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196-149
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. l~" i C{ ~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevefl incent Nathan Lowell Date: 3~1~'" Isl [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMIS N REPOR OF SUNDRY WELL OPERANS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To rill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 196 -149 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 o 50 - 029 - 22703 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 028298 & 034622 P1 - 24 9. Field / Pool(s): 4 Pr udhoe Bay Field / Point McIntyre Pool 10. Present well condition summary Total depth: measured 13080 feet Plugs (measured) None true vertical 9593 feet Junk (measured) None Effective depth: measured 12390 feet Packer: measured 11229&11410 feet true vertical 9140 feet true vertical 8383 & 8502 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20' 110' 110' Surface 3352' 9 -5/8" 3386' 3356' 5750 3090 Intermediate Production 12439' 7" 12470' 9191' 8160 7020 Liner Perforation Depth: Measured Depth: 12030'- 12270' True Vertical Depth: 8908 9063' Tubing (size, grade, measured and true vertical depth): 4 -1/2" x 3 -1/2" x 4 -1/2 ", 9Cr / 13Cr80 / 11456' MD 8532' TVD 12.6# x 9.2# x 12.6# 13Cr Packers and SSSV (type, measured and true vertical depth): 7" x 3 -1/2" HES TNT Packer 11229' MD 8383' TVD 7" x 4 -1/2" Baker Packer 11410' MD 8502' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 'Nov 0 5 7010 Treatment description including volumes used and final pressure: Cut and pull tubing from 11361'. Clean out and run new Chrome tubing. 4 0 oil & Gas Cons, C40,4190 A,mb;ag8 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 1800 1165 Subsequent to operation: 750 650 327 1415 651 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ® Daily Report of Well Operations ^ ® Development ❑ Service ❑ Exploratory ❑ Stratigraphic ® Well Schematic Diagram 15. Well Status Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 5645683 1 WA Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: n . U Phone 564 -4750 Date -q — Sondra Stewman, 564 -4750 Form 10-404 Revised 07/2009 l S �o fl /� Submit Original Only RBDMS NOV 05, TREE;; CMJ WELLHEAD = FMC J M d D RAG P1 -2 4 SAFETY NOTES: ** *4 * & CHROME CHROME ACTUATOR = BAKER C TUBING PLES 7" CHROME CSG" CTD KB. ELEV = 43.3' L 1& L 1 -O 1 LATERAL E ELMDs. BF. ELEV = Kpp 2797' 2223' 4 -12" CAMCO BAL- OSVLN, ID= 3.813" Max Angle = 54" @ 6020' Datum MD - 11931' 1 DatumTVD= 8800' SS GAS LIFT MANDRELS 1 4-t/2" TBG. 12.6 #, 13- CRVAMTOP. 2256'__ _ _ __ ST MD -_ TVD - -DEV -- TYPE - --VLV- __LAT-CH PORT _DATE . 0152 bpf, ID = 3.958" 1 3797 3699 38 MMG DOME RK 16 09/10/10 2 6727 5504 52 MMG DOME RK 16 09/10/10 9 -5/8" CSG, 40 #, L -80 BUTT, ID = 8.835" 3386 3 8267 6489 52 MMG DOME RK 16 09/10/10 4 9716 7406 50 MMG DOME RK 16 09/10/10 7" CSG, 26 #, L-80 BTGM, .0383 bpf, ID = 6.276" 11108 5 11128 8318 49 MMG SO RK 22 09/10/10 11198 -F3 HES X NIP, ID 7 2 - 8 - 17 - 1 Minimum ID = 2.37" @ 11434' 11229 7" X 3 -1/2' HES TNT PKR, ID = 2.949" 3 -1 /2" X 2 -7/8" LINER XO 11265 3 -1/2" HES X NI P, ID = 2.813" 11327 3 -1/2" HES XN NIP, ID = 2.75" 3 -1/2" TBG, 9.2 #, 13CR -85 VAM TOP 11360' 11375 7" X 4 -1/2" UNIQUE O 0087 bpf, ID = 2.992" TBG STUB (08/30/10) 11361' 11410 7" X 4 -1/2" BKR PKR, ID = 3.875" 11433 4 -1/2" HES X NIP, ID = 3.813" - ---4 -- J - j4 - 3 - 3 - 1 - j--F3.770 — B7 DEPLOYMENT SLV, ID = 3.00" 11444' 4-1/2" HES XN NIP, ID = 3.80" (MILLED 03/17/08) (BEHIN P IPE) 4 -1/2" TBG, 12.6 #, 13CR NSCT 11456' I I 11434 3 -112" x 2 -7/8' XO, ID = 2.37" 1. 0152 bpf, ID = 3.958" I 1 I 1 11456 4 -1/2" WLEG, - ID - = - 3 — 958 - D = 3958" I I 11448 SQZ CMT DONUT F/ 11448 -11493 FISH: TOPOF WIRE (10/ 01/10) 11510 MIILLEDTO 3.80 (07/17/08) TOPOFWHIPSTOCK 12040' I MILLOUT WINDOW (P1 -24L1) 12044'-12053 PERFORATION SUMMARY 1 1 I I KOP(P1- 24L1 -01) 12356' REF LOG: GR/LDT /CNL ON 09/23/96 1 1 ANGLE AT TOP PERF: 49" @ 12030' 1 Note: Refer to Production DB for historical perf data 1 I 12261 FISH: 29' SL TOOLS (10/01/10) SIZE SPF INTERVAL Opn /Sqz DATE 1 1 2-7/8" SLTD LNR, 6.16 #, L -80, STL 14750' P1 -241-1 1 1` .0058bpf, ID = 2.441" SLTD 12356 - 14719 C 08/09/08 12356 ALUMINUM BILLET P1- 241-1 -01 11433 -13976 C 08/13/08 SLTD ���` . ----- - - - - -- I -24L 1 P1 -24 N ----- - - - - -- , ? 4 11465 - 11469 S 09/28/96 N \ 3 -3/8" 4 12030 - 12070 C 04/20/97 . 14719 PBTD 2 -7/8" 6 12090 - 12200 C 04/17/98 N N 2 -7/8" 6 12220 - 12270 C 04/17/98 ` ? 4 12264 - 12268 S 09/28/96 `- - - ? 4 12276 - 12280 S 09/28/96 PBTD 13976' PBTD 12390 2 -7/8" SLTD LNR, 6.16 #, L -80, STL 14017' .0058bpf, ID = 2.441" 7" CSG, 29 #, 13 -CR NSCC, .0371 bpf, ID = 6.184" 12470' PI -24L `l - 0 DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNIT 10/03/96 D14 ORIGINAL COMPLETION 10/03/10 JCM/SV FISH (10/01/10) WELL: P1 -24 / L1 & 1-1 -01 08/14/08 NORDIC1 CTD MULTI -LAT (L1&L1 -01) PERMIT No: 1961490 / 2081030 / 2081240 09/04/10 D16 RWO API No: 50- 029 - 22703 -00 / 60 / 61 09/07/10 SV DRLG HO CORRECTIONS SEC 16, T12N, R14E, 1364' FSL & 965' FR 09/23/10 1 RCT /AG GLV GO (09/10/10) 09/27/10 ? /JMD I DRLG DRAFT CORRECTIONS BP Exploration (Alaska) P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 07/20/10 RAN 3.80" CENT, UNABLE TO PASS 1743' SLM. RAN 3.00" S. BAILER; BROKE THRU OBSTRUCTION @ 1743 SLM, UNABLE TO- PASS 1929' SLM. - RECOVERED2 CUP OF HYDRATES. PUMPED 12 BBLS METH DOWN TBG. WORKED FROM 1743' SLM TO 1943' SLM, UNABLE TO GET ANY DEEPER. LRS PUMPED 580 BBLS HOT CRUDE DOWN IA. DRIFTED TO K -VLV IN SVLN @ 2168' SLM W/ 3.805" G.RING, BRUSH, NO PROBLEMS. PULLED 4 -1/2" K -VLV (K314 -A) FROM SVLN @ 2168' SLM/2197' MD. 07/20/10 T /1 /0= 2300/2500/40 Temp= SI Assist wireline pump as directed- Load IA 10 bbls 60/40 MW spear followed with 577 bbls 180* crude down the IA. RD IA & RU TBG, Started pumping 110* crude down TBG 07/21/10 LRS LOADED TBG W/ 220 BBLS OF CRUDE. BRUSHED FROM SURFACE TO X- NIPPLE @ 11 397' SLM/11425' ELMD. SET PX -PLUG IN X- NIPPLE @ 11397' SLM/11425' ELMD. LRS CMITAA 3500 PSI,PASSED. DUMPED 10' OF SLUGGITS @ 11397' SLM. SET 4 1/2" JUNK CATCHER Q 11 378' SLM. ** *WELL LEFT S/I OPER NOTIFIED * ** 07/27/10 ** *WELL S/I ON ARRIVAL ** *(pre rwo) PULLED 4 -1/2" JUNK CATCHER FROM 11,391' SLM. BAILED -4.5 GALS SLUGGITS FROM 11,401' TO 11,406' SLM W/ 3.00" x 10'P-BAILER. PULLED P -PRONG FROM 4 -1/2" PX PLUG BODY @ 11,433' MD. CURRENTLY IN HOLE @ 11,407' SLM W/ 3.00" x 10' PUMP BAILER. 07/28/10 BAILED -2.5 GALS OF SLUGGITS FROM 11,407' TO 11,412' SLM W/ 3" x 10'P-BAILER. RAN 2.25" x 5'P-BAILER W/ SNORKEL BTM TO 11,413' SLM (Metal marks from end cap of blr btm / 1/2 cup of sluggits). PULLED 4 -1/2" PX PLUG BODY: (intact). DRIFTED TUBING TO 12,255' SLM W/ 2.25" CENT S -BLR. (no sample recovered). RAN 2.25" CENT, PETRADAT GAUGES AS PER PROGRAM (see data tab). SET 4 -1/2" WRP AT 11,388'SLM/11,417'MD. 07/28/10 Assist S -Line MIT OA 1000 psi ( RWO prep) SB for SL to set WRP. 07/29/10 T /I /0= 220/350/20 Temp =Sl Assist SL as directed. MIT -OA 1000 psi FAIL, CMIT -TxIA 3500 psi PASS (3rd attempt) (RWO expense) CMIT -TxIA: pumped a total of 12.8 bbls 90* crude down IA to test. 3rd test, 1st 15 min T /IA lost 0/0, 2nd 15 min T /IA lost 0/0, for a total T /IA loss of 0/0 in 30 min. Bled back -9 bbls. MIT - OA: pumped a total of .8 bbls crude down OA to test. 2nd test, 1 st 15 min lost 20 psi, 2nd 15 min lost 20 psi, 3rd 15 min lost 20 psi for a total of 60 psi in 45 min. Bled OAP. S -Line on well on dep. Wing shut swab shut ssv shut master open casing valves open to gauges Final Whps= 320/320/10 07/29/10 * * *CONT WSR FROM 7/28/10 * ** LRS CMIT -TxIA TO 3500 #.(passed after 3 attempts) LRS MIT -OA TO 1000# (failed after 3 attempts). DUMP BAIL 10' OF SLUGGITS ON TOP OF WRP TO 11,376' SLM SET 4.5 JUNK CATCHER AT 11,366' SLM. * * *RDMO,LEFT WELL SHUT IN,PAD OP NOTIFIED * ** 30 -Jul -2010 T /I /0= 600/300/100 Temp =Sl PPPOT-T (PASS) PPPOT -IC (PASS) (Pre RWO) PPPOT -T : RU 2 HP BT onto THA 2000 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4900/ 30 minutes. Bled void to 0 psi, RD test equipment, re- installed Alemite caps. Cycle and torque LDS "ET style" all functioned with no problems, LDS from 7:00 - 9:00 blocked by hydraulic panel needs to be functioned after removal. Page 1 of 8 • i P1 -24 / P1 -24 L1 & P1- 241_1 -01 Well History Date Summary PPPOT -IC : RU 2 HP BT onto IC test void 100 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, cycle and torque LDS "ET style" all functioned with no problems. * ** NOT ALL LDS CYCLED ON TUBING SPOOL * ** 31 -Jul -2010 ** *WELL SHUT -IN ON ARRIVAL * * *(E -LINE JETCUT) INITIAL T /IA/OA = 1350/1450/200 RIH WITH 25.5'x 3.65" TOOLSTRING. CORRELATED TO DOYON 14 TUBING SUMMARY DATED 23- SEP -1996. CUT TUBING AT 11370' W ITH 3.65" POW ERCUTTER: CCL TO CUTTER DEPTH = 8.5", CCL STOP DEPTH = 11361.5'. FINAL VALVE CONFIGURATION: SWAB CLOSED, WING CLOSED, MASTER OPEN, SSV OPEN. RDMO AND HAND OVER TO DSO FINAL T /I /O 1750/1750/0 ** *JOB COMPLETED * ** T /1 /0= 1650/1650/150 Temp =Sl CMIT TAA Passed to 2500 psi (RWO prep) CMIT T/I pressured up to 2500/2500 psi with 3 bbls diesel. T/I lost 100/60 psi in first 15 minutes and 0/20 psi in second 15 minutes. For a total of 100/80 psi in 30 minutes. Bled pressure down until getting gas gas. FW HP's= 1800/1800/300 VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV closed, Master open, IA open, OA open - Well SI 1- Aug -2010 T /1 /0= 1800/1800/120 Temp= SI Circ -Out TAA (Pre RWO) Rigged up to well. While attempting to bleed AL line pressure down flowline of P1 -23 the choke washed out. Currently standing by for Hardline crew to rig jumper line to P1 -20. * ** Job continued on 8 -2 -10 WSR * ** 2- Aug -2010 * ** Job continued from 8 -1 -10 WSR * ** Circ -Out (Pre RWO) Pumped 2 bbls meth, 289 bbls 1% KCL and 297 bbls seawater down Tbg up IA taking returns to flowline of P1 -20. Freeze protect TAA with 66 bbls diesel, U -Tubed for 1 hr. Job transfered to LRS# S -2. T /1 /0= 300/300/0. Circ -out. (RWO prep) MIT -OA * *FAILED ** to 1000 psi. Take over job for LRS Unit 62. (Mechanical issues) Freeze protect flowline on well P1 -20. Pumped 8 bbls of neat methanol to freeze protect P1 -20 flowline. Pumped .8 bbls dsl to pressure up OA. 2nd test 15 min OA lost 40 psi. 30 min OA lost 40 psi. 45 min OA lost 40 psi. Final WHP= 320/380/0 15- Aug -2010 T /I /0= 60/50/30. Temp =Sl. Bleed WHP's to 0 psi. (pre -RWO). T, IA & OA FL's @ surface. No flowline or wellhead scaffolding on this well, drilling scaffold in place. Bled IAP from 50 psi to 0 psi in 1 hour, during IA bleed TP decreased to 0 psi. Bled OAP from 30 psi to 0 psi in 30 minutes, 6 gallons of fluids were returned during IA & OA bleeds. Monitor for 30 minutes during rig down. No change in TP, IAP increased to 0+ & OAP increased to 0+ during monitor. Final W HP's= 0/0 + /0 +. Job Complete. 18- Aug -2010 T /1 /0= SSV /200/0 Temp =Sl Cycle LDS on tubing head Pre rig conducted on 07/30/10 Panel was restricting access on LDS 7:00 to 9:00, cycled and torqued LDS "ET style" all functioned with no problems. 23- Aug -2010 T /1 /0= 20/20/100 Tested Swab (barrier) valve for 5 min. (1208 -1213) 500 psi low /pass -3500 psi for 5 min. (1214 -1219) high /pass; Tested Master (barrier) valve for 5 min. (1224 -1229) low /pass -3500 psi for 5 min. (1231 -1236) high /pass; Tested lubricator to 300 psi low /pass -3500 psi high /pass; Set 4" CIW BPV #105 @ 108" w/1 -1' ext.; Upon completion tested tree cap to 500 psi; Pre Doyon 16 Post -rig 26- Aug -2010 T /I /O = 0/0/0 Verified Barriers, Pressure tested Lubricator - Low: 300 PSI 05:13- 05:18 / Pass High: 3500 PSI 05:21- 05:24 / Pass. Pulled 4- 1/16" CIW "H" BPV # 105 thru tree, 1 -1' ext. used ..... tag @ 111 "..... Doyon 16 moved over well .... no problems. 27- Aug -2010 TWO= 0/0/0 Pressure tested lubricator for 5 min. @ 300 psi low /pass -3500 psi high /pass; Pulled 4" CIW TWC # 256 thru stack, 3 -5' ext. & 1 -5' centralizer used, RKB 27'; Post Doyon 16 BOPE test. 3- Sep -2010 * ** DOYON 16 RIG ASSIST. JOB WAS CANCELLED * ** Page 2 of 8 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 5- Sep -2010 T /I /O= VacNac /0; Pulled 4- 1/16" CIW "H" TWC #286 thru tree for post Doyon 16; 1 -1' ext. used, tagged @ 114 "; No Problems 7- Sep - 2010 Charges for W RP redress - Pulled on 8/31/2010 by Doyon 16 - - - 8- Sep -2010 T /1 /0= 0/0/0. Temp =Sl. Rigged up 6000 psi chart recorder for MIT -IA to 2000 psi & MIT -TBG to 3500 psi, for slickline & LRS. Wound clock and installed new pens on recorder. slickline has control of valve positions. * ** WELL S/I ON ARRIVAL * ** (post rwo) PULL 4 1/2" DUMMY WRDP SSSV FROM 2201' SLM/2223' MD. SET 3 1/2" SLIP STOP CATCHER @ 3916' SLM. PULL RKP -DCR FROM STA #1(3781' SLM/3797' MD) SET RK -DGLV @ STA #1(3797' MD). PULL EMPTY 3 1/2" SLIP STOP CATCHER FROM 3916' SLM. FW HP= 150/150/0 * * * *CONT JOB ON 9- 9 -10 * ** LRS T -98 fluid support 9- Sep -2010 * * * *CONT JOB FROM 9- 8 -10 * ** *(post rwo) MIT -IA TO 2000 #.(PASS). MIT -T TO 3500 #(FAIL) SET 3 1/2" X SEL TEST TOOL @ 11238' SLM/11265' MD, MIT -T TO 3500 #(PASS) PULL RK -DGLV FROM STA #5, 11107' SLM/11128' MD. SET RKP -CIRC GLV IN STA #5,11107 SLM/11128' MD LRS PUMPED KCL PILL, PULL RKP -CIRC GLV FROM STA #5, 11107' SLM/11126' MD PULL RK -DGLV FROM STA #4, 9700' SLM/9716' MD & STA #3, 8250' SLM/8267' MD. T /1 /0= 20/20/0 * * * *CONT JOB FROM 9- 10- 10 * * ** T /I /0= x ( Assist S -Line / MITxT / MITx IA / Spot 9.8 ppg Brine ) MITx IA Passed / Pumped 3.3 bbls diesel down IA to achieve test press of 2000 Psi. IA lost 0 Psi in 1 st 15 min and 20 psi in 2nd 15 min for a total loss of 20 Psi in 30 min test. MITx IA passed per S -Line PE. Rig to TBG. MITxT / Pump 2.1 bbls diesel to achieve a test press of 3500 Psi against TBG Test Plug. TBG lost 100 Psi in 1st 15 Min and 20 Psi in 2nd 15 Min for a total Iss of 120 Psi in 30 Min test. Pumped 5 bbls neat meth, 23 bbls 9.8# inhibited brine, 213 bbls inhibited 1% KCL and a 35 bbl DSL freeze protect down IA, up TBG, taking returns to an open top tank. * *IA & OA valves left open to gagues upon departure, tags hung. ** FWP's= 0/460/100 10- Sep -2010 * * * *CONT JOB FROM 9- 9 -10 * ** *(post rwo) PULL ST #2 RK -DGLV @ 6713'SLM/6727'MD, PULL ST #1 RK -DGLV @ 3781'SLM/3797'MD SET ST #1 RK -LGLV @ 3781'SLM/3797'MD, SET ST #2 RK -LGLV @ 6713'SLM/6727' MD, SET ST #3 RK -LGLV @ 8250'SLM/8267'MD, SET ST #4 RK -LGLV @ 9700'SLM/9716' MD). SET ST #5 RK -OGLV @ 11 10TSLM/1 1 128'MD, PULL 3 1/2" X SEL TEST TOOL FROM 11238' SLM/11265' MD. PULL B &R FROM 11298' SLM. FW HP= 350/220/0 * * * *CONT JOB ON 9- 11- 10 * * ** 11- Sep -2010 * * * *CONT JOB FROM 9- 10 -10 * ** *(post rwo) PULL 3 1/2" RHC PLUG BODY FROM 11300' SLM/11327' MD. DRIFT W/ 2'x 1.50" STEM, 2,25" CENT, 1 3/4" S- BAILER TO 12261' SLM/12288 MD. (LOST OSS & LSS. UNABLE TO GET FREE). DROP & RECOVERED KINLEY CUTTER BAR, CUT @ BKR DEPLOYMENT SLV @ 11,433' MD ( -826' of .125" carbon & 29.5' toolstring left in hole). CURRENTLY GETTING EVERYTHING SET UP TO FISH WIRE & TOOLSTRING ** *JOB IN PROGRESS, CONTINUED ON 9/12/10 WSR * ** T /I /0= 500/140/20 Temp =S /I Assist slickline pump as directed (Post -RWO) Pumped 286 bbls crude down the tubing. Final WHP's= 1500/220/20 "Slickline has control of well at departure" Page 3 of 8 • 0 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 09/12/10 ** *WELL S/I ON ARRIVAL"* *(Post RWO) RAN BAITED 3-1/2" BLB, 2.32 BOWEN OVERSHOT BODY TO 11,424' SLM (No marks, unable to get any deeper). RAN BAITED 2 -7/8" BLB, 2.32" BOWEN OVERSHOT BODY TO 11,424' SLM, ABLE TO WORK TO 11,425' SLM. BOWEN OVERSHOT BODY HAD MULTIPLE SCRAPES ON THE SIDE, APPEARS TO BE FROM WIRE. CURRENTLY PUTTING TOGETHER WIRE GRAB, SCRATCHER, AND BRAIDED LINE BRUSH. 09/13/10 MULTIPLE RUNS TRYING TO FISH TOOLSTRING AND WIRE (see log for details). 09/15/10 ** *CONTINUED FROM 9/14/10 WSR * ** (post -rig) MADE MULTIPLE RUNS TO FISH SLICKLINE TOOLSTRING & WIRE (See log for details) RECOVERED --6' OF .125" CARBON WIRE ( -820' remains w/ 29.5' slickline toolstring) TAGGED 2.377" X -OVER @ 11,425' SLM / 11,434' MD W/ 2.50" L.I.B. (Clean impression of liner w/ no wire) ** *JOB IN PROGRESS, CONTINUED ON 9/16/10 WSR * ** 09/15/10 MADE MULTIPLE RUNS TO FISH SLICKLINE TOOLSTRING & WIRE (See log for details). ON LAST RUN W/ WIRE FINDER IT APPEARS THAT WE HAVE MOVED FISH & WIRE UP HOLE TO XN NIPPLE @ 11,319' SLM (11,327' MD). CURRENTLY POOH W/ 2 -7/8" GR (Sheared). 09/16/10 MADE MULTIPLE RUNS TO FISH SLICKLINE TOOLSTRING & WIRE (See log for details). ON LAST RUN W/ WIRE FINDER IT APPEARS THAT WE HAVE MOVED FISH & WIRE UP HOLE TO XN NIPPLE @ 11,319' SLM (11,327' MD). CURRENTLY POOH W/2 -7/8" GR (Sheared). 09/17/10 FREED UP BAIT SUB ASSY FROM 11,326' SLM (Wire finder missing 6 fingers: 3/8" width, 6 -1/2" long each). TAGGED WIRE W/ 2.50" LIB @ 11,333' SLM (Impression of ball of wire). MADE MULTIPLE RUNS TO FISH SLICKLINE TOOLSTRING & WIRE (See log for details). RECOVERED APPROX. 22' OF .125" CARBON WIRE ( -798' remains w/ 29.5' toolstring). CURRENTLY IN HOLE W/ BAITED, BRUSH, SCRATCHER, AND WIRE GRAB @ 11,352' SLM. 09/18/10 MADE MULTIPLE RUNS TO FISH SLICKLINE WIRE & TOOLSTRING (See log for details). RECOVERED -66' OF .125 CARBON WIRE (732' remaining w/ 29.5'- 1 -1/2" toolstring). CURRENTLY IN HOLE @ 11,401' SLM JARRING ON BAITED WIRE GRAB. 09/19/10 MADE MULTIPLE RUNS TO FISH SLICKLINE WIRE & TOOLSTRING (See log for details). RECOVERED -12' OF .125 CARBON WIRE (720' remaining w/ 29.5' x 1 09/21/10 MADE MULTIPLE ATTEMPTS TO FISH SLICKLINE WIRE & TOOLSTRING (See log for details). CURRENTLY POOH W/ 2.50" MAGNET FROM 11,425' SLM. 09/22/10 MADE MULTIPLE ATTEMPTS TO FISH SLICKLINE WIRE & TOOLSTRING (See log for details). TAGGED WIRE W/ 2.25" LIB 0 11,427' SLM (Impression of wire). RAN 2.35" GAUGE RING TO TOP OF WIRE AT 11,427'SLM CURRENTLY JARRING DOWN TO BALL UP WIRE FOR FISHING 09/23/10 MADE MULTIPLE ATTEMPTS TO FISH WIRE AND TOOLSTRING (see log for details) CURRENTLY POOH W/ BAITED 2.35" GAUGE RING. 09/25/10 MADE SEVERAL ATTEMPTS TO FISH WIRE AND TOOL STRING (recovered T of .125" wire for the day) CURRENTLY RIH W/ BAITED 2 PRONG WIRE GRAB. 09/26/10 MADE SEVERAL ATTEMPTS TO FISH WIRE & TOOLSTRING 09/27/10 MADE SEVERAL ATTEPMTS TO FISH WIRE AND TOOLSTRING CURRENTLY ATTEMPTING TO PULL BAITED SPEAR @ 11,510'SLM 09/28/10 MADE MULTIPLE ATTEMPTS TO PULL BAITED SPEAR @ 11,510 W/.125 WIRE CURRENTLY RIGGING UP BRAIDED LINE Page 4 of 8 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 09/29/10 T /I /0= 925/180/80 Assist S -Line (fish tool string) Pump 5 bbls 60/40 meth followed by 20 bbls KCL - Slick Pump 65 bbls dead crude. SD S -line lubricator leaking. Pump 180 bbls 9.9 l brine to kill well. Freeze protect well with 35 bbls crude and 5 bbls 60140 meth cap. Standby for fluid support Pump 198 bbls 9.9 brine followed by 2 bbls dead crude down TBG. Standby for S -Line. WSR continued on 09 -30 -10 * * *CONT WSR FROM 9/28/10 ** *(post rwo) RIGGED UP B /L, LATCHED FISH AT 11,490'SLM, LRS PUMPED 20 BBLS OF KCUSLICKWATER AND 64 BBLS OF CRUDE. GREASE HEAD STARTED LEAKING WHILE PUMPING.( 1 QUART SPILL), SECURED WELL, LRS LOAD AND KILL WELL W/ 180 BBLS OF 9.9# BRINE. ATTEMPT TO BLEED TBG TO 0 #(ONLY ABLE TO BLEED DOWN TO 100 #) LRS LOAD TBG W/ 200 BBLS OF 9.9# BRINE. * * *CONT WSR ON 9/30/10 * ** 09/30/10 ( WSR continued from 09 -29 -10 ) T /I /0= 925/180/80 Assist s -Line ( Fishing Job ) Freeze protect tbg with 40 bbls crude. FWHP's= 1000/120/0 SV/WV /SSV =S /I MV =O IA, OA =OTG * * *CONT WSR FROM 9/29/10 * ** (post rwo) PULLED BAITED SPEAR FROM 11,510'SLM, RECOVERED 11' OF WIRE * ** (APPROX 696' OF WIRE LEFT IN HOLE W/ 29.5'x 1 -1/2" Slickline Toolstring * ** (fish diagram on file) RIG DOWN.TAG LEFT ON WING VALVE ** *WELL LEFT S /I * ** DSO INSPECTED WELL HEAD PRIOR TO DEPARTURE 10/03/10 ** *WELL S/I ON ARRIVAL ** *(post rwo) LRS DISPLACE I/A 20 BBLS 60/40,122 BBLS CRUDE. SET 4 -1/2" WRDP -2 SSSV @ 2201' SLM (2223' MD) (SER# HBS -603 - 2 SETS STANDARD PACKING - 0 -RINGS IN EACH STACK PERFORM SUCCESSFUL CLOSURE TEST. ** *RELEASE WELL TO PAD OP & DHD TO POP * ** T /1 /0= 75/400/80 Assist Slickline/ Circ IA to crude (post RWO). Pumped 10 bbls 60/40 meth, 122 bbls crude and a 10 bbl 60/40 cap down IA. * *Tags hung, IA & OA valves left open to gauges upon departure, SLB still on location ** FW P's= 600/540/520 10/04/10 T /I /O = 410/450/170 Temp = SI. Slip stream meth into IA (assist OPS with POP). LRS and SL on site upon arrival. Waited for SL to set and test SSSV (finished Q 1200). PO POP well @ 0145. Pumped initial 6 bbl volume of meoh, then began to slip stream methanol @ 1 bbl /hr on the hour. See log for details. Job in progress. 10/05/10 T /l /O = 700/1700/220. Temp = 67 Slip stream meth into IA (assist OPs with POP). Job continued from 10 -4 -10 AWGRS. Continue to monitor well while pumping .5 bbl meoh down IA on the hour. See log for details. Job in progress. 10/06/10 T /I /O = 700/1700/180. Temp = 60 Slip stream meth into IA (assist OPs with POP). Job continued from 10 -5 -10 AWGRS. Continue to monitor well while pumping as directed by operations. See log for details. Job in progress. 10/07/10 T /1 /0 = 700/1700/220. Temp = 70 Slip stream meth into IA (assist OPs with POP). Job continued from 10 -6 -10 AWGRS. Continue to monitor well while pumping .5 bbl meoh down IA on the hour. See log for details. Job in progress. 10/08/10 T /I /O = 540/1620/140. Temp = 64 Slip stream meth into IA (assist OPs with POP). Job continued from 10 -7 -10 AWGRS. Continue to monitor well while pumping .5 bbl meoh down IA on the hour. See log for details. Job in progress. Page 5 of 8 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 10/09/10 T /I /O = 580/1340/20. Temp = 59 *. Slip stream meth into IA (assist OPs with POP). Job continued from 10- 8-10 AWGRS. Continue to monitor well while pumping .5 bbI meoh down IA on the hour. See log for details. Job continuing on night shift. 10/10/10 T /I /O = 720/1480/90. Temp = 62 Slip stream meth into IA (assist OPs with POP). * *Job Continued from 10 -09 -10 WSR ** Pumped 0.5 bbls methanol into IA on the hour until 07:00, continued to monitor well until 16:00. See log for details. Job Complete. Final WHPs= 700/1470/100. SV =C. WV, SSV, MV =O. IA, OA =OTG. NOVP. 10/11/10 T/1/0=700/1450/1 10. Temp =62 *. Monitor IAP & slip stream meth into IA if needed. (assist OP's w /POP). Rig up Tri -plex pump & PT all surface lines to 2700 psi. Pumping .5 bbl meth for 12 hour well test. See Log for details. 10/12/10 T /1 /0= 700/1450/110. Temp =62 *. Monitor IAP, slip stream meth into IA. (assist OP's w /POP). ** Continued from previous days AWGRS. Continued pumping .5 bbls meth per hour, (See log for details). 10/13/10 T /I /O = 650/1540/130. Temp =64. Slip stream meth into IA (Assist OPs with POP) every hour as directed by operator. Continued from previous day's AWGRS. Pumped MEOH into IA @ . 5 bbl /hr, (see log for details). T /l /O = 650/1540/130. Temp =64. Monitor IAP, slip stream meth into IA (assist OP's w/ POP). Continued from previous day's AWGRS. Continued pumping .5 bbl MEOH per hour into IA. 10/14/10 T /I /O = 650/1520/120. Temp =62 Slip stream meth into IA (Assist OPs w /POP). Continued from previous day's AWGRS. Continued pumping MEOH into IA as directed (see log for details). Job Continuing. SV = C. WV, MV & SSV = 0. IA & OA = OTG. NOVP. 10/15/10 T /l /O = 710/1610/130. Temp =64 Slip stream meth into IA (Assist OPs w /POP). Continued from previous day's AWGRS. Continued pumping MEOH into IA as directed 10/16/10 T /I /O = 700/1580/130. Temp =66 Slip stream meth into IA (Assist OPs w /POP). Continued from previous day's AWGRS. Continued pumping MEOH into IA as directed (see log for details). Job shut down for fishing job. Job complete. Final WHPs = 700/1590/130. SV = C. WV, SSV, MV = 0. IA & OA = OTG. NOVP. ***WELL FLOWING ON ARRIVAL ** *(post rwo) LRS F/P FLOWLINE THEN PUMPED 120 BBLS 180* DIESEL FOR HOT TUBING FLUSH. RAN 3.65" BOWEN WIRE FINDER. TAG 4 -1/2" CA. WRDP -2 @ 2205' SLM (No wire encountered). PULLED 4 -1/2" CA. WRDP -2 (s /n = HBS -603, 2 - sets std o -ring pkg stks) FROM 2,223' MD. DRIFT TO 2.75" XN NIPPLE @ 10,327' MD W/ 2.725" BOWEN WIRE FINDER (Flared out to - 2.990 ", No wire encountered). TAG 3 -1/2" x 2.377" X - OVER @ 11,434' MD W/ 2.50" L.I.B. (Impression of clear liner top). ** *JOB IN PROGRESS, CONTINUED ON 10/17/10 WSR * ** T /I /0= 1450/1420/120 Temp = SI , Assist Slickline ( Hot Tubing Flush ) Freeze Protected flowline with 7 bbls neat meth. Pumped 5 bbls of neat and 120 bbls of 180* F diesel down the tubing. Final WHP= 550/1480/480. Slickline rigging up on well at departure. 10/17/10 ** *CONTINUED FROM 10/16/10 WSR ** *(post rwo) RAN 2.00" L.I.B. TO 11,436' SLM ( -10' into liner top, all clear, no impression). RAN 2.31" BOWEN WIRE FINDER TO 11,510' SLM (wire marks -4" up inside finder). RAN 2.00" L.I.B. TO 11,510' SLM (Impression of wire loop on face, wire gouge on side). LAY DOWN SURFACE EQUIPMENT & CRANE DUE TO HIGH WINDS. ** *WELL S/I & SECURED, SWCP 4517 ON WEATHER HOLD * ** * * ** -695' OF .125" CARBON WIRE & 29.5'x 1 -1/2" TOOLSTRING STILL IN HOLE * * ** Page 6 of 8 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 10/19/10 ** *CONTINUED FROM 10/17/10 WSR ** *(post rwo) MADE SEVERAL ATTEMPTS TO FISH SLICKLINE WIRE & TOOLSTRING. TOP OF WIRE Q 11510' SLM - (See tog for details) ** *JOB IN PROGRESS, CONTINUED ON 10/20/10 WSR * ** * * ** -695' OF .125" CARBON WIRE & 29.5'x 1 -1/2" TOOLSTRING STILL IN HOLE * * ** 10/20/10 ** *CONTINUED FROM 10/19/10 WSR ** *(post rwo) MADE MULTIPLE ATTEPMTS TO FISH SLICKLINE WIRE AND TOOLSTRING. RECOVERED -3' OF WIRE, CURRENTLY RIH W/ BAITED SPEAR. 10/21/10 * * *CONT FROM 10/20/10 WSR ** *(post rwo) MADE MULTIPLE ATTEMPTS TO FISH SLICKLINE WIRE AND TOOLSTRING RECOVERED APPROX. 29.5' OF WIRE. CURRENTLY POOH. 10/22/10 * * *CONT WSR FROM 10/21 /1 0***(post rwo) MADE MULTIPLE ATTEMPTS TO FISH SLICKLINE WIRE AND TOOL STRING. RECOVERED - 10' OF WIRE. CURRENTLY JARRING ON BAITED 2.35" GAUGE RING. 10/23/10 * * *CONT WSR FROM 10/22/10 ** *(post rwo) JARRED ON BAITED 2.35" GAUGE RING AT 11,461'SLM ** *LAY DOWN FOR HIGH WINDS * ** 10/24/10 * * *CONT WSR FROM 10- 23 -10 * ** (post rwo) PULLED BAITED 2.35" GAUGE RING FROM 11,470'SLM(recovered 13' of wire). RAN BAITED 2.35" GAUGE RING TO 11,615'SLM.(worked from 11,604'sim to 11,615'sim). CURRENTLY RIH W/ BAITED SPEAR. * * *CONT WSR ON 10/25/10 * ** 10/25/10 * * *CONT WSR FROM 10/24/10 ** *(post rwo) MADE MULTIPLE ATTEMPTS TO FISH WIRE AND TOOLSTRING.(*** APPROX 640' OF WIRE AND 29.5" TOOL STRING. * * *) BRUSHED SSSVLN AT 2201'SLM/2223'MD W/ 4 -1/2" BLB,3.805" GAUGE RING. MADE ONE ATTEMPT TO SET 4 -1/2" WRDP- 2(ser# bws -152) SCSSSV AT 2201'SLM/2223'MD(unable to get c/I and b/I integrity). PUMPED 7 BBLS METH DOWN TBG. CURRENTLY IN HOLE W/ 3.84" NO -GO CENT,2'x1- 7/8 "STEM,4 -1/2" BLB,3.805" GAUGE RING WORKED FROM 740'SLM DOWN TO 1150'SLM * * *CONT WSR ON 10/26/10 * ** 10/26/10 * * *CONT WSR FROM 10/25/10 * ** (post rwo) RAN ASSORTMENT OF GAUGE RINGS FROM 3.84" TO 3.50" TO CLEAR UP HYDRATES / PUMPED 15 BBLS OF METH DRIFT W/ 3.84" NO -GO CENT TO SSSVLN AT 2,201'SLM/2,223'MD. MADE A COUPLE ATTEMPTS TO SET 4 1/2" WRDP -2 SSSV (SER # BWS -152) 2 SET STD PACKING W /O- RINGS. (unable to get c/1 and b/I integrity) PARRAFIN ON FIRST VALVE SO PERFORMED BRUSH & FLUSH TO SSSV NIPPLE WITH 100 BBLS OF 190* CRUDE CURRENTLY PULLING OUT W/ SECOND VALVE * * *CONT WSR ON 10/27/10 * ** T /1 /0= 1400/1400/0 ( Assist s -line w /brush n flush /set sssv /) Pump 2 bbls neat meth spear followed by 100 bbls dead crude @ 190* down TBG to assist S -Line with Brush and Flush. FW HP= 900/1400/200 / S- Line on well @ departure. IA and OA open to gauges. Operator notified. Page 7 of 8 P1 -24 / P1 -24 L1 & P1- 241-1 -01 Well History Date Summary 10/27/10 * * *CONT WSR FROM 10/26/10 * ** (post rwo) PULLED 4 -1/2" WRDP FROM 265'SLM ( packing & O -rings intact/ scarring on valve body from possible - -- shear stock) BRUSHED SSSVLN @ 2201'SLM W/ 4 -1/2" BRUSH, 3.805" GAUGE RING RE -SET 4 -1/2" WRDP -2 SSSV (SER# BWS -153) @ 2201'SLM (unable to gain control line integrity), PULLED SSSV BACK OUT (all pkg & o -rings intact) (pkg stacks measure 36" center to center) PERFOMED B &F ON SSSV NIPPLE @ 2201'SLM WHILE LRS PUMPING 100 BBLS OF 180* DIESEL SET 4 1/2" WRDP -2 (SER # BWS 153) 2 SETS OF STD PACKING W/ O- RINGS. UNABLE TO GET LINE INTEGRITY, PULL VALVE SET 4 1/2" DSSSV (OVERSIZED SANDWICH BOTH STACKS). HELD 5500# AND BLED TO ZERO (pkg stacks measure 40" center to center) SET 4 1/2" DSSSV (STANDARD PACKING) HELD 5500# AND BLED TO ZERO (pkg stacks measure 40" center to center) SET 4 -1/2" WRDP -2 (SER# HKS -42) @ 2,201'SLM/2,223'MD (2 - SETS OF PACKING, UPPER SET STD W/ O -RING, BOTTOM SET 1 PIECE OVERSIZE PKG ON EACH SIDE OF ORING) PERFORM CLOSURE TEST (GOOD TEST) T /1 /0= 1000/1400/20 Assist S -Line Brush and Flush (Post RWO) Pump 100 bbls 180* diesel down tbg. FWHP's= 1400/1400/300 S -line in control of well at LRS departure. 10/31/10 T /1 /0= 1150/1450/160 Temp =Sl Hot to POP (Assist Ops with POP) Pumped 5 bbls neat methanol spear and 117 bbls 180* crude down IA. Turned well over to DHD and DSO to POP. FW HP's= 1320/1080/740 T /1 /0= 1380/1160/150. Temp =Sl. Slip stream Meth into IA (Assist OP's w /POP). ALP =S1 @ casing valve. Pump 5 bbls Meth down IA to start, follow up w/1 bbl /hr (see log for details). Pumped a total of 8 bbls of Meth. Continued on 11 -01 -10 WSR 11/01/10 Continued from 10 -31 -10 WSR TIO= 650/1900/0. Temp =60. Slip stream Meth into IA (Assist OP's WPOP). Continue to pump 1 bbl of meth per /hr (see log for details). 11/03/10 T /1 /0 = 640/1400/2. Temp = 60 AL online. Slip stream Meth into IA (Assist OP's w /POP). Continue to pump 1 bbi of meth per /hr TIO= 560/1420/0 +. Temp =58 *. Slip stream Meth into IA (Assist OP's w /POP). Continue to pump 1 bbl of meth per /hr 11/04/10 ** *Continued from 11 -03 -10 WSR * ** T /I /O = 690/1410/90. Temp = 68 AL online. Slip stream Meth into IA (Assist OP's w /POP). Continue to pump 1 bbl of meth per /hr (see log for details). Pumping operations suspended at 6:00 am due to weather. Well is to be SI by ops. SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. Page 8 of 8 North America AL�iSKA ��' %:Page `of 1 pa ark:�o Common Well Name: P1 -24 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 8/20/2010 End Date: X4- OOPQB -E (500,000.00) Project: Point McIntyre - Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251'9N Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/25/2010 20:00 - 00:00 4.00 MOB P PRE HELD UNANNOUNCED H2S DRILL. -HELD AAR FOR DRILL. -MOB RIG OFF OF P1 -07A AND OVER P -24. -RIG UP MODULES 8/26/2010 00:00 - 02:00 2.00 MOB P PRE O PSI ON IA AND OA -MOB RIG OVER WELL, SPOT AND SHIM RIG. ACCEPT RIG AT 0200 HRS. 02:00 03:30 1.50 RIGU P PRE R/U 2" LINE FROM OA TO CUTTINGS TANK. -RIG UP DOUBLE ANNULAR VALVE. -RIG UP CIRCULATION LINES. -HAVE LADDER REMOVED OFF OF WELL HOUSE NEXT TO BEAVALATOR. -TEST MASTER AND SWAB VALVES TOO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. -BRING ON 9.0 PPG NACL BRINE AND WEIGHT UP TO 9.1 PPG. 03:30 - 07:30 4.00 RIGU P PRE PJSM FOR PULLING BPV. - DSM IS TO WITNESS TESTING OF MASTER AND SWAB VALVES PRIOR TO TESTING THEIR LUBRICATOR. - RETEST MASTER AND SWAB VALVE WITH DSM WITNESS TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. -R /U DSM LUBRICATOR TO TREE AND TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. - CONTINUE TO WEIGHT UP 9.0 PPG BRINE TO 9.1 PPG BRINE. Printed 10114/2010 3:01:20PM North America °ALASKA BP : age nc f3�zera #� ©riumrna`ry Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPOB -E (1,518,000-00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) Printed 10/14/2010 3:02:59PM AOL orth erlca BP- Page 2 0 23 Operation 5umrnary Report Common Well Name: PI-24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING iNC. - - - - - -- UWI: / Lat 070 °23'26.- 303 "3 Long: — -- - 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/26/2010 07 :30 - 10:00 2.50 KILLW P DECOMP HOLD PJSM WITH RIG CREW, CH2MHILL DRIVERS, MI MUD ENGINEER, AND WSL TO DISCUSS WELL KILL CIRCULATION. DISCUSS THE FACT THAT THIS WELL RECENTLY TESTED AT 60 -PPM H2S. WSL POINTED OUT THAT THE CELLAR WINDWALLS NEED TO BE IN THEIR DOWN POSITION TO PREVENT MOISTURE ACCUMULATION FROM THE FOG DAMAGING OR POISONING THE H2S SENSORS IN THE CELLAR- -ONE BEHIND THE BOP AND ONE NEAR THE PITCHER NIPPLE. -0730 TO 0745 -Hrs, REVERSE CIRCULATE 31 -Bbls, 4 -BPM AT 1030 -psi, TO GET THE DIESEL OUT OF THE TUBING, TAKING RETURNS TO THE CUTTINGS TANK. - 0745 -Hrs, REALIGN CIRCULATING MANIFOLD VALVES AND CIRCULATE THE LONG WAY, LEADING WITH A 20 -Bbl SAFE - SURF -O SWEEP 4.25 -BPM AT 1030 -psi. - 0820 -Hrs, 4 -BPM AT 1380 -psi TO 1600 -psi FOR 130 -Bbls. - 0850 -Hrs, 4.25 -BPM, 1110 -psi AT 240 -Bbls PUMPED. RETURNS ARE SMELLY, BUT NOT STRONG. - 0905 -Hrs, 4.25 -BPM, 1120 -psi AT 270 -Bbls PUMPED GET A STRONG ODOR OF H2S AT SHAKERS, BUT NO ALARM. THE SMELL DISSIPATES IN 2 -3- MINUTES. PITWATCHER HAD A HAND -HELD GAS DETECTOR WITH A 10 FOOT SAMPLE LINE THAT HE LEFT IN THE BOTTOM OF THE TROUGH GOING TO THE DRAG CHAIN. IT MEASURED 170- TO-200 -PPM H2S FOR A FEW SECONDS, THEN QUICKLY DROPPED TO 0 -PPM. PITWATCHER WAS OUTSIDE THE SHAKER ROOM. - 0910 -Hrs, SENT 165 -Bbls OF RETURNS TO HYDROCARBON RECYCLE CONTAINING ABOUT 40% DIESEL. - 0930 -Hrs, CONDUCTED UNANNOUNCED H2S DRILL AND EVERYONE MET AT THE UPWIND MUSTER POINT WITHIN 2- MINUTES. WSL OBSERVED THE DRILLER SAFE -OUT THE WELL AND DON AN SCBA. DRILLER ALSO GRABBED THE HAND -HELD GAS DETECTOR. HELD AN AAR IN THE CREW TRAILER WITH EVERYONE ACCOUNTED FOR: THE RIG CREW, TOOLPUSHER, 3 CH2MHILL DRIVERS, MI MUD ENGINEER, 2 ADP STUDENTS, DOYON CASING CREWMAN, AND WSL. FINDINGS: THE SIGN -IN SHEET WAS DOWNWIND IN THE SPOC SHACK - -WE WILL NOW REQUIRE THAT ANYONE THAT NEEDS TO WORK ON THE RIG FOR ANY PERIOD OF TIME MUST SIGN INTO THE SPOC SHACK AND IN THE DRIVER'S CAB SIGN-IN SHEET. PERSONNEL NEWLY ASSIGNED TO ANOTHER POSITION MUST REVIEW THEIR NEW DRILL REQUIREMENTS. - 0950 -Hrs, RESUME CIRCULATING TO GET TO 9 . 