The URL can be used to link to this page

Home My WebLink About201-071STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS e Q i% ` ,.p LZ U 'ta`9 JUL 'l 2 2ri:j 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing Change ApproWd'Projram ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CO261 B WHIPSTOCK El 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Stratigraphic❑ Exploratory ❑ Service ❑ 201-071 3. Address: P. O. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-029-23010-00 7. Property Designation (Lease Number): s. Well Name and Number: ADL 25660, ADL 25667 KRU 1 J-10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,845 feet Plugs measured None feet true vertical 6,326 feet Junk measured 9126, 10326 feet Effective Depth measured 10,843 feet Packer measured 9,985 feet true vertical 6,324 feet true vertical 5,798 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 85 feet 20 120' MD 120' TVD SURFACE 6,911 feet 9 5/8 " 6,945' MD 3995' TVD PRODUCTION 10,199 feet 7 10,231' MD 5944' TVD LINER 876 feet 4 1/2" 10,843' MD 6325' TVD Perforation depth: Measured depth: 10446-10466.10658-10678 feet True vertical depth: 6073-6085. 6205-6218 feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 9,979' MD 5,794' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- BAKER ZXP LINER TOP PACKER 9,985' MD 5,798' TVD SSSV - NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - - - - Subsequent to operation: SHUT-IN - - - - 14. Attachments (required per 20 MC 25.070, 25.071. s 25.2821) 15. Well Class after work: Daily Report of Well Operations GI Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319.253 Authorized Name: �A L �+. L Contact Name: Ryan McLaughlin J contact Email: Ryan.McLaughlin@cop.com Authorized Title: Staff CTD Engineer Authorized Signature: q Contact Phone: (907) 265-6471 Date: 1 Form 10-404 Revised 4/2017 1/7-1- gl'tlt9 Submit Original Only 1,4 jll, RBDMS�''r' JUL 2 3 2019 ConocoPhillips Alaska Inc. KUP PROD WELLNAME 1J-10 WELLBORE 1J-10 +6.1a.ymnmslo ulnam Last Tag Veo-tl Wwmauc (enuan An..Wn Dap mel I End Dah Ynnippre IaaI MaE By Last Tag: RKB 103480 32])201] 17-10 pproven IahwER: a.e Last Rev Reason Annobron I End Gam I Yonsiore Lana<MM ey Rev Reason'. Set Whipstock 20/2019 1J-10 Tama _._. ..... ..... Casing Strings Casing Dewnption OGIIN flion) Top gone) .1 Gape(1 bet Denlh Map)... YllM1en(I... Grade Top Thread CONDUCTOR 20 19.12 35.0 1200. 120.0 91.50 H40 WELDED -170- Casing DeasrlWon IG lin) Tap IKKB) the Depth IRKBI Be111eph ITUD1...IMI ll...Ortle Top Thread SURFACE 9516 883 34.5 6,945.3 3,995.4 40.00 L-80 BTC con0'ucion;aalzdo Caehg Oeenlpion 00(in, ID (lnl To as) Set Depi MKB) antl DepN IVi'" vv`Pn I...... Tp Tlneq PRODUCTION ] 6.28 31.7 10,230.8 5,9444 26.00 LtK) BTC -MOD NIPPLE 900 taslnst Description OD (In) 1.,in ) Tp (ryKel SMOepsperan anal GepM fN,-'evm p-haade Top Th,. LINER 4112 3.96 9,9672 10,843.0 6,324] 12.60 L,80 NSCT Liner Details Nitride) NP(TVm MKBI Tophi Ihm DH Com fin) GAS UFi', S.'L1.8 9,9672 5,]8].0 5374 TIEBACK BAKER PACKER B TIE -BACK SLEEVE 4438 9,985.2 5,]9].8 5367 PACKER BAKER ZXP LINER TOP PACKER 4438 -53% 9,989. 5,800.0 HAN ER BAKER LINER HANGER 4.500 10,32)7 6,0017 53.86 NIPPLE AM OD'NIPPLE - DRILLED OUT . T 3830 GAS UFT'. BBILT DURING ATTEMPT TO PULL FISH 2nW006 WORKOVER 165 7 6,1185 5181 NIPPLE OTIS'X I LE w/No Go, 3. K BORE, 3.725 3,725" prank Tubing Strings SURFACE', ave6.80.9.3� Tubing D.1-ptlon Shirg Ma.. 10 (Int Top 111KB) 9et0epin(X. SBt Oeplh(TV01 F. Iso MNg G,ade Top Connttl.on TUBING 6112 3.96 29.6 9,991) 5,801.5 12.60 L-80 IS Completion Details dANLIFTB,R6] Top IN0) Topincl Nominal Top MKB) raps.) ('I Ihm ties Com aTin 29.6 29.6 Ot HANGER FMC GEN V TUBING HANGER 4.500 508.0 508.0 1.97 NIPPLE CAMCO DB -6 NIPPLE w/3875 TOPN GO PROFILE 3875 9,933.4 5,7670 5386 NIPPLE GAMQU DB NIPPLE M 3.812 PR - LIHILLED OUT TO 3,87 383 wan uFT; e,13z9 DURING ATTEMPT TO PULL FISH 2/812006 WORKOVER 9,978.7 5,]93.8 53.]0 LOCATOR BAKER GBH -22 LOCATOR 3.958 Fix,-wm3u z: B.IaTO 7979.9 5.796.5 53.69 SEALASSV BAKER SEAL ASSEMBLY wI MULESHOE 3958 Other In Hole (YYireline retrievable plugs, Valves, pumps, fish, etc.) Gas uFT: e,mzz ToPMKB) Top"of rant(.) Tapeta r) 06 Co. Run Gah 10 (1") 9,126.0 5,278.9 51.36 Fish - DAL= ASIAN Unit ON Liner bad L! .8', 8 Its"HD 511 5152019 3.363 242.2 string (21864),Triple Cron, Bushing (1.1262-718-X- Trem9 Motor (10 X62), O2 -W- REG x 2318" PAC, NIPPLE:9,e334 PDC Bit Duraforce XD (087) TOE TVD 5164. T, BOF TVD 5316.6, DAL of Fish = 2422 10,301.0 5,986.0 53.88 WINDOW -PBI WIOd"W ul m 1-10, m ,M.drilled a 1J-10L11PB1 and left a motor, bit, and 112 joint of liner on 26]2019 0.000 It it boII LMMR; 9519.1 0. 60 6,0007 53.88 FISH HERE GUN PERE GUN DROPPED ,T P 311712008 10,532', LENGTH 344', MAX OD 3.63` WORKED TO sEuaesY: e.ev.a RETRIEVE THIRD WWI. WELL SHUT IN B FREEZE PROTECTED. 38" BAT SUB LEFT ON TOP OF E{INE TOOL 101252004: Fish Pulled up 510,312 CTMD 57200.5: Tagged Fish @ 10339' RKB 11192008 Tagged Fish @ 1030TSLM 2152008 WORKOVER TO PULL FISH -ONLY PUSHED IT DOWNHOLE FROM 10312TO 104M PRODUCTON: 31 ]-102308 Perforations 8t Slots Wallaki 1:10,3010 and TAP(TVD) BM IND) IshdslR Tp MKO) Bion MKB) (ME) MB) Unkski Date ) Type Com 0 10046 10,488.0 6.012.7 Q084.9 C-3. 1J-10 ]11912001 60 APERF 3 8" PSD PJ pings, 60° ph J 10,858.0 10,6]80 6,20 50 6,2178 A5. 1J-10 1611212301 6.0 1 WERE 25"H DBH BDP Frac Summary ataRDaM FININNnl0pq ses) progNnl In Formatwn (Ib) 51W= Sq1 Sb,t Oats Top Deph"""N ns MN.) 4nklaFluMSyster, voicaPn(bbl) ,Auun,yMM) 1 5152001 10,6580 10,6]8.0 1 Mandrel Inserts IN j I an LILINER:10.J2i.&10319,0 pa Tp pvD) Valor I- PatNm TRO Run N Top (.a.) dealB ) Maya .1 0pon) mv Tope Type ".I (NIf Run Dale Lom 1,723.8 2,558.4 CAMCO KB -2 1 GAS LIFT GLV BK 0.168 1.2460 11212019 4:30 2 6,3117 3,723. CO KBG-2 1 GAS LIFT OV BK 0250 0.0 11 019 ]'30 ARERF. 1050-10.0 0- 3 8,0682 4,6270 OAMCO K 1 GAS LIFT DMY BK 0000 0.0 3 9101) 500 4 9,132.6 5,283.0 AMCO KB -2 1 GAS LIFT DMY BK 0.000 0.0 IW5120101 1495 5 9,882.2 SD6.8 JUAMCQ KBG-2 1 1 GAS LIFT IDMY IBK I 0.000 I 0.0 121912U14 1700 Notes: General a Safety Erie Gam Anndnnon 2/52008 NOTE: WORKOVER DONE TO PULL FI H, MILLED L : UN U CESSF HED FISH DOWNHOLE plan' 10,euafaemo FRAC: tape. 3101019 i NOTE: Leha mot or, bit, and ha8ao l of liner on bosom in 1J-1 Wl PB1 i in UNntfies -108Aa.0- 1J-10 Proposed CTD Schematic 0" 91.58 H40 ghee Q 120'MD 94178" 408 L40 shoe Q 6945' MD T 268 L40 shoe @10201'MO KOP Q 10,283' MD -sem peels 10448'-10466' MD 1/2" 88 12. L -a0 hoe Q 10,943' MD 3-1/2" Cameo DB4i nipple @ 508' MO (3.875" min ID) d -W 12.Bk IBT EOE BN Tubing to surfed, 4-1/2" Camco gas lift mandrels @ 41/2' Carried DB landing nipple Q 9933' MD (milled 3.87" min ID) Baker 4 -In' OSH-22 Lodetm Baker Seal assembly Q 99a0' MD (3.958' ID) Baker dealer& Tei Shaw Baker ZXP Liner Top Packer Q 9985' MD (4.438' ID) Baker Liner Hanger Camilo D -Nipple Q 10,328' MD (ended 3.97" ID) FISH Q -10,400' MDPad Gun Ote XN-Nipple Q 10,521' MD (mieed 3.725" ID) Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tune EM Tune our (hr) Phase Op Code Activity Code Time P -T -X Operation stun Depth (W13) End Depm(WS) 2/10/2019 2110/2019 2.00 MIRU MOVE DMOB P Continue RDMO from 35-08, load out 0.0 0.0 17:00 19:00 DTH trucks, secure rig landings and stairs, secure cellar, Peak arrives on site at 19:00 hrs 2/10/2019 2110/2019 4.00 MIRU MOVE DMOB P Load up shop & 1/2 -Way house, hold 0.0 0.0 19:00 23:00 PJSM with rig / Peak team. Pull o8 well. Install Jeeps. Rig down cellar lanes 2/10/2019 2/11/2019 1.00 MIRU MOVE MOB P Move from 3S -Pad to 1J -Pad (25.4 0.0 0.0 23:00 00:00 miles) 2/11/2019 2/11/2019 4.35 MIRU MOVE MOB P Continue moving rig to 1J -Pad 0.0 0.0 00:00 04:21 2/11/2019 2/11/2019 5.40 MIRU MOVE MOB T Field went to phase 3 driving 0.0 0.0 04:21 09:45 conditions. park rig at KCS Y (15.4 mile), standby for weather, Phase condtions lifted, send grader and blower to 1 J -pad to confirm clear of snow. 2/11/2019 2/11/2019 4.25 MIRU MOVE MOB P Continue moving rig to 1J -Pad 0.0 0.0 09:45 14:00 1 (stopped at KOC for fuel) 2/11/2019 2/1112019 2.50 MIRU MOVE MOB P Arrive on 1J -Pad 14:00 hrs, drop off 0.0 0.0 14:00 16:30 jeeps, sub & pits spotted, mats laid (-50 min to lay mats for sub & pits) 2/11/2019 2111/2019 4.00 MIRU MOVE MOB P DTH on location rig up tiger tank and 0.0 0.0 16:30 20:30 hardline (air-test/good-test), Continue RU checklist, hook up PUTZ, hook up steam, drop stairs & landings, spot shop & half -way house 2/11/2019 2111/2019 1.00 MIRU MOVE MOB P Complete RU checklist, energize 0.0 0.0 20:30 21:30 Koomey, unlock injector & reel, begin MU tiger -tank hard-line, grease tree & tangos, grease Romeo & Bravo valves 2/11/2019 2/12/2019 2.50 MIRU WHDBOP NUND P Nipple up BOP, grease crew on 0.0 0.0 21:30 00:00 location, service tree valves. '" Note: Rig Accept 2/11/19 @ 21:30 pm 2/12/2019 2/1212019 0.60 MIRU WHDBOP NUND P Complete prep for BOP test 0.0 0.0 00:00 00:36 2/12/2019 2/12/2019 0.90 MIRU WHDBOP PRTS P PJSM, fluid pack, & shell test, good 0.0 0.0 00:36 01:30 2/12/2019 2/1212019 1.50 MIRU WHDBOP BOPE T Begin BOP lest, good test on test 1, 0.0 0.0 01:30 03:00 though continue to see pressure when bleeding off, observe gas through night cap, trouble shoot master & SSV, function SSV open and closed, re -fluid pack stack, taking to tiger tank, close swab to check for pressure build at tangos, good, carry on w/ test " 250 psi low / 3500 psi high (witness waived by Bob Noble ofAOGCC) 2/12/2019 2/12/2019 6.10 MIRU WHDBOP BOPE P Continue w/ BOP test, fail/pass on 0.0 0.0 03:00 09:06 test #13, draw -down test 2112/2019 2/1212019 1.00 MIRU WHDBOP BOPE P Flud pack coil, reverse circulate, test 0.0 0.0 09:06 10:06 inner reel valve 2/12/2019 2/12/2019 1.10 MIRU WHDBOP PRTS P Pop off injector, PT PDL's & tiger -tank 0.0 0.0 10:06 11:12 line 2/12/2019 2/12/2019 0.40 SLOT WELLPR OTHR P dearfloor 0.0 0.0 11:12 11:36 2/12/2019 2/12/2019 1.40 PROD1 RPEQPT PULD P PJSM, PD BHA#1 Coil -Trak w/ 0.0 43.0 11:36 13:00 nozzle, slide in cart, install checks, MU to coil, tag up, set counters Page 1/18 Report Printed: 7122/2019 . Operations Summary (with Timelog Depths) T,y f U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start -rime End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (flKB) End Depth (ftKB) 2/12/2019 2/12/2019 2.00 PROD1 RPEQPT TRIP P RIH w/ BHA #1 43.0 10,160.0 1300 1500 2/12/2019 2/12/2019 0.20 PROD? RPEQPT CLOG P Log formation for -5' correction 10,160.0 10,186.0 15:00 1512 2/12/2019 2/12/2019 0.30 PROM RPEQPT TRIP P Close EDC, PUW = 37K, continue 10,186.0 10,307.0 15:12 15:30 RIH, log K7 for -1' correction, tag TOWS at 10,307', PUW = 42K 2/12/2019 2/12/2019 0.70 PROD1 RPEQPT DISP P Continue flushing w/ seawater 10,307.0 10,280.0 15:30 16:12 2/12/2019 2/12/2019 1.20 PROD1 RPEQPT DISP P Obtain SBHP 10,295.0 10,295.0 16:12 1724 MID bit = 10,295', TVD sensor - 5974.7', annular= 2882 psi, EMW = 9.29 ppg Decision made to reduce KWF to 10.8 ppg for BHA swap (no formation open at this point) 2/12/2019 2/12/2019 2.60 PROD1 RPEQPT DISP P Squeeze 150K -SRV pill followed by 10,295.0 2,000.0 17:24 20:00 10.8 ppg KWF to surface Losses started @ 0.5 bpm increased to 1.5 bpm, and lost returns @ - 2000 feet. "Phase 1 @ 20:23 2/12/2019 2/12/2019 3.60 PROD? RPEQPT DISP T Additional KW fluid called out earlier, 2,000.0 2,000.0 20:00 2336 water truck needle for dilution of KW stuck on pad, Still Phase one. Roads & pads, extracted water truck, off loaded same. Built 9.5 ppg KW fluid. 