pool Prudhoe Bay Field 88' FNL, 2465' FWL, Sec. 17, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10778' feet Plugs(measured) NONE true vertical 9222' feet Effective depth: measured 1 0735' feet Junk (measured) NONE true vertical 9184' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 20" 1850# Poleset 1 1 0' 1 1 0' Surface 2489' 1 3-3/8" 1700 sx PF 'E' & 251 7' 251 7' 400 sx PF 'C' Intermediate 1 01 38' 9 -5/8" 500 sx Class G & 1 01 62' 8679' 300 sx PF 'C' Liner 926' 7" 320 sx Class G 9852'-1 0778' 8397'-9221' Perforation depth: measured 10440'-10450', 10458'-10482', 10492'-10502' true vertical 8929'-8938', 8945'-8966', 8975'-8983' Tubing (size, grade, and measured depth) ':"~ _~ Cb~l I/~,D 5-1/2"/4-1/2", L-80, tbg wi tail @ 9921' ' Packers and SSSV (type and measured depth) OTIS 'HRQ' @ 2210', Baker 'SB-3A' pkr @ 9798'~:,_._ 13. Stimulation or cement squeeze summary ' '~/-~ ~J-%. - None , ,,, , ~,IS, Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Reoresent{ttive Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments *WORKOVER WELL HISTORY 16. Status of well classification as: Copies of Logs and Surveys run ~ Water Injector ~ Daily Report of Well Operations X~ Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~ 0 ~ ~Z. ~.--.. Title Drilling Analyst Date Form 10-404 Rev ¢,";/17/89 SUBMIT IN DUPLICATE ARCO Oh-.'nd Gas Company ,~, Daily Well History-Final Report Instructions: Prepare and submit the' "~t" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned or Sold. "Final Report" should be submitted al.~)_"~liF~l~...-.-t"-I~tations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report coml~., a~td I'el;resentative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. ~: · Accounting cost center code .. Dislrict ICounty or Parish /State ARCO ALA'SKA INC. NORTH SLOPE AK Fie~d ~Lease or Unit Well no. PRUDHOE BAY I ADL: 28330 DS 12-29 Auth. or W.O. no. ~Title AS 3781 I WORKOVER /%PI: 50-029-21087 Operator I A.R.Co. W.I. ARCO J 22.0000 Spudded or W.O. begun ~ Date' ACCEPT I 9/1/90 Complete record for each day reported AUDI RIG #4 Date and depth as of 8:00 a.m. 09/10/90 ( TD: 0 PB:10735 SUPV:DAC 9) I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our ~ Prior status if a W.O. 0700 HRS I RIG RELEASED MW: 8.5 FSW FINISH RUN 5-1/2" COMPLETION ASS'Y. LAND TBG. PRESSURE TEST. OK. ND/NU. TEST TREE. OK. SET BPV. SECURE WELL. RELEASE RIG 2300 HRS 9/9/90. DAILY:S162,849 CUM:$563,777 ETD:S563,777 EFC:$703,100 Classifications (oil, gas, etc.) Producing method IType completion (single, dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct t'-.. Signatur~,,~` ~,~'~ ~' I ~...~0~' Da, I''tie Drilling Supt. For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. DNIMon of AtlanflcRIcMleldCempa~y Well History - Initial Report- Dally ARCO Oil"~d Gas Company Inelruetlons: Prepare and submit the "lldtlll R~' on the first Wednesday after a well is spudded or work:over operations are started. Daily work prior to srxJddln~ahould be summarized on the form giving inclusive dates only. Oistrict ARCO ALASKA ;~NC' PRUDHOE BAY Field AS3781 Auth. or W.O. no. ICounty. parish or borough ILea~e or Unit AK IState [[ ,lo~-29 ARCO ARCO W.I. ~" ~ ' Operator ACCEPT Spudded or W.O. begun Date and depth as of 8:00 a.m. 09/02/90 ( TD: 0 PB:10735 SUPV: RWO 09/03/90 ( TD: 0 PB:10735 SUPV:RWO 09/04/90 ( TD: 0 PB:10735 SUPV:RWO 09/05/90 ( TD: 0 PB:10735 $UPV:RWO 09/06/90 ( TD: 0 PB:10735 SUPV:DAC 09/07/90 ( TD: 0 PB:10735 SUPV: DAC 09/08/90 ( TI): 0 PB:10735 $UPV: DAC 09/09/90 ( ~13: 0 PB:10735 SUPV: DAC AUDI Complete record for each day reported 1 ) LD TUBING HANGER 2) 3) 4) Hour Prior status if a W.O. ~HW: 8.5 FSw FINISH MOVE RIG F/L 5-18 TO DS 12-29. ACCEPT RIG AT ~%~:00 : . 9/1/90. MIRU. KILL WELL. ND TREE. NU STACK. PULL TBG HGR TO FLOOR. LD TBG HGR. DAILY:S54,144 CUM:$54,144 ETD:S54,144 EFC:$703,100 . RU ATLAS WL MW: 8.5 FSW FINISH LD TBG HGR. POOH W/5-1/2" COMPLETION ASS'Y AND LD SAME. (NOTE: DID NOT PULL TAIL ASSY) RIH AND SET RBP AT 2983' MD. RU BJ AND LAY SAND ON RBP. RU ATLAS WL FOR CBL/CCL RUN. DAILY:S37,814 CUM:$91,958 ETD:S91,958 EFC:$703,100 LD 9-5/8" CASING MW: 8.5 Few FINISH LOG WITH CBL/CCL. RIH W/TRI-STATE 9-5/8" CUTTER. CUT 9-5/8" CASING. LD CUTTER AND PU SPEAR. SPEAR 9-5/8". POOH W/9-5/8" CASING. DAILY:S38,016 CUM:$129,974 ETD:S129,974 EFC:$703,100 RIG EVACUATED ]~8:8.5 FSW FINISH LD 9-5/8" CUT/PULL CSG. RIH AND MAKE BACKOFF AT 1996' MD. POOH. RIH W/SPEARAND BACKOUT BACKOFF CONNECTION. POOH W/STUB. RIH W/BIT AND SCRAPER. SECURE WELL. EVACUATE RIG DUE TO A FIRE AT DOWELL IN DEADHORSE. DAILY:S27,811 CUM:$157,785 ETD:S157,785 EFC:$703,100 TESTING CASING MW: 8.5 Few ]~%NNED RIG AT 0800 AFTER EVACUATION DUE TO FIRE AT DOWELL IN DEADHORSE. RAN 9-5/8" CASING. SCREWED IN AND TESTED. OK. SET ECP. TESTING CASING AT 0600. DAILY:S84,604 CUM:$242,389 ETD:S242,389 EFC:$703,100 CLEAN OUT JUNK BASKET MW: 8.5 FSW ND BOPE/TBG HEAD. SET SLIPS. NU. TEST PACKOFF. OK. TEST CSG. OK. FISH PIECES OF CENTRALIZERS OFF SAND PLUG. DAILY:S28,060 COM:$270,449 ETD:S270,449 EFC:$703,100 CUT AND SLIP DRLG LINE MW: 8.5 FSW RETRIEVE RBP. PU BAKER DUMMY SEAL ASS'Y AND RIH. STING INTO PACKER. TEST DP 3000 PSI. OK. TEST ANt~u'LUS 3000 PSI. OK. DISP WELL W/INHIBITED SEAWATER. DAILY:S97,406 COM:$367,855 ETD:S367,855 EFC:$703,100 RIH W/5-1/2" COMPLETION MW: 8.5 FSW POOH LDDP. NO DAMAGE TO DUMMY SEALS. RUAND RUN 5-1/2" COMPLETION ASSY W/ 4-1/2" TAIL (OTIS 'HRQ' SSSV @ 2210', BAKER 'SB-3A' PKR @ 9798', TT @ 9921'). DAILY:S33,073 ' CUM:$400,925 ETD:S400,928 EFC:$703,100 For, .... ~)lratlon'~nddiatributlon '%' Et ~ I V ]~!J see Proce%urea Manual, Section 10, ' ~.~,~ Drilling, Pages 86 and 87. Anchora?a AR3B-459-1-D Drilltrlg asNumberall dai y well history forms consecutively no. they are prepared for each wel. I lPage I ARCO ALASKA, ZNC~ F' 0 B 0 v i (-] (:; 7, A (.*, ., ~ /% _ _: -._ .... ANCHORAGE, ALA3'K A DATE' 9-i 7-90 F.'.!--FERENCE' ARCO CA:CED HOLE FINAL!-: 'i - 9 ':) .- ':: - ':) ;:, C N L - 6 F.' F.;.: i 1N ,- ,._~ / ._. _ . . . ..... · i -24 v.-v ..... /;-.;, PDK-i ,:),::i:,/6R/CE:L RUN "':'.-'7 ,..-,- ,... -.-:;, ¢.h 'i'B6 CUTTER RUN ~,'.,. ,,..... 6- ! ::.'~ 8-:.].f, i --?,::_) i':'ERF F;..'E:C:OF,'D F;;UN '.7 .... ...:"S :_,°-~';;:~-'."-.";:',... . ._. (;J:-'--' I;'-J,. CA2"rNi.;.... . RUN ? - 45 8 -:'~ ,::2 - "..-.-' .".) C B T i:.;.'. U h! ,'.'.4, -. 45 .-.., (:'~ - 5 f"; ... '- ~;' . ;:~ ... C E T R U N i 2--29 9-.5-'..--';.J ACBL/VF:,L/~: l (.; R L..' N i12' . · -'! ........ : '-'". .s-'-i 6 ':::'-,- ,'-V;:;.., p' I:, ~.: - -~.. :, ~:;¢:;/~R/CE:~,, ... _ ,_/' ~':; ORAX RUN. i ,4_2.a... , o_.,.._o;.:-,,. ,_, ., ., COLLAi";.:.,'"F'[-.'RF F;.:UN i 8-? 9-i ,:;:,-9,3 PDK-i ¢':Z:'..-"'6 R/CCL. RUN F'WDW i-2A 9- 6- 9 ;..'} C:BT i;.' U N PWi)W i -2A '.'..;'- 6- 9 ¢ CE]" RL!N F'WDWt-2A 9-'7-9,'.:) f"KR ,~'ET]"iNG RF'C'ORD RUN i: i, i, i, i... i, i, i, i, i, i., i, i, · "': ii .-:. ,~.' ii _;" 5" ,.....-., 5-' .... ~_~,,.,,_ .sIGN AND RFTURN THE ATTACHE:D COF'Y A£' F,'E:CEZF'T HAVE A NICE DAY~ ~AI_.LY i"10 F' F ECi( E F,' Al'O- i ~' '~'~ OF' DATA. SEP 1 9 1990 , ,~/ Alaska 0il .& Gas Cons. G0m~'t$$iOIIF'F'ROV'ED ~ TRAN$.~ 9,S,~ 6.~ Anchorage A i' L A,~i: A!'I_A.':¢ A FLA~.; ;~." C H; £ C' i--i i:: E: H; A rl_/'.,,~i: A i"L Ag' A'T L A :'--:."' Z-.'CH J:.-'C H ~,"Ci4 DISTRIBUTION · ,,-' . CENTRAL FILE3: ¢ F'H:[I,_LI'-'"'I- ,.', -,-'"' CHEVRON PB WELL F'ILE,.9 D *,.., M R & D -.-'"' EXTENSION EXF'LuR~TION :~ BF':~,. ~ EXXON .~'~ $'T'A i'E OF ALA ~"::~',, A MARATHON TEXACO ~- MOBIL. THE CORRECTED AF'I~ FOR F'WDWi-2A ]:2-' ""'(~,-¢:.~'-'o--vY.r.)P,~-(-'.~t STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLIOATION FOR SUNDFIY APPFIOVAL$ 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing ~ Repair well X Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing X Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ._X. ARCO Ala, ska. Inc. Exploratory _ RKB 71' feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1328' FSL, 104' FWL, Sec. 17, T10N, R15E, UM 12-29 At top of productive interval 9. Permit number 272' FNL, 2313' FWL, Sec. 17, T10N, R15E, UM 84-32 At effective depth 10. APl number 105' FNL, 2451 FWL, Sec. 17, T10N, R15E, UM 50-029-21087 At total depth 11. Field/Pool Prudhoe Bay Field 88' FNLr 2465' FWLr Sec. 17r T10N~ R15E~ UM Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10778' feet Plugs(measured) NONE true vertical 9222' feet Effective depth: measured 10735' feet Junk(measured) NONE true vertical 91 84' feet Casing Length Size Cemented Measured depth True vertical depth Conductor 8 0' 2 0" 1850# Poleset I 1 0' 1 1 0' Surface 251 7' 1 3-3/8" 1700 sx PF 'E' & 251 7' 251 7' 400 sx PF 'C' Intermediate 1 01 62' 9-5/8" 500 sx Class G & 1 01 62' 8679' 300 sx PF 'C' Liner 926' 7" 320 sx Class G 9852'-10778' 8397'-9221' Perforation depth: measured 10440'-10450', 10458'-10482', 10492'-10502' true vertical 8929'-8938', 8945'-8966', 8975'-8983' Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, Tbg w/ tail @ 9921' _.~ ~. ,:-- Packers and SSSV (type and measured depth) ~ '~':~'~ OTIS 'HRQ' ~ 2223'~ Baker 'SB-3A' pkr ~ 9798' 13. Attachments Description summary of proposal _X Detailed operation program ~ BOP sketch ~X 14. Estimated date for commencing operation 15. Status of well classification as: ^u_oust 15. 1990 Oil _X__.. Gas ~ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service '17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SiDned ( ~ ~~tJ,L~ Title Drillin9 Analyst Date ~"~-~0 FOR COMMISSION USE ONLY Conditions ~f approval: Notify Commission so~re, presentative may witness IApproval No Plug integrity _ BOP Test X- Location clearance __ I Mechanical Integrity Test_'~ Subsequent form require 10-~t,-~ Anproved C,~op~J ORIGINAL Approved by the order of the Commission I ¢IklNIF {':,. S~/IITH Co~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 12-29 WORKOVER PREUMINARY PROCEDURE OBJECTIVES: · Pull the 5-1/2" tubing and seal assembly. · Set a RBP in the 9-5/8" casing at 3000'. · Cut, pull and replace the 9-5/8" casing from the surface to 2500'. · Retrieve the RBP. · Re-run the 5-1/2" tubing and seal assembly. PRIOR TO RIG-UP: Coordinate with the wireline group and perform the following slickline work: · Pull the Otis SSSV at 2,222'. · RIH and set an Otis 'PXN' plug in the 3.725" 'XN' nipple at 9908' MD. · Pull the RKED from GLM #8 at 9,572' MD. 1. ~IRU AUDI 4. Giroula~ and displace th~ ~11 with 8.5 ppg 2. ND Tree. NU and te~ BOPE. 3. Pull and LD the 5-1/2" completion. Have all equipment inspected and redressed. The 4-1/2" Camco CIM will be replaced with a 5-1/2" Camco MMG-7-LTS CIM. 4. Set a 9-5/8" RBP at +3000' and spot 50' of sand on top. 5. Run a CBL to find the top of the cement in the 13-3/8" X 9-5/8" annulus. 6. Cut, pull, and back-off the 9-5/8" casing two joints above the top of cement in the 13-3/8" x 9-5/8" annulus. 7. RIH w/12-1/4" bit and 13-3/8" casing scraper to the top of the backed-off 9-5/8" casing. CBU, POOH. . RIH w/13-3/8" R'l-rS and set above 9-5/8" casing stub. Pressure test 9-5/8" x 13-3/8" annulus below RTTS to 2000 psi for 30 min. Pressure test the 13-3/8" above the R'I-I-S to 2000 psi for 30 min. . Run new, 9-5/8" MOD BTC casing with external casing packer and screw into casing stub. Displace hole with hot, OBM prior to screw in. Test 9-5/8" connection and set ECP. Set 9-5/8" slips, ND BOPs and tubinghead. Install new 9-5/8" packoff. NU tubinghead and BOPs. 10. RIH, displace OBM with seawater. Retrieve the RBP at_+3000'. 11. RIH with dummy seals on DP. Sting into packer and test packer and 9-5/8" casing to 3000 psi for 30 min. Displace hole with inhibited seawater. POOH, LD DP. 12. Re-run the 5-1/2" completion string with a new 5-1/2" CIM and treater string and GLM's. Freeze protect and land the tubing. Pressure test tubing and annulus. 13. ND BOPE. NU and test the Tree. 14. Release rig. Move off. Turn well over to Production. 15. Pull 'PXN' plug. Pull Otis dummy SSSV and run live Otis SSSV. Workover Fluid = 8.5 ppg seawater BHP = 3675 psi at 8800' TVD (8.0 ppg equivalent) 13-5/8" 5000 PSI BOP STACK ANNULAR PREVENTER 7 PIPE RAMS 6 ACCUMULATOR ~APA(~ITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BLIND RAMS 5 DRILLING SPOOL PIPE RAMS 3 TUBING HEAD 2 1.13-3/8" CASING HEAD 2. 5000 PSI TUBING HEAD 3.13-5/8" - 5000 PSI PIPE RAMS 4. 5000 PSI DRILLING SPOOL 5.13-5/8" - 5000 PSI BLIND RAMS 6. 13-5/8" - 5000 PSI PIPE RAMS 7.13-5/8" - 5000 PSI ANNULAR BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL IN WINTER OR SEAWATER DURING SUMMER MONTHS. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 1~ MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOP TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY FOR DRILLING OPERATIONS. FOR COMPLETION/ WORKOVER OPERATIONS, PERFORM COMPLETE BOP TEST EVERY 21 DAYS AND FUNCTION TEST BOP WEEKLY. DAM 11/20/$9 BOP SCH (FOR: NAB 2ES) ARCO ALASKA, INC. P.O. BOX 10.A. 360 ANCHORAGE, ALASKA 99Dt0 DATE' 3-9-90 REFERENCE' ARCO F'RES~URE DATA 3-4 t-6-90 BHP--$TATIC GRADIENT CAMCO 3-t8 t-6-90 BHF ....~TATIC GRADIENT CAMCO 9-.t5 t-t5-90 BHP--3'TATIC GRADIENT CAMCO 9-i9 t-t5-9~ BHF'--~TATIC GRADIENT CAMCO ~ t-~ ~-5-9~ BHF'--~TATIC ~ t .-.~ 6 ~ -5-9~ BHF:'--~'TATIC ~ 2.-2S J -7-9~ BHF'--~TATIC HRS ~2-29 t-~S-9~ BHP--~'TATIC GRADIENT CAMCO I S-~2 ~ -7-90 BHP--~'TAT I C HR~ t4-2t ~-S-9~ BHP--FLOWING GRADIENT CAMCO ~4-S6 ~-S-9~ BHP--FLOWING GRADIENT CAMCO t6-~t ~-~S-9~ BHP--~TATIC GRADIENT CAMCO ~8-S t~-29-89 BHP--~TATIC GRADIENT CAMCO ~8-9 ~t-29-89 BHP--~TATIC GRADIENT CAMCO ~8-t6 ~t-29-89 BHP--~TATIC GRADIENT CAMCO ~8-20 ~.-.29-89 BHF'--~TATIC GRADIENT CAMCO PLEASE ......... HAYE A NICE DAY! SALLY HOFFECKER MAR 1 4 !990 APPROVED AT0-i529 A[askaOjj&GasCo~s.~o~$S~ TRANS~ 9 SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA~ DISTRIBUTION CENTRAL FILES T ~ ~'HILLIP~ CHEVRON PB WELL [:'ILEX D & M -~ ~ R & D EXTENSION EXF'LORATION ~ ~ BF'X EXXON . - STATE OF ALASKA MARATHON ~' TEXACO '1~ . MOBIL 1. Operations Performed: Operation Shutdown.. Alter casing __ Repair well STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMM~ION REPORT OF SUNDRY WELL OPERATIONS Plugging Other Perforate Workover 2. Name of Operator ARCO Al~.ska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate X Pull tubing X 5. Type of Well' Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 71' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number 12-29 9. Permit number/approval number 84-32/9-562 10. APl number 50-029-21 087 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Location of well at surface 1328' FSL, 104' FWL, Sec. 17, T10N, R15E, UM At top of productive interval 272' FNL, 2313' FWL, Sec. 17, T10N, R15E, UM At effective depth 105' FNL, 2451 FWL, Sec. 17, T10N, R15E, UM At total depth 88' FNL, 2465' FWL, Sec. 17, T10N, R15E, UM Present well condition summary Total Depth: measured true vertical 10778' feet Plugs(measured) NONE 9222' feet Effective depth: measured 1 0735' feet Junk (measured) NONE true vertical 9184' feet Casing Length Structural Conductor 8 0' Surface 251 7' Intermediate 1 01 62' Liner 926' Perforation depth: measured Size Cemented 2 0" 1850# Poleset 13-3/8" 1700sx PF'E'& 400 sx PF 'C' 9-5/8" 500 sx Class G & 300 sx PF 'C' 7" 320 sx Class G None open to production true vertical None open to production 12. Measured depth True vertical depth 110' 110' 2517' 2517' 10162' 8679' 9852'-10778' 8397'-9221' RE£ VED Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, Tbg w/ tail @ 9921' Packers and SSSV (type and measured depth) OTIS 'HRQ' ~ 2223', Baker 'SB-3A' pkr @ 9798' 13. Stimulation or cement squeeze summary Tubing Pressure Intervals treated (measured) Perforations f/10370'-10502' Treatment description including volumes used and final pressure 45 bbls 12:10 HCI~ 45 bbls 12:3 HCI~ 2 bbls 12% HCI & 15 bbls ARC cmt 14. N/A Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 16. Status of well classification as: Water Injector__ Oil .__X.._ Gas Suspended Service 15. Attachments *WORKOVER WELL HISTORY Copies of Logs and Surveys run m Daily Report of Well Operations X* Date I-Z5'?O SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 05/17),~9 ARCO Oil and Gas Company Well History - Initial Report Instructions: Prepare and sbbmit the "Initial Reporl" on [he first Wednesday after a well is spudded or workover operations are started. Daily work prior tO spudding should De summarized on the form giving inclusive dates only. County. parish or borou n District ARCO ALASKA INC. PRUDHO~ BAY Field Lease or ~L: 2833O Auth. or W.O. n,l~S3081 IT t e WORKOV]?.R I IState ~ DS 12-2~well no. API: 50-029-21087 Operator A~,CO Spudded °r W'(~'~T IOate 12/14/89 IH°ur Dale and depth as gl 8:00 a.m. 12/15/89 ( TD: 0 PB:10735 SUPV:JPS 12/16/89 ( TD: 0 PB:10735 SUPV:JPS 12/17/89 ( TD: 0 PB:10735 SUPV:JP~ 12/18/89 ( TD: 0 PB:10735 SUPV:JPS 12/19/89 ( TD: 0 PB:10735 SUPVtJPS 12/20/89 ( TD: 0 PB:10"35 SUPV:JPS Complet ..... ~ fa~y ~poHed 1130 ARCO2WlJ'. 0000 Pr or status if a W.O. PULL TUBING HANGER MW: 0.0 FSW MOVE RIG FROM DS 15-1 TO DS 12-29. ACCEPT RIG @ 1130 HRS, 12/14/89. FILL HOLE W/22 BBLS SEAWATER. MONITOR WELL. WELL STABLE. NU BOPE AND TEST SAME TO 5000 PSI. PULL BPV. BOLDS. MU LANDING JOINT IN TOP OF TUBING HANGER AND PULL SAME TO RIG FLOOR. DAILY:S236,500 CUM:$236,500 ETD:S236,500 EFC=$1,173,000 POOH W/5-1/2" TUBING MW: 0.0 FSW MU 5-1/2" OVERSHOT AND RIH. TAG FISH @ 98'. COULD NOT ENGAGE. ATTEMPT TO ENGAGE TUBING THREE MORE TIMES W/OUT SUCCESS. DRESS INSIDE AND OUTSIDE OF FISH. RIH W/SPEAR AND ENGAGE TUBING. PU 235K~ AND FISH CAME FREE. POOH TO 5-1/2" TUBING. CIRC 8.5 PPG SEAWATER. MEASURED 1-10 PPM H2S WHILE CIRC. WELL DEAD AFTER CIRC 800 BBLS. HOLE STABLE, NO LOSSES. POOH, LD 5-1/2" TBG. DAILY:S28,400 CUM:$264,900 ETD:S264,900 EFC:$1,173,000 RIH W/SHOE ON DP MW: 0.0 FSW LD 231JTS 5-1/2" TUBING, 11GLMS, AND SEAL ASSEMBLY WITH PBR ATTACHED. PBR HAD 2' PIECE OF 4-1/2" TUBING ATTACHED. TEST BLIND RAMS TO 5000 PSI. MU DRESSING SHOE FOR 4-1/2" TUBING FISH ON DP AND RIH. DAILY:S28,000 CUM=$292,900 ETD:S292,900 EFC:$1,173,000 RIH W/DRESSING SHOE MW: 0.0 FSW RIH, DRESS 4-1/2" TUBING STUB FROM 9832'-9839' MD. CBU, POOH. RECOVERED 3' 4-1/2" TUBING INSIDE WASHPIPE. RIH W/WASHPIPE. TAG FISH @ 9835'. CBU, POOH. RECOVERED 2' 4-1/2" TUBING. RIH W/DRESSING MILL AND WASHPIPE. DAILY:S28,100 CUM:$321,000 ETD:S321,000 EFC:$1,173,000 MU 8-1/2" MILL MW: 0.0. FSW RIH W/DRESSING MILL. WASH OVER FISH FROM 9838' TO 9841' MD. POOH. MU OVERSHOT AND RIH. ENGAGE FISH @ 9841' MU. LATCH FISH AND PU 24K) OVER STRING WT. OVERSHOT SLIPPING OFF. WELL FLWNG. CBU. POOH. NO FISH. MU 8-1/2" CONCAVE MILL TO DRESS TOP OF FISH. DAILY:$28,300 CUM=$349,300 ETD=S349,300 EFC:$1,173,000 CIRCULATING MW: 0.0 FSW RIH W/8-1/2" MILL. TAG PKR @ 9840' MU. MILL AND DRESS OFF TO? OF PKR TO 9841' MD. CIRC HOLE-CLEAN 2~D POOH. MU 4-3/4" PILOT MILL AND RIH. CLE/tN OUT PKR BORE FROM 9841' TO 9844' MD. CIRCULATE HOLE CLEAN. DAILY=S27,800 CUM~$377,100 ETD=S377,100 EFC~$1,173,000 The above is correct Signature For form~prepa~ration ~~- see Procedures Manual, Section 10, Drilling, Pages 86 and 87', Date I Title / / aa-/t',~ Drilling Supt. AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. iPage no. · . ARCO Oil and Gas Company Daily Well History--ln~_. Instructions: Th~s form ,s used during Grilling or v.'orko'..er operations. If lasting, coring, or perforatino, show formation name in describing work performed. I"~umDer ~il erl!t stem !ests sequentially. Attach description of all cores· Work performed by Producing ~Section will be reported on "!nferim" sheets until fina! complehon. Report official or representative test on "Final" form. [) Submit "Interim" sheets when filled ou! but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and [ollowing setting of oil string until completion. District [County or Parish I State ARCO ALASKA INC. PRUDHOE BAY AK Field Lease or Unit DS 12-29 Complete record for each day while drilling or workover in progress AUDI RIG 4 Date and depth as of 8:00 a.m. 12/21/89 ( TD: 0 PB:10735 SUPV:ZR 12/22/89 ( TD: 0 PB:10735 SUPV:ZR 12/23/89 ( TD: 0 PB:10735 SUPV:ZR 12/24/89 ( TD: 0 PB:10735 SUPV:ZR 12/25/89 ( TD: 0 PB:10735 SUPV:ZR 12/26/89 ( TD: 0 PB:10735 SUPV:ZR The above is Correct .1) ,2) For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 CIRCULATING MW: 0.0 FSW CIRC HOLE CLEAN, POOH. MU 4" SPEAR AND RIH. TAG FISH @ 9841' MD. ATTEMPT TO LATCH FISH. POOH, NO RECOVERY. MU 4.75" SPEAR AND RIH. LATCH FISH AND PU 110K# OVER STRING WGHT. RELEASE PER. CIRCULATE BOTTOMS UP. DAILY:S28,500 CUM:$405,600 ETD:S405,600 EFC:$1,173,000 RIH W/SPEAR MW: 0.0 FSW TAG FISH @ 9841' MD. SPEARED FISH AND PU TO ll0K~ OVER STRING WGT. PACKER RELEASED. CIRC BTMS UP. POOH 1JT, PKR HUNG UP. WORK PKR THROUGH TIGHT SPOT. POOH, NO RECOVERY. MU NEW 4-3/4" OD SPEAR AND RIH. TAG FISH @ 9808'. PUSH FISH TO 9847'. ATTEMPT TO SPEAR FISH. POOH, NO RECOVERY. MU 4" OD SPEAR BELOW 4-3/4" OD SPEAR AND RIH. DAILY:S28,000 CUM:$433,600 ETD:S433,600 EFC:$1,173,000 RIH W/SPEAR MW: 0.0 FSW TAG FISH @ 9841' MD. ATTEMPT TO LATCH FISH W/OUT SUCCESS. POOH. MU 4.875" SPEAR AND RIH. LATCH FISH @ 9844'. POOH. FISH DRAGGING AND SWABBING. RECOVERED PACKER BODY. PACKER MANDREL STILL IN HOLE. TEST BOPS TO 5000 PSI. RIH W/4" SPEAR. DAILY:S27,500 CUM:$461,100 ETD:$461,'100 EFC:$1,173,000 RIH W/RTTS MW: 0.0 FSW RIH W/4" SPEAR. TAG FISH @ 10431' MD. ATTEMPT TO ENGAGE FISH, POOH. NO RECOVERY. RIH W/4" SPEAR W/LONGER EXTENSION. ENGAGE FISH @ 10442' [fiD. POOH, RECOVERED PKR MANDREL AND 4-1/2" TAILPIPE. MU 9-5/8" RTTS AND RIH. DAILY:S34,863 CUM:$495,963 ETD:S495,963 EFC:$1,173,000 LD 2-7/8" STINGER MW: 0.0 FSW RIH W/RTTS. SET RTTS @ 9815' MD. TEST 9-5/8" CASING TO 3000 PSI F/30 MIN. RELEASE RTTS, POOH. PU 50 JTS 2-7/8" TUBING AND RIH ON 3-1/2" DP. TAG FILL AT 10545' MD. SPOT AND SQZ 45 BBLS 12:10 HCL, 45 BBLS 12:3 HCL, & 2 BBLS 12% HCL FLUSH ACID INTO PERFS. FINAL INJ RATE = 1 BPM @ 1600 PSI. SPOT 15 BBLS ACID RESISTANT CEMENT ACROSS PERFS AND SQZ 1-1.5 BBLS CMT INTO PERFS @ 1800 PSI FINAL SQZ PRESS. POOH, LD 2-7/8" TUBING STINGER. DAILY:S80,867 CUM:$576,830 ETD:S576,830 EFC:$1,173,000 CIRCULATING MW: 0.0 FSW POOH, LD 2-7/8" TUBING STINGER. MU 8-1/2" BIT AND 9-5/8" CSG SCRPR AND RIH TO TOP OF 7" LINER @ 