1 - ppg - 1000 -Hrs, RETURNS ARE CLEAN 9.1 -ppg NaCl BRINE AFTER CIRCULATING 458 -Bbls. Printed 10/14/2010 3:02:59PM ` orfhAmenca AIRASKA ' BP � page � �fi�3 Opera #ion Summary.Repart 1 _ � �, Common Well Name: PI-24—DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: - DOYON - DRILLING INC. - - UWLJ -Lat: -070 °2326.303 "3 Long: - 0148 °35'01.251 "W Active Datum: ORIG KELLY BUS @ (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 13:30 3.50 KILLW P DECOMP MONITOR WELL AT GAS BUSTER OUTLET AND DRIPS STOP AT 1040 -Hrs. - 1040 -Hrs, R/U TO TEST THE SWAB AND MASTER VALVES TO 3500 -psi, RECORDED ON CHART. SWAB VALVE IS A SOLID TEST. - 1100 -Hrs, TEST MASTER VALVE, BUT IT WON'T HOLD DESPITE THE EARLIER SUCCESSFUL TESTS. - 1130 -Hrs, CALL GREASE CREW TO GREASE THE MASTER VALVE. -1300 -Hrs, GREASE CREW ARRIVED. GREASE MASTER VALVE AND RESUME TESTING THE MASTER VALVE FOR GOOD, CHARTED TEST. 13:30 - 15:30 2.00 WHSUR P DECOMP FMC TECH INSTALL TWC. R/U TO TEST TWC AND RECORD ON CHART. TESTED TO 1000 -psi FROM BELOW FOR A SOLID TEST. RETESTED 5 -TIMES FROM THE TOP TO 3500 -psi DUE TO EXCESS GREASE INSIDE THE VALVE CAVITY AFTER THE GREASE CREW INJECTION. - 1600 -Hrs, FMC TECH BLEED GAS OFF THE 2 -ea 1/4" CONTROL LINES. 15:30 - 18:00 2.50 WHSUR P DECOMP PJSM TO N/D TREE WITH RIG CREW TOOLPUSHER, WSL, RWO /CTD SUPERINTENDENT, AND RWO /CTD TEAM LEADER FROM ANCHORAGE. - 1600 -Hrs, BREAK BOLTS ON ADAPTOR FLANGE AND TREE. - 1630 -Hrs, HOOK UP CHOKE AND KILL LINES. -1 700-Hrs. WD TREE AND ADAPTOR FLANGE. 18:00 - 19:00 1.00 WHSUR P DECOMP TERMINATE CONTROL LINES. -CLEAN UP WELL HEAD. - -TEST FIT HANGER THREADS WITH XO. GOOD TEST AT 6-1/2 TURNS. 19:00 - 22:00 3.00 BOPSUR P DECOMP BREAK 13 -5/8" X 13 -5/8" SPACER SPOOL OF S TACK. - INSTALL 13 -5/8" X 11" SPACER SPOOL ON WELL HEAD. -N /U 4 PREVENTER BOP STACK. 3 -1/2" X 6" VBRS, BLIND SHEAR, MUD CROSS, AND 2 -7/8" X 5" VBRS. -CLEAN AND SERVICE RIG FLOOR. -R/U LINES AND EQUIPMENT TO TEST BOPE. -FILL STACK WITH WATER FOR TESTING BOPE. 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM FOR TESTING BOPE. -TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH. - PERFORM ALL TEST TO BP AND AOGCC oP STANDARDS. frl -ALL TESTS PERFORMED FOR 5 CHARTED MINS. -TEST WITH 4 -1/2" AND 3 -1/2" TEST JOINTS. -TEST WITNESSED BY BP WSL JOHN WILLOUGHBY AND DOYON TOUR PUSHER JERRY HANSEN. Printed 10/14/2010 3:02:59PM arti� America = `ALASKA BP gaga 9f z` Re ort O elration. Sumrnar�`.: r = P Y._ p Common Well Name: PI-24 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor. - DOYON DRILLING INC. - - — UWI:- / - Lat: 070'23'26.303 "3 Long: 0148 °35'01.251'1N Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/27/2010 00:00 - 02:30 2.50 BOPSUR P DECOMP CONTINUE TESTING BOPE. -TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH. - PERFORM ALL TEST TO BP AND AOGCC STANDARDS. -ALL TESTS PERFORMED FOR 5 CHARTED MIN& -TEST WITH 4 -1/2" AND 3 -1/2" TEST JOINTS. -TEST WITNESSED BY BP WSL JOHN WILLOUGHBY AND DOYON TOUR PUSHER JERRY HANSEN. 02:30 - 03:00 0.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. -RD TEST EQUIPMENT. -B /D CHOKE AND KILL LINE. 03:00 03:30 0.50 PULL P DECOMP P/U DUTCH RISER. - RILDS. 03:30 - 06:00 2.50 PULL P DECOMP PJSM FOR PULLING TWC. -R/U DSM LUBRICATOR. -TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. -TEST AT HI PRESSURE FAILED WITH A GLAND LEAK IN THE LUBRICATOR. -0440 Hrs - DSM TIGHTENED LEAKING GLAND. - RETEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. -GOOD TEST. -PULL TWC. LD LUBRICATOR, UD DUTCH RISER. - 0530 -Hrs, P/U LANDING JOINT AND XO AND RIH TO ENGAGE HANGER. FMC TECH BACKOUT ALL LDSs. PULL HANGER FREE WITH 140K -Ibs, CONTINUE PULLING AND THE 4-1/2" TUBING RING PULLS FREE WITH 155K -Ibs. P/U ANOTHER 5' AND PREPARE TO CIRCULATE WELLBORE. 06:00 - 07:30 1.50 PULL P DECOMP CIRCULATE AT 7- 1 /2 -BPM, 800 -psi, TAKING ALL RETURNS ACROSS THE SHAKERS. RETURNS ARE CLEAN AND REMAIN AT 9.1 -ppg. DO NOT SEE ANY DEBRIS OR OIL ACROSS THE SHAKERS DURING THE ENTIRE CIRCULATION OF 375 -Bbls PLUS 50 -Bbls. - 0715 -Hrs, STOP PUMPING TO MONITOR WELL FOR 15- MINUTES. WELL IS DEAD. Printed 10/14/2010 3:02:59PM vit, Arrierlca :ALASKA BP Pa9 ' : ©peratmon Summary.Rep`ort x Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC: - - - - UWI. / Lat: 070'23'26.303"3 Long: -- - 0148 °35'01.251 "W W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 22:00 14.50 PULL P DECOMP PJSM WITH RIG CREW, TOOLPUSHER, FMC TECH, SCHLUMBERGER SPOOLER TECH, AND WSL TO DISCUSS HOW WE WOULD REMOVE THE 2 -ea 1/4" CONTROL LINES. DON'T TRY TO GRAB A FALLING CONTROL LINE AT ANY TIME. DROPPED OBJECTS INCLUDE SMALL PARTS FROM THE TOP DRIVE WHICH WAS INSPECTED DURING THE BOPE TEST. PINCH POINTS ARE EVERYWHERE, ESPECIALLY AROUND THE SPOOLING CONTROL LINES AND THE SWINGING TUBING BEING UD ON THE PIPE SKATE. ALSO DISCUSSED THE FACT THAT THIS IS THE CREW'S LONG DAY, AND REMINDED THE DRILLER TO MAKE SURE THAT THE CREW TAKES APPROPRIATE SAFETY BREAKS. -FLUID ON- BOARD: 355 -Bbls IN THE PITS, 40 -Bbls IN THE PILL PITS, AND 30 -Bbls IN THE TRIP TANK FOR 425 -Bbls OF 9.1 -ppg NaCI BRINE. 0745-Hrs, BREAK OFF AND UD HANGER USING LIFTING CAP WITH CROSSOVER. - 0800 -Hrs, PUMP DRY JOB. R/U SCHLUMBERGER SPOOLER IN FRONT OF IRON ROUGHNECK. - 0830 -Hrs, CUT CONTROL LINES AND R/U TO SPOOLER DRUM. - 0 900 -Hrs START POH AND UD THE 4 -1/2 ". 12 ^6# 13Cr NSCT TUBI - 0940 -Hrs, JT #15 OF 280 - JOINTS PLUS A CUTOFF, 4 -GLMS, A BAL -O SVLN2- CONTROL LINES, AND 62 -ea SS CLAMPS. - 1005 -Hrs, UD JT #24. CONTROL LINES APPEAR TO HAVE PARTED DEEP. SCHLUMBERGER SPOOLER TAKING UP SLACK, SPOOLER CONTINUED TO SPOOL UP WHAT APPEARED TO BE ALL OF THE CONTROL LINE. - 1025 -Hrs, JT #30 UD. -SAW PARAFFIN ON JOINTS 110 THRU 125. -ALL JOINTS AFTER 125 PULLED CLEAN. - 2000 -Hrs, JT 270 UD. -DRAIN STACK AND FISH BANDS OUT OF STACK WITH HOOK ASSY. ON A ROPE. - RECOVERED 9 FULL BANDS AND 2 PARTIAL BANDS (MISSING BAND BUCKLES) FROM STACK. -TOTAL TUBING RECOVERED 280 FULL JOINTS PLUS 1 CUT JOINT AT 10.37' FLARED TO 4 -5/8 ". -TOTAL JEWELRY RECOVERED 1 BAL -0 SVLN, 4 GLMS, 49 STAINLESS STEEL BANDS. - MISSING 13 BANDS AND 2 BAND BUCKLES. -R/D POWER TONGS. -CLEAR AND CLEAN RIG FLOOR. Printed 10/14/2010 3:02:59PM orth America - ALASfA BP Page i�f23: Opera #ron Surnrnary-Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000-00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor. DOYON DRILLING INC. UWI: / Lat: 070 °23'26303 "3 L ong: 0148 °35'01.251 "W _A ctive Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) A 09:26 - 07:30 PULL P DECOMP - 0610 -Hrs, CIRCULATE AT 7- 1 /2 -BPM, 800 -psi. ALL RETURNS ARE BACK TO THE PITS ACROSS THE SHAKERS, THEY STAY CLEAN AND AT 9.1 -ppg. DO NOT SEE ANY DEBRIS OR OIL ACROSS THE SHAKERS FOR A FULL CIRCULATION OF 375 -Bbls PLUS 50 -Bbls. - 0715 -Hrs, STOP PUMPING AND MONITOR WELL FOR 15- MINUTES. WELL IS DEAD. 22:00 00:00 2.00 WHSUR P DECOMP PJSM FOR PULLING PACK OFF WITH WSL, TOUR PUSHER, CREW AND FMC REP. - DISCUSS SAFETY HAZARDS, DROPPED OBJECTS - SUCH AS DROPPING PACK OFF FROM -J -HOOK, WELL CONTROL - MONITORING WELL ONCE PACK OFF IS FREE. - ENSURE OA PRESSURE IS 0. -PICK UP PACK OFF RETRIEVING TOOL AND RIH 25', J -INTO PACK OFF. - BOLDS. -PULL PACK OFF. TAKING 15K TO PULL FREE. - MONITOR WELL - STATIC -UD OLD PACK OFF. -R/U AND RIH WITH NEW 7" STANDARDIZED PACK OFF. -SET PACK OFF 25' IN APPLYING 10K TO SEAT PACK OFF. 8/28/2010 00:00 01:00 1.00 WHSUR P DECOMP PRESSURE TEST PACK OFF TO 80% COLLAPSE PSI. 4200 PSI FOR 30 CHARTED MIN. GOOD TEST. -R/D TEST EQUIPMENT. 01:00 - 01:30 0.50 WHSUR P DECOMP INSTALL WEAR RING. 01:30 - 02:30 1.00 CLEAN P DECOMP PJSM FOR M/U BHA AS FOLLOWS: -6" OD X 4- 9/16" ID DRESS OFF SHOE, 4 -3/4" X 3 -7/8" INNER MILL 2.23, EXTENSIONS, BOOT BASKET, SUB, 7" CSG SCRAPER, BIT SUB, BUMPER SUB, PO SUB, MAGNETS, X0, AND 6 EA 4 -3/4" DC. 02:30 - 14:30 12.00 CLEAN P DECOMP RIH P/U DRILL PIPE FROM PIPE SHED. - 0600 -Hrs, P/U DRILLPIPE JOINT #107. - 0845 -Hrs, P/U JT #156 FOR 5203' OF DRILLPIPE RIH. - 0930 -Hrs, P/U JT #210 FOR 6877' OF DRILLPIPE RIH. - 1115 -Hrs, P/U JT #270, 8737' OF DP IN HOLE. - 1415 -Hrs, P/U JT #320, 10,287' OF DP IN HOLE. RECIPROCATE SCRAPER 4 -TIMES IN 7" CASING FROM 11,127' TO 11,287'. Printed 10/14/2010 3:02:59PM orth America - ,ALASKA BP ragety �. Qpe_ration Summary Report Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor : -DOYON DRILLING INC: UWC / Lat: 070 °23'26 :3033- Long: 0148 °35'01.251 "W Active Datum ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 16:00 1.50 FISH P DECOMP 1430 -Hrs, P/U JT #350 AND GET SLOW PUMP PARAMETERS: #1 - -32 -SPM AT 180 -psi, 39 -SPM AT 340 -psi; #2 - -30 -SPM AT 150 -psi, 40 -SPM AT 470 -psi. TEST LINES FROM PUMP #2 TO 3500 -psi. - 1445 -Hrs, GET PARAMETERS FOR - DRESS -OFF RUN: 5 -BPM AT 720 -psi, 60 -RPM ROT WT OF 170K -Ibs AND FREE TORQUE OF 7K- FT -LBS. - 1455 -Hrs, STOP ROTATING AND REDUCE PUMP TO 3 -BPM AT 240 -psi. SLOWLY RIH AND TAG STUB AT 9' IN ON #350, PLACING THE STUB AT 11,361'. P/U AND RIH TO VERIFY ONE MORE TIME_ - 1500 -Hrs, P/U START ROTATING AND BRING UP TO 60 -RPM, 7K -ft -Ibs TORQUE, AND LEAVE PUMP ON AT 3 -BPM AT 240 -psi. SLOWLY LOWER OVER STUB AND TORQUE STOPS ROTATION. INCREASE PUMP RATE TO 5 -BPM AND 710 - 720 -psi. KICK OUT 20 -Bbl FLOZAN SWEEP. REPEAT P/U AND RIH OVER THE STUB AND BRING TORQUE LIMIT UP TO START MILLING JUNK AROUND THE STUB. CAN SEE TORQUE VARIATIONS AS THE SHOE CONTINUES OVER THE STUB. PRESSURE INCREASES TO 740 -psi AT 5 -BPM. - 1525 -Hrs, CONTINUE MILLING AFTER INSIDE DRESS -OFF MILL CONTACTS THE STUB, BUT MILL OFF —4 -5 ", THEN STOP ROTATING AND P/U OFF STUB SLIGHTLY TO SEE THE PRESSURE DROP OFF TO 690 -psi. EASE DOWN OVER STUB TO STACK OUT ON IT AT 11,361' PLUS A FEW INCHES. - 1530 -Hrs, P/U ABOVE STUB TO VERIFY THAT WE CAN GET BACK OVER IT. SLOWLY RIH AND STACK OUT 1 -2K -Ibs. P/U AND START ROTATING 20 -RPM, PUMP 5 -BPM AT 660 -psi, RIH AND SEE THE STUB BUT SHOE SLIPS OVER. STOP ROTATING AND CONTINUE RIH. START ROTATING TO 60 -RPM WITH 5 -BPM AT 660 -psi AND CONTINUE IN TO PUT THE DRESS -OFF MILL BACK ON THE STUB TO POLISH IT FOR 1 -2 ". P/U AND STOP ROTATING. 16:00 - 17:00 1.00 FISH P DECOMP 1600 -Hrs, PUMP 20 -Bbl FLOZAN SWEEP, 8 -BPM AT 880 -psi. SEE ONLY PARAFFIN BALLS WITH METAL SHAVINGS ACROSS THE SCREENS WHEN THE SWEEP COMES ACROSS. MIX AND PUMP DRY JOB. FLUID ON HAND 425 -Bbls OF 9.1 -ppg NaCl. 17:00 - 20:30 3.50 FISH P DECOMP POH AND S/B DP AND DCs IN DERRICK. POH FROM 11,361' TO 4,248'. Printed 10/14/2010 3:02:59PM orfh'America - ALASKA - B Page 8' if 23 v Operation Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPOB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC - - - - — - UWI / Lat: 070 °23'26.303 "3 Long: -- -- 0148 °35'01.251 "W A Dat ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 21:30 1.00 FISH P DECOMP HELD UNANNOUNCED H2S DRILL WITH TOUR PUSHER, WSL, RIG CREW, BAKER FISHING REP, AND CH2MHILL TRUCK DRIVER. -CREW RESPONDED IN 2 MIN. THE WELL WAS SECURED. -HELD AAR. THE RESPONSE TIME WAS APPROPRIATE, AND ALL HANDS DID A REALLY GOOD JOB. -THE NEED FOR IMPROVEMENT WAS THE WSL FORGOT TO MENTION TO THE NIGHT TRUCK DRIVER TO SIGN INTO THE 1 A DOOR ON THE RIG AND HE SIGNED INTO THE SPOC SHACK. THIS WAS ADDRESSED AND WILL BE BROUGHT UP TO THE TRUCKING PJSM FOR THIS LOCATION AS SPOC SHACK IS ALWAYS DOWN WIND. ALSO ADDRESSED WAS THE NEED FOR A HARMONY IN THE CHANGE OUT OR SAFE AREA OF THE RIG AS THERE IS ONE IN THE SPOC SHACK ON THE OPPOSITE SIDE. THERE WHERE ALSO 2 SIGN IN SHEETS IN THE DOOR 1 A, CAUSING CONFUSION AND ONE WAS ELIMINATED. WE DISCUSSED THE DONNING OF THE SCOTT AIR PACKS, THE NEW HAND ON THE RIG WAS TAKEN IN TOW BY AN EXPERIENCED FLOOR HAND - GREAT JOB. WE ALSO DISCUSSED THE FACT OF WHAT IF WE HAD NON SHEARABLE TOOLS ACROSS THE STACK. 21:30 - 00:00 2.50 FISH P DECOMP POH AND S/B DP AND DC IN DERRICK. -POH FROM 4,248' TO 235'. - MONITOR WELL - STATIC. 8/29/2010 00:00 - 01:00 1.00 FISH P DECOMP UD 7" CSG SCRAPER DRESS OFF BHA. - MARKINGS ON THE MILL SHOWED GOOD INDICATIONS OF MILLING TUBING. - RECOVERED 3 FULL SS BANDS AND 2 BAND CLAMPS. - MAGNETS RECOVERED 1/2 GAL. OF METAL SHAVINGS. 01:00 - 03:00 2.00 FISH P DECOMP PJSM FOR WU JUNK CATCHER BHA: -BULL NOSE, ITCO SPEAR, SPEAR EXTENSION, STOP SUB, XO, SHEAR PIN GUIDE, FOX TUBING, XO, BUMPER SUB, PUMP OUT SUB, DC, XO. -RIH WITH BHA TO 277.01'. 03:00 - 06:30 3.50 FISH P DECOMP RIH W/ DP FROM DERRICK. -RIH FROM 227' TO 11,262' AND STOP TO SLIP AND CUT DRILLING LINE. 06:30 - 07:30 1.00 FISH P DECOMP SLIP AND CUT DRILLING LINE. Printed 10/14/2010 3:02:59PM X Qftfl ArrierlCa °ALASKA - BP f?age 9 of 23 Up'd 1 M Report Common Well Name: PI -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC: - UWI: / Lat: 070'23'26:303'3 Long: 0148 °35'01.251 "W Active Datum: ORI KELLY BU SHING @43.30ft (abov M ean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 09:00 1.50 FISH P DECOMP RESUME RIH TO 11,358' AND GET PARAMETERS: P/U WT 205K -Ibs, S/O WT 150K -Ibs; SLOW PUMP RATES FOR PUMP #1: 3 -BPM AT 590 -psi, 4.5 -BPM AT 1800 -psi. REDUCE RATE TO 3.5 -BPM @ 790 -psi. RIH AND SEE TAG AT 11,361', CONTINUE RIH AND SET 20K -Ibs DOWN TO SHEAR PINS IN SHEAR PIN GUIDE, BUT NO ACTION. P/U AND SLOWLY RIH FOR SAME TAG DEPTH. -P /U ABOVE STUB AND START ROTATING AT 15 -RPM AND RIH AND SLIP DOWN INSIDE THE STUB WITH THE JUNK CATCHER BHA BULLNOSE. STOP ROTATING AND CONTINUE RIH TO SHEAR THE PINS. - 0800 -Hrs, INCREASE PUMP RATE TO 5 -BPM AT 1820 -psi TO CLEAN OFF THE TOP OF THE JUNK CATCHER. STOP PUMPING. CONTINUE RIH AND GET INSIDE THE JUNK CATCHER AT 11,392'. SET DOWN 6K -Ibs WITH BOTTOM OF BULLNOSE AT 11,396'. - 0810 -Hrs, P/U TO 20K -Ibs OVER. SET DOWN TO NEUTRAL AND P/U TO 20K -Ibs OVER. SET DOWN TO NEUTRAL, START PUMP AND BRING UP TO 1.5 -BPM AT 310 -psi AND LOSE THE 20K -Ibs DRAG WHILE P /U. - 0815 -Hrs, BREAK -OFF TOPDRIVE AND S/B STAND IN DERRICK. PULL NEXT STAND WITH ELEVATORS AND SEE SAME 20K -Ibs OVERPULL. M/U TO TOPDRIVE AND BRING ON PUMP TO 1.8 -BPM AT 310 -psi AND OVERPULL DISAPPEARS. BREAK -OFF TOPDRIVE AND S/B STAND IN DERRICK. - 0820 -Hrs, DROP BALUROD TO OPEN THE PUMP -OUT SUB. - 0850 -Hrs, BALL ON SEAT AND PUMP -OUT SUB OPENS WITH 1500-psi 09:00 09:30 0.50 FISH P DECOMP CIRCULATE BOTTOMS UP 8.5 -BPM AT 1440-psi. 09:30 - 14:00 4.50 FISH P DECOMP POH AND S/B DP AND DCs IN DERRICK. - 1330 -Hrs, S/B DCs IN DERRICK. 14:00 - 15:00 1.00 FISH P DECOMP - 1400 -Hrs, B/O AND UD PUMP -OUT SUB AND BUMPER SUB. B/O FIRST JOINT OF 2 -7/8" FOX TUBING. - 1420 -Hrs, B/O AND UD JUNK CATCHER. HAD THE REMAINS OF THE BOTTOM PLUG FROM THE JET CUTTER INSIDE AS WELL AS TWO PIECES OF SS- BANDS. B/O AND UD WASHPIPE EXTENSIONS AND FIND 8- PIECES OF SS BANDS WRAPPED INSIDE NEAR THE SHEAR PIN GUIDE. 15:00 - 16:30 1.50 FISH P DECOMP M/U WRP RETRIEVAL TOOL BHA: WRP RETRIEVAL TOOL, XO, SHEAR PIN GUIDE ASSY, 2 -7/8" FOX TUBING, XO, BUMPER SUB, PUMP OUT SUB, DC, AND X0. -RIH TO 304.09' Printed 10/14/2010 3:02:59PM AML orth America ALASKA - BF Page 2; Operation Summary Report Common Well Name: PI-24—DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000-00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING- INC. - UWI; / -Lat: 070 °23'26.303 "3 Long: - 0148 °35'01.251 "W A Datu : ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 22:30 6.00 FISH P DECOMP RIH WITH DP FROM DERRICK. -RIH FROM 304' TO 11,385'. - OBTAIN PARAMETERS OF UP WT 204K, DOWN WT OF 152K -WITH PUMPS OFF. UP WT OF 200K, DOWN WT OF 152K WITH PUMPS ON AT 3.3 BPM AND 260 PSI. OBTAIN SLOW PUMP RATES OF: PUMP #1 - 30 SPM/ 160 PSI, 40 SPM/ 260 PSI, PUMP #2 - 30 SPM/ 230 PSI, 40 SPM/ 410 PSI RIH TO TOP OF STUB AT 11,361'. SHEAR THE SHEAR OUT SUB AT 1 OK. -R/U AND OBTAIN REVERSE CIRCULATING PARAMETERS OF 5 BPM AND 750 PSI. 22:30 00:00 1.50 FISH P DECOMP PJSM WITH RIG CREW, WSL, TOUR PUSHER, AND BAKER FISHING HAND. -RI AND TAG TOP OF SAND AT 11390' CLOSE BAG AND BEGIN WASHING DOWN TO 11,398'. CIRCULATE A B/U WITH DP VOLUME (150 BBLS). RATE OF 5 BPM AND 770 PSI. SHAKERS HAD GOOD SLUGGITS ON B/U. Printed 10/14/2010 3:02:59PM orth America. ALASKA,- BF?' Pagel I pf:23' Operat>Ib`n Summary Rep, r't Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00 ) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. UWI: / Lat:-07O °23'26:303 "3 Long: 1 0148'35'01.251'W A Da ORI KELLY BU @43.30ft (above Mea Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/30/2010 00:00 - 03:30 3.50 FISH P DECOMP R/U TO CIRCULATE THE LONG WAY. -BRING PUMPS UP TO 9 BPM AND 1980 PSI. -WASH DOWN TO 11404' AND TAKE 8K OF WEIGHT. - MONITOR WELL - WELL STATIC. -P /U AND SEEN NO WT INCREASE. P/U TO 11385' - ATTEMPT TO RIH PAST 11404' TO SEE IF WE HAD PLUG AND COULD NOT GET ANY DEEPER THEN 11,400' STACKING 5K WEIGHT. -P /U AND ATTEMPT AGAIN. AT 11,400' STACKED 10K WEIGHT. -NO LOSSES AND STATIC WELL. CLOSE RAMS AND ATTEMPT TO BULL HEAD TO ENSURE WE HAD THE PLUG. NOT SUCCESSFUL PRESSURED UP TO 580 PSI. SHUT PUMPS DOWN AND PRESSURE HELD. BLEED OFF PRESSURE. -BEGIN WASHING DOWN CIRCULATING AT 3.5 BPM AND 300 PSI. ROTATE PAST 11,400' AND DOWN TO 11,411'. STACK 5K WEIGHT ON PLUG. - ANNULAR VOLUME DROPPED ABOUT 2 BBLS. -P /U TO NEXT TOOL JOINT AT 11,370'.CLOSE THE PIPE RAMS AND BULL HEAD 4 BBLS AWAY AT 80 PSI. WITH GOOD CONFIRMATION WE HAD THE PLUG. WE OPENED UP THE RAMS TO PULL ABOVE THE TUBING STUB AT 11,361'. WHEN WE PULLED AN EXTRA 25K OVERPULL. WORKED NUMEROUS TIMES UP TO 75K OVERPULL AND DOWN TO 10K OVER AND ATTEMPTED WITH PUMPS ON AT 1 BPM AT 590 PSI DOWN THE DP. THE ANNULAR WAS STATIC. CONFIRMED WITH WEATHERFORD THE MAX PULL ON THE PLUG WAS 85K SO WE WORKED PIPE DOWN (SLAPPING THE BUMPER SUB) TO 25K OVER 2 TIMES WHEN WE BECAME FREE. -A TOTAL OF 42 BBLS WAS BULLHEADED WHILE WORKING PIPE. PRESSURE INCREASED FROM 280 PSI TO 590 PSI AT 1 BPM. -P /U TO 11,320' ABOVE THE STUMP. - MONITOR WELL - WELL GAVE BACK 1 BBL OF FLUID. THEN WENT STATIC. -CLOSE RAMS AND BULL HEAD 5 BBLS AT 3 BPM AND 400 PSI AND WHEN PUMPS WHERE TURNED OFF THE PRESSURE BLEED DOWN TO 210 PSI PRIOR TO OPENING THE BLEEDER. A TOTAL OF 47 BBLS WAS BULL HEADED AWAY. - MONITOR WELL - STATIC. -DROP BALL TO OPEN PUMP OUT SUB. Printed 10/14/2010 3:02:59PM AWL ; North America Al -ASKA =BP 12Qf 4peration'Summary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC: - - - - - -- - UWI: / Lat: 070 °2326.303 "3 Long: 0148'35'01.251"W Active Datum ORIG KELLY BUSHIN @ 43.30ft (ab M ean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 04:30 1.00 FISH P DECOMP BREAK CIRCULATION TO CIRCULATE B /U. TAKING 3 BBLS TO FILL HOLE. - CIRCULATE AT 8 BPM WITH 1200 PSI. DYNAMIC LOSS RATE OF 30 BPH. -0345 Hrs - SAW FLOW INCREASE TO 53% WITH A GAINOF 17 BBLS WITHIN 2 MIN. SOME FLUID FROM BUBBLES BURSTING ON TOP OF THE FLUID SURFACE AT THE FLOWLINE �� P SPILLOVER POINT WAS SPLASHED UP ONTO THE ROTARY TABLE, WETTING DOWN THE C p,fe ROTARY BUSHINGS AND A SMALL AREA IN e ,-I FRONT OF THE IRON ROUGHNECK. THERE C ✓�" WAS AN OILY SHEEN ON THE WET AREAS, CLOSED THE UPPER PIPE RAMS. -SHUT IN PRESSURE ON DP - 40 PSI, CSG - 120 PSI. NOTIFICATIONS MADE TO DRILLING SUPERINTENDENT AND TO DAY WSL. -0425 SHUT IN PRESSURES OF 40 PSI DP AND 260 PSI CSG. 04:30 06:30 2.00 FISH P DECOMP PJSM - LINE UP AND CIRCULATE THROUGH CHOKE. -BRING PUMPS ONLINE UP TO 4 BPM/ 380 PSI SLOWLY AND OPEN CHOKE SEEING FLUID RETURNS IN 5 BBLS AT 8.7 PPG. - RETURNS ARE WATER AND CRUDE, TURNING TO CRUDE, THEN WATER 55 BBLS INTO THE CIRCULATION. - 0530 -Hrs, CONTINUE CIRCULATING AND AT 210 -Bbls SEE CRUDE OIL COMING OVER THE SHAKERS WITH 50 -psi CASING PRESSURE AND 440 -psi DRILLPIPE PRESSURE. RETURNS CHANGE TO BRINE WITHIN 8- 10 -Bbls AND WEIGHT OF RETURNING BRINE IS 9.17 -ppg. - 0615 -Hrs, CALL RWO SUPT AND RWO ENGINEER TO KEEP THEM IN THE LOOP ON THE CIRCULATION. GET TO BOTTOMS -UP VOLUME OF 255 -Bbls AND ANOTHER SLUG OF CRUDE OIL COMES ACROSS THE SHAKERS. THE FLUID CLEANS UP TO BRINE IN 5- 6 -Bbls. PUMP A TOTAL OF 350 -Bbls. STOP PUMPING WITH 0 -psi CASING AND 40 -psi DRILLPIPE. BLEED OFF THE DRILLPIPE AND CHECK FOR FLOW AT THE GAS BUSTER OUTLET TO THE POSSUM BELLY. - 0630 -1-Irs, WELL IS DEAD. Printed 10/14/2010 3:02:59PM Pa a 13si #23 orth America - ALASKA BP s„ operation Summary :Report . r Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/412010 - Rig - Contractor: DOYON DRILLING INC: UW:- /_Lat: 070 °23'26:303 "3 Long: - 0148 °35'01.251 "W Active Dat : O KELLY BUSHING @43.30ft (above Mean Sea L evel) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 09:30 3.00 FISH P DECOMP CALL RWO LEAD ENGINEER TO DISCUSS PLAN FORWARD FOR THE WELL KILL. ADVISED TO GO AHEAD AND CIRCULATE THROUGH THE CHOKE AND WAIT ON ORDERS FROM TOWN. - 0645 -Hrs, START PUMPING AT 4 -BPM AND 400 -PSI. CHECK LOSS RATE AND CALCULATE 12 -BPH DURING FIRST 20 -Bbls. PUMPING UNDER CLOSED 3 -1/2" X 6" VBRs. - 0715 -Hrs, FLUID ON BOARD: 335 -Bbls OF 9.1 -ppg NaCI BRINE IN PITS AND A FULL VAC TRUCK OF 290 -Bbls 9.1 -ppg NaCI BRINE ONSITE, WITH ANOTHER FULL LOAD OF 9.2 -ppg (TO BE CUT BACK CONTINGENT ON SI WELL PRESSURES) ON THE WAY. -DO NOT SEE ANY OIL OR DEBRIS ACROSS THE SHAKERS FOR A CIRCULATION OF 293 -Bbls. CALCULATE A DYNAMIC LOSS OF 15:5 -BPH WHILE PUMPING AT 4 -BPM AND 400 -psi. - 0830 -Hrs, STOP PUMPING WITH 0 -psi CASING AND DRILLPIPE PRESSURE BLEEDING OFF TO 40 -psi ALMOST INSTANTANEOUSLY. OPEN BLEEDER AND BLEED OFF DP TO 0 -psi AND MAKE A FLOW CHECK AT THE SHAKERS. OPEN 3 -1/2" X 6" VBRs. FLUID LEVEL IS BELOW THE OPENED VBRs. FILL THE STACK TO THE FLOWLINE SPILLOVER AND PREPARE TO MONITOR THE WELL. - 0850 -Hrs, MONITOR WELL FOR 30- MINUTES AND THE FLUID LEVEL SLOWLY DROPS. j - 0920 -Hrs, FILL STACK FROM TRIP TANK AND IT TAKES 6.2 -Bbls FOR A CALCULATED STATIC LOSS RATE OF 12.4 -BPH. Printed 10114/2010 3:02:59PM h Auk North America _ ALASKA = BP .Page 14 ©f 23 �Operaion Summary Report Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: - DOY - ON DRILLING iNC. UWC / Lat 070 °23'26.303'3 Long: 0148 °35'01.251 "W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 16:00 6.50 FISH P DECOMP PJSM TO DISCUSS POH AND UD DP, DCs, AND THE WRP RETRIEVAL BHA. ALSO HOLD AAR ON THE WELL KILL AND DISCUSS THE MINIMUM REQUIREMENTS FOR BULLHEADING AFTER REMOVING A BARRIER FROM ABOVE AN OPEN WELLBORE: 1.5 TIMES THE TAILPIPE VOLUME AT A RATE OF 1 -BPM PER INCH OF TAILPIPE DIAMETER. - 0935 -Hrs, CALLED RWO SUPT AND RWO ENGINEERING TEAM LEAD AND RECEIVE APPROVAL TO POH AND UD THE DP STRING. - 1130 -Hrs, CALL AOGCC TO NOTIFY THEM OF IMPENDING TEST FOR THE BOP COMPONENTS ACTUATED FOR THE WELL SHUT -IN. BOB NOBLE, AOGCC NORTH SLOPE INSPECTOR IMMEDIATELY RETURNED THE CALL AND WAIVED AOGCC'S RIGHT TO WITNESS THE TESTS. -1345 -Hrs, UD DP JT # 75. CALCULATED LOSS RATE OF 9 -13PH. - 1420 -Hrs, UD JT #90; CALCULATED LOSS RATE IS 7.4 -13PH. STOP RIH TO MONITOR WELL FLUID LEVEL AND THE FLUID LEVEL IS SLOWLY DROPPING. 1425 -Hrs, CALL RWO ENGINEER TO INFORM HIM OF THE DECREASE IN THE CALCULATED LOSS RATE. PITWATCHER REPORTS THAT FLUID IN ALL PITS IS 9.1 -ppg HEAVY. - 1455 -Hrs, FILL THE STACK AFTER MONITORING FOR 30- MINUTES AND IT TAKES 3 -Bbls TO FILL FOR A 6 -BPH LOSS RATE. CALLED RWO ENGINEER AND AGREE TO WEIGHT ALL FLUID IN PITS TO 9.2 -ppg WHILE USING CONSTANT HOLE FILL BEFORE RESUMING POH WITH THE DP. 16:00 17:30 1.50 FISH P DECOMP WAIT ON ADDITIONAL SALT TO WEIGHT UP PITS TO 9.2-pp g. 17:30 18:30 1.00 FISH P DECOMP BUILD 9.2 -ppg NaCl BRINE IN ALL PITS FROM THE 9.1 -ppg IN THE PITS. 18:30 - 00:00 5.50 FISH P DECOMP CONTINUE TO POH UD DP. - MAINTAIN CONSTANT HOLE FILL WITH 9.2 PPG NACL BRINE. - MONITOR WELL EVERY 30 JTS OF DP UD. -21:00 Hrs - LOSS RATE OF 6.0 BPH. -21:30 Hrs - LOSS RATE DECREASED TO 5.4 BPH. STOP AND MONITOR WELL. ATTAIN ANOTHER LOSS RATE 5.6 BPH. - CONTINUE POH UD DP TO 5843'. - MAINTAIN CONTINOUS HOLE FILL AT 5.4 BPH LOSS RATE. 8/31/2010 00:00 - 06:00 6.00 FISH P DECOMP POH UD DP FROM 5,843' TO 303'. - MAINTAIN CONTINOUS HOLE FILL. - MONITOR WELL FOR 10 MINS EVERY 30 JTS OF PIPE PULLED. -0100 Hrs - 3.5 BPH LOSS RATE. -0230 Hrs - 6.4 BPH LOSS RATE. -0300 Hrs - 2.8 BPH LOSS RATE. -0330 Hrs - 9.3 BPH LOSS RATE. -0430 Hrs - UD JT 313 - 4.1 BPH LOSS RATE. -0500 Hrs - 4.6 BPH LOSS RATE. Printed 10/14/2010 3:02:59PM North;Arnerica.YALASKA - :gP+ Page )5 of 2 r Qpera #ion 5L mrn4 Rap °art Common Well Name: PI-24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:00AM Rig Release: 9/4/2010 - Rig Gontfactor DOYON- DRILLING- +NC. - -- - - -- - - - - - UWI: -/ Lat.- 070 °23'26.- 303 "3 Long: - 0148'35'01.251'W Activ D at u m_ : O_ RIG KELL BU SHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 07:30 1.50 FISH P DECOMP B/O AND UD BHA. - 0630 -Hrs, UD FIRST JT OF 2 -7/8 ". B/O AND UD THE WRP. IT SHOWED NO SIGNS OF DAMAGE. - MIDNIGHT TO 0630 -Hrs TOTAL FLUID LOSS WAS 85.7 -Bbls FOR A 14 -BPH LOSS RATE. FLUID ONSITE: 278 -BBLS, VAC TRUCK WITH 160 -Bbls OF 9.2 -ppg NaCl BRINE, AND VAC TRUCK WITH 290 -Bbls OF 9.1-ppg NaCl BRINE. 107:30 - 12:00 4.50 BOPSUR P DECOMP R/U TO TEST THE BOP EQUIPMENT THE WE LL S/I EVENT 8 -30 -2010. - 08301-Irs, HOLD PJSM FOR NON - ROUTINE WORK SUCH AS TESTING THE BOP AGAINST A TEST PLUG FOR A PARTIAL TEST OF THE ENTIRE BOP SYSTEM. -TEST THE 3 -1/2" X 4 -1/2" VBRS USING THE 3 -1/2" AND 4 -1/2" TEST JTS, BOTH CHOKE AND KILL HCRs AND THE HYDRIL PREVENTER WITH 3 -1/2" TEST JT. (USED THE ANNULAR IT TO STRIP THROUGH WHILE CLEANING THE SLUGGITS OFF OF THE WRP) -TEST TO 250 -PSI LOW AND 3500 -PSI HIGH. HOLD AND CHART EACH TEST FOR 5- MINUTES. -AOGCC REP BOB NOBLE WAIVED STATE'S RIGHT TO WITNESS TEST ON 8 -3 -10 AT 1100-HRS. - 1100 -Hrs, THE HYDRIL PREVENTER FAILED THE TEST. CALL RWO ENGINEER AND CONFIRM THAT WE CAN USE THE NEW HANGER WITH A TWC TO INSTALL IN THE TUBING HEAD AND SET IT UP AS A BARRIER FOR THE WD OF THE HYDRIL. A ROLLING TEST UNDER THE HANGER WILL HAVE TO BE PERFORMED TO 1000 -psi, AND A 3500 -psi TEST BETWEEN THE BLINDS AND THE HANGER WHILE PUMPING DOWN THE KILL LINE. 12:00 - 12:30 0.50 BOPSUR N DECOMP UD TEST JOINT AND TEST PLUG. -FILL HOLE TAKING 13 BBLS. -LOSS RATE OF 14.0 BPH. - MAINTAIN CONSTANT HOLE FILL. 12:30 - 14:30 2.00 BOPSUR N DECOMP PJSM FOR SETTING HANGER WITH TWC. -P /U AND R/U HANGER WITH TWC INSTALLED. -SET HANGER AND RILDS. -13:42 Hrs -TEST TWC TO 3500 PSI FROM ABOVE. GOOD - 1000 PSI ROLLING TEST FROM BELOW AT 1.7 BPM TO MAINTAIN 1000 PSI. TOOK 10 BBLS TO FILL HOLE AND 40 BBLS TO SEAT TWC BALL. HOLD 1000 PSI FOR 10 MIN ONCE BALL WAS SET. 64 BBLS TOTAL VOLUME PUMPED AWAY FOR TEST. -14:00 Hrs - SEND OVERSHOT FOR COMPLETION TO BAKER MACHINE TO HAVE TURNED DOWN FROM 5.93" OD TO 5.80" OD. -SUCK DOWN STACK. - MAINTAIN CONSTANT HOLE FILL. Printed 10/14/2010 3:02:59PM orth Arnerlca - ALASKA _;BP: Aage 1f3 .; Op ration Summary Report _ Common Well Name: P1 -24 DIMS AFE No X4- OOPQB -E 1,518,00000 Date: 8/21/2010 End Date: ( ) Event Ty WORKOVER WO Start Yp Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Gontractof�DOYON DRILLING ING-.. - - - - -- - - UWI: / Lat: 070'2326.303 "3 Long: 0148 °35'01.251 "W Active D ORIG KELLY BUSHING @4 (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 21:30 7.00 BOPSUR N DECOMP PJSM FOR CHANGING OUT ANNULAR PREVENTER. - BARRIERS ARE 1)TESTED TWC AND TUBING HANGER AND 2) TESTED BLIND RAMS. - CHANGE OUT ANNULAR PREVENTER. - MAINTAIN CONSTANT HOLE FILL. 21:30 - 22:30 1.00 BOPSUR P DECOMP R/U AND TEST BAG WITH 3 -1/2" TEST JOINT. -TEST BAG TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. -R/D TEST EQUIPMENT - MAINTAIN CONSTANT HOLE FILL AT 6.6 BPH LOSS RATE 19:45 Hrs'- AOGCC -WAS NOTIFIED OF UPCOMING ANNULAR PREVENTER TEST. JOHN CRISP WAIVED WITNESS. 22:30 - 00:00 1.50 BOPSUR P DECOMP CHECK FOR PRESSURE UNDER THE HANGER NONE. -BOLDS AND PULL HANGER TO FLOOR, INSPECT HANGER - GOOD. - MAINTAIN CONTINOUS HOLE FILL AT 6.6 BPH LOSS RATE. 9/1/2010 00:00 - 02:00 2.00 RUNCOM P RUNCMP FINISH UD HANGER. -PJSM R/I 1 TO RUN 3 -1/2" 9.2# 13cR VAM TOP COMPLETION. -P /U AND R/U HANDLING EQUIPMENT. -MAKE UP FLOOR VALVE. - MAINTAIN CONTINUOUS HOLE FILL AT 7 BPH LOSS RATE. 02:00 - 16:00 14.00 RUNCOM P RUNCMP PJSM WITH WSL, TOUR PUSHER, HALIBURTON HANDS, DOYON CSG, AND RIG CREW ON RUNNING COMPLETION. DISCUSS DROPPED OBJECTS - CALIPER ELEVATORS, DISCUSSED PINCH POINTS, PIPE SHED SAFETY, DISCUSSED WELL CONTROL, ENSURE PIT WATCHER DOES NOTHING BUT FLUID MANAGEMENT, CHECK FOR FLOW EVERY 2000' RIH, MAINTAIN CONTINUOUS HOLE FILL. -P /U OVERSHOT ASSY AND RIH AT 0245 HRS. -RIH WITH XN ASSY, JOINT A, X -NIP ASSY, TNT PACKER ASSY, X -NIP ASSY, JOINT #1. -0315 HRS RIH WITH GLM #1. -0330 HRS MAINTAIN CONTINUOUS HOLE FILL AT 7 BPH LOSS RATE. -0400 HRS 15 JOINTS RIH. - 0950 -HRS - 150 -JTS RIH. PU WT = 80K -LBS, SO WT - 80K -LBS. MONITOR WELL - FLUID LEVEL DROPPING SLOWLY. - CONTINUE RIH WITH 3 -1/2" 9.2# 13CR80 TUBING to 9117'. LOSS RATE = -5 -BPH. -PU WT = 104K -LBS, SO WT = 95K -LBS. 16:00 - 17:00 1.00 RUNCOM P RUNCMP MONITOR WELL - FLUID LEVEL DROPPING. - CHANGE OUT ELEVATORS TO HANDLE 4 -112" TUBING. -PU 4 -1/2" 12.6# 13CR80 VAM TOP X 3 -1/2" 9.2# 13CR80 VAM TOP XO ASSEMBLY AND MU. Printed 10/14/2010 3:02:59PM =° ort' Arne'rica - ALASKA - BP Pale ? v 2 IT Qpera'tion Summary Reporf Common Well Name: PI-24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 - Rig Contractor: DOYON DRILLING INC - - UWI: / Lat: 070 °23'20.303 "3 Long: 0148 °35'01.251 "W Active Da tum: O_ RIG K BUSHI @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 17:30 0.50 RUNCOM P RUNCMP HOLD PJSM ON RIGGING UP CONTROL LINE SPOOLING UNITS WITH HES AND RIG CREW. DISCUSS DROPPED OBJECT POTENTIALS, SPOOLER AND SHEAVE PLACEMENT AND POSITIONS OF PEOPLE. -RU HES CONTROL LINE SPOOLING UNITS. - MAINTAIN CONTINUOUS HOLE FILL WITH LOSS RATE OF —5 -BPH. 17:30 - 22:30 5.00 RUNCOM P RUNCMP CIRCULATE A TUBING VOLUME AT 1.7 -BPM WITH 100 -PSI. LOSS RATE = 6.6 -BPH. - ATTEMPT TO RD CIRCULATING EQUIPMENT AND WELL IS OUT OF BALANCE. -RE- ESTABLISH CIRCULATION AT 2.4 -BPM WITH 150 -PSI AND PERFORM A FULL WELLBORE CIRCULATION PLUS LOSS RATE. LOSS RATE OF 6.5 BPH. - CIRCULATE A TOTAL OF 350 BBLS AND HAVE 9.2 PPG IN AND OUT. MONITOR WELL - ON A VAC. 22:30 00:00 1.50 RUNCOM P RUNCMP P/U SSSV. - DRIFTED SSSV WITH BALL AND ROD. GOOD. -M /U AND RIG UP TEST EQUIPMENT TO TEST SSSV. MAINTAIN CONTINUOUS HOLE FILL AT 6.2 BPH LOSS RATE. 9/2/2010 00:00 - 03:00 3.00 RUNCOM P RUNCMP CONTINUE TO RIH WITH 4 -1/2" 12.6# 13Cr VAM TOP TUBING FROM 9,133'. - MAINTAIN CONTINUOUS HOLE FILL AT 6.4 BPH LOSS RATE. -0300 Hrs. RIH WITH JT # 54 P/U WEIGHT OF 125K, S/O WEIGHT OF 11 OK. -0300 Hrs LOSS RATE OF 7.1 BPH. 03:00 - 04:30 1.50 RUNCOM P RUNCMP SPACE OUT. -P /U JOINT # 55 RIH WITH NO WEIGHT DIFFERENCE. -P /U JOINT #56 RIH WITH NO WEIGHT DIFFERENCE. -THE FIRST INDICATION WAS ON JT 57 AT 2' IN SHOWING 4K. RIH 5' IN ON JOINT 57 AND STACK 25K. - ROTATE PIPE 1 TURN AND WORK TORQUE DOWN. RIH AND STACK 25K DOWN 5' IN ON JT 57. -WORK TORQUE DOWN AND ATTEMPT AGAIN WITH SAME RESULTS. -0400 Hrs - ROTATE PIPE 1 TURN AND WORK TORQUE DOWN. ATTEMPT TO SLIDE OVER STUMP AND STACK 15K DOWN. -0430 Hrs - ROTATE ANOTHER 1/4 TURN AND CONTINUE TO WORK TORQUE DOWN. NO SUCCESS. - DECIDED TO ATTEMPT TO WASH OVER STUMP. Printed 10/14/2010 3:02:59PM oath America - lAat P , Pose ,Of 23 Opera #ion Summary Reporf Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000-00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRIL -- UWI / Lat: 070 °23'26.303 "3 Long: - 0148 °35'01.251 "W Ac tive D ORIG KELLY BUSHING @43.3 (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 06:00 1.50 RUNCOM P RUNCMP L/D JOINT #57 AND REMOVE COMPENSATOR. -R/U TO CIRCULATE DOWN TBG. -P /U AND M/U JT #57. BRING PUMPS ONLINE AT 2 BPM WITH 80 PSI. -WASH DOWN AND SEE 4K WEIGHT AT 5' IN ON JOINT 57, - CONTINUE DOWN AND SHEAR SCREWS WITH 14K AT TIN AND SECOND SHEAR AT 16IN.NOGOAT17'IN. GOOD CONFIRMATION SEEING BOTH SHEARS ON CALCULATION. - PERFORM SPACE OUT CALCULATION AND WILL USE 2 '10' PUPS AND 1) 6' PUP. 06:00 06:30 0.50 RUNCOM P RUNCMP LD 4 -1/2" TUBING JOINT #57 AND RD CIRCULATING EQUIPMENT. - ATTEMPT TO PULL JOINT #56 AND OVERPULL 25K -LBS AT 11362'. - DISCUSS OPTIONS WITH RWO ENGINEERING TEAM. 06:30 08:30 2.00 RUNCOM N RUNCMP RU CIRCULATING EQUIPMENT TO REVERSE CIRCULATE. - ATTEMPT TO REVERSE CIRCULATE WELL. =PUMP 7- STROKES AND PRESSURE UP TO 410 -PSI. PRESSURE DOES NOT BLEED OFF WITH PUMPS OFF. -BLEED OFF PRESSURE. CHECK ALL CIRCULATING EQUIPMENT AND ENSURE PROPER LINE UP. BLOW AIR THROUGH CIRCULATING LINES ON RIG FLOOR. NO PROBLEM WITH CIRCULATING EQUIPMENT. - ATTEMPT TO REVERSE AGAIN WITH IDENTICAL RESULTS. -RD CIRCULATING EQUIPMENT. -FILL TUBING TO MAINTAIN CONTINUOUS HOLE FILL. - DISCUSS SITUATION WITH RWO ENGINEERING TEAM AND DECIDE TO WORK OVERSHOT OVER 4 -1/2" TUBING STUB. Printed 10/14/2010 3:02:59PM xy North- America ALA80 B;p Page 19 f 23: on Summary Report Common Well Name: P1 -24 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 Rig Contractor: DOYON DRILLING INC. - -- - - - - - - -- UWI:7 Lat: 070 "23'26.303 "3 Long: — - 0148 °35'01.251 "W Activ Datum: ORIG KELLY BUSH @43.30ft (abo Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 10:30 2.00 RUNCOM N RUNCMP MU 4 -1/2" TUBING JT #57 TO STRING AND TO TOP DRIVE. -RIH TO 11367' (1' OF SWALLOW OVER 4 -1/2" STUMP) - DISCUSS SITUATION WITH RWO ENGINEER AND DECIDE TO CONTINUE TO SLACK OFF AS FAR AS POSSIBLE AND THEN WORK 8' INTERVAL TO MAINTAIN OVERSHOT OVER STUMP AT ALL TIMES. - CONTINUE TO RIH AND SET DOWN 1 OK -LBS AT 11372'. - DISCUSS SITUATION WITH RWO ENGINEER. DECIDE TO ATTEMPT TO REVERSE CIRCULATE WELL CLEAR. -PU TO 11 368' AND RU TO REVERSE CIRCULATE. -CLOSE ANNULAR AND ATTEMPT TO REVERSE. -PUMP 7 -STKS AND WELL PRESSURES UP TO 410 -PSI AND HOLDS. BLEED OFF, CHECK EQUIPMENT AND REPEAT WITH IDENTICAL RESULTS. - DISCUSS SITUATION WITH RWO ENGINEER AND DECIDE TO CONTINUE TO ATTEMPT TO PASS 11372'. -RIH AND SET DOWN 25K -LBS AT 11,372' THREE TIMES WITHOUT SUCCESS. -ON FINAL ATTEMPT, PU TO SEE WEIGHT BREAKOVER AND SEE 1OK -LB OVERPULL. SLACKOFF TO PU WT AT 11368'. LOSS RATE USING HOLE FILL = 0 -BPH. - DISCUSS SITUATION WITH RWO ENGINEER. 