2/12/2019 2/13/2019 0.40 PROM RPEQPT DISP P Online with 9.5 ppg NaBr to the coil, 2,000.0 2,000.0 23:36 0000 filling hole, note 39 bbl coil volume all 10.8 ppg, 49 bbls away started seeing returns, waited until 9.5 ppg returns at surface. 2/13/2019 2/13/2019 0.80 PROD1 RPEQPT DISP P Waited until 9.5 ppg at surface, 2,000.0 2,000.0 00:00 0048 brought fluid back inside. 10.45 ppg and heavier EMW yealds zero returns. Density out steering to drop, 9.5 ppg comming back. 2/13/2019 2/13/2019 0.40 PROD1 RPEQPT TRIP P Waited until 9.5 ppg at surface, 2,000.0 55.0 00:48 01:12 brought fluid back inside. 10.45 ppg and heavier EMW yields zero returns. POOH 2/13/2019 2/13/2019 0.70 PROD? RPEQPT PULD P LD BHA#1 over a dead well, on 55.0 0.0 01:12 01:54 vacuum, 2/13/2019 2/13/2019 1.00 PROD1 RPEQPT PULD P PU 4 joints of PH6, caped w nozzle 55.0 0.0 01:54 02:54 and 2XO's, Nozzle -0.66', XO's-0.69/0.73', joints 1,2,3,&4-31.38', 31.36', 31.53', and 32.81'. 2/13/2019 2/13/2019 0.70 PROD1 RPEQPT CTOP P Pull UQC, cut and boot E -line, stab 55.0 0.0 02:54 03:36 onto PH6, Pump up to 2.5 bpm, listen for wire moving and stop. Repeated ramp to 2.5 bpm 3 more times no noise associated with wire movement. 2/13/2019 2/13/2019 1.00 PROD? RPEQPT CTOP P Fill well to stump, flow check good, 55.0 0.0 03:36 04:36 unstab, pull wire, 132' retained, theoretical was 151'. Cut 8.5' of coil, cut a -line and reboot. BHA hand noticed flat spot on pipe, recut pipe and reboot a -line. 2/13/2019 2/13/2019 2.50 PROD1 RPEQPT CTOP P Instal BH coil connector, pull test, 55.0 0.0 04:36 07:06 I pressure test Page 2118 ReportPrinted: 7/22/2019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hr) Phase Op Cotla Adrvity Code Time P -T -X Operation Stan Depm (WS) End Depth(ftKB) 019 3/2019 0.50 PROD? RPEQPT CTOP P Pull 4 jnts PH -6, run nozzle & 1 jnt PH 0.0 0.0 07:06 07:06 0736 07 -6 in hole, stab on injector, prep to pump ball 2/13/2019 2/13/2019 0.70 PROD? RPEQPT CTOP P Drop ball, close & pressure up on IRV 0.0 0.0 07:36 08:18 to 3000 psi, open IRV, bring on pumps to 2.5 bpm, pump 1.5 coil volumes Order 50 sacks Poly Swell to rig 2/13/2019 2/13/2019 0.80 PROD1 RPEQPT CTOP P Pop off, LD PH -6 jnts, additional 32' of 0.0 0.0 08:18 09:06 slack pumped forward, retireved ball from nozzle, good test on a -line, cut e - line, epoxy & protect tag end 2/13/2019 2/13/2019 1.40 PROM WHPST PULD P PJSM, PU BHA#2 Window Assembly 0.0 245.0 09:06 10:30 2/13/2019 2/13/2019 0.90 PROD WHPST DISP T Displace coil to milling fluid 245.0 245.0 10:30 11:24 2/13/2019 2/13/2019 1.50 PROD1 WHPST WAIT T Wait on Poly Swell to rig 245.0 245.0 11:24 12:54 Establish pressures at various rate: 1 bpm: circ = 196 psi, WHIP = 182 psi 1.5 bpm: circ = 282psi WHIP = 305 psi 2 bpm: circ = 415 psi, WHIP = 396 psi 2.5 bpm: circ = 534 psi, WHP = 521 psi 2/13/2019 2/13/2019 1.10 PROD1 WHPST CIRC T Fresh water arrives at rig, PolySwell 245.0 245.0 12:54 1400 arrives at rig, atltl sacks of KCI, atltl sacks of PolySwell, mix 2/13/2019 2/13/2019 1.50 PROD1 WHPST CIRC T Begin pumping pill, low efficiency on 245.0 245.0 14:00 15:30 pump #2, unable to get pill pumping, pull screen on pump $#1, pumping pill @ 2.3 bpm, pill at top of per's (circ = 699, WHIP =731) 2/13/2019 2/13/2019 0.90 PROM WHPST CIRC 7 Squeeze away 10 bbl at .75 bpm, 245.0 245.0 15:30 16:24 shutdown pumps allow to swell for 45 min " 192 total pumped leaves 2 bbl above TOWS 2/13/2019 2/13/2019 0.60 PROD1 WHPST CIRC T Squeeze -5more bbl's @ .5 bpm, wait 245.0 245.0 16:24 1700 2/13/2019 2/13/2019 1.70 PROD1 WHPST CIRC T Squeeze away remaing poly swell, 245.0 245.0 17:00 1842 leaving 2 bbl above TOWS, wait 2/13/2019 2/13/2019 1.80 7R0D1 WHPST TRIP P RIH, min rate down the coil, targeting 245.0 10,247.4 18:42 2030 1 for 1 returns. Some poly swell back at the shaker causing choke issues, had to take -2 bbls outside, gas back 2/13/2019 2/13/2019 0.30 PROD? WHPST DLOG P Tie into Flag for +6.7'correction. PU Wt 10,247.4 10,312.0 20:30 2048 42 k lbs, RIF, dry tag TOW @ 10312.39' 2/13/2019 2/13/2019 1.10 PROD1 WHPST CIRC P Increase rate to 10,312.0 10,147.0 20:48 21:54 1 bpm down coil, full returns, WH 19 psi, CT 1819, 2 bpm down coil, 1.9 bpm out - WH 23 psi, CT 3091' 2.6 bpm in, 2.48 bpm out - WH 37 psi, CT 4150 psi, - Circulate bottoms up, large amount of poly swell returned to the shaker, over flowed, last +/-60 bbls to the cuttings pit. Returns cleared up post bottoms up. 2/13/2019 2/1312019 0.30 PROD1 WHPST TRIP P RBIH, 10,147.0 10,311.3 21:54 22:12 Page 3/18 Report Printed: 7/2 212 01 9 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hr) Phase Op Code Activity Cone Time PJA Operabon Start Depth (ftKB) End Depth (ftKB) 2/13/2019 2/14/2019 1.80 PROD1 WHPST WPST P Tag up w/ top of whipstock@ 10,311.3 10,313.5 22:12 00:00 10,311.3', Free spin CT 3750 psi, WH 178 psi, CT Wt 15 k lbs. Flag pipe at the horses head, start feeding tenths, - 1' /hr , with average 240 psi motor work. 2.61 bpm in 2.50 bpm out. 2/14/2019 2/14/2019 2.50 PROD1 WHPST WPST P Continue to mill exit window. 2.6 bpm 10,313.5 10,315.5 00:00 0230 in 2.5 bpm out, CT free spin 3750 psi, allowed CT wt to drop to 11 k lbs and CT pressure to climb to 4100 psi - 350 psi motor work. Parked for - 13 min, CT pressure fell off rapidly to 4000 psi and CT weight climbed to 12.6 k lb& reengaged the stick, mill ahead, WH 168 psi. 2/14/2019 2/14/2019 2.00 PROD1 WHPST WPST P Increase ROP to 1.2 ft/hr 2.6 bpm in, 10,315.5 10,318.0 02:30 04:30 2.54 bpm out, WH 170 psi, Ct 3800 psi, CT Wt 13.5 k lbs. 2/14/2019 2/14/20192.00 PROD1 WHPST WPST P Continue milling window, CWT= 10,318.0 10,320.2 04:30 06:30 12.5K, circ = 3811 2.6 bpm in, 2.53 bpm out 2/14/2019 2/14/2019 3.00 PROD1 WHPST WPST P Milling window, CWT =12.7K, circ, = 10,320.2 10,323.5 06:30 09:30 3828 psi, WHP = 172 psi, approx 10.07 ppg assuming 25 psi/1000' frictional pressure loss, mill exits bit - 10323.4' 2/14/2019 2/14/2019 1.30 PR0D1 WHPST WPST P Milling window, CWT = 13.1 K, circ = 10,323.5 10,325.0 09:30 10:48 3932 psi, WHP = 172 psi TOW = 10,311.3', BOW = 10,323.4' 2/14/2019 2/14/2019 2.40 PROD1 WHPST WPST P Begin pushing on it, milling rat -hole, 10,325.0 10,336.3 10:48 13:12 CWT = 10.7K, circ = 4115 psi, WHP = 172 psi, pump 5x5 sweeps 2/14/20192/14/2019 0.60 PROD1 WHPST REAM P Begin reaming, up -hole, PUW=37K 10,336.3 10,305.0 13:12 13:48 2/14/2019 2/14/2019 1.10 PROD1 WHPST DLOG P PUH to 10,305', trap 580 psi WHP 10,305.0 10,305.0 13:48 14:54 (EMW of -10.3 ppg), shut down pumps, allow WHP to drop, confer w/ town, decision made to kill well w/ 9.9 ppg KWF SBHP: WHIP = 252, EMW = 9.6 ppg, still dropping 2/14/2019 2/14/2019 2.00 PROD1 WHPST REAM P Continue reaming passes (3 up & 3 10,305.0 10,305.0 14:54 16:54 down total), dry drift window up & down clean, PUW = 40K 2/14/2019 2/14/2019 3.00 PROD? WHPST CTOP P Transfer and build 9.9 ppg KW fluid. 10,305.0 10,264.0 16:54 1954 2/14/2019 2/14/2019 0.70 PROD1 WHPST DISP P Start pumping KW to the coil 10,264.0 10,282.0 19:54 20:36 2114/2019 2/14/2019 1.60 PROD1 WHPST DISP P POOH laying in 9.87 ppg KW and 10,282.0 256.0 20:36 2212 painting flags Park @ 10142.43 and paint a red flag and again @ 10047.39' red and white candy cane. Continue to POOH. 2/14/2019 2/14/2019 1.20 PROD1 WHPST PULD P Park, flow check - good, slight vac. 256.0 256.0 22:12 2324 LD BHA #2 over a dead well, Retrieved and cut off an additional 60' of a -line. Meg wire - greater than 2000 ohms, good test. Skid cart. 2/14/2019 2/15/2019 0.60 PROD1 WHPST PULD P Fluid still in the stack. Lay tlown BHA 256.0 0.0 23:24 0000 1 I #2 Speed mill antl string reemer 3.80" go 3.79" Na go Page 4/18 Report Printed: 712212019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Tima End Time Dur (hd Phase Op Code Agivily Cotle Time P -T-X Operation Stan Depth (MB) End Depth (WB) 2/15/2019 2/15/2019 1.90 PROD? DRILL CIRC P Boot wire, install side jet nozzle, stab 0.0 0.0 00:00 01:54 on, turn coil over to milling fluid, shelter time to chink bomb bay doors, jetting the stack. 2/15/2019 2/15/2019 3.40 PROD? DRILL PULD P Pop off, PU BHA #3, drilling liner, 0.0 0.0 01:54 0518 2/15/2019 2/15/2019 2.50 PROD1 DRILL TRIP P RIH w/ BHA#3, correct +4.3'to pipe 0.0 10,230.0 05.18 07:48 flag, PUW = 39K 2/15/2019 2/15/2019 1.50 PROD1 DRILL DISP P Displace well to drilling fluid @ 1.5 10,230.0 10,230.0 07:48 09:18 bpm, bring rate up to 2.0 bpm, circ = 4144 psi, WHP = 19 psi (choke wide open), 2/15/2019 2/15/2019 0.20 PROM DRILL TRIP P Shut down pumps, RIH 20 fpm 10,230.0 10,336.0 09:18 09:30 through window, at 10,330' bring rate Idrilling up to 2 bpm, FS = 4105 psi, begin at 10,336' 2/15/2019 2/15/2019 1.50 PROD1 DRILL DRLG P Drilling, FS = 4105 psi, circ = 4277 psi, 10,336.0 10,356.0 09:30 11:00 CWT = 12.7K, 1.98 bpm in, 1.94 bpm out, choke open, stall at 10,343', PUW = 41 K, continue drilling ahead 2/15/2019 2/15/2019 1.80 PROM DRILL DRLG P Drilling, CWT = 9.85K, circ = 4207, 10,356.0 10,356.0 11:00 1248 -100% returns, begin stacking weight, though no increase in motor -work, stacking pipe in hole, PU to breakover, PUW = 43K, zero dp counter, again stacking weight @ 10,356', atempt again, PUW = 43K, again slack weight at 10,356', PUW =47K Confer w/ town, decision made to PU 10' (full rate), PUW = 50K, no success, make multiple attempts. Appear to be hitting bottoms though no motor -work 2/15/2019 2/15/2019 1.70 PROD1 DRILL CIRC T Thaw product, build 50 bbl Drilzone 10,356.0 10,356.0 12:48 1430 pill for potential bit balling 2/15/2019 2/15/2019 0.60 PR0D1 DRILL CIRC T Begin pumping 25 bbl Drilzone pill, 5 10,356.0 10,356.0 14:30 1506 bbl mud spacer, follow by 25 bbl Ito Drilzone, bit just off bottom, PU & go drilling 2/15/2019 2/15/2019 1.90 PROD1 DRILL DRLG T Drill ahead to 10,361'& stall, PUW = 10,356.0 10,380.0 15:06 1700 43K, continue drilling ahead. Circ = 3941 psi, open choke, 99% returns, 15 -20 fph, -100 psi motor -work, again begin to stack weight, building 30 bbl Drilzone, PUW = 42K 2/15/2019 2/15/2019 0.60 PR0D1 DRILL DRLG T Stacking coil weight and not making 10,380.0 10,377.0 17:00 1736 hole. PU to 10,369', Ct Wt 40.6 k Itis, 4 more pick ups to get restarted with decreasing PU weight. Restarted, drilling ahead slowly with pickups to 10,377where the motor stalled. 2/15/2019 2/15/2019 1.20 PROD1 DRILL DRLG T Unable to Pick up after stall, Pull up to 10,377.0 10,377.0 17:36 1848 70 k lbs, bleed coil back to 0. work pie, work CT pressure up to 2000 psi, work pipe to 70 k. No movement, no indication of circulation. 2/15/2019 2/15/2019 0.70 PROD1 DRILL DRLG T Dog house discussion, manually pump 10,377.0 10,377.0 18:48 19:30 up injector circuits. Cycle pipe up to 80k squatting up to -10 k, pulling speeds up to 100 ft/min, no movement. Consult w engineering. Work pipe to 90%- 90,000 lbs. squatting,varying running speed. no movement. Consult town again. Page 5/18 Report Printed: 7/22/2019 < Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Steri Time End Time our (hr) Phase Phese Op Code nativity cone Time P-T-X Operation Depth (%Ka) End Depth rtK8) 2/15/2019 2/15/2019 1.50 PROD1 DRILL DRLG T Online with the pump in attempt to 10,377.0 10,377.0 19:30 21:00 shear the 2500 psi circ port above the motor. Well started taking fluid @ 0.4 bpm and 2800 psi. Worked pipe to 80k while pumping, no movement or indication burst disc burst. Increase rate to 2.5 bpm and 7000 psi. No indication of shear circ sub opening, no indication of the flaw disconnect in the liner disconnecting. Start additional generator. 