9845' MD. POOH. MU 6" BIT AND 7" CSG SCRPR AND RIH. TAG TOC@ 10118' MD. DRLD HARD CMT FROM 10118' TO 10200' MD. PUMP HEC SWEEP AND CIRCULATE HOLE. JWell no. AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil~'~nd Gas Company ,'~' "~-~'~ Daily Well History--in~e Inslruclions: Th;s form iS use~. during dritti~g or ';;orkover operations. If testing, coring, or perforating, show formation name in describina work performed. Number ail drill s',em tests sequentially. Attach Description of al! cores. Work performed by Producing Sect[on will be reported on 'qnterim'~ sheets until final complehon. Report official or representative tesf on ~'Final" form. !) Submit "Interim" sheets when filled oat but not less frequently than every 30 days, or (2) On Wednesday Ut the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field County or Parish IState ARCO ALASKA INC. I PRUDHOE BAY AK ~Lease or Unit I DS 12-29 Date and cleptb as of 8:00 a.m. 12/27/89 ( TD: 0 PB:10735 SUPV:ZR 12/28/89 ( TD: 0 PB:10735 SUPV:GTG 12/29/89 ( TD: 0 PB:10735 SUPV:GTG 12/30/89 ( TD: 0 PB:10735 SUPV:GTG Complete record for each day while drilling or workover in progress AUDI RIG 4 ,5) L6) BACK OUT 9-5/8" CASING MW: 0.0 FSW POOH. MU 7" EZSV CMT RTNR AND RIH. SET RTNR @ 10190' MD. TEST RTNR AND CSG TO 1500 PSI. POOH. DISPLACE TOP 200' OF 9-5/8" WITH DIESEL. PULL 9-5/8" PACKOFF. RIH W/MULTI-STRING CSG CUTTER. CUT 9-5/8" @ 79'. POOH. PULL 9-5/8" CSG. MU TRI-STATE CSG BACK-OFF TOOL. SET TOOL AND BACK-OUT 9-5/8" CSG CONNECTION @ 102'. BACKED OUT 3-1/4 TURNS. RELEASE BACK-OFF TOOL AND POOH. MU 9-5/8" CSG SPEAR ON 3-1/2" DP AND RIH. ENGAGE 9-5/8" STUB AND ATTEMPT TO FINISH BACKING OUT CONNECTION @ 102'. DAILY:S33,542 CUM:$643,714 ETD:S643,714 EFC:$1,173,000 CUTTING 13-3/8" CSG MW: 0.0 FSW ATTEMPT TO BACK OUT 9-5/8" CASING CONNECTION @ 102' MD. COULD NOT BACK OUT. LD SPEAR. RIH W/TRI-STATE BACK OFF TOOL. TOOL WOULD NOT SET PROPERLY. POOH, REDRESS TOOL. RIH AND BACK OFF SAME CONNECTION 3 MORE TURNS. POOH. RIH W/ SPEAR AND ENGAGE 9-5/8" STUB. BACK OFF CONNECTION @ 102' AND POOH. LD 9-5/8" STUB. RIH TO TOP OF 9-5/8" W/13-3/8" CSG SCRPR. POOH. RIH AND SET 13-3/8" RTTS AND STORM VALVE @ 42' MD. ND BOPS AND TBGHD. CUT OFF BRADENHEAD. TACK WELD 13-3/8" LANDING JOINT TO 13-3/8" }{ANGER AND BACK OUT 13-3/8" NANGER AND PUP JOINT. PU ONE FULL JOINT OF 13-3/8" J-55 BTC CSG AND SCREW INTO STUB. TORQUE CONNECTION TO 8500 FT-LBS. TEST CONNECTION TO 1000 PSI. PULL 150K# ON 13-3/8" AND SET EMERGENCY SLIPS. MAKE ROUGH CUT ON 13-3/8". DAILY:S29,101 CUM:$672,815 ETD:S672,815 EFC:$1,173,000 RIH W/6" MILL MW: 0.0 FSW CUT 13-3/8" CASING AND WELD ON NEW FMC GEN 4 BR~J)ENHEAD. TEST WELD TO 500 PSI INSTALL NEW FMC GEN 3 4-PORT TUBINGHEAD. NU BOPS AND TEST TO 5000 PSI. RIH AND RETRIEVE 13-3/8" RTTS. PU 3 JTS 9-5/8" MOD BTC CASING AND RIH. SCREW INTO 9-5/8" STUB @ 102'. PRESS TST 9-5/8" TO 3000 PSI. ND BOPS. SET SLIPS ON 9-5/8" CASING W/200K#. CUT OFF 9-5/8" AND DRESS STUB. INSTALL PACKOFF. NU TUBINGHEAD AND BOPS. TEST PACKOFF TO 3500 PSI. TEST BOPS TO 5000 PSI. TEST 9-5/8" CASING TO 3000 PSI. MU 6" MILL AND RIH. DAILY:S48,210 CUM:$721,025 ETD:S721,025 EFC:$1,173,000 MILLING EZSV MW: 0.0 FSW RIH W/6" MILL. TAG EZSV @ 10190' MD. MILL ON EZSV TO 10192'. POOH, LD MILL. MU 6" BIT AND RIH. TAG EZSV @ 10192' AND DRILL ON SAME. DAILY:S91,100 CUM:$812,125 ETD:S812,125 EFC:$1,173,000 IWell no. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 / ~/~ o Drilling Supt. AR3B-459-2-B Number all daily well history forms consecutively as hey are prepared for each well. Page no. ARCO Oii'~d Gas Company Daily Well History--Inter;- Inslruclions: Th~s form is ~se~ during drilling or v,'orkover operations. If testing, coring, or perforating, show formation name in describing work performed, NumOer a;! drill stem tests sequentially. Attach description o[ ali cores. Work performed by Producing Section will be reported on "Interim" sheets until final complehon Report official or representative test on "Final" form. I) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday ot !he week in which oil string is set. Submit weekly for workovers and foilowing setting of oil strin~ until completion. District County or Parish IState ARCO ALASKA INC. PRUDHOE BAY I AK Field Lease or UnitDS 12-29 Well no. Date and depth Complete record for each day while drilling or workover in progrese as of 8:00 a.m. AUDI RIG 4 12/31/89 ( TD: 0 PB:10735 SUPV:GTG 01/01/90 ( TD: 0 PB:10735 SUPV:GTG 01/02/90 ( TD: 0 PB:10735 SUPV:GTG POOH MW: 0.0 FSW DRILL EZSV AND CEMENT TO 10505' MD. PRESS TST SQZ TO 1500 PSI Y/30 MIN. DRILL CMT TO 10539'. WASH AND DRILL FILL TO 10728' MD. CIRCULATE HOLE CLEAN. TEST CASING TO 1500 PSI F/15 MIN. POOH. DAILY:S88,130 CUM:$900,255 ETD:S900,255 EFC:$1,173,000 RUN 5-1/2" COMPLETION MW: 0.0 FSW POOH. MU 8-1/2" MILL AND 9-5/8" CSG SCRPR AND RIH TO TOP OF 7" LINER @ 9844'. DISPLACE FLUID TO INHIBITED SEAWATER. POOH, LD DP. MU BAKER SB-3A LOWER SEALBORE PERM3%NENT PKR ON 5-1/2" 17~ L-80 BTC MOD IPC TUBING W/ 4-1/2" TAILPIPE AND RIH. CONNECT 3/8" CHEM INJ LINE TO CIM AND TEST SAME TO 5000 PSI. CRUSH 3/8" LINE IN ROTARY. RE-INSTALL AND TEST TO 5000 PSI. RIH W/5-1/2" COMPLETION TUBING. DAILY:S34,850 CUM:$935,105 ETD:S935,105 EFC:$1,173,000 TESTING 5-1/2" TUBING MW: 0.0 FSW RIH W/5-1/2" COMPLETION. MU FMC TUBING'HANGER. LAND HANGER. PRESS TBG TO 3000 PSI TO SET PKR @ 9792' MD. BLEED PRESS TO 2500 PSI AND PU TBG TO 232K~ TO SHEAR PLUG IN PKR TAILPIPE. BLEED PRESS, LAND TUBING. PRESS TST TUBING TO 3000 PSI. (OTIS 'HRQ' SSSV @ 2223', BAKER 'SB-3A' PKR @ 9798', & TT @ 9921'.) DAILY:S358,636 CUM:$1,293,741 ETD:S1,293,741 EFC:$1,173,000 The above is correct For form preparation and distribution see Procedures Manual Section 10, Orilling, Pages 86 and 87 Date ITitle //~,~ ,/~'~ Drilling Supt. .: AR3B-459-2-8 INumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO ~and Gas Company Daily Well History-Final Repo Inslruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or wail is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefimte or appreciable length of time. On workovers when an official test is not re*3uired upon complelion, report completion and representative test da~a in blocks provided. The "Final Reporl" form may be used for reporting the ant{re operation ff space is available. District ARCO ~JkSKA INC. Field Auth. or W.O. no. AS3081 Operator ARCO Spudded or W.O. begun ACCEPT Dale and depth as of 8:00 a.m. Oounty or "~D.OE BAY Lease or U~D,r,: 28330 m t e WORKOI/'ER 01/03/90 (2)) TD: 0 PB:10735 SUPV:GTG ADI: 50-029-21087 A-R-C°-W'~i.0000 Date 12/14/89 Complete record for each day ~po~ed AUDI RIG 4 I Accounting cost center code State ~ DS 12-21welln°' I otal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well our 1130 IPrior status if a W.O. I RIG RELEASED MW: 8.5 FSW TEST 9-5/8" X 5-1/2" ANNULUS TO 3000 PSI F/30 MIN. BLEED PRESS, LD LNDNG JT. SET BPV, ND BOP. NU 5-1/2" TREE. PULL BPV, SET TEST PLUG. TEST TREE AND HNGR TO 5000 PSI. PULL TEST PLUG. FREEZE PROTECT TOP 3111' OF TBG AND ANN W/ DIESEL THRU CIRC VALVE. SHEAR PLUG IN PKR TAILPIPE W/3400 PSI TBG PRESS. SET BPV. PULL BPV. RD, RELEASE RIG @ 1800 }iRS, 1/2/90. DAILY:S65,587 C0M:$1,359,328 ETD:S1,359,328 EFC:$1,173,000 Old TO New TD Released rig Date Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Off cial reservo r name{s) Potential test data PB Depth K nd of rig Well no. Date Reservoir Producing Inter.,al Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable Effective date corrected The above is correct Signature Date Title For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supt. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Page no. Dlvi~Jon of AtlanticRichfieldCompany ARC'O ALASKA, P,. O, BOX i ANCHORAC.'-E: ALAS'KA 995i ,.') DATE' ~ ~-~ 8-9~ ....... Ek,.,[: ARCO CASED HI]LE F'~NAL£' ..,-~-~2 i.-°-°8-8~'.. , MZ iNJECTION F'ROFILE RIIN_ ~, 5-25 ~ 2-.3g,-87 CET RUN ~ , ~-"-:' 5 i -8.-9£) COLLAR/F'ERF RUN i 7-9 ~2-27-89 F'RODUCTION F'ROFILE F.:ijN 'i, ,-"- ~, 8 i .--'-'-2-'-;--8 :.-."" ,'Y. r:' I Ni'~.I::'F;~/TE:i"'~F:' .... CAt:' RUN ~ , ~ '; -t 5 i ")-')7-R9 No'r>?.~-/TEHF' F.'.UN i i'"- ~-' -7-9,:3 . , ~ 2:,' i CO[_LAR/F'ERF RUN i i '.~-.'";-"";,_ ....._. i ..'~-"--'o-°o:, ,.,, F'F,'ODUCTZC~N F'ROF:.[LE ,,~'ijN. , i , i 5.-'-i i i 2-i 8-89 COLLAR RUN i , i 5-i :5 ' i -9-96' COL. I_Ai;.'./F'ERI-- RUN i , iS-2i i2-..]i-89 PRODUCTION PROFILE RUN i, ,,-.-: i2 ..S6~-89 F'RODUCT_'[ON F'ROFIL. E/F'ZTS' ~'UN ''~ .; ', PI_EASE ~IGN~ ANI) RETURN THE ATTACHED CC1F'Y AS F<E~,EIF'T' 'R- OF DATA HAVE A NICE DAY! SALLY HOFFECKER ATO- i 529 F.:ECEIVED BY _~~~ RECEIVED JAN !S90 'rRANs::APPROVE~' I.,~,.~-~-, Alaska 0il & Gas Cons. Com~o~ _.s, ~ Anch0~ge DISTRIBUTION -" CENTRAL FILES ~-'"'PHIl_LIPS '1' ~" CHEVRON F'B WELL FILES D & M R & D ~- EXTENSION EXF'LORATION .,-~ BF'X ~' EXXON ..-~' STATE Or---, ALASKA 'il' MARATHON :.": TEXACO ~' MOBIl._ .'r C A r-i C 0 s C i--i;. ': i-I i'-i F;.'..~' S: C',u, ':.q i- L A C A i"i C 0 C A M C ATi_A£ CAMCO U ~'-:,;m Inspector RECEIVED STATE; 05 ~,s~ OZL & cAS CO.~s~:nv/,~:o:~ ~.._-.:,ss~o~ DEC I ~,O,~.E, Inspection ~e~,~r: ~ Contractor ~ud S3stems Tr~p Tank Pit Gauge Flor Honitor T_/d ._ R i.~~' Location, General~6~ I~elt Sign General Housekeeping6~_ Rig ~ ..... aeserve Pi.~ ..... /~ P~ Visual Audio ~OPE Stack Annular Preventer Pipe Ram~ ~lind Rams Choke Line Valves ~,C.~, Val~e Kill Line Valves Check Valve Alaska Oil & Gas Cons.. _ ~ ~ ~c~o~e Test Pressure ................. 25;00 J--)- 0 0 0 --. ,,~"00 0 ~0oo ACCUI'~LATOR SYSTEH Full Charge Pressure.~.JdO p~ig Pressure After Closure tq ~o pst~ Pump incr, clos, pres, 200 pst~ Full Charge Pressure A~alned:. -. Contgols: Haster ..................... Remote / Blinds swit:h covez ~e~t Pressure Test Pres~ur~.._~5-~ __ . Test Pressure Test Pressure Kelly and Floor Safety Valves -- Upper Xell~ - ~ Lo,er Kelly , / ~all Type Inside BOP /' Choke Manifold No. Valves ...... No. flanges ~7..~ Adjustable Chokes ........... .. Tes~ Time ..... ;:--. .............. Test Results: failures_ --~ .... Repair or Replacement of failed equipment to be made within Commission office notified. min~5 ~ec. mia 10 sec. .....--- deys and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor ARCO ALASKA, F'.O. BOX iO~60 ANCHORAGE, ALASKA 99~ J O DATE' i2-5-89 REFERENCE' ARCO CASED HOLE FINALS 2-2i ii-i8-89 PERF RECORD 2-2 i i i -24-89 COLLAR/F'ERF 4-4 i i -i 6-89 COLLAR/F'ERF 5-t9 ii-i4-89 COLI_AR (F'KR SET REC) 9-°°...-. i i-°'?-89.. ~ COLLAR/F'ERF ii-28 ii-ii'-89 COHF'LETZON RECORD i., .9 ii i7-89 COLLAR/PERF i 3-4 i i -2L~-89 COLLAR/PERF i 5-i i i-i 9-89 METi' t 5-i 3 i i -t 6-89 COLLAR i 5-i 3 i i.-22-89 VERTILOG i 8-24 i t -i 3-89 COLLAR/F'ERF PI_EASE $IGN~RETURN i~TTACH~ED ~CEIF'T. RECEIVED BY SAI-.LY HOFF'ECKER OEO ' ~ RUN RUN RUN RUN RUN RUN i, RUN t, RUN t, RUN i, RUN i, RUN i, RUN i, OF DATA. SCH Ai'LA~' Al-LAt''.> AT'LAS ATL. A£,' ':'r: ,~ ,.,H A'f'LA3~ ATLAS £'CH A'rLA£' A'¥LA~' Al'LAS DISTRIBUTION CENTRAL FILES ~ ~ PHILLIPS CHEVRON F'B WELL FILES D&M R~D EXTENSION EXPLORATION ~ ~ BPX EXXON ~ ~ STATE OF ALASKA MARATHON ~ TEXACO MOBIL' THE CORRECTED AF'I~ FOR 2 ..-i IS 5(~-0'29-2078t STATE OF ALASKA A-r.,.-,~KA OIL AND GAS CONSERVATION COMN..._~iON APPLICATION FOR SUNDRY APPROVA l,r, A [ Operation shutdown ~ Re-enter suspended well __ Plugging ~ Time extension __ Stimulate Pull tubing ~ Variance __ Pedorate ~ Other 1. ~ype 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 4. Location of well at surface 1328' FSL, 104' FWL, Sec.17, T10N, R15E, UN At top of productive interval 272' FNL, 2313' FWL, Sec.17, T10N, R15E, UN At effective depth 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 71 ' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 12-29 9. Permit number 84-32 10. APl number 50-- 029-21087 11. Field/Pool Prudhoe Bay 0il Pool At total depth 88' FNL, 2465' FWL, Sec.17, TION, R15E, UM None RECEIVED None 2 7 1989 A~aska Oil & Gas Cons, Commission 12. Present well condition summary Total depth: measured 10778'MD feet Plugs(measured) true vertical 9222 'TVD feet 10735 'MD Effective depth: measured 9184 ' TVD feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Arlchoiral~j~vertical depth Structural 80 ' 20" 1850 sx Pol eset 80 'MD 80 'TVD Conductor 2517' 13-3/8" 1700 sx PF 'E' & 2517'MD 2517'TVD Surface 400 sx PF'C' Intermediate 10162' 9-5/8" 500 sx 'G' & 10162'MD 8679'TVD Production 300 sx PF 'C' Liner 926' 7" 320 sx 'G ' 9852 ' -10778 'MD 8397 '-9221 'TVD Perforation depth: measured 10370-10426'; 10440-10450 '; 10458-10478 '; 10492-10502 '; true vertical 8867-8917 '; 8929-8938'; 8945-8962'; 8975-8983 '; Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9780' MD; 4-1/2", 12.6#, N-80, PCT Tail ~ 9893'MD Packers and SSSV (type and measured depth~aker FHL Packer @ 9790'MD; Camco Ba1-0 5SSV (~ 2190'MD Description summary of proposal ,/ Detailed operations program ~ BOP sketch 13. Attachments 14. Estimated date for commencing operation 115. Status of well classification as: Start Date: August 15, 1989 16. If proposal was verbally approved Oil ~__ Gas __ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Regional Drilling Engr. FOR COMMISSION USE ONLY feet Plug integrity __ BOP Test ~ Location clearance __ ,~/-¢ Mechanical integrity Test ~ Subsequent form required 10- Conditions of approval: Notify Commission so representative may witness ORIGINAL SIGNED BY LONNIE C. SMITH I A PP rova' N °.p~_~--'-"~ ~.~ Approved by order of the Commissioner t~OO /CAI, Form 10-403 Rev 06/15/88 Approved 009¥ Returned Commissioner SUBMIT IN TRIPLICATE PRUDHOE BAY DS 12-29 PROPOSED WORKOVER PROCEDURE SUMMARY OBJECTIVE: REPAIR A FAILED PACKER AND PARTED TUBING BY PULLING THE 5 1/2" TBG AND 9 5/8" PACKER. ADDITIONALLY THE 13 3/8" LEAKY WELLHEAD WILL BE REPLACED AND A GAS-SHUT-OFF CEMENT SQUEEZE WILL BE PERFORMED ON THE EXISTING PERFS. A NEW 9 5/8" PKR WITH 5 1/2" TBG WITH GLM'S AND A TREATER STRING WILL THEN BE RUN. THE NEW PERFS WILL BE SHOT THROUGH TBG AFTER THE RIG IS RELEASED. 1. RU SL, PULL SSSV, PULL EQ DUMMY FROM 9743'. RD SL. SET BPV. MIRU NORDIC RIG #1. 2. PULL BPV. CIRC TUBING/CASING WITH 8.5 PPG SEAWATER. SET BPV. ND TREE, NU BOP'S. PULL BPV. 3, ENGAGE TBG HGR, POOH, LD 5 1/Z' TBG HGR. INSPECT'I'BG HGR FOR FAILURE AND SELECT PROPER FISHING TOOL 4. PU DP, RIH WITH FISHING TOOL. 5. FISH AND RECOVER PARTED TUBING. POOH LD TBG. 5. FISH AND RECOVER FAILED FHL PACKER. POOH LD PACKER AND TAILPIPE. 8. RU WL, SET 9 5/8" CEMENT RETAINER AT 9840', POOH LOG GR ACROSS UPPER 200' OF CSG. TEST RETAINER TO 3000 PSI. 7. RIH W/DP AND STINGER, ACIDIZE EXISTING PERFORATIONS, OVERFLUSH PERFS, CEMENT SQUEEZE PERFS, POOH DISPLACE TOP 200' OF CSG TO DIESEL. 8. CUT 9 5/8" CSG WITH CSG CU'FI'ER JUST BELOW HANGER. 9. SPEAR AND RECOVER 9 5/8" HGR. 10. RIH BACK-OFF 9 5/8" CASING AT 100'. 11. SPEAR AND RECOVER 9 5/8" CASING. 12. CIRC OUT ARCTIC PACK, INSTALL 13 3/8" RTTS W/STORM VALVE. 13. ND BOPE, ND SPOOLS, SLOT 20" CASING JUST BELOW HANGER AND REMOVE. 14. BACK-OFF 13 3/8" CASING JUST BELOW HANGER. 15. SCREW NEW JT OF K-55 13 3/8" CASING. 16. WELD ON NEW 20" CASING SECTION, WELD ON NEW 13 3/8" FMC GEN 'IV STARTING HEAD, NU SPOOLS, NU BOPE AND TEST. 14. RETRIEVE 13 3/8" TEST PACKER AND STORM VALVE. 15. SCREW IN 9 5/8" CSG, TEST 9 5/8" CSG TO 3000 PSI, LAND, ND BOPE AND CUT CSG, NU BOPE AND TEST. 16. RIH W/8 1/2" MILL, CLEAN OUT TO 9852' TOL. CIRC CSG CLEAN. 17. RIH W/6" BIT, CLEAN OUT TO 10735' PBTD, CIRC LINER CLEAN. TEST GSO SQ PERFS TO 1000 PSI. REC, EiVED 2 7 Alaska Oil & Gas Cons. Commission Anchorage 18.. SET 9 5/8" PROD PKR ON DP. POOH LDDP. 19. RUN 5 1/2" TBG STRING WITH GLM'S AND TREATER STRING. 20. DISPLACE WELL W/INHIB SEAWATER + FREEZE PROTECT. 21. LAND TBG, TEST TBG, TEST CSG. 22. SET BPV, ND BOP'S, NU + TEST TREE. RELEASE RIG. 23. PERFORATE FOLLOWING DEPTHS, AT 4 JSPF WITH 3 3/8" THRU TBG GUNS: MF._ASURED DEPTH TVD 10404-10410 8898-8903 10464-10482 8950-8966 10492-10502 8974-8983 EST BHP= 3658 PSI AT 8800' TVD WORKOVER FLUID= 8.5 PPG. SR. DRILLING ENGINEER 06/09/89 NORDIC v RIG #1 13-5/8", 5000 PSI BOP STACK ANNULAR PREVENTER 6 TUBIN6 HEAD 1. 13-3/8' CASING HEAD 2. g-5/8" CASING HEAD 3. 5000 PSI TUBING HEAD 4. 13-5/8" - 5000 PSI BLIND RAMS 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 13-5/8' - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST __ 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS ;5000 PSi WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND P, ECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. PECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLDWI'TH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD--DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAHS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. O. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTI~EAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REHAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEI"I TO ZERO PSi. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOP, 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORHATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO ORILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. ARCO ALASKA, INC. F'.O. BOX i00360 ANCHORAGE, ALASKA 995i0 DATE' 5-i0-89 REFERENCE' ARCO PRESSURE DATA i -.4 4 - 24 - 89 i -9 4-S-89 i - t 6 S-'~o-89~., i -26 S-'~9-89~. o-t ~ 4-~S-89 5-i i 4-i-89 S-i 6 4-~:-89 6-i6 S-Si .-89 9- i i 3-'~'~-8~~.= , i~-'~ 4-2i-89 ~ ~ .- i '2-i (D 4-2i -89 i 2-t 3 3-i 6-89 i 2-28 3-i 7-89 } 2-29 ~-i 6-89 i2-29 4-23-89 t 3-8 4-22-89 i 3-23A 4-23-89 i3-26 4-26-89 i3-33 4-26-89 -t 5-9 3-3i -89 i 8-2~b 4-3-89 BHF'--$TATIC GRADIENT BHF'--STATIC GRADIENT BHF'--STATIC GRADIENT BHF'--STATIC GRADIENT BHF'--$TATIC GRAD]:ENT BHP--STATIC GRADIENT BHF'--$TATIC GRADIENT BHF'--$TATIC GRADIENF BHF'--FLOWING GRADIENT BHF'--STATIC GRADIENT BHP--FLOWING GRADIENT BHP--F'LOWZNG GRADIENT' BHF'--FLOWING GRADIENT BHP--$'FATIC GRADIENT BHP--$TAi'IC GRADIENT BHP--F'LOWING GRADIENT BHF'--FLOWING GRADIENT BHF'--FLOWZNG GRADIENT BHP--FLOWING GRADIENT BHP--$TA'FIC GRADIENT BHP--STAI'IC GRADIENT PLEASE SIGN AND RETURN THE AI'TACHED COPY AS CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO RECEIPT OF DATA~ RECEIVED BY HAVE A NICE DAY! SALLY HOF'FECKER ATO-i529 APPROVED ~_ TRAN$~ 89 DISTRIBUTION CENTRAL F~LES ~ ~ PHILLIPS CHEVRON PB WELL FILES D&M ~ ~ R&D EXTENSION EXF'LORATION ~ ~ BPX EXXON ~ STATE OF ALASKA MARATHON ~ TEXACO ARCO ALASKA, INC. F'.O. BOX ANCHORAGE, ALASKA 995t8 DATE' 5-9-89 REFERENCE' ARCO CASED HOLE FINAL£ t-8 4-t6-89 INJECTION F'ROFILE RUN t-24 4-8-89 PRODUCTION PROFILE RUN 2-t 2 4-2J-89 TEMP , RUN 2-'i4 4-i 5-89 PRODUCTION PROFILE RUN 2-t7 2-t 7-89 SPINNER/TEMP/FLUID DEN$/GR RUN 2-2S 4-tS-89 PRODUCTION PROFILE RUN 4-7 4-t 6-89 F'RODUCTION F'ROFILE RUN 4-~._, 4-t 8-89 ~'PINNER/TEMF' RUN 7-25 4-t8-89 ' LEAK DETECTION RUN 9-t 4-tS-89 PRODUCTION PROFILE RUN tt-S 4-24-89 LEAK DETECTION RUN tt-t~] 4-t 4-89 LEAK DEFECTION RUN t1-t6 4-i .-2-89 PRODUCTION F'ROFILE RUN t2-7A 4-i 9-89. F'RODUCTION LOGGING SVC~'· RUN t2-t0 4-2t -89 GA~' LIFT SURVEY RUN i 2-29 4-2~-89 TEt4F' RUN J3-J 4-t 4-89 LEAK DETECTION RUN t~-8 4-22-89 PRODUCTION PROFILE RUN t3-23A 4-2.~-89 MI INJECTION F'ROFILE RUN ~4-2 4-t 9-89 PRODUCTION PROFILE RUN t 4-~ 8 4-6-89 F'IT$ RUN t6-tt 4-24-89 LEAK DETECTION RUN. t7-6 4-t9-89 INJECTION F'ROFILE/TEMF' KUN. t7-8 4-1'?-89 MULTI-RATE INJECTION PROFILE RUN t8-.~ 4-2i-89 F'RODUCTION LOGGING SVC~'~ RUN t8-7 4-2t-89 PRODUCTION LOGGING SVC~ RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA RECEIVED BY' .~I_._F-~" E_"2.~Z '%-'~ ~ DAY HAVE A NICE~ ,, ~ ~, .-.-.. 0 _& · ~ -.~ · D:Z;~R l BUI'I ON CENTRAL FILE~ ~ ~ PHILLIPS CHEVRON $ MOBIL EXTENSION EXPLORATION ~ BPX EXXON ~ ~ STATE OF MARATHON .~ TEXACO ALASKA 5' 5' .,..' o. 5" 5' 5' 5' i : &5~ 5' 5' 5" 5' CAMCO CAMCO CAM(;() CAMCO CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO A-I'I_A~ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMcO A'¥LA~ A]'LA~ * THE CORRECT AF'I$ FOR 2-12 I$ 5¢~-'FJ29-20':277· ** THE CORRECT API-~ FOR t6-tl I$ 5~'J-e29-2f~516. ARCO Alaska, Inc.. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 26, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-29 Permit No. 84-32 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/3LB/jp Attachment cc: Standard Alaska Production Company 3. Gruber, AT0-1478 Pi(DS 12-29)W1-3 WELLS3/39 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldOompany AR3B--6132-C ARCO ALASKA, INC. F'.O, BOX 100360 ANCHORAGE, ALASKA DATE: 3-27-89 REFERENCE' ARCO CASED HOLE FINALS 2-7 3.-2-89 3'- i t 3-3.-89 5-~0 3-~ '7-89 5-~ ? 3-4-89 9- ~ I 3-5-89 ~ ~-~ t 3-~ 7-89 ~ t-t 3 3-6-89 J J-~ 6 3-~ 4-89 ~ 2-29 3-~ 6-89 F'WDWt-i 3-3-89 F'WDW3- t 3.-4-89 PITS INJECTION PROFILE PITS F'RODUCTION PROFILE TEMP SURVEY TEMP SURVEY PRODUCTION F'ROFILE TEMP PITS TEMP SURVEY STATIC TEMP SURVEY RUN i, RUN i, RUN i, 5' RUN 1, 5' RUN t, 2'&5' RUN t, RUN i, 5' RUN i, RUNS i-6, RUN l, 2' RUN i, 2' PLEASE £IGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. CAMCO CAMCO OTIS CAMCO CAMCO OTIS CAMCO OTIS OTIS CAMCO CAMCO RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 TRAMS ~891/4~ APF'ROVED 2~.___ DISTRIBUTION CENTRAL FILES CHEVRON D & H EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES SAF'C S'I'ATE OF ALASKA TEXACO ** THE CORRECTED API~ FOR THIS LOG IS STATE OF ALASKA OIL AND GAS CONSERVATION COMM t~...