10:30 - 11:00 0.50 RUNCOM N RUNCMP PUMP DOWN TUBING TO FILL HOLE AT 1.5 -BPM WITH 180 -PSI. - ESTABLISH RETURNS AT 5 -BBLS PUMPED AND PRESSURE DROPS OFF TO 120 -PSI. -LOSS RATE = 20 -13PH. 11:00 - 14:00 3.00 RUNCOM N RUNCMP CONTINUE CIRCULATING AT 1.5 -BPM WHILE DISCUSSING SITUATION WITH RWO ENGINEER. - DECIDE TO CIRCULATE A BOTTOMS UP, WORK PIPE WITH PUMPS ON AND THEN PUMP A 40 -BBL HI VIS SWEEP AROUND TO CLEAN WELL. -STAGE PUMPS UP TO 2 -BPM WITH 230 -PSI. - NOTHING SEEN ACROSS SHAKERS DURING CIRCULATION. VERY SMALL AMOUNT OF GAS AT BOTTOMS UP. -LOSS RATE WHILE CIRCULATING REDUCES FROM 16 TO 13 -13PH. 14:00 14:30 0.50 RUNCOM N RUNCMP RIH TO 11 379' WITH PUMPS ON AT 2 -BPM AND WITHOUT ISSUE. - RECIPROCATE SLOWLY FROM 11 379' TO 11 371' FIVE TIMES. -ALL MOVEMENT MADE WITHOUT ISSUES. Printed 10/14/2010 3:02:59PM o6,"Amed6a.- AI K Operation °Sliammary Report Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 - Rig Ccmtractor: -0OYON DRILLING INC.- - - - UWL /L-at: 070 °2326.303 '3 - Long: 0148 °35'01.251 "W Activ Da tum : O RIG KELLY BU SHING @43 (above Mean Sea L evel) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 18:00 3.50 RUNCOM N RUNCMP PUMP 40 -BBL HI VIS SWEEP AT 2 -BPM WITH 190 -PSI. LOSS RATE= 16 -13PH. -WITH 85 -BBLS PUMPED, SLOW PUMPS TO 1 -BPM AND 50 -PSI. LOSS RATE = 4 -BPH. -AS SWEEP TURNS THE CORNER, WORK PIPE SLOWLY BETWEEN 11 379' AND 11371'. NO ISSUES PIPE MOVEMENT. -ONCE ALL SWEEP IS IN THE ANNULUS, STAGE PUMPS UP TO 2.8 -BPM WITH 240 -PSI. LOSS RATE = 18 -13PH. - PRESSURE CLIMBS SLOWLY AND WHEN IT REACHES 300 -PSI, WORK PIPE SLOWLY AGAIN. PRESSURE DROPS OFF. -FINAL RATE = 2.8 -BPM, FINAL PRESSURE _ 360 -PSI. LOSS RATE= 14 -BPH. -VERY SMALL AMOUNT OF SLUGGITS SEE AT SHAKERS THROUGH CIRCULATION. -RED PAINT AND FINE FLAKES OF PARAFIN SEEN WITH SWEEP. 18:00 18:30 0.50 RUNCOM N RUNCMP MONITOR WELL. FLUID LEVEL DROPPING VERY SLOWLY. -DRAIN POSSUM BELLY AND CLEAN UNDER SHAKERS. MINIMAL AMOUNT OF SLUGGITS RECOVERED. 18:30 - 20:30 2.00 RUNCOM N RUNCMP P/U AND DOWN WITH OUT PUMPS FROM 11 379' TO 11,370' DRY WITH UP WEIGHT AT 155K THEN DROPPING TO 130K. DOWN WEIGHT OF 95K THEN DROPPING BACK TO 11 OK THIS WAS THE SAME WITH 3 ATTEMPTS. -BRING PUMPS ONLINE WITH 2 BPM AND 60 PSI WORKING PIPE FROM 11,379' TO 11370' SEEING 130K UP WEIGHT AND 11 OK DOWN WEIGHT AND VERY LITTLE RATTINESS. -SPOKE WITH ADW TOWN ENGINEER AND DECIDED TO PUMP OFF OF STUMP AND THEN PULL THE NEXT 2 JOINTS WITHOUT PUMPS. P/U JT 57 WITH 2 BPM AND 60 PSI AND PULLED OFF OF STUMP WITH 130K UP AND 11 OK DOWN. -SHUT DOWN PUMPS AND UD JT 57, PULL AND UD JT 56 WITH 135K UP WEIGHT. 20:30 21:15 0.75 RUNCOM N RUNCMP R/U AND TO PULL JT 55 BUT FLUID WAS FLOWING OUT OF TOP OF PIPE SO WE MADE UP TO JT 55 AND PUMPED A TUBING VOLUME AT 2.5 BPM AND 180 PSI WITH 16 -19% FLOW RETURNS. DYNAMIC LOSS RATE OF 3.4 BPH. MUD WT IN 9.2 PPG MUD WT OUT 9.2 PPG PRIOR TO SHUTTING DOWN PUMPS. 21:15 - 21:30 0.25 RUNCOM N RUNCMP MONITOR WELL. FLUID LEVEL DROPPING SLOWLY. 21:30 - 23:00 1.50 RUNCOM P RUNCMP P/U AND UD JOINT #55. -MU SPACE OUT PUPS, 9.92',9.89',5.65'. -P /U JOINT 55 AND RIH WITH 110K DOWN. - MAINTAIN CONTINUOUS HOLE FILL AT 3 BPH LOSS RATE. 123:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM FOR P/U M/U HANGER. -M /U HANGER. -M /U LANDING JOINT. Printed 10/14/2010 3:02:59PM oith America - ALASKA - BP Pagel?f3 6k Operation Summary.Report Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 - Rig -C-on tractor: - DOYON DRILLING INC:- - _ - -- -__ _ - _ _ _ _- .- _- UWI: -/ Lat: 070 °-23'26.303 "3 Long: 0148 °35'01.251 "W A D at u m: ORIG KELL BUSHING @43.30ft ( above Mean Sea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/3/2010 00:00 - 02:30 2.50 RUNCOM P RUNCMP PJSM FOR SPLICING CONTROL LINE TO SSSV. - SPLICE 1 CONTROL LINE U UNDER HANGER AND TEST CONTROL LINES TO 5000 PSI. - GOOD TEST. -RUN CONTROL LINES THROUGH HANGER AND TEST PACK OFF TO 5000 PSI. GOOD TEST. -RUN CONTROL LINE TO RIG FLOOR AND RETEST TO 5000 PSI. GOOD TEST. LEAVE 3500 PSI ON CONTROL LINES WHILE LANDING. 02:30 - 03:30 1.00 RUNCOM P RUNCMP RIH TO LAND HANGER 23' IN ON LANDING JOINT. -21' IN ON LANDING JOINT DOWN WT INCREASED 18K OVER. -P /U AND BREAK CIRCULATION AT 2 BPM AND 130 PSI. -WASH OVER TUBING STUB AT ABOVE RATES AND LAND HANGER 23' IN ON LANDING JOINT. -30 CANNON CONTROL LINE CLAMPS USED. BOTTOM OF OVERSHOT IS LOCATED AT 11,375'. NO GO AT 11,380', LEAVING 8' OF SWALLOW OVER 4 -1/2" STUB. 03:30 - 04:00 0.50 RUNCOM P RUNCMP ATTEMPT TO REVERSE CIRCULATE -PUMP 9.2 PPG BRINE FROM PITS. - ANNULUS PRESURED UP TO 500 PSI IN 13 STROKES. SHUT DOWN PUMPS AND PRESSURE HELD FOR 2 MIN. -BLEED DOWN ANNULUS. -SPOKE WITH ADW TOWN ENGINEER AND AGREED TO DROP BALL AND ROD AND SET PACKER HAVING THE PACKER FLUID -PUT INTO PLA 04:00 - 05:00 1.00 RUNCOM P RUNCMP LINED UP TO CIRCULATE DOWN TUBING TO WASH BALL SEAT CLEAR OF ANY DEBRIS OFF AT 2 BPM AND 230 PSI. - REMOVE BAILS TO TURN TOP DRIVE AND REMOVE XO FROM LANDING JOINT. -R/U AND DROP BALL AND ROD. 05:00 06:30 1.50 RUNCOM P RUNCMP PUMP DOWN TUBING AND PRESSURE UP ON BALL AND ROD ON SEAT. - PACKER BEGAN SETTING AT 1900 PSI THEN BROUGHT PRESSURE UP TO 3500 PSI. - ATTEMPT TO TEST TUBING FOR 30- CHARTED MIN. - TUBING PRESSURE DROPPING OFF. -CHECK SURFACE EQUIPMENT AND REPLACE ONE BLOCK VALVE. -STILL UNABLE TO GET A GOOD TEST. 06:30 - 07:30 1.00 RUNCOM P RUNCMP BLEED TUBING PRESSURE TO 2500 -PSI AND TEST IA TO 3500 -PSI FOR 30- CHARTED MINUTES. -GOOD TEST ON ANNULUS WITH TUBING PRESSURE STILL FALLING. -BLEED ANNULUS PRESSURE TO 0 -PSI AND BLEED TUBING PRESSURE TO 1000 -PSI. Printed 10/14/2010 3:02:59PM o rth ArrriCa - ALASKA - BP; Pa9 2 of 23= Opera #ion summary Report Common Well Name: P1 -24 AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 -- - Rig Contractor DOYON DRILLING INC. - - - - - - - - UWI: / Lat: 070 °23'26:303 "3 Long: - 0148 °35'01.251 "W Active Datum: ORIG K ELL Y BUSHING @43.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 08:30 1.00 RUNCOM P RUNCMP DISCUSS SITUATION WITH RWO ENGINEERING TEAM AND CONTINUE TO MONITOR TUBING PRESSURE. - TUBING PRESSURE CONTINUES TO DROP AND THEN HOLDS STEADY AT 1000 -PSI. 08:30 10:30 2.00 RUNCOM P RUNCMP ATTEMPT TO TEST TUBING TO 3500 -PSI AGAIN. TEST FAILS. -TEST TUBING TO 1000 -PSI FOR 10- CHARTED MINUTES. GOOD, FLAT LINE TEST. ATTEMPT TO PRESSURE TEST TUBING TO 3500 -PSI AGAIN AND UNABLE TO GET GOOD TEST. -BLEED TUBING PRESSURE TO 0 -PSI 10:30 - 11:00 0.50 RUNCOM P RUNCMP PRESSURE UP ON ANNULUS TO 2700 -PSI AND SEE DCR SHEAR. - REVERSE THROUGH VALVE AT 2 -BPM WITH 130 -PSI. CIRCULATE DOWN TUBING AT 2 -BPM WITH 140 -PSI. -LD LANDING JT AND VAC OUT BOP STACK. 11:00 - 15:00 4.00 RUNCOM - P RUNCMP FMC T -BAR IN TWC. - ATTEMPT TO TEST BELOW TWC TO 1000 -PSI FOR 10- CHARTED MINUTES. �wG� - VISUALLY CONFIRM TWC IS NOT LEAKING. r® NO FLUID SEEN WHEN LOOKING AT TOP OF TWC. HANGER IS NOT LEAKING. NO FLUID re- SEEN COMING FROM AROUND HANGER. -BUMP TEST PRESSURES UP TO KEEP FROM I ; FALLING BELOW TEST PRESSURE. -HOLE IS STAYING FULL OF 9.2 -PPG KWF AS WE ARE ABLE TO CONSISTENTLY PRESSURE TEST. -BEST TEST LOSES 75 -PSI OVER 10- MINUTES. - ATTEMPT TO TEST BELOW TWC TO 700 -PSI. LOSE 70 -PSI OVER 10- MINUTE TEST INTERVAL. HOLE STAYS FULL OF 9.2 -PPG KWF AND NO LEAKS SEEN AROUND TWC OR HANGER. - ATTEMPT TO TEST BELOW TWC TO 500 -PSI FOR 10- MINUTES. LOSE 50 -PSI OVER 10- MINUTE TEST INTERVAL. HOLE STAYS FULL OF KWF AND NO LEAKS SEEN AROUND TWC OR HANGER. 15:00 - 17:00 2.00 RUNCOM P RUNCMP PU LANDING JTAND FILL. MU TEST EQUIPMENT. -TEST TWC FROM ABOVE TO 3500 -PSI FOR 10- CHARTED MINUTES. GOOD TEST. -XO FROM LANDING JT TO TIW VALVE. 17:00 17:30 0.50 RUNCOM P RUNCMP R/D TEST EQUIPMENT. - ESTABLISH CONTINUOUS HOLE FILL THROUGH IA. NO LOSSES. 17:30 - 20:00 2.50 BOPSUR P RUNCMP PJSM FOR RIGGING DOWN BOPE. -R /D HALIBURTON EQUIPMENT FROM RIG FLOOR. -N /D BOPE Printed 10/14/2010 3:02:59PM North America - AL`pSKA - B,P Page 20 23 Qperation 5urnmary Report g Common Well Name: P1- 24_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 8/21/2010 End Date: X4- OOPQB -E (1,518,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/2/2008 12:00:OOAM Rig Release: 9/4/2010 -Rig-Contractor-0OYON DRILLING INC. _ _ - - - - -- _ _ UWI: / Lat: 070 °23'26.303 "3 Long: 0148 °35'01.251''W Active Datum: ORIG KELLY BUSHING @43.30ft (above Mean Sea Le Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 WHSUR P RUN DAPTFR FLANGE_ - NOTICE BUBBLING AROUND PACK OFF ON CONTROL LINE. FLUID IS BEING PUMPED INTO THE IA TO KEEP HOLE FULL. - REPAIR LEAK IN CONTROL LINE PACK OFF, WITH A SWEDGE LOCK. TEST TO 5000 PSI. GOOD TEST. -N /U ADAPTER FLANGE. 9/4/2010 00:00 - 04:00 4.00 WHSUR P RUNCMP F INISH N/U ADAPTER FLANGE. -TEST CONTROL LINES TO 5000 PSI FOR 10 CHARTED MIN. EACH. GOOD TEST. -TEST ADAPTER SPOOL TO 5000 PSI FOR 10 CHARTED MIN. GOOD TEST. TREE. -TEST TREE TO 5,000 PSI FOR 10 MIN. -GOOD TEST. 04:00 - 06:00 2.00 WHSUR P RUNCMP SECURE TREE. -R /D SECONDARY ANNULAR VALVES AND SECURE THE TREE. -EMPTY AND CLEAN PITS. - RELEASE RIG AT 0600 Hrs. Printed 10/14/2010 3:02:59PM FW: PM1-24 BOP Useage 8-30-2010• Regg, James B (DOA) From: Willingham, James M [James.Willingham@bp.com] Sent: Monday, August 30, 2010 5:12 PM To: DOA AOGCC Prudhoe Bay Cc: Engel, Harry R; Crane, Lowell R Subject: FW: PM1-24 BOP Useage 8-30-2010 Importance: High Attachments: PM1-24 8-30-2010 BOPE Useage .doc From: Rooney, Michael S (CDI) Sent: Monday, August 30, 2010 5:09 PM To: Willingham, James M Subject: PM1-24 BOP Useage 8-30-2010 Importance: High «PM1-24 8-30-2010 BOPE Useage .doc» • Page 1 of 1 ~~~1~12 ~~~ ~ ~4~ ~"yl_ 8/31/2010 ~~ Blow Out Preventer Equipment (BOPE Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of ~ BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: James Willingham Wellsite Leader Name: Mike Rooney Contact Number: 659-5329 Contact Number: 907-659-4608 Traction Number:2010-IR-3602389 Well Location & Name: PM1-24 Permit To Drill PTD Number: 1961490 Date and Time of Incident: 08/30/2010 03:45 Original Scope of Work: Retrieving WRP @ 11,411' in 4-1/2" tbg stub. Pull out of tubing stub with WRP. Close the 3-1/2" X 6 VBR and bull head 35 bbls of 9.1 ppg NaCI brine. Open Ram and circulate Bottoms up. POOH UD Drill Pipe. Operational Description Leading up to Well Control Event: (Planned Event) Released WRP at 11,411'. Hole volume dropped by 2 bbls. P/U to 11,370'. The upper rams 3-1/2" X 6" VBRs' where closed and 4 bbls was bull headed to see if plug was released. The rams where then opened and we found we where stuck with the WRP at 11,370'. Attempted to free by pulling up to 75K over and putting 5 k over down wt. with pumps on at 1 bbl a minute and up to 5 bbl a min. No success. When we freed the plug we pulled up above the Stump. We started circulating b/u and at 196 bbls away we saw an increase in flow and shut in the 3-1/2" X 6" VBRs. BOPE Used and Reason: 3-1/2" X 6" VBRs. Well Control. Is a BOPE Test Required after use (Yes / No): Yes, the VBRs. 24 hour notice re wired to NS AOGCC Ins ectors prior to testin BOPS com onents. Plan Forward: Additional Comments: Will test upper 3-1/2" X 6" VBRs with 3'/z" and 4-1/2" test joint @ 250 / 3500 When out of hole .... Test time approximately 02:00 AM, 08/31/2010. Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bayCa)_alasKa.gov ~ Email CC List BP WSL Har En el Wells Team Leader Jeff Kilfo le En ineerin Team Leader O erations Drillin En ineer- Well File Wells O erations Mana er Drillin & Com letions En ineer Mana er Wells Intervention Mana er ~~~ ~ t~ BOPE Usage Report for AOGCC August 2, 2010 HRE Request to produce P1-24 without a SSSV in place Page 1 of 4 Regg, James B (DOA) ~.~.rr ~, _ ~.._ ~.. ~, From: Regg, James B (DOA) ~~ /t `~\~~~~'~ ~j(,,~ Q (-~L~-- Sent: Friday, April 23, 2010 3:17 PM ~ )q ~ ¢qC~ Qm ~ To: 'Engel, Harry R' Cc: Warner, Ross L Subject: RE: Request to produce P1-24 without a SSSV in place Thank you for the quick responses. I have discussed your request with Commissioner Foerster and we concur with allowing the operation of P1-24 as you described below. This approval is conditioned on 24-hour man watch, and a passing SSV performance test within 48 hours of establishing production. Notify the Commission Inspector at 659-3607 when ready for the SSV test. A failing SSV test will require the well to be immediately shut in. This approval is valid through the end of July 2010. I would appreciate an update prior to installation of the K-valve or decisions affecting the operation of this well. Jim Regg AOGCC ~~5~- S) ~~ ~-~ ~' -`i ~ I F~' ~z~'~ ~ Piss _ ~ 333 W.7th Avenue, Suite 100 ~ LL4.Q.~ `~ ~~ Anchorage, AK 99501 907-793-1236 From: Engel, Harry R [mailto:Harry.Engel@bp.com] Sent: Thursday, April 22, 2010 5:02 PM To: Re99, James B (DOA) `~~x,~~=~ ~~i~ ~, ~ ~~1~~' Cc: Warner, Ross L Subject: RE: Request to produce P1-24 without a SSSV in place Jim- Yes the heater is the same. We don't anticipate any problems with the heater, it was taken out of service last year for maintenance purposes. Additionally we have learned how to better deal with hydrates by using continuous methanol injection while bringing the well online. A rig over is an option and a program is being prepared as a back up to the Gem valve. Let me know if you need anything else. Thanks, Harry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, April 22, 2010 4:29 PM To: Engel, Harry R Subject: RE: Request to produce P1-24 without a SSSV in place Is the heater you mention the same that was take out of service for maintenance? What contingencies do you have in place to avoid problems experienced during start-up attempt in early 2009 (lass of heater)? Why is a tubing workover to replace SSSV and control lines not an option? Jim Regg AOGCC 4/23/2010 Request to produce P1-24 without a SSSV in place Page 2 of 4 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Engel, Harry R [mailto:Harry.Engel@bp.com] Sent: Tuesday, April 20, 2010 4:37 PM To: Regg, James B (DOA) Cc: Warner, Ross L; NSU, ADW Well Integrity Engineer Subject: RE: Request to produce P1-24 without a SSSV in place Jim- The 24-hour man watch is to provide additional oversight and safety given the SSSV will be out of hole. A 24 hour man watch means there are two men assigned to this well so one of the two persons will be on site 24 hours a day. Normal this means each individual servers a 12 hour shift and the relieving takes place at the well site. The 2-3 months is only based on what we did last winter so we are hoping with warmer weather and past experience this time frame will be shorter. The answer to the third question is a statement about K-valves in general. Currently the control and electrical engineers are working the timing. We are hoping that when their assignment is completed we can get this GEM-Valve in ground in about four to five months from now. Geoservices is in a position to ship the equipment to Alaska when we give them the go-ahead. I hope this helps. Thanks, Harry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, April 16, 2010 9:32 AM To: Engel, Harry R Cc: Schwartz, Guy L (DOA) Subject: RE: Request to produce P1-24 without a SSSV in place Just a couple due diligence requests before I respond: - Describe 24 hour man watch. - Is the 2-3 months to complete the 3 steps outlined below (POP; heat up well; install K-valve) based on past experience of bring P1-24 on line from cold status? -You mention K-valve design as a contributing factor to technical problems bring well on line and sustaining flow; is there an alternate K-valve design or was this just a statement about K-valves in general? Any additional thoughts on timing for telemetry controlled SSSV? Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Engel, Harry R [mailto:Harry.Engel@bp.com] Sent: Wednesday, April 14, 2010 3:57 PM To: Regg, James B (DOA) Cc: Warner, Ross L; NSU, ADW Well Integrity Engineer; Bill, Michael L (Natchiq); NSU, ADW Well Operations Supervisor; 4/23/2010 Request to produce P1-24 without a SSSV in place NSU, ADW WL & Completion Supervisor; Cismoski, Doug A Subject: Request to produce P1-24 without a SSSV in place Jim- Page 3 of 4 This is a follow-up to our discussion last week at your office regarding the operation of this well. P1-24 Background This well was side tracked in August 2008 with two horizontal legs. These horizontal sections are 2710' and 1967' in length. This downhole location is important as currently this well is the most westerly well in the field. Production information from this well will be used for evaluation of the area and will probably result in more drilling during the future. The well was put on production and we experienced considerable problems with hydrates and asphaltenes. Numerous well interventions were required to keep the well on line. The control line to the SSSV profile is compromised therefore a K valve was installed to comply with AOGCC requirements. The technical problem with the K valve is the well can only be flowed to the high pressure (600 psi) header, so fairly high wellhead pressures are necessary to keep the K valve operable. The combination of the K valve design and flowing through the high pressure header reduces the well's potential to flow. In early January 2009 we initiated a hydrate control program of misting methanol into the tubing with a 24 hour man watch at the well site as there was no SSSV in the well. We received permission from your office for this operation. We struggled along with this operation for a number of months, but finally were able to wean the well off of methanol and raise the wellhead temperature to 90 F. We were considering setting a K valve at this time but the crude heater on the pad was taken out of service for required maintenance. The heater was being used to heat the lift gas to this well and once that heater was shut down the well head temperature fell to about 50 F and the well hydrated off. This took place in early August of 2009. Simultaneously we investigated a new technology to use a Telemetry Controlled SSSV in place of the K valve. This was the subject that we shared with you and other AOGCC staff members last week. This valve is much like a normal SSSV, but it is held open by radio transmission. Hydraulic control lines are not necessary. Currently we are planning to install one of these valves in this well. Request We would like to put this well back on line using a 24 hour man watch and methanol injection in lieu of a SSSV. Our plan is to flow the well until we achieve a fairly warm flowing wellhead temperature while using a gas lift heater. At that point we will attempt to install a K valve and hopefully keep the well on line until the Telemetry Controlled SSSV can be installed. If we can't operate the well with K valve we will shut the well in and wait for the installation of the new Telemetry Valve. Specifically we are requesting approval for the following operations: / . Put the well on line with a 24 hour man watch. We will test the SSV within 48 hours after production is established /. Inject methanol and heat lift gas until we raise the well head temperature to about 90 F ;/ . Install a K valve, per AOGCC review and approval We anticipate the above will probably take about 2-3 months to complete. ~- 4/23/2010 Request to produce P1-24 without a SSSV in place Under the above condition we expect the well to produce about 400 bopd and 110 bwpd. Please let me know if you have any questions or require more information Regards, Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907-564-4194 office 907-564-5510 fax Page 4 of 4 ~. U"v ~~C~C~ ~MSi ~~-,~}-- 4/23/2010 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 ~ ~r, ~ ~~ ~ ~~~ j~,~~t ~, Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, 1~6~i49 pi-a4- Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) r~ Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA 0 NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-05 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-O6 1961370 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-08A 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 50029221340000 NA 0.6 NA 6.80 7/7/2009 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7/6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13/2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 AOGCC, request approval to install K-Valve in well P1-24 Page ~`' Regg, James B (DOA) (~ ~ ~~ v 14~ ..From: Regg, James B (DOA)_ ~~ (~~[~I®~I Sent: Monday, June 15, 2009 10:06 AM ~~ To: NSU, ADW Well Integrity Engineer Cc: DOA AOGCC Prudhoe Bay Subject: RE: P1-24 (PTD 1961490) K-valve Testing Your request to bring P1-24 on line as described in the June 11 (and before that, Apri127 email messages (below)) is approved. Contact the AOGCC North Slope Inspector for opportunity to witness the SSV test, which will be done within 48 hours of restarting production. A failing SSV test will require the well to be immediately shut in. Jim Regg 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, June 11, 2009 4:03 PM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: RE: Pi-24 (PTD 1961490) K-valve Testing Hi Jim, As we discussed on the phone, P1-24 was put on production on 5/12/09 with the K-valve out of hole and 24-hour manwatch. Due to an unforseen plant upset, the pad was shut down on 5/28/09. Although some well tests were obtained, the test period was no long enough to get the necessary production data. We are requesting approval to again put the well production with 24-hour man watch and continuous methanol injection to obtain an AOGCC witnessed SSV test and then keep the well online for an additional 1-2 months with the same 24-hour man watch. This will allow for stabilized production and longer term production tests at final operating temperature. At that time, we will cease methanol injection and reset the K-valve. Please let me know if you have any questions or concerns. Thank you, Anna ~u6e, 2'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, May 08, 2009 8:35 AM To: NSU, ADW Well Integrity Engineer 6/15/2009 AOGCC, request approval to in~ll K-Valve in well P1-24 • Page 1~ Regg, James B (DOA) ~ ~ ~b ` ~ `~ From: Regg, James B (DOA) ~ SI~~~ Sent: Friday, May 08, 2009 8:35 AM ~ t To: NSU, ADW Well Integrity Engineer t Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: RE: P1-24 (PTD 1961490) K-valve Testing Your request to bring P1-24 on line as described in the April 27 email messge (below} is a ved. Contact the AOGCC North Slope Inspector for opportunity to witness the SSV test, which will be done within 48 hours of restarting production. A failing SSV test will require the well to be immediately shut in. Jim Regg AOGCC ~, 333 W.7th Avenue, Suite 100 r*,~ ~~ ~V~~`J ~ J ~ J~~,. Anchorage, AK 99501 {'` ,~,,. a, 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, May 07, 2009 1:07 PM To: Regg, James 6 (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: P1-24 (PTD 1961490) K-valve Testing Hi Jim, The SSV will be tested within 48 hours of returning the well to production. With you approval, we hope to return the well to production and test the SSV this weekend. The 24-hour man watch is to provide additional oversight and safety given the SSSV will be out of hole. Please feel free to call to discuss or let me know if there are any other questions. Thank you, Anna ~Du6e, ~'. E. Welt 4ntegrity Goordlnator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5'100 x9154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, May 05, 2009 11:29 AM To: NSU, ADW Well Integrity Engineer Subject: RE: P1-24 (PTD 1961490) K-valve Testing when will SSV be tested? what is BP committing to do by agreeing to 24-hour manned watch? Jim Regg 5/8/2009 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, April 27, 2009 11:01 AM ~CJ ~ ~~ To: Regg, James B (DOA) / \ ~`~ Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); GPB, Gas Lift Engr; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Chmielowski, Jessie; Warner, Ross L; G NSU ADW Slickline PE; GPB, GPMA OTL; Cismoski, Doug A; Liddelow, Robert W; NSU, ADW Well Operations Supervisor Subject: RE: P1-24 (PTD 1961490) K-valve Testing Jim, We would like to make another attempt at flowing P1-24. However, there are two issues with the well: the last SSV test was on 04/12/O~~nd~he K-valy~ has been oulle~i because it closed due to the well hvdratin~ff. WE wouldTike to put the well online with 24-hour man w, AOGCC witnessed SSV test. We would then like to same 24-hour man watch, to allow for stabilized prop cease methanol injection and reset the K-valve. continuous methanol injection to first obtain an ~e ~~~ell ~nli A f~~ an ariditiona -~ months, with the at final operating temperature. At that time, we will Our interpretation of the SVS regulations lead us to gain the AOGCC's permission to move forward with our plan. Please let me know if you need additional information to aid in your decision. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Cismoski, Doug A Sent: Wednesday, April 15, 2009 7:48 AM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); GPB, Gas Lift Engr; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Chmielowski, Jessie; Warner, Ross L; G NSU ADW Slickline PE; NSU, ADW Well Integrity Engineer; GPB, GPMA OTL Subject: RE: P1-24 (PTD 1961490) K-valve Testing Mr. Regg Our records indicate the same. This request is no longer valid. While allowing the well to stabilize and achieve final flowing pressures, the K-valve closed per design. The result is as expected, Operations is unable to re-open the K-valve and we suspect the well has hydrated off. Anew plan is being jointly developed between Engineering and Operations. Doug 5/1/2009 AOGCC, request approval to i~all K-Valve in well P1-24 • Page 1 of 3 Regg, James B (DOA) From: Regg, James B (DOA) ; Q~~ ~I14~~ Sent: Tuesday, April 14, 2009 9:55 AM To: Cismoski, Doug A Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); GPB, Gas Lift Engr; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Chmielowski, Jessie; Warner, Ross L; G NSU ADW Slickline PE; NSU, ADW Well Integrity Engineer; GPB, GPMA OTL Subject: RE: P1-24 (PTD 1961490) K-valve Testing Please confirm date of most recent SSV test on P1-24; Commission records indicate it was 4/12/2008. Your request cannot be approved without a successful test of the SSV. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Cismoski, Doug A [mailto:CismosDA@BP.com] Sent: Thursday, April 09, 2009 11:57 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); GPB, Gas Lift Engr; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Chmielowski, Jessie; Warner, Ross L; G NSU ADW Slickline PE; NSU, ADW Well Integrity Engineer; GPB, GPMA OTL Subject: P1-24 (PTD 1961490) K-valve Testing Mr. Regg Well PBU P1-24 (PTD: 1961490) was sidetracked in August 2008 and BP Operations have been struggling with this well's propensity to form hydrates since. I've attached a summary of well events since October 2008 that illustrate a cycle of clearing the hydrates, replacing the K-valve and the Drill Site Operator calling in to Wells to report the well hydrated off again. Recently, Operations and Wells Team have been working together to bring this well on-line with intermittent methanol injection to the gas lift. On April 7, 2009, BP Wells installed a K-valve. BP Operations and Wells teams are continuing to slipstream methanol intermittently in the gas lift. BP would like to keep the well on-line and allow it to stabilize production, reach final operating temperature and stop the methanol injection. In order to accomplish this, the well should remain on-line, uninterrupted for two more weeks. BP is requesting to delay the state witnessed testing of the K-valve for 2 weeks. P1-24 was put on production on March 31 and the K-valve installed on April 7. BP Operations would request a State Inspector to witness a K- valve closure test to be conducted no later than April 23, 2009 or the well be shut-in. Thank you in advance for your consideration. Doug Cismoski Wells Program Manager Alaska Drilling and Wells From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] 4/14/2009 AOGCC, request approval to i~all K-Valve in well P 1-24 • Page 2 of 3 Sent: Thursday, April 09, 2009 9:01 AM To: Cismoski, Doug A Subject: FW: AOGCC, request approval to install K-Valve in well P1-24 Doug, Here is the last message I have on P1-24. I suggest you send a message to Mr. Regg describing the situation with the well and make your request. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Friday, November 21, 2008 1:39 PM To: GPB, Gas Lift Engr Cc: GPB, LPC DS Operator; GPB, LPC DS Ops Lead; Carr, Jessie L; Varble, Doug A; G NSU ADW Slickline PE; Maunder, Thomas E (DOA) Subject: RE: AOGCC, request approval to install K-Valve in well P1-24 Approval attached; call if you have any questions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: GPB, Gas Lift Engr [mailto:GPBGasLiftEngr@BP.com] Sent: Tuesday, November 18, 2008 7:56 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: GPB, LPC DS Operator; GPB, LPC DS Ops Lead; Carr, Jessie L; Varble, Doug A; G NSU ADW Slickline PE Subject: AOGCC, request approval to install K-Valve in well P1-24 Hello Jim, Thomas, Per the AOGCC correspondence dated June 16, 2006, Bulletin No. 06-04 regarding subsurface controlled subsurface safety valves, I am requesting approval to install a "K" Valve in well NS15. P1-24 is a recent coil tubing drilling well that had a deep GLV installed on 11-09-08. We have recent well test data and want to install a K valve and keep the well on production. Attached is the K valve design sheet that contains all pertinent information/data regarding the well's flow characteristics, K-Valve configuration, trip/closure pressure, etc. We will wait on your approval prior to installing the K valve. Please notify me or Stan Groff if/once approval is granted and we will immediately install the valve. If you have any design questions please feel free to contact me. «P1-24 K-Valve Design 11-18-08 .xls» Thanks, Johnny Kenda Arctic Lift Systems Inc. GPB, Gas Lift Eng. 907-659-5863 4/14/2009 AOGCC, request approval to i~all K-Valve in well P1-24 • Page 3 of 3 907-659-3423 (p) 601-807-8992 (c) 4/14/2009 • ~ i ~~, ~ i 4`3 Pmt P1-~q Pl-24L1 Production Synopsis P 1-241 was coiled sidetrack during August, 2008. Two horizontal side tracks were drilled. One leg is 2710' long and the second leg is 1967' long. Slotted liners were set. The purpose of this drilling was to test the western boundary of the Pt. McIntyre Field. 1. 8/18/08: Installed gas lift valves and obtain a static pressure survey. 2. 10/10-13/08: ASRC well testing. 566 bopd and 115 bwpd. 3. 10/20/08: Slickline discovered hydrates at 1445' and unable to work through. 4. 10/22/08: Hot oil down the IA with no success to free up tubing. 5. 11/07/08: Coil cleanout of hydrates. 6. 11/08/08: Installed a new gas lift design. 7. 11/16/08: Put the well on line. Problems with well surging, etc. 8. 11/22/08: Well hydrated off again. 9. 11/23/08: Hot oil job down IA 10. 11/24/08: Set K valve. 11. 11/27/08: Put well back on line. 12. 11/28/08: Well hydrated off again. K valve had closed. 13. 11/29/08: Hot oil job down IA to thaw hydrates. 14. 01/06/09: Pulled K valve and drifted to 11,400 ft. 15. O 1 /09/09: Put well on production with continual methanol pumping down IA 16. 01/14/09: Fluid level shooting in IA indicated we were not lifting at the screened orifice. 17. 01/24-26/09: Set a new gas lift design. 18. 02/17/09: Put well back on production with continual methanol pumping. 19. 02/19/09: Pump failed. Shut down operations. 20. 03/06/09: Put well back on line pumping methanol. 21.03/11/09: Well tested 528 bopd and 178 bwpd. 22. 03/13/09: Set K valve with dome setting # 851. 23. 03/14/09: K valve went shut. Not clear if this was a State test of production problem. 24. 03/16/09: Attempted to put well back on line. No success. 25. 03/17/09: Attempted to pump down tubing with no success. 26. 03/28/09: Hot oil job down IA. Pumped 452 down IA. 190 bbls down tubing. 