2/15/2019 2/15/2019 0.60 PROD1 DRILL DRLG T Cycle rate to 3 bpm and 7000 psi 13 10,377.0 10,377.0 21:00 21:36 times with no indication of shear/ shift _f/_1 in liner running assembly. 5/201-9 2/15/2019 1.30 PROD1 DRILL DRLG T PJSM, drop 5/8" ball, launch with 3100 10,377.0 10,288.0 21:36 22:54 psi, hear indication of launch, chase @ 1.8 bpm, Ct 5500 psi, WH 200 psi. Cut rate with 26 bbls away to 0.45 bpm. @ 41 bbls away, surge rate from 0.25 bpm to 2.5 bpm. At 4340 bbls away, CT to 5800 psi, Walk pressure up to 7300 psi. after - 2 minutes saw pressure fall to 1300 psi. PUH to 10288 (technically 10086'), established circulation @ 2 bpm, CT 2763 psi, WH 246 psi. 7300 .."Top offish - 10159' CTMD. 2/15/2019 2/16/2019 1.10 PROD1 DRILL CIRC T Park and reset counters after dropping 10,288.0 10,050.0 22:54 00:00 off drilling liner. Circulate bottoms up X2 while creeping up hole slowly. CT 2736 psi, WH 228 psi, 2.01 bpm in / 1.95 bpm out. 2/16/2019 2/16/2019 0.90 PROD1 DRILL CIRC T Continue to circulate botooms up 10,050.0 10,720.0 00:00 00:54 2116/2019 2/16/2019 0.30 PROD1 DRILL DISP T Pump 9.9 KW fluid to the TI --To-096,.0 10,086.0 00:54 01:12 2/16/2019 2/16/2019 1.50 PROD7 DRILL DISP T POOH displacing well to 9.9 ppg KW 10,086.0 237.0 01.12 02:42 fluid. full returns. 2/16/2019 2/16/2019 1.40 PROD? DRILL PULD T LD BHA 3, less drilling liner left in 237.0 0.0 02:42 04:06 hole. Hole fill <1 bbl/hr 2/16/2619 2/16/2019 7.70 PROD1 DRILL WAIT T Wait on a-line, -0 0 0.0 04:06 11:48 Confer w/ town, decision made to cut fish w/ chemical cutter at 10,325' 2/16/2019 2/16/2019 1.90 PROD1 DRILL ELNE T SLB e-line arrives at rig, PJSM, RU e- 0.0 0.0 11:48 13:42 line, get tools to rig floor 2/16/2019 2/16/2019 -1 30 PR0D1 DRILL ELNE T PJSM,PU a-line tools 0.0 0.0 13:42 15:00 2/16/2019 2/16/2019 -1 00 PR DI DRILL ELNE T RIH w/ chemical cutter, PUH to log K1, 0.0 10,330.0 15:00 16:00 arrive at cutting depth, make cut in 3.5" FlushMax pipe at 10,330' (CCL depth of 10,319', a-line tension drops from 1170 of to 878 Ibf, wiat 5 minutes, RIH to release dogs 2/16/2019 2/16/2019 1.00 PROD? DRILL ELNE T POOH w/e-line 10,330.0 0.0 16:00 17:00 2/16/2019 2/16/2019 1.70 PROD1 DR ILL ELNE T Lay lown E-line tools and clear the rig 0.0 0.0 17:00 1842 floor 2/16/2019 2/16/2019 -1 70 PR0D1 DRILL P_UL D T PJSM, PU BHA 94, fishing assembly. 0.0 236.0 18:42 2024 2/16/2019 2/16/2019 1.50 PR0D1 DRILL TRIP T RIH, Ct PU Wt@ 10,099' CTMD 42 k 236.0 10,155.0 20:24 21:54 lbs, PUH 37.5 k lbs. Page 6118 Report Printed: 7/22/2019 Operations Summary (with Timelog Depths) U-10 Time Log Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Start Time 2/16/2019 End Time 2/16/2019 our thr) 0.10 Phase PROD1 op Code ACttvity Code Time P-T-XStart operation Depth (ftKB) End Depth (fiKB) 21:64 22:00 DRILL TRIP T Run into fish @ - 30 ft/min. Set down 10,155.0 10,155.0 Flow Max. on fish at 10155' CTMD. S/D - 3k Ibs, "* Left 61.00' offish in hole, partial PU to 50 k lbs, Fish on, Pull into 60k, 2/16/2019 2/17/2019 2.00 PROD1 DRILL TRIP T Jar fired, pulled free, 22:00 00:00 joint Flush Max, XO burst tlisc, motor POOH with fish. CT wt 38k Ibs and 10, 155.0 396.0 77"^ 1.40 PROD? DRILL CTOP T and bit. Clean floor, skid cart, no wire in slowly dropping. 03:00 03:00 2/17/2019 02:00 2/17/2019 03:00 1.00 PRODi DRILL PULD T LD flish, hanger assembly, and 6 full 165.0 0.0 joints plus 1 partial cut jpint of 3.5: Flow Max. "* Left 61.00' offish in hole, partial 7.74' joint #2 3.5 Flush max, full 27.64' joint Flush Max, XO burst tlisc, motor 019 2/17/2019 1.40 PROD? DRILL CTOP T and bit. Clean floor, skid cart, no wire in 03:00 03:00 0424 site, Stab on and pump slack back. 0.0 0.0 2/17/2019 04:24 2/17/2019 2.10 PROD1 DRILL CTOP T Unstab, skid cart, pick up hydraulic 0.0 06:30 cutter, cut 296' of pipe to find e -line, 0.0 2/17/2019 2/17/2019 1.70 PROD1 DRILL cul additional 4' for a total of 300' cut 06:30 08:12 CTOP T Bevel & ream pipe, install CTC, pull 0.0 0.0 test 2/17/2019 08:12 2/17/2019 1.30 PROD? DRILL CTOP T Install UOC & re -head a -line, pressure 0.0 09:30 test CTC test wire, greater than 1800 0.0 2/17/2019 2/17/2019 0.50 PROD1 DRILL CIRC mega ohms and 69.5 ohms. 09:30 10:00 T Pump coil volume forward @ 2.5 bpm 0.0 0.0 2/17/2019 10:00 2/17/2019 0.90 PRODi DRILL PULD T PU BHA#5 Nozzle, slide in cart, MU 0.0 10:54 to coil, tag up, set counters 53.0 2/17/2019 10:54 2/17/2019 12:48 1.90 PROD1 DRILL TRIP T RIH w/ BHA#5, begin sending drilling 53.0 10,280.0 fluid 2/17/2019 12:48 2/17/2019 13:00 0.20 PROD1 DRILL DLOG T Log K7 for correction 10,280.0 10,299.0 2/17/2019 13:00 2/17/2019 14:18 1.30 PROD1 DRILL TRIP T 1 Continue RIH & jog WS tray multiple 10,299.0 10,312.0 times, pumping 2 bpm (TOWS to 10,312'), pump two 5x5 sweeps 14:18 019 14:18 2/17/2019 16:00 1.70 PROD1 DRILL TRIP T POOH, displacing to 9.9 ppg KWF, 10,312.0 53.0 Flow check, good 2/17/2019 2/17/2019 0.50 PROD1 DRILL PULD T PJSM, LD BHA #5 (break off nozzle) 16:00 16:30 53.0 0.0 2/1 16:30 7/2019 2/17/2019 0.40 PROD1 DRILL PULD T PU BHA #6 WS Fishing Assembly 0.0 16:54 (BOT hook), slide in cart, MU to coil, 66.0 019 2/17/2019 1.70 P-ROD DRILL TRIP T tag up, set counters 16:54 16:54 18:36 RIH w/ BHA #6 66.0 9,845.0 28:36 19 2/1712019 18:48 0.20 PROD1 DRILL DLOG T Tie into the K1 for a -2.5' correction 9,845.0 9,879.0 PU Wt 40 k lbs 2/17/ 2/17/2019 18.48 2/17/2019 19.30 0.70 PROD1 DRILL PULL T Continue to RIH, Wt check above WS 9,879.0 10,315.0 @ 10239'40 k lbs. RIH from 10300 to 10315'@ 5 ft/min cycle pipe across trayjetting with hook oriented neutrally @ 194, 190, 200, and 180' ROHS wile pumping 2 bpm, 1.8 bpm returns, 10.1 ppg EMW @ the window. PU above WS, orient hook to 14° ROHS. RIH, stack 2.5 k WOB @ 10309.9' PU, up to -3.0 k lbs WOB, broke back, 2/17/2019 2/17/2019 2.20 PROD1 DRILL TRIP suspect TP fish on, 19:30 21:42 OOH, orienter turned off, 90 ft/min 10,315.0 70.0 2/17/2019 2/17/2019 21:42 22:36 0.90 PROD1 DRILL PULD T Stand back upper BHA, LD fishing 70.0 0.0BHA and fish -(whipstock) Page 7118 1eport Printed: 7/22/2019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log statTme End Time our inn Phase Op Code Aatieity Cade Time P -T -X Operation Stan Dapth (MS) End Depth (flKB) 2117/2019 2/17/2019 0.70 PROD1 DRILL PULD T PU BHA#7 clean out assembly, 0 ° 0.0 62.5 22:36 23:18 motor with D331 bit, 2.7" no go. inspect pack offs, good. 2/17/2019 2/18/2019 0.70 PROD1 DRILL PULD T RIH 62.0 3,267.0 23:18 00:00 2/18/2019 2118/2019 1.10 PRODi DRILL TRIP T Continue to RIH. 3,267.0 9,842.0 00:00 01:06 2/18/2019 2/18/2019 0.20 PRODt DRILL DLOG T Tie into K1 for +6' correction 9,842.0 9,864.0 01:06 01:18 211812019 2/18/2019 0.20 PROD1 DRILL CIRC T Contine to RIH, milling fluid at the bit 9,842.0 10,329.0 01:18 01:30 1 @ 10302'. SID @ 10,329, stall, PU 42 k lbs 2/18/2019 2/18/2019 1.00 PROD1 DRILL CIRC T RBIH, 1.84 bpm in, 1.80 bpm out, free 9,842.0 10,326.0 01:30 02:30 spin 421 psi, 10.04 ppg EMW a@ the window. SID 10,326', stall, PU 42 k lbs. RBIH, start taking weight @ 10,325.96'. Motor work, no ROP, hard tag. 2/18/2019 2/18/2019 1.00 PROD1 DRILL CIRC T Perform jetting passes from 10320 to 10,326.0 10,317.0 02:30 03:30 10300. Tum coil over to seawater 2/18/2019 2/18/2019 1.20 PRODi DRILL DISP P Seawater at the bit, wash from 10300 10,317.0 4,436.0 03:30 04:42 to 10320 x2. POOH chasing seawater uphole. Park w 25 bbls of seawater above the bit, open EDC. POOH 2/18/2019 2/18/2019 1.30 PROD1 DRILL DISP P LRS, rigged up and PT'd to 4500 psi, 4,436.0 70.0 04:42 0600 start pumping 40 bbls diesel to the coil @ 2 bpm, 4400 psi. 2/18/2019 2/18/2019 0.70 PRODt DRILL PULD P PJSM, PUD BHA#7 70.0 0.0 06:00 06:42 " 395 psi SITP 211612019 2/18/2019 1.50 DEMOB WHDBOP RURD P Jet stack, & sucked out, freeze protect 0.0 0.0 06:42 08:12 -tree, clear floor 2/18/2019 2/16/2019 1.50 DEMOB WHDBOP RURD P Work RD checklist, freeze -protect tree, 0.0 0.0 08:12 09:42 blow -down PUTZ, break off TT line (hard-line still MU) 2/1812019 2/18/2019 1.30 DEMOB WHDBOP NUND P Break -off MP line, lock -out injector. NO 0.0 0.0 09:42 11:00 BOPE Rig Released: 2/18/19 @ 11:00AM 6/12/2019 6/12/2019 1.50 MIRU MOVE P Complete RD, pull off well, hook up 0.0 0.0 00:00 01:30 jeeps and sows. 611212019 6112/2019 3.00 MIRU MOVE MOB P Roll off pad to 1J-10 0.0 0.0 01:30 04:30 6/12/2019 6/12/2019 1.50 MIRU MOVE WAIT P Park inbetween 2C access pads to 0.0 0.0 04:30 06:00 1 1 allow for crewmeld change out 6/12/2019 6/12/2019 5.00 MIRU MOVE MOB P Move dg from 2C access road to 1J 0.0 0.0 06:00 11:00 pad - meet with pad op. permission to spot up/rig up. Inspect wellhead close OA and IA, 6/12/2019 6/12/2019 2.20 MIRU MOVE RURD P Move in and spot modules 0.0 0.0 11:00 13:12 6/12/2019 6/12/2019 4.50 MIRU WHDBOP RURD P Begin RU check list, drop stairs, 0.0 13:12 17:42 secure landings, scaffold crew on location to build deck, MU hard-line, begin moving shop & 1/2 -Way House 6/12/2019 6/12/2019 0.75 MIRU WHDBOP NUND P Begin NU BOP, continue RU checklist 0.0 0.0 17:42 18:27 Rig Accept @ 19:00hrs Page 8118 ReportPrinted: 7/22/2019 Operations Summary (with Timelog Depths) +r7 ' ii -10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Tlme End Time Dur(hu Phase Op Code Amvity Cade Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 6/12/2019 6/12/2019 4.00 MIRU WHDBOP RURD P Crew Change, lockout Koomey Unit 0.0 0.0 18:27 2227 and attempt to function (locked out) Preform Lockout audit (good), Change out 2-3/8" Deployment rams, check tree bolts. Grease crew on location, service tree valves, rig crew service choke manifold and rig valves. 6/12/2019 6/12/2019 0.55 MIRU WHDBOP RURD P Fluid pack test pump and surface 0.0 0.0 22:27 23:00 lines, Perform shell test on door seal and containment (good) 6/12/2019 6/13/2019 1.00 MIRU WHDBOP DOPE P Start Initial BOPE test, 3,500 psi 0.0 0.0 23:00 00:00 High/250 psi Low/2,500 psi Annular, witness waived by AOGCC (Austin McLeod) 6/13/2019 6/13/2019 3.50 MIRU WHDBOP BOPE P Continue initial BOP test, 3.500 psi 0.0 0.0 00:00 0330 High/250 psi Low/2,500 psi Annular, witness waived per AOGCC (Austin McLeod) 6/13/2019 6/13/2019 0.30 MIRU WHDBOP CTOP P RD testing equipment, blow down & 0.0 0.0 03:30 0348 freeze protect test pump 6/13/2019 6/13/2019 0.75 MIRU WHDBOP PRTS P Slide INJH cart forward, install nozzle, 0.0 0.0 03:48 0433 stab onto stump, test inner reel valve and pac-off. 6/13/2019 6/13/2019 1.50 MIRU WHDBOP PRTS P Fliud pack and test PDL's and tiger 0.0 0.0 04:33 06:03 tank line 6/13/2019 6/13/2019 1.50 SLOT WELLPR CTOP Blow down test equipment, work valve 0.0 0.0 06:03 0733 check list, mud test - found sticks, plastic ad other debris packing off screens while taking on mud from Peak Vac truck. Circulated over the top to shaker screens, fluid overran the shaker with 200 mesh - research partial size of black product in mud, need 100 mesh or larger. 6/13/2019 6/13/2019 1.50 SLOT WELLPR PULD P PJSM, PU BHA# 8 - Clean out BHA, 0.0 54.0 07:33 0903 3.80 parabolic (D331) mill W BOT 2- 7/8" straight motor below 2-3/8" coilTrak, Stab injector, bump up, set counters 6/13/2019 6/13/2019 2.00 SLOT WELLPR DISP P RIH turning well over to Seawater. 