~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _.. Alter casing __ Repair well Change approved program __ Operation sh~t0own __ Re-enter suspended well ~ Plugging ~ Time extension __ Stimulate ~ / Pull tubing __ Variance __ Perforate __ Other ..Y_ 2. Name of Operator 3. Address Box 100360~ 4. Location of well at surface A329' FSL, 105' FWL Sec. t top of productive interval ' 72' FNL, 2257' FWL, Sec. At effective depth At total depth 241' FSL, 2429' FWL, Sec. Anchorace, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 17, TiON, R15E, UM 34, T10N, R15E, UM 8, T10N, R15E, UM 6. Datumelevation(DForKB) 71' RKB Z UnitorPropedyname Prudhoe Bay Unit 8. Well number DS 12-29 feet 9. Permitnumber 84-32 10. APInumber 50-- 029-21087 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10778 feet Plugs (measured) 9222 feet Effective depth: measured 10735 ~ Junk (measured) truevedical 9184 ~et Casing ~ngth Size Cemented Measured depth Surface 80' 20" 1850 sx Poleset Intermediate 2446' 13-3/8" 1700 sx Perm 'E' & 400 sx PF'C' Production 10091' 9-5/8" 500 sx C1 'G' & 300 sx PF'C' Liner 926' 7" 320 sx C1 'G' ~ueve~icaldepth 80' 80' 2517' 2517' 10162' 8679' 10778' 9221' Perforationdepth: measured 10370-10426'; 10440-10450'; 10458-10478'; 10492-10502' trueve~ical 8868-8918'; 8930-8939'; 8946-8963'; 8975-8984' ~bing(size, gmde, and measureddepth) 5½", 17#, L-80, PCT @ 9780' MD; 4½", 12.6#, N-80, PCT tail PackersandSSSV(typeand meas~reddepth) Baker FHL Packer @ 9790' MD; Camco Bal-0 SSSV @ 2190' MD REE EIVED 9 8 9 3' ~ ,0il & 6as Cons, "~ ~ch0rage ' 13. Attachments Description summary of proposal v/ Detailed operations program __ BOP sketch _~' 14. Estimated date for commencing operation ~ 15. Status of well classification as: October 1988 16. If proposal was verbally approved Oil __ Name of approver Date approved Service 17. I hereby c2rtify that the foregoing is true and oorrect to the best of my knowledge. Signed ,~Z~'J"~~Z~ T~eOperations Engineering Manager FOR COMMISSION USE ONLY Gas __ Suspended __ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical IntegrityTest __ Subsequent form required 10- "~ o, qe6 OoP~ ~p~r d ORIGINAL SIGNED BY ~,~~ Approved by order of the Commissioner LONNIE C. SMITH Commissioner Form 10-403 Rev 06/15/88 WELLS3/39 J. L. Brady, 263-4245 I Approval No. ~_. ,,..~ ~' SUBMIT IN TRIPLICATE DS 12-29 Coiled Tubing Unit Cement Squeeze Procedure 1. Surge the well with the slickline surge tool set in the tubing tail. Make a slickline tag run and do a fill cleanout if needed. 2. RIH with CT.and wash the perforations with full strength mud acid. Flow well to produce out all the acid. 3. RIH with CT. Fluid pack the tubing with filtered water. 4. Pump 30 bbls of cement followed by 2 bbls of water and 80 bbls of contaminant. Hold 1500 psi surface squeeze pressure for 60 minutes. Squeeze off the following perforations: Zone Perforations SPF 4 10370'-10426' FSD 4 10440'- 10450 FSD 4 10458'-10478' FSD 4 10492'-10502' FSD 5. Jet or reverse out the 6. Perforate as follows: Zone contaminated cement. Perforations SPF 4 10404'-10410' LSD 4 10464'-10482' FSD 4 10492'-10502' FSD (Ref.: BHCS 4-13-84) (Ref.: BHCS 4-13-84) Other Well Information: Current status: On production. Expected static bottomhole pressure: 3750 psi. @ 8800' SS Expected fluid in wellbore at reperforation: seawater. 6 5 4 3 2 C01L£D TUBINg UNIT BOP EOU ! PHENT 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANG£1 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" STUFFING BOX HIRELINE BOP EOUIPMENT 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRELINE RAUtS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF A~,l]..rl AI..~.s'I,,'~: l~i',Jc-.. ~N.P, Nfllq'A(,E... AI...A,.gKA 99~'i ,:~ DATE' RF. FERF.-.~KICE: ARCO CA..gED 14OI.E F];NAI... ~2-tG 6-27.-98 F'I T,.~ RI.IN ¢1 5- t 7 7-4-8,9 CNI... RI. IN ~.-3,._ 6- TEMPER'TllRE/RAMMA RAY O'!IN ,,,. .............. ,~lli 2-i & ,S-2,.R.-8.P., F"RODI!CT'[ON F'R'.R.I-"T.I...E I;,'ll~.J ~i2-..-'R..9 A-2.6.-88 PR'O.!}UCTION F'ROFII IT/GAMMA RAY Ri. IN ....... & t :~- t ,o., ,.A';~4-RR GAMMA R'AY/.¢..Ri.. L A l-l' R! lI, J 1t 4-6 A-°~-...q.R fTnl...l..AR I...OR RtJN ·. . .i ..-....! ............. 6 - .,,. 6 - 88 F' 'r T ~ R U N ~l 14-6. "~ ..... F~E ,~.T. GN AND RETURN THE ATTACHEf.) COPY A,~ RECEIPT OF DATA... RECEIVED BY HAVE A NI!.';E DAY! F' .F. G g.,'r; BENNETT ATO--i 5;29 TRANb] ~884W. 4 APPROVED .D 1; Y.'¥R ]' B! .IT I ON CAM~R CAMRO CAMCO CAMCO CAMCO ~ CENTRAl... F .'Il I ..E,':-;' ~- CHEVRKIN K X T E W:F.,' 'r. f'lN F'/P!..ORAT T ON EXXOt'~ MAI~'ATI4.0N :.":. MOBIl... ARCO ALaska, Inc. Anchorage° ALaska' DATE: June t? ,t986 REFERENCE: 5-4' 5-tt. t 2-29- ARCO Magnetic Tapes w/Listing 5-3-86 CN/CN$ ~30726t 5-3-86 CH/CN$ ~363685 5-5-86 CH/CN£ ~363687 GeaT Gear Gear Please $ig~ and return the attached copy as receipt of data. Received By HAVE A NICE DAY! Linda Hu[ce ATO-t52?F TRAN$ ~86372 DISTRIBUTION ~ Phi LLipz Centra L F i Le~ Y Chevron F'B We L L F i Les D& M R&D Extension ExpLoration ~ Sohio · !~ · Exxon . -State of ALaska Marathon Texaco Mob i l ARCO ALaska, Inc. P.O. Box 100360 Anchorage, ALaska DATE: June t8 ,t986 REFERENCE: ARCO Cased HoLe Final 5-4 5-3-86 CH/CN[og Run I 5" 5-tt 5-3-86 CH/CNLog Run 1 5' 12-29 5-5-86 CH/CNLog Run 1 5' Gear Gear Gear PLease sign and refurn ~he a~ached copy as receip$ of da~a. Received By_ HAVE A NICE DAY! Linda Hulce AT0-t529 TRAN$ ~8637i DISTRIBUTION CentraL Fi Les Chevron D & M ExTension Exploration Ex xon Marathon Mob i l .,."' Phillips F'~ Well Fi les R& D '~- $oh i o - $~a~e of Alaska ~ Texaro ARCO A~aska, Inc· F'. O· Box t A~chorage, A£aska 995t0 DATE' March REFERENCE' l~, 4986 ARCO Cased Hole Fi~a[ DS 9-20 ~-°~-86~ Spimner 5" DS 9-22 i -23-86 Sp inner/Inj. 5 · ~D$ 9-24 ti-i-85 ACBL/VDL/$ig/GR Run '~DS 9-27 t~-3-85 Prod. Logging Svc· Run I 5" ~D$ 9-27 ~-5-86 GR/Spinoer '~DS 9-28 J-3-86 GR/Spin~er 5" ~ DS 9-29 J2-t3-85 F'DK J~8 Run ~DS 9-36 ~-2-85 ACBL/VDL/Sig/GR Ru~ J 5' ~DS JJ-J2 J-9-86 CFS Run ~DS ~2-29 tJ-38-84 CCL/Perf Record Ru*~ ~ 5' Otis Otis DA DA Otis O¢is DA DA Go $ch PLease sig~l a~d re~urn the a~kached copy as receip~ of da~a· Received By DA HAVE A .NICE Ir~.~a Car[in ATO-~ 429F ,~ TRANS ~86~97 DISTRIBUTION F'hi [lips F'B We[[ Fi Les R & D $oh i o State' Of Alaska Texaco ARCO Alaska, Inc P.O. Box t00360 Anchorage, Alaska 995~0 DATE: March REFERENCE: ARCO Cased Hole Fina[ DS 9-20 DS 9-22 ~D$ 9-24 ""~-D$ 9-27 '"'~ DS 9-27 ~DS 9-28 '~' DS 9-29 9-s6 ~DS ti-J2 ~DS t~-~9 -22-86 Sp inner -23-86 Sp i nner/Inj. t-t-85 ACBL/VDL/S i g/GR t-3-85 F'rod· Logging Svc· -5-86 GR/Sp inner -3-86 GR/Sp inner .-~-t3-85 F'DK t~ i -2-8~ ACBL/VDL/~ i g/GR -~-86 CF~ t-3G-84 CCL/Perf Record Run Run t Run I Run J Run J i i i i i i i i i i Otis Otis DA DA Otis Otis DA DA $ch PLease sign and return the at~ached copy as receipt Received By DA HAVE A NICE Irt,~a CarLin .. ........... ATO-t429F -. ......... TRAN$ ~86197 of data. DISTRIBUTION Central Fi [es Chevron D& M Extension Exp [orat ion Exxon Marathon Mob i ~ ~ Phi [lips F'B Well Fi les R & D ~ Soh i o · ~- ~-:-"' $'t'a te 76f: A-t~a~k a ¥:: _-- :::_: ~ Texaco ARCO Alaska, inc. ~ t Post Office Box 100360 Anchorage. Alaska 99510 Telelonone 907 276 1215 Date: June 11, 1985 Reference- ARCO CH Finals' ~ 1-18~ Collar Log .- ~2-13/. Neutron GR ---3-9 ~ Neutron GR Gamma Ray .... "- 6-2 / CET '~---6~i0 / Neutron GR -- 6-24/.Neutron GR ~ 7-26 ,//Neutron GR '~'~12-21/~ Spinner '"'12-22/. Collar Log .~"-12-22 / Spinner '~12-25 /Temp. Log ,' ~---12-25 / Spinner · -~ 12-28 /Spinner ~ 12-29/Spinner 14-15 / Neutron GR .~' 5-11-85 14-35/. Neutron GR 5-11-85 ~---15-9 / CBL 11-8-84 5-20-85 Run I 5" Camco 5-12-85 I 5" DA 5-15-85 2 5" DA 5-17-85 I 5" DA 3-7 -85 I 5" Sch 5-10-85 1 5" DA 5-18-85 1 5" DA 5-16-85 I 5" DA 5-15/16-85 1 5" Camco 5-20-85 1 5" Camco 5-21-85 1 5" Camco 5-22-85 I 5" Camco 5-18-85 1 5" Camco 5-17/18-85 1 5" Camco 5-16/17-85 ~ 5" : Camco 1 5" DA 1 5" DA I 5" Sch Please sign as reciept of data. Received by Pam Lambert ATO 1429C Trans 148 Chevron .. D&M Expl., Services E.xt. ' Exp lora~ ion Exxon- Marathon Mobil Fh~-tl'ips PB Well Files R & D Sohio S=aZe~of Ataskw ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Te~ept~one 907 276 1215 Date: Jun 5, 1985 Reference' ARCO Pressure Data / 1-8 ' PFO 5-15-85 Camco / 1-18 Static Gradient 5-20-85 Camco 5-2 ~/Static Gradient 5-16-85 Camco 12-21~lowing Gradient 5-15/16-85 Camco 12-22 '~lowing Gradient 5-19/20-85 Camco 12-27 ~PFO 4-17/18-85 Camco 12-28~Flowing Gradient 5-17/18-85 Camco 12-29 ~Flowing Gradient 5-16/17-85 Camco Pam Lambert ;' ' · ' '~"- ::3 ATO 1429C Trans 138 Chevron D & M '~hillip8 Expl. Services PB Well Files Ext. Exploration ~'& D Exxon Sohio Ma ra thon ~'~i'~[!-o f A1 aska Mo b i 1 ~xaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: May 29, 1985 Reference: ARCO Pressure Data 12-21 PBU/Spin 5-15-85 Camco 12-22 PBU 5-19-85 Camco 12-28 PBU/Spin 5.17/18-85 Camco 12-29 PBU/Spin 5-16/17-85 Camco Please sign as receipt of~d~ta. ~. Received BY ~.!~ska 0il Pam Lambert ATO 1429C '-'~' Trans 125 Chevron D& M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: Apr il 23, 1985 Reference: ARCO CH Finals / 3-8~ Perf Log 1-9-85 Run 1 5" Sch 6-5 ~ Collar Log 1-12-85 1 5" Sch 6-1lb/ Collar/Perf 12-25-84 1 5" Sch 11-12/TDT 3-20-85 1 5" Sch 12-23t/Spinner/Temp 4-8-85 1 5" Camco 12-25"Collar/Perf 12-7-84 1 5" Sch 12-26/Collar/Perf 12-2-84 1 5" Sch 12-29~/ Collar/Perf 12-10-84 1 5" Sch 14-35~Collar/Perf 3-33-85 1 5" GO 17-10`/S~pinner 4-4-85 1 5" GO sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 081 Chevron Mobil E & P D & M Phillips Expl. Services PB Well Files Ext. Exploration R & D Exxon Sohio Marathon '~$~atel/of Alaska Mobil Texaco ARCO Alaska, Inc. Post Office Bt~.~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 14, 1985 Mr. Harold Hedlund State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 12-29 Dear Mr. Harold, The DS 12-29 Well Completion Report, dated 06/19/84, incorrectly lists the ADL number as 28329. The correct lease designation for this well is ADL 28330. Would you please make this change to your records/files. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/L28 xc: DS 12-29 Well File P. T. Willman, ATO 1069 K. McFarland, ATO 1429 RECEIVED ! 8 ]985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inr--- Prudhoe £ Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 2, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine'Drive Anchorage, Alaska 99501 Re: DS 12-27 Permit No. 84-23 DS 12-28 Permit No. 84-31 DS~-~-~'~Permit No. 84-32 Dear Mr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/mjb Attachments cc: Sohio Alaska Petroleum Company File Pi(DS 12-27)W1-3 File Pi(DS 12-28)W1-3 File Pi(DS 12-29)Wl-3 RECEIVED JAN 0 1985 Alaska 0ii & Gas Cons. Commissi0n Anchorage ARCO Ali-kl, Inc. Il · Subaldlary of AllenllcRIchfleldCompany STATE OF ALASKA ALASKAOiL AND GAS CONSERVATION c0rI~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-32 8. APl Number 50--029-21087 OTHER [] 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Suriace) 1328' FSL & 104' FWL, Sec 17, T10N, R15E, UM (Producing Interval) 272' FNL & 2313' FWL, Sec 17, T10N, R15E, UM (Total Depth) 88' FNL & 2465' FWL, Sec 17, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 71' RKB I ADL 28329 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-29 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) 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.) (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). Began perforating operation on 11/29/84 (finished on 12-10-84). RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 10458'-10478' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun 92, shot interval 10440'-10450' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #3, shot interval 10410'-10426' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #4, shot interval 10390'-10410' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun ~5, shot interval 10390'-10410' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun 96, shot interval 10370'-10390' MD (4 SPF). Shut-in well, POOH, all shots fired. Secured well, RD. 12-10-84 Pressure test equipment and resume perforating operation. RIH w~.~, ~n interval 10492'-10502' MD (4 SPF). Shut-in well, POOH, all shot~'i~if~d~." ----l~e~ed well, RD. JAN 0 4 1985 Ref: BHCS: 4-13-84 Alaska 0il & Gas Cons. Commission Anchorage 14. I here:ertify that the fo~:e aTorrect to the best of my knowledge. //~'/~'"~ Signed --~......~- Title Regional Operations Engineer Date , The space below for Commission use Conditions of Approval, if any: I Approved by By Order of COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In Prudhoe L - Engineering Post Office ~lox 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 2, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-26 Permit No. 84-14 DS 12-27 Permit No. 84-23 DS 12-28 Permit No. 84-31 · -DS~~ Permit No. 84-32 Dear Mr. Chatterton: Attached are Well Completion reports for the above-mentioned wells. Please discard the Well'Completion report for well 12-27 that was sent to you on December 31, 1984. The perforation depths are incorrect. / Very truly yours, D. F. Scheve DFS/JEB/mjb Attachments cc: Sohio Alaska Petroleum Company File Pi(DS 12-26)W4-3 File Pi(DS 12-27)W4-3 File Pi(DS 12-28)W4-3 File PI(DS 12-29)W4-3 RECEIVED JAN 0 ]985 Alaska Oil & Gas Cons. CommlssloD Anchorage ARCO Alalka, Inc. II · Sublldlary' of All.nllcRIchlleldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO~.~,IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I-~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number . ARCO Alaska, Inc. 84-32 3, Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21087 4. Location of well at surface 9. Unit or Lease Name 1328' FSL, 104' FWL, Sec.17, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 272' FNL, 2313' FWL, Sec.17, T10N, R15E, UM 12-29 At Total Depth 11. Field and Pool 88' FNL, 2465' FWL, Sec.17, T10N, R15E, UM Prudhoe Bay Field 5. Elevation71, R~<~in feet (indicate KB, DF, etc.)I] 6. LeaseADL 2C~20-~,~Z3 ~7.,~- -~'-Designati°n¢'., ,~ /1¢and Serial. N_p,. ,.~/7~./~,~,~. Prudhoe Bay 0il Pool 12' Date Spudded03/31/84 13. DateT.D. Reached04/14/84 14'DateC°mp"Susp'°rAband' 115' Water Depth' if °ffsh°re 116'N°'°fC°mpleti°ns04/26/84 N/A feetMSL 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Perm'afrost 10778'MD,9222'TVD 10735'MD~ 9184'TVD YES [J~ NO [] 2190 feet MDI 1900' (Approx) 22. TyPe Electric or Other Logs Run DIL/BHCS/SP/GR, FDC/CNL/GR~ GR/CBL~ Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91. ~4~ H-40 Surf 80' 30" Instld w/1850# Poleset 13-3/8" 72.0# L-80 Surf 2517' 17-1/2'~ Cmtd w/1700 sx Perm "E" & 400 sx PF "C" cmt 9-5/8" 47,04~ L-80 Surf 10,162' 12-1/4' Cmtd w/500 sxs "G" cmt + 300 sxs PF "C" 7" 29.0# L-80 9852' 10,778' 8-1/2" Cmtd w/320 sxs Class "(." cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 9892' 9790' 10370 - 10426' MD 10440 - 10450' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10458 - 10478' MD Perfed on 11-29-84 w/4 SPF D_EPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED *10492 - 10502' MD N/A *Added on 12-10-84 TVD of Perfs: 8867 - 8983' MD 27. N/A PRoDucTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) , Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-el L RATIO TEST PERIOD ~ FIow'~ubing Casing Pressure CALCULATED=~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CUR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ;- GEO(OG'ICMARI~EF~; ? '~':~;::':"' '- !L; , !:.: ':~: ~'' :'-'-;: :-"; -~ '/' i":'ii;-" ;':Ido'RMATi'ON'TESTS--'" . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10,288 ' 8794' NONE O/W Contact 10,655 ' 9115 ' Base Sadlerochit NOT REA£ JED . 31. LIST OF ATTACHMENTS · . __ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~6r~'~~~ Title Re§ioQal Oper' F..n_~. 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- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 P.O. Box i0£)36¢) Anchorage, A ~a~.ka eot'jO DATE' December 2t i°84 REFERENCE' ARCO F'res.s'ure Dai'a D S, 9-6 t 6,- I t -.q.a . · .. '~ 4 I t -'")" -cz, D,,.9, I '2-8B i i -26-84 D., S,, , t .,_o-'~O..t i -26-84 D,. S' ., I --.°-2t t t-.x,':.;-84,_ ,.. D. S.. .. i~")-'-)":'---. I --'~- f -84, -.., ~.., i "':'-")S i 2-t -84 .~..~.. D S I o_">, ' 2-3-84 ,,. ,. ~. .- ¢., 'l D .9 i.-.~-'")-',...;t D S.-. i 2--.'0 t '~-' ,. ... .. ..... I -84 D,. '? . I Fi-3~ I I -i ';'_o.',, ,., T.:,., S-.., I 3-4 t t -' i 7-84 D ,.S' t 3;-6 t i -t 0_0_4 I;.,.S~ i,'.,-,' ii_iTM o. D S t S--I S i I -'i o._o,~. T', S i ~-t 4. i i -I o_o,,, D £,' i 4-i '') i i -"~ 6-84 D S-. t 6-i o,I _f:, ,. ,.9 , i 6-6 c:'-22-84,. D,,'2,. t6-? 3-i9-84. D,.S', 16-'t i S--'i 9-84 ""' S, I -'-~ q-26-84 .~-" .,.. .-. I' _:' . D ,. S.,. i TM ~' 3-' i ! ~'_.) ;. P B U S/. 't. a I' i c o S'fat'i c ~ i'- a -t- i c ~.> . S.-.' I' a l' i c St'a t' i c S"t. a -I: i c Sial'lc S'i'at' i c Si'ai' ic S±atic ,~±a± i c S:.'ta ± i c S't' a 4,: i c ~':. ,. a +. i c S-. ~: a T i c ~'ta ~: i c u.¥'vey Grad i eni' 6tad i e'n +. C-.r ad i e'n+. Grad lent Grad i e'nt Gl'ad i eli 4,.' G- r a d i e n '? Grad i eh!' E,.r a d i e'n't' Grad i e'n't: Grad i e'n t' Gracl fen± Grad i e'n't' G'r a cii e'n'~ Grad i en't' Grad i en't' F'DD Survey F'BU ~;' u'r' v ey S!'a~ic: Gradien't S'~ai' i c [.;tad i en~ F'~:-: LJ ~urvey 5'i'a I' i c [,:~ad i en~ ~--8 file ~.-. L,a fiiC f.-. ,_.a file L-8/l'iE []: a m c L.a Ji}C C8 file L. a hi C Ca mC ~ hlC Ca h~c L. 8 f~ c C; a m c C a m c: ~.F'a hiC Pi. eas'e ~ign and re!'urn -the a't'.!'ached copy a_---, receip"r of daf: ., F-.'ec e i ',..:ecl By_. Kel Ly Hc:F:'ar;a'nd ATO-f -" '~ °F' ... -~- ,;:...- T R A N S, 4',: 422 Alaska Oil & Gas C0ns.'Cc Anchorage I)!STRIBUT]:ON Ch E'VI' C)!'i i) :_-, E: ::,..' l::' i. o'~" a 't' i c., n S e r v i c e :=-- E-" x '~: e ;",, .~: i c:,'n E :,.: r-:' L c:, r a !' i o ;-, Exxor, Pi a r ..-'.', '~ h o Viol3 .~ L Hr;i'": : i:'- ,'.::_ '", F'hi [ t, jp~. F"ru "hoe I?,ay W.e[ l.F:'i ie2: i.-. ~ %.: S,'c)h [ D 5:i'a te of STATE OF ALASKA ALAsK~oIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLZ-I OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface_) 1328' FSL, 104' FWL, Sec 17, T10N, R15E, UM (Producing Interval) 272' FNL, 2313' FWL, Sec 17, T10N, R15E, UM (Total Depth) 88' FNL, 2465' ~, Sec. 17, T10N R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 6. Lease Designation and Serial No. ADL 28329 7. Permit No. 84-32 8. APl Number 50- 029-21087 9. Unit or Lease Name Prudhoe Bav Unit 10. Well Number DS 12-29 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: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ]~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well BI Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 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). ARCO Alaska Inc. proposes to perforate well 12-29 at selected intervals within the Sadlerochit Sand of the Prud~oe Bay Unit. All wireline work will be done through a 5000 psi ~.~ 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 10370 - 10426' MD (56') 10440 - 10450' MD (10') 10458 - 10478' MD (20') 10492 - 10502' MD (10') Ref: BHCS 4-13-84 RFCEi oft 'Fom'~ No,, t Alaska Oi! & Gas Cons. Cor,:'tmiss~on Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. '~~j~ ,~O~e--~."'~ Title Regional ~Ingineer The space below for Commission&e Date Conditions of Approval, if any: A~roved ~y_ COMMISSIONER _Approved Copy Ret.urnec~, BV Order of the Commission Date · Submit "Intentions" in Triplicate Form 10~,03 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 28, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 12-21 DS 12-22 DS 12-23 DS 12-25 DS 12-26 DS 12-27 DS 12-28 DS 12-29 Permit No. 84-48 Permit No. 84-60 Permit No. 84-58 Permit No. 83-166 Permit No. 84-14 Permit No. 84-23 Permit No. 84-31 Permit No. 84-32 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours~' D. F. Scheve DFS/WT/imh Attachments cc: Sohio Petroleum File ?i(DS 12-21)W1-3 File ?I(DS 12-22)W1-3 File Pi(DS 12-23)W1-3 File Pi(DS 12-25)W1-3 File Pi(DS 12-26)W1-3 File ?i(DS 12-27)W1-3 File Pi(DS 12-28)W1-3 File ?I(DS 12-29)W1-3 RECEIVED tvov 2 8 l g4 Ala~,~a ~tt & (~as Coils. C0rnmlssr0~ Anchorage ARCO Alaska, Inc. is a Subsidiary' of AllantlcRichfieldCompany STATE OF ALASKA , 0 i{ I G IN A ALASK, ~,~ ",ND GAS CONSERVATION (. i.~-.....~SSION WELL COMPLETIt,, OR RECOMPLETION PORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-32 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21087 4. Location of well at surface 9. Unit or Lease Name 1328' FSL, 104' FWL, Sec.17, T10N, R15E, UM ' L~-,~ Prudhoe Bay Unit At Top ProduCing Interval ! VEriFieD t 10. Well Number 272' FNL, 2313' FWL, Sec.17, T10N, ELSE, UM Surf. '~- I 12-29 At Total Depth i B. H,'" ~-~_~ 11. Field and Pool 88' FNL, 2465' FWL, Se¢.17, TION, R15E, UM Prudhoe Bay Field 5. Elevation71' RKBin feet (indicate KB, DF, etc.) 6. ADLLease~Designati°n~'.~,,~and Serial~N~o~,~/¥.,--__'~///~2i"~' Prudhoe Bay 0i 1 Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 03/31/84 04/14/84 04/26/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10778'MD,9222'TVD 10735'MD, 9184'TVD YES El NO [] 2190feetMDI 1900' (Approx) ., 22. Type Electric or Other Logs Run D IL/BHCS/SP/GR, FDC/CNL/GR, GR/CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" Instld w/1850# Poleset 13-3/8" 72.0# L-80 Surf 2517' 17-1/2" Cmtd w/1700 'sx Perm "E" & 400 sx PF "C" cmt 9-5/8" 47.0# L-80 Surf 10,162' 12-1/4" Cmtd w/500 sxs "G" cmt 300-sxs PF "C" 7" 29.0# L-80 9852' 10,778' 8-1/2" Cmtd w/320 sxs Class "G' cmt 24. Perforations open to 'Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 5-1/2" 9892' 9790' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ , Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JUN 2 11984, Alaska Oil & Gas Cons. Commissior~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 JMM/WC06 CONTINUED ON REVERSE SIDE 29. GE_L'..O-'_.:;-_,.'M: 2KE'_':~_ :-". .. ?.,.-- '-:FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad1 e rochi t 10~, 288 ' 8794' NONE 0/W Contact 10,655' 9115' Base Sadlerochit NOT REA( tED 31. LIST OF ATTACHMENTS Dril-lin~ Hi.~torv. Cvro.~eoni~ Surv~.v (2 eo~ies~ 32. I he~reby certi[y'tha~ the foregoing is true and correct to the best of my knowledge Signed ';': ~...~/~~ Area Drilling Engr. Title 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- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 DS 12-29 DRILLING HISTORY NU 20" diverter. Spudded well @ 1000 hrs, 03/31/84. Drld 17-1/2" hole to 2535'. Ran 64 jts 13-3/8" 72#/ft, w/FS @ 2517'. Cmtd 13-3/8" csg w/1700 sx Perm "E" cmt + 400 sxs PF "C". ND 20" diverter, Instld 13-3/8" packoff & tstd to 2000 ps'i ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form Tstd form to 12.5 ppg EMW ' ok Drld 12-1/4" hole to 10,186'. Ran 260 ~ts 9-5/8" 47#, L80 BTC csg w/fs ~ 10,162. Cmtd 9-5/8" csg w/500 sx cl "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10,778'TD. Ran DIL/Sonic/SP/GR f(10,779' to 10,164') FDC,/CNL/GR fr(10,779' to 10,164') Ran 23 jts 7" 29#/ft f/9852' - 10,778'. Cmtd 7" lnr w/320 sx cl "G" cmt. Drld cmt to 10,735', PBTD Tstd lnr lap to 3000 psi - ok. Displaced well to H O. Ran CBL f/10,750' 9,7,50'. Ran 5-1/2" completion assy w/tail @ 9~92 & pkr @ 9790 & SSSV ~-2190 . Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel & crude Dropped ball & set pkr. Secured well & released rig @ 1200 hrs, 04/17/84. Inject returns down 9-5/8" x 13-3/8" annulus. Leave 3,000' diesel cap-freeze protection. Arctic Packed on 04/21/84. JMM/DH03' tw RECEIVED JUN2 11984 Alaska 0ii & Gas Cons, Commission Anchorag~ ~EVI 5 ~ e,l',J sper, r, -sun May 14, 1984 Mr. Randy Ruedrich AROOAlaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-40033 Well: 12-~29(SEC17 T10N R15E) Prudhoe Bay North Slope, Alaska Survey Date: April 26, 1984 Operator: Sellers Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager jm/~K Enclosure RECEIVED JUN2 1 19S4 Alaska Oil & Gas Cons, Commission Anch'ara[le .:: :' ~ ANL.-HURAI.: E AL.A,z,I.,..A :::::::::::::::::::::::::::::: ""-]"2=-~.,~.9 ..... ("'%r':.'TT'"T"/C)'F,f-"RT~E') .......................................................... ' r':.r]MF'i 1TAT .T FiN DATE F'RI~IDHOE. BAY. AF:'R ii .... 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(], 44 27;:~:'-:. 11 N 1441.7:3 E O. :::7: 26:36, :::7 N 147';?. :.::8 E ::::::::::::::::::::::::::::::::: : -::: ~ - -' ......... :,'O'c:/- 'i"?: .............. O. 3(':,- .... ..?.(*::?::.-I'Q-'-~T .... .1 ..... :I ..... -:1.~ -ET_.. .............. HE"A E:L.IIRE ]F~ VE:I:~:'T' I C:AI....VE[RT I CAL. INCL. I'.'~ E F' 'T H I3 I-.'{: F' T H D E P ]' H D E-: (':i H I N .900 0 7660, 58 7589. ?5 . !?/O0 7'744..'.':'~ 1 767:3. :=:1 .................. e'2.~:.~O ......... ~:'9'-;'t~ i ............... '.~'F ~-,;"..':.,*.1. ...................... ?2 ....'4'4- .......... I::: Ei: C. 'T' ]: 0 Iq lie (:ii F:~: I'Z iZ :iii: ::'=::L !!:"_,'7 I,,I :3:3, r.'i:,'ii)liii: 30 !5'7 Iq :3:2,, () IZ ~..~.;~5i' ..... :~.~,c: .__ Iq ._,._":":~, :30_ I:'::' ' :2::iii: 2 :L Iq ::::::3.6 ? ES 1. :[ .~5 ';::' ./:., ~::;"" :3 f:.J:; .... ......... , 1'4 O Iii"' ]. .... ~, ~~. , . ..... . . . .. ...- ...... :Et.1. 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(:.', I::( C i'" I[)I:~ [) I N i:~ T lei: ::3 V E R'I" I C: I:~ L iii[ G/:[ () 0 N I:)F< TI'"t / '.!::;Cll...I"I'i'"t EE (..~,'.[i;'T'/' (,'J ii-'-':'E;'l' :.-"..:; , , , .,.-,-, ~..~ ,., ....... ,., .~,,~,,' .,,~ ,.~" ,~',~,'..,.',~,-~ ,',~',~-~""'~!:~t'~ ~f':~'~' ' ' : ::!::::. i: ?i:"]iJl !::'::!i' ::i ' ' .... "'""~'"'[ Z ~;;" '"~:~' ' "" ~" ' () ,,/:,./.':, ..:, 10 ..... '1-O N i ,:,,_,C:,, 2' .¢ E ..:>&~&,~'~:~.:: ' · .:,.".=,(., 7o Iq 1 o,=, 7.4,-, (),, :3!5 .... ,....,.-,-) , .-, . ,--,,:',. ,= = ,, ,,;., ..., ....~,.'...~ ... ,,, .,.,,_ ,., ,.1....1. ,,, . ,.., .., , .... '-,~- ." ...... ,, :!ii', :1. ':i',:F:'.::'(), 06, N 1 '.~Zl.'7 ,, '71 E: :::', E: 4 :F: . f.:f,:::: . (),'.': ::ii: :3.6:3.6!!5 N :l. !?'7/.':,. 40 I:!.:: :3 !? 0 (). 74 · ' ._,4c~, ~"., N .~t.~..,, ~ . .4'~ .......... -':'" .... --'""~ ...................... ~" ?' '~' ..... ' ..... '"" ....' .... ~ ........ . ".' 'i::~ ....... :3446. 11 N "" ..... '" "~'~"":""":~' ........ :=:4E:4.4:[ Iq 20D/.:,. '76 ..t.I, ~ .,,,t, ,,.. - .... ... ......... "'"t'"~~'''""' ' '1""..~--%W.. ............... Zl. t'l ~, ..:: ......... :.O,'.~';'"7 N ...: ..... ::,..-: ........ :, ~:: -.._. // · "', t:::' I =' I:;.'" ' ~ . · .- ............. 1 :i. I',1 2: i 0 <'i:.. ,":.'7 [:": 4 :[ :'""::2 ("~4- :3!:5:::i',:i3, ,::-6, Iq 2:1. ::ii O. :.-37 E 4:1. 7::-"',, "-..':".::) :36'2:1: ' 26' N ............. Z: 1'~ 6.4d~'"'tE .................. .... ' ' ":;"'" :2:4 ..... . · -:, c,.:_ .,:., N 2184 .'3'7 E ~...' ....~, ,. ,5 ! ":'/':'"::' '::'/" N :2"'.212 ' F~ ................. c,._ E 4296, 6,'5 .':-".','71 '?';".I 0 N ..... ~?q..1.-=~;~--ff .............. -~.'~~ :2','7 !54. '70 Iq 2:2 '7.2:. 4 ::": E" 4:3 :::; ;ii!;. E', 1 .:!i "7'i;:"::::, :iii:,":, i,1 ::'it:::~O-':l.. :30 tZ 4-4:'"i',',:3. :=::L :38'.'3E:, '01 N ~.'3~'e',', "I'2'" I~ ................ ~"~~ ........ :386'='._, ..... .~.~:i N '-'""/-,0..' ..:,.. ,94 E 4527,8:1,".': HCJR]:ZON]-(:IL ]DI.'~i';I='LA't]:E:MENT = 45:27.::.=.':1 F::'E[E:T Al' NCIF;:]"H :2:.1_ I)EC~ .,:: ...... M~N,' EA:!=:T AT""MD ..-. .~...//,::, RECEIVED JUN 2 1/984 Alaska' 0/i & 6as Oons. Oornm/ssion Anchora,oe I:::'F:i:I...IDHCK.E BAY AF::'F~ I t._ 2.5., 1 'i?'.f;,4 ...I i"~1::'~ NI. MBEF:;: AI-<.....BC~...'-zI. OO:F::F: ~'.~I_ASSI<A I<FZI_t....V BU:iii;H ill I,.IG EI_EiV. = 71. O('l F'T'. :iii:(7.) 0 () ;;ii: 99'7 ,, 0 :iii: :;ii: 9:26. ,, 0:7; ;;ii: E:. '.:;' 9 5000 46::3 il.. 95 461. 0.95 958.56 I',l O 000 5410.02 52;:39 ,, 02 156,1.69 N .................... -'~00'0 ............... '.4:;'1"I~T,"~ ................. 00~ ::~7' ................... ~.'4:tk; '4:"""..::, N :::OC)O E,',.:::r..::,:2. :[ ::-3 6791.. '1. :':.'; :2.6'!70. 1 ('> I',l 'PO00 "' ' '" "':'"" '"'"= / c., c:, (.) 7' !:5 :::::'::.'.' f:i f": .... -- , .... ::"'; :l ....... .4.= N i~ .... ,"', i # ....! ................. ~000 .................... ~:~ 1. ,~'~: ........... 8'4 ~0';'9~ ............ 3.~a8 ,, 66 ""N 1077E; 9221.45 9150.45 ::ii: E: 6 :B o 55 N I'1.'O .... 'f' V i7 V E F: "f' :1: C: A L I] i F:' I:::' I:_'"'_' R E N C EJ .................... C01~I~IS-' '~TTTZIN .......... '-' ...... THE C:AL:Ct.tt:.A'T:r_ON'"'F'ROCBDURET,%"A~--DASE:'D. ON' 'TH~_,,."'I:.:,m:..,.E7.. -"OF TH1RE'.E'""D/T.-M~S~~i.'TITT~-'_r:tJRVATURE:'"'i~'iETHOD':;' ......... ' ....... : ....)-' .................................. RECEIVED ...... JUN 2 i 1984 Alaska Oil & Gas Cons. Commission Anchorage F'RU[:IHEIE B~Y AI::'R ]: L. :}:::.:',., :l. '? ',:?, :.l. ,...II:::tB Nl_llvt[}:<l::::R &L.~SI<A I<EL.L Y BI. I::i H :1: Nl::ii E:LE::V. = 7 ~. O0 F"T'. · .:.:.w.....x.M.~>x.:..:.~:t%.~ ,~.:.:. .:.:.: :.:. :.:....:.....: .:. v.: INTER:~~:~::: VALI.,.IEtF; F'F/R EVEN ,10o F.E.::.I uF' :::;I.IB-SEA DEF]'H M E A :':i; I_.1R E I:) V E R 'T' :1: C A l... V E R 'T I F: A L R E F:: 'l' A I',t J3 l...I i... A I::< (:::00 t:.,: t3:1: N A ']" E: ::::; "-DE'P']"H"~ ............................ DEf;'fl=H ........................... .~E'~ff'f~ ............... N:(:JI~:H-t / $'Ott"'f:H .E A :.'.;:; ]" / N E.C¥'f' .1~''~ . ',, . ~ , .'"1 ."* 571 ._ 7:1. O0 ~",0('~. 0('~ O, ..:,..:~ ',-'.~; 771 7'7:1.. ()0 70 (). 87:1. 8 '7 J. ,, 0 (".) :::', 071 1071.00 :1. 0 ()0. ()0 (-~. !71 1171.00 llF~O. O0 0.2<"~ Iq ::':'~ 7 .t :1. :371.00 .1. :.?, ()O. () -1.'71 14'.'2' 1 ,, ()0 :1. 4()CI ,, ()0 2 ,, 12 1'5~'! " 1571. O0 .... i~00~ O0 ' 671 1671.00 1600.0 ¢:~ 3.74 S 771 1771.00 1700.00 4. 19 S O. O0 0.02 E 0 ,, :1, 1 E: 0 ,, :1./"., 0,:32 E 0.60 E 1. 1 <':, E 1 ,, 8? I? 2, ',F', 1 E 3, 'i:;'1 E ~, 8:?,' E · 5,72 E 6,42 E ,.'.i.., ? Zl:'" .R:..: <!:,. '::.': 1 l.'ii: 5,, 2:3 4, I:3 FL 2,7:3 E ..................... R[C't:IVED ................. JUN2 1 19114 Alaska Oil & Gas Cons, Commission AT, OhO'rage F::'F~LIDI-'-ICIE BAY AF:'I::(II .... 25., :l.';~):;;~',zl .... ICfB Iql..IMBE:R AK'"-.BO-4()()E::3 AL...ASI<~ KEL..I,...Y BL. SH:[NG EL. EV. = 7~. 0() F'"I", tNTE VAI_UES F'OIR EVEN 100 F'EE'T' OF ._, IJ [. -- .z, EA DEl' iH 'T' R U IE S I_l B - S E A 'T' C '~1" A L M E A '.iii; I_1R E ][) V [::; R "1" I C A l_ V E:' R T I C A L I::;~ l-'[ C "1" A N ('ii I...IL.. [::'.'~ t::;: CCI CEt t::;: Ii i I',t A 'T' 1:!:: '.::i; I'"i :CI--"1' V D V E:' R'T' I F: A L.. ..... I)IE'P'f:H ............... DEpIy. H .................... DE]=~,t, pf ............ .._NOIRT. H/SOi,iTH EA:3'I" / WE:iii;'T' D I H F EREN....E ......... 1:5:71 1871 00 1800 Cx} 4, ~"" '""'"' .... ,,,:., '.-Z; 1, ,::,,::: E 0, 0'7 0. .................... d: ..~J. ........ .t97-.t ;f.~ ................. ~t}.~;;-' .~.'0 4;'8..3 :]!:' 0, 7f.';' E 0 ,'O't-'? 2()71 2('~'71. C)0 2('~()0 ,, ("1("~ 4, 8:.:3 ::-'i; (). 15 W () ,, ("~',:ii () ,, 0() 21 '7 ZI. Z:'.': i. "7 ZI., ()0 2 :l. ()("1. ()C) 4, ',Jif, :1. :iii; () ,, ,:i:, ',.?I W () ,, ()',i!i~ C). ........ : ........ ~2Fi ............... 2~'7'I","'0~ ................. 2~'00 .'00 4 ~'78' S 0. ?4 W 0,' 0.?..: 0700 ........... 2371 2:371 00 '-"R '" 1. 1 '7 W 0.08 0.00 . .~:... 0 () .0 () 4. '='.. ._,':' .....':::' 2471 2471 00 2400 00 .=; ""'"' S :l. 1 -':ii: W 0.08 0 (:~0 # .in ,~, ii ."...,.I ..' .'~K?'~ .................... ""~'~ ...................... '"'"" ............... zl:"."8~ ' ~ ....... .,::._ ,, J. .,::._, ,, J., ~ .,::._, .'00/. ~0 0',,' 35" W ....... .0-;;" .0'? ........................... 26'71 2. 671 , c) .......... (') 2 A C) () , C)..... (') "::' .,. .... F,, 2 :B '":',:.. 00 E (').. ,, 1 ._,"::' 0. (),.'::, Ixl 4, ::-'i: :iii: Iii[ (). 4. 3 (), :2'7' N ..... 14. :37 E N 24.44 E N ' 34.87 E lxl ................ 43 :-"-70'"' E iq 5(']. ?(:) [ii: Iq 5'.-:) ,, ('~7 Iii.:. N 6'i?. 12 E N 81.53 [ N '."T~d:,./',2 E ......................... RECEi VED ........................... .......................... J.UN2 1 198 .................................... Alaska Oil & Gas Cons. Commission ................... Anchorage .................................................. ARCO ALASKA I I.z.--~ ( .:,E .... 17 ~ 1. O'N" F~ 1/5~'~'z::;';;¥** ........... :::::':-:'2:; ..... (]Ohll~l_lT~'T'I ON DATE I::'F~I.JDHOE BAY AF'R];i ....25., 19':B4 .... lOB NI...IMBEF:( AK..-BCI...'.4()C~:33 AL. ASI<A KELL. Y BUSHZ NG EL..EV. = 71.0() F:'T'. "I"R t...1E MEASURED VERT' I CAL VER'I" I C:AL. I::(E C'l"AIq GI...iL..A F;~ '" 0 J" I::(B I NATES MD--"I"VD VEFr('T' I C:AL_ ' ..................... ~ ' . EA.. f / WEST · .,,~, 1 "}. :2:7'71.00 :3700, C)0 274. ._~-",:, N :::,,"Z,-_,-~. ~;;~.~ ............. ~:7'- t ......... t:tf:t ............. '~'4~tf:), -.,tC]l~)- ................................ ~"~ :7-'-~'~*'-'t~t · ....s .....~._ ....,,_, ¢ ~. ~ ....... ...1~,..i .... . . .. ...~.. ~..- ...' · , 4054 :39'71.00 :'3'? 00.00 :387.4'J~ N . . ' u .... ~/I:':' c;;' 4178 Zl. 071 00 4.000 ('K'~ +.c ..... Z:3 N :4442 '4577 ~)~1'~ 4849 4985 5256 53.92 .................. 552? ..... 5~45 4271.00 4'200. O0 ,613, ',,~6 N 4371, O0 4:300.00 697.23 N 447'.1:-:"00 .............. 4400;;00 ............ /~.571.00 450 (). () 0 :::',65. '?() N 114.51 .1. 35.58 15'!?. !? 4 1 :i::: :iii: . :5:8 220-. 66 255.58 2'.:91. :':: 2 :327'. 4. 6" :'364.75 4- 6 '71.0 Ci 46 () (). () () 4.7(71 ,.-~) .......... 4700, 00 4871. O0 4800.00 4.971.0£) 4'F/00.00 ....... 5071. (.~'] .... 500'0'.-00- 51 '71. (')0 5100.00 52:71. C)0 '.15:20 C). 0 5:3'?' 1.00 5:300.00 5471. O0 5400.00 5571.00 5500.00 !? 4'.::';'. 4- .6 N 4 (':):]il. :"-'i:4 .......... i'0:32.33 'N ......... 44'3, 1' .9 1114.66 N 483.18 1197.01 N I .,.' 7 ::'. ,: .... N" 1:3/',:2. 1 &, I'q 44 .... '70 N ,.' i- I:::' 152Fi. ~'7 N 1613.35 N 1698.70 N 524.6:3 .'.%7.2/:, 612.6 :F. .661.81 712.'4C) 764.75 :=: 19. '7~, E '.'.278 C) 7 ':'":~ ::: 9 I.:j ::ii: 14. 1. :3 3 6. (':)5 E 38,~._ 39 .--,'-'=.,. 56 E 421.41 :36.01 · ~ ..... :,. ........ ~;-'._ _ -~_,,._, ........... 1:2 49'"; 34 ::3'7 ":' z. · -_ , ~ ..'_ ...~ Ii:_"' ~ ::: 4.6,1 :'::', 9.27 E' ._~i 7 ~'~'''' ~'-.' .-, .................... .-,~'~7""¢' ~'. · ,-, ~. ......................... E 615.16 40.93 ~ F, . 42 · 52 E =-_7 6'7 ................................................ 'RECEIVED JUN2 i Alaska Oil & Gas Cons. Commission .... Anchorage .................................. ' I A, ' ' E- -'"' DATE uF ~:i.:RVEY: APR F::'RI.IDHOE B~Y AF'RIL '""=' ].'J;;':~J:4 lOB NIJMBIEF~ .g2 .,..I v ALASKA KEL. LY BUSHING E:I_EV. := 71. O0 FT. ~ ......... ~ .... ~: ::~ ~:~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: I NTE.,?.~..:~::.~::~:.~ _:..:._ VALLIES F'OR EVEN 10C) F'IEET OF :-:;LIB-'.:;EA DEF'TFI 'I"RI._IE M E A S I_1R lei; D V E R T I C: A L.. ...... DEPTH ..... DEPTH .'F.; U B- S E A T' O'l"A I .... VERT I C:AL F;,'E:C.:T Al,,l(.:d_ll_ AF:~ C:OOF:~131 NATES ......... DEPTPF NOR T' H / ..":"J.';O LI"I" H EAST/WEST . ,~ .-i I[" c"'# #... m ~,.:,7 .) .z, 671 O0 5/_-,ex') O0 17:5:2.24- N ....................... ~1"i ............ .=,?? I .... ........ . 00... ............ ._'~0'0 ~"00 .................... I ~'~,_, _,....,.~, ,,""r~.... ,, hi' ' ...... ' .::, ,:, t:, d 1 .. 1. Iq 6/_-, .-, ..:. 5 :-3 '71. C:, C) '-'"' .... . ,F) 0 '::/4. '7. ':;' 67'ii> :2: 5'F' '7:1.. C) (') !;5 'i:? (") ("~. () 0 :202:7.70 lq , ..... ,,, ,, ....... ,~i~ ~l-_-'.i ,- ,.,,., ,:,.~N 70'70 6171. O0 6100 . O0 =":'1:3:'::_. 70 N 7207 6271.00 6200. 00 ';":"2:59.1:3 Iq ................... ~4-.C-: ........... Z.''~' ...... ~- ."- '-,.:,71"~00 .......... -' ..... ~;._'3,00 O0 ......... ...: .......... :, ::'!:7' N 74'78 64'71. ('-)(") 64 ()(). 0 () 240'7. '7:i"": N 7./:, 1:2 6'";-' ............ .... / .1. ('~ ('~ /:, 50 (') 0 (') 24 :.:.'i', :1. 2:7 N 7,_ oU 6771 O0 67,00 00 2/-:,2/., :':: :/ N :_-':01 i c'-, 871.0 (') .. 6 :-": (::' (') , 00 :2696, :2--.: 6N ....... . .... '""~" ..I .......... 81-41' ,."s.'¢..'71. r"~A ...../.';¢0~'. 00 .... .....764 '"'"" N :-_: :2 '.7 (') .......... '7 (:~ 71 o (") '7,::.~ c:, (') (),.":, 2 :::i: :--: 1 ="= .... 1"4 :3::-':'.-.-¢7 '7171 · (-~('~ 'Z i o(.'). C)O '2:.:'-'.'.-76 · :25 I,,I .,~,~.; ..... .~, . ...,( --,,:'.] ,.=.,.:~ ,. -- ..'.._-, '72'71. O0 7..' 30. O0 .- .'.._, .".. 46 N 8648 7.'_--:71. AO 7300.00 :--:020. :':: 1N :=: 770 7471· 00 7400 · 00 .::~_) ...../'~';?. 09.. N ........................................ ,::, 7 ....m ........ E 9:_'-:1..63 E ,:.) IL':,, ,,": ~:::' '-' ........ / E 1045 ,. 54- lie 1 10 :',;.". ':;:"6 1:[!5,/.-,.'7';;' E I211,:29' -; .1.'"" ~"' "'"'"~ .,::. ~;, ._l ,, ..", ..,. 1 31 ::.'::. 0 2 Z 1'-""*' 'P6 - .'-, ~, ::,", 1421.61 E 1472. ('~ 1 :~:- 1 F: "20.7:3 E 1568 - ~'-. .0._,-E 1 ¢!:, 14.. 0/:, E 16 f"'i :i:. 7':2: E 1702. 17 E' 1.744 1'-' E 1784.47 E ) MD-TVE VE:R'T"[ r:' AL '- /:, 99.41 41.74 ¢).-. ~,, 74 .... :, 7' ............................. 7',i::', 2 ,, 2: :2.': 4. I. :':": 6 '-"'-'""' <.'i:,'.:.~ 40 '~" ,.-., .,~..,.' . ... ~' ... 9:36.2:2 36.64 .......... ~'7'". '~',- :l ()()'7. :2.:'7 :':i: 5. (:)4. :1. (-) 41.9 ~") 3 q. 5 :':: 1 1 cZ) 9 '-' 1 ':'"" C) 4 ::: 1 14 C). 6 2 :31.41 1 :/':7,":--¢... :'::4 ....,_,'":"::', 7'2 12',::',":,. 70 :2.:: 7'. 3/3, I-~.~'~.' '"z~ ~'/= ...... "~"-~ .............................. RECEIVED JUN 2 i 19B4 Alaska Oil & Gas' Cons."CommisslOn ................... Anchorage ARCO ALASk:A ........ ''- ' ' .i. NL. URF URA TEE ........ I"~ =:l'f''2'~ ........ ("SEC: 17 TI'ON ' F:'F~I...IDHIZIE BAY AL..~SKA ZNTERPObATEE, VALLiES I::'FiR EVEN ' 'T' R U E S LIB - S E ~ "1" C 'T'A L. IdEA EH...IR EI] VERT :1; CAL. VERT I C:AL RE:C]"F~N(;:~I...IL. AF~ DEFFH ............... DE P ]"H .................. DEP:'f:~' ........ NOR:i:'H/5~OLtl"H 8892 7571.00 7500. () 0 :31:36.0'7 ........ .'.~.' ~ .............. ~_,-~'.f. '; O O' ....... ~_,'~. ':" ~.".-~ ................ :~'1'~ i' :' i"~ 91:31 77'71 ,, 0 () 7700, 00 :3245, 07' 9250 78 '71 ,, () O 7'E: () 0, () 0 :329 E', ,, :32 9484 8071. O0 8000.00 3399.42 9598 8171.00 8100.00 3445.65 9822 8:371.00 'E: :300. () () :352 E:. 66. 99:33 847:1., ()C~ :~340(). ()C~ :3566. :32 ............. t'O(~ ................... ~7t', 00 ............ 8t-¢)', 00 ......... 3602.90 8600. O0 :3638.05 8700. O0 :3/_-,71.55 8 9 0 0 ,, () () :3 7 4 i;;'. '? '7 i;;' 00 (). O 0 ::ii: '7'.':;' 5. :'-.'; 2 · '9100.' 0()" :384('). 6'7 9150.45 :3L::/_-,3.55 10152 E: 671.00 0.,:6-.' o7/1. 10373; ........ E,,_~I :00 10487 89'71 ,, 00 :1. () 60:3 '? 071 ,, () 0 ..... 1:'0'7~'9 ' 9171.00 10778 9221,45 N J. :32:3. :2:9 Iii.:; N ...... :I. E: ,:..:., () ,, 6:3 'E ' N :i. ',ii!: 9 '?. :1. 5 N :1. 'iF; :3:3 ,, J. 'Ei: ii:-'; N 1967,5.5~ 'E Iq 199i..'.'. 7:2: Ii:_:' Iq 5it 0:2:0. :30 E hl 20D9",,' 7'.?' 'IE' I\i 20',:'i: '? ,, E?, :1. E:' Iq 2114.72 E N '?141,'23 E Iq 2170.97 E N 2202. :29 E · N ..... 2f._.'~.'T3?"~- N 226 E:. 6, 4 lei: N :;230.5.49 E' N 2342.35' E N 22:60.94 E 132::I 2:6 21 4.A 1.34.1: 4:? .......................................... ~';; .~ ........ '"'~ .................... -- .................. ......... :1. :::.' 60 ,, :iii: 2 J. 9. :3 4 i :3'7'F' ,, '7 J. :1 :iii:. ::i:'.'T,' .t' 3'W?; 4 i .............................. '1'~';'"? t :.. : ,, ..:: .. :: 141..:, '"'' . F:;_ ('). 16.09 :' :~:.: · :.i' 142'7, 84 14, 34 I"~40';"~,'_,3, ......................... .1.'~°".' i 4 !=; :1.. 'il;':3 1:1. ,, 27 146:2. 12 :/0.2 I'4 :?'l .'"Ce,' .................................. '~2";':77.~ ............... '~ ' ...... ::::::::::::::::::::::::::: ....... 1481.95 10 ,, 0'.:} : i491.97 lO. 02 .'. 1 ::ii', ,, ,.....I 15... ',32 7.98 1 .'.'5 :'.'.': :::-". '74 ]. 548 .' 5"d, ' ............. 1556.55 ............ THL~_.AL-e. LtLAT I EIN PR~EtE.1E. Eff.:tRE-E:---t..fS, E A L II',IE(-1R I'NTERPOL_ATI ON -E~E:TWEEN ..................... THE IqEARF:::-':;T 2(} F'OC~]" I¥1D (F:'ROH I~Ai)]:l...Iri~; OF ()IJRVA'T'I..IF;~Ei:) POINT:::i; ..... RECEIVED JUIN 2 11984 Alaska 0il & Gas Cons. Commission Anchorage ARCO ALASKA IN~_.URPUF~A"'" ...... lED ,,. : DATE OF'.SLIRvEY ~]~?' ::?:;?;?~ ~:~ ~.:?, ?? ...... ~ ~-,-,-~-. ~' -. ~ ,- :::::::::::::::::::::::::::::::::::::::::::::::::::: ........... I.,:-.-.~$.~.. ~....Z7 TI'O~'Ri ..... E) CFMF'IjTATTON BATE F::'IRUDHOE BAY AF::'F~II_ :2'.5,, :1.?~:~4 JEB NLIMBE;I::~ AK-BO-40()3:3 ALASKA KEL. I....Y BUSHIN(3 IEL. EV. = 71.0() F']". "1" R LIE ~i':'; U B- S E A 'T' E "1" A L MEA:.:.';I_IRE:D VE;RT I E:AL. VERT I C:AL RE (:;:'I" Alqr:iUL. AF:'4 'DEI'~t'~1~ DE'P'TH .................................. DE'PTI"f'~:~TI'4:7"."~';f."llLtT'H :[ 0181 ............ :t. 0:2'1'0 102:31 1 () 25 () ............. I.' 02'88 10 5 0 () 1(" "-'~' J ...., z. 869A. 50 8625.50 3646.59 N 8741. ? 6 :36'70. ? 6 :3661. '7 :[ N :3 '75'~;;' ,, :24- :3688.24 :366'7 ,, 45 N 8') 8 Z. 43 8'~ ~ 0.4:3 3754.70 N 'F;O03.88 8932.88 :3764.88 N :2 J. '7:3. 218'? ,, 21 'i? :3. 2:1. 'i? :.':i: ,, 227:2 ,, 2';-i:80. 22?5. 2:3 (.;;,:iii:. 2 :':!', 21. 234:'2', :;:" :3 ,:, 0 . 'ii?4 F TOF:' SAG RIVER 723 EE "I";"~F.".. ..... .:::,Hl...r~._ :2.3 E "1" 0 F:' 6'7 liii: "I"(:)F::' :ii!;HI...IBI.... I I< C :30 E: T'OP 48 E SURVEY DE:F'TH : '76 E 'I"OF' ZOIqE 3 -'.: I. E ..... TOP 'Z'.'.r1N:F:. ..... '"'..- 12 t.'.':: I...I ;'i T :30 E 01 L :" N A"r lii."l::;: C 0 N T A C T 26 E ............. PLI' lt~ B'~ rZtK"'"'T'D '" ......................... ,-,.-:.:-,':---::,~ ................... :-.:'--- .? ....... '::;'4 E TOTAL DEPTHDR-"ILLER ~::.~ · .......... T4E C'-Ei V'E D .................................. ......................... JU N2' 1"'];9114 ............................................ ' Alaska 0il & Gas Cons. Commission ................ Anchora'~e ........................................................... ARCO ALASKA ]iNCORPORATED 12- :b 21'P ( S E C 17 "1- ;I 0 N R 115 E ) "' .'..STI~AT I ~RAPFI I ~ SI.'.IMMAR¥ DER];VE';D I...I'.SII'-,I(3 i']I I.._ i'}l:ii:F:"TH'.i~; K'~I',Ii)'.iii;F:'F'i'~l::tl::;:Y SI...II"..I '.:..::;I...IF:;:VEY DA"FA MARKER ........... ' J~EASLIRED .E, EF"I"I'-I -r'vi::, ................... T'H'[CKNES'.E; WITI4 REF:~ii~;i(i;!?~ii~i~!!;::?~(i~LHEAD ??;:.:': ':: BKB BKB SUB-":;EA VERTIC:AL (ORIGIN-132~i ~4FWL)~' :~"'"'"'~'::: ............. "t"OP "$HUBL t K'A .... .~t~10 .............................. 8'722.8'7 TOF' SHUBLIK B 1()231 8741.96 'TOF' SHLIBL I K C 1025C) E:759.24 .... T OP"~~E'~t'T ...................... ~rZ~ ................. ~F; 7 ?9 ;-6'P "I-OF' Z 0 N E :3 J. () 526 90 ():3 ,, E:8 T 0 F' Z 0 NE 2 1 () 5'73 9' 044, 4 E. 8~ 51.87 :3 E,'? 0.96 ::3688, 24 872:2 ' .,S f...'.' 8'.-:;' :::': 2,, E: :::i', :iii: 9"7:3.46 · ~...,emi- ~~~ · :3661,71N 2 t 93, 23E 36E,,7, 45!',1 . 21 ~8,. ~7E: ~: :: --E..:'t,c_-;~PP';-~ ...... '""'220-':.; ;;:::'30E?:: ...... ' ....... :}:',7,.'::,4. :3E',lq '22',E:0.76, E: :;ii: 78:3.2 'il;' N '.'i." 29.5, '71 E 01L/WATER C:ONTACT :t. (')/:,55 9115.26 9F)44.26 ,: ~.~ .... ~ .... : ..... :,,,< .......... I"~I_L BBAt~.K TD 1U 7o..) 9184. :3:3 '::) 11:3 ,, :3:3 :3846, .. ,..... ,,.. . .............................................................................. ~ ' ..... ~~""'DRP'T'H"'DRTLt::~'"q.~ ................................................. ~'::,m-~ ..... 4'~ .......... ?;.~() 45' ..:,~~,N :?!.,:)"FROM LINEAR..:, EXTRAPOLATION, ,-, ,- , BELOW DEEPEST STATION, _ ' , "'" ' ':': i i!: ~.) CF]MPLITER F:'IROGF(AM oFERRY '.SI..IN 'THREE DIMENSIOIqAL RADIIJ'S F"~F CLIRVATLIRE --~ T'~'-"~:t~tt:.tL:AT'tON"' A N E,'--~'N ~'E~]L: A ff~'ON" 'B Y""'R Ant~ l't .fiD"' {~ ""[:-t..l F'(V (~ I" t,. R E. ....................................................................................... AF'IR I 1_ 25., :1. 9 :Fi: 4 J U N 2 11984 Alaska..Oil ,& ,Gas Cons,:,,.Commission ............................................ ~ ........... Anchorage 0.00 2000.00 4000.00 6000.00 8000.00 10000.00, ARO0 Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40033 Well: 12-~29 ($EC17 T10N R15E) Prudhoe Bay North Slope, Alaska Survey Date3 April 26, 1984 Operator: Sellers Scale: 1" = 2000' 4527.81 @ N 31° 25'E 10778 I 2000. O0 4000. O0 $000. O~ VERTICqL FROJE. CT !ON ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40033 Well: 12-~29 (S~C17 T10N R15E) Prudhoe Bay North Slope, Alaska Survey Date: April 26, 1984 Operator: Sellers Scale: 1" = 1000' TRUE NORTH J. -1000. O0 3000. O0 000. O0 10778 Surface Location 1328 FSL 104' l 1000. O0 -! 000. O0 I 2000. O0 HORIZONTRL RECEIVED JUN 2 119%~ Alaska Oil & Gas' Cons, commission Anchorage PROJECTION Suggested~form to be inserted in each "Active" well folder to d~eck for timely compliance with our regulations. Reports and Materials to be received by: ~_~-~~-'-' -' Date Required Date Received Remarks · · Ccmpleti°n Report Yes · __Well History. Yes ~ -~ ~/~-6'~ "-~~,~' -.. ~_Samp les ,/~./~ -'Pr __, ~~. Core Description .Registered Survey Plat ~C~ 3 · Inclination Survey ///~*~' ~ Directional Survey yC~ ~p/ ProddctiOn Test Reports . Digitized Data y~:~'~ DS 12-29 DRILLING HISTORY NU 20" diverter. Spudded well @ 1000 hrs, 03/31/84. Drld 17-1/2" hole to 2535'. Ran 64 jts 13-3/8" 72#/ft, w/FS @ 2517'. Cmtd 13-3/8" csg w/1700 sx Perm "E" cmt + 400 sxs PF "C". ND 20" diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10,186'. Ran 260 jts 9-5/8" 47#, L80 BTC csg w/fs @ 10,162. Cmtd 9-5/8" csg w/500 sx cl "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10,778'TD. Ran DIL/Sonic/SP/GR f(10,779' to 10,164') FDC,/CNL/GR fr(10,779' to 10,164') Ran 23 jts 7" 29#/ft f/9852' - 10,778'. Cmtd 7" lnr w/320 sx cl "G" cmt. Drld cmt to 10,735', PBTD Tstd lnr lap to 3000 psi - ok. Displaced well to H O. Ran CBL f/10,750' 9,750'. Ran 5-1/2" completion assy w/tail @ 9~92 & pkr @ 9790 & SSSV ~-2190'. Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel & crude Dropped ball & set pkr. Secured well & released rig @ 1200 hrs, 04/17/84. Inject returns down 9-5/8" x 13-3/8" annulus. Leave 3,000' diesel cap-freeze protection. Arctic Packed on 04/21/84. JMM/DH03- tw '~,k~ 0~,1 & Gas ConS. Gommission STATE OF ALASKA r ALASKA-C,_,AND GAS CONSERVATION CO.[. IlSSION ~ ~~ MONTHLY REPORT OF DRILLING AND WORI OVER OPERATION$/ · Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-32 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21087 9. Unit or Lease Name 1329' FSL, 105' FWL, Sec.17, TION, R15E, UM Prudhoe Bay Unit 4. Location of Well at surface :5. Elevation in feet (indicate KB, DF, etc.) RKB 71 ' 6. Lease Designation and Serial No. ADL 28329 10. Well No. 12-29 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of. April ,19 84 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1000 hfs, 03/31/84. Drld 17-1/2" hole to 2535'. Ran, cmt, & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,186'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 10,778'TD. OH logs. Ran, emtd, & tstd 7" lnr. Ran CBL. Ran 4-1/2" compl assy. Secured well & RR @ 1200 hrs, 04/17/84. Inject returns down 9-5/8" x 13-3/8" annulus. Leave 3000' diesel cap, freeze protection. Arctic Packed on 04/21/84. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set @ 80'. 13-3/8", 72.0#/ft, L-80, BTC csg w/FS @ 2517'. Perm "C" cmt. 9-5/8" 47.0#/ft, L-80, BTC csg w/FS @ 10,162'. 7", 29.0#/ft, L-80, BTC csg f/9852' - 10,778'. Instld w/1850# Poleset. Cmtd w/1700 sxs Perm "E" cmt + 400 sx Cmtd w/500 sx Class "G" cmt. Cmtd w/320 sx Class "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/Sonic/SP/GR f/10,779' - 10,164'. FDC/CNL/GR f/10,779' - 10,164'. GR/CBL f/10,750' - 9750'. .16. DST data, perforating data, shows of H2S, miscellaneous data ~ NONE ~s Cons '~nchorage ' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed~-.- Form 10~,04 JMM/MR03 Submit in duplicate DS 12-29 DRILLING HISTORY NU 20" diverter. Spudded well @ 1000 hrs, 03/31/84. Drld 17-1/2" hole to 2535' Ran 64 jts 13-3/8" 72#/ft, w/FS @ 2517'. Cmtd 13-3/8" csg w/1700 sx Perm ~'E" cmt + 400 sxs PF "C". ND 20" diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10,186'. Ran 260 jts 9-5/8" 47#, L80 BTC csg w/fs @ 10,162. Cmtd 9-5/8" csg w/500 sx cl "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10,778'TD. Ran DIL/Sonic/SP/CoR f(10,779' to 10,164') FDC,/CNL/GR fr(10,779' to 10,164') Ran 23 jts 7" 29#/ft f/9852' - 10,778'. Cmtd 7" lnr w/320 sx cl "G" cmt. Drld cmt to 10,735', PBTD Tstd lnr lap to 3000 psi - ok. Displaced well to H O. Ran CBL f/10,750' 9,750'. Ran 5-1/2" completion assy w/tail @ 9~92 & pkr @ 9790 & SSSV ~-2190'. Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel & crude Dropped ball & set pkr. Secured well & released rig @ 1200 hrs, 04/17/84. Inject returns down 9-5/8" x 13-3/8" annulus. Leave 3,000' diesel cap-freeze protection. Arctic Packed on 04/21/84. JMM/DHO3:tw RECEIVED 8 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office ~'~ox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Cased Hole Finals D.S. 9-25 D.S. 9-26 D.S. 12-29 D.S. 13-33 4-5-84 4-21-84 4-16-84 4-14-84 ACBL/VDL/S ig na tu r e/GR ACBL/VDL/S ig na tu r e/GR ACBL/VDL/S igna tur e/GR · PLS Run 1 Run 1 Run 1 Run 1 11 5" 5" 5" DA DA DA DA sign and -?turn the attached copy as Have A Nice Day: receipt ox data. Kelly McFarland ATO-1429F Trans. # 185 DISTRIBUTION 'Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob il Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 16, 1984 Reference: ARCO Open Hole Finals D.S. 9-26 4-18-84 Epilog 4-18-84 BHC/Acoustilog/GR 4-18-84 DIFL/GR 4-18-84 CDL/GR 4-18-84 CDL/CNL/GR 4-18-84 GR 4-18-84 RFT 5" DA Run 1 2" & 5" Run 1 5" Run 1 2" & 5" Run 1 2" & 5" Run 1 5" Run 1 D.S. 12-21 4-29-84 CPL/Cyberlook 4-29-84 BHCS 4-29-84 DIL/SFL 4-29-84 LDT/CNL/GR (Raw) 4-29-84 LDT/CNL/GR (Poro) 4-29-84 GR through 9-5/8" csg. 4-29-84 RFT Run 1 5" Sch Run 1 2" & 5~' Run 1 2" & 5" Run 1 5" Run 1 5" Run 1 5" Run 1 * D.S. 12-29 4-13-84 BHCS Run 1 5" GO * 4-13-84 DILL Run 1 5" * 4-13-84 CDL Run 1 5" * 41-3-84 CDL/CNL Run 1 5" * Th~es.~5" logs were re-run due to the caliper missing off the bottom o.~.the ones previously distributed. Please destroy them and replace ~with ihese' Please sign and return the attached copy as receipt of data. Have a Nice Day! Kelly McFarland ATO-1429F Trans. #175 DISTRIBUTION Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc.~.... Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 16, 1984 Reference: ARCO Magnetic Tapes w/listings - \ ~ . . '"~ ...... Z~:f0-~~T-M---Answer~#69T59 Sch ~' D.S. 1-9~ .... 4-20-84 TDT-M #69158 -.'. ~ ~ =~ - ~~g~~tzon Answer #69161 Run' 2 Sch ~D.S., 12-9~ 4-22-84 ~ TDT/5 masses of TDT-M f~69160 Run 2 Sch ~~~~~~L~h~g~age Pro6uct Answer #69163 Run 2 Sch ~.S. 12-16~ A-22-84 TDT/5passes .~f TDT-M #69162 Run 2 Sch ~~~ ~. ~H_f; ~ ~ 1776 . GO , ~'.~ 578 ~ '5-5~4 '~asses CN~MSN w/ON Average ~1964 DA -/ ~D.S..9-4 -~-~-~ - 3 passes ~[~ w/CN Ave-rage---~fi~o~ - ' - . - ~ : - ~ D. B~ 5' 11-8t eH ~N~~%9~ --- ~0 Pleas' - e sign and return the attached copy as receipt of data. Kelly McFar land ATO-1429F Trans. #173 Have a Nice Day! DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon ;q/l A v~ ~ ~--~z _ Mob i 1 ,qzas~a Oil ~ Gas - .~ , ~.,~ . . Mobil E & P ~nChora~ Phillips Prudhoe Bay Well Files ,R& D /~ ~ Carolyn Smith ~o,~ Sohio State of AlaskaC~D ~0~ ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 16, 1984 Reference: ARCO Open Hole Finals D.S. 12'28 D.S. 12-29 3-24-84 WEL 3-24-84 BHCS 3-24-84 DILL 3-25-84 CDL 3-25-84 CDL/CNL 3-24-84 GR 4-13-84 WEL 4-13-84 BHCS 4-13-84 DILL 4-13-84 CDL 4-13-84 CDL/CNL 4-13-84 GR 5" GO Run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5" Run 1 5" 5" GO Run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5" Run 1 2" & 5" Run 1 5" ~~P~ease sign and return the attached copy as receipt of data. Have a Nice Day! Kelly McFarland ATO- 1429F Trans. #174 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon · ' ~'.',,:i?._,, ,?~.,~i Ph~llzps ~ ~. Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska ARCO Alaska, Ir Post Offi(?L~"3x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 5. pril 11, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 12-29 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to dispose of reserve pit fluids down the 9-5/8" x 13-3/8" annulus of this well. Since we have expect to start this work on April 12, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4610. Sincerely, T. L. Fithian Area Drill ing Engineer TLF/JG'tw GRU6/L92 Enclosures RE£E VED Gas ~oo.s, Commission Ancho~'~ge ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA -- ALASK._~IL AND GAS CONSERVATION ~_._)IMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL []XX COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-32 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21087 4. Location of Well Surface: 1329' FSL, 105' FWL, Sec.17, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71 ' RKB 6. Lease Designation and S. erial No. ADL 28329 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-29 11. Field and Pool Prudhoe Bay Fi eld Prudhoe BAy 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Perforate [] Stimulate [] Repair Well [] Pull Tubing NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] Abandon [] Stimulation [] Abandonment [] Change Plans [] Repairs Made [] Other [] 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). ARCO Alaska, Inc., proposes to dispose of reserve pit fluids down the 9-5/8" x 13-3/8" annulus of this well. The 9-5/8" x 13-3/8" annulus will be left with a non-freezing fluid during any interruption in the disposal process (i.e.; rig move, shutdown of disposal process for an extended period of time, etc.). Estimated Start: April 12, 1984 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space belch-for Commission use -~ Conditions of Approval, if any' Area Drilling Engineer ,Approved Copy rnecJ Date 4'V'I ~-;"'~ lit LON~IE C. SMITH By Order of Approved by COMMISSIONER the Commission Date Form 10-403 GRU6/SN45 Rev. 7-1-80 Submit "Intentions'f in Triplicate and "Subsequent Reports" in Duplicate O&G # 4 4/80 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Inspector Location: Sec_l Drilling Contractor ~/ff~ · Representative Permit # ~ I 3~asing Set Rig ~ /~,7~ Representative- Location, General Well Sign General Housekeeping Reserve pit __ BOPE Stack Test Pressure _~nter... ~ 2~.~ ~lves ~_~-~ ~ ~ ,,~p ~.~ ~ves ~ :D': 6 ACCUI.1U I~\TO R S'YS Full Charge Pressu ps.ig ' Pressure After Clo psig 200 psig Above Precharge Attained: -- Full Charge Pressure Attained: Controls: Master Remote ~.ff Blinds switch cover TE~-I re sure Annular Preve Pipe Rams Blind Rams Choke Line H.C.R. Valve Kill Line Valve Check Valve Kelly and Floor Safety Valves - Upper Kelly. Test Pressure Lower Kelly Test Pressure Ball Type Test Pressure Inside BOP Test Pressure Choke Manifold Test Pressure No. Valves //3 No. 'flanges ~ ,~ -' Adjustable Chokes D'/~'~-~ ~ ~/~' ' ~lydrauically operated choke ~/~~/~ Test Results: Failures ~c/67/~/~ Test Time / hrs. ~ ~/~ Repair or Replacement of failed equipment to be made within. ~- ' days and':' Ins~ctor/Com~'ssion office notified. ~min.~O' sec rain ~ sec Distribution orig ' - AO&GCC cc - Operator cc - Supervisor Inspector .... JO51 ---.,.,--, 115' ---,.-- Gyro 708' 700' Sec. J8 Well 21 Well Well Well Z7 'o Gyro 'Sec. NOTES: I. Elevations are ARCO dotum~ M.L.L.W, 2. Distances ore Grid· X and Y co-ordinales ore Alaska State Pl a n~ Zone 4. CERTIFICATE OF SURVEYOR I HERE BY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION AND AL.L DIMENSIONS AND-OTHER DETAILS ARE CORRECT. Wells 21,22,23,27,28 F.,29 Surveyor : : .~-~-.~.L No. 21 ID_ 41.04 Lat. 70° t3'0,3.99~" Y 5931 781 .86 Long. 148° 24' 18..96~' X 697 676.88 WELL No. 22 EL. 40.81 Lat. 70° 12' 55.758~, Y 5 93)0 7'20 ~80 L~g. 148° 24 '42. ZL:>O X 696 905';49 W_,ELL No. 23 :"- EL 40.83 Lat. 70° 12.;52.583',~ Y 5 930-601.56 Long. 148°?.4 41.976 X 696 915.00 WELL' No. Z7 Lat. 70° 13',0(~)~.463',~ Y 5 9`31 425.85 Long. 148° 24 18.197 X 697 717_ .74 WELL No. 28 ' EL. 41.35 Lot. 70°13'01.638'~ Y 5 931 545. I0 Long. 148°24'18.465' X 697 700.46 WELL No. 29 EL. 41.24 Lot. 70°13'02.81`3',', Y 5931 662.29 Long. 1 48024' 18. 712 X 697 688.76 .GYRO LOCATIONS: EAST GYRO Lot. 70° IZ' 51.051;', Y 5 9.30 469. Ii ' Lang. 148°24'16.17P. X 697 807.55 WEST GYRO , ,, Lot.' 70° t2 48. 070, Long. 148° ?_4'~0.996' Y 5 930 143.71 X 696 960:71 ARCO Alaska, Inc. AS BUILT DRILL SITE No. 12: WELLS 21,22,23,27,28 g~ 29 LOCATED IN PROTRACTED SECTIONS 17 & 183T. 10 N.,R.15 E., U.M. D3te '1-8-84 Scale.,1" = ~00' Chkd by B.H. Field bk ~3-93/~-z MEMORANDUM TO: THRU: Stare of Alaska ALASKA OIL AI~D GAS CONSERVATION COI¢.~IS$ION t.l~erton DATE: //~. ~ /~ FILE NO: Lonnie C. Smith /-'(, Commi s s loner TELEPHONE NO: April 6, 1984 D.21.10 FROM: Harold R. Hawkins Petroleum Inspector SUBJECT: Witness BOPE Test on ARCO Alaska, Inc., DS 12-29, Sec. 17, T10N,R15E,UM, Permit No. 84-32. Monday, April 2, 1984: I left Kuparuk Field, subject of another ~epoEt;" to PrudHbe Bay DS 12-29 to witness a BOPE test. I witnessed the BOPE test on Parker Rig 176. There were no fail- ures. I also witnessed the testing of alarm system for the mud volume and flow indicators which operated properly. I filled out an AOGCC report which is attached. In summary, I witnessed the BOPE test on DS 12-29, that Parker Drilling 176 performed for ARCO. The BOPE equipment and mud flow indicators worked satisfactorily. Attachment 02-O01A(Rev. 10179) ARCO Alaska, Inc Post of~ice-~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Harch 7, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - DS 12 Wells 21, 22, 23, 27-29 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, , a. Gruber Associate Engineer GRU6/L18-tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany F~bruary 27, 1984 Mr. T. L. Fi thian Area Drilling Engineer ARCO Alaska, Ine. P. O. Box 100360 Anchorage, Alaska 99510 Prudhoe Bay Unit DS 12-29 ARCO Alaska, Inc. Permit No. 84-32 Sur. Loc. 1329'FSL, 105'~, Sec. 17, Tt0N, RISE, L%!. Btmhole Loc. 241'FSL, 24~9'~, Sec. 8, T!0N, R15E, bM, Dear Mr. Fithian: Enclosed is the approved application for permit to drill the above referenced well. If coring is c~nducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuou~ directional murvey ta required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information, shall be submitted on all logs for copying except e×p~rimental logs, velocity strrvey~ and dtpmeter surveys. ~any rt.ver~ in Alaska and their drainage zyztems have been classified as important for th~ spawning or migra~io~ of anadromous fizh. Operations in these areas are subject to AS 16.05.870 and the regulationm promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing.operations you may be contacted by the Habitat Coordinator'~ Of{~c~, DePartment of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations pro~a!gated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by th~ Federal Water Pollution Control Act, a~ amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation._ To aid us in scheduling field work, ~!eaze notify this office 24 hours prior to commencing instal!etlon of the blowout prevention Mr, T. L. Fi thian-- Prudhoe Bay Unit DS !~-~. -2- -~Februarv 27 1984 equipment so that a representative of th~ Co~ission mm~y be present to witness testing of the eguipment before the surface casing shoe ts drilled, L?here a diverter system is required, please also notify this office ~4 hours prior to co~encing e~u~.....pmmnt., inst~].,~.at~+~.n~ ~ n so that the Co~ission ~av: w~tnes~ testing. beCore dr{lling below ~he 8hoe of the conductor pip~. In the event of suspension or abandonment, please glva thi~ witnea~ present. Very truly yours, _,. : :""~:~:~i ' -:../'"' · .. C' V. cha~.~:erton Alaska Oil and Cz.s Conservation Co, isa!on b~ Enclosure cc, Department of Fish & Game, Mabitat Section w/o eno!. Department of Environmental Conservation w/o enCl. ARCO Alaska, Inc. Post Office B'c~x~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 21, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 12-29, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 12-29 and the required $100 filing fee. Attachments to the application include plats detailing the section and plan views of the proposed wellbore; a proximity plat; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on March 30, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4610. Sincerely, T. L. Fithian Area Drill ing Engineer TLF/JG6L11: tw Enclosures ECE# ED FEB 2 1984 ,~,,cnorago ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA bT1_ AND GAS CONSERVATION C0,~rMISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L~ SINGLE ZONE []X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1329' FSL, 105' FWL, 5ec.17, T10N, R15E, UN At top of proposed producing interval 9. Unit or lease name Prudhoe Bay Unit 10. Well number 12-29 72' FNL, 2257' FWL, Sec.17, T10N, R15E, UM ~/,"-,b At total depth A .... ~'" 3, C0/~/7)~9o 241' FSL, 2429' FWL, Sec.8, T10N, R15E, UN "~uOO/WqO 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 71' I ADL 28329 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number ~8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 1 mi, NE of Deadhorse miles 241 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10888' MD, 9231 'TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120.Anticipated pressures KICK OFF POINT 2600 feet. MAXIMUM HOLE ANGLE 40 Ol (see 20 AAC 25.035 (c) (2) 11. Field and pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 12-28 Well120' @ surface feet 18. Approximate spud date 03/30184 3135 psig@ Surface 4058 psig@ 9231 ft. TD (TVD) SIZE Hole ~l 7-1/2" ~l 2-1/4" Casing 20" 13-3/8" 9-5/8" 9-5/8 x Weight 91.5# 72.0# 47.0# 3-3/8" A 29.0# Proposed Casing, Liner and Cementing Program 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 We1 d L-80 BUTT L-80 BUTT · cti c Pac L-80 BUTT SETTING DEPTH Length MD 80 30' I 30' 2470' 30' I 30' 10157 TOP TV D 29' I 29' I 1002' 9886' 18459' MD BOTTOM TVD 110'1 110' I 2500'12500' 10186'18690' I 10888' ! 9231 ' I QUANTITY OF CEMENT (include stage data) 2000# Pol eset 2300sx CSIII & 400sx CS ! 500sx Class G & 300 sx CS I 400 sx Class G ARCO Alaska, Inc., proposes to directionally drill this well to 10,888'MD (9231' TVD) to produce from the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing and packer will be run. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be installed and operationally tested prior to spud. DS 12-29 will be 120' away from DS 12-28 ~ the surface. There are no other wellbores closer than 200' anywhere along the proposed well course. 23. I hereby certify that the f~r)'egoing is true and correct to the best of my knowledge SIGNED '--/~,/_. ~)__~//~/wC/~fx--,'F TITLE Area Drilling Engineer The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required APl number []YES {~NO i--]YES [~AIO {~'YES []NO 50-- Permit number Approval date ,~' ~'~'~1"'/2 ~ .~2/2~7/j~ SEE COVER LETTER FOR OTHER REQUIREMENTS / //.-,?/ ////./ APPROVED BY/ // // / //'~"~ /~. ~ ,COMMISSIONER DATE' February 27, 1984 ~.._~ /. ~_.../~~~/'~ b'y order of the Commission " Form 10A01 GRU~/PD05 / · Submit in triplicate 0 0 1000 2000 3000 4000 50OO 60OO TO00 K-1t 6000 9000 10000 11000 tO00 2000 3000 4000 5000 6000 lOOO 2000 7000 0 4000 5000 6000 7000 8000 ,9000 10000 1]000 I I I I,m I I I I m/ ........... I I I I .................... ~0' CASING TVD m 110 1~ I,~ JACO ALASKA, I~IC. , , , , .. ~a-a~a- cAsm~ ~o-~oo ~: 13g9'FSL, 105'~, ~c 17, 2.5 7.5 ~: g0'~, ~285'~, ~c 17, 17.5 27.5 ~_K .__ I ........ ,., ~ I- ., ~ ..... TAR~E~ .... ~ ~Z~ ~ .... ~ .... ~O ~ 7leo MD 1 0210 OEP -- 3C B0 ~ . K-~ ~O - 7021 MD mete e OEP m 3711 ...... LeU ~D--8803 hlO--e~8 DEP= +1gl e-6/e'CASIllq ~OmBBgO IOm1Q186 OEP '4~46 ~ . SAG fllqfER TVO -- 8700 MO --10100 DEF --4354 ~HUE LIK ~O -- 8727 MD -- 10234 DEf~ -- 4378 TOP ~AD~R~ :HIT TVO ~ 87gl MD m 10327 .D~ P = 4438 -,- ~[ ~ ~; :~ r~;~.;o-;~-,..--- .,. ~ TVO ,'G2~1 MD ' 108~ 8 DEP ~4792 3A~E ~kOLEROCH~ ~1 , ~ eae4 MD = 1 OEO D~ . . . ....... ~ , ~ ....... ~ .... , ............. moo ~ooo 3000 ~ooo 5ooo ~ooo VERT I CRL SECT I ON DS'12-29 Fi. - ~4 O00ROINB~P.S o -2000 - 1000 ~ 1000 2000 '--~3000 dO00 5000 I I ! ! I ! ! I ! I I I I I I I I I I I I I I I I I I I I I I ~ I · I I I I ] I I , I I I I ' S~' 1329~FSL, 105' ~, Sec 17, ] T10N, '~SE, ~ ~ ~' 20'~, 228S' ~, Sec 17, TION, ~SE, ~ ~512-2~ . . , , I I 2285 ' / T~T 4058 ~- 8871' 105 ~ ~ No~h - 3931 2 E~t - 2180 ~ 1329' i it I W ~-~ Z -2000 - 1000 0 1000 2000 3000 dO00 Fi. - N OOOROINFtTES 5000 DS 12-29 o -2000 - 1000 Z Fi. - kl OOOROINRTES~ tO00 2000 3000 4000 50OO INC. / i ! -2000 - 1000 0 1000 2000 ~000 4000 E - ~ OOORDINF~?ES SO00 (::3 (:3 I Z D $1 2: - 2:9 '.--- E - 1,4 COORD T NA?ES.~~ -~tO0 -300 -200 - t O0 0 1 O0 200 '~00 ~( I I I I I I I I I I t I I I I I I I I I I I , ~ 1 / /~658 / 2089 ~ ,, 1~897 '- . . . ~ L -~}00 -300 -200 - 100 0 100 200 300 E - N COORDINATES NOTE' Well paths extend, beyond thi.s viewing window, jj SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM INC. SCHEMATIC IO" HYD. OPR. BALL VALVE WE~L BORE (SEE DETAIL) IO' HYD. OPR. BALL VALVE ALL 90° TURNS ARE "TEE" CUSHION I 1', ~LL QBORE RESERVE PIT AREA NOTE ' FLOWL INE F DR ILL ING R I SER L 20" 20O0 PSI WP ANNULAR PREVENTOR Valves on diverter lines open automati- cally when the annular pre'venter is closed. 20" CONDUCTOR PIPE "DETAIL" 20260102< RNNULRR 1 PREVENTOR PIPE RRMS BLIND RRMS DRILLINB SPOOL PI'PE RRMS 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydrauIic fluid. 2. Assure that accumuiator pressure is 5000 psi with 1500 psi downstream o£ the regulator. 5. Observe time, then ciose ail units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure, 13-S/8" BOP Stack Test 1. Fill BOP stack and manifold with-a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark rtmning joint with predetemined plug sea.ting depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 5. Close annular preventer and upstream valves. 4. Functionally test chokes. -$. -In each of the following tests, first hold a 250 psi low pressure test for a minimum of 5 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum of 3 .minutes. Bleed pressure to zero. 7. Open armnlar preventer and close top set Of pipe rams. Increase pressure to S000 psi and hold for at least 5 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes.. Increase pressure to $000 psi and hold for at least 3 minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to S000 psi below the bottom set of pipe rams and hold for at least 3 min- utes. Test reamining untested manifold valves (if any) with $000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe ral11s. Back off runrdng joint and pull out of hole. Close blind rams and test to S000 psi for at least 5 miuntes. Bleed pressure off all equipment. Open blind rams. Hake sure manifold and lines are full of non- freezing liquid and ail valves are set in drilling position. Test standpipe valves to SO00 psi. Test Kelly cocks and inside BOP to $000 psi with Koomey pump, Check operation of Degasser. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. Perfom complete BOPS, test once a week and func- tionally operate BOPS. daily. 10. 11. 12. 13. 14. 1S. 16. 17. 18. Revised 2/21/84 CHECK LIST FOR NEW. WELL.: PERMITS ITEM · APPROVE :'DATE Company · YES 'NO REMARKS ·, (1) Fee (2) Loc thru 8) (8) (3) Admin (g thru 11) '(10 and 11) .C sg '(12 thru ,'20) (5) (21 thru 24) · 3. 4. 5. 6. 7. 8. · 10. 1i. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Is the permit fee attached ......................................... ........ Is well to be located in a defined pool ..~ Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore.p~at inT~d~d ............... Is operator the only affected party ............... Can permit be approved before ten-day wait .......................... Does operator have a bond in force ................................. Is a conservation order needed ..... i ............. Is administrative approval needed ................................... Is conductor string, provided eeeeeeeeeeeeeeeeeelleeleeeeelee~eeeeeeee Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones .o.° ................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off'from an existing weilbore ............. Is old wellbore abandonment procedure included on 10-403 ............ adequat well bore eparatio proposed Is e s n ...... ..................... Is a diverter system required ....................................... ~ff~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE, have sufficient pressure rating - Test to ,b5~2~ psig .. ~q Does the choke manifold comply w/API RP-53 (Feb.78) .................. (6) Add: 25. Additional requirements ...... . ....................................... Additional Remarks: Geology: Eng~i~. eering: _ ~g~ JKT~_~ HJH ~T'/~ rev: 12/08/83 , , INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. .o * ALASKA COMPUTING CENTER . ****************************** . ....... SCHLUFIBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NA~E : D.S. 12-29 FIELD NAlVlE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292108700 REFERENCE NO : 98374 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/07/28 ORIGIN : FLIC REEL NAME : 98374 CONTINUATION # : PREVIOUS REEL : COF~4ENT : ARCO ALASKA INC, D.S. 12-29, PRUDHOE BAY, 50-029-21087-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/28 ORIGIN : FLIC TAPE NAME : 98374 CONTINUATION # : 1 PREVIOUS TAPE : COM~iF2~ : ARCO ALASKA INC, D.S. 12-29, PRUDHOE BAY, 50-029-21087-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAFIE: D.S. 12-29 API NUMBER: 500292108700 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 28-JUL-98 JOB NUMBER: 98374 LOGGING ENGINEER: J SPENCER OPERATOR WITNESS: G SARBER SURFACE LOCATION SECTION: 17 TOWNSHIP: 1 ON RANGE: 15E FNL: FSL: 1329 FEL: FWL : 105 ELEVATION (FT FROM MSL O) KELLY BUSHING: 71. O0 DERRICK FLOOR: 70. O0 GROUND LEVEL: 41. O0 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/F~ 7.000 10778.0 29.00 3.500 10438.0 9.30 5.500 9818.0 17.00 4.500 9921.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(FiEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: FDN LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 26-APR-84 LOGGING COMPANY: GEARHART BASELINE DEPTH 88888.0 10483.5 10468.0 10465.5 10452.0 10447.0 10439.0 10431.0 10428.0 10424.0 10418.0 10409.0 10407.0 10396.5 10385.0 10374.5 10363.5 10356.0 10338.5 10313.0 10308.5 10303.0 10300.5 10297.0 10266.5 10254.0 10252.0 10241.0 10230.5 10224.0 10212.5 10207.0 10203.5 10186.5 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... TDTP ....... 88894.5 10490.0 10473.0 10470.0 10457.0 10452.0 10443.5 10434.5 10431.5 10427.5 10421.5 10413.0 10411.0 10400.0 10388.0 10378.0 10366.5 10360.5 10345.0 10317.5 10313.0 10307.5 10304.0 10301.5 10273.5 10258.5 10256.0 10243.5 10234.0 10228.0 10216.0 10211.0 10207.0 10189.0 102.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO'S DS 12-29 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN SIGMA BASE PASS #1 AND THE FDN GAM~A RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10522.5 1 O160.5 $ CURVE SHIFT DATA - PASS TO PASS (f4EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUFIBER : BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... TDTP ....... RES~U~KS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 4 TYPE REPR CODE VALUE 6 73 7 65 8 68 O. 5 9 65 FT 11 66 i1 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 GR FDN GAPI 1102767 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10480 000 SIGM. TDTP 22.459 TPHI. TDTP 54.431 SBHF. TDTP 53.031 SBHN. TDTP 37 965 SIGC. TDTP 0.000 SIBH. TDTP 37.965 TRAT. TDTP 2.286 SDSI.TDTP 1 275 BACK. TDTP 528.781 FBAC. TDTP 1357.625 TCAN. TDTP 33730.000 TCAF. TDTP 9577 500 TCND. TDTP 22637.000 TCFD. TDTP 5820.750 TSCN. TDTP 7104.000 TSCF. TDTP 2017 125 INND. TDTP 1887.375 INFD.TDTP 358.594 TENS. TDTP 1402.344 CCL. TDTP 0 000 GR.FDN 25.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: DEPT. 10160.500 SIGM. TDTP 45.442 TPHI. TDTP SBHN. TDTP 59.274 SIGC. TDTP 0.000 SIBH. TDTP SDSI. TDTP 4.290 BACK. TDTP 386.548 FBAC. TDTP TCAF. TDTP 1907.046 TCND. TDTP 8906.531 TCFD. TDTP TSCF. TDTP 102.247 INND. TDTP 1688.273 INFD. TDTP CCL. TDTP 0.000 GR.FDN -999.250 100.000 SBHF. TDTP 80.654 TRAT. TDTP 751.384 TCAN. TDTP 1049.331 TSCN. TDTP 211.249 TENS. TDTP 61.579 2.739 11221.029 896.333 1390.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10522.5 10157.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUAIBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center 88888.0 10503.5 10501.0 10491.0 10482.0 10478.0 10471.0 10467.5 10465.5 10459.5 10450.5 10448.0 10439.5 10427.0 10423.0 10419.5 10418.0 10408.5 10407.0 10403.5 10396.5 10392.0 10384.0 10378.0 10374.0 10363.0 10356.0 10347.0 10338.0 10332.0 10326.0 10322.5 10319.5 10312.5 10308 0 10302 0 10300 0 10296 5 10288 5 10283 0 10278.0 10273.5 10270.5 10266.0 10261.5 10247.0 10243.0 10236.5 10232.5 10227.5 10220.0 10212.0 10207.0 10203.0 88894.5 10510.0 10508.5 10498.0 10489.0 10486.0 10476.0 10473.0 10470.0 10465.0 10457.0 10453.0 10444.0 10431.0 10427.0 10423.5 10421.5 10413.0 10411.0 10408.5 10400.0 10395.0 10388.5 10381.0 10377.5 10367.0 10360.5 10353.0 10345.0 10338.0 10332.5 10329.5 10324.5 10317.5 10313.5 10308.0 10304.0 10301.0 10294.0 10287.0 10284.5 10280.0 10276.5 10273.5 10266.0 10251.0 10246.5 10238.5 10236.5 10231.0 10224.0 10216.0 10211.0 10207.5 28-JUL-1998 16:07 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 10196.5 10202.0 10186.5 10189.5 10176.5 10179.5 10163.5 10163.0 100.0 99.5 $ RE~J~gKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ........................................................................... l ........... NAME SERV UNIT SERVICE API API API API FILE NUMB AU3FI~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 SBHIV TDTP CU 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: NAM~ SERV UNIT SERVICE API API API API FILE NUFiB NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) SDSI TDTP CU 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1102767 O0 000 O0 0 2 i 1 4 68 0000000000 INFD TDTP CPS 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1102767 O0 000 O0 0 2 i 1 4 68 0000000000 CCL TDTP V 1102767 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10480.000 SIGM. TDTP 22.771 TPHI. TDTP 50.952 SBHF. TDTP SBHN. TDTP 36.900 SIGC. TDTP 0.000 SIBH. TDTP 36.900 TRAT. TDTP SDSI.TDTP 1.304 BACK. TDTP 584.625 FBAC. TDTP 1335.547 TCAN. TDTP TCAF. TDTP 9865.000 TCND. TDTP 22591.750 TCFD. TDTP 5752.000 TSCN. TDTP TSCF. TDTP 2085.250 INND. TDTP 1893.375 INFD. TDTP 372.188 TENS. TDTP CCL.TDTP 0.000 DEPT. 10157.500 SIGM. TDTP 47.532 TPHI. TDTP 81.799 SBHF. TDTP SBHN. TDTP 61.977 SIGC. TDTP 0.000 SIBH. TDTP 86.787 TRAT. TDTP SDSI. TDTP 8.857 BACK. TDTP 434.346 FBAC. TDTP 824.769 TCAN. TDTP TCAF. TDTP 1409.986 TCND. TDTP 9785.602 TCFD. TDTP 354.748 TSCN. TDTP TSCF. TDTP 18.526 INND. TDTP 1959.255 INFD. TDTP 194.576 TENS. TDTP CCL. TDTP 0.000 47. 773 2.195 32262. 000 6820. 000 1431. 000 64.312 4.981 12669.070 820.894 1355.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10522.5 1 O160.5 $ CURVE SHIFT DATA - PASS TO PASS (f~SURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 10506.0 10501.5 10491.0 10482 0 10478 5 10467 5 10450 5 10437 5 10429 5 10427 5 10423 5 10408 5 10404.5 10399.0 10396.0 10392.0 10384.0 10377.5 10373.5 10364.0 10356.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... TDTP 88894.5 10512.5 10508.5 10498.0 10490.5 10485.0 10473.0 10456.0 10441.5 10433.5 10431.0 10427.0 10413.0 10408.5 10402.5 10400.0 10395.0 10387.5 10381.0 10377.5 10367.0 10360.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 10 10352.0 10357.0 10347.5 10353.5 10341.0 10347.5 10338.5 10345.0 10335.0 10342.0 10331.5 10337.5 10327.5 10332.5 10322.5 10328.0 10317.5 10322.5 10312.0 10317.5 10302.5 10307.5 10300.0 10304.0 10296.5 10301.5 10292.0 10297.5 10289.0 10294.0 10283.0 10287.0 10276.5 10282.5 10273.5 10280.0 10267.5 10276.0 10265.5 10273.0 10261.0 10266.0 10253.0 10258.5 10250.5 10254.5 10248.0 10251.0 10243.0 10246.5 10236.0 10238.5 10233.0 10236.5 10227.5 10231.5 10223.5 10228.0 10219.5 10224.0 10211.5 10216.0 10207.0 10210.5 10203.0 10207.0 10197.0 10202.5 10185.5 10189.0 10177.0 10179.5 100.0 102.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFIB NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 SBHNTDTP CU 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1102767 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 12 DEPT. 10480.000 SIGM. TDTP 22.358 TPHI. TDTP SBHN. TDTP 33.897 SIGC. TDTP 0.000 SIBH. TDTP SDSI.TDTP 1.525 BACK. TDTP 550.898 FBAC. TDTP TCAF. TDTP 9173.500 TCND. TDTP 24255.000 TCFD. TDTP TSCF. TDTP 1914.625 INND. TDTP 2007.750 INFD. TDTP CCL. TDTP 0.000 DEPT. 10160.500 SIGM. TDTP 47.043 TPHI. TDTP SBHN. TDTP 62.036 SIGC. TDTP 0.000 SIBH. TDTP SDSI. TDTP 5.150 BACK. TDTP 454.115 FBAC. TDTP TCAF. TDTP 1777.799 TCND. TDTP 10044.322 TCFD. TDTP TSCF. TDTP 65.441 INND. TDTP 1791.386 INFD. TDTP CCL.TDTP 0.000 59.607 SBHF. TDTP 33.897 TRAT. TDTP 1364.730 TCAN. TDTP 5902.125 TSCN. TDTP 401.539 TENS. TDTP 100.000 SBHF. TDTP 86.921 TRAT. TDTP 824.973 TCAN. TDTP 577.851 TSCN. TDTP 209.962 TENS. TDTP 31.055 2.418 33772.000 7049.000 1415.000 72.048 3.337 12799.715 803.689 1335.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER : 4 DEPTH INCREF~J~f: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH ......................... TDTP 10488.0 $ STOP DEPTH .......... 10161.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 13 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10506.0 10501.0 10491.0 10480.5 10475.0 10468.0 10451.5 10447.0 10443 5 10439 5 10437 0 10433 5 10430 0 10424 0 10406 5 10399.0 10396.0 10392.0 10384.5 10377.5 10374.0 10362.5 10355.5 10351.5 10347.0 10337.5 10335.5 10332.0 10326.0 10323.0 10312.5 10308.0 10306.5 10302.5 10300.0 10296.5 10278.0 10265.5 10260.5 10253.0 10247 0 10243 0 10232 5 10223 5 10220 0 10211 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... TDTP ....... 88894.5 10512.5 10508.5 10498.0 10488.5 10483.5 10473.0 10456.5 10452.5 10448.5 10444.0 10442.0 10438.5 10435.0 10427.5 10411.0 10402.5 10400.0 10395.0 10388.0 10381.0 10377.5 10366.5 10360.5 10356.5 10353.5 10345.0 10341.5 10337.5 10332.5 10329.0 10317.5 10313.5 10310.5 10308.0 10304.0 10301.5 10284.5 10273.0 10266.0 10258.5 10251.0 10246.5 10236.5 10228.0 10224.0 10216.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 14 10206.5 10210.5 10202.5 10207.0 10186.0 10189.0 10176.5 10179.5 10166.0 10169.0 100.0 103.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN SIGMA BASE PASS #4 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD AU3MB SAMP ELE~ CODE (HEX) DEPT FT 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNTDTP CU 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE ~ NUM~ SIZE REPR PROCESS ID ORDER #' LOG TYPE CLASS MOD NUM~ SAMP ELE~I CODE (HEX) ....................................................................................... TRAT TDTP 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 TSCNTDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 1102767 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10480.051 SIGM. TDTP 23.875 TPHI. TDTP 61.206 SBHF. TDTP 33.766 SBHN. TDTP 36.679 SIGC. TDTP 0.000 SIBH. TDTP 36.679 TRAT. TDTP 2.407 SDSI.TDTP 1.575 BACK. TDTP 615.281 FBAC. TDTP 1352.938 TCAN. TDTP 32222.000 TCAF. TDTP 8677.500 TCND. TDTP 24016.000 TCFD.TDTP 5752.430 TSCN. TDTP 6760.000 TSCF. TDTP 1820.563 INND. TDTP 2040.625 INFD. TDTP 369.602 TENS. TDTP 1382.906 CCL. TDTP 0.000 DEPT. 10161.051 SIGM. TDTP 44.684 TPHI. TDTP 92.041 SBHF. TDTP SBHN. TDTP 58.375 SIGC. TDTP 0.000 SIBH. TDTP 78.609 TRAT. TDTP SDSI. TDTP 6.079 BACK. TDTP 458.234 FBAC. TDTP 836.516 TCAN. TDTP TCAF. TDTP 1180.500 TCND. TDTP 10295.000 TCFD. TDTP 362.000 TSCN. TDTP TSCF. TDTP 49.875 INND. TDTP 1854.500 INFD. TDTP 200.078 TENS. TDTP CCL. TDTP 0.000 73. 656 4. 473 11006. 000 972. 500 1393. 688 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 16 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ND?4BER: 5 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREM~2Fr O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUFiBERS 1, 2, 3, 4, TDTP THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, 3, &4. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 17 TYPE REPR CODE VALUE .............................. 0 66 1 .............................. ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) ....................................................................................... 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 1102767 0000000000 0000000000 DEPT FT 1102767 O0 000 O0 0 5 1 1 4 68 SIGM PNAV CU O0 000 O0 0 5 1 1 4 68 TPHI PNAV PU-S O0 000 O0 0 5 1 1 4 68 SBHF PNAV CU O0 000 O0 0 5 1 1 4 68 SBHNPNAV CU O0 000 O0 0 5 1 1 4 68 SIGC PNAV CU O0 000 O0 0 5 1 1 4 68 SIBH PNAV CU O0 000 O0 0 5 1 1 4 68 TRAT PNAV O0 000 O0 0 5 1 1 4 68 SDSI PNAV CU O0 000 O0 0 5 1 1 4 68 BACK TDTP CPS O0 000 O0 0 5 1 1 4 68 FBAC TDTP CPS O0 000 O0 0 5 1 1 4 68 TCANPNAV CPS O0 000 O0 0 5 1 1 4 68 TCAF PNAV CPS O0 000 O0 0 5 1 1 4 68 TCND PNAV CPS O0 000 O0 0 5 1 1 4 68 TCFD PNAV CPS O0 000 O0 0 5 1 1 4 68 TSCN PNAV CPS O0 000 O0 0 5 1 1 4 68 TSCF PNAV CPS O0 000 O0 0 5 1 1 4 68 INND PNAV CPS O0 000 O0 0 5 1 1 4 68 INFD PNAV CPS 1102767 O0 000 O0 0 5 1 1 4 68 ** DATA ** DEPT. 10480.000 SIGM. PNAV 22.866 TPHI.PNAV 56.549 SBHF. PNAV SBHN. PNAV 36.360 SIGC.PNAV 0.000 SIBH. PNAV 36.360 TRAT. PNAV SDSI.PNAV 1.420 BACK. TDTP 528.781 FBAC. TDTP 1357.625 TCAN. PNAV TCAF. PNAV 9323.375 TCND.PNAV 23374.938 TCFD.PNAV 5806.826 TSCN. PNAV TSCF. PNAV 1959.391 INND.PNAV 1957.281 INFD.PNAV 375.480 41.406 2.327 32996.500 6933.250 DEPT. 10158.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 18 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUF1BER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER: 1 DEPTH INCREFiENT: 0.5000 FILE SUmmARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10548.5 10155.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TI) LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 08-MAR-98 CP 44.2 304 08-MAR-98 10538.0 10530.0 10158.0 10516.0 1800.0 TOOL NUFIBER ........... CGRS-A 971 TDT-P SET 21 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 19 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10778.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : DEAD CRUDE 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS PRODUCTION PROFILE LOG DATED 25-JULY-199 LOGGED ON SANDSTONE MATRIX. TAGGED TD AT 10530 FT md PUMPED 240 BBLS CRUDE PRIOR TO LOGGING. CONTINUED TO PUMP CRUDE AT 1 BBL/MIN DURING LOGGING. PUMPED A 5 BBL DIESEL FLUSH AT END. SUPPRESSED GAM~A RAY COUNTS ( HIGH SCALE LEVELS ). CHANGED PARAMETER "CSIZ" AT THE SCAB LINER "ON-THE-FLY". THIS FILE CONTAINS BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 2O TYPE REPR CODE VALUE 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFIB NOTiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS1 CU 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS1 PU 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS1 CU 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS1 CU 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS1 CU 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS1 CU 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS1 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS1 CU 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 TCAFPS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 TCNDPS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 INNDPS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS1 CPS 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS1 V 1102767 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10480.000 SIGM. PS1 22.543 TPHI.PS1 41.303 SBHF. PS1 SBHN. PS1 38.599 SIGC. PS1 0.931 SIBH. PS1 38.599 TRAT. PS1 SDSI.PS1 0.891 BACK. PSi 310.757 FBAC. PS1 428.931 TCAN. PS1 TCAF. PS1 10932.010 TCND.PS1 22583.848 TCFD.PS1 6750.593 TSCN. PS1 34.091 1.981 31717.215 6681.103 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 21 TSCF. PS1 2302 . 784 INND. PS1 2003 . 176 GR. PS1 443 6. 000 CCL. PS1 0 . 000 DEPT. 10155.000 SIGM. PS1 SBHN. PS1 69.069 SIGC. PS1 SDSI.PS1 12.255 BACK. PSi TCAF. PS1 1588.510 TCND. PS1 TSCF. PS1 4.371 INND.PS1 GR.PS1 8520.000 CCL.PS1 INFD.PS1 50.853 TPHI.PS1 0.000 SIBH. PS1 415.137 FBAC. PS1 7631.769 TCFD.PS1 1812.507 INFD.PS1 0.000 368.747 TENS.PSi 94.821 SBHF. PS1 102.874 TRAT. PS1 791.443 TCAN. PS1 86.869 TSCN. PS1 198.104 TENS.PSI 1425.000 89.079 4.031 12465.031 507.077 1360.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFI~ER: 2 DEPTH INCREFIENT: 0.5000 FILE SUFk4ARY VENDOR TOOL CODE START DEPTH ........................... TDTP 10546.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TDDRILLER (FT): STOP DEPTH 10150.5 08-MAR-98 CP 44.2 304 08-MAR-98 10538.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 22 TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) 10530.0 10158.0 10516.0 1800.0 TOOL STRING (TOP TO BOTTOM) ~OR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUM~ER CGRS-A 971 TDT-P SET 21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10778.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : DEAD CRUDE 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS PRODUCTION PROFILE LOG DATED 25-JULY-199 LOGGED ON SANDSTONE MATRIX. TAGGED TD AT 10530 FT md PUMPED 240 BBLS CRUDE PRIOR TO LOGGING. CONTINUED TO PUMP CRUDE AT 1 BBL/MIN DURING LOGGING. PUMPED A 5 BBL DIESEL FLUSH AT END. SUPPRESSED GAMMA RAY COUNTS ( HIGH SCALE LEVELS ). CHANGED PARAMETER "CSIZ" AT THE SCAB LINER "ON-THE-FLY". THIS FILE CONTAINS BASE PASS #2. LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 23 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFIB NUbfB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) DEPT FT 1102767 O0 000 O0 0 7 1 1 4 SIGM PS2 CU 1102767 O0 000 O0 0 7 1 1 4 TPHI PS2 PU 1102767 O0 000 O0 0 7 1 1 4 SBHF PS2 CU 1102767 O0 000 O0 0 7 1 1 4 SBHNPS2 CU 1102767 O0 000 O0 0 7 1 1 4 SIGC PS2 CU 1102767 O0 000 O0 0 7 1 1 4 SIBH PS2 CU 1102767 O0 000 O0 0 7 1 1 4 TRAT PS2 1102767 O0 000 O0 0 7 1 1 4 SDSI PS2 CU 1102767 O0 000 O0 0 7 1 1 4 BACK PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 FBAC PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 TCAN PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 TCAF PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 TCND PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 TCFD PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 TSCN PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 TSCF PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 INND PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 INFD PS2 CPS 1102767 O0 000 O0 0 7 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 24 NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) TENS PS2 LB 1102767 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1102767 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS2 V 1102767 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10480.000 SIGM. PS2 23.520 TPHI.PS2 45.784 SBHF. PS2 SBEN. PS2 37.904 SIGC. PS2 0.000 SIBH. PS2 37.904 TRAT. PS2 SDSI.PS2 1.184 BACK. PS2 316.936 FBAC. PS2 435.214 TCAN. PS2 TCAF. PS2 10726.672 TCND. PS2 23075.824 TCFD.PS2 6682.897 TSCN. PS2 TSCF. PS2 2267.715 INND.PS2 2065.051 INFD.PS2 340.551 TENS.PS2 GR.PS2 4544.000 CCL.PS2 0.000 DEPT. 10150.500 SIGM. PS2 55.798 TPHI.PS2 92.814 SBHF. PS2 SBHN. PS2 69.899 SIGC. PS2 0.000 SIBH. PS2 104.757 TRAT. PS2 SDSI.PS2 2.517 BACK. PS2 443.817 FBAC. PS2 842.602 TCAN. PS2 TCAF. PS2 1493.027 TCND.PS2 8790.775 TCFD.PS2 -86.591 TSCN. PS2 TSCF. PS2 0.000 INND.PS2 1947.282 INFD.PS2 207.744 TENS.PS2 GR.PS2 8832.000 CCL.PS2 0.000 34.388 2.054 32552.559 6881.905 1380.000 83.384 4.197 11902.914 419.709 1365.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 25 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 10539.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10155.0 08-MAR-98 CP 44.2 304 08-MAR-98 10538.0 10530.0 10158.0 10516.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMF~A RAY TDTP THERIW_AL DECAY $ TOOL NIIM~ER ........... CGRS-A 971 TDT-P SET 21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10778.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG): DEAD CRUDE 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 26 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS PRODUCTION PROFILE LOG DATED 25-JULY-199 LOGGED ON SANDSTONE MATRIX. TAGGED TD AT 10530 FT md PUMPED 240 BBLS CRUDE PRIOR TO LOGGING. CONTINUED TO PUMP CRUDE AT 1 BBL/MIN DURING LOGGING. PUMPED A 5 BBL DIESEL FLUSH AT END. SUPPRESSED GAM~A RAY COUNTS ( HIGH SCALE LEVELS ). CHANGED PARAMETER "CSIZ" AT THE SCAB LINER "ON-THE-FLY". THIS FILE CONTAINS BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NA~IE SERV UNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS3 CU 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS3 PU 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 27 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUAIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... SBHF PS3 CU 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 SBHNPS3 CU 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS3 CU 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS3 CU 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS3 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS3 CU 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 TCAFPS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 TCNDPS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 TCFDPS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 INNDPS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PS3 CPS 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS3 V 1102767 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10480.000 SIGM. PS3 23.907 TPHI.PS3 50.789 SBHF. PS3 SBHN. PS3 36.153 SIGC. PS3 0.000 SIBH. PS3 36.153 TRAT. PS3 SDSI.PS3 1.218 BACK. PS3 358.495 FBAC. PS3 494.433 TCAN. PS3 TCAF. PS3 9509.953 TCND.PS3 22849.219 TCFD.PS3 5954.637 TSCN. PS3 TSCF. PS3 1986.050 INND.PS3 2029.510 INFD.PS3 361.982 TENS.PS3 GR.PS3 4484.000 CCL.PS3 0.000 DEPT. 10155.000 SIGM. PS3 53.962 TPHI.PS3 98.863 SBHF. PS3 SBHN. PS3 67.570 SIGC. PS3 0.000 SIBH. PS3 99.475 TRAT. PS3 SDSI.PS3 2.546 BACK. PS3 453.607 FBAC. PS3 810.173 TCAN. PS3 TCAF. PS3 1642.406 TCND.PS3 8836.688 TCFD.PS3 265.642 TSCN. PS3 TSCF. PS3 0.000 INND.PS3 1938.427 INFD.PS3 192.479 TENS.PS3 GR.PS3 8600.000 CCL.PS3 0.000 35.005 2.157 31449.637 6567.912 1385.000 80.641 3.571 12293.467 440.063 1345.