27. 03/30/09: Pulled K valve. 28. 04/04/09: Put well on production with continual methanol pumping down the IA. 29. 04/06/09: Tested 758 bopd and 350 bwpd. FTP-860 psig and FTT-67 F. 30. 04/07/09: Set K valve with a setting of # 851. 31.04/08/09: Tested 238 bopd and 9 bwpd. FTP - 964 psig and FTT-79 F. Bean size was reduced from 55 beans to 50 beans for the above. Ross Warner 04/09/09 Combined SVS Test Results Well Name Jan Permit # 01, 2008 PLT CP /F Through SSV CP /F SSSV CP /F Insp/ Oper Date Test Tested Reason (Excludes Reason = "Retest") Retest Failure Period Tests Components Failures Rate PRUDHOE BAY UN PTM P1-09 1961540 1 0 1 1 1 0 OP 3/14/2008 Misc 3 1 PRUDHOE BAY UN PTM P1-02A 2020650 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM P1-04 1930630 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM Pl-OS 1930870 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM P1-06 1961370 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM Pl-07A 2040370 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM P1-08A 2021.990 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM P1-09 1961540 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM P1-11 1920860 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM P1-17 1930510 1 0 1 1 1 0 OP 4/12/2008 180 3 1 PRUDHOE BAY UN PTM P1-18A 2020760 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM P1-23 1961240 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM P1-24 1961490 1 0 1 0 1 0 OP 4/12/2008 180 3 0 PRUDHOE BAY UN PTM P1-Gl 1921130 1 0 1 0 1 0 iN 4/28/2008 Misc 3 0 PRUDHOE BAY UN PTM P1-13 1930740 1 0 1 0 1 0 IN 5/1/2008 Misc 3 0 PRUDHOE BAY UN PTM P1-25 1890410 1 0 1 0 1 0 IN 6/3/2008 Misc 3 0 PRUDHOE BAY UN PTM P1-03 1890130 1 0 1 0 1 0 OP 6/30/2008 Misc 3 0 PRUDHOE BAY UN PTM P1-20 1920940 1 0 1 0 1 0 OP 6/30/2008 Misc 3 0 PRUDHOE BAY UN PTM Pl-02A 2020650 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM P1-04 1930630 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM P1-OS 1930870 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM P1-06 1961370 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM Pl-07A 2040370 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM Pl-08A 2021990 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM P1-09 1961540 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM P1-ll 1920860 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM P1-16 1930340 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM P1-17 1930510 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM P1-G1 1921130 1 0 1 0 1 0 OP 10/20/2008 180 3 0 PRUDHOE BAY UN PTM P1-13 1930740 1 0 1 0 1 0 IN 1/25/2009 Misc 3 0 Tuesday, April 14, 2009 Page 1,eI~ J~B~ AOGCC, request approval to i~all K-Valve in well P1-24 • Page 1 of 3 .~J [ ~~-- c ~-~ Regg, James B (DOA) From: Cismoski, Doug A [CismosDA@BP.com] ';~~~ ~jl~/~~ Sent: Wednesday, April 15, 2009 7:48 AM ~ \ I To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); GPB, Gas Lift Engr; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Chmielowski, Jessie; Warner, Ross L; G NSU ADW Slickline PE; NSU, ADW Well Integrity Engineer; GPB, GPMA OTL Subject: RE: P1-24 (PTD 1961490) K-valve Testing Mr. Regg ~ Our records indicate the same. This request is no longer valid. While allowing the well to stabilize and achieve final flowing pressures, the K-valve closed per design. The result is as expected, Operations is unable to re-open the K-valve and we suspect the well has hydrated off. Anew plan is being jointly developed between Engineering and Operations. Doug From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, April 14, 2009 9:55 AM To: Cismoski, Doug A Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); GPB, Gas Lift Engr; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Chmielowski, Jessie; Warner, Ross L; G NSU ADW Slickline PE; NSU, ADW Well Integrity Engineer; GPB, GPMA OTL Subject: RE: P1-24 (PTD 1961490) K-valve Testing Please confirm date of most recent SSV test on P1-24; Commission records indicate it was 4/12/2008. Your request cannot be approved without a successful test of the SSV, Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Cismoski, Doug A [mailto:CismosDA@BP.com] Sent: Thursday, April 09, 2009 11:57 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); GPB, Gas Lift Engr; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Chmielowski, Jessie; Warner, Ross L; G NSU ADW Slickline PE; NSU, ADW Well Integrity Engineer; GPB, GPMA OTL Subject: P1-24 (PTD 1961490) K-valve Testing Mr. Regg Well PBU P1-24 (PTD: 1961490) was sidetracked in August 2008 and BP Operations have been struggling with 4/15/2009 AOGCC, request approval to all K-Valve in well P1-24 • Page 2 of 3 this well's propensity to form hydrates since. I've attached a summary of well events since October 2008 that illustrate a cycle of clearing the hydrates, replacing the K-valve and the Drill Site Operator calling in to Wells to report the well hydrated off again. Recently, Operations and Wells Team have been working together to bring this well on-line with intermittent methanol injection to the gas lift. On April 7, 2009, BP Wells installed a K-valve. BP Operations and Wells teams are continuing to slipstream methanol intermittently in the gas lift. BP would tike to keep the well on-line and allow it to stabilize production, reach final operating temperature and stop the methanol injection. In order to accomplish this, the well should remain on-line, uninterrupted for two more weeks. BP is requesting to delay the state witnessed testing of the K-valve for 2 weeks. P1-24 was put on production on March 31 and the K-valve installed on April 7. BP Operations would request a State Inspector to witness a K- valve closure test to be conducted no later than April 23, 2009 or the well be shut-in. Thank you in advance for your consideration Doug Cismoski Wells Program Manager Alaska Drilling and Wells From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, April 09, 2009 9:01 AM To: Cismoski, Doug A Subject: FW: AOGCC, request approval to install K-Valve in well P1-24 Doug, Here is the last message I have on P1-24. I suggest you send a message to Mr. Regg describing the situation with the well and make your request. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Friday, November 21, 2008 1:39 PM To: GPB, Gas Lift Engr Cc: GPB, LPC DS Operator; GPB, LPC DS Ops Lead; Carr, Jessie L; Varble, Doug A; G NSU ADW Slickline PE; Maunder, Thomas E (DOA) Subject: RE: AOGCC, request approval to install K-Valve in well P1-24 Approval attached; call if you have any questions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: GPB, Gas Lift Engr [mailto:GPBGasLiftEngr@BP.com] Sent: Tuesday, November 18, 2008 7:56 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: GPB, LPC DS Operator; GPB, LPC DS Ops Lead; Carr, Jessie L; Varble, Doug A; G NSU ADW Slickline PE Subject: AOGCC, request approval to install K-Valve in well P1-24 4/15/2009 AOGCC, request approval to i~all K-Valve in well P1-24 ~ Page 3 of 3 Hello Jim, Thomas, Per the AOGCC correspondence dated June 16, 2006, Bulletin No. 06-04 regarding subsurface controlled subsurface safety valves, I am requesting approval to install a "K" Valve in well NS15. P1-24 is a recent coil tubing drilling well that had a deep GLV installed on 11-09-08. We have recent well test data and want to install a K valve and keep the well on production. Attached is the K valve design sheet that contains all pertinent information/data regarding the well's flow characteristics, K-Valve configuration, trip/closure pressure, etc. We will wait on your approval prior to installing the K valve. Please notify me or Stan Groff if/once approval is granted and we will immediately install the valve. If you have any design questions please feel free to contact me. «P1-24 K-Valve Design 11-18-08 .xls» Thanks, Johnny Kenda Arctic Lift Systems Inc. GPB, Gas Lift Eng. 907-659-5863 907-659-3423 (p) 601-807-8992 (c) 4/ 15/2009 P1-24 (PTD #1961490) Clarification of SSSV Regulation Page 1 of 4 • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, December 01, 2008 4:44 PM ` l~~ ~?'C{ ~~ To: 'NSU, ADW Well Integrity Engineer' (. Subject: RE: P1-24 (PTD #1961490} Clarification of SSSV Regulation I'm too young to be having a senior moment, but today sure has been just like one. You'd think I could remember an approval that I wrote less than 2 weeks ago. I apologize for all the extra work. I assume in your last email message that you are referring to P1-24 and not P1-24. You do not need anything else from the Commissian regarding the K-valve in P 1-24. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~~~r~~~~>~ ~y~~( E~ 2CGfi From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, December 01, 2008 3:07 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: P1-24 (PTD #1961490) Clarification of SSSV Regulation Jim, Thank you for the call earlier to explain the reasoning behind the approval, it helps me to understand why the regulations are in place instead of blindly following. Regarding P1-14, l talked with our Gas Lift Engineer and we were able to track down two documents. Both documents are enclosed in this email. The excel sheet contains specifics about the well and flow conditions, design specifications and bench testing results. I hope that this is the information that you need for the approval. The second document is an approval for the use of a K-Valve installation dated 11121/08. l do not know if additional information or another approval is required but if any other information is needed please let me know and I will find it and provide to you directly. Thank you, Taylor Wellman filling in for Anna DubefAndrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, December O1, 2008 9:53 AM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: P1-24 (PTD #1961490) Clarification of SSSV Regulation Jim, The well was brought online on 11/17/08 for the temporary flow period and K-Valve design evaluation. The well was flowed until being shut in for slickline installation of the K-Valve on 11/23f08. Following the installation the well was POP'ed on the evening of 11124108. The well was shut in an 11028108 and is still shut in to date. If you need additional information let me knew. 12/1 /2008 P1-24 (PTD #1961490) Clarification of SSSV Regulation Page 2 of 4 Thank you, Tayior Wellman filling in far Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, December O1, 2008 9:00 AM To: NSU, ADW Well Integrity Engineer Subject: RE: P1-24 (PTD #1961490) Clarification of SSSV Regulation is wail well flawing? If so, when was it brought on line? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Saturday, November 29, 2008 10:06 AM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: P1-24 (PTD #1961490) Clarification of SSSV Regulation Jim, Well P1-24 (PTD #1961490) had a proper calibrated K-Valve installed on 11124108. Thank you for approving the temporary flow period. Let me know if you would like any ether informatian about this installation ar well. Thank you, Taylor Wellman filiing in for Anna DubeJAndrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 14, 2008 1:53 PM To: NSU, ADW Well Integrity Engineer Cc: DOA AOGCC Prudhoe Bay Subject: RE: P1-24 (PTD #1961490) Clarification of SSSV Regulation Thank you far the quick response; flawing 7 days is acceptable. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, November 14, 2008 1:47 PM 12/1 /2008 P1-24 (PTD #1961490) Clarification of SSSV Regulation Page 3 of 4 To: Regg, James B (DOA) Subject: RE: P1-24 (PTD #1961490) Clarification of SSSV Regulation Jim, A K-valve was first set in P1-24 on August 14, 1998. However, now that we plan to reset the K-valve post-CTD sidetrack, we will submit paperwork for approval (to comply with the Guidance Bulletin No. 06-04). If we can flow the welt for 7 days, we should be able to obtain the required information for the approval request. Thank you, Andrea Hughes From: Regg, lames B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 14, 2008 11:59 AM To: NSU, ADW Well Integrity Engineer Subject: RE: P1-24 (PTD #1961490) Clarification of SSSV Regulation I don't see where Commission has approved a K-valve for P1-24; my records may not be complete. Guidance document addressing approval process for alternate SSSVs is attached. How long will the well need to be flowed to get necessary information to properly set dome charge in K-valve? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, November 14, 2008 11:36 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: P1-24 (PTD #1961490) Clarification of SSSV Regulation Jim and Tom, Well P1-24 (PTD #1961490) had a coiled tubing sidetrack that drilled two horizontal laterals, each approximately 2000' long with a slotted liner, in August of this year. The well remained shut-in until 10/09/08 when an ASRC test separator was used to flow the well. The test with ASRC found: 680 GFR with 17% WC, FWHT-58 F and FWHP was 786 psig, GOR was 1070 and total GOR was 7435 with the choke setting of 176 beans. Unfortunately, when the well was put into the pad test separator, it hydrated off. A coiled tubing clean out of the hydrate plug occurred on 11/06/08 and a new gas lift valve design was set on 11/09/08. The well is ready to be put on production. However, the parent well requires a K-valve be set for production and we do not have enough information to properly set the dome charge in the K-valve. The intention of this email is to obtain approval to place the well on production without a SSSV. Once adequate information is obtained, a K-valve will be set in the well and the information will be provided to you. 12/ 1 /2008 P1-24 (PTD #1961490) Clarification of SSSV Regulation Page 4 of 4 Please provide comments on our proposal as well as guidance on any misinterpretations of the SVS Regulations we may have made. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 12/1/2008 • SARAH PAL1Al, GOlfERNOR e~ ® ~ ®1`L V[l~y S 333 W 7th AVENUE. SUITE 100 ~~TT~~rr r ~ t~~y ~ { ~ T C®ei-7E~~Aii®li L®r~r~~`S''I®l~l ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 21, 2008 Mr. Johnny Kenda Gas Lift Engineer, PRB 20 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~~;;~) ~~' ~ ~° ~ ~~~~ Re: Prudhoe Bay Unit P 1-24 (PTD 1961490) Subsurface Controlled Subsurface Safety Valve Dear Mr. Kenda: By electronic mail dated November 18, 2008, BP Exploration (Alaska), Inc. (BPXA) requested approval to install an alternate subsurface safety valve in Prudhoe Bay Unit Well P 1-24 (PBU P 1-24). Alaska. Oil and Gas Conservation Commission (Commission) regulation 20 AAC 25.265(a)(2) provides for the approval of an alternate type of subsurface safety valve. Commission Guidance Bulletin No. 06-04 outlines the regulatory requirements to obtain approval for an alternate subsurface safety valve. BPXA's request to employ a subsurface controlled subsurface safety valve in PBU P 1-24 is GRANTED. Two horizontal lateral wellbore sections were completed from PBU P 1-24 using coil tubing drilling in August 2008. The wellbores remained shut-in until flow tested in early October by BPXA. Problems with hydrates required the installation of a redesigned gas lift valve which was accomplished on November 8, 2008. BPXA has provided the information necessary to make a decision about this valve, including the well's flow characteristics, valve design specifications and test rack data demonstrating the valve is capable of successfully halting flow from the well when the pressure above the valve is reduced below the established set point. Subsequent testing of PBU P1-24 must be conducted when the valve is installed and in conjunction with the scheduled tests of other safety valve systems on PBU P1-pad wells. Please contact the Commission at least 24 hours in advance for an opportunity to witness these tests. A tubing workover of PBU P1-24 will invalidate this approval and necessitate the reinstallation of a surface controlled subsurface safety valve. Sincerely, n ~I~L~~~1 ~• ,1~~~+ James B. Regg l / Sr. Petroleum Engineer AOGCC, request approval to install K-Valve in well P1-24 Page 1 of 1 Regg, James B (DOA) P~ l °l(~ - I Q-`~ From: GPB, Gas Lift Engr [GPBGasLiftEngr@BP.com] Sent: Tuesday, November 18, 2008 7:56 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: GPB, LPC DS Operator; GPB, LPC DS Ops Lead; Carr, Jessie L; Varble, Doug A; G NSU ADW Slickline PE Subject: AOGCC, request approval to install K-Valve in well P1-24 Attachments: P1-24 K-Valve Design 11-18-08 .xls Hello Jim, Thomas, Sys -- s~x- Per the AOGCC correspondence dated June 16, 2006, Bulletin No. 06-04 regarding subsurface controlled subsurface safety valves, I am requesting approval to install a "K" Valve in well NS15. P1-24 is a recent coil tubing drilling well that had a deep GLV installed on 11-09-08. We have recent well test data and want to install a K valve and keep the well on production. Attached is the K valve design sheet that contains all pertinent information/data regarding the well's flow characteristics, K-Valve configuration, trip/closure pressure, etc. We will wait on your approval prior to installing the K valve. Please notify me or Stan Groff if/once approval is granted and we will immediately install the valve. If you have any design questions please feel free to contact me. «P1-24 K-Valve Design 11-18-08 .xls» Thanks, Johnny Kenda Arctic Lift Systems Inc. GPB, Gas Lift Eng. 907-659-5863 907-659-3423 (p) 601-807-8992 (c) 11/18/2008 I~Dlll x~uwmwuaRrwa-s wen: P1-24 Date: 11 /18/2008 IoR: 400 Problem Description • Wireline Work Request AFE: PMP01WL24-C Engineer: Kends FTS: AWGRS Job Scope: ~ SSSV for Rate ~., ~s~o, P 1-24 Distribution Wireline (4) Reading File H2S Level: __- Well needs K-Valve set to meet stat regulations post deep GLD /CTD. Initial Problem Review Remedial Plan - WIRELINE ACTION Install "K" valve set at Test Rack/Shop Pressure of 851 psi @ 60 deg . _ {~ s F `~J~ r; - ~~ t,~~ r Psi --- ~, r~ c~~ - ' ~ =~ DSO to~roduce well at 920-950 pwh___ Date Work Completed Well Status/Results Date by Problem Resolved ? Y N Well Review (Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBUD) Avg. WC (%) Lift Gas (MMSCF/D) TGLR (SCF/STBL/D) FTP (psi)/Steady? CLP (psi)/Steady? Casing Press. (psi)/Steady? Orifice Depth: IA Fluid Level: Date of FL Survey: Follow-up Recommendations: / / Expected NOB: Actual NOB: __ _ _ MGOR used for NOB: MAINTENANCE ONLY (e.g. Fix AC, Shallower for Slugging) RATE (Non-Post-WW) (e.g. deepen, optimize orifice) Post-W ellwork • "K" Valve Calculation Sheet P1-24 Date: 11/18/07 Test Data Test Date Gross Fluid Rate Flowing Well Head Pressure Flowing Well Head Temperature GOR TGLR • 11 /17/08 677 BLPD 754 psi 57 deg F 100 scf/bbl 5642 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "K" Valve Setting Depth TVD 2197 ft '~ Flowing Tubing Pressure With Gas Lift 887 psi Flowing Tubing Pressure Without Gas Lift NA psi Flowing Tubing Pressure @ 887# Pwh 1174 psi ~~ t~a,Ct~ "K" Valve Test Rack Set Pressure at 60 deg F 851 psi Valve Size & Volume Ratio 4-1 /2" 1.314 i~l~~~~..F ~~~Uwli ~~~a~F~l~ f.a'a ai+~v~? ~t -~ ~;?~37'r Pwh • -- ~ i Tubing Pressure at Valve 1174 _ BPT (psia) 1188 >1238 <1238 emperature (deg F) at Valv 82 a 4.048E-06 6.7188E-06 b 1.050556 1.042548 _ Base Pressure __ __Base Temp (TV-60) 1140.16236 i 22; c , -1194.274 -1188.44972 -------- ----- ___ __ '; ' --- 1131.8654 1131.693457 - ----- Corrected Pressure__ -' 1131.693457 psia TCF 0.952283286 olume Ratio for_Valve Size = 1.314 ~ Pb @ 60 = 1117.98058 ---- - ------ --- Test Rack Pressure = 851 _ i i Volume Ratios _ ____ 4 1/2" & 5 1/2" 1.314 / 31/2" 1.257 _ __ 2 7/8" - 1.211 ---- - 2 3/8~~ 1.204 ----------; -- -- ~~ j `` 'TUt,bivv~ We[~L• P1-24 ~ GPMA ~ WEB Date: 4116/99 ftK6 P1-24 _ _ 2197 SSSV LN API: 500292270300 Well Type: PROD Angle @ TS: deg @ SSSV Type: CAT I -SSSV Ong Compltn: 10/3196 Angie @ TD: 45 deg @ 13080 Annular Fluid: DIESEL T Last W/O: Rev Reason: Schematic 2198 r changes Reference GR/LDT/CNL Ref Log Date: 9123/96 Last Update: 11/13/98 Log: ' Last Tag: 12379 ELMD TD: 13080 ftK6 4310 ~ Last Tag Date: 4/12/98 Max Hole 54 deg @ 6020 4311 I ~ 4 ?`-- ~ tSaYe ', Notes I Date Note 7397 ~' 10/1!96 Minimum ID: 3.725" OTIS XN NIPPLE AT 11436' MD 7398 E> '.-General Notes. __ I Date Note ~ 10/1/96 Tubing Hanger: FMC @ 29' MD 9744 F ~ 10/1/96 Well Status: NEW 9745 I Last Tag Depth @ 12470 T Of Fl id D th @ 1?965 op u ep _ Other`(plugs 'equip a#c.) -JEWELRY ., , 11343 (' Depth TVD Type Description ID ; ~ G 2197 2197 SSSV LN 4-112" CAMCO BAL-O SVLN, ID=3.812" - W/O WR SSSV 3.812 11344 , - , 11403 8497 PKR BAKER 7" S-3 PERMANENT PACKER, ID=3.875", 3.875 i, 11425 851 NIP HES' IPPLE 1 ' " , ID = 3.813 , 3.8 3 2 X N ~ t 11436 8519 NIP HES'XN' NIPPLE, ID = 3.725", 3.750 11403 PKR 11447 8526 WLEG TUBING TAIL W/VVIRELINE ENTRY GUIDE, ID=3.958", (11447' 3.958 ELMD) 11404 ` is 11448 8527 SQUEEZE SQUEEZE CEMENT DONUT F/ 11448-11493 3.700 DONUT Casin Shin s - All Size Weight Grade Top Btm Feet Description 11425 NIP ` 9.625 40.00 L-80 0 3386 3386 SUR. CASING 7.000 26.00 L-80 0 11108 11108 PROD. CASING 1142 7.000 29.00 13CR 11108 12470 1362 PROD. CASING 6 °'UtSin ;Strin -All t ize Weight Grade Top Btm Feet Description f 4.500 12.60 13CR 0 11447 11447 TUBING 11436 NIP ~ Gas Lift MandrelsNalves ' Stn MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date Vlv 11437 Mfr Type Run Comment 1 4310 4041 <BG-2-L: CA BK-1 1.0 BTM 0.250 2578 12!16/97 GLM ' INT ~ 2 7397 5934 CBG-2-L, CA BK-1 1.0 BTM 0.250 2556 2!27/98 GLM INT 11447 WLEG ; ~ 3 9744 7424<BG-2-L. CA DK 1.0 BTM 0.000 0 3/26/98 GLM INT 11448 SQUEEZE 4 11343 8458<BG-2-L: CA DKO-2 1.0 BTM 0.375 0 12/16/97 GLM DONUT '` ` INT ' Pertorations-Summary:... 11460 Interval TVD Zone Status Feet SPF Date Type Comment Squeeze ® ;{ ® 12030 - 8908 - 8934 40 44/20/97 3-3/8" GUNS - Frac'd 4/21/97 11470 12070 11480 ~: 12090 - 8947 - 9018 110 6 4/17/98 3-3/8" GUNS 11490 12200 -- 12220 - 9031 - 9063 50 6 4/17/98 3-3/8" GUNS 12040 Perf 12270 ___-_ Stimutations''8~ Treatments 12060 Interval Date Type Comment - 11465 - 11469 9!28!96 Squeeze SQUEEZED PERFS Perf 12264 - 12268 9/28!96 Squeeze SQUEEZED PERFS 12150 12276 - 12280 9/28/96 Squeeze SQUEEZED PERFS 12240 Perf 12265 Squeeze 12266 12267 12277 Squeeze 12278 12279 P1-24 (PTD #1961490) Clarification of SSSV Regulation Page 1 of 2 ~~ • Regg, James B (DOAj From: Regg, James B (DOA) '~®,~.y NII~~2o~~3 Sent: Friday, November 14, 2008 1:53 PM `~ l To: 'NSU, ADW Well Integrity Engineer' Cc: DOA AOGCC Prudhoe Bay Subject: RE: P1-24 (PTD #1961490) Clarification of SSSV Regulation Thank you for the quick response; flowing 7 days is acceptable. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, November 14, 2008 1:47 PM To: Regg, James B (DOA) Subject: RE: Pi-24 (PTD #1961490) Clarification of SSSV Regulation Jim, A K-valve was first set in P1-24 on August 14, 1998. However, now that we plan to reset the K-valve post-CTD sidetrack, we will submit paperwork for approval (to comply with the Guidance Bulletin No. 06-04). If we can flaw the well for 7 days, we should be able to obtain the required information for the approval request. Thank you, Andrea Hughes From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 14, 2008 11:59 AM To: NSU, ADW Well Integrity Engineer Subject: RE: P1-24 (PTD #1961490) Clarification of SSSV Regulation I don't see where Commission has approved a K-valve for P1-24; my records may not be complete. Guidance document addressing approval process for alternate SSSVs is attached. How long will the well need to be flowed to get necessary information to properly set dome charge in K-valve? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11 /14/2008 P1-24 (PTD #1961490) Clarification of SSSV Regulation Page 2 of 2 ~~ ~ • From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, November 14, 2008 11:36 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: P1-24 (PTD #1961490) Clarification of SSSV Regulation Jim and Tom, Well P1-24 (PTD #1961490) had a coiled tubing sidetrack that drilled two horizontal laterals, each approximately 2000' long with a slotted liner, in August of this year. The well remained shut-in until 10/09/08 when an ASRC test separator was used to flow the well. The test with ASRC found: 680 GFR with 17% WC, FWHT-58 F and FWHP was 786 psig, GOR was 1070 and total GOR was 7435 with the choke setting of 176 beans. Unfortunately, when the well was put into the pad test separator, it hydrated off. A coiled tubing clean out of the hydrate plug occurred on 11/06/08 and a new gas lift valve design was set on 11/09/08. The well is ready to be put on production. However, the parent well requires a K-valve be set for production and we do not have enough information to properly set the dome charge in the K-valve. The intention of this email is to obtain approval to place the well on production without a SSSV. Once adequate information is obtained, a K-valve will be set in the well and the information will be provided to you. Piease provide comments on our proposal as well as guidance on any misinterpretations of the SVS Regulations we may have made. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 11 / 14/2008 07/03/08 ~~~~~mU~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO.4768 Company: State of Alaska Alaska Oil & Gas Cons Comm ~~~~~ J~~ ~ ~ 2~Ut3 Attn: Christine Mahnken ~` U 333 West 7th Ave, Suite 100 Anchorage, AK 99501 U/nll Inh ~ MPB-50 11999019 ___ _____- --_-. RST WFL ~ __.~ 06/13/08 .... 1 ........ v.. 1 M-04 11962601 PRODUCTION PROFILE 06/21/08 1 1 Pi-24 12066527 MEM LDL G?`'°' f 06/18/08 1 1 04-11A 11975778 LDL ~~, a- / 06/24/08 1 1 M-04 11962601 PRODUCTION PROFILE _ 06/21/08 1 1 12-03 12071857 USIT d (. `(p -~ 06/21/08 1 1 GNI-03 12066530 MEM PRESS/TEMP LOG '~.~ G 06/20/08 1 1 E-10B 40016750 OH MWD/LWD EDIT 04/05/08 2 1 18-13B 11972960 MCNL v°~-- (0 12/07/07 1 1 18-13B 12021159 MCNL v'}..- ~ 05/18/08 1 1 .._....~..~~.-.......~.. `... .... .,...............v ...-. vnnn`.V v.v~ vvr ~ CAVfI ~ V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. , Anchorage, Alaska 99508 Date Delivered: i ., ty Ir ~l, / .. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth / ~ / Received by: _ .-~ - C. THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 PL M ATE E IA W C:LOR. I~MF1LM. DOC L U N D E-'-'--'-~ TH IS M ARK ER------ STATE OF ALASKA -- ALASK .... ~IL AND GAS CONSERVATION COMMI[ .)N REPOR"m OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Perforate ~ Pull tubing __ Alter casing __ Repair well __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 3913' FNL, 964' FEL, Sec. 16, T12N, R14E At top of production interval 2475' FNL, 1386' FEL, Sec. 9, T12N, R14E At effective depth At total depth 1598' FNL, 1394' FEL, Sec. 9, T12N, R14E Datum elevation (DF or KB) KB 43.1 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P1-24 9. Permit number/approval number 96-149 / 10. APl number 500292270300 I1. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured: Effective Depth: Casing Conductor Surface Intermediate Liner true vertical: measured: true vertical: Length 110' 3386' Size 20" 9 5/8" 11108' 7" 13080 feet Plugs (measured) 9593 feet 12379 feet 9133 feet Cemented 260 SX Arcticset 1290 sx CS III, 327 sx Class G, 250 sx CS II 385 sx Class G Junk (measured) None. None. Measured depth True vertical depth 110' 110' 3386' 3356' 11108' 8304' Perforation depth: measured 12030-12070', 12090-12200', 12220-12270' true vertical 8864-8890', 8903-8974', 8987-9019' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 13CR @ 0-11447' MD, Packers and SSSV (type and measured depth) 3 7/8 X 7 PKR @ 11403' MD, 3 4/5 x 4 1/2 SSSV @ 2197' MD JUL 22 1999 Alaska 0ii & Gas Cons. C0mmissi~ Anchorage 13. stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14, Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 964 3775 58 180 Subsequent to operation 1822 4212 294 180 16. Status of well classification as: Oil ~ Gas __ Suspended 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Date 17. I hereby cerff~.that the foregoi.~ is .flue and correct to the best of my knowledge. Signed Title Tubing Pressure 773 775 Service ' 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P1-24 DESCRIPTION OF WORK COMPLETED ADDED PERFORATIONS Date Event Summary 04-17-1998 RIH w/3 3/8"HSD guns and added pedorations at: 12090'-12200' MD 12220'-12270' MD AIIshots at6 SPF, 60 deg phasing and random orientation. Well' P1-24 SSSV LN -- PKR ~ NIP ~ NIP ~ WLEG SQUEEZE DONUT Squeeze Perf Ped -- Perf -- GPMA WEB Date' 4/16/99 APl: 500292270300 SSSV Type: CAT I - SSSV Annular Fluid: DIESEL T Reference GR/LDT/CNL Log: Last Tag: 12379' ELMD Last Tag Date: 4/12/98 Well Type: PROD Orig Compltn: 10/3/96 Last W/O: Ref Log Date: 9~23~96 TD: 13080 ftKB Max Hole 54 deg @ 6020 Angle: Angle @ TS: deg @ Angle @ TD: 45 deg @ 13080 Rev Reason: Schematic changes Last Update: 11/13/98 Date Note 10/1/96 Minimum ID: 3.725" OTIS XN NIPPLE AT 11436' MD ~'rai Nbte:~?: ;:::::ii:~:-?:i ?:::-i ~ i il iii!i-,i !:::.::: ii!i-' i::i~.i:i, ii i~:;?:: !-i:ii~iii~: :'i !:?:~i~!::-i ii '"-:::i :'.'il ~:i:'.: ;::' :. ~.::':: ':,i:~:::.;'!'.!ii: Date Note 10/1/96 Tubing Hanger: FMC @ 29' MD 10/1/96 Well Status: NEW Last Tag Depth @ 12470 Top Of Fluid Depth @ 11965 ii::'~!:JEW:E~Ry ;.i .'!-: .i: :.ii !i;-::~:.' .:: ~:-':ili ::i~ ~ ::'~:~-I'~ i i!i!iiiii::!: :~;!i:!:~?.:i i:- !: i-i!'::~:.' i:~'!::!i~'~:': :.!~:.'-i:::i ':' !':.!-" ?:~ii:~::::?:'ii~.~: Depth TVD Type Description ID 2197 2197 SSSV LN 4-1/2" CAMCO BAL-O SVLN, ID=3.812" - W/O WR SSSV 3.812 11403 8497 PKR BAKER 7" S-3 PERMANENT PACKER, ID=3.875", 3.875 11425 8512 NIP HES 'X' NIPPLE, ID = 3.813", 3.813 11436 8519 NIP HES 'XN' NIPPLE, ID = 3.725", 3.750 11447 8526 WLEG TUBING TAIL WNVIRELINE ENTRY GUIDE, ID=3.958", (11447' 3.958 ELMD) 11448 8527 SQUEEZE SQUEEZE CEMENT DONUT F/11448-11493 3.700 DONUT Size Weight G-rade Top Btm Feet Description 9.625 40.00 L-80 0 3386 3386 SUR. CASING 7.000 26.00 L-80 0 11108 11108 PROD. CASING 7.000 29.00 13CR 11108 12470 1362 PROD. CASING i::i :ii: ~ '. ~ .::: : :~'~'ii ~ Size Weight Grade Top Btm Feet Description 4.500 12.60 13CR 0 11447 11447 TUBING Stn MD TVD Man Man VMfr VType Mfr Type 1 4310 4041(BG-2-L,~ CA BK-1 2 7397 5934(BG-2-L,~ CA BK-1 3 9744 7424 (BG-2-L,~ CA DK 4 11343 8458(BG-2-L,~ CA DK0-2 V OD Latch Port TRO Date VIv Run Commer 1.0 BTM 0.250 2578 12/16/97 GLM INT 1.0 BTM 0.250 2556 2/27~98 GLM INT 1.0 BTM 0.000 0 3/26/98 GLM INT 1.0 BTM 0.375 0 12/16/97 GLM INT InterVal TVD Zone Status Feet SPF Date Type Comment 12030 - 8908 - 8934 40 4 4/20/97 3-3/8" GUNS - Frac'd 4/21/97 12070 12090 - 8947 - 9018 110 6 4/17/98 3-3~8" GUNS 12200 12220 - 9031 - 9063 50 6 4/17/98 3-3/8" GUNS 12270 Interval Date Type 1465 - 11469 9/28/96 Squeeze 2264 - 12268 9/28/96 Squeeze 2276 - 12280 9/28/96 Squeeze Comment SQUEEZED PERFS SQUEEZED PERFS SQUEEZED PERFS Squeeze Squeeze STATE OF ALASKA ALASKA ~-~" AND GAS CONSERVATION COMMIS~-N REPORT SUNDRY WELL OPERATI JNS · Operations performed: Operation shutdown __ Stimulate~ Plugging__ Perforate __ Pull tubing __ Alter casing __ Repair well __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 Location of well at surface 3913' FNL, 964' FEL, Sec. 16, T12N, R14E At top of production interval 2475' FNL, 1386' FEL, Sec. 9, T12N, R14E At effective depth At total depth 1598' FNL, 1394' FEL, Sec. 9, T12N, R14E 5. Type of Well: Development~_ Exploratory __ Stratigraphic __ Service __ Datum elevation (DF or KB) KB 43.1 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P1-24 9. Permit number/approval number 96-149 / 10. APl number 500292270300 11. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Size Conductor 110' 20" Surface 3386' 9 5/8" Intermediate Liner 11108' 7" 13080 feet Plugs (measured) 9593 feet 12379 feet 9133 feet Cemented Junk (measured) 260 sx Arcticset 1290 sx CS III, 327 sx Class G, 250 sx CS II 385 sx Class G None. None. Measured depth True vedical depth 110' 110' 3386' 3356' 11108' 8304' Perforation depth: measured 12030-12070' true vertical 8864-8890' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 13CR @ 0-11447' MD Packers and SSSV (type and measured depth) 3 7/8 X 7 PKR @ 11403' MD, 3 4/5 x 4 1/2 SSSV @ 2197' MD RECEIVED JUL 22 1999 AJaska Oil & -¢~s Cor,~. Commission 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Please refer to attached. ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 967 3667 91 1700 .2460 6446 380 1400 Tubing Pressure 800 762 5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1S~ i In he i ~°,r~/~_.