54.0 10,045.0 09:03 11:03 Initial tubing pressure 886 psi 6/13/2019 6/13/2019 0.30 SLOT WELLPR DLOG P Tie into the upper Kalubik -10' 10,045.0 10,106.9 11:03 11:21 correction 6/13/2019 6!13/2019 0.60 SLOT WELLPR CIRC P PU Weight 41 k Ibs, RIH, hard tag and 10,106.9 10,301.9 11:21 11:57 stall @ 10301.9' with 1 k WOB, PU 41 k Ibs, RBIH, and S/D two more times at the same depth, hard stall stacked WOB to 7 k and 4.7 k WOB, pickups clean @ 41-44 k Ibs CT Wt. Attempted to hold 11.8 ppg EMW, loosing 0.5 bpm, targeting 10.5 ppg until well swapped over to mud. Call and consult with town engineering on depth with K1 6/13/2019 6/13/2019 1.10 SLOT WELLPR DISP P Pump sweeps followed by mud - 8.65 10,300.8 10,000.0 11:57 1303 ppg Power Pro with Kla-Shield (3% KCI, 1.5% Kla-Stop, 1% Lube 776, 1% Drilzone, 8 ppb Asphasol Supreme, 4 ppb Resinex). Chase to bit while cycling pipe. Targeting 11.8 ppg EMW. Pull above seal bore assembly 6/13/2019 6/13/2019 0.40 SLOT WELLPR DL OG P Park, swap to CCL, RIH logging from 10,000.0 10,300.0 13:03 13:27 9970' to 10,300' bit depth. Park , open EDC. Page 9118 Report Printed: 7/22/2019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Cotle Time P-T-X Operation Start Depth (ftK8) End Depth htK8) 6/13/2019 6/13/2019 3.00 SLOT WELLPR TR`IP P POOH targeting 11.8 ppg EMW at the 10,300.0 46.0 13:27 1627 shoe. minor loses, tag up space out 6/13/2019 6/13/2019 1.20 SLOT WELLPR PULD P PUD BHA #8 clean out BHA. 46.0 46.0 16:27 17:39 Struggle to equalize PDL, pump not moving fluid. 6/13/2019 6/13/2019 0.85 PROD1 RPEQPT PULD P Re-config BHI tools, clean RF, crew 46.0 0.0 1739 18:30 change, PU 4.5" XL Mono-bore WS 6/13/2019 6/13/2019 1.10 PROD1 RPEQPT PULD P PD WS Setting BHA #9 0.0 76.7 18:30 1936 6/13/2019 6/13/2019 0.20 PR551 RPEQPT PULD P Function open 2-3/8" Deployment 76.7 76.7 19:36 1948 ras, tag up, reset counters mH 6/13/2019 6/13/2019 1.80 PR0D1 RPEQPT TRIP P RI 76.7 10,065.0 19:48 21:36 6/13/2019 6/13/2019 0.20 TROD1 DLOG P Log formation for depth control (Upper 10,065.0 10,138.0 21:36 21:48 Kalubik) @ 5 fph, correction of minus 10.5', PUW 37 k 6/13/2019 6/13/2019 0.20 PROD1 RPEQPT TRIP P Continue IH to setting depth 10,138.0 10,298.7 21:48 22:00 6/13/2019 6/13/2019 0.50 PR0D1 RPEQPT WPST P Confirm TOWS setting depth 10,283' 10,298.7 10,283.0 22:00 22:30 as per plan, 330 ROHS, shut down pump, close EDC, obtain static differentual pressure 543 psi 6/13/2019 6/13/2019 0.20 PROD? RPEQPT WPST P Bring pump up to shear 5,083 psi, set 10,283.0 10,244.0 22:30 22:42 down 6 k DHWOB, PUW 36 k 6/13/2019 6/14/2019 1.30 PROD? RPEQPT TRIP P Obtain static pressure @ 5,946.32' 10244.0 10,244.0 22:42 00:00 ND 6/14/2019 6/14/2019 0.70 PR0D1 RPEQPT DISP P Continue building KWF, PUH slowly @ 10,283.0 10,244.0 00:00 0042 1 fpm 6/14/2019 6/14/2019 0.75 PROD1 RPEQPT DISP P Start displacing well to 11.5 ppg KWF, 10,244.0 10,244.0 00:42 01:27 Note: bleed IA pressure from 1,458 psi down to 1000 6/14/2019 6/14/2019 1.90 PR0D1 RPEQPT TRIP P POOH 10,244.0 76.7 01:27 03:21 6/14/2019 6/14/2019 0.50 PR0D1 RPEQPT OWFF P check well for flow (Initial Loss Rate 6 76.7 76.7 03:21 03:51 bph), PJSM for LD BHA 6/14/2019 6/14/2019 0.60 PR001 RPEQPT PULD P LD setting tools on a dead well 76.7 0.0 03:51 0427 6/14/2019 6/14/2019 0.80 PRODi RPEQPT CTOP Move Cart forward, remove BHI UQC, 0.0 0.0 04:27 05:15 cut and boot a-line 6/14!2019 6/1412019 1.00 PROD1 RPEQPT CTOP TU/MU 4 joints of 2-3/8" PH6 with 0.0 05:15 06:15 ported nozzle for catching ball 6/14/2019 6/14/2019 0.80 TRO D1 RPEQPT GTOP Sab injector pump 1 coil volume 0.0 06:15 07:03 forward 6 surges up to 2.5 bpm to pump wire forward. 6/14/2019 6/14/2019 0.60 PROD? RPEQPT CTOP Unstab injector, cut and pull wire, 0.0 07:03 07:39 recoverd 136' of a-line. Cut pipe back 13', reboot Eline. 6/14/2019 6/14/2019 0.50 PROD1 RPEQPT CTOP Install BOT external coil connector, 0.0 07:39 08:09 Pull test to 37 k lbs, PT to 4000 psi - good. 6/14/2019 6/14/2019 0.80 PROD1 RPEQPT CTOP P Drop ball, pumps to 2.5 bpm, hear 0.0 0.0 08:09 0857 ball launch, some more wire move, hear ball leave the coil to the goose neck, S/D 40 bbls away 6/14/2019 6/14/2019 0.50 PROD1 RPEQPT CTOP P Pop off, LD PH-6 jnts, additional 134 0.0 0.0 08:57 09:27 of slack pumped toward, retireved ball from nozzle, good test on a-line 65.6 Ohms/2000 M ohms, cut a-line, epoxy & protect tag end. "Total wire recovered 270' Page 10118 ReportPrinted: 7122/2019 Operations Summary (with Timelog Depths) NABORS CDR3-AC U-10 Job: DRILLING Start Time End Time our (Inn Phase O Code A start Depth 6/14/2019 6/14/2019 2.40 PROD1 RPEQPT CTOP y cpae Time P -r -x Discuss amounts of wire (nKe) End Depth 10.0 09:27 11:51 relieved, 0 0 Stabbed on and pumped one last time. No additional wire returned, left 2'stump. LD PH -6. 6/14/2019 11:51 6/14/2019 1.40 PROD1 WHPST PULD P PJSM, PU BHA #2 Window Assembly, 0.0 248.7 13:15 bump up and set counters 6/14/2019 13:15 6/14/2019 1.60 PROD1 WHPST TRIP P RIH pumpinng 15 bbl spacer between 248.7 10,283.0 14:51 KW and Mud W black product, PU Wt @ 10200'39 k lbs, Dry tag TOB -6 10,283 6/14/2019 14:51 4/2019 0.70 PROD? WHPST DISP P Turn well over to milling fluid. Took 10,283.0 10,226.0 15:33 gas back to surface, exported returns to the tiger tank. IA pressure built rapidly was 1108 psi @ 14:00. to 1400 psi. Suspect T x IA, deep leak, possibly the OV, 6/14/2019 15:33 6/14/2019 1733 2.00 PROD1 WHPST DISP T Export 119 bbls. IAtracking wellhead. 10,226.0 10,283.0 Bring Mud back inside. Bleed IA from 1,400 to 1155 psi. Observe fluid entering the IA. Set rates and RIH to mill window. 6/14/2019 17:33 6/14/2019 1.00 PROD1 WHPST TRIP P Set parameters, CT 4340 psi, WH 351 10,283.0 10,293.0 18:33 psi, @ 2.5 bpm in and 2.5 bpm out, RIH wt 11.1 k Ibs, IA 1219 psi, OA 58 psi., chase weight down to 10,293', PUH and dry tag x 2 TOWS @ 10293' 6/14/2019 18:33 6/14/2019 20:33 2.00 PROD1 WHPST MILL P Set parameters, CT 4340 psi, WH 351 10,293.0 10,294.7 psi, @ 2.5 bpm in and 2.5 bpm out, RIH wt 11.1 k lbs, IA 1219 psi, OA 58 6/14/2019 20:33 6/14/2019 2.00 PROD? WHPST VILL psi Milling ahead , 4,574 psi, WH 558 psi, 10,294.7 10,295.7 22:33 @ 2.5 bpm in and 2,48 bpm out, IA 1,306 psi, OA 75 psi 6/14/2019 22:33 6/15/2019 00:00 1.45 PROD1 WHPST MILL P Milling ahead , 4,654 psi, WH 558 psi, 10,295.7 10,296.5 @ 2.5 bpm in and 2,48 bpm out, IA 1,307 psi, OA 82 psi 6/15/2019 00:00 6/15/2019 00:30 0.50 PROD? WHPST MILL P Milling ahead , 4,654 psi, WH 558 psi, 10,296.5 10,296.7 @ 2.5 bpm in and 2,48 bpm out, IA 1,307 psi, OA 82 psi 6/15/2019 00:30 6/15/2019 00:42 0.20 PROD1 WHPST MILL P Stall motor, PUH PUW 36 k 10,296.7 10,296.7 6/15/2019 00:42 6/15/2019 2.00 PROD1 WHPST MILL P Restart 2.49 bpm @ 4,325 psi, 10,296.7 10,298.9 0242 Diff=130 psi, WHP=550, IA=1,301, OA=82 6/15/2019 02:42 6/15/2019 05:00 2.30 PROD? WHPST MILL P Milling ahead, 4,274 psi, WH 541 psi, 10,298.9 10,301.5 @ 2.50 bpm in and 2,53 bpm out, IA 1,301 psi, OA 86 psi 05:00 019 05:00 06:30 019 06:30 1.50 PROD1 WHPST MILL P Milling aheatl , 4,228 psi, WH 576 psi, 10,301.5 10,303.3 @ 2.5 bpm in and 2.5 bpm out - CT Wt Z5 k lbs, 6/15/2019 06:30 6/15/2019 07:48 1.30 PROD1 WHPST MILL P **Mill exits the casing - 11.8' window - 10,303.3 10,304.9 10,303.3' Milling ahead, 4,180 psi, WH 582 psi, @ 2.50 bpm in and 2.45 bpm out, 6/15/2019 07:48 6/15/2019 1.70 PRODi WHPST MILL P .. Both mill and reamer out - start 10,304.9 10,318.0 0930 pushing on it - 10,304.9' Milling ahead, 4,180 psi, WH 582 psi, @ 2.50 bpm in and 2.45 bpm out, 10,312.1' Stall, PU Wt 40 k lbs TO rat hole - Geo confirms shale in sample 6/1512019 09:30 019 0.80 PROD1 WHPST MILL P Perform reaming passes to 10,288' 10,318.0 10,289.0 10 10:18 18 second up pass clean. Page 11/18 Report Printed: 7/22/2019 <, Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start TM End Tma Dur(m) Phase Op Code Activity Code Time PJA Opemtcm Start Depth (WB) End Depm (WB) 6/15/2019 6115/2019 1.00 PROD1 WHPST MILL P PUH, cut pumps, Dry drift, good, turn 10,289.0 10,258.0 10:18 11:18 coil over to kill weight fluid - 11.5 ppg NaBr 6/15/2019 6/15/2019 3.30 PROD1 WHPST TRIP P PUH tuming well over to KW fluid. 10,258.0 270.0 11:18 14:36 Pulled heavy@ 10113', 9937', 9742', and 9389' Unexplainable, tripped injector set points. Seems to happen at pulling speeds above 80-85 ft/min. Reduced POOH speed to 70 ft/min. 6/15/2019 6/15/2019 2.00 PRODi WHPST PULD P At surface, 90 psi well head as soon 270.0 0.0 14:36 16:36 as the pumps were cut. Bleed IA, WH dropping with IA. Zero WH with 880 psi on the IA, Shut in IA, climbed slowly to 958 and stabilized, Zero flow, PJSM, LD BHA #10. DSM and string reamer gauged out at 3.79" / 3.80" respectfully. 6/15/2019 6/15/2019 2.00 PROD1 DRILL PULD P PU Drilling liner 0.0 218.6 16:36 18:36 6/15/2019 6/15/2019 0.30 PROD1 DRILL PULD P PU TJ Hydraulic Disconnect, XO 2- 218.6 248.6 18:36 18:54 3/8" Reg x 2-3/8" Pac, and dual back pressure valve 6/15/2019 6/15/2019 0.30 PR0D1 DRILL PULD P PU 6 2-3/8" PH6 CS Hydrill joints 248.6 436.0 18:54 19:12 6/15/2019 6/15/2019 0.30 PROD1 DRILL PULD P PU/MU BHI CoilTrak tools with 436.0 458.1 19:12 19:30 lockable swivel. 6/15/2019 6/15/2019 1.80 PRODt DRILL TRIP P Stab INJH, tag up, reset counters, RIH 458.1 8,059.0 19:30 21:18 pumping 0.46 bpm at 595 psi, Limited tripping speed per NS Rep - 80 fpm 6/15/2019 6/15/2019 0.20 PROD1 DRILL TRIP P Check depth at EOP flag 7,605.6', 8,059.0 10,308.0 21:18 21:30 looks like minus 10', continue IH thru window with no pumps, @ 10,313' bring pump up to 0.36 bpm tag bottom @ 10,318', correct minus 10.0', PUH PUW 41 k 6/15/2019 6/15/2019 1.80 PROD1 DRILL DISP P Displace well to 9.0 ppg drilling fluid 10,308.0 10,308.0 21:30 23:18 6/15/2019 6/15/2019 0.20 PROD1 DRILL DRLG P Bring pump up to 2.52 bpm at 5,643 10,308.0 10,309.0 23:18 23:30 1 psi, WHP=229, IA=926, OA=74 6/15/2019 6/16/2019 0.50 PROD1 DRILL DRLG P Drill ahead to 10309.2', seems to be 10,309.0 10,309.0 23:30 00:00 1 stalled, PUH 55 k, broke back to 43k, bring pump back online, 2.5 bpm 5.738 psi, WHP=225, IA=943, OA=75 6/16/2019 6/16/2019 0.20 PROD1 DRILL DRLG P PUH PUW 41 k 10,309.0 10,263.0 00:00 00:12 6/16/2019 6/16/2019 0.30 PRODi DRILL DRLG P RBIH, dry tag bottom @ 10,308' 10,263.0 10,308.0 00:12 00:30 6/16/2019 6/16/2019 0.20 PROD1 DRILL WPRT P PUH, bring pump up to 2.54 bpm @ 10,308.0 10,306.0 00:30 00:42 5,087 psi, seemed to be in a stall 6,400 psi, PUW70 k, RBIH @ 1.5 bpm (413,600 psi, attempt to RIH from 10,300', stackout at 10,306' 6/16/2019 6/16/2019 0.20 PROD1 DRILL WPRT P PUH above window 10,177', continue 10,306.0 10,177.0 00:42 00:54 building tubed pill 3 bbls to 5% lubes 2.5% lo-torque, and 2.5% 776, while receping pipe 6/16/2019 6116/2019 0.80 PROD1 DRILL WPRT P 5 bbls of lube pill out bit, RIH, stackout 10,177.0 10,283.0 00:54 01:42 10,283', PUH PUW 43 k x 6, uinable to pass through TOWS, PUH slowly phone town team on plan forward, Page 12118 Report Printe 1: 712212019 1 . Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stag Time End Time Dor (hr) Phase Op Cade Activity Code Time P -T -X Operation Start Depth (MB) End Dept (ftKB) 6/16/2019 6116/2019 1.50 PROD1 DRILL DISP T Recieved call back, decision was 10,283.0 10,283.0 01:42 03:12 made to kill well with 11.5 ppg KWF, confirm KWF is 11.5 ppg, configure pits for displacement. 6/16/2019 6/16/2019 0.25 PR0D1 DRILL TRIP T POOH 40 k, while displacing well to 10,283.0 9,355.6 03:12 0327 11.5 ppg KWF, pulled tight at 9,355'50 k, top of tools @ 9,097', work pipe up/down -10 k/+70 k 6/16/2019 6/16/2019 1.50 FROMDRILL TRIP T Phone town team on plan forward, 9,355.6 9,355.6 0327 0457 tools limitations, plan forward finish killing well, work pipe up to 80 It, pump 5/8" steel ball to attempt release of the NS liner running tool. 019 6/16/2019 3.30 PROD1 DRILL DISP 7 Continue killing the well, KW strung 9,355.6 9,355.6 04:57 04:57 08:15 out. 1.45 bpm in and 1 bpm out, reduce pump rate, 1 bpm in and .9 bpm out. Out MM density slowly rising, Out MM reading — A ppg higher than pressurized mud balance in pits. 6/16/2019 6/16/2019 1.00 PROD1 DRILL DISP T Kill weight all the way around. 