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 28 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .009 SERVICE : FLIC VERSION . O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUAIBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCPd~4ENT: 0.5000 FILE SUFmLARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10549.5 10156.5 TDTP LOG HEADER DATA DATE LOGGED: 08-MAR-98 SOFTWARE VERSION: CP 44.2 TIME LOGGER ON BOTTOM: 304 08-MAR-98 TD DRILLER (FT) : 10538.0 TD LOGGER (FT) : 1053 O. 0 TOP LOG INTERVAL (FT) : 10158.0 BOTTOM LOG INTERVAL (FT) : 10516. 0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAM~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUM~ER ........... CGRS-A 971 TDT-P SET 21 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 29 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10778.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : DEAD CRUDE 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FA~ COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS PRODUCTION PROFILE LOG DATED 25-JULY-199 LOGGED ON SANDSTONE MATRIX. TAGGED TD AT 10530 FT md PUMPED 240 BBLS CRUDE PRIOR TO LOGGING. CONTINUF~ TO PUMP CRUDE AT 1 BBL/MIN DURING LOGGING. PUMPED A 5 BBL DIESEL FLUSH AT END. SUPPRESSED GAM~A RAY COUNTS ( HIGH SCALE LEVELS ). CHANGED PARAMETER "CSIZ" AT THE SCAB LINER "ON-THE-FLY". THIS FILE CONTAINS BASE PASS #4. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 3O TYPE REPR CODE VALUE 0.5 FT 11 3 73 88 4 66 1 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS4 CU 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS4 PU 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS4 CU 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 SBHNPS4 CU 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS4 CU 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS4 CU 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS4 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS4 CU 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 TCANPS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 TCAFPS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 INND PS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS4 CPS 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS4 V 1102767 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 10480.000 SIGM. PS4 21.743 TPHI.PS4 46.174 SBHF. PS4 SBHN. PS4 39.333 SIGC. PS4 1.078 SIBH. PS4 39.333 TRAT. PS4 SDSI.PS4 1.027 BACK. PS4 341.600 FBAC. PS4 452.607 TCAN. PS4 TCAF. PS4 10752.111 TCND.PS4 25013.184 TCFD.PS4 7046.767 TSCN. PS4 28.840 2.112 32931.813 6905.805 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 16:07 PAGE: 31 TSCF. PS4 2254.719 INND.PS4 2088.572 GR.PS4 4516.000 CCL.PS4 0.000 DEPT. 10156.500 SIGM. PS4 SBHN. PS4 70.540 SIGC.PS4 SDSI.PS4 2.816 BACK. PS4 TCAF. PS4 1531.167 TCND.PS4 TSCF. PS4 0.000 INND.PS4 GR.PS4 8648.000 CCL.PS4 INFD.PS4 51.675 TPHI.PS4 0.000 SIBH. PS4 454.549 FBAC. PS4 8634.695 TCFD.PS4 1790.615 INFD.PS4 0.000 368.137 TENS. PS4 91.823 SBHF. PS4 106.212 TRAT. PS4 828.237 TCAN. PS4 8.901 TSClV. PS4 191.179 TENS.PS4 1430.000 95. 013 4. 271 12152. 523 491.118 1385. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 98/07/28 ORIGIN : FLIC TAPE NAM~ : 98374 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, D.S. 12-29, PRUDHOE BAY, 50-029-21087-00 **** REEL TRAILER **** SERVICE NAF1E : EDIT DATE : 98/07/28 ORIGIN : FLIC REEL NAME : 98374 CONTINUATION # : PREVIOUS REEL : COM~ : ARCO ALASKA INC, D.S. 12-29, PRUDHOE BAY, 50-029-21087-00 COMPUTER PROCESSED D~REC'T LOGGING R£C£1VED JUN ~! 0 19B6 'Al~sl~ Oit & Gas Cons. Commisslo~ Anchorage ANALYSIS Companp ARCO ~L~._,KA INC F'ield PRUDHOE BAY .... ' 0 !5 - 0 5 - 8 6 DATE OF JOb: C:ount.,.~., NORTH ~LEFE State ALASKA Countp?.,, liSA CLIENT F ORMA T DATA TAPE LOG INFORMATION STANDARD FORMAT ( L , I , S, ) Well No,' ARCO l'~-°g 0~00.00 to 1 05'7'1, O0 Name: DS 12-29 CH/CNS Field: PRUDHOE BAY DATE OF dOB: 05-05-86 Date, !t ,tL.~NE, l'ime:: 1 0:27 AM IdED, Page: 1 L, I, S, TAPE RECORDS HEADER RECORDS P .s g m '2 Date: 8.,:,, u6., ii Or. igin: Re:mt name: Cor~'bin.uation 4~; Oi Previous tmpm: Dat.~: 86,"06/'ii Or'igin: Tape. namCz: g,S..,~8,' Con'l;inuat. ion ~; O1 Ill 8 i'~ t $ I : :+: E 0 F * :~ :+: : ~,~-~. ~ ~ FiLE HEADER Fiim name] &G5FOi , Haximum lmngth: 1024 HEADER RECORDS File: t, ppm: LO Pr.e~.~ i ous .F'i Datm: Pagm l N F O R H A T 1, F._iN_ R E C O R D M N E M CN WN FN COUN CTRY SEC T TOWN RANG EKB LMF DMF RUN LCC LUN FL LUL. EN~ i WITN DL ~Li TC~ TL~B BHT H '~S ~. I1 RFiF HFST HFSS RMC MCST MCSS C 0 N T E N T o UNiT ARCO AL. ASKA INC, DS l 2'-29 CH/CNS PRUDHOE BAY DATE OF NORTH SLOPE ALASKA USA i7 i -0 N I5E ................. 71 , 000 ......... , , , , ?0. 000 ........... , , 4I , 000 .................. KB ...... ' ~Cl ........................... ~63687 ....... ~ ....... ,'~lJo , , , , , , , , , , , , , NORTH SLOP~ NORTH SLOPE ROEDER FIFE i 0546 O00 ~05~9 ,00 O i0200 :0.00 i 8548 ,000 O,::OOO , , , O, OOO ,,, 0, :0 O O . . . 0.000 ,.. CRUDE JOB FT FT FT ;141111Ifl ~11111111 .......... FT .............................. HR D E b F DEGF ,Iltlll,l,lIllI lllI:IIlIl I i CP OHNM 0 H I"i DEGF 0 H bi H DEGF ;l;latll IiIllIIl ililllll iiiillllll iiiiiiiiii GIiiiiIIii .000 ........................ O00 ........................ 000 ........................ alii Izrl Illl ll/IIlllIlIIlllIlIIlllIlllI IlaaIIallI iI~lIlllll Iici O0 llIIIlllIIIIIllllllllllllllfIIllIIItlIIIl'llillIII 0 000 ................................................... TYPE CAI'G 0 0 0 0 0 0 0 0 0 0 0 0 '0 0 0 0 '0 0 0 0 ..-z 0 .]: 0 0 -' 0 .7, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 0 0 0 2 0 '2 0 ':,.' 0 '-2 0 2 0 2 0 2 o IZE C: 0 D E C C) t'"1M E N T R E C 0 R D S This LIS t. apm was writ. ten by, Gmarhart Industrims klir.~:lin~ All cur. ve~ and tool mnmmonics usmd arm '~.hosm ~,~hich most G~.mrhar-'~. cur'v~ mhd tool mnemonics, ') GEARHART TO SCHLUMBERGER biNEM SERVICE UNIT MNEH SERVICE UNiT DEPTH FEET DEPT FT GR MERGE GAP I GR MERGE GAPI CCL MERGE f'lV CCi,. MERGE NV FCNL HERGE CPS FCNL MERGE CP'=~, NCNL MERGE CPS NCNL MERGE ~ ~'" NPHS COMPUTED SSPU NPHI COHPUT RU ~ i RAT [.OHP~ TED NRAT COMPUT AVG COMF'UTED AVG COJ"tF'U T F' .:z~ g e DATA ENTRY :~,'.E::~ ENTRY BLOCK LEGEND TYPE DESCRIPTION )--- ,0 T¢~r. minator, ( no more mntr F 0 R M A T SPECIFICA T Y P E S I ,~. E C 0 D E 0 't 66 TION,* :~ * * D A T U M .S P E C i F i C; A T i 0 N 8 L 0 C K S :~ :~. ** SERVICE SERVICE APl API AP HNEH ID ORDER ~ UNIT LH~_~ TYPF_' CLA DEPT S6.3687 Fl' 0 0 GR MERGE 363687 GAP I .0 5'.$ CCL MERGE 36S68'?" MV 0 i 5 0 FCNt... MERGE S6:$687 CPS 0 78 NC:NL MERGE ~6S687 :CPS 0 78 NF'H I COMPUT 367.4687 PU 0 1 ~': A T COHPUT .36C~687 ........ 0 0 ~G C. OMPUT ~ 6 ~ 6,,'P.,7 ...........0 0 I SS APl M 0 [:, '* P' E ,C I F I CAT IONS FILE PRC ~ SIZE LVL SMPL RC 4 0 i 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 i 68 PROC:ESS INDtCA" 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO0 DEPT GR CCL DA FCNL RECORDS NCNL NPHI NRAT AVG; Pmgm 8 0569,000 10469. 000 10369,000 I0269,000 O. 000 ~8,,400 29,700 67.700 0.000 ,520 1.170 .9S0 0,000 47i, 700 952,000 O, 000 526.100 784.7" 00 865,000 22,670 24,940 i8,889 i5.339 -999,250 1,199 034 ,900 i4,5i 4 24.9 05 I 8,787 i3,8ii FiLE TRAILER **** File Maximum lmngth: 1'024 T R A I L E R RECORDS Film typ,m: LO Nmxt ~i imt D.nt~: P.~gm EOF *** FILE HEADER ***~ Maximum length: 10'24 HEAD ER RECORD""" Se:r. vicm nature: Dar. m: File tppm: LO Prmvious ¢iim: P .=J ~..q,. E"' t 0 H N E M CN WN FlY COUN STAT CTRY SECT TOWN RANG EK8 E.E.~ F L. I"1F' DMF RI. JN LCC SON L U l',i FL LUL ENGI W I'f'N DD Di,,~ TLI BL.t TCS I"LAB BH T MRT N T RH F HFST M F S S RMC M C S T MCSS I NFORMAT I ON RECORDS CONTENTS UNIT ARCO ALASKA INC. DS t 2-29 CH/CNS PRUDHOE BAY NORTH SI_OPE ALASKA USA 17. .... iON,,. 15E. , , 71.0.00 70,0 00 4 t . 0:00 MS .... I~ i i I I i 36~687 7'2 08 NORTH SLOPE NORTH SLOPE ROEDER FIFE ~ 0546 t0549 :i 020 0 i ,(;548 0, O 00 0, '000 0, O00 0, 000 CRUDE 6: O. 0, DA"FE OF' JOB '05-05-86 FT F'F . F 'r 000 ............................................... FT 000 ................. 00:0 ................. 000 ................. I%&illtlrllll& 666::: .......... :' 000 ............... 000 ............... O00 .... ' ................... 0.000 ................................................... FT FT FT HR HR DEGF DEGF' CP OHMM OHMM DEGF OHMM DEGF TYPE L,H] .~ CODE P .a g e: 'tl C O M M E ~:,i T R E C O R D S :.~::s 'l"him~ LiS t..----,pa l.~as ,.,~r. it't,'.i.n bp Gear. haft Induztr'ia:z :~:~ All c;ur. va .and tool mnemor, i,z~ u~e~d ar.e tho.~a ~,,hich mc,~t clo~elp m.a'bch ~:~ Gear. ha~c ,=u~"ve .an,~ tc, oi rnnemonic~, ) C~EARHART MNEM ~ERVICE DEPTH ~R! MER~E CCL. i MER~E FCNLi ~ERGE NCNL1 MER~E .NPH:Sl COHPUTED RATi COMPUTED TO SCHLUHE'4ER .-,ER U N I T M N E M F E E T D E F' 'T ~APt C~R HV CCi_.. CPS FCNL L. F ~, N C N L '" SP U~ NPH I NRRT SERVICE UNIT FT HERCE ~APi HER~E ~V HERQE CPS NERVE CPS COMPUT PU COMPUT ....... DATA * · E :'1': :'{': ;~ :~ ~ ENTRY *** ENTRY BLOCK LEGEND TYPE DEscRIPTiON 0 't'~rminato~ ( no mor.~ ~ntries FORMAT oPECIFIvA TYPE SIZE CODE 0 t 66 TIONo iS :~:~ DATUM SPECIFICATION BLOCKS :~:~,:~ oERVlCE APl SERVICE °''' ' Hi',IEi~ ID ORDER St: LIMIT LOC;.' API API API FILE TYPE CLASS MOC', '~ D E P T <7 F-, .7, 6 ~ 7 F T 0 0 GR MERGE 363687 GAP I 0 5"i. COL MERGE 36.~687 MY 0 15.0 FCi',iL I'IERGE ..7636,.97 CPS ' O 78 NCNL MERGE 363687 CPS 0 78 NPHI COMPUT 363687 PU 0 122 ~"' ":"I~ T CONPUT 36 ~ 68 ;"" ....... 0 O ! 0 0 0 i 0 i 0 i 3 i 0 2 0 i 0 0 i ECI F 1 CAT I ON ~L~ PRC ~ SiZE LVL Si'iPL RE: 4 0 i 68 4 O 't 68 4 O i .68 4 0 i 68 4 0 i 68 4 0 i 68 4 O i 68 PROF:ESS iNDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 i4 D E P 1" O A T A R'E "RD GR CCL FCNL NCNL NPHI NRAT P.~ g e 15 1057i ,0.00 0,000 0,000 0,000 0,000 i 047i. 0 O0 1037i,.000 400 ,27'0 723,1~'00 746.200 20. t40 i ,073 1 027i. 000 74, O0 0 .490 1097,800 g'"~' .~o .900 i ~:.', ? ? 8 .9 i 0 TRA ! LER RECORDS Fiie namm~ &GSF01,002 mum lmngt, h: 1 024 Version File t~pe: LO 16 ',* EOF :+:*:~ Film name: ~5F01.00o Maximum length: iO~4 H E A O E R RECORD S Fil~_ tppe: LO Prmvious .F'ilm: Datm: Page i 7 M t.4 E t,i CH i,.tN FN COUN STAT CTR¥ SECT TOWN R A N G EI<B L. M F D M F R U N LCC SON LUN FL LUL EN~ ~ td i T N DD DL TLI BLI T CS 'T'LAB BHT MRT MT RMF MFST MFSS RMC MCST biCSS I NF ORMA T ION RECORDS C 0 N T E H l' S .ARCO ALASKA IHC, DS i 2-29_. CH,.,'CHo PRUDHOE BAY DATE OF' NORTH SLOPE ALASKA USA i 'ON i5E ........ 71 000 ,, 7:0 000 ., 4 i 008 ,, his KB 36:3687 7208 NORTH SLOPE NORTH SLOPE ROEDER FiF.E I 0546 i 0549 1 8280 i 0548 :O, O O 0 0, :080 O, 00 O · 0, :OO 0 CRUDE 0 O0. 0 O0. ,0 000. ~ i m i 0, '.'000 ............... 0, O00 ............... O. 000 ............... JOB: m 05-.05-86 ~ aTm~m~l ilIIi UNIT I'YPE C A T G , CODE P ag e. :I 8 GEA C 0 M M E N T RECORDS :~-:'~ This :LIS tap~ was written b!:.., G~_arhart Indu.-~tr.i~s. wir. al ine Ser. vica~, :~:~ All curve and tool mn~,onics used ar,~ t.h'-~-~ c~.~ ~,,hich most closely match mm gmmrhart curve and toot mnemonics, :.~ ') GEARHART TO SCHLU~iSERGER MNEM SERVICE UN'IT 19NEM SERVICE UNIT DEPTH FEET DEPT FT ~,-,~. MERGE GAP I GR MERGE GAP I CCL2 MERGE MV CCL. MERGE MY FCNL2 MERGE CPS FCNL MERGE L:Pc. NCNL2 MERGE ~Z_.P:~" NCNL MERGE CPS NPHS2 COMPUTED SSPU HPHI COMPUT PU RAT2 COMPUTED NRAT COMPUT ~9 DATA ENTRY 8LOCKS *:~.:~ ENTP, Y F.OR M A TYF'E T SPEC I FI CA olZE t.,U[.. E TION~,' :¢.** EI,ITRY BLOCK LEGEHD T'~,fPE DESCRIPTION 0 Te.rmin.~t. or ( no more mntrims DATA FORMAT ~'::~* DATUM SPECiF'iCAT:iON 81. OCKS m~,~mm SERVICE ,SERVICE AP1 AP1 MNEM ID ORDER ~ ,UNIT .LOG TYPE AP1 APl FILE CLASS MOD ~ DEPT 36~687 FT 0 0 GR MERGE 36568? GAPI 0 54 CCL MERGE ~6~687 MV 0 i5O FCNL MERGE ~6~687 CPS 0 78 NCNL MERGE ~6~687 CPS 0 78 NPHi COMPUT 36~687 PU 0 i22 N~AT COMPUT 36,$68'? ....... O O ) O 0 0 i 0 2 i 0 2 3 i O 2 :.",'::, 0 0 2 2 O 2 0 O 2 SPEC I F I CA T I O.NS PRC ~ SI~E LVL SMPL 4 0 i 68 4 0 i 68 4, 0 I 68 4 0 '1 68 4 0 i 68 PR ....... c.K; [:, UUP-.:.,.. IN iCATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEP]" DATA R E C 0 R [:,~ "~ G R C C L F C: N L N C N L N P H I N R P, T '22 I057},00'0 O,OOt'. 0,000 0,000 0,000 1t4,,t :000 900 64 n 47."-~ 3; 00 ~ 08 900 2 ,, ~=... 0 'l . 205 I 0.3 ? 1 . :0:0 0 r UU .620 7'P t , 8.0 O -' '~- ,_ ,' .;,,S, ..'~ 0 O 19 80 O i 067 1 0'27I , 00'O 75,50O ,650 i'146,2'00 1 012,400 12,7,,=:, ,i, ,9s 0 * * m F I L E T ~, A 'i' L E R * * * * Fils .r. mms~: 8cGSFOl. Maximum lsngth: 1024 TRAILER RECORDS Fils tpps: LO Nex:t -Pite: Date EOF DIR'ECT DI. GITAL LOGGING COMPUTER PROCESSED ANALYSIS Companb, ARCO ALASKA INC. ~ell DS 12-29 Field PRUDHOE BAY Co un t~ ....NP_R~H_ ~_SLO?E. .......................... State ALASKA CL I ENT FORMA'T DATA TAPE LOG INFORMATION STANDARD FORMAT < L , I , S , Time: 11:3i RM THU, L, I, S, TAPE RECORDS ~.** REEL HEADER Service name: &,~5F01 Pr~viou~ re~l: HEADER Data: 84?0.4/26 Origin: RECORDS Rm~l name: Pag~ 2 Continuation #: 01 ~m* TAPE HEADER Date: 84/04/26 Origin: Tapz name: Continuation #: Oi * EOF *:~* FiLE HEADER **** ********************** File name: &GSFOi,OOi Maximum length: 1024 HEADER RECORDS File tppe: LO Version #: Previou,z ~ilm: Date: Pagm MNEM CN WN FN COUN STAT OTRY SECT TOWN r,.~NG EGL PD LMF DMF RUN LCC SON LUN FL LUL ENGi WITN DD DL TLI 8LI TCS TLA8 8HT MVIS RM RMF MFST MFSS RMC MCST MCSS CONTENTS ,i,1. ,.w. ~ 1... ~ .,. ,.1~ ,,I ARCO ALASKA INC, DS 12-29 PRUDHOE BAY NORTH SLOPE ALASKA USA iON ...... 15E ...... 71 O00, . 70 '000, , 41 000. . SL KB 30 28 776 , 76 1 NORTH SLOPE NORTH SLOPE WAITE PENROSE 1 0778,000 ........ I 0779,000 ........ 1 0i64. OOO ........ I 0775,000 ........ 900.000 .......... 1554,000 ......... {82. 000 ....... 182. OOO .......... LIGNOS FLOWLINE 36,000 ............. 1 ,240 .............. {,190 .............. 63. 000 ............. MEAS ....... 2,190 ...... , ....... 55,000 ............. MEAS ....... INFORMATION i. II I I' ir ii ii I tl ,..I m m I m m I I mIr ! ma , ii , ii,.~ IIii i i Ii i ii m I mI I m, I ii m II l ~. m I I I I I, Ii , m I I l ! t ~ I m I .I t , II , ii m m i ii i iis m I 1. , , ir i I m m e I I I I I m i I I I m m i ~ m ~ I I I I I I i i l m I m i I I i I I i I I I I I I ~ I i I ~ I m I I I I m m I RECORDS I | i I | I ~ i I ii I , I ii m I m ii ii i. I Im I m si m~ mi ~l ii I ! ma m ii m ii m III ,I ii Iii 41 I iI Ii ii i $e ii i 11 I tI em ,· II Im I II II II IIII Im mi m II II me I II II II i mI II im I It ,I II I II II tI I Im II II I im II ,I ! iI II Iii i II Im I, iiII Ii $, m ii Im mI I i4 I !II I m I ! t ii ii ii m m I m I m I II i I, , II i ii l iiir I , Im iiiI I !1 ii UNIT' TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 2 79 0 0 10 65 0 0 JO 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 4 4 68 DEaF 0 1 4 68 DEGF 0 i 4 68 0 2 20 65 0 2 20 65 CP O 2 4 68 OHMM 0 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHMM 0 2 4 68 DEaF 0 2 4 68 0 2 12 65 Page: COMMENT RECORDS · ~ This LIS tap~ mas written by Gearhart · ~ All curve and tool mnemonics ~uz~d are thoz~ which mozt cloz¢ly match · ~. G~arhart curve and~,tool mncmonicz, GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE" UNIT DEPTH FEET ~EPT FT TEN CDL/CNS MV TENS FDCCNL MV SP DIL/BCS MY SP DILBCS MV GR CDL/CNS GAPI GR FDCCNL GAPI ILD DIL?BCS OHMM ILD DILBCS OHMM ILM DIL/8CS OHMM ILM DILBCS OHMM LLJ DIL/BCS OHMM LI_SU DILBCS OH'MM ..~i CILD DIL?BCS MMHO CILD DILBCS MMHO DELT DIL?SCS US/F DT DILBCS US/F AMPS DIL?SCS MV AMPL DILBCS MV Page DAT~ ENTRY .m.~m ENTRY 8LOCK LEGEND, "t'~PE DESCRIPTION 0 Tmrminator ( no'morm'mntrim~ ) FORMAT SPECIFICATIONS TYPE SIZE CODE 0 t ~6 Pagm DAT FORMAT DATUM SPECIFICATION BLO0~S ~ SERVICE SERVICE MNEM ID ORDER # APl APl API API UNIT LO~ TYPe CLASS MOD DEPT 281776'FT' 0 0 0 0 TENS FDCCNL 281776 MV 42 0 0 0 SP DILBCS' 281776 MV 0 1 0 0 ~R FDCCNL 28i77~PI 42 3! 0 0 ".D DILBCS' 281776 OHMM ,0 12 46 0 DILBCS 281776 OHMM 0 12 44 0 L'LSU DILBCS 28i776 OHMM 0 22 8 0 CtLD DiLBCS 28i776 MMHO 0 68 46 0 DT DILBC$ 281776.,US/F 0 52 32 0 AMP[. DILBCS 281776 NV 0 ~3 3 0 SPEC I F I CA T IONS F IL'E PRC # # SIZE LVL SMPL RC 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 ! 68 0 4 0 1 6.8 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 1 68 0 4 0 I 68 PROOEgS INDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 000000 OOO000 000000 000000 0000'00 000000 .000000 000000 000000 000000 000000 P~ge DATA DEPT TENS SP GR DT Ai'iPL 0798. 000 O. 000 O. 000 O. 000 O. 000 227. 0698. 000 -2. 000 71 . 1'00 23. 300 92. I O0 211 . 200 n.598. 000 13. 000 79. 300 26. 200 95. 700 193.500 10498.000 6.000 85. 500 ' 29.000 87.600 221 .200 t0398. 000 1 . 000 76.500 24. I 0'0 9i .500 192.800 ~..-.-=.~. 000 -6. 000 83. 400 35. 200 90. 400 167. 700 RECORDS ILD ILM LLSU CILD Pagm 8 1 ;538 '1 000,000 1.950 2.312 3.758 512.861 4. 207 5.0.35 8. 147 237'. 684. 32. 434 29. 040 26. 730 30. 832 58.4?9 40. 272 37. 844 17.1 O0 20. 324 2.3.7,58 29. 377 49. 204 10198.000 -3,000 99~308 62.200 80.500 245.700 '19. 011 18 .3'"3~. 1.5 · 631 52 .602 FILE TRAILER Fil~ name: t;GSF01.001 name TRA I LER RECORDS Maximum length: 10~4, File type: LO Next Date: Page FILE HEADER Fi, l~ n~ma: &GSFOI,,O02 Maximum length: ~01~4 HEADER RECORDS Smrvi~~ Film'typm: LO V~r~ion #: Previous ?ilm: Pag~ 10 MN£M WN FN COUN STAT CTRY SECT TOWN ~D LMF DMF RUN LCC SON LUN FL LUL EN6I WITH DL TLI TCS TLAB BHT h6S M¥IS RH RMF MFST MFSS RMC MCST MC$S CONTENTS ARCO.ALASKA DS i2-29 PRUDHOE BAY NORTH SLOPE ALASKA USA iON ......... 15E,, 71 000 ...... 70 000 ..... , 4i 000 ...... 7611 , NORTH SLOPi NORTH SLOPE WAITE PENROSE 10778.000,, 10779,000,, 10164.000,, 10775,000,, 900.000 .... 1554,000,,, 182,000 .... 182,000 LIGNOS FLOWLINE 36,000 ...... 1,240 ....... 1,190 ....... 63,000 MEAS 2,190 ....... 55; 000 ...... INC, IlllI IIiI1 IlIlt IIIII llIII Illlllll Iltll|ll IlllIIlI I|l|lIII IllUlIII lIlIIIlI INFORMATION RECORDS I i i i I I ! 'i i i i i i I i i I i I i i I I i i i I I i' 11 I. I i I I ! ! i' i 1 · i i i I I I $ I i I I I I I I i i i I I I i i I I I I I i I I i · i ! · $ I I I 1 i m i I i i i i I i UNIT FT FT FT i , t i i 1 . FT . F'T . DEGF , ! · CP . OHMM , OH HM , DEGF · , OHMM . DEGF TYPE cATi~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 0 3 0 3 o 3 0 3 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 0 3 0 3 0 3 0 2 0 4 0 1 0 1 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 2 SIZE CODE 40 65 20 65 2O 65 20 65 2 65 2 65 2 65 2 79 2 79 1 0 65 10 65 20 65 20 65 20 65 20 65 4 68 4 68 4 68 20 65 20 65 4 68 12 65 4 68 12. 6,.5 Pag~ 11 COMMENT RECORDS ** This LiS:tape was .written by Gearhart Induztri. ez gireline S~rvicaz, ** All curve and tool mnemonics'used arc those which most closely match ** Gearhart"curve an~,':tool mm~menics, ** ********************************************************************************* ******************************************************************************** GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MHEM SERVi. CE~ UNIT DEPTH FEET DEPT FT CDLi COMPUTED DPHI CNDOi CDL/CH'~B M OOL NPHI FOCCNL PU CH,SS 1 CDL~ IjHS M SAND NPH I FDCCHL PU NCHSl CDL/CNS CPS' HCNL FDCCNL CPS FCNSl CDL/CNS CPS FCNL FDCCHL CPS CNSl CDL/CNS ~ LINE NPH~ FDCCNL PU C LxCUS .V TE S CCUL GR 1 CDL/CNS G~P I GR FDCCNL G~P I ' XCEL1 CDL/CNS IH C~L~ FDCCNL ~H YC~L1 CDLZCNS IH C~L2 FDCCNL FCDL 1 CDL/CNS CPS FFDL FDCCNL CPS NCDL1 CDL/CHS CPS NFDC FDCCNL CPS RHOB 1 CDLZCNS G/CS RHOB FDCCNL GZCS DRH01 CDL/CNS GZC3 DRHO FDCCHL G/C3 Page, 12 DATA m~s~ ENTRY BLOCKS ENTRY ,~PE DESCRIPTION 0 T~rminator ( no mor~ entriez ) FORMAT SPEC I F I CAT I OHS TYPE SiZE CODE 0 1 GG Pmgm DATA FORMAT SPEC I F I CAT IONS DATUM SPECIFICATION BLOCKS SERVICE SERVICE APl MNEM ID ORDER # UNIT LOG APl APl APl FILE TYPE CLASS HOD ~ DEPT 281776 'FT 0 DPH I 281 776 0 NPHI FDCCNL 281776 PU 42 NPHi FDCCNL 281776 PU 42 NCNL FDCCNL 281776 CPS 42 FO~uNL 281776 CPS 42 k;Iz:NL 281776 PU 42 TENS FDCCNL 281776 NV 42 GR FDCCNL 281 776 ,GAPi 42 CALl FDCCNL 281 776 IN 42 CAL2 FDCCNL 281 776 IN 42 FFDL FDOCNL 28i776 CPS 42 NFDC FDCCNL 281776 CPS 42 RHOB FDCCNL 28i776 G/CS 42 DRHO FDCCNL 28!776 127C3 '42 0 0 0 0 0 0 O i 68 i 0 68 3 0 i 0 0 0 0 0 0 i 68 2 0 i 0 0 0 i 3i 0 0 1 2.8 0 0 1 0 0 0 1 0 0 0 i 0 0 0 35 i 0 1 · 39 0 0 1 PRC # SIZE LVL SMPL RC PROCESS INDICATORS 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 ,68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 6,8 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 00000,0 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 0000'00 000000 000000 0000'00 000000 000000 000000 000000 000000 0000,00 000000 O0000O 00'0000 000000 O.O000O 0000'00 000000 000000 000000 000000 000000 0000'00 000000 000000 000000 Pagm 14 RECORDS P.ag,s . 15 DEPT DPH I NPH I NPH I NCNL FCNL NPH I TENS ~R CALI CAL2 FFDL NFDC RHO8 DRHO 0798, OOO 46,305 -1 .663 4,000 O, 000 O, 000 O, 000 O, 000 O. 000 O, 000 O, 000 i5~, 000 140,200 t 10698. 000 27,576 19,826 26,820 :342,400 34:3,`300 22,820 -2,000 2`3,300 8,41 0 8.6.30 518,00,0 508,900 2. 195 , 0:33 t)598,000 26,182 21 ,'948 28,920 ,336,400 325,30:0 24,920 13,000 26,200 9,11 0 9,190 522,900 516,700 2,2i8 , 047 1 0498,000 23,333 19,073. 26,070 3.~7,600 351 ,200 22,070 6,000 29. 000 8,63,3 8,630 429,000 4.80,500 2,265 , O18 1 039:3,000 . 19,879 20,.~92 27,580 342,400 3.34,000 23,580 1 , 000 24. i 00' 8,590 8,~;50 40'0,700 478,1 O0 2,322 , 020 I 0298. 000 26,242 14,285 21 ,280 408,000 45:3,900 t 7,2,90 -6, OOO :35.200 8.560 8,5~,0 501 . 00,0 4,95,000 2.2t7 , 01~. 1 0198,000 18. 