~s_t rue Form 10-404 Rev 06/15/88 I16. Status of well classification as: Oil~x Gas __Suspended and correct to the best of my knowledge· Title ~l ,~' ~ Date Service SUBMIT IN DUPLICAT '"E'''-'''~L'~ P1-24 DESCRIPTION OF WORK COMPLETED HYDRAULIC REFRACTURE STIMULATION TREATMENT Date Event Summary 12-08-1997 Performed Hydraulic Refracture Treatment to stimulate perforations at: 12030'-12070' MD The job was performed in the following stages: a) MIRU. b) Pumped Breakdown Treatment of 50# Cross-Linked Gel into perforations. c) Pumped Scour Stage of 2011# 16/20 Carbolite Proppant into perforations. Final treating pressure was 5600 psig. d) Pumped Data Frac w/Cross-Linked Gel into perforations. e) Determined ISIP = 2434 psig. f) Pumped Hydraulic Propped Fracture Treatment into perforations with average treating pressure of 4500 psig. g) Placed 2007# 20/40 Carbolite* and additional 143138# 16/20 Carbolite* into the formation. (*Carbolite contained Dowell PropNet fibers to help ensure proppant retention in formation.) h) Frac screened out while pumping 14 ppg stage. i) RDMO. Well' P1-24 SSSV LN -- PKR ~ NIP ~ NIP ~ WLEG SQUEEZE DONUT Squeeze [] Perf '_ Perf -- Perf · GPMA WEB Date: 4116/99 APl: 500292270300 SSSV Type: CAT I - SSSV Annular Fluid: DIESEL T Reference GR/LDT/CNL Log: Last Tag: 12379' ELMD Last Tag Date: 4/12/98 Well Type: PROD Orig Compltn: 10/3/96 Last W/O: Ref Log Date: 9~23~96 TD: 13080 ftKB Max Hole 54 deg @ 6020 Angle: Angle @ TS: deg @ Angle @ TD: 45 deg @ 13080 Rev Reason: Schematic changes Last Update: 11/13/98 Date Note 10/1/96 Minimum ID: 3.725" OTIS XN NIPPLE AT 11436' MD Gehei~ai Nbte.~': Date Note 10/1/96 Tubing Hanger: FMC @ 29' MD 10/1/96 Well Status: NEW Last Tag Depth @ 12470 Top Of Fluid Depth @ 11965 Depth TVD Type Description ID 2197 2197 SSSV LN 4-1/2" CAMCO BAL-O SVLN, ID=3.812" - W/O WR SSSV 3.812 11403 8497 PKR BAKER 7" S-3 PERMANENT PACKER, ID=3.875", 3.875 11425 8512 NIP HES 'X' NIPPLE, ID = 3.813", 3.813 11436 8519 NIP HES 'XN' NIPPLE, ID = 3.725", 3.750 11447 8526 WLEG TUBING TAIL W/WIRELINE ENTRY GUIDE, ID=3.958", (11447' 3.958 ELMD) 11448 8527 SQUEEZE SQUEEZE CEMENT DONUT F/11448-11493 3.700 DONUT Size Weight Grade Top Btm Feet Description 9.625 40.00 L-80 0 3386 3386 SUR. CASING 7.000 26.00 L-80 0 11108 11108 PROD. CASING 7.000 29.00 13CR 11108 12470 1362 PROD. CASING All: ~ : ~' ....: ":::~ '':i · :: ::: : ::: :! Size Weight Grade Top Btm Feet Descfipt~-on 4.500 12.60 13CR 0 11447 11447 TUBING Stn MD TVD Man Mfr I 4310 4041(BG-2-L,~ 2 7397 5934(BG-2-L,~ 3 9744 7424 (BG-2-L,~ 4 11343 8458(BG-2-L,~ Man VMfr VType VOD Latch Port TRO Date Vlv Type Run Comment CA BK-1 1.0 BTM 0.250 2578 12/16/97 GLM INT CA BK-1 1.0 BTM 0.250 2556 2/27/98 GLM INT CA DK 1.0 BTM 0.000 0 3/26/98 GLM INT CA DK0-2 1.0 BTM 0.375 0 12/16/97 GLM INT In-~-~a ~vb 12030- 8908-8934 12070 12090- 8947-9018 12200 12220- 9031-9063 12270 Zone Status FeetSPF Date Type Comment 40 4 4/20/97 3-3/8" GUNS - Frac'd 4/21/97 110 6 4/17/98 3-3/8" GUNS 50 6 4/17/98 3-3/8" GUNS Interval Date Type 11465 - 11469 9/28/96 Squeeze 12264- 12268 9/28/96 Squeeze 12276- 12280 9/28/96 Squeeze Comment SQUEEZED PERFS SQUEEZED PERFS SQUEEZED PERFS Squeeze Squeeze STATE OF ALASKA ALASKA '--"_ AND GAS CONSERVATION COMMIS,'C~---'N REPOR'f SUNDRY WELL OPERATIuNS Operations performed: Operation shutdown __ Stimulate .~ Plugging Pull tubing __ Alter casing __ Repair well __ Pedorate Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 Location of well at surface 3913' FNL, 964' FEL, Sec. 16, T12N, R14E At top of production interval 2475' FNL, 1386' FEL, Sec. 9, T12N, R14E At effective depth At total depth 1598' FNL, 1394' FEL, Sec. 9, T12N, R14E 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Size Conductor 110' 20" Surface 3386' 9 5/8" Intermediate Liner 11108' 7" 5. Type of Well: Development/~___~_ Explorato~ ___. 13080 feet 9593 feet 12379 feet 9133 feet Cemented Stratigraphic __ Service __ Datum elevation (DF or KB) KB 43.1 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P1-24 ~9. Permit number/approval number 96-149 / 0. APl number 500292270300 11. Field/Pool Point Mclntyre Plugs (measured) None. Junk (measured) None. 260 sx Arcticset 1290 sx CS III, 327 sx Class G, 250 sx CS II 385 sx Class G Measured depth True vertical depth 110' 110' 3386' 3356' 111O8' 83O4' Perforation depth: measured 12030-12070' true vertical 8864-8890' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 13CR @ 0-11447' MD, Packers and SSSV (type and measured depth) 37/8X7 PKR @ 11403' MD, 3 4/5 x 4 1/2 SSSV @ 2197' MD RECE1V ED JUL 22. 19 9 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Please refer to attached. ORIGINAL Prior to well operation Subsequent to operation Representative Daily Avemqe Production or Iniection D~a OiI-Bbl Gas-Mcf W~er-Bbl Casing Pressure Tubing Pressure 0 0 0 500 700 2350 4938 116 100 800 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 certi t the f regoing ' ~nd correct to the best of my knowledge. S 'gn~~.e ~ ,.. ~'~ ..... Title '~'/'~' ¢¢ ,.'v' ¢'¢,-7'~' Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P1-24 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE STIMULATION TREATMENT Date Event Summary 04-21-1997 Performed Hydraulic Fracture Treatment to stimulate the perforations at: 12030'-12070' MD The job was performed in the following stages: a) MIRU. b) Pumped Breakdown Treatment of 50# Cross-Linked Gel into perforations. c) Pumped Scour Stage of 2011# 16/20 Carbolite Proppant into perforations. Final treating pressure was 3700 psig. d) Pumped Data Frac w/Cross-Linked Gel into perforations. e) Determined ISIP = 2320 psig. f) Pumped Hydraulic Propped Fracture Treatment into perforations with average treating pressure of 4267 psig. g) Placed additional 101774# 16/20 Carbolite and 39936# 12/18 Carbolite into the formation. h) Frac screened out while pumping flush. i) RDMO. Well' P1-24 SSSV LN -- PKR -- NIP -- NIP -- WLEG SQUEEZE DONUT Squeeze Perf -- Perf -- Per'[ · - Squeeze Squeeze GPMA WEB Date: 4/16/99 APl: 500292270300 Well Type: PROD -Angle @ TS: deg @ SSSV Type: CAT I - SSSV Annular Fluid: DIESEL T Reference GR/LDT/CNL Log: Last Tag: 12379' ELMD Last Tag Date: 4/12/98 Orig Compltn: 10/3/96 Last W/O: Ref Log Date: 9123196 TD: 13080 ffKB Max Hole 54 deg ~ 6020 Angle @ TD: 45 deg @ 13080 Rev Reason: Schematic changes Last Update: 11/13/98 Angle: Date Note 10/1/96 Minimum ID: 3.725" OTIS ×N NIPPLE AT 11436' MD G~h~i:N~te~:!i : .~::: .:iii::'i :: ~:~ ii~ i~ ~ i ~ Date Note 10/1/96 Tubing Hanger: FMC @ 29' MD 10/1/96 Well Status: NEW Last Tag Depth @ 12470 Top Of Fluid Depth @ 11965 :Othe~i(~I~:g~i~;:~tC:~)~JEWEERY: . :: .-:..: . : ~ ~ Depth TVD Type Description ID 2197 2197 SSSV LN 4-1/2" CAMCO BAL-O SVLN, ID=3.812" - W/O WR SSSV 3.812 11403 8497 PKR BAKER 7" S-3 PERMANENT PACKER, ID=3.875", 3.875 11425 8512 NIP HES 'X' NIPPLE, ID = 3.813", 3.813 11436 8519 NIP HES 'XN' NIPPLE, ID = 3.725", 3.750 11447 8526 WLEG TUBING TAIL W/WIRELINE ENTRY GUIDE, ID=3.958", (11447' 3.958 ELMD) 11448 8527 SQUEEZE SQUEEZE CEMENT DONUT F/11448-11493 3.700 DONUT Size Weight Grade Top Btm Feet Description 9.625 40.00 L-80 0 3386 3386 SUR. CASING 7.000 26.00 L-80 0 11108 11108 PROD. CASING 7.000 29.00 13CR 11108 12470 1362 PROD. CASING Tubing':stfing~..'AIl~-~'..i.__~ _"~ '.~ 'i ~:i: ~: ~:: ~i:i:i' Size Weight Grade Top Btm Feet Description 4.500 12.60 13CR 0 11447 11447 TUBING Ga~EiffMahdre!s/Valves -~ i:'~: ;;.-:;: ~ ~ ; ~ : ; ::_ stn MD TVD Man Man VMfr VType Mfr Type 1 4310 4041(BG-2-L~ CA BK-1 2 7397 5934(BG-2-L,~ CA BK-1 3 9744 7424 (BG-2-L,~ CA DK 4 11343 8458(BG-2-L,~ CA DK0-2 V OD Latch Port TRO Date VIv Run Comment 1.0 BTM 0.250 2578 12/16/97 GLM INT 1.0 BTM 0.250 2556 2/27/98 GLM INT 1.0 BTM 0.000 0 3/26/98 GLM INT 1.0 BTM 0.375 0 12/16/97 GLM INT Interval 'rVD Zone Status FeetSPF Date Type 12030 - 8908 - 8934 40 4 4/20197 12070 12090 - 8947 - 9018 110 6 4/17/98 12200 12220 - 9031 - 9063 50 6 4/17/98 12270 Comment 3-3~8" GUNS - Frac'd 4/21/97 3-3/8" GUNS 3-3/8" GUNS Interval Date Type 11465 - 11469 9/28/96 Squeeze 12264- 12268 9/28/96 Squeeze 12276- 12280 9/28~96 Squeeze Comment SQUEEZED PERFS SQUEEZED PERFS SQUEEZED PERFS STATE OF ALASKA ALASK/~ .... 'L AND GAS CONSERVATION COMMIS," REPORT OF SUNDRY WELL OPERATIUNS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Perforate '~__ Pull tubing __ Alter casing __ Repair well __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 3913' FNL, 964' FEL, Sec. 16, T12N, R14E At top of production interval 2475' FNL, 1386' FEL, Sec. 9, T12N, R14E At effective depth At total depth 1598' FNL, 1394' FEL, Sec. 9, T12N, R14E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service __ Datum elevation (DF or KB) KB 43.1 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P1-24 9. Permit number/approval number 96-149 / 10. APl number 500292270300 11. Field/Pool Point Mclntyre 2. Present well condition summary Total Depth: measured: Effective Depth: Casing Conductor Surface Intermediate Liner true vertical: measured: true vertical: Length 110' 3386' Size 20" 9 5/8" 11108' 7" 13080 feet 9593 feet 12379 feet 9133 feet Cemented Plugs (measured) Junk (measured) 260 SX Arcticset 1290 sx CS III, 327 sx Class G, 250 sx CS II 385 sx Class G None. None. Measured depth True vertical depth 110' 110' 3386' 3356' 11108' 8304' Perforation depth: measured 12030-12070' true vertical 8864-8890' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 13CR @ 0-11447' MD, Packers and SSSV (type and measured depth) 3 7/8 X 7 PKR @ 11403' MD, 3 4/5 x 4 1/2 SSSV @ 2197' MD RECEIVED JUL 22 1 99 Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Representative Da ly Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 0 0 0 160 Subsequent to operation 0 0 0 160 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operation,~_ Tubing Pressure 0 75O I16. Status of well classification as: __ Suspended Oil ~ Gas 17. I hereby ~ th true and correct to the best of my knowledge. Isigne~~,~h,//Y~ Title Date Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P1-24 DESCRIPTION OF WORK COMPLETED ADDED PERFORATIONS Date Event Summary 04-20-1997 RIH w/3 3/8" guns and added perforations at: 12030' - 12070' M D All shots at 4 SPF and 180 deg phasing. Well: P1-24 SSSV LN -- PKR -- NIP -- NIP -- WLEG SQUEEZE DONUT Squeeze Perf - Perf .. Perf - Squeeze Squeeze GPMA WEB Date' 4/16/99 APl: 500292270300 SSSV Type: CAT I - SSSV Annular Fluid: DIESEL T Reference GPJLDT/CN L Log: Last Tag: 12379' ELMD Last Tag Date: 4/12/98 Well Type: PROD Odg Compltn: 10/3/96 Last W/O: Ref Log Date: 9/23/96 TD: 13080 ftKB Max Hole 54 deg @ 6020 Angle: Angle @ TS: deg @ Angle @ TD: 45 deg @ 13080 Rev Reason: Schematic changes Last Update: 11/13/98 Date Note 10/1/96 Minimum ID: 3.725" OTIS XN NIPPLE AT 11436' MD G~t~lN~te~iii:.! ~.j i ~ ::~.~:: :, '~:~:. i ' Date Note 10/1/96 Tubing Hanger: FMC @ 29' MD 10/1/96 Well Status: NEW Last Tag Depth @ 12470 Top Of Fluid Depth @ 11965 Depth TVD Type Description ID 2197 2197 SSSV LN 4-1/2" CAMCO BAL-O SVLN, ID=3.812" - W/O WR SSSV 3.812 11403 8497 PKR BAKER 7" S-3 PERMANENT PACKER, ID=3.875", 3.875 11425 8512 NIP HES 'X' NIPPLE, ID = 3.813", 3.813 11436 8519 NIP HES 'XN' NIPPLE, ID = 3.725", 3.750 11447 8526 WLEG TUBING TAIL WNVIRELINE ENTRY GUIDE, ID=3.958", (11447' 3.958 ELMD) 11448 8527 SQUEEZE SQUEEZE CEMENT DONUT F/11448-11493 3.700 DONUT Size Weight Grade Top Btm Feet Description 9.625 40.00 L-80 0 3386 3386 SUR. CASING 7.000 26.00 L-80 0 11108 11108 PROD. CASING 7.000 29.00 13CR 11108 12470 1362 PROD. CASING Al!:..:~-:~--: :: ~:: :::::i!_ Size Weight Grade Top Btm Feet Description 4.500 12.60 13CR 0 11447 11447 TUBING Ga~:Eift.Mand~ei~/valVeS~:~J~!':-'J ~::"_ i.::::':::: : :i ::: ~: :: Stn MD 'FVD Man Man VMfr VType Mfr Type 1 4310 4041(BG-2-L.~ CA BK-1 2 7397 5934(BG-2-L.~ CA BK-1 3 9744 7424 (BG-2-L.~ CA DK 4 11343 8458(BG-2-L.~ CA DK0-2 V OD Latch Port TRO Date Vlv Run Comment 1.0 BTM 0.250 2578 12/16/97 GLM INT 1.0 BTM 0.250 2556 2/27/98 GLM INT 1.0 BTM 0.000 0 3/26/98 GLM INT 1.0 BTM 0.375 0 12/16/97 GLM INT Interval TVD Zone Status FeetSPF Date Type 12030- 8908-8934 40 4 4~0/97 12070 12090- 8947-9018 110 6 4/17/98 12200 12220- 9031-9063 50 64/17/98 12270 Comment 3-3/8" GUNS - Frac'd 4/21/97 3-3/8" GUNS 3-3/8" GUNS Interval Date Type 11465 - 11469 9/28/96 Squeeze 12264- 12268 9/28/96 Squeeze 12276- 12280 9/28/96 Squeeze Comment SQUEEZED PERFS SQUEEZED PERFS SQUEEZED PERFS STATE OF ALASKA ALASK/''~-~' 'L AND GAS CONSERVATION COMMIS'--"~N REPOR'I OF SUNDRY WELL OPERATIUNS · Operations performed: Operation shutdown__ Stimulate_ Plugging~ Perforate __ Pull tubing __ Alter casing __ Repair well __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 3913' FNL, 964' FEL, Sec. 16, T12N, R14E At top of production interval 2475' FNL, 1386' FEL, Sec. 9, T12N, R14E At effective depth At total depth 1598' FNL, 1394' FEL, Sec. 9, T12N, R14E 5. Type of Well: Development~__ Exploratory __ Stratigraphic __ Service __ Datum elevation (DF or KB) KB 43.1 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P1-24 9. Permit number/approval number 96-149 / 0. APl number 500292270300 11. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Size Conductor 110' 20" Surface 3386' 9 5/8" Intermediate Liner 111O8' 7" 13080 feet Plugs (measured) 9593 feet 12379 feet 9133 feet Cemented Junk (measured) 260 SX Arcticset 1290 sx CS III, 327 sx Class G, 250 sx CS II 385 sx Class G None. None. Measured depth True vedical depth 110' 110' 3386' 3356' 11108' 8304' Perforation depth: measured 11465' - 11469' true vertical 8538' - 8541' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 13CR @ 0-11447' MD, Packers and SSSV (type and measured depth) 3 7/8 X 7 PKR @ 11403' MD, 3 4/5 x 4 1/2 SSSV @ 2197' MD RECEIVED JUL 22 1999 Alaska Oil & Gas Cons. Commission Anchorage 13. stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Please referto aEached. ORIGINAL 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1800 100 Subsequent to operation 0 0 0 250 100 15. Attachments ~16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ~ Oil ~ Gas __ Suspended ~Service 17. I hereby certiJ:y that theJ.oregojng~ true and correct to the best of my knowledge. S igne¢~~~~-~~)~___~ ,' . Title r,~/"'"'t,~~ Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P1-24 DESCRIPTION OF WORK COMPLETED ACID WASH AND SQUEEZE PERFORATIONS Date Event Summary 02-17-1997 Performed an Acid Wash and Squeeze to stop leaking perforations at: 11465' - 11469' MD CTU placed temporary sand plug in casing in preparation for job. Top of sand plug at 11502' MD to isolate perforations below that depth. The job was then performed using the following procedure: MIRU coiled tubing unit and acidizing equipment. Pumped the following with top acidizing fluids in the order listed: a) 29 bbls 2% NH4CI, followed by b) 9 bbls 50% diesel/40% xylene/10% mutual solvent at 1.2 bpm, followed by c) 30 bbls DAD acid (12% HCI/10% xylene/3% acetic acid) at 1.3 bpm, followed by d) 16 bbls mud acid (6% HCI/0.75% HF/3% acetic acid) at 1.3 bpm, followed by e) 15 bbls DAD acid (12% HCI/10% xylene/3% acetic acid) at 1.3 bpm, followed by f) 80 bbls 2% NH4CI, followed by g) 33 bbls 1% KCI water Noted approximately 50 psi break in treating pressure with acid on perfs. RD acidizing equipment and MIRU cementing equipment. Pumped the following fluids in the order listed to squeeze the perforations: a) 88 bbls 1% KCI water, followed by b) 15 bbls neat Liquid Latex Acid Resistant (LARC) cement, followed by c) 35 bbls 1% KCI water With 2 bbls LARC out end of tubing, wellhead pressure increased to 3000 psi and broke over indicating frac'ing cement away. Laid in rest of cement in casing. Attempted hesitation squeeze pumping 1.5# Biozan gel but not successful. Displaced cement into perforations with 1.5# Biozan (approx. 5 bbl overflush). Freeze protected well with 50 bbls crude and standback CTU injector for night. 02-18-1997 03-04-1997 03-16-1997 03-28-1997 04-05thru 04-07-1997 Reinstall CTU injector on wellhead. Pumped the following fluids in the order listed to squeeze the above noted perforations: a) 200 bbls 1% KCI water, followed by b) 5 bbls neat LARC, followed by c) 22 bbls LARC w/4.5#/bbl of Nycon fibers, followed by d) 34 bbls 1% KCI water Injected 25 bbls cement in squeeze perfs at 1.5 bpm, and left fiber cement plug in wellbore at 11,474' MD. RDMO CTU and cementing equipment. MIRU CTU to underream cement plug. Pressure test plug to 4500 psig - leaked to 4350 psig in 5 minutes. No injection established. Underreamed cement plug and cement/sand interface from 11,474' to 11,510' MD. Pressure tested squeeze to 4500 psig - failed. Established injectivity rate of 0.75 bpm at 3990 psig. Freeze protected well and RDMO CTU. Reestablished sand plug with top at 11,493' MD. MIRU CTU and cementing equipment. Pumped the following fluids in the order listed to squeeze the above noted perforations: a) 20 bbls 1% KCI water, followed by b) 5 bbls neat LARC, followed by c) 14 bbls LARC w/fibers, followed by d) 35 bbls 1% KCI water Squeezed cement to 4000 psig WHP for one hour placing less than 1 bbl cement behind pipe. Cleaned out excess cement to 11,435' CTM, leaving fiber cement plug from there down to top of sand plug. Freeze protected well and RDMO CTU. MIRU CTU. Milled cement from 11,430' to 11,483' CTM and cleaned out sand plug to 12,130' CTM. Freeze protected well and RDMO CTU. Well' P1-24 SSSV LN -- PKR -- NIP -- NIP -- WLEG -- SQUEEZE -- DONUT Squeeze Perf -- Perf - Perf Squeeze Squeeze GPMA WEB Date: 4/16/99 APl: 500292270300 SSSV Type: CAT I - SSSV Annular Fluid: DIESEL T Well Type: PROD Orig Compltn: 10/3/96 Last W/O: Reference GPJLDT/CNL Ref Log Date: 9/23/96 Log: Last Tag: 12379' ELMD Last Tag Date: 4/12/98 ~afety Note~ :: i i : : : TD: 13080 ftKB Max Hole 54 deg @ 6020 Angle: Angle @ TS: deg @ Angle @ TD: 45 deg @ 13080 Rev Reason: Schematic changes Last Update: 11/13/98 Date Note 10/1/96 Minimum ID: 3.725" OTIS XN NIPPLE AT 11436' MD Date Note 10/1/96 Tubing Hanger: FMC @ 29' MD 10/1/96 Well Status: NEW Last Tag Depth @ 12470 Top Of Fluid Depth @ 11965 Othe~'.(~l~§~,' eq~ipj etc~)~ ~jEWEERY ~ :: : : Depth TVD Type Description 2197 2197 SSSV LN 4-1/2" CAMCO BAL-O SVLN, ID=3.812" - W/O WR SSSV 11403 8497 PKR BAKER 7" S-3 PERMANENT PACKER, ID=3.875", 11425 8512 NIP HES 'X' NIPPLE, ID = 3.813", 11436 8519 NIP HES '×N' NIPPLE, ID = 3.725", 11447 8526 WLEG TUBING TAIL WNVIRELINE ENTRY GUIDE, ID=3.958", (11447' ELMD) 11448 8527 SQUEEZE SQUEEZE CEMENT DONUT F/11448-11493 DONUT ID 3.812 3.875 3.813 3.750 3.958 3.700 Size Weight Grade Top Btm Feet Description 9.625 40.00 L-80 0 3386 3386 SUR. CASING 7.000 26.00 L-80 0 11108 11108 PROD. CASING 7.000 29.00 13CR 11108 12470 1362 PROD. CASING Tubih~ StH~:AI,i : : : :::: :: ::: :i: : : : : i: : '1 Size Weight Grade Top Btm Feet Description 4.500 12.60 13CR 0 11447 11447 TUBING G~EiftiM~drel~/Valve~i::::: : : :: : :: Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Date Vlv Mfr Type Run Comment 1 4310 4041 (BG-2-L,~ CA BK-1 1.0 BTM 0.250 2578 12/16/97 GLM INT 2 7397 5934(BG-2-L,~ CA BK-1 1.0 BTM 0.250 2556 2/27/98 GLM INT 3 9744 7424(BG-2-L,~ CA DK 1.0 BTM 0.000 0 3/26/98 GLM INT 4 11343 8458(BG-2-L,~ CA DK0-2 1.0 BTM 0.375 0 12/16/97 GLM INT p~rforati6~ Su~:~ry. : :::: : ::: Interval TVD Zone Status Feet SPF Date Type Comment 12030 - 8908 - 8934 40 4 4/20/97 3-3/8" GUNS - Frac'd 4/21/97 12070 12090 - 8947 - 9018 110 6 4/17/98 3-3/8" GUNS 12200 12220 - 9031 - 9063 50 6 4/17/98 3-3/8" GUNS 12270 Interval Date Type 11465- 11469 9/28/g6 Squeeze 12264- 12268 9/28/96 Squeeze 12276- 12280 9/28/96 Squeeze Comment SQUEEZED PERFS SQUEEZED PERFS SQUEEZED PERFS PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 96-149 96-149 CBT 96-149 PERF 96-149 AIT 96-149 BHC/SL 96-149 LDT/CN 96~149 7484 96-149 CBL 96-149 DGR-MD 96-149 DGR-TVD 96-149 7936 96-149 MWD SRVY 96-149 GAS LIFT 96-149 MWD SRVY BRIDGE PLUG RCD ~2000 ,j~2000-12328 ~2276-12280 ~m~/3280-13074 ~23280-13074 ~300-13074 L~'~IT/BHC/LDT/CN ~1~400-12365 ~410-13080 ~73-9593 ~PERRY DGR ~/~-13080 ~'/845-11400 .~SPERRY 0-13080 10-407 COMPLETION DATE /~/ 3 /~ / DAILY WELL OPS dry ditch samples required? yes ~ And Are received? Was the well cored? yes ~___~Analysis & description received? Are well tests required? ~s ~Received? ~a~~ Well is in compliance ~..~ Initial COMMENTS Page: 1 Date: 09/15/98 RUN RECVD FINAL 10/11/96 FINAL 10/11/96 FINAL 10/11/96 FINAL 10/11/96 FINAL 10/11/96 FINAL 10/11/96 FINAL 10/11/96 FINAL 01/31/97 FINAL 03/12/97 FINAL 03/12/97 3,4 03/20/97 05/07/97~ 1 07/03/97~ 08/28/97 STATE OF ALASKA0 R t G i A L ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RI::COMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [] Gas [] Suspended [] Abandoned- [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-149 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22703 4. Location of well at surface 9. Unit or Lease Name :~~-~E ,: i~~ ...... L / Point Mclntyre 1364' NSL, 965' WEL, SEC. 16, T12N, R14E ~ C;C~?F'L~'~ ?<:- ! ~~ At top of productive interval R14E i/~.~'~7~: ~':. ' ~ll~i~ 10. Well Number 2475' SNL, 1386' WEL, SEC. 9, T12N, __~,~'~'- i P1-24 Attotal depth ~ \?%E~ ~ 11. Field and Pool ~~, N~, 1400, w~, s~o. ~,~i~N, ~14~ ~ ,e~: ~ .... ._ . , Point Mclntyre 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Des~gnabon and Serial No. Plan RTE - 43.3'I ADL 034622 1~. ~a,~ S~u~~_l ~-~ I ~ ~' ~t~ *'~' ~°"~° i ~ 4' ~'~ °°~" ~s"" °~ ^~'~'i~ ~' ~'or ~o~t"' '' °"~"°ro I ~ ~' ~°' °' °°m"'o''°''~-~-,~ ~ o-~-~ ~^ ~, o.~ 13080' 9593' F-rI 13000' 9537' F'rI [~Yes [-]No 2107' MD 1800' {Approx.) 22. lype Electric or Other Logs Run MWD,GR,Res,Den Neut,Sonic 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# H-40 Surf 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 34' 3386' 12-1/4" 1290 sx cs III, 327 sx 'G', 250 sx CS II 7" 26# L-80 31' 11609' 8-1/2" 385 sxClass 'G' 7" 29# 13CR80 11609' 12470' 8-1/2" 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD , Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3 3/8" Gun Diameter, 4 spf 4 1/2" 12.6# 13Cr 11456' 11410' MD TVD MD TVD 12030-12070 8864-8891 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH iNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 212 bbls diesel _ _ . 27, PRODUCTION TEST · Date First Production I Method of Operation (Flowing, gas lift, etc.) 4/24/97I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAvrrY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water.._~b. ~i~cote.- - ~ '~, ~. ~ Ch~i .p_.~.~¢:. ,.~ L_.i ~,..; -.-- ~,.- r-*~-., -~ Form 10-407 Rev. 07-01-80 Submit In Duolicate 30. Formation Tests 29. Geologic Markers 1 Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Zone UC4 12030 8865 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Leak Off Test Data 32. I hereby certify that thews t~~t to the best o~ my knowledge ~/ ~,/~ Signed ~' ~ Steve Shultz Title Senior Drilling Engineer Date P1-24 96-149 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator ARCO Date 00:34, 28 Aug 97 Page 1 The analysis is from - 01:30, 14 Sep 96 - to - 01:30, 14 Sep 96 Programs in Result Table: P1-24 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(ecfuivalent mud weight) P1-24 Event 01:30, 14 Sep 96 01:30, 14 Sep 96 0 hr 0 min Obtained leak off 13.000 Hole Size MDR 8-1/2 Facility Date/Time 09 Sep 96 10 Sep 96 11 Sep 96 12 Sep 96 Pt Mac 1 Progress Report Well P1-24 Rig Doyon 14 11:00-14:00 11:00-11:15 11:15 11:15-14:00 14:00 14:00-20:00 14:00-20:00 20:00 20:00-01:00 20:00-01:00 01:00 01:00-01:30 01:00-01:30 Duration 3hr 1/4hr 2-3/4 hr 6hr 6hr 5hr 5hr 1/2 hr 1/2 hr Activity Move rig Held safety meeting Began precautionary measures Rig moved 100.00 % At well location - Cellar Nipple up Divertor Rigged up Divertor Work completed - Divertor in position BHA run no. 1 Made up BHA no. 1 Stopped: To test equipment Test well control equipment Tested Divertor Page Date 01:30 01:30-03:00 01:30-03:00 03:00 03:00-06:00 03:00-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-06:00 07:00-09:30 09:30 09:30-10:00 10:00 10:00-06:00 06:00 06:00-22:00 06:00-20:00 20:00 20:00-20:30 20:30 20:30-20:45 20:45 20:45-22:00 22:00 22:00-06:00 22:00-23:30 23:30 23:30-00:30 00:30 00:30-01:30 01:30 01:30-06:00 06:00 06:00-12:30 06:00-08:30 08:30 08:30-09:15 09:15 09:15-09:30 1-1/2 hr 1-1/2 hr 3hr 3hr lhr lhr 23 hr 2-1/2 hr 1/2 hr 20 hr 16hr 14hr 1/2 hr 1/4hr 1-1/4 hr 8hr 1-1/2 hr lhr lhr 4-1/2 hr 6-1/2 hr 2-1/2 hr 3/4 hr 1/4 hr Function test completed satisfactorily Fluid system Circulated at 40.0 ft Broke circulation BHA run no. 1 Drilled cement to 130.0 ft Began precautionary measures BHA run no. 1 (cont...) Pulled BHA BHA Laid out BHA run no. 2 Made up B HA no. 2 BHA no. 2 made up Held safety meeting Began precautionary measures Drilled to 1672.0 ft Began precautionary measures BHA run no. 2 (cont...) Drilled to 2947.0 ft Walk & build rate unacceptable - BHA Circulated at 2947.0 ft Obtained bottoms up (100% annulus volume) Flow check Observed well static Pulled B HA BHA Stood back BHA run no. 3 Made up BHA no. 3 BHA no. 3 made up Serviced Block line Line slipped and cut R.I.H. to 2947.0 ft On bottom Drilled to 3224.0 ft Began precautionary measures BHA run no. 3 (cont...) Drilled to 3410.0 ft Build rate unacceptable - BHA Circulated at 3410.0 ft Obtained bottoms up (100% annulus volume) Flow check 1 27 August 97 Facility Date/Time 13 Sep 96 Progress Report Pt Mac 1 Well P1-24 Rig Doyon 14 Page 2 Date 27 August 97 09:30 09:30-11:00 11:00 11:00-12:30 12:30 12:30-19:30 12:30-12:45 12:45 12:45-18:30 18:30 18:30-19:30 19:30 19:30-21:30 19:30-21:30 21:30 21:30-01:30 21:30-23:00 23:00 23:00-23:30 23:30 23:30-01:00 01:00 01:00-01:30 01:30 01:30-04:00 01:30-02:00 02:00 02:00-03:30 03:30 03:30-04:00 04:00 04:00-06:00 04:00-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-11:00 08:00-11:00 11:00 11:00-16:00 11:00-16:00 16:00 16:00-16:30 16:00-16:30 16:30 16:30-00:30 16:30-18:30 18:30 18:30-20:00 20:00 20:00-20:30 Duration 1-1/2 hr 1-1/2 hr 7hr 1/4hr 5-3/4 hr lhr 2hr 2hr 4hr 1-1/2 hr 1/2hr 1-1/2 hr 1/2hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 2hr 2hr 2hr 3hr 3hr 5hr 5hr 1/2 hr 1/2 hr 8hr 2hr 1-1/2 hr 1/2hr Activity Observed well static Pulled out of hole to 200.0 ft At BHA Pulled B HA BHA Laid out Run Casing, 9-5/8in O.D. Held safety meeting Began precautionary measures Ran Casing to 3385.0 ft (9-5/8in OD) Hanger landed Circulated at 3385.0 ft Obtained bottoms up (100% annulus volume) Run Drillpipe, 5in O.D. Ran Drillpipe to 3299.0 ft (5in OD) At Float collar: 3299.0 ft Cement: Casing cement Circulated at 3299.0 ft Obtained bottoms up (100% annulus volume) Pumped 77.000 bbl spacers - volume (null) Required volume of spacer pumped Mixed and pumped slurry - 494.000 bbl Lead cement pumped Mixed and pumped slurry - 77.000 bbl Tail cement pumped CIP @ 0130 hrs Pull Drillpipe, 5in O.D. Circulated at 3289.0 ft Riser displaced Pulled Drillpipe in stands to 1020.0 ft Stopped: To pick up/lay out tubulars Laid down 1020.0 ft of Drillpipe 34 joints laid out Nipple down Divertor Rigged down Divertor Work completed, equipment laid out Wellhead work Installed Casing spool Equipment work completed Nipple up BOP stack Rigged up BOP stack Work completed - BOP stack in position Test well control equipment Tested BOP stack Pressure test completed successfully - 5000.000 psi Chuck Sheve, AOGCC, witnessed BOPE test Wellhead work Installed Wear bushing Equipment work completed BHA run no. 4 Made up B HA no. 4 BHA no. 4 made up R.I.H. to 3299.0 ft At Float collar: 3299.0 ft Circulated at 3299.0 ft Facility Pt Mac 1 Progress Report Well P1-24 Page 3 Rig Doyon 14 Date 27 August 97 Date/Time 14 Sep 96 15 Sep 96 16 Sep 96 17 Sep 96 18 Sep 96 20:30 20:30-21:00 21:00 21:00-21:30 21:30 21:30-00:00 00:00 00:00-00:30 00:30 00:30-01:30 00:30-01:00 01:00 01:00-01:30 01:30 01:30-06:00 01:30-06:00 06:00 06:00-06:00 06:00-18:00 18:00 18:00-18:30 18:30 18:30-18:45 18:45 18:45-19:30 19:30 19:30-20:00 20:00 20:00-06:00 06:00 06:00-21:45 06:00-17:00 17:00 17:00-18:15 18:15 18:15-18:30 18:30 18:30-20:30 20:30 20:30-21:45 21:45 21:45-06:00 21:45-23:00 23:00 23:00-02:30 02:30 02:30-06:00 06:00 06:00-06:00 06:00-06:00 06:00 06:00-06:00 06:00-06:00 06:00 Duration 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 4-1/2 hr 4-1/2 hr 24 hr 12hr 1/2 hr 1/4 hr 3/4 hr 1/2 hr 10hr 15-3/4 hr llhr 1-1/4 hr 1/4hr 2hr 1-1/4 hr 8-1/4 hr 1-1/4 hr 3-1/2 hr 3-1/2 hr 24 hr 24 hr 24 hr 24 hr Activity Obtained bottoms up (100% annulus volume) Tested Casing - Via annulus Pressure test completed successfully - 3000.000 psi Held drill (Kick (well kill)) Completed operations Drilled cement to 3385.0 ft At 9-5/8in casing shoe Drilled to 3460.0 ft Stopped: To perform FIT Perform integrity test Circulated at 3460.0 ft Obtained bottoms up (100% annulus volume) Performed formation integrity test Obtained leak off 13.0 ppg EMW BHA run no. 4 Drilled to 3848.0 ft Began precautionary measures BHA run no. 4 (cont...) Drilled to 4997.0 ft Started scheduled wiper trip: due to Footage drilled Circulated at 4997.0 ft Obtained bottoms up (100% annulus volume) Flow check Observed well static Pulled out of hole to 3830.0 ft At top of check trip interval R.I.H. to 4997.0 fl On bottom Drilled to 5774.0 ft Began precautionary measures BI-IA run no. 4 (cont...) Drilled to 6645.0 fl ROP dropped from 120.0 fi/hr to 60.0 ft/hr - Bit quit Circulated at 6645.0 ft Obtained bottoms up (100% annulus volume) Flow check Observed well static Pulled out of hole to 1085.0 ft At BHA Pulled B HA BHA Laid out BHA run no. 5 Made up BHA no. 5 BHA no. 5 made up R.I.H. to 6645.0 ft On bottom Drilled to 6778.0 ft Began precautionary measures BHA run no. 5 (cont...) Drilled to 7860.0 ft Began precautionary measures BHA run no. 5 (cont...) Drilled to 9048.0 ft Began precautionary measures Facility Date/Time 19 Sep 96 20 Sep 96 21 Sep 96 22 Sep 96 Pt Mac 1 Progress Report Well P1-24 Page 4 Rig Doyon 14 Date 27 August 97 06:00-06:00 06:00-07:00 07:00 07:00-08:00 08:00 08:00-09:15 09:15 09:15-10:00 10:00 10:00-06:00 06:00-06:00 06:00-22:00 22:00 22:00-22:30 22:30 22:30-23:15 23:15 23:15-00:00 00:00 00:00-01:00 01:00 01:00-01:30 01:30 01:30-03:00 03:00 03:00-04:00 04:00 04:00-06:00 06:00-06:00 06:00-06:00 06:00-06:00 06:00-17:30 17:30 17:30-18:00 18:00 18:00-20:00 20:00 20:00-22:30 22:30 22:30-02:30 02:30 02:30-03:00 03:00 03:00-06:00 06:00-20:00 06:00-07:00 07:00 07:00-10:30 10:30 Duration 24 hr lhr lhr 1-1/4 hr 3/4 hr 20 hr 24 hr 16hr 1/2 hr 3/4 hr 3/4 hr lhr 1/2 hr 1-1/2 hr lhr 2hr 24 hr 24 hr 24 hr 11-1/2 hr 1/2 hr 2hr 2-1/2 hr 4hr 1/2 hr 3hr 14 hr lhr 3-1/2 hr Activity BHA run no. 5 (cont...) Drilled to 9078.0 ft Started scheduled wiper trip: due to Footage drilled Circulated at 9078.0 ft Obtained bottoms up (100% annulus volume) Pulled out of hole to 6645.0 ft At top of check trip interval R.I.H. to 9078.0 ft On bottom Drilled to 10512.0 ft BHA run no. 5 (cont...) Drilled to 11517.0 ft (cont...) Began precautionary measures Circulated at 11517.0 ft Began precautionary measures Pulled out of hole to 9078.0 ft At top of check trip interval R.I.H. to 11517.0 ft On bottom Drilled to 11540.0 ft Stopped · To circulate set stabilizer at 7 3/4 drill to 11540. Circulated at 11540.0 ft Lo-vis ~nud spotted downhole pump 30 bbl lo-vis followed by 60 bbl hi-vis sweep , ahead of KCL mud Drilled to 11591.0 ft Stopped · To circulate Circulated at 11591.0 ft Obtained req. fluid properties - 100.00 %, hole vol. cir out interface, re screen one shaker. Drilled to 11676.0 ft BHA run no. 5 (cont...) Drilled to 12575.0 ft (cont...) BHA run no. 5 (cont...) Drilled to 12994.0 ft (cont...) Mud pumps failed - Work string Worked toolstring at 12994.0 ft Completed operations Repair mud pump Drilled to 13080.0 ft Reached planned end of run - Section / well T.D. Circulated at 13080.0 ft Obtained req. fluid properties - 130.00 %, hole vol. Pulled out of hole to 3385.0 ft At 9-5/8in casing shoe Serviced Block line Line slipped and cut R.I.H. to 12000.0 ft BHA run no. 5 (cont...) R.I.H. to 13080.0 ft (cont...) On bottom Circulated at 13080.0 ft Heavy slug spotted downhole ',.