1.02 9,355.6 9,355.6 08:15 09:15 bpm in and 0.9 bpm out, CT 2702 psi, WH 0, IA 1348 psi, OA 81 psi. CT Wt 10.81 k lbs S/I pump for flow test, WH climbed to 579 psi, Bleed IA for 15 minutes, WH fell to Zero, IA @ 600 psi, S/I bleed, IA climbed to 677 and slowly climbed. Flow test well, Well is dead. Work coil from 80 K lbs to -20 K lbs 5 times, still stuck. 6/16/2019 6/16/2019 0.80 PR0D1 DRILL DISP T Launch 5/8" ball to activate liner 9,355.6 9,355.6 09:15 10:03 hanger release tool Pump KW @ 2 bpm. Ball left the reel at 31 bbls away Reduce rate to — 0.5 bpm. 6/16/2019 6/16/2019 0.30 PROD? DRILL DISP T Ball on seat. Pressure up CT to 4 k, 9,355.6 9,211.0 10:03 10:21 wait, pick up to 50k lbs CL Slack of to 9 It CT Wt, pump CT to 5 k psi, wait, slack off to 0 k CT PU 50ft/min, to 55 It Ibis CT wt. slack off to 9 k ct wt, pump on CT again, observe shear at 5350 psi, WH 456 psi. Well unloaded as we PUH, had been packed off above. POOH pumping 2 bpm, full returns, screening down at shaker to 120 mesh. Balls ofAsphasol Supreme/ Resinex coming off the shaker, not much if any metal. 6/16/2019 6/16/2019 4.20 PROD1 DRILL TRIP T PUH, CT 5645 psi, 2.28 bpm in and 9,211.0 2,000.0 10:21 14:33 2.11 bpm out WH 296psi, IA 955 psi, OA 105 psi. Did not correct bit depth for dropped off liner and setting tools. Estimate top of fish @ 9113.37 - Should tag ten feet deeper @ 9123' because of correction. **242.23' of fish left in hole, liner hanger, 8 joints of 3.5" 511 tubing, triple connection bushing W 2.5 k SI disk, sleeve over motor, 2-7/8" straight motor, XO and 4.125" bi center bit. 6/16/2019 6/16/2019 0.90 PRODt DRILL TRIP T Large amount of pea gravel sized 2,000.0 240.0 14:33 1527 cuttings returned to the shaker @ 2000'. Heavy flow for — 10 minutes, increased pump rate to 2.4 bpm. Gravel returns diminished by 1,550'. Page 13118 ReportPrinted: 7/22/2019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stag Time End Time our Phase Op Code Activity Code Time P -T -X Operation Start Depth (flKBj End Depth (flKB) 6/16/2019 6/16/2019 2 1.20 PROD? DRILL PULD T Bump up, IA 858 psi, S/I pumps, WH 240.0 0.0 15:27 1639 climbed to 280 psi, bleed IA for 5 min WH fell to 0 psi. S/I bleed. Flow check good. Lay down BHA#11 over a dead well. -Retrieved 5/8" ball from liner setting tool. 6/16/2019 6/16/2019 1.20 PR0D1 DRILL PULD T PU BHA #13, Clean out assmbly 0.0 213.7 16:39 17:51 6/16/2019 6/16/2019 1.90 PR0D1 DRILL TRIP T Stab INJH, tag up reset counters, RIH 213.7 9,126.0 17:51 19:45 6/16/2019 6116/2019 1.50 PR= DRILL TRIP T Dry tag TOF @ 9,126', PUH continue 9,126.0 9,126.0 19:45 21:15 loading new mud system into pits 6/16/2019 6/16/2019 0.50 PROD1 DRILL DISP T Displace well to drilling fluid, line up 9,126.0 9,123.0 21:15 21:45 returns to tiger (15 bbls), bring back in, blow down the tiger tank line. 6/16/2019 6/16/2019 1.25 PROM DRILL WPRT T Perform recips x 3 from 9,123' up hole 9,123.0 8,040.0 21:45 2300 8,050' w/sweeps, pumping 2.8 bpm at 4,915 psi, WHP=301, IA=379, OA=74, not seeing pea gravel (shale), black sand and glass beads. 6/16/2019 6/17/2019 1.00 PROD1 DRILL WPRT T POOH, performing jogs from 8,100'x 8,040.0 6,464.0 23:00 00:00 3 w/5x5 sweep 6/17/2019 6/17/2019 1.70 PR0D1 DRILL WPRT T Continue swab wiper, performing jogs 6,464.0 214.0 00:00 0142 from 6,350' and 3,750'x 3 w/5x5 sweeps 6/17/2019 6/17/2019 1.80 PROD1 DRILL TRIP T Tag up, reset counters, RBIH 214.0 9,100.0 01:42 03:30 6/17/2019 6/17/2019 0.50 PROD1 DRILL DISP T Displace well to 11.5 ppg KWF 9,100.0 9,100.0 03:30 0400 6/17/2019 6/17/2019 1.80 PR0D1 DRILL TRIP --7- POOH, while displacing well to KWF, 9,100.0 243.0 04:00 05:48 interface 10 bbls sent out to tiger tank. 6/17/2019 6/17/2019 1.40 PROD? DRILL PULD T Bleed IA, till WH zero, S/I bleed, flow 243.0 0.0 05:48 07:12 check good. LD BHA #12 over a dead well. 6/17/2019 6/17/2019 1.00 PROD1 DRILL PULD T PU BHA#13, fishing assembly. Stab 0.0 226.8 07:12 08:12 on, Bump up and set counters. 6/17/2019 6/17/2019 1.80 PRODi DRILL TRIP T RIH w fishing assembly pumping min 226.8 9,130.0 08:12 10:00 rate 11.5 ppg KW fluid. Light weight fluid coming back according to micro motion, Verified good kill weight returning via pressurized mud balance. Pinch in choke to hold a small amount f back pressure micro motion signal cleaned up, 11.5 ppg KW returning. Continue in hole. PU Wt 33 k lbs @ 8918' Set down 9130 6/17/2019 6/17/2019 0.70 PROD1 DRILL FISH T Make multiple fishing attempts with 9,130.0 9,134.7 10:00 10:42 GS spear. Run into fish washing down from 1 tol.9 bpm. Stacking up to -10 k CT Wt, PU Wt, 30-34 k lbs, No indication of engaging fish, Pick up weights clean. Deepest CT depth recorded 9134.7 with -10 k CT Wt. Page 14118 Report Printed: 7/22/2019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Entl Tme our (hr) Phase Op Cotle Apiviry Code Time P -T-% Operation Btah Depth (ftKB) End Depth(ftKB) 6/17/2019 6/1712019 3.6D PROD1 DRILL FISH T PUH 300 feet, RBIH, SID in same 9,134.7 9,119.0 10:42 14:18 spot, 9134.6' and -5 k CT Wt. Wash over fish @ 1.9 bpm, while building kill weight viscosifed sweep. Pump 10 bbls high vis 11.5 ppg sweep Wash down over fish as sweep exits, chase sweep out of hole. Nothing notable in the returns as the sweep landed at the shaker. 6/17/2019 6/17/2019 0.80 PROD1 DRILL FISH T Hit 5 jar licks down trying to latch 9,119.0 9,091.0 14:18 1506 every time. No movement in fish and no definitive indication that fish is on. 019 6/17/2019 1.40 PR051 DRILL TRIP T POOH pumping over the top 9,091.0 262.0 15:06 15:06 16:30 6/17/2019 6/17/2019 1.40 PR0D1 DRILL PULD T LD BHA#13 over a dead well, did not 262.0 0.0 16:30 1754 have to bleed IA. (IA 495 psi, OA 73 psi) 6/17/2019 6/17/2019 1.10 PROD1 DRILL PULD T PU BHA#14 ,No Go, 2-3/8" inteq AKO 0.0 237.6 17:54 1900 @ 0°, w 2.77" slick D331. 6/17/2019 6/17/2019 1.50 PROD1 DRILL TRIP T RIH with motor and mill - clean out 237.6 9,118.0 19:00 20:30 assembly. 6/17/2019 6/17/2019 0.60 PROD1 DRILL CIRC T Dry tag @ 9137.5' PU 33 k lbs. RBIH 9,118.0 9,136.0 20:30 21:06 pumping 1.89 bpm. Set 10k lbs CT Wt down, no fluctuation in pump pressure, not making hole. Chase 10 bbl 11.5 ppg Hi Vis sweep to bit and jet inside fishing neck while puling slowly up hole. 6/17/2019 6/17/2019 2.65 PRODt DRILL TRIP T POOH chasing sweep pumping 1.87 9,136.0 238.0 21:06 23:45 bpm and pulling 50 ft/min. 6/17/2019 6/18/2019 0.25 PROD1 DRILL OWFF T Check well for flow 238.0 238.0 23:45 00:00 6/18/2019 6/18/2019 0.50 PROM DRILL PULD T Continue rnonitoring well for flow, LD 238.0 0.0 00:00 00:30 cleanout BHA#14 6/18/2019 6/18/2019 0.85 PROD1 DRILL PULD T PU/MU fishing assembly 0.0 226.8 00:30 01:21 6/18/2019 6/18/2019 1.60 PROD1 DRILL TRIP T RIH w/ fishing BHA#15 to fish NS 226.8 9,080.0 01:21 02:57 Liner Coiling Assembly, w/4' GS and jars. 6/18/2019 6/18/2019 0.15 PROM DRILL TRIP T Perform PUW 33 k 9,080.0 9,080.0 02:57 03:06 6/18/2019 6/18/2019 1.50 PROD1 DRILL FISH T Continue IH, dry tag TOF @ 9,080.0 9,121.0 03:06 04:36 9,121'CTMD uncorrected, PUW 33 k, no fish, bring pump up to 1.5 bpm, RBIH, set down minus 10 k CTSW, PUH, RBIH, attempt to latch fish, increase pump rate 1.75 bpm, set down 8.0 k 6/18/2019 6/18/2019 1.90 PROD1 DRILL TRIP T POOH unable to engage fish, hole 9,121.0 0.0 04:36 06:30 appears to be clean, pump pipe displacement 6/18/20 119 6/18/2019 0.50 PROD1 DRILL OWFF T OWFF for 30 min. 0.0 0.0 06:30 07:00 6/18/2019 6/18/2019 2.10 PROD1 DRILL PULD T LD BHA 15 and inspect 4" GS, the 0.0 0.0 07:00 09:06 4" GS, had a shiny mark, a full 360° around the dog retainer skirt, with a slight lip.11 appear the GS is fully NOGO'd to leave this mark but is not engaging the deployment sleeve. Trimmed 3/8" of the dog retainer sleeve to give the GS a deeper reach. MU BHA #16 with modified 4" GS Page 15/18 Report Printed: 7/22/2019 r Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time our (hr) Phase Op Code Activity Cade Time P -T -X Operation Staff Depth (fiKB) End Depth (WB) 6/18/2019 6/18/2019 1.60 PROD1 DRILL TRIP T RIH w/ fishing BHA#16, 4" GS, 0.0 9,126.0 09:06 1042 modified skirt, PUW 33K 6/18/2019 6/18/2019 0.70 PROD1 DRILL FISH T Tag at 9726, SD 10K, PU clean, make 9,126.0 9,126.0 10:42 11:24 9 attempts to engage and latch, no overpulls, try pumping, surging 6/18/2019 6/18/2019 1.50 PROD? DRILL TRIP T POOH, unable to engage fish, tag up 9,126.0 0.0 11:24 12:54 6/18/2019 6/18/2019 0.50 PROD1 DRILL OWFF T OWFF for 30 min 0.0 0.0 12:54 13:24 6/18/2019 6/18/2019 -1 40 PR0D1 DRILL PULD T LD BHA#16 and inspect 4" GS, no 0.0 0.0 13:24 14:48 discernible marks on GS. MU BHA 417, 3.77" OD LIB 6/18/2019 6/18/2019 1.60 PROD1 DRILL TRIP T RIH w/ LIB to take picture offish, at 0.0 9,126.0 14:48 1624 9000' CTMD, PUW 33K, pump jars open and let pressure stabilize 5 min, down on pump, run into fish at 50 FPM, 13K, tag at 9126' CTMD, w/ 10K -61-1812 down, i jar lick. 01-9 6/18/2019 1.50 PR0D1 DRILL TRIP T POOH to develop picture. 9,126.0 226.7 16:24 17:54 079 019 0.50 PROD1 DRILL OWFF T At surface, check well for flow, PJSM 226.7 226.7 17:54 17:54 18 24 1824 -6/-18/2 6/18/2019 01-9 0.50 5ROD1 DRILL PULD T LD LIB BHA #17 226.7 0.0 18:24 18:54 6/18/2019 6/18/2019 0.75 PROD1 DRILL CTOP T Discuss plan forward with town team 0.0 18:54 19:39 6/18/2019 6/18/2019 1.00 PROD? DRILL PULD T PU fishing BHA#78 w/stinger and 0.0 235.3 19:39 20:39 D331 (2.77od) 6/18/2019 6/18/2019 1.50 PROD1 DRILL TRIP T RIH 235.3 9,119.0 20:39 22:09 6/18/2019 6/18/2019 0.80 PROD1 DRILL FISH T PUW 33 k,Tag TOP of fish @ 9,119.0 9,119.0 22.09 22:57 9,119' (8.0' higher), PUW 33 It, PUH to 9,100', RBIH bring pump up to 1.83 bpm w/5,360 psi, slow down to 5 fpm, observe 200 psi increase in pump pressure, stack out at 9,116', PUH, PUW 33 k, PUH further RBIH increasing speed up to 45 fpm, set down -10 k, PUW 33 k, repeat process while pumping washing down slowly, not seeing any indication of latching up. x 13, with no success. 6/18/2019 6/18/2019 0.20 PROD1 DRILL TRIP T Discuss plan forward with town team, 9,119.0 9,119.0 22:57 23:09 decision was made to POOH for po- go, motor and mill. Paint EDP flag 8,903 EOP (Yellow) 0.85 PROM DRILL TRIP T POOH 9,119.0 3,789.0 23:09019 23:09 00:00019 00:00 6/19/2019 6/19/2019 0.75 PRODi DRILL TRIP T Continue POOH with GS BHA #18 3,789.0 235.3 00:00 00:45 6/19/20196/19/2019 0.50 PROD1 DRILL OWFF T Tag up, observe well for flow (no -flow) 235.3 235.3 00:45 01:15 6/19/2019 6/19/2019 0.50 PROD1 DRILL PULD T LD BHA #18 on a dead well 235.3 0.0 01:15 01:45 019 019 0.50 PROM DRILL PULD T PU/MU Cleanout BHA #19 0.0 237.6 01:45 01:45 02:15 02:75 6/19/2019 6/19/2019 1.50 PROD1 DRILL TRIP T Tag up, reset counters, RIH, PUW 33 237.6 9,100.0 02:15 03.45 k 6/19/2019 6/19/2019 0.20 PR0D1 DRILL TRIP T Continue RIH, set down 2-3k CTSW 9,100.0 9,133.8 03:45 0357 @ 9,133', 8,904' EOP same as Pervious BHA#17 Page 16/18 Report Printed: 7122/2019 . Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Star! Time End Time Out hr ( ) Phase O Code p Acdvi CWe tY Time P -T- X Operation n De ptin Start Eno Depth (flKB) 6/19/2019 6/19/2019 2.80 PROD1 DRILL TRIP T Work numbers, discuss recorded tag 9,133.8 9,133.0 03:57 06:45 up and depths. Wait to discuss with Town team. 6/19/2019 6119/2019 1.40 PROD1 DRILL TRIP T POOH, w/ motor & D331 mill 9,133.0 237.6 06:45 08:09 6/19/2019 6/19/2019 0.50 PROD1 DRILL OWFF T Tag up, observe well for flow (no -Flow) 237.6 237.6 08:09 08:39 6/19/2019 6/19/2019 1.70 PROD1 DRILL PULD T LD BHA#19, MU BHA#20, GS w/ 0.0 238.3 08:39 10:21 motor and 2.77" D331 mill, Tag up, reset counters, 6/19/2019 6/19/2019 1.60 PROD1 DRILL TRIP T RIH w/ 4" GS above motor and 2.77" 238.3 9,139.0 10:21 11:57 D331 mill. 6/19/2019 6/19/2019 0.50 PROD1 DRILL FISH T Tag @ 9139', pumping 0.3 bpm, CP= 9,139.0 9,139.0 11:57 12:27 4200 psi, down on pump, let pressure bleed off, no jar lick, PU clean. Make 4 more attempts to latch, saw over 1000 psi pressure drop after 2nd attempt, unsure why, CP now at 4600 psi at 1.9 bpm, CP was 5900 psi at same rate, not able to latch fish 6/19/2019 6/19/2019 1.56 PROD1 DRILL TRIP T POOH 9,139.0 0.0 12:27 14:00 6/19/2019 6/19/2019 0.50 PROD1 DRILL OWFF T Tag up, observe well for flow 0.0 0.0 14:00 14:30 6/19/2019 6119/2019 1.75 PROD1 DRILL PULD T LD BHA#20, no indication of latching, 0.0 0.0 14:30 16:15 no marks 6/19/2019 6/19/2019 1.50 PROD1 DRILL CTOP P Pump wire slack back, cut off BOT 0.0 0.0 16:15 17:45 connector, cut coil, found wire @ 290' - Note: 290' of coiled tubing trimmed. 6/19/2019 6119/2019 1.75 PROW DRILL CTOP P Crew change, test a -line (64.8/>2000), 0.0 0.0 17:45 19:30 Install CTC, pull test 35 k, head up BHI upper quick 6/19/2019 6/19/2019 0.50 PROD1 DRILL CTOP P PT CTC 4,500 psi 0.0 0.0 19:30 20:00 6/1912019 6119/2019 0.20 PROD1 DRILL CTOP P Install 2-1/8" nozzle with 0.75 ID port 0.0 0.0 20:00 20:12 on bottom, 6.125" length. 6/19/2019 6/19/2019 0.30 PROD1 DRILL CTOP P Stab INJH, pump 1 coil volume 0.0 0.0 20:12 20:30 forward 6/19/2019 6/19/2019 0.45 PROD1 DRILL PULD P PJSM, PU CoilTrak tools 0.0 42.8 20:30 20:57 6/19/2019 6/19/2019 1.80 PROW DRILL TRIP P Tag up, reset counters, RIH 42.8 8,640.0 20:57 22:45 6/19/2019 6/19/2019 0.30 PROD1 DRILL DLOG P Log formation correction of minus 5.0', 8,640.0 8,668.0 22:45 2303 6/19/2019 6/19/2019 0.20 PROD1 DRILL TRIP P Continue IH, while circulating SW 8,668.0 9,113.0 23:03 23:15 j down coil 6/19/2019 6119/2019 0.25 DEMOB WHDBOP DISP P Displace well to SW 9,113.0 9,113.0 23:15 23:30 6/19/2019 6/2012019 0.75 DEMOB WHDBOP DISP P POOH, while displacing well 9,113.0 6,344.0 23:30 00:15 6/2012019 6/20/2019 0.70 DEMOB WHDBOP TRIP P Continue POOH, LRS on location, 6,344.0 2,500.0 00:00 00:42 PJSM move unit in and rig up to rig, P/T hose to 4,500 psi 6/20/2019 6/20/2019 0.75 DEMOB WHDSOP FRZP P Load CT w/45 bblFreeze protect well 2,500.0 2,500.0 00:42 01:27 6/20/2019 6/20/2019 0.50 DEMOB WHDBOP FRZP P POOH, while displacing well to deisel 2,500.0 2,500.0 01:27 01:57 6/20/2019 6/20/2019 1.05 DEMOB WHDBOP PULD P PUD, BHA#21 2,500.0 42.8 01:57 03:00 Page 17118 Report Printed: 7/2 212 01 9 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log -Code Start Time End Time Our (hr) Phase Op Activity CoOe Time P -T -X Operatlon Stan Depth (kKB) End Depth(fiKB) 6/20/2019 6/20/2019 1.00 DEMOB WHDBOP PULD P LD, Displace and freeze protect BHA 42.8 0.0 03:00 04:00 #21 *** Note: June 13th Static w/8.84 ppg fluid IH, ECD=11.139 ppg, RKB to Sea Lvl = 114.25', AP=3,441 psi, Pres Sensor=5,946.32' TVD *** Note: Final tubing pressure 1,057 psi / no BPV installed 6/20/2019 6/20/2019 0.50 DEMOB WHDBOP RURD P MU Nozzle, stab onto well, recep coil 0.0 0.0 04:00 04:30 while flushing all surface lines and stack. 6/20/2019 6/20/2019 0.25 DEMOB WHDBOP RURD P Unstab INJH, RU to bore -o -scope 0.0 0.0 04:30 04:45 BOPE, while off loading and cleaning pits 6/20/2019 6/20/2019 5.25 DEMOB WHDBOP RURD P RDMO, Work thru Demob checklist, 0.0 0.0 04:45 10:00 Rig off High Line, *** Rig Release Q 10:00 AM ***, NES Trucks on location at 11:45 AM, Hold Pre Move safety meeting Page 18/18 Report Printed: 7/22/2019 pTo zoi- d�/ Haggerty -Sherrod, Ann (Northland Staffing Services) From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, June 20, 2019 2:35 PM To: McLaughlin, Ryan Subject: [EXTERNAL]RE: 1J-10 Operations Update Ryan, Thanxfor the update. Victoria From: McLaughlin, Ryan <Ryan.McLaughlin@conocophi Ilips.com> Sent: Thursday, June 20, 2019 2:27 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Ohlinger, James 1 <James.J.Ohlinger@conocophillips.com> Subject: 11-10 Operations Update Victoria, CDR3 rigged up on 11-10 (PTD 201-071) on June 12`" to re -attempt a liner drilling project we were unsuccessful with back in February. After milling the window and rathole, we ran in hole with our liner drilling BHA and got to bottom but were unable to make any hole. We decided to trip for a new BHA and on the way out of hole we became stuck at 9354' MD, unable to move up or down. We dropped a 5/8" ball and released off the liner drilling BHA leaving a bit, motor, 8jts of tubing, and a sealbore deployment sleeve in the 4-1/2" tubing. We then made a cleanout run and started into fishing operations. After several days of fishing, we were unsuccessful in getting our GS latched into the fish neck profile. Yesterday we made the decision to rig down and move to our next well 1C-19 while further diagnostics will be performed with wireline off -rig. We plan on submitting a 10-404 and 10-407 to close out the whipstock sundry and PTD. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 Loepp, Victoria T (CED) P TP a 61 o� � From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Thursday, June 20, 2019 2:27 PM To: Loepp, Victoria T (CED) Cc: Ohlinger, James J Subject: 1J-10 (PTD 201-071, Sundry 319-030) Operations Update Attachments: KRU 11-10(PTD 201-071, Sundry 319-030) Close out whipstock sundry; 11-10 R2 Final CTD Schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, CDR3 rigged up on 1J-10 (PTD 201-071) on June 121h to re -attempt a liner drilling project we were unsuccessful with back in February. After milling the window and rathole, we ran in hole with our liner drilling BHA and got to bottom but were unable to make any hole. We decided to trip for a new BHA and on the way out of hole we became stuck at 9354' MD, unable to move up or down. We dropped a 5/8" ball and released off the liner drilling BHA leaving a bit, motor, 8 jts of tubing, and a sealbore deployment sleeve in the 4-1/2" tubing. We then made a cleanout run and started into fishing operations. After several days of fishing, we were unsuccessful in getting our GS latched into the fish neck profile. Yesterday we made the decision to rig down and move to our next well 1C-19 while further diagnostics will be performed with wireline off -rig. We plan on submitting a 10-404 and 10-407 to close out the whipstock sundry and PTD. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1J-10 Permit to Drill Number: 201-071 Sundry Number: 319-253 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.2767542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner K DATED thisZ2day of May, 2019. RBDMSL±-J MAY 2 3 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 0D79_N11111 Y.Ti1 RECEIVED MAY 16 2n19 A(1nrIr 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: COM B Whipstock ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑' • Stratigraphic ❑ Service ❑ 201-071 3. Address: 6. API Number: PO Box 100360, Anchorage, AK 99510 50-029-23010-00 -� 7. If perforating: 8. Well Name and Number: S• / 7 It What Regulation or Conservation Order governs well spacing in this pool? N/A KRU U-10 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25660 ADL2-S-L4/ss r� r9 Kuparuk River Oil Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): - ✓ 10,845' 6326' 10,843' 6324' 2315 WA 10,326' Casing Length Size MD TVD Burst Collapse Structural Conductor 85' 20" 120' 120' Surface 6911' 9-5/8" 6945' 3995' Intermediate Production 10,199' 7" 10,231' 5944' Liner 876' 4-1/2" 10,843' 16325' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10446'-10466',10658-10678' 16073'-6085',6205'-6218' 4-1/2" L-80 9992' Packers and SSSV Type: Packer (Baker ZXP Liner Top Packer) Packers and SSSV MD (ft) and TVD (ft): Packer (998575798') 12. Attachments: Proposal Summary ❑� Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 28 -May -19 - OIL ❑� - WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Ryan McLaughlin Authorized Title: Staff CTD Engineer Contact Email: Ryan. MCLau hlin c0 .Cort/ �Z _ � Contact Phone: 265-6218 (�/%� Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: l✓, '✓1 Plug Integrity ❑ BOP Test M/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,8l71J �t��j �— ya 35067 i1J3t �nn✓/crrrpr�vrnf`rr >�rSf i'a ?5l�o�s y�� 3BDMS c� MAY 2 3 2019 Post Initial Injection MIT Req'd? Yes ❑ No �. Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY // Q Approved by: C MISSIONER THE COMMISSION Date: !/ ` / � 122 V71— 517/ / Form 10-403 Revised 4/2077 Aqproetl applica n MIJQ, 2 Rk the date of approval. Submit Form and Attac ments in Duplicate ,fRr r9 5 /7 y PAP ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 15, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner j ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set a whipstock in the KRU 1J-10 (PTD# 201-071). Attached to this application are the following documents: - 10-403 Sundry Application for KRU 1J-10 - Operations Summary in support of the 10-403 Sundry Application Proposed Pre -CTD Schematic - Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 11-10 (PTD# 201-071) Summary for Sundry Background KRU Well 1J-10 is a Kuparuk producer equipped with 4-1/2" tubing and 4-1/2" production liner. The project targets stranded C -Sand resource to the south and east of 11-10 into an area along the C -Sand margin south of existing production and injection. This project will involve drilling four CTD laterals from the 1J-10 parent " wellbore. The first lateral will kickoff from a mechanical whipstock set inside the 4-1/2" liner at 10,280' and will drill out 200' from the motherbore to straddle the Kalubik shale with Northern Solution's Liner Drilling BHA. The subsequent three laterals will target the Kuparuk C4 sand package with access gained from the 1J-101-1 lateral. Pre -CTD Work 1. RU CTU: Perform Fill Cleanout down to whipstock setting depth 2. RU E -line: Set 4-1/2" monobore whipstock at 10,280' MD - 3. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 11-101-1 Lateral (Straddle the Kalubik w/Liner Drilling BHA) — PTD 219-012 a. Mill 3.80" window at 10,280' MD b. Drill 4-1/4" lateral with ORCA liner drilling BHA to TD of 10,500' MD. c. Hydraulically release off 3-1/2" liner drilling BHA leaving TOL at 10,200' MD 3. 11-101-1-01 Lateral (C4 sand - southeast) — PTD 219-013 a. Set top of whipstock in 3-1/2" drilled in liner at 10,420' MD b. Mill 2.80" window at 10,420' MD c. Drill 3" bi-center lateral to TD of 15,200' MD. d. Run 2-3/8" slotted liner with aluminum billet from TD up to 12,300' MD. 4. 1J -10L1-02 Lateral (C4 sand -south) —PTD 219-014 a. Kickoff of the aluminum billet at 12,300' MD. b. Drill 3" bi-center lateral to TD of 14,775' MD. c. Run 2-3/8" slotted liner with aluminum billet from TD up to 12,150' MD. 5. 