000 18.67'i 25,670 3'46,600 355,200 2t .670 -3,000 62,200 8,590 8.7~0 408.900 4'83,400 2,353 · 039 FILE TRAILER Fil~ name: &~,FOJ,O02 Maximum lmngth: 1024 TRAILER RECORDS $~rvic~ name: Fil~ type: LO N~x~ Verzion #: ~ile: Oat~: 16 FILE HEADER Film name: &G~F01,003 Maximum length: I0~4, Film type: LO HEADER RECORDS Previous Page 17 MNEM CN WN FN CO, UN STAT C'fRY SECT TOWN ~.~F EGL LMF DM.F RUN L C C SON LUN FL LUL ENGI WITH DD DL TLI BLI TCS TLAB BHT hss M¥IS RM I4FST MF.S RNC MCST NCSS CONTENTS ARCO ALASKA INC, DS i 2-29 PRUDHOE BAY NORTH SLOPE ALASKA USA iON ............... . 1SE ............... 71 ,000 ............ 70,000,, .. ......... 41 . '080 ............ SL KB ................ I I I I . I $ , , . , 11 I $ I 11 , 30,, 2817?6 7611 NORTH SLOP~ NORTH SLOPE WRITE PENROSE 1 077~. 0 O0 ....... 10779,000 ....... 1 0164,000 ....... 10775,000 ....... 900,000. ........ ~554,000 ........ 182,000 ......... 182,000 ......... L Z GNO FLOWLINE. 36. 000 ............. 1 ,240 .............. ~.190 .............. 63,000 ............. ME~S ....... 2,190 .............. 55. 000 .............. MEAS ....... ;I Ir , a I il I t , i ii , t I ii , Ir e , , , i I. Ir ii i .l I NFORMAT I ON RECORDS s . $ I I I , i I ' I 11 I I I I I ! I e I I I I I I I , I ~ I I UNIT TYPE. CATG' SIZE CODE 0 0 40 65 O 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 2 79 0 0 i 0 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 ~5 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEC, F 0 1 4 68 OEGF 0 1 4 68 0 2 20 65 0 2 20 65 CP 0 2 4 68 OHF1M 0 2 4 68 OlqMM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 Pag~ 18 COMMENT RECORDS This LIS tape was written by Gearhart Indust~-ies gir~line Services. All curve and tool mnemonics 'used are those which most closely match Gearhart curve ~nd'tool mnemonics, ~£ARHART TO SCHLUmBERgER MNEM SERVICE UNIT MNEM SERVICE' UNIT ~R~ ~DL/ONS GAPI ~R FDCONL ~API TEN~ ODL/CNS ~V TENS FD~NL MV Page DATA ENTRY BLOCKS ENTRY ***************************** *** ENTRY BLOCK LEGEND **** .~PE ~E$CRIPTION 0 Terminator ( no mot-~ ~ntri~ ) FORMAT TYPE SIZE SPEC I F I CA CODE TIONS 2O DATA FORMAT mmm DATUM SPECIFICATION 8LOCES ~ SERVICE'SERVICE AP1 APl APl APl FILE MNEH ID ORDER # UNIT'LOG TYPE CLASS MOD # DEPT 281776"FT' 0 0 0 0 0 QR ~Cu~NL 281776 GAPI 4~ 31 O O 2 TENS FDCCNL 281776 ~V 42 0 8 8 2 SPECIFICATIONS PRC # SIZE LVL SMPL RC 4 0 1 68 4 0 1 68 4 O 1 68 PROCESS INDICATORS 000000 000000 000000 000000 000000 OOO000 000000 · 000000 00000'0 Pagm, 21 DATA RECORDS Pag~ 22 DEPT GR TENS I 0214,500 O. 000 -2,000 1'0114,500 68,1 O0 O. 000 10014.500 64,500 O. 000 ~14,500 115,:300 3,000 9814,500 11 ~. 7'00 -3,000 9714,500 70.600 2,000 9614,500 70.400 0,000 9514,500 9,5,1 O0 O, 000 9414,500 95,500 O, 000 9314.500 55,900 0 000 9214 ~114 500 49,200 500 48,500 -2 -2 000 000 9014 500 46.000 0 000 8914 500 48,200 -2 000 8814 500 5'2.600 2 000 87i4 500 57.100 -2.000 8614 500 51,200 0,000 8514 500 50.500 -1,000 DATA DEPT GR TENS 8414 SOO 5;3. 700 -1 ,000 8314 500 6?,800 0.000 82i 4 500 56,800 0.000 ,~_ 1 'i 4 8014 ~0'0 52,300 O, 000 500 58, i O0 -2,000 791 4 500 53,700 3,000 7814 500 51.200 0,000 7'714 500 49.900 1,000 7614 500 30,500 0,000 7514 500 47.600 0,000 7414 .500 47,500 1,000 7314 500 47,100 2.000 721 4 500 34,900 0,000 7114 500 40,900 0,000 7014 500 40. 000 -5. 000 6914 500 23.300 0.000 6814 500 24.700 1.O00 6714 500 30,200 -2,000 DEPT GR TENS 3.000 6514,500 30,90:0 -3,000 64. J4.,500 25,00'0 0,000 ~,.314 ,621 4 , 500 51 . 400 -7,000 500 42,50.0 3,000 6114 500 30,800 4,000 6014 500 33.10'0 -3,000 5914 500 46,400 -2,000 .5814 500 50,400 2.000 5714 500 36,700 8,000 5614 ~14 500 32,400 1 , 000 ,500 44,500 3. 000 5414,500 2;2.400 3,000 5314,500' 45.700 1 , 000 5214.500 30.400 1 . 000 5114.500 3;2.600 O, 000 5014,500 43.800 1 ,000 4914,5,00 18,700 -4,000 DATA RECORDS Page_ 25 DEPT ~R TENS 4014.500 36.200 -3 000 471'4.500 ~ 000 4614.500 42.200 0 000 ~')514. 500 4.3.500 44'~4.500 46,000 0 000 2 000 4314.500 45.500 0 000 .4214..500 45.600 O. 000 4114,500 32,300 -1 , 000 4014.500 43.200 -2. 000 3914.500 33.400 1 . 000 3814.500 47.000 4.000 ~14.500 41.300 0.000 3,314 500 56,000 3,000 500 34.300 -4.000 3414 500 40.700 3.000 3314 500 29.100 -2.000 3214 5O0 48.600 0,000 3114 500 33.900 0,000 DATA R~ECORDS DEPT GR TENS 3014,500 37,60'0 -2,000 Page 26 2914;500 25,800 -1 , 000 2814.500 27.000 2,000 ~714,500 4~,700 0,000 .2614.500 28,200 -2,000 25i4,500 32,400 0,000 FILE TRAILER File name: &G5FO~,00,3 Service namE; TRAILER RECORDS Maximum length: 1024 File t~pm: LO Version'#: Next ¢i le: Date: Pag~ 27 *'EOF Copyright 1987,1988,1989~'~i~990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. Tape Subfile 1 is type: LIS **** REEL HEADER **** 91/ 9/30 01 **** TAPE HEADER **** 91/ 9/30 01 Tape Subfile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD DS 12-29 500292108700 ARCO ALASKA INC 89836 W.R.BARKER J.DETHLEFS 17 10N 15E 71.00 70.00 41.00 OPEN HOLE CASING DRILLER' S CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 0.000 3RD STRING 0.000 PRODUCTION STRING 0.000 CURVE SHIFT DATA - ALL PASSES TO STANDARD BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH CNC 2418 GR 1 1 24-JUL-91 10189.5 10190.0 10191.0 10192.0 10192.5 10193.5 10217.0 10218.0 10222.5 10225.0 10230.0 13.375 2517.0 72.00 9.625 10162.0 47.00 7.000 10778.0 29.00 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH LSN SSN CNRA 10189.5 10189.5 10189.5 10189.5 10190.5 10190.5 10190.5 10190.5 10191.5 10191.5 10191.5 10191.5 10192.0 10192.0 10192.0 10192.0 10193.0 10193.0 10193.0 10193.0 10193.5 10193.5 10193.5 10193.5 10217.5 10217.5 10217.5 10217.5 10218.5 10218.5 10218.5 10218.5 10222.0 10222.0 10222.0 10222.0 10224.5 10224.5 10224.5 10224.5 10230.0 10230.0 10230.0 10230.0 10272.0 10288.5 10293.5 10294.5 10310.0 10349.0 10352.5 10357.0 10364.0 10365.0 10365.5 10366.5 10404.5 10406.0 10421.0 10422.0 10427.5 10454.0 10528.0 10528.5 10530.5 10572.0 10573.0 10676.0 10678.0 $ REMARKS: 1027~2~.0 10272.0 10272.0 1~72.0 10290.0 10290.0 10290.0 10290.0 10295.0 10295.0 10295.0 10295.0 10295.5 10295.5 10295.5 10295.5 10313.5 10313.5 10313.5 10313.5 10351.0 10351.0 10351.0 10351.0 10354.5 10354.5 10354.5 10354.5 10357.5 10357.5 10357.5 10357.5 10364.5 10364.5 10364.5 10364.5 10365.0 10365.0 10365.0 10365.0 10366.0 10366.0 10366.0 10366.0 10367.0 10367.0 10367.0 10367.0 10405.5 10405.5 10405.5 10405.5 10407.0 10407.0 10407.0 10407.0 10421.0 10421.0 10421.0 10421.0 10421.5 10421.5 10421.5 10421.5 10427.0 10427.0 10427.0 10427.0 10454.0 10454.0 10454.0 10454.0 10528.0 10528.0 10528.0 10528.0 10529.0 10529.0 10529.0 10529.0 10531.0 10531.0 10531.0 10531.0 10575.0 10575.0 10575.0 10575.0 10576.0 10576.0 10576.0 10576.0 10674.0 10674.0 10674.0 10674.0 10678.0 10678.0 10678.0 10678.0 CNC TIED INTO B.H.C. SONIC LOG DATED 4/13/84. PERFORATIONS: 10440-10450, 10458-10482, 10492-10502 WELL DATA: 3250 BPD, 14%WATER CUT, 7200 GOR. PUMPED 300 BBLS CRUDE BEFORE STARTING TO LOG, CONTINUED TO PUMP 1 BBL PER MIN. WHILE LOGGING. SITP WAS 450 PSI WHILE LOGGING. $ **** FILE HEADER **** FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 1 START DEPTH 10180.0 STOP DEPTH 10720.0 (MEASURED DEPTH) BASELINE DEPTH CNC in separate files. EQUIVALENT UNSHIFTED DEPTH LSN SSN CNRA 10189.5 10190.0 10189.5 10189.5 10189.5 10189.5 10190.5 10190.5 10190.5 10190.5 10191.0 10192.0 10192.5 10193.5 10217.0 10218.0 10222.5 10225.0 10230.0 10272.0 10288.5 10293.5 10294.5 10310.0 10349.0 10352.5 10357.0 10364.0 10365.0 10365.5 10366.5 10404.5 10406.0 10421.0 10422.0 10427.5 10454.0 10528.0 10528.5 10530.5 10572.0 10573.0 10676.0 10678.0 $ REMARKS: 1019~1"5 10191.5 10191.5 1'~'91.5 10192.0 10192.0 10192.0 10192.0 10193.0 10193.0 10193.0 10193.0 10193.5 10193.5 10193.5 10193.5 10217.5 10217.5 10217.5 10217.5 10218.5 10218.5 10218.5 10218.5 10222.0 10222.0 10222.0 10222.0 10224.5 10224.5 10224.5 10224.5 10230.0 10230.0 10230.0 10230.0 10272.0 10272.0 10272.0 10272.0 10290.0 10290.0 10290.0 10290.0 10295.0 10295.0 10295.0 10295.0 10295.5 10295.5 10295.5 10295.5 10313.5 10313.5 10313.5 10313.5 10351.0 10351.0 10351.0 10351.0 10354.5 10354.5 10354.5 10354.5 10357.5 10357.5 10357.5 10357.5 10364.5 10364.5 10364.5 10364.5 10365.0 10365.0 10365.0 10365.0 10366.0 10366.0 10366.0 10366.0 10367.0 10367.0 10367.0 10367.0 10405.5 10405.5 10405.5 10405.5 10407.0 10407.0 10407.0 10407.0 10421.0 10421.0 10421.0 10421.0 10421.5 10421.5 10421.5 10421.5 10427.0 10427.0 10427.0 10427.0 10454.0 10454.0 10454.0 10454.0 10528.0 10528.0 10528.0 10528.0 10529.0 10529.0 10529.0 10529.0 10531.0 10531.0 10531.0 10531.0 10575.0 10575.0 10575.0 10575.0 10576.0 10576.0 10576.0 10576.0 10674.0 10674.0 10674.0 10674.0 10678.0 10678.0 10678.0 10678.0 CNCi. INP SHIFTED, DEPTH MATCHED CURVES FOR FOLLOWING: GRCH, NPHI , FUCT, NUCT, NRAT AND TENS. $ CN : ARCO ALASKA INC WN : DS 12-29 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Code Samples Units Size Length 1 FUCT 2 GRCH 3 NPHI 4 NRAT 5 NUCT 68 1 CPS 4 4 68 1 GAPI 4 4 68 1 PU-S 4 4 68 1 4 4 68 1 CPS 4 4 6 TENS 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 34 24 Tape File Start Depth = 10735.000000 Tape File End Depth = 10133.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1422 datums Tape Subfile: 2 193 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH 2418 10180.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 2 BASELINE DEPTH CNC0 10720.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH LSN0 SSN0 CNRA 10182.0 10181.5 10183.0 10182.5 10184.0 10183.0 10184.5 10184.5 10186.5 10186.5 10187.5 10187.0 10189.0 10187.5 10190.0 10188.5 10190.5 10189.5 10193.0 10192.0 10210.5 10210.5 10211.0 10211.0 10212.0 10211.5 10214.5 10214.0 10215.0 10215.0 10218.0 10218.0 10219.0 10218.5 10221.5 10221.0 10223.0 10222.0 10224.5 10223.5 10225.0 10224.5 10225.5 10225.0 10237.5 10237.5 10239.0 10239.0 10242.0 10241.0 10249.0 10248.0 10249.5 10249.0 10264.0 10263.5 10264.5 10264.5 10278.0 10278.0 10278.5 10279.0 10281.5 10282.0 10287.5 10288.5 10294.5 10295.5 10295.0 10296.5 10306.0 10307.5 10306.5 10308.5 10181.5 10181.5 10181.5 10182.5 10182.5 10182.5 10183.0 10183.0 10183.0 10184.5 10184.5 10184.5 10186.5 10186.5 10186.5 10187.0 10187.0 10187.0 10187.5 10187.5 10187.5 10188.5 10188.5 10188.5 10189.5 10189.5 10189.5 10192.0 10192.0 10192.0 10210.5 10210.5 10210.5 10211.0 10211.0 10211.0 10211.5 10211.5 10211.5 10214.0 10214.0 10214.0 10215.0 10215.0 10215.0 10218.0 10218.0 10218.0 10218.5 10218.5 10218.5 10221.0 10221.0 10221.0 10222.0 10222.0 10222.0 10223.5 10223.5 10223.5 10224.5 10224.5 10224.5 10225.0 10225.0 10225.0 10237.5 10237.5 10237.5 10239.0 10239.0 10239.0 10241.0 10241.0 10241.0 10248.0 10248.0 10248.0 10249.0 10249.0 10249.0 10263.5 10263.5 10263.5 10264.5 10264.5 10264.5 10278.0 10278.0 10278.0 10279.0 10279.0 10279.0 10282.0 10282.0 10282.0 10288.5 10288.5 10288.5 10295.5 10295.5 10295.5 10296.5 10296.5 10296.5 10307.5 10307.5 10307.5 10308.5 10308.5 10308.5 10307.0 10310.5 10341.0 10342.0 10342.5 10344.5 10346.0 10351.5 10352.5 10354.5 10357.5 10366.0 10366.5 10367.0 10388.0 10413.0 10413.5 10414.5 10429.0 10430.0 10433.5 10434.5 10436.0 10450.0 10452.5 10455.5 10456.0 10457.5 10467.5 10468.5 10470.5 10474.5 10475.5 10478.0 10481.5 10482.0 10499.0 10499.5 10501.0 10522.5 10525.5 10566.0 10588.0 $ REMARKS: 1030~.5 10309.5 10309.5 1~309.5 10313.0 10313.0 10313.0 10313.0 10342.5 10342.5 10342.5 10342.5 10343.5 10343.5 10343.5 10343.5 10344.5 10344.5 10344.5 10344.5 10346.5 10346.5 10346.5 10346.5 10347.0 10347.0 10347.0 10347.0 10352.5 10352.5 10352.5 10352.5 10353.0 10353.0 10353.0 10353.0 10355.0 10355.0 10355.0 10355.0 10357.5 10357.5 10357.5 10357.5 10366.0 10366.0 10366.0 10366.0 10367.0 10367.0 10367.0 10367.0 10367.5 10367.5 10367.5 10367.5 10387.0 10387.0 10387.0 10387.0 10412.0 10412.0 10412.0 10412.0 10413.0 10413.0 10413.0 10413.0 10413.5 10413.5 10413.5 10413.5 10428.0 10428.0 10428.0 10428.0 10428.5 10428.5 10428.5 10428.5 10432.0 10432.0 10432.0 10432.0 10433.5 10433.5 10433.5 10433.5 10435.0 10435.0 10435.0 10435.0 10448.0 10448.0 10448.0 10448.0 10450.5 10450.5 10450.5 10450.5 10454.0 10454.0 10454.0 10454.0 10454.5 10454.5 10454.5 10454.5 10457.5 10457.5 10457.5 10457.5 10467.5 10467.5 10467.5 10467.5 10468.0 10468.0 10468.0 10468.0 10469.5 10469.5 10469.5 10469.5 10473.5 10473.5 10473.5 10473.5 10474.0 10474.0 10474.0 10474.0 10476.5 10476.5 10476.5 10476.5 10480.5 10480.5 10480.5 10480.5 10481.5 10481.5 10481.5 10481.5 10498.5 10498.5 10498.5 10498.5 10499.5 10499.5 10499.5 10499.5 10501.0 10501.0 10501.0 10501.0 10521.5 10521.5 10521.5 10521.5 10524.5 10524.5 10524.5 10524.5 10566.0 10566.0 10566.0 10566.0 10590.5 10590.5 10590.5 10590.5 EDITED, SHIFTED CURVES FROM THE FOLLOWING GRCH, TENS, NPHI, FUCT, NUCT AND NRAT. $ CN : ARCO ALASKA INC WN : DS 12-29 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Code Samples Units 1 FUCT 68 1 CPS 2 GRCH 68 1 GAPI 3 NPHI 68 1 PU-S 4 NRAT 68 1 5 NUCT 68 1 CPS 6 TENS 68 1 LB Size Length 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 28 24 Tape File Start Depth = 10629.000000 Tape File End Depth = 10133.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1174 datums Tape Subfile: 3 139 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 31 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH 2418 10180.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 3 BASELINE DEPTH NPHI 10145.0 10142.5 10152.0 10149.5 10183.0 10183.5 10183.5 10184.0 10185.0 10184.5 10185.5 10186.0 10186.5 10187.0 10190.0 10188.0 10192.0 10192.0 10194.5 10194.5 10207.0 10205.5 10208.0 10206.5 10210.5 10211.0 10221.0 10221.5 10222.0 10222.0 10222.5 10222.5 10223.5 10223.0 10226.0 10225.5 10226.5 10226.5 10228.5 10228.5 10243.0 10242.5 10247.5 10247.0 10248.0 10248.0 10257.0 10257.0 10261.5 10261.0 10262.0 10261.5 10269.0 10269.5 10270.0 10270.0 10270.5 10271.0 10272.0 10272.5 10277.0 10278.5 10281.5 10283.0 10282.0 10284.0 10283.0 10284.5 10289.5 10291.0 10290.0 10292.0 10291.0 10292.5 10720.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH FUCT NUCT NRAT 10142.5 10142.5 10142.5 10149.5 10149.5 10149.5 10183.5 10183.5 10183.5 10184.0 10184.0 10184.0 10184.5 10184.5 10184.5 10186.0 10186.0 10186.0 10187.0 10187.0 10187.0 10188.0 10188.0 10188.0 10192.0 10192.0 10192.0 10194.5 10194.5 10194.5 10205.5 10205.5 10205.5 10206.5 10206.5 10206.5 10211.0 10211.0 10211.0 10221.5 10221.5 10221.5 10222.0 10222.0 10222.0 10222.5 10222.5 10222.5 10223.0 10223.0 10223.0 10225.5 10225.5 10225.5 10226.5 10226.5 10226.5 10228.5 10228.5 10228.5 10242.5 10242.5 10242.5 10247.0 10247.0 10247.0 10248.0 10248.0 10248.0 10257.0 10257.0 10257.0 10261.0 10261.0 10261.0 10261.5 10261.5 10261.5 10269.5 10269.5 10269.5 10270.0 10270.0 10270.0 10271.0 10271.0 10271.0 10272.5 10272.5 10272.5 10278.5 10278.5 10278.5 10283.0 10283.0 10283.0 10284.0 10284.0 10284.0 10284.5 10284.5 10284.5 10291.0 10291.0 10291.0 10292.0 10292.0 10292.0 10292.5 10292.5 10292.5 10294.5 10295.0 10302.0 10305.0 10305.5 10306.0 10310.0 10314.0 10315.0 10335.0 10344.0 10345.0 10349.5 10350.0 10352.0 10353.0 10353.5 10357.0 10359.0 10360.0 10360.5 10366.0 10397.5 10398.0 10399.0 10419.0 10419.5 10420.0 10421.0 10429.5 10430.0 10431.0 10432.0 10432.5 10433.5 10435.5 10436.0 10452.0 10454.5 10470.5 10471.0 10473.0 10487.0 10487.5 10489.0 10499.0 10501.5 10502.0 10520.5 10521.0 10524.0 10524.5 10528.0 10552.0 10565.5 10566.0 $ REMARKS: 102'~.0 10296.0 10296.0 10296.0 10298.0 10298.0 10298.0 10298.0 10304.0 10304.0 10304.0 10304.0 10307.0 10307.0 10307.0 10307.0 10309.0 10309.0 10309.0 10309.0 10309.5 10309.5 10309.5 10309.5 10314.0 10314.0 10314.0 10314.0 10317.5 10317.5 10317.5 10317.5 10318.5 10318.5 10318.5 10318.5 10337.5 10337.5 10337.5 10337.5 10346.5 10346.5 10346.5 10346.5 10347.0 10347.0 10347.0 10347.0 10351.5 10351.5 10351.5 10351.5 10352.0 10352.0 10352.0 10352.0 10354.0 10354.0 10354.0 10354.0 10354.5 10354.5 10354.5 10354.5 10355.0 10355.0 10355.0 10355.0 10357.5 10357.5 10357.5 10357.5 10359.5 10359.5 10359.5 10359.5 10360.0 10360.0 10360.0 10360.0 10361.0 10361.0 10361.0 10361.0 10366.5 10366.5 10366.5 10366.5 10399.0 10399.0 10399.0 10399.0 10399.5 10399.5 10399.5 10399.5 10400.0 10400.0 10400.0 10400.0 10420.0 10420.0 10420.0 10420.0 10421.0 10421.0 10421.0 10421.0 10421.5 10421.5 10421.5 10421.5 10422.0 10422.0 10422.0 10422.0 10429.0 10429.0 10429.0 10429.0 10429.5 10429.5 10429.5 10429.5 10430.0 10430.0 10430.0 10430.0 10431.0 10431.0 10431.0 10431.0 10432.0 10432.0 10432.0 10432.0 10432.5 10432.5 10432.5 10432.5 10435.0 10435.0 10435.0 10435.0 10435.5 10435.5 10435.5 10435.5 10452.0 10452.0 10452.0 10452.0 10454.0 10454.0 10454.0 10454.0 10469.5 10469.5 10469.5 10469.5 10470.0 10470.0 10470.0 10470.0 10473.0 10473.0 10473.0 10473.0 10487.0 10487.0 10487.0 10487.0 10488.0 10488.0 10488.0 10488.0 10489.5 10489.5 10489.5 10489.5 10499.0 10499.0 10499.0 10499.0 10501.5 10501.5 10501.5 10501.5 10502.5 10502.5 10502.5 10502.5 10521.0 10521.0 10521.0 10521.0 10522.0 10522.0 10522.0 10522.0 10524.0 10524.0 10524.0 10524.0 10524.5 10524.5 10524.5 10524.5 10530.0 10530.0 10530.0 10530.0 10552.0 10552.0 10552.0 10552.0 10566.0 10566.0 10566.0 10566.0 10566.5 10566.5 10566.5 10566.5 EDITED AND SHIFTED DEPTH MATCHED CURVES FROM THE FOLLOWING: GRCH, NPHI, TENS, FUCT, NUCT AND NRAT $ CN : ARCO ALASKA INC WN : DS 12-29 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Code Samples Units Size Length 1 FUCT 2 GRCH 3 NPHI 4 NRAT 5 NUCT 6 TENS 68 1 CPS 4 4 68 1 GAPI 4 4 68 1 PU-S 4 4 68 1 4 4 68 1 CPS 4 4 68 1 LB 4 4 * DATA RECORD (TYPE~ 0) 1014 BYTES * 24 Total Data Records: 28 Tape File Start Depth = 10631.000000 Tape File End Depth = 10135.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2596 datums Tape Subfile' 4 153 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NU1MBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS 2418 $ REMARKS: 1, 2, 3 CN : ARCO ALASKA INC WN : DS 12-29 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Code Samples Units Size Length 1 FUCT 2 GRCH 3 NPHI 4 NRAT 5 NUCT 68 1 CPS 4 4 68 1 GAPI 4 4 68 1 PU-S 4 4 68 1 4 4 68 1 CPS 4 4 * DATA RECORD (TYPE# 0) 1014 BYTES * 2O Total Data Records: 29 Tape File Start Depth = 10735.000000 Tape File End Depth = 10133.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 ~535 datums Tape Subfile: 5 50 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH 2418 10135.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 10735.0 24-JUL-91 FSYS256 REV:G002 VER:4.0 1739 24-JUL-91 10778.0 10721.0 10150.0 10720.0 1800.0 YES TOOL NUMBER 2418 GR $ COMPENSATED NEUTRON GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH (FT) : 2418 1310 0.000 10778.0 0.0 CRUDE 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 0.0 0.0 AMOUNT: GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: TOOL STANDOFF (IN): REMARKS: CN WN FN COUN STAT : ARCO ALASKA INC : DS 12-29 : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.0 0.000 0.000 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Code Samples Units Size Length 1 CCL 68 1 4 4 2 CLSN 68 1 CPS 4 4 3 CN 68 1 PU-L 4 4 4 CNC 68 1 PU-S 4 4 5 CNRA 68 1 4 4 6 CSSN 68 1 CPS 4 4 7 GR 68 1 GAPI 4 4 8 LSN 68 1 CPS 4 4 9 SPD 68 1 F/MN 4 4 10 SSN 68 1 CPS 4 4 11 TEN 68 1 LB 4 4 12 TTEN 68 1 LB 4 4 * DATA RECORD (TYPE# 0) 994 BYTES * 48 Total Data Records: 127 Tape File Start Depth = 10735.000000 Tape File End Depth = 10135.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6546 datums Tape Subfile: 6 199 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 2418 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 10133.0 10629.0 24-JUL-91 FSYS256 REV:G002 VER:4.0 1807 24-JUL-91 10778.0 10721.0 10150.0 10720.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 2418 GR $ COMPENSATED NEUTRON GAMMA RAY TOOL NUMBER 2418 1310 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 10778.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : CRUDE 0.00 0.0 0.0 0 0.0 0.000 0.000 O.O00 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH (FT) : 0.0 0.0 AMOUNT: GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: TOOL STANDOFF (IN) : REMARKS: CN : ARCO ALASKA INC WN : DS 12-29 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.0 0.000 0.000 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Code Samples Units Size Length 1 CCL 68 1 4 4 2 CLSN 68 1 CPS 4 4 3 CN 68 1 PU-L 4 4 4 CNC 68 1 PU-S 4 4 5 CNRA 68 1 4 4 6 CSSN 68 1 CPS 4 4 7 GR 68 1 GAPI 4 4 8 LSN 68 1 CPS 4 4 9 SPD 68 1 F/MN 4 4 10 SSN 68 1 CPS 4 4 11 TEN 68 1 LB 4 4 12 TTEN 68 1 LB 4 4 48 994 BYTES * * DATA RECORD (TYPE# 0) Total Data Records: 105 Tape File Start Depth = 10629.000000 Tape File End Depth = 10133.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5805 datums Tape Subfile: 7 177 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 8 is type: LIS **** FILE HEADER **** FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH 2418 10135.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10631.0 24-JUL-91 FSYS256 REV:G002 VER:4.0 1832 24-JUL-91 10778.0 10721.0 10150.0 10720.0 1800.0 YES TOOL NUMBER TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 2418 GR $ COMPENSATED NEUTRON GAMMARAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): NORMALIZATION WINDOW START DEPTH (FT): 2418 1310 0.000 10778.0 0.0 CRUDE 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 0.0 STOP DEPTH (FT): AMOUNT: GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: TOOL STANDOFF (IN): REMARKS: CN : ARCO ALASKA INC WN : DS 12-29 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.0 0.0 0.0 0.000 0.000 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Code Samples Units Size Length 1 CCL 2 CLSN 3 CN 4 CNC 5 CNRA 6 CSSN 7 GR 8 LSN 9 SPD 10 SSN 11 TEN 12 TTEN 68 1 4 4 68 1 CPS 4 4 68 1 PU-L 4 4 68 1 PU-S 4 4 68 1 4 4 68 1 CPS 4 4 68 1 GAPI 4 4 68 1 CPS 4 4 68 1 F/MN 4 4 68 1 CPS 4 4 68 1 LB 4 4 68 1 LB 4 4 * DATA RECORD (TYPE# 0) 994 BYTES * 48 Total Data Records: 105 Tape File Start Depth = 10631.000000 Tape File End Depth = 10135.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9816 datums Tape Subfile: 8 177 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 9 is type: LIS **** TAPE TRAILER **** 91/ 9/30 01 **** REEL TRAILER **** 91/ 9/30 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 30 SEP 91 4:17a Elapsed execution time = 32.13 seconds. SYSTEM RETURN CODE = 0