~11 UULLUIIID LllJDI. JUL ¥¥UI~IILUL% tJlll ~,~11 Facility Date/Time 23 Sep 96 24 Sep 96 Pt Mac 1 Progress Report Well P1-24 Rig Doyon 14 Page Date 5 27 August 97 10:30-12:30 12:30 12:30-13:00 13:00 13:00-18:00 18:00 18:00-20:00 20:00 20:00-06:00 20:00-22:00 22:00 22:00-01:30 01:30 01:30-06:00 06:00-08:30 06:00-08:30 08:30 08:30-09:00 08:30-09:00 09:00 09:00-14:30 09:00-14:00 14:00 14:00-14:30 14:30 14:30-06:00 14:30-15:30 15:30 15:30-20:30 20:30 20:30-23:30 23:30 23:30-00:30 00:30 00:30-04:00 04:00 04:00-04:30 04:30 04:30-05:00 05:00 05:00-06:00 06:00-14:00 06:00-13:00 13:00 13:00-14:00 Duration 2hr 5hr 2hr 10hr 2hr 3-1/2 hr 4-1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1/2hr 5-1/2 hr 5hr 1/2 hr 15-1/2 hr lhr 5hr 3hr lhr 3-1/2 hr lhr 8hr 7hr lhr Activity Pulled out of hole to 11630.0 ft At top of check trip interval pulled 75k over, from 13080 to 12,100 R.I.H. to 13080.0 fl On bottom No problems. Pulled out of hole to 360.0 fl At B HA strap out no correction. Pulled BHA BHA Laid out Electric wireline work Rigged up Logging/braided cable equipment Work completed - Logging/braided cable equipment in position Test Computer software unit Function test completed satisfactorily had to change out sonic tool. Conducted electric cable operations Electric wireline work (cont...) Conducted electric cable operations (cont...) Completed logging run with CDL-CNL-GR from 13065.0 ft to 3385.' And rig down tools. Wellhead work Removed Bore protector Equipment work completed Test well control equipment Tested All functions Pressure test completed successfully - 5000.000 psi Installed B ore protector Eqpt. work completed, running tool retrieved BHA run no. 6 Made up BHA no. 6 BHA no. 6 made up R.I.H. to 12970.0 ft Began precautionary measures Reamed to 13080.0 ft On bottom Circulated at 13080.0 ft Heavy slug spotted downhole spot 40 bbl 15# mud on bottom Pulled out of hole to 11860.0 ft At top of check trip interval tight coming up. R.I.H. to 12650.0 ft At Setting depth: 12650.0 ft Pulled out of hole to 11700.0 ft At top of check trip interval Laid down 800.0 ft of 5in OD drill pipe BHA run no. 6 (cont...) Laid down 12850.0 ft of 5in OD drill pipe (cont...) At B HA Pulled BHA Facility Date/Time 25 Sep 96 26 Sep 96 Pt Mac 1 Progress Report Well P1-24 Page 6 Rig Doyon 14 Date 27 August 97 14:00 14:00-06:00 14:00-14:30 14:30 14:30-15:30 15:30 15:30-15:45 15:45 15:45-17:00 17:00 17:00-18:00 18:00 18:00-06:00 06:00-06:30 06:00-06:30 06:30 06:30-14:30 06:30-14:30 14:30 14:30-19:00 14:30-14:45 14:45 14:45-15:30 15:30 15:30-16:00 16:00 16:00-17:00 17:00 17:00-19:00 19:00 19:00-00:30 19:00-20:00 20:00 20:00-20:30 20:30 20:30-23:00 23:00 23:00-00:30 00:30 00:30-01:30 Duration 16hr 1/2 hr lhr 1/4 hr 1-1/4 hr lhr 12hr 1/2 hr 1/2hr 8hr 8hr 4-1/2 hr 1/4 hr 3/4 hr 2hr 5-1/2 hr lhr 1/2 hr 2-1/2 hr 1-1/2 hr lhr Activity BHA Laid out Run Casing, 7in O.D. Retrieved B ore protector Equipment work completed Rigged up Casing handling equipment Work completed - Casing handling equipment in position Held safety meeting Completed operations Pre j ob meeting. Ran Casing to 1500.0 ft (7in OD) Casing handling equipment failed - Work string Serviced Casing handling equipment Equipment work completed repair line on pipe skate. Ran Casing to 7in (12470.0 ft OD) Run Casing, 7in O.D. (cont...) Ran Casing to 12470.0 ft (7in OD) (cont...) Got stuck whilst pipe stationary make up landing jt and hanger. Stuck 7in Casing Worked stuck pipe at 12470.0 ft Aborted attempts to work Casing free at 12470.0 ft work pipe mix and pump mud max pull 475k unable to get any cir or movement. Cement · Casing cement Held safety meeting Completed operations hold pre job meeting. Pumped 70.000 bbl spacers - volume (null) Required volume of spacer pumped pump 5 bbl water test lines to 4000 psi OK pump 15 bbl water followed by 70 bbls of weighted spacer (11.4) Mixed and pumped slurry - 79.000 bbl Cement pumped Displaced slurry - 474.000 bbl Plug bumped Cement in place at 1630 test casing to 3500 psi for 30 rain OK Cleared Circulating head Equipment work completed rig down tools. Nipple down Wellhead connector Rigged down Wellhead connector Equipment work completed Rigged up Casing handling equipment Equipment work completed Rigged down Casing handling equipment Work completed, equipment laid out cut 7" install pack off. Rigged up Wellhead connector Work completed - BOP stack in position test pack off to 5000 psi Test well control equipment Facility Pt Mac 1 Progress Report Well P1-24 Page 7 Rig Doyon 14 Date 27 August 97 Date/Time 27 Sep 96 00:30-00:45 00:45 00:45-01:30 01:30 01:30-06:00 01:30-02:00 02:00 02:00-05:30 05:30 05:30-06:00 06:00 06:00-09:00 09:00 09:00-06:00 09:00-10:30 10:30 10:30-11:30 11:30 11:30-22:30 22:30 22:30-00:00 00:00 00:00-01:00 01:00 01:00-03:00 03:00 03:00-06:00 06:00-07:00 06:00-06:30 06:30 06:30-07:00 07:00 07:00-12:00 07:00-07:30 07:30 07:30-12:00 12:00 12:00-13:00 12:00-13:00 13:00 13:00-15:00 13:00-15:00 15:00 15:00-16:00 15:00-16:00 16:00 Duration 1/4 hr 3/4 hr 4-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 3hr 21 hr 1-1/2 hr lhr llhr 1-1/2 hr lhr 2hr 3hr lhr 1/2 hr 1/2 hr 5hr 1/2 hr 4-1/2 hr lhr lhr 2hr 2hr lhr lhr Activity Installed BOP test plug assembly Eqpt. work completed, running tool retrieved Tested BOP stack Pressure test completed successfully - 5000.000 psi Electric wireline work Rigged up Rigging equipment Work completed - Logging/braided cable equipment in position Conducted electric cable operations Completed logging run with Cement bond log from 12341.0 ft to 120 Rigged down Logging/braided cable equipment Work completed, equipment laid out Rigged up Variable ram Equipment work completed Change both sets of pipe rams 3 1/2 x 6 variables on top and 3 1/2 solids on bottom. BHA run no. 7 Serviced Drillstring handling equipment Equipment work completed Finish loading and strapping drill pipe. Made up B HA no. 7 BHA no. 7 made up Singled in drill pipe to 11500.0 ft Stopped · To change handling equipment Serviced Kelly/top drive hose Work completed, Kelly/top drive hose changed out change out kellys Singled in drill pipe to 12390.0 ft On bottom Circulated at 12390.0 ft Hole displaced with Water based mud - 110.00 % displaced displace sea water from hole. Pulled out of hole to 3000.0 ft BHA run no. ? (cont...) Pulled out of hole to 578.0 ft (cont...) At B HA Pulled BHA BHA Stood back Electric wireli ne work Rigged up Logging/braided cable equipment Work completed - Logging/braided cable equipment in position Perforated from 12276.0 ft to 12280.0 ft Interval perforated Fluid system Circulated at 12276.0 ft Broke circulation try and break cir unable to break injection rate down casing lbbl min at 1250, down back side lbbl rain at 650. Electric wireline work Perforated from 12264.0 ft to 12268.0 ft Interval perforated Fluid system Circulated at 12264.0 ft Broke circulation tr3 to ~----'- ~:- again no luck UI L~O.K L, II }0.0 ft Facility Date/Time 28 Sep 96 Progress Report Pt Mac 1 Well P1-24 Page 8 Rig Doyen 14 Date 27 August 97 Duration Activity 16:00-23:30 16:00-18:30 18:30 18:30-23:00 23:00 23:00-23:30 23:30 23:30-06:00 23:30-23:45 23:45 23:45-01:00 01:00 01:00-02:00 02:00 02:00-04:00 04:00 04:00-04:30 04:30 04:30-05:00 05:00 05:00-06:00 06:00-07:30 06:00-07:30 07:30 07:30-11:00 07:30-07:45 07:45 07:45-08:30 08:30 7-1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr 6-1/2 hr 1/4 hr 1-1/4 hr lhr 2hr lhr 1-1/2 hr 1-1/2 hr 3-1/2 hr 1/4 hr 3/4 hr Electric wh'eline work Perforated from 11465.0 ft to 11469.0 ft Interval perforated Set downhole equipment (wireline) Completed run with Cement retainer to 12000.0 ft Rigged down Logging/braided cable equipment Work completed, equipment laid out BHA run no. 8 Made up B HA no. 8 BHA no. 8 made up make up cement stinger and plug catcher sub. R.I.H. to 3600.0 ft Stopped · To service drilling equipment Serviced Block line Line slipped and cut R.I.H. to 12007.0 ft On bottom Tag EZESV Rigged up Cement head Work completed - Cement head in position Circulated at 12000.0 ft Broke circulation Above EZSV Circulated at 12007.0 ft BHA run no. 8 (cont...) Circulated at 12007.0 ft (cont...) Obtained clean returns - 200.00 % hole volume cir at 3 1/2 -4 bbl per min at 6 bbl per min losing 2 bbl Cement: Squeeze Held safety meeting Completed operations hold pre job meeting. Pumped 50.000 bbl spacers - volume (null) Required volume of spacer pumped pump 5 bbl water test lines to 3000 psi OK, pump 15 bbl water, pump 30 bbl MCS-30 at 11.2# 08:30-09:00 09:00 09:00-09:30 09:30 09:30-10:30 10:30 10:30-11:00 11:00 11:00-14:30 11:00-14:15 lhr 3-1/2 hr 3-1/4 hr Mixed and pumped slurry - 40.000 bbl Released Wiper plug pumped 40 bbl Of 15.8 cement at 5.5 bbl per min. Displaced slurry - 86.500 bbl Plug sheared displace with B.J. at 5.5 bbl per min CIP at 0915 .shear plug sting out of retainer Reverse circulated at 11995.0 ft String displaced with Water based mud - 120.00 % displaced reversed at 3-4 bbl per min had 7-10 bbl cement returlls. Rigged down Cement head Work completed, equipment laid out BHA run no. 7 Pulled out of hole to 30.0 ft Progress Report Facility Pt Mac 1 Well P1-24 Page 9 Rig Doyon 14 Date 27 August 97 Date/Time 29 Sep 96 30 Sep 96 14:15 14:15-14:30 14:30 14:30-06:00 14:30-15:00 15:00 15:00-19:30 19:30 19:30-20:00 20:00 20:00-20:30 20:30 20:30-23:00 23: 00 23:00-06:00 06:00-05:00 06:00-10:00 10:00 10:00-12:00 12:00 12:00-12:30 12:30 12:30-14:00 14:00 14:00-15:00 15:00 15:00-21:30 21:30 21:30-22:00 22:00 22:00-04:30 04:30 04:30-05:00 05:00 05:00-06:00 05:00-05:30 05:30 05:30-06:00 06:00-06:00 06:00-07:30 07:30 07:30-08:00 08:00 08:00-17:30 17:30 17:30-18:00 18:00 Duration 1/4 hr 15-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2hr 2-1/2 hr 7hr 23 hr 4hr 2hr 1/2 hr 1-1/2 hr lhr 6-1/2 hr 1/2 hr 6-1/2 hr lhr 1/2 hr 1/2 hr 24hr 1-1/2 hr 1/2 hr 9-1/2 hr 1/2 hr Activity At BHA Pulled BHA BHA Laid out lay down cement stinger. BHA run no. 8 Made up B HA no. 8 BHA no. 8 made up R.I.H. to 11928.0 ft Began precautionary measures Washed to 11975.0 ft At Top of cement: 11975.0 ft Drilled cement to 12005.0 ft Tagged Cement retainer Milled Cement retainer at 12005.0 ft Completed dressing Cement retainer Drilled cement to 12295.0 ft BHA run no. 8 (cont...) Drilled cement to 12390.0 ft (cont...) At Float collar: 12390.0 ft Had firm cement to 12378. (14 bbls) Circulated at 12390.0 ft Obtained clean returns - 120.00 % hole volume Serviced Mud pumps Equipment work completed flush pumps. Circulated at 12390.0 ft Hole displaced with Brine ~ 110.00 % displaced Rest hole at 12390.0 ft Resumed operations monitior hole. Finish cleaning mud system. Reverse circulated at 12390.0 ft Obtained clean returns - 110.00 % hole volume Reverse cir at 4 bbl per min and filter 9.9 brine. Flow check Observed well static Laid down 11700.0 ft of 3-1/2in OD drill pipe At B HA Break kelly, trip out laying down drill pipe. Pulled B HA BHA Laid out Run Single completion, 4-1/2in O.D. Retrieved B ore protector Equipment work completed Rigged up Tubing handling equipment Run Single completion, 4-1/2in O.D. (cont...) Rigged up Tubing handling equipment (cont...)~ ~.~: .~.~ :~=~-~ ...... ~- , ~-- Work completed- Tubing handling equipment Held safety meeting Completed operations ~,~ Held pre job safety meeting. :" Ran Tubing to 9244.0 ft (4-1/2in OD) ~!_0,8~ Stopped' To pick up/lay out tubulars 'li~ ~.~.~ Rigged up sub-surface equipment - SCSSSV control Work completed - SCSSSV dummy pack off in position Facility Date/Time O1 Oct 96 02 Oct 96 Progress Report Pt Mac 1 Well P1-24 Page 10 Rig Doyon 14 Date 27 August 97 18:00-18:30 18:30 18:30-21:30 21:30 21:30-23:00 23:00 23:00-01:00 01:00 01:00-05:30 05:30 05:30-06:00 06:00-10:00 06:00-10:00 10:00 10:00-03:30 10:00-12:00 12:00 12:00-13:00 13:00 13:00-14:30 14:30 14:30-17:00 17:00 17:00-19:00 19:00 19:00-22:30 22:30 22:30-01:30 01'30 01:30-03:30 03:30 03:30-04:00 Duration 1/2hr 3hr 1-1/2 hr 2hr 4-1/2 hr 1/2hr 4hr 4hr 17-1/2 hr 2hr lhr 1-1/2 hr 2-1/2 hr 2hr 3-1/2 hr 3hr 2hr 1/2 hr Activity Held safety meeting Completed operations hold pre job safety meeting. (test control lines to 5000psi OK) Ran Tubing to 11419.0 ft (4-1/2in OD) Stopped:At sub-assembly Rigged up Tubing hanger Work completed - Hanger assembly in position control lines tested to 5000 psi. OK Reverse circulated at 11455.0 ft String displaced with Inhibited brine - 100.00 % displaced reverse in corixet brine water Set packer at 11409.0 ft with 4000.0 psi Side pocket valve failed - Abort operation Drop ball set packer with 4000 psi, pressure bled off. surge fluid to try and seat ball, failed. Pump down annulus to see if packer is set, back side holdes 2000 psi, no increase in pressure on tubing. bleed tubing off, pressure up on ann to 2000 psi Rigged up Slickline unit Run Single completion, 4-1/2in O.D. (cont...) Rigged up Slickline unit (cont...) Work completed - Double drum winch in position monitor annulus (stayied at 1800 psi) rig up pressure equipmentb on top of NSCT landing joint. Electric wireline work Conducted slickline operations on Slickline equipment - Retrival run Retrieved 2197.0 ft from SCSSSV dummy pack off Conducted slickline operations on Slickline equipment - Retrival run Completed misrun with Setting tools to 11443.0 ft trip in to retrieve rod and setting ball. Conducted slickline operations on Slickline equipment - Retrival run Completed misrun with Setting tools to 11443.0 ft change bell guide on 1.375 retrieveing tool, from 3.60 to 2.68, and rerun. Conducted slickline operations on Slickline equipment - Tool run Completed run with Cleaning / Investigation tools from -0.0 ft to 114, ft run impression block. Conducted slickline operations on Slickline equipment - Retrival run Completed misrun with Setting tools to 11443.0 ft run 1.375 retrieveing tool with 3.60 bell guide found marks inside of tool. Conducted slickline operations on Slickline equipment - Retrival run Completed run with Setting tools from -0.0 ft to 11443.0 ft trip in with 3/4" over shot and recover 3/4" rod "fishing neck and setting ball were both off of rod". Conducted slickline operations on Slickline equipment - Retrival run Completed run with Nipple plug from -0.0 ft to 11443.0 ft retrieve RHC plug,ball and, fishing neck. Conducted slickline operations on Slickline equipment - Setting run Completed run with Standing valve to 11443.0 ft set same Perform integrity test -3.0 Facility Date/Time 03 Oct 96 Progress Report Pt Mac 1 Well P1-24 Page 11 Rig Doyon 14 Date 27 August 97 03:30-04:00 04:00 04:00-06:00 04:00-05:30 05:30 05:30-06:00 06:00-20:30 06:00-07:30 07:30 07:30-09:00 09:00 09:00-11:00 11:00 11:00-18:00 18:00 18:00-18:30 18:30 18:30-19:30 19:30 19:30-20:30 20:30 20:30-21:00 20:30-21:00 21:00 21:00-23:00 21:00-23:00 23:00 23:00-02:00 23:00-01:30 01:30 01:30-02:00 02:00 02:00-04:00 02:00-04:00 04:00 04:00-05:00 04:00-05:00 Duration 1/2 hr 2hr 1-1/2 hr 1/2 hr 14-1/2 hr 1-1/2 hr 1-1/2 hr 2hr 7hr 1/2hr lhr lhr 1/2 hr 1/2hr 2hr 2hr 3hr 2-1/2 hr 1/2 hr 2 hr 2hr lhr lhr Activity Tested Standing valve Pressure test completed successfully - 2000.000 psi test tubing to 2000 psi with annulus open bleed of to 500 psi. test both sides to 2000 psi standing valve and annulus holding. Electric wireline work ******** NO SPILLS******** ******** NO ACCIDENTS******** ********* 216 ACCIDENT FREE WORK DAYS******** Conducted slickline operations on Slickline equipment - Tool run Completed run with Standing valve from -0.0 ft to 11443.0 ft shear off standing valve and trip out Conducted slickline operations on Slickline equipment - Retrival run Electric wireline work (cont...) ******** NO SPILLS******** ******** NO ACCIDENTS******** ********* 216 ACCIDENT FREE WORK DAYS******** Conducted slickline operations on Slickline equipment - Retrival run Completed misrun with Side pocket valve to 7404.0 ft Conducted slickline operations on Slickline equipment - Retrival run Retrieved 7404.0 ft from Side pocket valve Conducted slickline operations on Slickline equipment - Setting run Completed misrun with Side pocket valve to 7404.0 ft Conducted slickline operations on Slickline equipment - Setting run Completed run with Nipple plug from -0.0 ft to 11443.0 ft Set downhole equipment (wireline) Completed run with Nipple plug to 11443.0 ft Pressure test tail pipe plug to 2000 psi, OK Set downhole equipment (wireline) Completed run with SCSSSV dummy pack off to 2197.0 ft Rigged down sub-surface equipment- Toolstring Work completed, equipment laid out Perform integrity test Tested Tubing Pressure test completed successfully - 3500.000 psi Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree Hook up C/L, Test to 5000 psi, NFLI adapter flange & Tree, Test to 5000 psi Equipment work completed Removed Hanger plug R/U Lubricator, Pull TWC, R/D Lubricator Equipment work completed Fluid system Freeze protect well - 212.000 bbl of Diesel Freeze Protect Tbg, Tgb Annulus & 7" x 9-5/8" Annulus Completed operations Wellhead work Installed Hanger plug R/U Lubricator, Set BPV, R/D Lubricator, Pressure t~St tO ~ rmr~ _ ~: l~uu l.J~l Facility Date/Time Progress Report Pt Mac 1 Well P1-24 Page 12 Rig Doyon 14 Date 27 August 97 Duration Activity 05:00 05:00-06:00 05:00-06:00 06:00 lhr lhr Equipment work completed Move rig Rigged down Rig services Secure Wellhead & Tree, Pump out cellar, Clean pits, Prepare for rig move Equipment work completed Released Rig from operations on Well P1-24 @ 0600 hfs on 10-3-96 DFIILLII~G 5 I~FIVIC i~ Section 1. : GENERAL INFORMATION Job No.: AK-MM-60126 "- Well No.: P1-24 MWD End of Well Report ~l~mm~-sum General Information I Company Rig Well Field Country API number Sperry-Sun job number Job start date Job end date North reference Declination Dip angle Total magnetic field Date of magnetic data Wellhead coordinates N Wellhead coordinates E Vert. section direction MWD Engineers Company Representatives Company Geologists ARCO ALASKA INC : DOYON 14 : P1-24 POINT MCINTYRE USA 50-029-22703-00 : AK-MM-60126 : 06-SEP-96 22-SEP-96 : TRUE : 28.8 : 80.8 : 57376.00 10-SEP-96 : N 70:23:26.303 : W 148:35:1.251 : 356.4 · P. ROBERTS T. McGUIRE S. BURKHARDT · N. SCALES K. WHITE Engineering units used: Depth / length : OD / ID : Temperature : Flow Rate : Pressure : Weight on bit : Mud Weight : inches deg. F galls/min psi lbs (1000s) PPg Viscosity PV YP Chlorides Fluid loss Casing weight sec/quart cp lb/(100 sq. ft.) ppm ml (cc.) lbs/ft Job No.: AKIMM-60126 Well No.: P1-24 MWD End of Well Report SPE~-~¥-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING POINT MCINTYRE/P1-24 500292270800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 092196 MWD SURVEY JOB NUMBER: AK-MM-60126 KELLY BUSHING ELEV. = 43.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -43.10 127.06 127.06 83.96 216.33 216.33 173.23 306.25 306.25 263.15 397.76 397.76 354.66 COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 0 0 N .00 E .00 .00N .00E 0 6 S 66.20 E .08 .04S .10E 0 6 N 61.60 E .10 .04S .24E 0 5 N 81.63 E .04 .01N .38E 0 11 N 72.83 E .11 .06N .60E VERT. SECT. .00 -.05 -.05 - .02 .03 483.59 483.59 440.49 573.85 573.85 530.75 664.54 664.53 621.43 754.18 754.16 711.06 844.22 844.19 801.09 0 19 N 71.65 E .16 .18N .97E 0 31 S 41.96 E .54 .04S 1.49E 0 46 S 49.34 E .30 .75S 2.23E 0 43 S 47.11 E .07 1.53S 3.11E 0 58 S 30.11 E .39 2.59S 3.92E .12 -.13 -.89 -1.73 -2.83 933.97 933.92 890.82 1024.02 1023.96 980.86 1117.42 1117.35 1074.25 1211.53 1211.45 1168.35 1304.87 1304.79 1261.69 1 14 S 38.04 E .34 4.02S 4.90E 1 4 S 31.39 E .24 5.50S 5.94E 0 29 S 35.72 E .62 6.57S 6.63E 0 11 S 5.89 W .39 7.05S 6.85E 0 9 S 27.05 W .08 7.32S 6.78E -4.32 -5.87 -6.98 -7.47 -7.73 1395.53 1395.45 1352.35 1489.05 1488.97 1445.87 1582.52 1582.44 1539.34 1676.62 1676.54 1633.44 1767.43 1767.35 1724.25 0 16 N 58.59 W .35 7.31S 6.54E 0 18 N 67.54 W .06 7.10S 6.12E 0 16 N 35.63 W .18 6.82S 5.75E 0 16 N 41.19 W .02 6.46S 5.46E 0 16 N 7.87 E .25 6.08S 5.35E -7.71 -7.47 -7.17 -6.79 -6.40 1860.34 1860.26 1817.16 1953.42 1953.33 1910.23 2048.69 2048.59 2005.49 2142.87 2142.74 2099.64 2234.63 2234.42 2191.32 0 31 N 4.32 E .28 5.43S 5.41E 0 36 N 14.35 E .14 4.52S 5.57E 1 8 N' 3.58 E .58 3.09S 5.75E 1 42 N .18 E .60 .76S 5.81E 2 54 N 6.45 W 1.34 2.91N 5.56E -5.76 -4.87 -3.44 -1.12 2.56 2328.56 2328.17 2285.07 2422.99 2422.29 2379.19 2516.15 2514.99 2471.89 2610.50 2608.69 2565.59 2703.27 2700.53 2657.43 4 3 N 4.21 W 1.23 8.58N 5.05E 8.25 5 11 N 5.67 W 1.21 16.16N 4.38E 15.85 6 9 N 8.11 W 1.06 25.29N 3.26E 25.03 7 14 N 8.69 W 1.16 36.17N 1.65E 36.00 8 55 N 6.26 W 1.85 49.10N .02W 49.00 2796.76 2792.63 2749.53 2888.81 2882.71 2839.61 2981.22 2972.55 2929.45 3074.34 3062.60 3019.50 3168.51 3152.79 3109.69 10 48 N 1.84 W 2.17 65.06N 1.09W 65.00 12 51 N 3.31 E 2.50 83.90N .78W 83.78 14 13 N .70 E 1.63 105.51N .04W 105.31 15 13 N 4.29 W 1.73 129.15N .82W 128.95 18 10 N 5.82 W 3.16 156.10N 3.23W 156.00 ORIGINAL SPF if-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING POINT MCINTYRE/P1-24 500292270800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 092196 MWD SURVEY JOB NUMBER: AK-MM-60126 KELLY BUSHING ELEV. = 43.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3262.25 3241.23 3198.13 3353.30 3325.95 3282.85 3411.49 3379.28 3336.18 3504.73 3461.47 3418.37 3598.89 3539.81 3496.71 20 33 22 22 24 46 31 28 35 52 N 10.45 W 3.03 186.84N 7.70W N 8.60 W 2.12 219.69N 13.19W N 7.05 W 4.26 242.74N 16.35W N 11.77 W 7.58 286.01N 23.72W N 13.84 W 4.82 336.89N 35.34W 186.95 220.08 243.28 286.93 338.45 3689.76 3613.22 3570.12 36 20 3780.84 3686.07 3642.97 37 25 3874.66 3758.16 3715.06 42 5 3969.68 3825.72 3782.62 47 13 4063.78 3888.28 3845.18 49 25 N 12.27 W 1.15 389.05N 47.43W N 11.54 W 1.28 442.55N 58.70W N 11.50 W 4.98 501.33N 70.68W N 12.30 W 5.43 566.67N 84.47W N 10.56 W 2.71 635.54N 98.38W 391.27 445.37 504.79 570.86 640.48 4153.82 3945.50 3902.40 51 39 4247.26 4002.73 3959.63 52 47 4340.55 4059.20 4016.10 52 41 4433.63 4115.90 4072.80 52 15 4527.25 4172.53 4129.43 53 17 N 8.72 W 2.95 704.07N ll0.00W N 8.18 W 1.30 777.13N 120.85W N 7.57 W .53 850.68N 131.03W N 7.84 W .52 923.83N 140.92W N 8.48 W 1.23 997.62N 151.51W 709.60 783.19 857.24 930.87 1005.18 4620.39 4228.33 4185.23 53 5 4715.51 4285.89 4242.79 52 25 4807.93 4342.46 4299.36 52 4 4900.42 4399.43 4356.33 51 52 4991.16 4455.44 4412.34 51 53 N 9.32 W .75 1071.30N 163.04W N 10.76 W 1.40 1145.86N 176.24W N 11.27 W .58 1217.59N 190.20W N 9.26 W 1.73 1289.28N 203.19W N 6.15 W 2.70 1360.00N 212.75W 1079.44 1154.68 1227.15 1299.51 1370.70 5086.75 4514.55 4471.45 51 42 5180.26 4572.80 4529.70 51 13 5272.40 4629.32 4586.22 53 5 5366.39 4685.76 4642.66 53 5 5461.14 4742.96 4699.86 52 38 N 6.16 W .19 14~34.69N 220.81W N 7.05 W .90 1507.35N 229.22W N 6.02 W 2.20 1579.63N 237.49W N 5.60 W .36 1654.40N 245.10W N 4.91 W .75 1729.61N 252.02W 1445.74 1518.79 1591.45 1666.55 1742.05 5553.46 4799.13 4756.03 5645.99 4855.81 4812.71 5739.62 4913.44 4870.34 5833.72 4970.56 4927.46 5925.49 5024.99 4981.89 52 52 51 53 53 24 2 58 16 58 N 6.19 W 1.13 1802.53N 259.10W N 6.37 W .43 1875.23N 267.10W N 6.17 W .18 1948.58N 275.16W N 4.15 W 2.19 2023.04N 281.88W N 4.28 W .78 2096.73N 287.31W 1815.27 1888.33 1962.04 2036.78 2110.66 6019.56 5080.24 5037.14 54 4 6114.37 5136.22 5093.12 53 32 6207.30 5191.98 5148.88 52 42 6300.55 5248.02 5204.92 53 25 6394.68 5304.20 5261.10 53 17 N 4.33 W .11 2172.65N 293.02W N 4.87 W .73 2248.92N 299.16W N 4.93 W .89 2322.98N 305.51W N 4.57 W .82 2397.26N 311.68W N 3.52 W .91 2472.60N 317.01W 2186.79 2263.29 2337.61 2412.13 2487.65 SPEk_..f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING POINT MCINTYRE/P1-24 500292270800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 092196 MWD SURVEY JOB NUMBER: AK-MM-60126 KELLY BUSHING ELEV. = 43.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6489.27 5360.22 5317.12 6577.73 5413.05 5369.95 6671.22 5469.45 5426.35 6765.14 5526.80 5483.70 6857.84 5584.60 5541.50 54 4 52 35 53 12 51 31 51 19 N 3.33 W .84 2548.67N 321.56W N 3.16 W 1.68 2619.50N 325.57W N 2.15 W 1.08 2693.98N 329.03W N 1.38 W 1.90 2768.31N 331.32W N 1.06 W .34 2840.76N 332.87W 2563.86 2634.81 2709.35 2783.68 2856.09 6949.86 5642.71 5599.61 7038.68 5699.63 5656.53 7136.60 5763.02 5719.92 7231.04 5824.75 5781.65 7326.26 5887.41 5844.31 50 20 49 55 49 23 48 58 48 43 N 1.43 W 1.11 2912.09N 334.41W N 1.22 W .51 2980.26N 335.99W N .85 W .62 3054.88N 337.34W N .82 W .45 3126.34N 338.38W N .65 W .29 3198.03N 339.30W 2927.37 2995.50 3070.06 3141.44 3213.05 7419.69 5948.75 5905.65 7511.13 6008.39 5965.29 7604.64 6069.19 6026.09 7699.81 6130.71 6087.61 7792.88 6190.61 6147.51 49 49 49 49 49 12 22 31 56 55 N 1.87 W 1.11 3268.49N 340.85W N 1.95 W .20 3337.76N 343.16W N 2.66 W .60 3408.74N 346.02W N 2.94 W .49 3481.27N 349.57W N 2.90 W .04 3552.41N 353.20W 3283.46 3352.74 3423.77 3496.38 3567.60 7884.57 6249.43 6206.33 7977.72 6308.65 6265.55 8071.04 6367.32 6324.22 8162.71 6424.45 6381.35 8257.78 6483.20 6440.10 50 15 50 47 51 16 51 37 52 2 N 2.25 W .65 3622.67N 356.36W N 3.25 W 1.01 3694.49N 359.81W N 2.58 W .76 3766.96N 363.50W N 3.11 W .58 3838.56N 367.06W N 3.60 W .61 3913.18N 371.43W 3637.92 3709.82 3782.37 3854.06 3928.80 8353.05 6541.28 6498.18 8445.24 6597.50 6554.40 8535.28 6652.81 6609.71 8627.18 6709.74 6666.64 8721.79 6768.70 6725.60 52 49 52 1 52 9 51 16 51 37 N 4.04 W .89 3988.53N 376.47W N 4.44 W .92 4061.39N 381.87W N 3.81 W .57 4132.25N 386.98W N 2.00 W 1.82 4204.29N 390.64W N 1.76 W .42 4278.24N 393.07W 4004.32 4077.38 4148.42 4220.54 4294.50 8815.28 6827.55 6784.45 8910.06 6888.17 6845.06 9003.77 6948.33 6905.23 9096.67 7007.85 6964.75 9189.62 7067.33 7024.23 5O 2O 5O 8 49 58 50 19 50 5 N 3.23 W 1.84 4350.81N 396.22W N 4.19 W .81 4423.51N 400.93W N 3.61 W .50 4495.19N 405.82W N 2.14 W 1.27 4566.42N 409.39W N .16 E 1.92 4637.83N 410.63W 4367.12 4439.98 4511.82 4583.14 4654.48 9282.50 7127.01 7083.91 9377.78 7188.33 7145.23 9470.41 7247.90 7204.80 9563.18 7307.58 7264.48 9657.41 7368.27 7325.17 49 55 49 57 50 0 49 54 49 54 N .81 W .82 4708.99N 411.03W N .03 E .68 4781.91N 411.53W N .95 W .81 4852.84N 412.10W N 1.55 W .51 4923.85N 413.65W N 1.04 W .41 4995.91N 415.28W 4725.52 4798.33 4869.16 4940.12 5012.15 SPEk..f-SUN DRILLING SERVICES ANCHOR3kGE ALASKA PAGE SHARED SERVICES DRILLING POINT MCINTYRE/P1-24 500292270800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 092196 MWD SURVEY JOB NUMBER: AK-MM-60126 KELLY BUSHING ELEV. = 43.10 FT. OPER3kTOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9749.75 7427.84 7384.74 9846.08 7489.83 7446.73 9939.41 7549.64 7506.54 10031.00 7608.40 7565.29 10124.77 7668.65 7625.55 49 45 50 8 5O 9 50 2 49 59 N 1.86 W .70 5066.44N 417.06W N 2.03 W .43 5140.13N 419.57W N 2.13 W .08 5211.73N 422.17W N 3.03 W .76 5281.92N 425.33W N 2.54 W .40 5353.68N 428.82W 5082.65 5156.35 5227.97 5298.22 5370.06 10219.11 7729.27 7686.17 10312.67 7789.46 7746.36 10406.14 7849.77 7806.67 10500.33 7910.69 7867.59 10592.15 7970.17 7927.07 50 49 49 49 49 2 52 45 39 35 N 2.96 W .35 5425.88N 432.29W N 1.40 W 1.29 5497.45N 435.01W N 2.91 W 1.24 5568.80N 437.70W N 3.61 W .58 5640.52N 441.78W N 3.31 W .25 5710.34N 446.00W 5442.33 5513.93 5585.31 5657.15 5727.10 10686.33 8031.22 7988.12 49 10780.66 8092.09 8048.99 50 10873.97 8151.95 8108.85 50 10967.15 8212.23 8169.13 49 11060.92 8273.54 8230.44 49 35 2 9 13 7 N 5.23 W 1.55 5781.85N 451.34W N 4.50 W .76 5853.65N 457.45W N 3.24 W 1.04 5925.06N 462.28W N 1.68 W 1.62 5996.04N 465.34W N 2.05 W .32 6066.95N 467.65W 5798.80 5870.84 5942.42 6013.44 6084.36 11155.92 8335.51 8292.41 49 26 11251.02 8397.39 8354.29 49 22 11345.44 8459.14 8416.04 48 58 11440.16 8521.44 8478.34 48 46 11536.80 8585.06 8541.96 48 53 N 3.78 W 1.42 6138.85N 471.31W N 3.49 W .24 6210.92N 475.89W N 1.25 E 3.82 6282.32N 477.29W N .55 E .60 6353.66N 476.17W N 1.10 E .45 6426.39N 475.13W 6156.35 6228.56 6299.91 6371.03 6443.56 11631.79 8647.46 8604.37 11726.36 8709.58 8666.48 11821.23 8771.68 8728.58 11916.33 8833.66 8790.56 12011.63 8895.76 8852.66 48 58 48 54 49 19 49 19 49 20 N 1.85 E .60 6497.98N 473.28W N 1.68 E .15 6569.26N 471.09W N 1.21 E .57 6640.96N 469.28W N 1.59 E .30 6713.06N 467.52W N .95 E .51 6785.33N 465.91W 6514.89 6585.88 6657.33 6729.18 6801.20 12106.64 8957.43 8914.33 49 43 12201.72 9018.80 8975.70 49 52 12293.76 9078.03 9034.93 50 1 12389.19 9139.02 9095.92 50 31 12481.91 9197.89 9154.79 50 38 N 1.51 E .60 6857.59N 464.36W N 1.59 E .17 6930.18N 462.40W N 2.03 E .40 7000.59N 460.17W N 1.70 E .60 7073.95N 457.78W N .74 E .81 7145.56N 456.26W 6873.22 6945.54 7015.68 7088.74 7160.11 12576.73 9258.01 9214.92 50 39 12671.34 9318.09 9274.99 50 30 12765.74 9378.49 9335.39 49 56 12861.08 9441.11 9398.01 47 56 12956.17 9505.89 9462.79 46 9 N .55 E .16 7218.88N 455.43W N 1.51 E .80 7291.96N 454.12W N .98 E .73 7364.48N 452.54W N 1.31 E 2.11 7436.35N 451.11W N .89 E 1.90 7505.93N 449.77W 7233.24 7306.08 7378.37 7450.00 7519.35 SPE~_~f-SUN DRILLING SERVICES ANCI{ORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING POINT MCINTYRE/P1-24 500292270800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 092196 MWD SURVEY JOB NUMBER: AK-MM-60126 KELLY BUSHING ELEV. = 43.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 13003.82 9539.09 9495.99 45 29 N 13080.00 9592.50 9549.40 45 29 N .82 E 1.41 7540.10N .82 E .00 7594.42N 449.26W 7553.42 448.48W 7607.59 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7607.65 FEET AT NORTH 3 DEG. 22 MIN. WEST AT MD = 13080 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 356.39 DEG. TIE-IN SURVEY AT SURFACE PROJECTED SURVEY AT 13,080.00' MD SPk ..Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING POINT MCINTYRE/P1-24 500292270800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 092196 JOB NUMBER: AK-MM-60126 KELLY BUSHING ELEV. = 43.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGUL2LR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -43.10 .00 N .00 E 1000.00 999.94 956.84 5.12 S 5.71 E 2000.00 1999.91 1956.81 4.04 S 5.69 E 3000.00 2990.75 2947.65 110.13 N .01 E 4000.00 3846.31 3803.21 588.41 N 89.22 W .00 .06 .06 .09 .03 9.25 9.16 153.69 144.44 5000.00 4460.89 4417.79 1366.92 N 213.50 W 6000.00 5068.76 5025.66 2156.85 N 291.83 W 7000.00 5674.73 5631.63 2950.66 N 335.36 W 8000.00 6322.73 6279.63 3711.73 N 360.79 W 9000.00 6945.90 6902.80 4492.31 N 405.64 W 539.11 385.42 931.24 392.13 1325.27 394.03 1677.27 352.01 2054.10 376.83 10000.00 7588.49 7545.39 5258.19 N 424.07 W 2411.51 357.42 11000.00 8233.69 8190.59 6020.90 N 466.07 W 2766.31 354.80 12000.00 8888.18 8845.08 6776.51 N 466.06 W 3111.82 345.50 13000.00 9536.42 9493.32 7537.37 N 449.30 W 3463.58 351.77 13080.00 9592.50 9549.40 7594.42 N 448.48 W 3487.50 23.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE~ .f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING POINT MCINTYRE/P1-24 500292270800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 092196 JOB NUMBER: AK-MM-60126 KELLY BUSHING ELEV. = 43.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -43.10 43.10 43.10 .00 143.10 143.10 100.00 243.10 243.10 200.00 343.10 343.10 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .06 S .13 E .00 .00 .02 S .28 E .00 .00 .02 N .44 E .00 .00 443.10 443.10 400.00 543.10 543.10 500.00 643.11 643.10 600.00 743.12 743.10 700.00 843.13 843.10 800.00 .11 N .75 .17 N 1.30 .56 S 2.01 1.44 S 3.01 2.57 S 3.91 E .00 .00 E .00 .00 E .01 .01 E .02 .01 E .03 .01 943.15 943.10 900.00 1043.17 1043.10 10'00.00 1143.17 1143.10 1100.00 1243.18 1243.10 1200.00 1343.18 1343.10 1300.00 4.18 S 5.02 5.81 S 6.13 6.75 S 6.76 7.16 S 6.84 7.40 S 6.72 E .05 .02 E .07 .02 E .07 .01 E .08 .00 E .08 .00 1443.18 1443.10 1400.00 1543.18 1543.10 1500.00 1643.18 1643.10 1600.00 1743.18 1743.10 1700.00 1843.18 1843.10 1800.00 7.20 S 6.34 6.97 S 5.86 6.58 S 5.57 6.19 S 5.33 5.59 S 5.40 E .08 .00 E .08 .00 E .08 .00 E .08 .00 E .08 .00 1943.19 1943.10 1900.00 2043.20 2043.10 2000.00 2143.23 2143.10 2100.00 2243.32 2243.10 2200.00 2343.52 2343.10 2300.00 4.63 S 5.54 3.20 S 5.74 .74 S 5.81 3.35 N 5.51 9.64 N 4.97 E .09 .01 E .10 .01 E .13 .03 E .22 .09 E .42 .20 2443.88 2443.10 2400.00 2544.42 2543.10 2500.00 2645.19 2643.10 2600.00 2746.38 2743.10 2700.00 2848.19 2843.10 2800.00 18.04 N 4.19 28.29 N 2.83 40.52 N .99 55.85 N .71 74.94 N 1.27 E .78 .36 E 1.32 .54 E 2.08 .76 W 3.27 1.19 W 5.09 1.82 2950.84 2943.10 2900.00 3054.13 3043.10 3000.00 3158.32 3143.10 3100.00 3264.25 3243.10 3200.00 3371.84 3343.10 3300.00 98.05 N .14 123.86 N .42 152.97 N 2.92 187.53 N 7.83 226.67 N 14.25 W 7.74 2.65 W 11.03 3.29 W 15.22 4.19 W 21.15 5.93 W 28.74 7.59 SPEk..Z-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING POINT MCINTYRE/P1-24 500292270800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 092196 JOB NUMBER: AK-MM-60126 KELLY BUSHING ELEV. = 43.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3483.39 3443.10 3400.00 3602.95 3543.10 3500.00 3726.88 3643.10 3600.00 3854.55 3743.10 3700.00 3995.27 3843.10 3800.00 275.35 N 21.59 339.20 N 35.91 410.58 N 52.10 488.28 N 68.03 585.02 N 88.48 W 40.29 11.54 W 59.85 19.56 W 83.78 23.93 W 111.45 27.67 W 152.17 40.72 4149.98 3943.10 3900.00 4313.98 4043.10 4000.00 4478.07 4143.10 4100.00 4644.99 4243.10 4200.00 4808.97 4343.10 4300.00 701.11 N 109.53 829.73 N 128.24 958.65 N 145.72 1090.71 N 166.23 1218.40 N 190.36 W 206.88 54.70 W 270.88 64.01 W 334.97 64.09 W 401.89 66.92 W 465.87 63.98 4971.17 4443.10 4400.00 5132.78 4543.10 45'00.00 5295.35 4643.10 4600.00 5461.36 4743.10 4700.00 5625.32 4843.10 4800.00 1344.36 N 211.07 1470.58 N 224.73 1597.88 N 239.42 1729.79 N 252.03 1859.04 N 265.30 W 528.07 62.20 W 589.68 61.61 W 652.25 62.57 W 718.26 66.02 W 782.22 63.96 5787.92 4943.10 4900.00 5956.29 5043.10 5000.00 6125.95 5143.10 5100.00 6292.30 5243.10 5200.00 6460.09 5343.10 5300.00 1986.50 N 279.11 2121.57 N 289.17 2258.20 N 299.95 2390.66 N 311.15 2525.08 N 320.19 W 844.82 62.60 W 913.19 68.37 W 982.85 69.65 W 1049.20 66.35 W 1116.99 67.79 6627.28 5443.10 5400.00 6791.34 5543.10 5500.00 6950.47 5643.10 5600.00 7106.00 5743.10 5700.00 7258.99 5843.10 5800.00 2658.84 N 327.67 2788.81 N 331.82 2912.57 N 334.43 3031.65 N 337.00 3147.42 N 338.68 W 1184.18 67.19 W 1248.24 64.06 W 1307.37 59.14 W 1362.90 55.53 W 1415.89 52.99 7411.05 5943.10 5900.00 7564.45 6043.10 6000.00 7719.06 6143.10 6100.00 7874.66 6243.10 6200.00 8032.33 6343.10 6300.00 3261.95 N 340.64 3378.21 N 344.60 3495.99 N 350.33 3615.06 N 356.06 3736.80 N 362.12 W 1467.95 52.06 W 1521.35 53.40 W 1575.96 54.62 W 1631.56 55.60 W 1689.23 57.67 8192.75 6443.10 6400.00 8356.06 6543.10 6500.00 8519.45 6643.10 6600.00 8680.55 6743.10 6700.00 8839.65 6843.10 6800.00 3862.07 N 368.33 3990.92 N 376.63 4119.78 N 386.15 4245.93 N 392.07 4369.54 N 397.28 W 1749.65 60.41 W 1812.96 63.32 W 1876.35 63.39 W 1937.45 61.11 W 1996.55 59.09 SPE!. _'-SUN DRILLING SERVICES ANCHOP_AGE ALASKA PAGE 9 SHARED SERVICES DRILLING POINT MCINTYRE/P1-24 500292270800 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/96 DATE OF SURVEY: 092196 JOB NUMBER: AK-MM-60126 KELLY BUSHING ELEV. = 43.