11-10L1-03 Lateral (C4 sand -east) —PTD 219-015 a. Kickoff of the aluminum billet at 12,150' MD. b. Drill 3" bi-center lateral to TO of 14,100' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TO up to 10,400' MD. 6. Freeze protect, NO BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 7. Obtain SBHP. 8. Return well to production. IJ-10 Proposed CTD Schematic @'jl 120' MDQ shce 9-5/8" 40# L-80 shoe @ 6945' MD 7" 26# L-80 shce @ 10231' MD KOP @ 10.280' MD _ KDP @ 10.420' MD KOP @ 10,301' MD \ C-sand Peds 10446' -10466' MD -sand perfs 110658'- 0678' MD 41/2" 12.69 L-80 shoe @ 10,843' MD 3-1/2" Camco DM nipple @ 5D6' MD (3.875' min ID) 41/2" 12.6# IBT ELIE 8rd Tubing to surface 41/2" Camco gas lift mandrels @ 41/2" Camco DB landing nipple @ 9933' MD (milled 3.87' min ID) Baker 41/2" GBH -22 Locator Baker Seal assembly @ 9980 MD (3.958" ID) Baker Packer 8 Tie -Back Sleeve Baker ZXP Liner Top Pecker @ 9985' MD (4.438" ID) Baker Liner Hanger Camco D -Nipple @ 10,328' MD (milled 3.87" ID) FISH @-10,400' MD: Perf Gun Otis XN-Nipple @ 10,521' MD (milled 3.725" ID) Northern Solutions - ORCA Liner Drillinu BHA Liner Hanger 3-1/2" 9.3# L-80 Hyd511 111OL1-03 wp01 TOg-16,1W MD Tailor Dnor �10;4W'MD 1110L1-01 xp02 @�-15.20a MD 7mWpr B4M 12,300'MO 111004i2yp1 D@-14,775'MD Top olaeal @ 12,150' MD KUP PROD WELLNAME 1J-10 WELLBORE 1J-10 Cw iffips 'Il Attributes Max Angle 8 MD TD Alaska.IRC. Fkld Name We11Gorc APINVA KUPARUK RIVER UNIT 500292301000 WeNMre Status ncl l') MDIXK91 Ent roo PROD ).58 3.10161 10,845.0 Lanment HSS 1ppr) Dow Annowscur Ena Oate K6GM ntI Rp nowns, pine SSSV: NIPPLE 40 0102016 Ldst"i 2/812008 35.74 W2412WI U10.11q Sudinge N:rd PM Last Tag Miniotl4nmslashouep Annonalow Deli End Dete 1Wellhrre lsatMM By -- Last Trig: RKB 10.348,0 I 32]200 1.740 ipprowen I HAxpER, ma Last Rev Reason Annotation End Dab waw. Unumon By Rev Reason: Set Whipstock 2/)12019 1110 famaj Casing Strings LY Deecripllon oD1in) m(nl Tw'I CONDUCTOR 20 19.12 350 - Kel sA3epIn 111x0) set down RMDl-- WWen O... O,aee Top Tmeae 120.0 120.0 9150 H-40 IWELDEO Cacmp Descnpliw OD(inl MT. Two 01%81 Set Dell "..) got Canada Mot W1M1en(I Grade Tap Tnreb SURFACE 9518 8.83 34.5 6,945.3 3,995.4 40.00 480 BTC fAN WCTOPI S.D110.0 Casing descriptionOp(In) ID lin) TopmKSl SN pepIM1 IRKBI Set OeplM1 jlVD)... Whim a. -Brad. Top TII1NY PRODUCTION ] fi.28 317 10,230.8 5.414.1 2fi.00 LEO BTC -MOD Casing DescriptionOD (in) ID (in) Top LINER 412 396 9.9fi7.2 "i5<I OepIn muh) sH deptn flw... WainIL.. Gude Top TM1reoe 10.843.11 6,324] 1260 L-80 NSCT NIPPLEgeli Liner Details Ten MKBI To p(Np )MNBI Tcp hrfJ l•) Na( inti Item Oes Com (in) nnt 9.987.2 5787.0 53.74 TIEBACK BAKERPA KERB TIE -BACK SLEEVE 4.438 ces.1,, arae 9,985.2 5,797.6 53.6] PA KER BAKER ZXP LINER TOP PACKER 4,438 9,989.2 5,800.0 53.6 HANGER BAKER LINER HANGER 4.500 111 6,0017 53.86 NIPPLE CAMCO -D' NIPPLE -DRILLED OUTT03,BT 3,830 DURING ATTEMPT TO PULL FISH 2/8/2008 .01i WORK(VER 10,5207 6.11. 51 Al NIPPLE OTIS'XN'NIPPLE wINo Go, 3.812' PRO BORE 3.725 3.725"profile Tubing Strings Tuning B<ecantmn string Ma._1DIinI TopinKe) TUBING 4112 396 29.fi Sal Depin ln_sel Depm llwlL.. WtII1L11I crag. rup eonn<clmn 09917 5.801.5 12.60 L-80 IBT VARACE: 3e48saws- Completion Details Des urT: e.msa TopIND) TIN lxl TOP Lo(RKDI () hem Ms Humnal Com 10(n) 29.6 29.6 0.01 HANGER FMCGENVTUSING HANGER 4.500 SOBS 508.0 1.97 NIPPLE CAMCO DRE NIPPLE 113.8]5 TOP NOGOaR FILE 3. 9.933.4 5,767.0 53.86 NIPPLE CAMCO DB NIPPLE w) 3812 PROFILE- DRILLED OUT TO 3.87 3.830 Dee uFr: RIa26 DURING ATTEMPT TO PULL FISH 2182008 WORKOVER 49]87 5.793.8 53..70 LOCATOR BAKER GBH -22 LOCATOR 3.958 9,979.9 5.79d.5 53.69 SEALASSY BAKER SEAL ASSEMBLY.. MULESHOE 3.958 rats urr, s.ndz.z Other In: )VYlreline retrievable plugs, valves, pumps, fish, etc.) TWFL) "m al T10.30 (S98 (3. Can Com Runn019 ID (.a) 10.3010 5,986.0 53.88 WINDOW P01 Wi10L1PB Wonand 2/1)/2019 0.000 lot amo4.led, a d10 jwe our ofletlthe 1J-1UL1PB1 and INl a minor, b8, end 12 jour oniner on NIPPIE: 991 61 b011om. 10,326.0 6,000) 53.88 FI H PERFGUN GUN 063'; 3/02008 W, KE LENGTH MAN OD 14532', LENGTH 34.4', MAX OD WORKED TO SHUT ELL TIN BF RETRIEVED. FEZE PROTECTED. 36'BAT SUB LEFT ON TOP OF FELINE BAT SUB LEFT ON IN TOOL LOCATOR: asm] 1020M TFish Pulled u litri 12'CTMD 1/19/20'. Termed Fish @ 10339' RKB SEM4sv: n.wsa AL 11192208 TaggedR TO 10301' SSM 0 WORKOVER TO PULL FISH -ONLY PUSHED IT DO IT DOWNHOLE FROM 10312TO 104011' Perforations & Slots snot Den Too ('o 8'."IN lana151n Tons MKB) atm rim.) IflK8I ME) Llnkee acne Dale I Type fqm sonwas T.N..m.7-losing- 10,446,0 10.4fifi.0 6,0]2.7 6,084.9 Ca, 1110 )/19201 6.0 APERF 3 SAO PSD PJ dings, 60' ph wmodhi lo.sme 14658.0 W618.0 6,205.0 8.217.BAS, LED) 0122001 I 6.0IPERF 12.Y HSD BH B DP Frac Summary stmt was W162001 PropWntdaslgnM 0b1 Prappmtln Formxim lib) New. 10 torso si Sfml peb Tap CepM di Bim beat 1 W1s2001 10,650.0 10,678.0 unkbinon'Wm vaaessi warignry(hof Mandrel Inserts Ad N Top(N➢) Top(i rfdf Make Mvlel Wlw Ia1cM1 PodsW TRORun OI Sery ryTr. Type 9nI INg I Run dXe I Com 1 3,723.8 2.558A CAMCO ji,zhurz I 1 GASUFT GLV BK BASS 1,246.011212019 4:30 2 6.311.7 3723.0 CAMCOKBG21 GAS LIFT OV 8K 1 0.250 0.0112012019 730 3 8,068.2 4,62).0 CAMCO HBG -2 i GAS LIFT DMY line, IO.110 0.0 329200 5:00 4 9,132.6 5,283.0 CAMCO 1BG-2 1 GA,, UrI DMY 8K I 0.00 0.0 512312001 4'.15 Ll LINER: IO.aa.O-IOeTa.o 5 9,8822 5.]36.8 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 21912014 700 I Notes: General & Safety .End APER,', 1. ew.0.4680 Data Mr.. 210Aid, NOTE: WORKOVER DONE TO PULL FISH, MILLED NIPPLES: UNSUCCESSFUL. PUSHED FIB. DOWNHOLE 3202019 NOTE: Lot. our, bit, and half a joint of liner On MYlom in IJ70LI PB1 IPERE. 10,dss.010.519.0 F(tAC 10.849.0 LINER, s,s4]3-10.843.0- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS C P'T'T MA' 20jg 1. Operations Abana 'lug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown []` Performed: Suspj]3 Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program Plug for Re❑II forate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CO261B WHIPSTOCK❑, 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number. Name: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic ❑ Exploratory ❑ Service ❑ 201-071 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23010-00 7. Property Designation (Lease Number): 8. Well Name and Number. KRU 1 J-10 ADL 25660, ADL 25651 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,845 feet Plugs measured None feet true vertical 6,326 feet Junk measured 10,326 feet Effective Depth measured 10,843 feet Packer measured 9,985 feet true vertical 6,324 feet true vertical 5,798 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 85 feet 20 120' MD 120' TVD SURFACE 6,911 feet 95/81, 6,945' MD 3995' TVD PRODUCTION 10,199 feet 7 10,231' MD 5944' TVD LINER 876 feet 4 1/2 " 10,843' MD 6325' TVD Perforation depth: Measured depth: 10446-10466. 10658-10678 feet True Vertical depth: 6073-6085. 6205-6218 feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 9,992' MD 5,801' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER ZXP LINER TOP PI 9,985' MD 5,798' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: WA - - - - Subsequenttooperation: NIA - - - - 14. Attachments (required per 20 Me 26.070, 25.071, a 25 283) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development 71 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-030 Contact Name: Ryan McLaughlin Authorized Name: Ryan McLaughlin Contact Email: Ryan.McLaughlin@cop.com Authorized Title: CTD Engineer / Contact Phone (907) 265- 6218 �S Authorized Signature: Date: Form 10-404 Revised 4/2017 vn- S/zl /11 /* f 00 RBDMSMAJ MAY 15 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 14, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: While drilling the 1J -10L1 lateral with our Liner Drilling BHA, we became stuck in the Kalubik at a depth of 10,362' MD. We dropped a ball to release off of our liner drilling BHA, then proceeded to rig up E -line to make a chemical cut at a depth of 10,330' MD. After a successful cut was made, we pulled the liner drilling BHA out of hole to a depth of 10,330' MD leaving the rest of the fish in hole (20' of liner, motor, drill bit). After this we ran in hole and pulled the whipstock that was set at 10,301' MD and cleaned the hole out to a depth of 10,326' MD. The plan forward was to set a patch over the window that was milled at 10,301' MD and return the well to production in the interim between coming back and making another attempt to drill the permitted laterals. A 10- 404 was to be submitted after a successful patch set to close out the sundry. However, efforts to set a patch over the window were unsuccessful and consequently, the well was never brought online. We are submitting the 10-404 now along with the documents outlined below, and a new sundry will be submitted to set another whipstock and drill the 1J-10 project under the current permits. Attached to this application are the following documents: - 10-404 form for Sundry 319-030 - Current Wellbore Schematic - Daily Drilling Reports - Well Service Reports for attempted patch setting - Email correspondence with Victoria Loepp If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin ConocoPhillips Alaska Coiled Tubing Drilling Engineer U-10 Proposed CTD Schematic 20" 91.5# H-40 shoe @ 120' MD 9-5/8" 40# L-80 shoe @ 6945' MD 7" 26# L-80 shoe @ 10231' MD KOP @ 10,301' MD C -sand parts 10446' - 10466' MD sand perfs 10658' -10678' MD 4-1/2" 12.6# L-80 shoe @ 10,843' MD 3-1/2" Camco DB -6 nipple @ 508' MD (3.875" min ID) 4-1/2" 12.6# ST ELIE 8rd Tubing to surface 4-1/2" Camco gas lift mandrels @ 3724', 6312', 80681, 9133', 9882' 4-1/2" Camco DS landing nipple @ 9933' MD (milled 3.87" min ID) Baker 4-112" GBH -22 Locator Baker Seal assembly @ 9980' MD (3.958" ID) Baker Packer & Tie -Back Sleeve Baker ZXP Liner Top Packer @ 9985' MD (4.438" ID) Baker Liner Hanger Camco D -Nipple @ 10,328' MD (milled 3.87" ID) FISH @ -10,326' MD: PerfGun Otis XN-Nipple @ 10,521' MD (milled 3.725" ID) Northern Solutions - ORCA Liner Drilling BHA Left in Hole Liner Hanger 3-1/2" Liner (19.9') Burst Disc Sub (0.75') XO (0.5') 2-7/8" Motor (10.58') 3-3/4" Bit (0.52') R 1P61 -10,362' MD FISH @ -10,330' MD Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Eno Time Dur (hr) Phase Op Ccde Adivity Code Time P -T -X Operation Start Depth (MB) End Depth (WB) 2/10/2019 2/10/2019 2.00 MIRU MOVE DMOB P Continue RDMO from 3S-08, load out 0.0 0.0 17:00 19:00 DTH trucks, secure rig landings and stairs, secure cellar, Peak arrives on site at 19:00 hrs 2/10/2019 2/10/2019 4.00 MIRU MOVE DMOB P Load up shop & 112 -Way house, hold 0.0 0.0 19:00 23:00 PJSM with rig / Peak team. Pull off well. Install Jeeps. Rig down cellar area 2/10/2019 2/11/2019 1.00 MIRU MOVE MOB P Move from 3S -Pad to 1J -Pad (25.4 0.0 0.0 23:00 00:00 miles) 2/11/2019 2/11/2019 4.35 MIRU MOVE MOB P Continue moving rig to 1J -Pad 0.0 0.0 00:00 0421 2/11/2019 2/11/2019 5.40 MIRU MOVE MOB T Field went to phase 3 driving 0.0 0.0 04:21 09:45 conditions. park rig at KCS Y (15.4 mile), standby for weather, Phase condtions lifted, send grader and blower to 1J -pad to confirm clear of snow. 2/11/2019 2/11/2019 4.25 MIRU MOVE MOB P Continue moving rig to 1J -Pad 0.0 0.0 09:45 1400 (stopped at KOC for fuel) 2/11/2019 2/11/2019 2.50 MIRU MOVE MOB P Arrive on 1J -Pad 14:00 hrs, drop off 0.0 0.0 14:00 16:30 jeeps, sub & pits spotted, mats laid (-50 min to lay mats for sub & pits) 2/11/2019 2/11/2019 4.00 MIRU MOVE MOB P DTH on location rig up tiger tank and 0.0 0.0 16:30 20:30 hardline (air-test/good-test), Continue RU checklist, hook up PUTZ, hook up steam, drop stairs & landings, spot shop & half -way house 2/11/2019 2/11/2019 1.00 MIRU MOVE MOB P Complete RU checklist, energize 0.0 0.0 20:30 21:30 Koomey, unlock injector & reel, begin MU tigertankhard-line, grease tree & tangos, grease Romeo & Bravo valves 2/11/2019 2/12/2019 2.50 MIRU WHDBOP