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8995.64 6943.10 6900.00 4488.98 N 405.43 W 2052.54 56.00 9151.85 7043.10 7000.00 4608.84 N 410.67 W 2108.75 56.20 9307.50 7143.10 7100.00 4728.11 N 411.30 W 2164.40 55.65 9462.95 7243.10 7200.00 4847.12 N 412.00 W 2219.85 55.45 9618.34 7343.10 7300.00 4966.03 N 414.73 W 2275.24 55.39 9773.37 7443.10 7400.00 5084.46 N 417.65 W 2330.27 55.03 9929.21 7543.10 7500.00 5203.90 N 421.87 W 2386.11 55.84 10085.03 7643.10 7600.00 5323.27 N 427.47 W 2441.93 55.82 10240.64 7743.10 7700.00 5442.36 N 433.14 W 2497.54 55.61 10395.81 7843.10 7800.00 5560.93 N 437.30 W 2552.71 55.17 10550.37 7943.10 7900.00 5678.58 N 444.15 W 2607.27 54.56 10704.66 8043.10 8000.00 5795.75 N 452.61 W 2661.56 54.28 10860.16 8143.10 8100.00 5914.48 N 461.68 W 2717.06 55.51 11014.40 8243.10 8200.00 6031.80 N 466.41 W 2771.30 54.24 11167.59 8343.10 8300.00 6147.70 N 471.90 W 2824.49 53.18 11320.99 8443.10 8400.00 6263.86 N 477.49 W 2877.89 53.40 11473.02 8543.10 8500.00 6378.37 N 475.94 W 2929.92 52.03 11625.14 8643.10 8600.00 6492.97 N 473.44 W 2982.04 52.12 11777.40 8743.10 8700.00 6607.73 N 469.99 W 3034.30 52.26 11930.81 8843.10 8800.00 6724.04 N 467.21 W 3087.71 53.41 12084.48 8943.10 8900.00 6840.69 N 464.81 W 3141.38 53.67 12239.42 9043.10 9000.00 6958.99 N 461.60 W 3196.32 54.94 12395.60 9143.10 9100.00 7078.90 N 457.64 W 3252.50 56.19 12553.20 9243.10 9200.00 7200.69 N 455.61 W 3310.10 57.60 12710.65 9343.10 9300.00 7322.27 N 453.33 W 3367.55 57.44 12864.06 9443.10 9400.00 7438.56 N 451.06 W 3420.96 53.41 13009.54 9543.10 9500.00 7544.17 N 449.20 W 3466.44 45.48 13040.00 9564.46 9521.36 7565.90 N 448.89 W 3475.54 9.11 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11122 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 7/3/97 Field: Greater Point Mclntyre Area Excluding P1-09 Floppy Well Job # Log Description Date BL RF Sepia Disk P1-24 · GAS LIFT SURVEY 970522 I 1 ~P2-03 . CBL 970404 I 1 ,, P2-19 · CBL 970614 I 1 P2-19 . CET 970614 I 1 P 2; 30- PRODUCTION PROFILE 97 0501 I 1 P2-42 ~,x~t r.... WAT. ER INJECTION PROFILE 970506 I 1 , p 2-49 . PRODUCTION PROFILE 97 061 2 I I . SIGNED: ~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. CI FI I I--I--I IM G SI~FI~I C I~ S May 1, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data P 1-24 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well P1-24 MWD survey Tie-In point at 0.00', Projected survey at 13,080.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, inc. Company AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data P 1-24 May 1, 1997 Dear Ms. Taylor: Enclosed are twvo hard copies of the above mentioned file(s). Well P1-24 MWD survey Tie-In point at 0.00', Projected survey at 13,080.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company CI I=! I I__1__ I ~J G S I= FI~/I C 1=: S WELL LOG TRANSMITFAL To: State of Alaska March 19, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive. Oh~ Anchorage, Alaska 99501 MWD Formation Evaluation Logs - P 1-24 AK-MM-60126 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention ot~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22703-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9,07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company C] FI I I--I--I IM G WELL LOG TRANSMITTAL To: State of Alaska March 12, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs DS P1-24, AK-MM-60126 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS P1-24: 2"x 5"MD Gamma Ray Logs: 50-029-22703-00 2" x 5" TVD Gamma Ray Logs: 50-029-22703-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10745 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1/29/97 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27/NK-28)] Well Job # Log Description Date BL Floppy RF Sepia Disk P1-11 PRODUCTION PROFILE 961 226 I 1 P1-24 CEMENT BOND LOG 961 21 6 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10458 Company: Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 10/8/96 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Lis Well Job # Log Description Date BL RF Sepia Tape 'P1-24 AlT 960923 I 1 P1-24 BHC 960923 I 1 P1-24 LDT/CNL 960923 I 1 P1-24 96273 OH EDIT-PEX-AIT~LDT/CNL~BHC 960923 1 SIGNED: . . OCT 11 199B DAT~J_ ~k~,.: 0fl ~x ~aS COII~, C0mrnissia~ .... ~"~c~C?~e: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10452 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 10/7/96 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy Well Job # LoB Description Date BL RF Sepia Disk P 1-06 PE~FORATI~iG RECORD 9 6 0 916 I I ' P1-06 STATIC PRESSURE SURVEY 960917 1 1 P1-24 CBL 960926 I 1 P 1-24 BRIDGE PLUG RECORD 9 6 0 9 2 7 I 1 P 1-24 PERFORATING RECORD 9 6 0 92 7 I 1 ~.~--_ _: '-' .'.,"~_ LW ~' _~ ~. OCT 11 199~ SIGNED: DAT ~3~ Of: ~ ~.,~o ~,u.c,. u~.~,t~tO~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. MEMORANDUM TO: THRU: Blair Wondzell, ~ P. !. Supervisor ~//~'/~;; State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 13, 1996 FILE NO: a2gkimdd.doc FROM: Chuck Scheve, ~.,4 SUBJECT: Petroleum Inspector BOPE Test Doyon 14 PBU P1-24 PTD ~96-149 Friday, September 13, 1995: i traveled to ARCO's Point Mclntyre P1-24 well being drilled by Doyon rig 14 and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE Test Report shows there were 2 failures. A flange leak on the choke line and the lower kelly valve. The flange was tightened and retested OK. The lower kelly valve was replaced. The 9.625" surface casing was cemented utilizing a Davis Lynch screw in float collar. The casing was run to 3385',circulated,and landed on the hanger. The landing joint was then layed down to allow drill pipe to be tripped into the casing. The 5" drill pipe was ran to 3299" and screwed into the float collar. At this point the casing was circulated again and reciprocation began. After circulating bottoms up 77bbls of spacer was pumped. The lead cement was then pumped until cement returns were observed at surface,a total of 494 bbls ( calculated volume with gauge hole = 254 bbls )followed by 77 bbis of tail cement and 58 bbls of mud. The casing was reciprocated throughout the cement job. This is this rigs first well after a shut down for maintenance. Much of the rig was freshly painted and all equipment appeared to be in good working order. Summary: I witnessed the BOPE test on Doyon rig 14 - test time 4 hours - 2 failures. Attachment: a2gkimdd.xls X Unclassified STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drig Contractor: Operator: Well Name: Casing Size: g 5/8 Test: Initial X Workover: . .Doyon Rig No. 14 PTD # BPX Rep.: P1-24 Rig Rep.: Set @ 3,385 Location: Sec. Weekly Other DATE: g/13/96 96-149 Rig Ph.# 659-4510 Nick Scales Mark Egholm 16 T. 12N R. 14E Meridian Umiat .. MISC. INSPECTIONS: Location Gen.: OK Housekeeping: '~)K (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign Yes Drl. Rig OK Hazard Sec. Yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 1 1 1 Pressure P/F 250/5,000 P 250/5,000 F/P ' 250/5,000 P 250/5,000 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams 1 Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves Check Valve Test Press. P/F 250/3000 P 250/5,000 P 250/5,000. 250/5,000 250/5,000 250/5,000 I 250/5,OO0 N/A 250/5,~ P P P P P N/A t/IUD SYSTEM: Visual Alarm Trip Tank OK OK =it Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 14 I 250/5,000 28 250/5,000 Functioned 1 Functioned P/F P P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3,100 1,650 minutes 15 2 minutes 40 OK Remote: . 4 Bottles.~2400 average.. Psig. sec. sec. OK Number of Failures: 2 ,Test Time: 4.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 0 daYs. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at:' Fax No 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supenrisor at 279-1433 ~ I I I REMARKS: Flange leak on choke line tightened and tested ok Small leak on lower Kelly valve replaced same Distribution: orig-Weli File c - OperJRig c - Database c - Trip Rpt File c - Inspector ,,, STATE WITNESS REQUIRED7 YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve FI-021L (Rev. 12/94) A2GKIMDD.XLS TONY KNOWLE$, GOVERNOR August 28, 1996 ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Shultz, SDE ARCO Alaska [nc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Point Mclntyre P 1-24 ARCO Alaska, Inc. 96~149 13642qSL, 965'WEL, Sec 16, T12N, R14E, UM o_o22qSL, 1400'WEL, Sec 09, T12N, R14E, UM Dear Mr Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, T~uckerman Babcock Commissioner BY ORDER OF TI-rE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o enct STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ila.~ [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil Type°fw°rk I-IRe-Entry I-IDeepenl []Service []Development Gas r-ISingle Zone I-I Multiple Zone i2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE - 43.3' Point Mclntyre 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034622 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1364' NSL, 965' WEL, SEC. 16, T12N, R14E Point. Mclntyre At top of productive interval 8. Well Number Number U-630610 2475' SNL, 1386' WEL, SEC. 9, T12N, R14E P1-24 Attotal depth §. Approximate spud date Amount $200,000.00 3232' NSL, 1400' WEL, SEC. 9, T12N, R14E 08/30/96 12'.'"Distance to nearest property lineI 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028297, 3232'I PTM-12, 14.9' at Surface 2560 12436' MD / 9189' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 2000' Maximum Hole Angle 52.27 o Maximum surface 3467 psig, At total depth (TVD) 8834' / 4350 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 133# H-40 BTC 108' Surface Surface 108' 108' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 3666' 41' 41' 3707' 3608' 129o sx CS III, 327 sx'G', 250 sx CS II 8-1/2" 7" 26# L-80 BTCM 11539' 41' 41' 11580' 8639' 230 sx Class 'G' 8-1/2" 7" 29# 13CR80 NSCC 856' 11580' 8639' 12436' 9189' 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet ORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner R[CEIVED AUG 2 1 1996 Perforation depth: measured true vertical Alaska 0il & Gas Cons. commission Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requ~ts Contact Engineer Name/Number: Jim Smith, 564-5026 Prepared By Name/Number: Kathy Campoamor, 564-5122 21' I hereby certify that ~ng,is/~N,ela~n%ct t° the best °f Signed my knowledge SteveShultz ! Title Senior Drilling Engineer Date · ~ "--"' '%Commission Use Only / Permit Number I APINumber I ApprovalDate I Seecoverletter /9,~' -/?.~' 50- ~ :~. ¢-- 2_ 2_, ~'(:5 ,-~ ~ -~ ~ --.~'~ for other requirements Yes es~' No Conditions of Approval: Samples Required [] Mud Log Required [] Yes ,,~NO Hydrogen Sulfide Measures ~'I~"Y [] No Directional Survey Required ,~Yes [] No Required Working Pressure for BOPE r-12M; 1-13M; ~ 5M; [] 10M; [] 15M Other: Approved By Original Signed By by order of . , ' ~'~hnnn~' Commissioner the commission Date ~'-c~ ,,~ Form 10-401 Rev. 12-01-85 'rucke i-i'L ~bii :OC Submit In Triplicate [Well Name: IP1-24 Well Plan Summary Type of Well (producer or injector): ] Producer Surface Location: 1364' FSL, 965' FEL, Sec. 16, T12N, R14E UM Target Location: 2475' FNL, 1386' FEL Sec. 9, T12N, R14E UM Bottom Hole Location: 3232' FSL, 1400' FEL Sec. 9, T12N, R14E UM ] AFE Number: 12C0103 I ]Estimated Start Date: 18/30/96 I [MD: ] 12436' I IT VD: 19189'rkb I I Well Design (conventional, slimhole, etc.): I Ultraslimhole Longstring I Rig: I Doyon #14 Operating days to complete: I 18 I KBE: 143.3' I Objective: I Kuparuk Sand Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1853 1853 SV4 3694 3598 9-5/8" casing 3707 3608 Set 9-5/8" casing 10'TVD into SV4 K-15 5885 5003 Lower Ugnu 7712 6153 West Sak 8685 6778 9.5 ppg minimum mud weight required K-10 11367 8502 K-5 11398 8522 HRZ 11678 8702 Kalubik 11779 8767 Kuparuk 11880 8832 10.0 ppg minimum mud weight required WOC 12316 9112 TD 12436 9189 120'MD below WOC Evaluation Program: SURFACE MWD directional only PRODUCTION MWD directional first bit in 8-1/2". After first bit: MWD directional with GR-RES-DEN-NEUT to TD CASED HOLE None LOGS Well Plan Summary Page 1 Mud Program: ISpecial design considerations lAn open hole displacement to +/- 10 ppg Flovis polymer/3% KC1 water I based mud will be performed above the reservoir at the HRZ I Surface Mud Properties: I SPUD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 150 30-40 20-30 40-60 9-10 < 15 Production Mud Properties: I LSND in upper hole to the HRZ DENSITY Plastic Yield Point 10 Sec Gel 10 rain Gel pH Fluid Loss (PPG) Viscosity 9.2 8-15 20-30 5-15 <30 9-9.5 6-12 10.0 8-15 20-30 5-15 <30 9-9.5 6-12 Production Mud Properties: I 3% KCL from HRZ thru Kupamk DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 10.0 8-15 25-30 12-15 <30 9-9.5 4-6 HTHP<15 Directional'. [ KOP: 1 2000'MD Build at 2 to 2.5°/100, Maximum Hole Angle: 52.27° @ 4332'MD, drop to 50° by 6880MD and hold 50° to TD at 12436'MD Close Approach Weft: PTM-12 (14.9'west @sfc) and the P1-23 (15.3'east @sfc) will be shut in until surface casing is mn. There are no deep close approaches. Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDfrVD 30" 20" 133# H-40 BTC 108' GL 108'/108' 12-1/4" 9 5/8" 40.0# L-80 BTC 3666' 41'/41' 3707'/3608' 8 1/2" 7" 26.0# L-80 BTCM 11539' 41'/41' 11580'/8639' 7" 29.0# 13CR80 NSCC 856' 11580'/8639' 12436'/9189' TBG 4.5" 12.64/ 13CR80 NSCT 11739' 41'/41' 11780'/8767' Well Plan Summary Page 2 Cement Data: Casing/Liner Lead: Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments 9-5/8" shoe at 3707'MD 11 shoe at 12436'MD 1290/12.2/1.92 **250% excess lead in perma,plus 30% excess to top of tail none 327/15.8/1.15 **30% excess tail & plan 750'TVD fillup which is 847'MD 230/15.8/1.14 Cold Set IH & Class "G Class "G" TOC- 10880' +/- (1000'MD above Kuparuk)If Stump Is. is present need 500' cmt above that sand. Top Out Job (if necessary) 250/14.95/0.96 Top Out--CSII Contacts Name Office Home Pager James E. Smith Adrian Clark Drilling Eng. Drilling Supt. 564-5026 345-8660 275-4015 564-4720 Drilling HazardsfRisks The original reservoir pressure is 4350 psi at 8800' ss. The expected reservoir pressure is 4250 psi at 8800'ss. Abnormally pressured formations are not expected in this well. Tight hole has been experienced in the lower Sagavanirktok, below the surface casing shoe. This has caused stuck pipe incidents and bit/BHA bailing Gumbo problems. ReP's in this section are typically very fast and care must be taken to ensure the hole does not become overloaded with cuttings. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. RECEIVED A,J~ 2 1 199r0 Alaska Oii & Gas Cons. Commission Anchorage Well Plan Summary Page 3 . o . o . 7. 8. 9. 10. P1-24 Operations Summary MIRU drilling rig. NU and function test diverter. Spud well and drill 12-1/4" hole to 2000' md. Kick off and build angle to 36.6° on 354° azimuth by 3707'MD (casing point). Set 9-5/8" casing and cement same to surface.. Nipple up BOP's and test same to 5000 psi. Test casing to 3000 psi for 30 minutes. Note AOGCC witness or waiver on the morning report. P/U 8 1/2" BHA, drill 20' new hole and perform LOT. Drill ahead and contiunue build to 52.27°, 354° azimuth. Hold angle and azimuth to 6500'MD, then drop angle to 50° and mm to 358°azimuth by 6880'MD. Hold tangent from 6880'MD to 12436' MD (TD). Displace mud to 10.0 ppg 3% KCL at HRZ. If LWD logs were not obtained while drilling the 8-1/2" hole, run wireline open hole logs. Make a cleanout run if the hole is tight. POOH and lay down drill pipe. Run 7" L-80 and 13 chrome casing and cement same, displacing with seawater. Test casing to 3500 psi for 30 minutes. Run 4-1/2" chrome tubing and completion assembly. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Displace tubing to diesel, freeze protect the annulus. Set packer, test tubing. Test annulus. Secure well, release rig. Well Plan Summary Page 4 HD~IZDX[TAL VIEW (TRUE r~[]RTH) SCALE 850 FL, / DIVISION SURVEY J~.F-: WELl_HEAD . ],r~ljBgED, 3] ~1C~36 MB, 9i89 t 2_ - B=. ~,00 . (73£- ~;8,~ 67 ~ ~B,~ 8708 - 3 i8,~ . _ 6778 - ~8.~ 5~4 - ~'~ 544t - ~5. - 3~,~ - - ~4,~ ~3 - 354.~ 970 - 3~,0~ ,3~ -3 3t72 - 353.~ [ 7~ 500 2~ 0 850 500 7~ 3608 TVD 8/16/96' 12~57 pm 3PX- Shaped Senvices Dni'LLing ALaska State PLane: Zone4 P~ Mac', PM~ P1-24 As-BuiLt Pt-~4 Wp3 EST WELLPIJkN FEASIBILITY STUDY This plan is for feasibility purposes only it has not yet been certifiedl IDRITION_ F1]INT DATA '% / , TV]) I~...~E/W MD Inc A~. TIE IN 0 0,00 350.00 0 0 N 0 E Bn~e Perm 18Cx3 0,00 350,00 18153 0 N 0 E KIP / START L:A]JX] 0,03 35~3,00 EgO0 O N 0 E DF BUILD 8 i,[X]/lO0 START DF 3UILD Et300 3,00 350,00 83(X) 8 N 1 W START BIr 8600 g. CO 350.00 QB 39 N 7 W 8,50/100 Pt $V4 3694 36,33 39,65 35¢98 453 N 58 W EN]) BF CLI~VE 4332 58,2_7 354, C/P 4053 8(94 N 1D6 W K-t5 5885 58,P__7 354.0c) 5C03 2116 N ~ W START [3~ 6500 58,P__7 354,09 5380 E600 N a88 ~ i,O0/lO0 Ct END [3~ CURVE] 6880 50,00 358.00 ~lB PIB95 N 303 W '. IL"~u 771a 50.00 358,00 6t53 3532 N 385 W K-10 11~? ~,00 358,00 850~ 6330 N 483 W K-s ~3~ ~,00 3=,00 8~2 63~4 N 424 w HRZ 11678 50,00 358,00 8708 6568 N 431 W Katu~k t177g 50.00 358,00 8767 6646 N 434 ~ Ta~.qe'~ 11880 50,00 358,00 883~ 6723 N 437 W (6/8/g6) / ~g(~k 12316 50.00 358,00 9112 7057 N 448 W CASING PDINT DATA OD MD Inc Az; TVD N/S g 5/8 in 3707 36.64 353,67 3608 460 N 59 7 in 18436 50,00 358,00 9189 7148 N 451 W To~.qet 6k~e TVD NS EW ~ C~id X C~id Y T~get (6/8~) 8838 67Er3 N 437 W 6735[X3 6DO1L:K]O RECEIVED AUG 2 1 1996 Alask~ Oil & Gas 6ons. 6ommission Anchorage JID Depth(fi) Tool ~e I P1-24 Wp3 0-18436 20.03 BPPiq-PBD Dote PLotted : 8/16/96 C~ected By Checked By Approved By D~te 000 153 50O 778 DOD VERTICAL VIEW SCALE 500 Ft, / DIVISI[N TVD REF: WELLHEAD VERTICAL SECTION REP WELLHEAD 0,00 E 0 ~ l~ IN 4~ 0.00 ~' 11~3 HD D. O0 E BOOO MI) KIP / START OF 3~0 e 8300 I~) S'TPRT 13.99 ~ ~ 16.4g 8 8~00 MD 18,':J~ 8 30DO 81.'18 E 3100 HD 31.48 E 41,4~ 8 ~ MD ,1~.47 ~ 4100 HD 81~6 5885 MD K-15 8613 50,00 8 ~18 I~ L. IJ~u WELLPLAN FEASIBILITY STUDY Thls plan is for feaslbilily purpol~s qnlv it has not yet been certifledl CRITICAL POINT DATA MD Inc Azi. TVD TIE IN 0 0.00 ~.00 0 tNlse Perm 1853 0,00 35~3.00 1853 KDP / START 2000 0,00 350.00 8000 OF BUILD 8 1,00/100 Ft START OF BUILD 2300 ' 3,00 350.00 2300 8 8,00/100 f~ START OF 8600 g,00 350.00 8598 CURVE 8 2.50/100 ft ~V4 3694 36,33 :~x~.65 3508 END OF CURVE 4338 58.87 354.09 4053 K- 15 5885 58,87 354.09 5003 START OF 6500 58.27 354.09 5380 CURVE 8 1,00/ 1 OD ft DOr Rv 50.00 .00 50,00 .00 6778 -10 11 7 50,00 .00 K-5 11398 50,00 358.00 8522 FRZ 11678 50,00 358,00 8708 K~tuk~ k 11779 50,00 358,00 8767 Top.qet 11880 50.00 358.0O 8832 (6/8/96) / N/S E/W ON OE ON OE ON OE 8N 3gN 7 V '. 459 N 58 ~ 894 N 106 V 2116 N 232 W 2600 N 882 V 8895 N 303 W 3538 N 385 V 4277 N 351 W 6330 N 423 W 6354 N 424 V 6568 N 431 ~ 6646 N 434 W 6723 N 437 W 7057 N 448 V CASING PO~T DATA OD MD Inc A~ TVD N/S E/W g 5/8 in 3707 ~,64 353.67 3608 460 N 59 W 7 in 12436 50.00 358.00 glBg 7148 N 451W T~.RetNc~me TVD NS EW C_.~'id X C.~id Y T~get (6/8/96) 8838 6783 N 437 W 673500 60012:~3D -500 0 500 1000 1500 80DO 8500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 IID Dept~rt) To~ Code P1-~4 Vp3 0-12436 L:~O.03 BFI4M-PBD TVD 9189.30 MD 124:~5.56 VS 7168.62 N/S 7148.38 N E/W 451.43 W Dote ~otted : 8/16/96 C~eated By : O~ecked By : P~oproved By : Dote : 6. 7. 8. 9. 10. 11. 1:3. 'ENGINEERING · WELL PERMIT CHECKLIST COMPANY/~'"~.- FIELD & POOL ~"~",~'/'r3 ~ INIT CLASS .Z~ .ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number ................ N 4. Well located in a defined 13oo1. N 5. Well located proper distance from drlg unit boundary .... N Well located proper distance from other wells ........ N Sufficient acreage available in drilling unit. ......... N If deviated, is wellbore plat included ............. N Operator only affected party .................. N Operator has appropriate bond in force ........... N Permit can be issued without conservation order ..... N Permit can be issued without administrative approval... N Can permit be approved before 15-daY wait. ........ N GEOL AREA .. ~~ UNIT# '.~?~, ~'/'P ON/OFF SHORE REMARKS N N APPR DATE 14. Conductor string provided ................... ~ N 15. Surface casing protects all known USDWs 16. CMT vol adequate to circulate on conductor ~'s~ll~ ~ '. '. '. 17. CMT vol adequate to tie-in long s~ing to surf csg ....... Y N 18. CMT will cover all known productive hodzons ......... {~) N 19. Casing designs adequate for C, T, B & permafrost. ..... .~ N 20. Adequate tankage or reserve pit ................ (Y-/N 21. If a re-drill, has a 10-403 for abndnmnt been approved .... 22. Adequate wellbore separation proposed ............ (~ N 23. If diverter required, is it adequate ................ (~ N 24. Ddlling fluid program schematic & equip list adequate .... .~[) N 25. BOPEsadequate ........................ (~ N 26. BOPE press rating adequate; test to '~"'o0(~ psig.(~) N 27. Choke manifold complies w/APl RP-53 (May 84) ....... ~ N 28. Work will occur without operation shutdown .......... ~ N 29. Is presence of H2S gas probable ............... (~ N GEOLOGY D ,TE can be issued w/o hydrogen sulfide measures ..... Y N////// ~ 30. Permit 31. Data presented on potential overpressure zones ....... Y x~l //~,,'~ ,~IJ ,, 32. Seismic analysis of shallow gas zones ............. )Y' N ' 33. Seabed condition survey (if off-shore) ............ //Y N 34. Contact name/phone for weekly pro(jres~, repo~,. .... X'. Y N ~exp~ora~ory on,l] ~ GEOLOGY': ENGINEERING: JDH JDN COMMISSION: TAB Comments/Instructions: HOW4lb - AN:ORM.Shcheklist rev 4,~J6 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Mar 13 17:17:02 1997 Reel Header Service name ............. LISTPE Date ..................... 97/03/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical services Tape Header Service name ............. LISTPE Date ..................... 97/03/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOG& WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: MWD RUN 3 AK'MM-60126 PAUL ROBERTS P1-24 500292270300 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 13-MAR-97 MWD RUN 4 AK-MM-60126 PAUL ROBERTS OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (ET FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD NICK SCALES KIRK WHITE 16 12N 14E 1364 965 43.10 41.60 9.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 9.625 3386.0 ~3RD STRING 12.250 7.000 13080.0 PRODUCTION STRING 8.500 13080.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR AND CRITICAL VELOCITIES CALCULATED USING THE 'POWER LAW' HYDRAULICS MODEL. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) USING GEIGER MUELLER TYPE GAMYuA RAY PROBE/DETECTORS. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC. ON JANUARY 14, 1997. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13080'MD, 9593'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3356.0 13017.0 ROP 3410.0 13080.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH -- Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 3 3410.0 6645.0 4 6645.0 13080.0 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6500 13080 9790 13161 6500 GR 19.1698 317.714 80.0392 13035 6500 ROP 1.7647 4777.73 95.7683 13161 6500 Last Reading 13080 13017 13080 First Reading For Entire File .......... 6500 Last Reading For Entire File ........... 13080 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3356.0 6591.5 ROP 3410.0 6645.5 $ LOG HEADER DATA DATE LOGGED: 15-SEP-96 SOFTWARE SURFACE SOFTWARE VERSION: 4.88 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 6645.0 TOP LOG INTERVAL (FT): 3410.0 BOTTOM LOG INTERVAL (FT): 6645.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.8 MAXIMUM ANGLE: 52.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0582CG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8.5 BOREHOLE CONDITIONS MUD TYPE: LSND-LT MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 42.0 11.8 1200 6.0 .000 .000 .000 .000 38.5 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Objective: Continue building angle in 8.5"out of 9 5/8" casing set at 3385 fT. Result: Drilled to 6645 Ft., POOH TO PICKUP PDC BIT. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GRC3 MWD 3 AAPI 4 1 68 4 2 ROP3 MWD 3 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 6500 6645.5 6572.75 292 GRC3 37.2947 109.544 77.5263 184 ROP3 21.8162 450 117.996 291 First Reading 6500 6500 6500 Last Reading 6645.5 6591.5 6645.5 First Reading For Entire File .......... 6500 Last Reading For Entire File ........... 6645.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/13 Maximum Physical Record..65535 File Type ................ LO 'Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH GR 6592.0 ROP 6647.0 LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM1viA RAY $ STOP DEPTH 13017.0 13080.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 22-SEP-96 4.88 5.46 MEMORY 13080.0 6645.0 13080.0 45.5 53.2 TOOL NUMBER P0582CG6 8.500 8.5 KCL GELL 10.20 54.0 9.0 18000 5.2 .000 .000 .000 .000 63.5 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: Objective: Continue to Drill tangent section and TD Well Result: TD Well @ 13080' MD $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GRC4 MWD 4 AAPI 4 1 6'8 4 2 ROP4 MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6582.5 13080 9831.25 12996 6582.5 GRC4 19.1698 317.714 80.0416 12870 6582.5 ROP4 1.7647 4777.73 95.2663 12867 6647 Last Reading 13080 13017 13080 First Reading For Entire File .......... 6582.5 Last Reading For Entire File ........... 13080 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/03/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File RECEtVEO OCT '! ] '1996 Ar~or,~:j_ e * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NA~E : ARCO ALASKA, INC. WELL NAME : P1-24 FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 50-029-22703-00 REFERENCE NO : 96273 * ALASKA COMPUTING CENTER * . . ****************************** * ............................ * * ....... SCHLUMBERGER ....... * ............................ * ****************************** COMPANY NAM~ : ARCO ALASKA, INC. WELL NAME : P1-24 FIELD NAFIE : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUFiBER : 50-029-22703-00 REFERENCE NO : 96273 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/10/ 4 ORIGIN : FLIC REEL NAME : 96273 CONTINUATION # : PREVIOUS REEL : COF~4ENT : ARCO ALASKA INC, P1-24, PT. MACINTYRE, API #50-029-22703-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/10/ 4 ORIGIN : FLIC TAPE NAME : 96273 CONTINUATION # : 1 PREVIOUS TAPE : COFk4EJ~T : ARCO ALASKA INC, P1-24, PT. MACINTYRE, API #50-029-22703-00 TAPE HEADER POINT MCINTYRE OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUM~ER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RUN1 96273 MAJCHER L. BAKER WELL CASING RECORD 1ST STRING 2ND STRING P1-24 500292270300 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 4-0CT-96 RUN 2 RUN 3 .......... 9 12N 14E 1364 965 43.30 41.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ................................ 8.500 9.625 3385.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 3RD STRING PRODUCTION STRING This tape has the data from the Platform Express plus BHC Sonic logged 23-Sep-96. The edited data was depth shifted to Sperry MWD GR. The mnemonics used are all LDWGmnemonics. $ PAGE: **** FILE HEADER **** FILE NAFiE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUFff~ARY LDWG TOOL CODE START DEPTH AIT 13074.0 BCS 13031.0 SDN 13055.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (NIEASUREDDEPTH) BASELINE DEPTH 88888.0 12922.5 12768.0 12704.0 12644.5 12630.0 12627.5 12602.5 12517.5 12456.5 12441.0 12416.0 12336.0 12328.0 12320.0 12306.5 STOP DEPTH 3380.0 3380.0 8300.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... AIT BCS SDN 88887.0 12921.5 12764.5 12702.0 12641.0 12625.5 12620. $ 12596.0 12511.0 12449.0 12434.0 12409.5 12329.0 12323.0 12314.5 12301.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12287.0 12242.0 12207.0 12177.0 12148.0 12123.5 12066.0 12060.5 12040.0 12028.0 11989.0 11980.5 11977.0 11938.0 11914.0 11886.0 11874.5 11839.5 11810.0 11803.0 11796.0 11790.0 11779.0 11747.0 11742.5 11737.5 11726.5 11722.5 11713.5 11702.5 11677.5 11658.0 11644.0 11602.0 11579.0 11549.0 11516.5 11493.0 11476.0 11448.5 11367.5 11317.0 11312.5 11270.0 11251.5 11239.5 11226.5 11100.5 11049.0 11036.5 11018.0 10977.0 10955.5 10853.0 10748.0 12281.5 12236.5 12202.5 12172.5 12144.5 12118.0 12060 5 12054 5 12037 0 12024 5 11988 0 11979 5 11975 5 11937 5 11914 0 11886 0 11873 5 11839 5 11809 0 11802.0 11794.5 11789.0 11778.0 11746.0 11742.5 11735.0 11725.0 11720.5 11711.5 11700.5 11675.5 11655.5 11641.5 11599.0 11575.5 11545.0 11514.0 11487.0 11466.5 11440.0 11362.5 11311.5 11306.5 11263.0 11249.0 11238.5 11223.5 11098.0 11045.5 11031.0 11013.0 10974.5 10952.5 10853.0 10746.0 4-0CT-1996 14:23 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10729.5 10601.0 10546.5 10504.0 10487.5 10399.0 10364 5 10320 5 10043 0 10001 0 9988 0 9961 5 9888 0 9863 0 9756 0 9653 5 9586.0 9544.5 9515.0 9452.5 9345.5 9296.5 9292.0 9272.0 9258.0 9225.5 9197.5 9111.0 9027.5 8998.5 8895.0 8862.5 8796.0 8760.0 8699.0 8657 5 8634 0 8613 5 8590 0 8564 5 8535 0 8505.5 8493.0 8475.0 8408.5 8395.5 8346.0 8327.0 8304.0 8261.5 8227.0 8215.0 8201.0 8192.5 8159.5 10729 0 10602 0 10548 5 10505 0 10486 5 10397 0 10359 5 10314.5 10038.0 9999.5 9985.5 9960.0 9889.0 9865.5 9754.0 9653.0 9584.5 9541.0 9512.0 9450.0 9340.5 9292.0 9286.5 9265.5 9250.5 9218.5 9192.0 9106.5 9023.5 8995.5 8893.5 8861 0 8790 0 8755 5 8689 0 8646 0 8624 5 8604 0 8582, 0 8556~ 0 8526, 0 8497.0 8484.5 8467.0 8400.5 8387.5 8336.5 8319.5 8294.0 8251.0 8216.5 8205.0 8191.0 8182.5 8149.0 4-0CT-1996 14:23 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8148.5 8130.0 8109.5 8074.5 8062.5 8038.0 8002.0 8000.0 7995.5 7974.0 7955.0 793 O. 0 7890.5 7883.0 7869.0 7851.5 7813.5 7801.0 7790.0 7779.0 7772.0 7741.5 7712.5 7656.5 7607.5 7598.0 7578.0 7571.5 7531.0 7487.5 7481.5 7472 5 7460 0 7453 0 7450 0 7442 5 7394 0 7304 0 7261 0 7217 0 7187 0 7161.5 7124.5 7100.5 7051.5 7033.0 7017.5 7002.0 6986.5 6973.0 6938.5 6911.5 6892.0 6838.5 6817.0 8138.0 8120.5 8100.0 8065.0 8053.5 8029.5 7994.0 7991.0 7986.5 7964.0 7945.5 7919.5 7881.0 7873.5 7859.5 7842.0 7804.0 7791.5 7781.0 7770.5 7763.0 7733.0 7705.0 7648.5 7599.5 7590 0 7569 5 7562 5 7522 0 7478 5 7473 0 7464 0 7451 5 7446, 0 7444 0 7434, 0 7385.5 7295.0 7252.5 7209.0 7179.0 7152.5 7115.5 7092.5 7043.5 7024.5 7009.0 6993.5 6978.5 6965.0 693 O. 5 6903.5 6884.5 6831.0 681 O. 0 4-0CT-1996 14:23 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6799.5 6742.5 6706.0 6698.5 6665.0 6655.5 6639.0 6603.5 6565.0 6531.5 6492.5 6488.5 6458.0 6391.0 6373.5 63 64.5 6350.0 6340.5 6324.0 6322.0 6285.5 62 61.5 6254.5 6181.0 6168.5 6152.5 6146.5 6136.0 6126.5 6115.5 6100.0 6088.0 6050.0 6000.5 5967.0 5940.5 5909.5 5872.5 5860.0 5837.5 5799.5 5774.0 5754.5 5717.5 5696.0 5676.5 5660.5 5576.5 5562.5 5533.0 5523.0 5438.0 5328.5 5242.0 5214.0 6792.0 6735.5 6697.0 6691.5 6655.0 6646.5 6629.5 6595.0 6557.0 652 6.0 6486.0 6482.0 6451.0 6384.0 63 68.0 6358.5 6344.5 6334.0 6317.0 6314.0 6278.0 6254.5 6245.5 6173.5 6159.5 6145.0 6141.0 6129.0 6118.5 6108.0 6095.0 6082.5 6044.5 5993.0 5959 0 5931 5 5899 0 5862 0 5851 5 5829 0 5791.0 5766.0 5745.5 5708.5 5687.5 5664.5 5651.5 5565.5 5552.0 5522.5 5511.0 5426.0 5319.0 5231.0 5203.0 4-0CT-1996 14:23 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5141.5 5071.5 5022.0 4926.5 4908.5 4870.5 4846.0 4813.0 4727.5 4704.5 4691.0 4657.5 4644.0 4554.5 4552.5 4542.0 4529.5 4520.5 4510.5 4480.5 4445.0 4382.0 4335.0 4309.5 4276.0 4264.0 4252.0 4209.5 4178.0 4138.5 4125.5 4121.0 4090.0 4087.5 4076.5 4057.0 4049.0 4009.5 3992.5 3987.5 3952.0 3938.5 3923.5 3915.0 3870.5 3810.5 3790.0 3739.5 3725.5 3702.0 3648.0 3608.5 3591.5 3506.5 3462.5 5130 5 5060 5 5010 0 4916 5 4898 0 4861 5 4836.5 4802.0 4715.5 4692.5 4680.0 4649.0 4635.0 4545.5 4542.5 4531.0 4521.0 4511.5 4501.0 4469.5 4435.0 4372.5 4325.5 4299.0 4265.5 4252.5 4240.5 4198.5 4167.5 4128.0 4115.0 4111.5 4082.0 4077.5 4067.0 4048.5 4039.0 4001.5 3983.0 3977.5 3941.0 3926.0 3910.5 3900.0 3857.5 3800.5 3778.0 3728.5 3714.5 3691.0 3637.0 3597.0 3580.0 3495.0 3451.0 4-0CT-1996 14:23 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE 3437.0 3426.0 3423.0 3413.0 100.0 90.0 $ M~RGED DATA SOURCE LDWG TOOL CODE RUN NO. $ REMARKS: PASS NO. M~RGE TOP M~RGE BASE This file is the edited OH data from Platform Express plus BHC Sonic. The data was depth shifted to Sperry MWD GR. The data is resampled to -.5' sample rate. The mnemonics used are as follows: AIT = AITH, BCS = BHC, SDN = PEX (Platform Express Density Neutron). The main log pass had several sections of invalid data due to pulling tight, so Repeat pass data was spliced in its place. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 $ 66 6 73 7 65 8 68 0.$ 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: ** SET TYPE - CHAN ** NANiE SERV UNIT SERVICE API API API API FILE NUNiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~iB SAMP ELEM CODE (HEX) DEPT FT 666675 O0 000 O0 0 1 1 1 4 68 0000000000 GR AIT GAPI 666675 O0 000 O0 0 1 1 1 4 68 0000000000 TENS AIT LB 666675 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 666675 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 666675 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU 666675 O0 000 O0 0 1 1 1 4 68 0000000000 NPOR CNT PU 666675 O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F 666675 O0 000 O0 0 1 1 1 4 68 0000000000 CALI SDN IN 666675 O0 000 O0 0 1 1 1 4 68 0000000000 t{DRA SDN G/C3 666675 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN 666675 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 666675 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN 0P24~666675 O0 000 O0 0 1 1 1 4 68 0000000000 AHT1 AIT 0PH~4666675 O0 000 O0 0 1 1 1 4 68 0000000000 AHT2 AIT 0P~4~666675 O0 000 O0 0 1 1 1 4 68 0000000000 AHT3 AIT OH~ff4666675 O0 000 O0 0 1 1 1 4 68 0000000000 AHT6 AIT Ot~4M 666675 O0 000 O0 0 1 1 1 4 68 0000000000 AHT9 AIT OPff4M666675 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13080.000 GR.AIT -999.250 TENS.AIT 7515.000 CNTC. CNT CFTC. CNT -999.250 NPHI.CNT -999.250 NPOR.CNT -999.250 DT. BCS CALI.SDN -999.250 PZDRA.SDN -999.250 PEF. SDN -999.250 RHOB.SDN MSFL.SDN -999.250 AHT1.AIT -999.250 AHT2.AIT -999.250 AHT3.AIT AHT6.AIT -999.250 AHTg. AIT -999.250 DEPT. 13000.000 GR.AIT 111.144 TENS.AIT 7554.000 CNTC. CNT CFTC. CNT 603.102 NPHI.CNT 33.972 NPOR.CNT 31.299 DT.BCS CALI.SDN 7.847 RDRA.SDN 0.133 PEF. SDN 4.154 RHOB.SDN MSFL.SDN 1.011 AHT1.AIT 3.150 AHT2.AIT 4.241 AHT3.AIT AHT6.AIT 3.687 AHTg. AIT 3.420 DEPT. 12000.000 GR.AIT 88.215 TENS.AIT 6858.688 CNTC. CNT CFTC. CNT 1789.063 NPHI.CNT 19.485 NPOR.CNT 18.114 DT.BCS CALI.SDN 7.905 I{DRA.SDN -0.001 PEF. SDN 3.101 RHOB.SDN MSFL.SDN 9.018 AHT1.AIT 5.708 AHT2.AIT '5.953 AHT3.AIT AHT6.AIT 6.262 AHTg.AIT 5.717 DEPT. 11000.000 GR.AIT 104.359 TENS.AIT 6458.875 CNTC. CNT CFTC. CNT 791.892 NPHI.CNT 30.678 NPOR.CNT 30.328 DT. BCS CALI.SDN 8.361 RDRA.SDN 0.087 PEF. SDN 3.342 RHOB.SDN MSFL.SDN 1.743 AHT1.AIT 2.257 AHT2.AIT 2.367 AHT3.AIT AHT6.AIT 2.457 AHTg.AIT 2.322 -999.250 -999.250 -999.250 -999.250 1779.735 90.000 2.367 3.440 3486.164 76.820 2.499 6.428 2173.875 90.069 2.403 2.495 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 10 DEPT. 10000.000 GR.AIT CFTC. CNT 723.986 NPHI. CNT CALI.SDN 7.726 PiDRA.SDN MSFL. SDN 1.168 AHT1.AIT AHT6.AIT 2.310 AHT9.AIT DEPT. 9000.000 GR.AIT CFTC. CNT 748.750 NPHI. CNT CALI.SDN 7.139 HDRA. SDN MSFL.SDN 1.337 AHT1.AIT AHT6.AIT 5.090 AHT9.AIT DEPT. 8000.000 GR.AIT CFTC. CNT 928.188 NPHI.CNT CALI.SDN -999.250 HDRA.SDN MSFL.SDN -999.250 AHT1.AIT AHT6.AIT 1.894 AHT9.AIT DEPT. 7000.000 GR.AIT CFTC. CNT 1405.825 NPHI.CNT CALI.SDN -999.250 F~DRA.SDN MSFL.SDN -999.250 AHT1.AIT AHT6.AIT 2.560 AHT9.AIT DEPT. 6000.000 GR.AIT CFTC. CNT 684.922 NPHI. CNT CALI.SDN -999.250 HDRA.SDN MSFL.SDN -999.250 AHT1.AIT AHT6.AIT 1.777 AHTg. AIT DEPT. 5000.000 GR.AIT CFTC. CNT 556.516 NPHI.CNT CALI. SDN -999.250 HDRA.SDN MSFL.SDN -999.250 AHT1.AIT AHT6.AIT 4.235 AHTg.AIT DEPT. 4000.000 GR.AIT CFTC. CNT 531.320 NPHI.CNT CALI.SDN -999.250 HDRA.SDN MSFL.SDN -999.250 AHT1.AIT AHT6.AIT 2.716 AHT9.AIT DEPT. 3381.000 GR.AIT CFTC. CNT 405.881 NPHI. CNT CALI.SDN -999.250 HDRA.SDN MSFL.SDN -999.250 AHT1.AIT AHT6.AIT 0.737 AHT9.AIT 106. 938 TENS. AIT 33.179 NPOR. CNT 0.112 PEF. SDN 2. 215 AHT2 .AIT 2.208 115.000 TENS.AIT 33.655 NPOR.CNT 0.114 PEF. SDN 2.076 AHT2.AIT 4.839 72.004 TENS.AIT 35.131 NPOR.CNT -999.250 PEF. SDN 1.820 AHT2.AIT 1.851 57. 089 TENS.AIT 2 6.210 NPOR. CNT -999. 250 PEF. SDN 1. 731 AHT2. AIT 2. 356 54.154 TENS. AIT 46. 076 NPOR . CNT -999. 250 PEF. SDN 1. 612 AHT2 .AIT 1. 736 86.164 TENS.AIT 41.704 NPOR.CNT -999.250 PEF. SDN 2.198 AHT2.AIT 4.174 83.780 TENS.AIT 37.717 NPOR.CNT -999.250 PEF. SDN 2.543 AHT2.AIT 2.752 64.333 TENS.AIT 45.163 NPOR.CNT -999.250 PEF. SDN 1.127 AHT2.AIT 0.741 5996.078 32.455 3.299 2.309 5443.375 31.644 2.529 3.729 4806.703 30.316 -999.250 1.947 4719.000 23.547 -999.250 2.673 4071.297 36.601 -999.250 1.796 3598.422 35.209 -999.250 3.831 3130.672 36.626 -999.250 2.450 2992.000 42.274 -999.250 0.686 CNTC. CNT DT. BCS RHOB. SDN AHT3 . AIT CNTC. CNT DT. BCS RHOB. SDN AHT3 . AIT CNTC. CNT DT. BCS RHOB. SDN AHT3 . AIT CNTC. CNT DT. BCS RHOB. SDN AHT3 . AIT CNTC. CNT DT. BCS RHOB. SDN AHT3 . AIT CNTC. CNT DT.BCS RHOB.SDN AHT3.AIT CNTC. CNT DT. BCS RHOB. SDN AHT3 . AIT CNTC. CNT DT. BCS RHOB. SDN AHT3 . AIT 2034. 563 95. 854 2.294 2. 262 2123.250 90.932 2.376 4.381 2439. 781 96. 383 -999. 250 1. 929 3105.236 82.900 -999.250 2.668 2167.914 120.128 -999.250 1.723 1671.939 115.000 -999.250 3.975 1680.496 131.973 -999.250 2.581 1477.076 138.400 -999.250 1.099 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 11 **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE . 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NOMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUFiBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE AIT BCS SDN $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 3380.0 3280.0 3380.0 3280.0 3380.0 3280.0 BASELINE DEPTH 88888 0 12922 5 12768 0 12704 0 12644 5 12630 0 12627 5 12602 5 125175 12456.5 12441.0 12416.0 12336.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... AIT BCS SDN 88887.0 12921.5 12764.5 12702.0 12641.0 12625.5 12620.5 12596.0 12511.0 12449.0 12434.0 12409.5 12329.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12328.0 12320.0 12306.5 12287.0 12242.0 12207.0 12177.0 12148.0 12123.5 12066.0 12060.5 12040.0 12028.0 11989.0 11980.5 11977.0 11938.0 11914.0 11886.0 11874.5 11839.5 11810.0 11803.0 11796.0 11790.0 11779.0 11747.0 11742.5 11737.5 11726.5 11722.5 11713.5 11702.5 11677.5 11658.0 11644.0 11602.0 11579.0 11549.0 11516.5 11493.0 11476.0 11448.5 11367.5 11317.0 11312.5 11270.0 11251.5 11239.5 11226.5 11100.5 11049.0 11036.5 11018.0 10977.0 12323.0 12314.5 12301.5 12281.5 12236.5 12202.5 12172.5 12144.5 12118.0 12060.5 12054.5 12037.0 12024.5 11988.0 11979.5 11975.5 11937.5 11914.0 11886.0 11873.5 11839.5 11809.0 11802.0 11794.5 11789.0 11778.0 11746.0 11742.5 11735.0 11725.0 11720 5 11711 5 11700 5 11675 5 11655 5 11641 5 11599 0 11575 5 11545 0 11514 0 11487 0 11466.5 11440.0 11362.5 11311.5 11306.5 11263.0 11249.0 11238.5 11223.5 11098.0 11045.5 11031.0 11013.0 10974.5 4-0CT-1996 14:23 PAGE: 12 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10955.5 10853.0 10748.0 10729.5 10601.0 10546.5 10504.0 10487.5 10399.0 10364.5 10320.5 10043.0 10001.0 9988.0 9961.5 9888.0 9863.0 9756.0 9653.5 9586.0 9544.5 9515.0 9452.5 9345.5 9296.5 9292.0 9272.0 9258.0 9225.5 9197.5 9111.0 9027.5 8998.5 8895.0 8862.5 8796.0 8760.0 8699.0 8657.5 8634.0 8613.5 8590.0 8564.5 8535.0 8505.5 8493.0 8475.0 8408.5 8395.5 8346.0 8327.0 8304.0 8261.5 8227.0 8215.0 10952.5 10853.0 10746.0 10729.0 10602.0 10548.5 10505.0 10486.5 10397 0 10359 5 10314 5 10038 0 9999 5 9985 5 9960.0 9889.0 9865.5 9754.0 9653.0 9584.5 9541.0 9512.0 9450.0 9340.5 9292.0 9286.5 92 65.5 9250.5 9218.5 9192.0 9106.5 9023.5 8995 5 8893 5 8861 0 8790 0 8755 5 8689 0 8646.0 8624.5 8604.0 8582.0 8556.0 8526.0 8497.0 8484.5 8467.0 8400.5 8387.5 8336.5 8319.5 8294.0 8251.0 8216.5 8205.0 4-0CT-1996 14:23 PAGE: 13 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8201.0 8191.0 8192.5 8182.5 8159.5 8149.0 8148.5 8138.0 8130.0 8120.5 8109.5 8100.0 8074.5 8065.0 8062.5 8053.5 8038.0 8029.5 8002.0 7994.0 8000.0 7991.0 7995.5 7986.5 7974.0 7964.0 7955.0 7945.5 7930.0 7919.5 7890.5 7881.0 7883.0 7873.5 7869.0 7859.5 7851.5 7842.0 7813.5 7804.0 7801.0 7791.5 7790.0 7781.0 7779.0 7770.5 7772.0 7763.0 7741.5 7733.0 7712.5 7705.0 7656.5 7648.5 7607.5 7599.5 7598.0 7590.0 7578.0 7569.5 7571.5 7562.5 7531.0 7522.0 7487.5 7478.5 7481.5 7473.0 7472.5 7464.0 7460.0 7451.5 7453.0 7446.0 7450.0 7444.0 7442.5 7434.0 7394.0 7385.5 7304.0 7295.0 7261.0 7252.5 7217.0 7209.0 7187.0 7179.0 7161.5 7152.5 7124.5 7115.5 7100.5 7092.5 7051.5 7043.5 7033.0 7024.5 7017.5 7009.0 7002.0 6993.5 6986.5 6978.5 6973.0 6965.0 6938.5 6930.5 6911.5 6903.5 4-0CT-1996 14:23 PAGE: 14 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6892.0 6838.5 6817.0 6799.5 6742.5 6706.0 6698 5 6665 0 6655 5 6639 0 6603 5 6565 0 6531 5 6492 5 6488.5 6458.0 6391.0 6373.5 63 64.5 6350.0 6340.5 6324.0 6322.0 6285.5 6261.5 6254.5 6181.0 6168.5 6152.5 6146.5 6136.0 6126.5 6115.5 6100.0 6088.0 6050.0 6000.5 5967.0 5940.5 5909.5 5872.5 5860.0 5837.5 5799.5 5774.0 5754.5 5717.5 5696.0 5676.5 5660.5 5576.5 5562.5 5533.0 5523.0 5438.0 6884.5 6831.0 681 O. 0 6792.0 6735.5 6697.0 6691.5 6655.0 6646.5 6629.5 6595.0 6557.0 6526.0 6486.0 6482.0 6451.0 6384.0 63 68.0 6358.5 6344.5 6334.0 6317.0 6314.0 6278.0 6254.5 6245.5 6173.5 6159.5 6145.0 6141.0 6129.0 6118 5 6108 0 6095 0 6082 5 6044 5 5993 0 5959 0 5931.5 5899.0 5862.0 5851.5 5829.0 5791.0 5766.0 5745.5 5708.5 5687.5 5664.5 5651.5 5565.5 5552.0 5522.5 5511.0 5426.0 4-0CT-1996 14:23 PAGE: 15 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5328.5 5319.0 5242.0 5231 . 0 5214.0 5203.0 5141 . 5 5130.5 5071 . 5 5060.5 5022.0 5010.0 4926.5 4916.5 4908.5 4898.0 4870.5 4861.5 4846.0 4836.5 4813 . 0 4802.0 4727.5 4715.5 4704.5 4692.5 4691 . 0 4680.0 4657.5 4649.0 4644.0 4635.0 4554.5 4545.5 4552.5 4542.5 4542.0 4531 . 0 4529.5 4521.0 4520.5 4511 . 5 451 O. 5 4501 . 0 4480.5 4469.5 4445.0 4435.0 4382.0 4372.5 4335.0 4325 . 5 4309.5 4299.0 4276.0 4265 . 5 4264.0 4252.5 4252.0 4240. 5 4209.5 4198.5 4178.0 4167.5 4138.5 4128.0 4125.5 4115.0 4121 . 0 4111 . 5 4090.0 4082.0 4087.5 4077.5 4076.5 4067.0 4057.0 4048.5 4049.0 4039.0 4009.5 4001 . 5 3992.5 3983 . 0 3987.5 3977.5 3952.0 3941.0 3938.5 3926.0 3923.5 391 O. 5 3915.0 3900.0 3870.5 3857.5 3810.5 3800.5 3790.0 3778.0 3739.5 3728.5 3725.5 3714.5 3702.0 3691 . 0 3648.0 3637.0 3608.5 3597.0 4-0CT-1996 14:23 PAGE: 16 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 17 3591.5 3580.0 3506.5 3495.0 3462.5 3451.0 3437.0 3426.0 3423.0 3413.0 100.0 90.0 $ REM_ARKS: This file contains the OH tools data logged into casing The data was depth shifted to Sperry MWD GR as the main log pass and then clipped to just contain the CH data. The data was acquired using the Platform Express plus BHC tool string and curves were renamed as required. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECOPcD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 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 NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUPIB SAMP EL~ CODE (HEX) DEPT FT 666675 O0 000 O0 0 2 1 1 4 68 0000000000 GR AIT GAPI 666675 O0 000 O0 0 2 1 1 4 68 0000000000 TENS AIT LB 666675 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 666675 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 666675 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU 666675 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 18 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) NPOR CNT PU 666675 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNT PU 666675 O0 000 O0 0 2 1 1 4 68 0000000000 DT BCS US/F 666675 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 3381.000 GR.AIT 64.333 TENS.AIT 2992.000 CNTC. CNT CFTC. CNT 405.881 NPHI. CNT 45.163 NPOR.CNT 42.274 CPHI. CNT DT. BCS 138.400 DEPT. 3290.000 GR.AIT 49.743 TENS.AIT 2899.000 CNTC. CNT CFTC. CNT 386.229 NPHI. CNT 46.592 NPOR.CNT 41.058 CPHI.CNT DT. BCS 63.500 1477.076 43.703 1296.672 40.473 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUFIBER: 1 TOOL STRING NUMBER: 1 LIS Tape Verification Listing Schlumberger Al'aska Computing Center 4-0CT-1996 14:23 PAGE: 19 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~94ARY VENDOR TOOL CODE START DEPTH AIT 13074.0 BCS 13031.0 SDN 13055.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIFiE CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BHC SONIC PEX PEX CARTRIDGE PEX PEX SONDE PEX PEX DETECTOR AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: STOP DEPTH .......... 3380.0 3380.0 3380.0 23-SEP-96 8B04 1030 22-SEP-96 300 13-SEP-96 13080.0 13080.0 3300.0 13072.0 1800.0 TOOL NUMBER SDT-C HRCC-B 847 HRMS-B 840 HRGD 840 AIT-H 8.500 3385.0 3380.0 KCL W/BARITE 12. O0 54.0 9.0 204.0 O. 364 74.0 O. 354 73.0 0.523 70.0 THERMAL SANDSTONE LIS Tape Verification Listing _Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 2O MATRIX DENSITY: HOLE CORRECTION (IN): 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: USED IDW AS MAIN DEPTH CONTROL PULLED 10,000 LBS TENSION AT 12720 BARITE MUD PRESENT IN BOTTOM 800 FT ~D OF WELL IDW CORRECTIONS: Wl=+l.2, W2=+0.7 ********************************************** ***THIS DATA IS CALLED TOOL STRING 1 DUE TO MULTIPLE SAMPLE RATES ACQUIRED AS RAW DATA*** ********************************************** $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT I1 66 25 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 666675 O0 000 O0 0 3 1 1 4 68 0000000000 SP AIT MV 666675 O0 000 O0 0 3 1 1 4 68 0000000000 TENS AIT LB 666675 O0 000 O0 0 3 1 1 4 68 0000000000 GR AIT GAPI 666675 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CArT CPS 666675 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNT CPS 666675 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 21 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP EL~ CODE (HEX) NPHI CNT PU 666675 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR CNT PU 666675 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNT PU 666675 O0 000 O0 0 3 1 1 4 68 0000000000 DT BCS US/F 666675 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13100.000 SP.AIT 0.000 TENS.AIT 5789.000 GR.AIT CNTC. CNT 1751.830 CFTC.CNT 566.204 NPHI.CNT 34.887 NPOR.CNT CPHI.CNT 35.713 DT. BCS 90.500 DEPT. 13000.000 SP.AIT 0.000 TENS.AIT 7631.000 GR.AIT CNTC. CNT 1810.405 CFTC. CNT 576.354 NPHI.CNT 34.523 NPOR.CNT CPHI.CNT 36.800 DT. BCS 88.900 DEPT. 12000.000 SP.AIT 0.000 TENS.AIT 6820.000 GR.AIT CNTC. CNT 3341.670 CFTC. CNT 1648.984 NPHI.CNT 20.387 NPOR.CNT CPHI.CNT 19.990 DT. BCS 78.100 DEPT. 11000.000 SP.AIT 0.000 TENS.AIT 6477.000 GR,AIT CNTC. CNT 2149.406 CFTC. CNT 807.479 NPHI.CNT 34.918 NPOR.CNT CPHI.CNT 29.577 DT. BCS 90.000 DEPT. 10000.000 SP.AIT 0.000 TENS.AIT 6057.000 GR.AIT CNTC. CNT 1966.586 CFTC. CNT 700.747 NPHI.CNT 32.761 NPOR.CNT CPHI.CNT 31.379 DT. BCS 94.700 DEPT. 9000.000 SP.AIT 0.000 TENS.AIT 5467.000 GR.AIT CNTC. CNT 2124.458 CFTC. CNT 719.993 NPHI.CNT 34.848 NPOR.CNT CPHI. CNT 34.051 DT.BCS 90.900 DEPT. 8000.000 SP.AIT 0.000 TENS.AIT 4856.000 GR.AIT CNTC. CNT 2191.489 CFTC. CNT 849.669 NPHI.CNT 34.184 NPOR,CNT CPHI. CNT 28.310 DT. BCS 103.000 DEPT. 7000.000 SP.AIT 0.000 TENS.AIT 4727.000 GR.AIT CNTC. CNT 1862.537 CFTC. CNT 589.706 NPHI.CNT 42.027 NPOR.CNT CPHI. CNT 37.314 DT. BCS 100.800 DEPT. 6000.000 SP.AIT 0.000 TENS.AIT 4098.000 GR.AIT CNTC. CNT 1839.806 CFTC. CNT 550.087 NPHI.CNT 44.220 NPOR.CNT CPHI. CNT 40.270 DT.BCS 113.900 DEPT. 5000.000 SP.AIT 0.000 TENS.AIT 3660.000 GR.AIT CNTC. CNT 1727.432 CFTC. CNT 556.531 NPHI.CNT 45.075 NPOR.CNT CPHI. CNT 36.455 DT. BCS 114.200 106.950 33.185 111.960 35.760 100.715 19.988 104.337 30.325 104. 286 31. 482 103.290 33.045 58.826 25.456 67.597 32.860 67.199 36.294 85.018 35,560 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 22 DEPT. 4000.000 SP.AIT CNTC. CNT 1580.819 CFTC. CNT CPHI. CNT 40.222 DT. BCS DEPT. 3391.000 SP.AIT CNTC. CNT 1477.076 CFTC. CNT CPHI. CNT 43.703 DT. BCS 0.000 TENS.AIT 467.417 NPHI.CNT 133.500 0.000 TENS.AIT 405.881 NPHI.CNT 138.400 3348.000 GR.AIT 43.461 NPOR.CNT 2992.000 GR.AIT 45.163 NPOR.CNT 84.485 40.335 64.333 42.274 ** END OF DATA ** **** FILE TRAILER **** FILE NAPIE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUFiBER : TOOL STRING NUMBER: PASS Nr3?4~ER: DEPTH INCREM~a%~I : FILE S~Y FILE HEADER FILE NUMBER 4 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 2 1 0.2500 VENDOR TOOL CODE START DEPTH AIT 13074.0 BCS 13031.0 SDN 13055.0 $ LOG HEADER DATA STOP DEPTH .......... 3380.0 3380.0 3380.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 23 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 23-SEP-96 8B04 1030 22-SEP-96 300 13-SEP-96 13080.0 13080.0 3300.0 13072.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BHC SONIC PEX PEX CARTRIDGE PEX PEX SONDE PEX PEX DETECTOR AIT ARRAY INDUCTION $ TOOL NUMBER SDT-C HRCC-B 847 HRMS-B 840 HRGD 840 AIT-H BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 3385.0 3380.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (Otff4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : KCL W/BARITE 12. O0 54.0 9.0 204.0 0.364 74.0 O. 354 73.0 0.523 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 USED IDW AS MAIN DEPTH CONTROL PULLED 10,000 LBS TENSION AT 12720 BARITE MUD PRESENT IN BOTTOM 800 FT MD OF WELL IDW CORRECTIONS: Wi=+l.2, W2=+O. 7 ********************************************** ***THIS DATA IS CALLED TOOL STRING 2 DUE TO MULTIPLE SAMPLE RATES ACQUIRED AS RAW DATA*** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 24 ********************************************** $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 42 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 666675 O0 000 O0 0 4 1 1 4 68 0000000000 AHT1 AIT OH~4 666675 O0 000 O0 0 4 1 1 4 68 0000000000 AHT2 AIT OH~4 666675 O0 000 O0 0 4 1 1 4 68 0000000000 AHT3 AIT 0I{~4 666675 O0 000 O0 0 4 1 1 4 68 0000000000 AHT6 AIT 0I~4~I666675 O0 000 O0 0 4 1 1 4 68 0000000000 AHT9 AIT Ot~V~4 666675 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 13100.000 AHT1.AIT 1.076 AHT6.AIT 3.033 AHT9.AIT 3.019 DEPT. 13000.000 AHT1.AIT 3.599 AHT6.AIT 3.080 AHTg.AIT 2.880 AHT2. AIT 2. 690 AHT3. AIT AHT2.AIT 3. 178 AHT3 .AIT 2. 748 3.086 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 25 DEPT. 12000. 000 AHT1 .AIT AHT6.AIT 6. 091 AHT9.AIT DEPT. 11000. 000 AHT1 .AIT AHT6.AIT 2. 491 AHTg. AIT DEPT. 10000. 000 AHT1 .AIT AHT6.AIT 3. 185 AHT9.AIT DEPT. 9000. 000 AHT1 .AIT AHT6.AIT 5. 396 AHTg.AIT DEPT. 8000.000 AHT1.AIT AHT6.AIT 2.039 AHT9.AIT DEPT. 7000.000 AHT1.AIT AHT6.AIT 2.472 AHT9.AIT DEPT. 6000.000 AHT1.AIT AHT6.AIT 1.937 AHT9.AIT DEPT. 5000.000 AHT1.AIT AHT6.AIT 3.918 AHTg.AIT DEPT. 4000.000 AHT1.AIT AHT6.AIT 2.701 AHT9.AIT DEPT. 3391.000 AHT1.AIT AHT6.AIT 0.737 AHT9.AIT 6.899 5.571 2.341 2.332 3.109 2.989 2.536 5.068 1. 733 2. 063 1. 487 2. 360 1. 825 1. 877 2.168 3. 834 2.517 2. 740 1.127 0.741 AHT2. AIT AHT2. AIT AHT2 .AIT AHT2. AIT AHT2. AIT AHT2. AIT AHT2. AIT AHT2 .AIT AHT2. AIT AHT2. AIT 7. 324 AHT3. AIT 2. 604 AHT3. AIT 3. 575 AHT3. AIT 4.233 AHT3.AIT 2.104 AHT3 .AIT 2. 327 AHT3.AIT 2.079 AHT3.AIT 3. 726 AHT3.AIT 2.467 AHT3.AIT O. 686 AHT3 .AIT 6. 007 2.487 2. 815 4.451 2. 029 2. 447 2. 034 3. 871 2.555 1.099 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 26 FILE HEADER FILE NUMBER 5 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 3 PASS NUMBER: 1 DEPTH INC~: O. 1667 FILE SU~ff4ARY VENDOR TOOL CODE START DEPTH AIT 13074.0 BCS 13031.0 SDN 13055.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 3380.0 3380.0 3380.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... BHC BHC SONIC PEX PEX CARTRIDGE PEX PEX SONDE PEX PEX DETECTOR AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MErD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~I) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : 23-SEP-96 8B04 1030 22-SEP-96 300 13-SEP-96 13080.0 13080.0 3300.0 13072.0 1800.0 TOOL NUMBER ........... SDT-C HRCC-B 847 HRMS-B 840 HRGD 840 AIT-H 8.500 3385.0 3380.0 KCL W/BARITE 12. O0 54.0 9.0 204.0 0.364 74.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : O. 354 O. 523 73.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: USED IDW AS MAIN DEPTH CONTROL PULLED 10,000 LBS TENSION AT 12720 BARITE MUD PRESENT IN BOTTOM 800 FT ~4D OF WELL IDW CORRECTIONS: Wl=+l.2, W2=+0.7 ********************************************** ***THIS DATA IS CALLED TOOL STRING 3 DUE TO MULTIPLE SAMPLE RATES ACQUIRED AS RAW DATA*** ********************************************** $ LIS FORMAT DATA PAGE: 27 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 28 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 666675 O0 000 O0 0 5 1 1 4 68 0000000000 PIDRA SDN G/C3 666675 O0 000 O0 0 5 1 1 4 68 0000000000 PEF SDN 666675 O0 000 O0 0 5 1 1 4 68 0000000000 RHOB SDN G/C3 666675 O0 000 O0 0 5 1 1 4 68 0000000000 MSFL SDN 0~666675 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 13100.000 MSFL.SDN 1.617 DEPT. 13000.000 MSFL.SDN 0.939 DEPT. 12000.000 MSFL.SDN 7.534 DEPT. 11000.000 MSFL.SDN 1.448 DEPT. 10000.000 MSFL.SDN 1.327 DEPT. 9000.000 MSFL.SDN 1.474 DEPT. 8314.000 MSFL.SDN 2.501 t{DRA.SDN 0.270 PEF. SDN 0.800 RHOB.SDN HDRA.SDN 0.132 PEF. SDN 3.986 RHOB.SDN H~RA.SDN 0.001 PEF. SDN 2.992 RHOB.SDN RDRA.SDN 0.090 PEF. SDN 3.413 RHOB. SDN FiDRA.SDN 0.131 PEF.SDN 3.089 RHOB.SDN HDRA.SDN 0.105 PEF. SDN 2.742 RHOB.SDN HDRA.SDN 0.023 PEF. SDN 3.634 RHOB.SDN 2. 569 2.400 2.508 2.386 2.328 2.396 2. 282 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 29 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE S~Y FILE HEADER FILE NUM~ER 6 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 4 1 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... AIT 13074.0 3380.0 BCS 13031.0 3380.0 SDN 13055.0 3380.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TOBOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BHC SONIC PEX PEX CARTRIDGE PEX PEX SONDE PEX PEX DETECTOR AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 23-SEP-96 8B04 1030 22-SEP-96 300 13-SEP-96 13080.0 13080.0 3300.0 13072.0 1800.0 TOOL NUMBER ........... SDT-C HRCC-B 847 HRMS-B 840 HRGD 840 AIT-H 8.500 3385.0 r .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 3O LOGGERS CASING DEPTH (FT): 3380.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (FIT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : KCL W/BARITE 12. O0 54.0 9.0 204.0 0.364 74.0 0.354 73.0 0.523 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: USED IDW AS MAIN DEPTH CONTROL PULLED 10,000 LBS TENSION AT 12720 BARITE MUD PRESENT IN BOTTOM 800 FT MD OF WELL IDW CORRECTIONS: Wl=+l.2, W2=+O. 7 ********************************************** ***THIS DATA IS CALLED TOOL STRING 4 DUE TO MULTIPLE SAMPLE RATES ACQUIRED AS RAW DATA*** ********************************************** $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 31 TYPE REPR CODE VALUE 11 66 128 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 666675 O0 000 O0 0 6 1 1 4 68 0000000000 CALI SDN IN 666675 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 13100.000 CALI.SDN 9.311 DEPT. 13000.000 CALI.SDN 8.835 DEPT. 12000.000 CALI.SDN 8.313 DEPT. 11000.000 CALI.SDN 7.937 DEPT. 10000.000 CALI.SDN 9.094 DEPT. 9000.000 CALI.SDN 7.786 DEPT. 8314.000 CALI.SDN 7.831 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 32 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREM~2Fr : FILE SUMFLARY FILE HEADER FILE NUM~ER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13074.0 12200.0 BCS 13031.0 12180.0 SDN 13055.0 12200.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VEJVDOR TOOL CODE TOOL TYPE ......................... BHC BHC SONIC PEX PEX CARTRIDGE PEX PEX SONDE PEX PEX DETECTOR AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 23-SEP-96 8B03 1030 22-SEP-96 300 13-SEP-96 13080.0 13080.0 3300.0 13072.0 1800.0 TOOL NUMBER SDT-C HRCC-B 847 HRMS-B 840 HRGD 840 AIT-H 8.500 3385.0 3380.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 33 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4~) AT TEMPERATURE (DEGF): MUD AT f~EASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : KCL W/BARITE 12. O0 54.0 9.0 204.0 O. 364 74.0 O. 354 73.0 0.523 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: USED IDW AS MAIN DEPTH CONTROL PULLED 10,000 LBS TENSION AT 12720 BARITE MUD PRESENT IN BOTTOM 800 FT AID OF WELL IDW CORRECTIONS: Wl=+l.2, W2=+0.7 ********************************************** ***THIS DATA IS CALLED TOOL STRING 1 DUE TO MULTIPLE SAMPLE RATES ACQUIRED AS RAW DATA*** ********************************************** $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 34 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SBRV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 666675 O0 000 O0 0 7 1 1 4 68 0000000000 SP AIT MV 666675 O0 000 O0 0 7 1 1 4 68 0000000000 TENS AIT LB 666675 O0 000 O0 0 7 1 1 4 68 0000000000 GR AIT GAPI 666675 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC CNT CPS 666675 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC CNT CPS 666675 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI CNT PU 666675 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR CNT PU 666675 O0 000 O0 0 7 1 1 4 68 0000000000 CPHI CArT PU 666675 O0 000 O0 0 7 1 1 4 68 0000000000 DT BCS US/F 666675 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 13080.000 SP.AIT 0.000 TENS.AIT 4869.000 GR.AIT CNTC. CNT 1712.930 CFTC. CNT 536.809 NPHI.CNT 34.727 NPOR.CNT CPHI.CNT 37.255 DT. BCS 89.700 DEPT. 13000.000 SP.AIT 0.000 TENS.AIT 7696.000 GR.AIT CNTC. CNT 1794.566 CFTC. CNT 612.625 NPHI.CNT 33.795 NPOR.CNT CPHI.CNT 32.682 DT. BCS 89.600 DEPT. 12170.000 SP.AIT 0.000 TENS.AIT 6724.000 GR.AIT CNTC. CNT 1667.885 CFTC. CNT 441.976 NPHI.CNT 54.580 NPOR.CNT CPHI.CNT 47.202 DT. BCS 89.100 119.104 36.440 100. 382 33. 423 81.068 52.340 ** EiVD OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 35 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION · O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCRE~!ENT: FILE SUFk~ARY FILE HEADER FILE NUMBER 8 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 2 1 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13074.0 12200.0 BCS 13031.0 12180.0 SDN 13055.0 12200.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BHC SONIC PEX PEXCARTRIDGE 23-SEP-96 8B03 1030 22-SEP-96 300 13-SEP-96 13080.0 13080.0 3300.0 13072.0 1800.0 TOOL NUMBER SDT-C HRCC-B 847 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 36 PEX PEX SONDE HRMS-B 840 PEX PEX DETECTOR HRGD 840 AIT ARRAY INDUCTION AIT-H $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 8.500 3385.0 3380.0 KCL W/BARITE 12. O0 54.0 9.0 204.0 O. 364 74.0 0.354 73.0 0.523 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: USED IDW AS MAIN DEPTH CONTROL PULLED i0,000 LBS TENSION AT 12720 BARITE MUD PRESENT IN BOTTOM 800 FT FiD OF WELL IDW CORRECTIONS: Wl=+l.2, W2=+0.7 ********************************************** ***THIS DATA IS CALLED TOOL STRING 2 DUE TO MULTIPLE SAMPLE RATES ACQUIRED AS RAW DATA*** ********************************************** $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 37 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CMAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 666675 O0 000 O0 0 8 1 1 4 68 0000000000 AHT1 AIT 0H~666675 O0 000 O0 0 8 1 1 4 68 0000000000 AHT2 AIT OH~M666675 O0 000 O0 0 8 1 1 4 68 0000000000 AHT3 AIT 0H~666675 O0 000 O0 0 8 1 1 4 68 0000000000 AHT6 AIT 0H~666675 O0 000 O0 0 8 1 1 4 68 0000000000 AHT9 AIT 0H~666675 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 13080.000 AHT1.AIT 1.230 AHT2.AIT AHT6.AIT 3.136 AHT9.AIT 2.806 DEPT. 13000.000 AHT1.AIT 3.325 AHT2.AIT AHT6.AIT 3.006 AHT9.AIT 2.883 DEPT. 12170.000 AHT1.AIT 4.740 AHT2.AIT AHT6.AIT 16.199 AHT9.AIT 15.783 2.734 AHT3.AIT 3. 645 AHT3. AIT 12.322 AHT3.AIT 2. 643 3. 049 12.086 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 38 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE · 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE RUN NUAIBER : TOOL STRING ~ER : PASS NUMBER: DEPTH INCREMENT: FILE SUM~L&RY FILE HEADER FILE NUMBER 9 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 3 1 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13074.0 12200.0 BCS 13031.0 12180.0 SDN 13055.0 12200.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: ! TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BHC SONIC PEX PEX CARTRIDGE 23-SEP-96 8B03 1030 22-SEP-96 300 13-SEP-96 13080.0 13080.0 3300.0 13072.0 1800.0 TOOL NUMBER ........... SDT-C HRCC-B 847 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 39 PEX PEX SONDE PEX PEX DETECTOR AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) '. DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MF~ASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): HRMS-B 840 HRGD 840 AIT-H 8.500 3385.0 3380.0 KCL W/BARITE 12. O0 54.0 9.0 204.0 O. 364 74.0 O. 354 73.0 0.523 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: USED IDW AS MAIN DEPTH CONTROL PULLED 10,000 LBS TENSION AT 12720 BARITE MUD PRESENT IN BOTTOM 800 FT FiD OF WELL IDW CORRECTIONS: Wl=+l.2, W2=+0.7 ********************************************** ***THIS DATA IS CALLED TOOL STRING 3 DUE TO MULTIPLE SAMPLE RATES ACQUIRED AS RAW DATA*** ********************************************** $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 4O ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 666675 O0 000 O0 0 9 i 1 4 68 0000000000 HDRA SDN G/C3 666675 O0 000 O0 0 9 1 1 4 68 0000000000 PEF SDN 666675 O0 000 O0 0 9 1 1 4 68 0000000000 RHOB SDN G/C3 666675 O0 000 O0 0 9 1 1 4 68 0000000000 MSFL SDN 0H~666675 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 13080.000 MSFL.SDN 0.261 DEPT. 13000.000 MSFL.SDN 0.930 DEPT. 12170.000 MSFL.SDN 0.497 HDRA.SDN 0.022 PEF. SDN 10.000 RHOB. SDN HDRA.SDN 0.084 PEF. SDN 8.859 RHOB.SDN RDRA.SDN -0.096 PEF.SDN 10.000 RHOB.SDN 1. 950 2.340 2. 363 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 41 **** FILE TRAILER **** FILE NA~E : EDIT .009 SERVICE · FLIC VERSION : 0 O1 CO 1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT . O10 SERVICE · FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUFfl~ER : DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NU~BER 10 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 4 1 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 13074.0 12200.0 BCS 13031.0 12180.0 SDN 13055.0 12200.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BHC SONIC PEX PEX CARTRIDGE 23-SEP-96 8B03 1030 22-SEP-96 300 13-SEP-96 13080.0 13080.0 3300.0 13072.0 1800.O TOOL NUMBER ........... SDT-C HRCC-B 847 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 42 PEX PEX SONDE PEX PEX DETECTOR AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE '. MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHIO,) AT TEMPERATURE (DEGF) : MUD AT F~ASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 REM3LmJfS: USED IDW AS MAIN DEPTH CONTROL PULLED 10,000 LBS TENSION AT 12720 BARITE MUD PRESENT IN BOTTOM 800 FT f4D OF WELL IDW CORRECTIONS: Wl=+l.2, W2=+O. 7 ********************************************** ***THIS DATA IS CALLED TOOL STRING 4 DUE TO MULTIPLE SAMPLE RATES ACQUIRED AS RAW DATA*** ********************************************** $ LIS FORMAT DATA HRMS-B 840 HRGD 840 AIT-H 8.500 3385.0 3380.0 KCL W/BARITE 12.00 54.0 9.0 204.0 O. 364 74.0 O. 354 73.0 0.523 70.0 TOOL STANDOFF (IN): 1.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 43 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAMiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) DEPT FT 666675 O0 000 O0 0 10 1 1 4 68 0000000000 CALI SDN IN 666675 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 13080.000 CALI.SDN 9.299 DEPT. 13000.000 CALI.SDN 9.931 DEPT. 12170.000 CALI.SDN 6.799 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 44 **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 11 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREFIF2TT: 0.5000 FILE SUF~/zARY VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 3380.0 3279.0 BCS 3380.0 3279.0 SDN 3380.0 3279.0 $ LOG HEADER DATA DATE LOGGED: 23-SEP-96 SOFTWARE VERSION: 8B04 TIFfl~ CIRCULATION ENDED: 1030 22-SEP-96 TII4~LOGGER ON BOTTOM: 300 13-SEP-96 TDDRILLER (FT): 13080.0 TD LOGGER(FT): 13080.0 TOP LOG INTERVAL (FT): 3300.0 BOTTOM LOG INTERVAL (FT): 13072.0 LOGGING SPEED (FPHR): 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BHC BHC SONIC SDT-C PEX PEX CARTRIDGE HRCC-B 847 PEX PEX SONDE HRMS-B 840 PEX PEX DETECTOR HRGD 840 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 45 AIT $ ARRAY INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : AIT-H 8.500 3385.0 3380.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) MUD AT M~ASLrRED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : KCL W/BARITE 12. O0 54.0 9.0 204.0 0.364 74.0 O. 354 73.0 O. 523 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: USED IDW AS MAIN DEPTH CONTROL PULLED 10,000 LBS TENSION AT 12720 BARITE MUD PRESENT IN BOTTOM 800 FT 14D OF WELL IDW CORRECTIONS: Wl=+l.2, W2=+0.7 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE.. 46 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 28 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELE~ CODE (HEX) DEPT FT 666675 O0 000 O0 0 11 1 1 4 68 0000000000 GR AIT GAPI 666675 O0 000 O0 0 11 1 1 4 68 0000000000 TENS AIT LB 666675 O0 000 O0 0 11 1 1 4 68 0000000000 CNTC CNT CPS 666675 O0 000 O0 0 11 1 1 4 68 0000000000 CFTC CNT CPS 666675 O0 000 O0 0 11 1 1 4 68 0000000000 NPHI CNT PU 666675 O0 000 O0 0 11 1 1 4 68 0000000000 NPOR CNT PU 666675 O0 000 O0 0 11 1 1 4 68 0000000000 CPHI CNT PU 666675 O0 000 O0 0 11 1 1 4 68 0000000000 DT BCS US/F 666675 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 3391.000 GR.AIT CFTC. CNT 405.881 NPHI. CNT DT. BCS 138.400 DEPT. 3300. 000 GR. AIT CFTC. CNT 386. 229 NPHI. CNT DT. BCS 63. 500 64.333 TENS.AIT 2992.000 CNTC. CNT 1477.076 45.163 NPOR.CNT 42.274 CPHI.CNT 43.703 49.743 TENS.AIT 2899.000 CNTC. CNT 1296.672 46.592 NPOR.CNT 41.058 CPHI.CNT 40.473 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 96/10/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-0CT-1996 14:23 PAGE: 47 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 96/10/ 4 ORIGIN . FLIC TAPE NAME : 96273 CONTINUATION # : 1 PREVIOUS TAPE : COMP~_2~T : ARCO ALASKA INC, P1-24, PT. MACINTYRE, API #50-029-22703-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/10/ 4 ORIGIN : FLIC REEL NAME : 96273 CONTINUATION # : PREVIOUS REEL : COMFiEIFf : ARCO ALASKA INC, P1-24, PT. MACINTYRE, API #50-029-22703-00