NUND P Nipple up BOP, grease crew on 0.0 0.0 21:30 0000 location, service tree valves. "' Note: Rig Accept 2/11/19 @ 21:30 Pun 2/12/2019 2/12/2019 0.60 MIRU WHDBOP NUND P Complete prep for BOP test 0.0 0.0 00:00 00:36 2/12/2019 2/12/2019 0.90 MIRU WHDBOP PRTS P PJSM, fluid pack, & shell test, good 0.0 0.0 00:36 01:30 2/12/2019 2/12/2019 1.50 MIRU WHDBOP BOPE T Begin BOP test, good test on test 1, 0.0 0.0 01:30 03:00 though continue to see pressure when bleeding off, observe gas through night cap, trouble shoot master & SSV, function SSV open and closed, re -fluid pack stack, taking to tiger tank, close swab to check for pressure build at tangos, good, carry on w/ test " 250 psi low / 3500 psi high (witness waived by Bob Noble ofAOGCC) 2/12/2019 2/12/2019 6.10 MIRU WHDBOP BOPE P Continue w/ BOP test, fail/pass on 0.0 0.0 03:00 0906 test #13, draw -down test 2/12/2019 2/12/2019 1.00 MIRU WHDBOP BOPE P Flud pack coil, reverse circulate, lest 0.0 0.0 09:06 10:06 inner reel valve 2/12/2019 2/12/2019 1.10 MIRU WHDBOP PRTS P Pop off injector, PT PDL's & tiger -tank 0.0 0.0 10:06 11:12 line 2/12/2019 2/12/2019 0.40 SLOT WELLPR OTHR P clear Floor 0.0 0.0 11:12 11:36 2/12/2019 2/12/2019 1.40 PROD1 RPEQPT PULD P PJSM, PD BHA#1 Coil -Trak wl 0.0 43.0 11:36 13:00 nozzle, slide in cart, install checks, MU to coil, tag up, set counters Page 118 ReportPrinted: 5/14/2019 . Operations Summary (with Timelog Depths) +�E U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Stan Depth (fiKB) End Depth(flKS) 2/12/2019 2/12/2019 2.00 FROM RPEQPT TRIP P RIH w/BHA #1 43.0 10,160.0 13:00 15:00 2/12/2019 2/12/2019 0.20 PROD1 RPEQPT DLOG P Log formation for-5' correction 10,160.0 10,186.0 15:00 15:12 2/12/2019 2/12/2019 0.30 FROM RPEQPT TRIP P Close EDC, PUW = 37K, continue 10,186.0 10,307.0 15:12 15:30 RIH, log Kt for -1' correction, tag TOWS at 10,307', PUW = 42K 2/12/2019 2/12/2019 0.70 FROM RPEQPT DISP P Continue flushing w/ seawater 10,307.0 10,280.0 15:30 1612 2/12/2019 2/12/2019 1.20 FROM RPEQPT DISP P Obtain SBHP 10,295.0 10,295.0 16:12 1724 MID bit= 10,295', TVD sensor - 5974.7'_, annular= 2882 psi, EMW = 9.29 ppg Decision made to reduce KWF to 10.8 ppg for BHA swap (no formation open at this point) 2/12/2019 2/12/2019 2.60 PROD1 RPEQPT DISP P Squeeze 150K -SRV pill followed by 10,295.0 2,000.0 17:24 20:00 10.8 ppg KWF to surface Losses started @ 0.5 bpm increased to 1.5 bpm, and lost returns @ - 2000 feet. *'Phase 1 @ 20:23 2/12/2019 2/12/2019 3.60 PROD1 RPEQPT DISP T Additional KW fluid called out earlier, 2,000.0 2,000.0 20:00 23:36 water truck needle for dilution of KW stuck on pad, Still Phase one. Roads & pads, extracted water truck, off loaded same. Built 9.5 ppg KW fluid. 2/12/2019 2/13/2019 0.40 PROD1 RPEQPT DISP P Online with 9.5 ppg NaBr to the coil, 2,000.0 2,000.0 23:36 00:00 filling hole, note 39 bbl coil volume all 10.8 ppg, 49 bbls away started seeing returns, waited until 9.5 ppg returns at surface. 2/13/2019 2/13/2019 0.80 PROD1 RPEQPT DISP P Waited until 9.5 ppg at surface, 2,000.0 2,000.0 00:00 0048 brought fluid back inside. 10.45 ppg and heavier EMW yealds zero returns. Density out staarting to drop, 9.5 ppg comming back. 2/13/2019 2/13/2019 0.40 FROM RPEQPT TRIP P Waited until 9.5 ppg at surface, 2,000.0 55.0 00:48 01:12 brought fluid back inside. 10.45 ppg and heavier EMW yealds zero returns. POOH 2/13/2019 2/13/2019 0.70 PROD1 RPEQPT PULD P LD BHA *1 over a dead well, on 55.0 0.0 01:12 01:54 vacuum, 2/13/2019 2/13/2019 1.00 PROD1 RPEQPT PULD P PU 4 joints of PH6, caped w nozzle 55.0 0.0 01:54 0254 and 2XO's, Nozzle-0.66', XO's-0.69/0.73', joints 1,2,3,&4 - 31.38', 31.36', 31.53', and 32.81'. 2/13/2019 2/13/2019 0.70 FROM RPEQPT CTOP P Pull UQC, cut and boot E-line, stab 55.0 0.0 02:54 03:36 onto PH6, Pump up to 2.5 bpm, listen for wire moving and stop. Repeated ramp to 2.5 bpm 3 more times no noise associated with wire movement. 2/13/2019 2/13/2019 1.00 PROD1 RPEQPT CTOP P Fill well to stump, flow check good, 55.0 0.0 03:36 04:36 unstab, pull wire, 132' retained, theoretical was 151'. Cut 8.5' of coil, cut a-line and reboot. BHA hand noticed flat spot on pipe, recut pipe and reboot a-line. 2/13/2019 2/13/2019 2.50 PROD? RPEQPT CTOP P Instal BH coil connector, pull test, 55.0 0.0 04:36 0706 I pressure test Page 218 Report Printed: 511412019 Operations Summary (with Timelog Depths) 1J-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (m) Please Op cotle Activity CMe Time P-T-X Operation Start Depth (WB) End Depth (fiKB) 2/13/2019 2/13/2019 0.50 PROD1 RPEQPT CTOP P Pull 4 jnts PH-6, run nozzle & 1 jnt PH 0.0 0.0 07:06 07:36 -6 in hole, stab on injector, prep to pump ball 2/13/2019 2/13/2019 0.70 PROD1 RPEQPT CTOP P Drop ball, close & pressure up on IRV 0.0 0.0 07:36 08:18 to 3000 psi, open IRV, bring on pumps to 2.5 bpm, pump 1.5 coil volumes Order 50 sacks Poly Swell to rig 2/13/2019 2/13/2019 0.80 PROD1 RPEQPT CTOP P Popoff, LD PH-6 jnts, additional 32' of 0.0 0.0 08:18 09:06 slack pumped forward, retireved ball from nozzle, good test on a-line, cut a- line, epoxy & protect tag end 2/13/2019 2/13/2019 1.40 PROD1 WHPST PULD P PJSM, PU BHA #2 Window Assembly 0.0 245.0 09:06 10:30 2/13/2019 2/13/2019 0.90 PROD1 WHPST DISP T Displace coil to milling fluid 245.0 245.6- 10:30 1124 2/13/2019 2/13/2019 1.50 PRODi W HPST WAIT T Wait on Poly Swell to dg 245.0 245.0 11:24 12:54 Establish pressures at various rate: 1 bpm: circ = 196 psi, WHP = 182 psi 1.5 bpm: circ= 282psi WHP = 305 psi 2 bpm: circ =415 psi, WHP = 396 psi 2.5 bpm: circ = 534 psi, WHP = 521 psi 2/13/2019 2/13/2019 1.10 PRODi WHPST CIRC T Fresh water arrives at rig, PolySwell 245.0 245.0 12:54 14:00 arrives at rig, add sacks of KCI, add sacks of PolySwell, mix 2/13/2019 2/13/2019 1.50 PROD1 WHPST CIRC T Begin pumping pill, low efficiency on 245.0 245.0 14:00 15:30 pump #2, unable to get pill pumping, pull screen on pump $#1, pumping pill @12.3 bpm, pill at top of perfs (circ = 699, WHIP = 731) 2/13/2019 2/13/2019 0.90 PROD1 WHPST CIRC T Squeeze away 10 bbl at .75 bpm, 245.0 245.0 15:30 16:24 shutdown pumps allow to swell for 45 min " 192 total pumped leaves 2 bbl above TOWS 2/13/2019 2/13/2019 0.60 PROW WHPST CIRC T Squeeze 5 more bbl's @.5 bpm, wait 245.0 245.0 16:24 17:00 2113/2019 2/13/2019 1.70 PROD1 WHPST CIRC T Squeeze away remaing poly swell, 245.0 245.0 17:00 18:42 leaving 2 bbl above TOWS, wait 2/13/2019 2/13/2019 1.80 PROD1 WHPST TRIP P RIH, min rate down the coil, targeting 245.0 10,247.4 18:42 20:30 1 for 1 returns. Some poly swell back at the shaker causing choke issues, had to take -2 bbls outside, gas back 2/13/2019 2/13/2019 0.30 PROD1 WHPST DLOG P Tie into flag for +6.7' correction. PU Wt 10,247.4 10,312.0 20:30 20:48 42k lbs, RIH, dry tag TOW @ 10312.39' 2/1312019 2/13/2019 1.10 PROD1 WHPST CIRC P Increase rate to 10,312.0 10,147.0 20:48 21:54 1 bpm down coil, full returns, WH 19 psi, CT 1819, 2 bpm down coil, 1.9 bpm out - WH 23 psi, CT 3091' 2.6 bpm in, 2.48 bpm out - WH 37 psi, CT 4150 psi, - Circulate bottoms up, large amount of poly swell returned to the shaker, over flowed, lost +/-60 bbls to the cuttings pit. Returns cleared up post bottoms up. 2/13/2019 2/13/2019 0.30 PROD1 WHPST TRIP P RBIH, 10,147.0 21:54 22:12 Page 318 Report Printed: 5,q/14/201 AL Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phew Op Code Activity Code Time PJA Operation (ftKB) End De" (flKS) 2/13/2019 2/14/2019 1.80 PROD1 WHPST WPST P Tag up w/ top of whipstock@ 10,311.3 10,313.5 22:12 00:00 10,311.3', Free spin CT 3750 psi, WH 178 psi, CT Wt 15 k lbs. Flag pipe at the horses head, start feeding tenths, - 1' /hr , with average 240 psi motor work. 2.61 bpm in 2.50 bpm out. 2/14/2019 2/14/2019 2.50 PROD1 WHPST WPST P Continue to mill exit window. 2.6 bpm 10,313.5 10,315.5 00:00 02:30 in 2.5 bpm out, CT free spin 3750 psi, allowed CT wt to drop to 11 k lbs and CT pressure to climb to 4100 psi - 350 psi motor work. Parked for - 13 min, CT pressure fell off rapidly to 4000 psi and CT weight climbed to 12.6 k lbs. reengaged the stick, mill ahead, WH 168 psi. 2/14/2019 2/14/2019 2.00 PROD1 WHPST WPST P Increase ROP to 1.2 Win. 2.6 bpm in, 10,315.5 10,318.0 02:30 04:30 2.54 bpm out, WH 170 psi, Ct 3800 psi, CT Wt 13.5 k Itis. 2/14/2019 2/14/2019 2.00 PROD1 WHPST WPST P Continue milling window, CWT= 10,318.0 10,320.2 04:30 06:30 12.5K, circ = 3811 2.6 bpm in, 2.53 bpm out 2/14/2019 2/14/2019 3.00 PRODt WHPST WPST P Milling window, CWT = 12.7K, circ = 10,320.2 10,323.5 06:30 09:30 3828 psi, WHP = 172 psi, approx 10.07 ppg assuming 25 psi/1000' frictional pressure loss, mill exits bit - 10323.4' 2/14/2019 2/14/2019 1.30 PRODt WHPST WPST P Milling window, CWT = 13.1 K, circ = 10,323.5 10,325.0 09:30 10:48 3932 psi, WHP = 172 psi TOW = 10,311.3', BOW = 10,323.4' 2/14/2019 2/14/2019 2.40 PROD1 WHPST WPST P Begin pushing on it, milling rat -hole, 10,325.0 10,336.3 10:48 13:12 CWT = 10.7K, circ = 4115 psi, WHP = 172 psi, pump 5x5 sweeps 2/14/2019 2/14/2019 0.60 PROD? WHPST REAM P Begin reaming, up -hole, PUW=37K 10,336.3 10,305.0 13:12 13:48 2/14/2019 2/14/2019 1.10 PRODi WHPST CLOG P PUH to 10,305', trap 580 psi WHP 10,305.0 10,305.0 13:48 14:54 (EMW of -10.3 ppg), shut down pumps, allow WHP to drop, confer w/ town, decision made to kill well w/ 9.9 ppg KWF SBHP: WHP = 252, EMW = 9.6 ppg, still dropping 2/14/2019 2/14/2019 2.00 PROD1 WHPST REAM P Continue reaming passes (3 up & 3 10,305.0 10,305.0 14:54 16:54 down total), dry drift window up & down clean, PUW = 40K 2/14/2019 2/14/2019 3.00 PROD1 WHPST CTOP P Transfer and build 9.9 ppg KW fluid. 10,305.0 10,264.0 16:54 19:54 2/14/2019 2/14/2019 0.70 PROD1 WHPST DISP P Start pumping KW to the coil 10,264.0 10,282.0 19:54 20:36 2/14/2019 2/14/2019 1.60 PROD1 WHPST DISP P POOH laying in 9.87 ppg KW and 10,282.0 256.0 20:36 22:12 painting flags Park @ 10142.43 and paint a red flag and again @ 10047.39' red and white candy cane. Continue to POOH. 2/14/2019 2/14/2019 1.20 PROD1 WHPST PULD P Park, flow check - good, slight vac. 256.0 256.0 22:12 23:24 LD BHA #2 over a dead well, Retrieved and cut off an additional 60' of a -line. Meg wire -greater than 2000 ohms, good test. Skid cart. 2/14/2019 2/15/2019 0.60 PROD? WHPST PULD P Fluid still in the stack. Lay down BHA 256.0 0.0 23:24 00:00 #2 Speed mill and string reamer 3.80" go 3.79" No go Page 418 ReportPrinted: 511412019 Operations Summary (with Timelog Depths) ii -10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Our (hr) Phase Op code ACbV@/Code Time PJTX Operation start Depth (WS) End Dep@ME) 2/15/2019 2/15/2019 1.90 PRODt DRILL CIRC P Boot wire, install side jet nozzle, stab 0.0 0.0 00:00 01:54 on, tum coil over to milling fluid, shelter time to chink bomb bay doors, jetting the stack. 2/15/2019 2/15/2019 3.40 PRODi DRILL PULD P Pop off, PU BHA #3, drilling liner, 0.0 0.0 01:54 05:18 2/15/2019 2/15/2019 2.50 PROM DRILL TRIP P RIH w/BHA#3, correct+4.3'to pipe 0.0 10,230.0 05:18 07:48 flag, PUW = 39K 2/15/2019 2/15/2019 1.50 PROD1 DRILL DISP P Displace well to drilling fluid @ 1.5 10,230.0 10,230.0 07:48 09:18 bpm, bring rate up to 2.0 bpm, circ = 4144 psi, WHIP = 19 psi (choke wide open), 2/15/2019 2/15/2019 0.20 PROD1 DRILL TRIP P Shut down pumps, RIH 20 fpm 10,230.0 10,336.0 09:18 09:30 through window, at 10,330' bring rate up to 2 bpm, FS = 4105 psi, begin drilling at 10,336' 2/15/2019 2/15/2019 1.50 PROD1 DRILL DRLG P Drilling, FS = 4105 psi, circ = 4277 psi, 10,336.0 10,356.0 09:30 11:00 CWT = 12.7K, 1.98 bpm in, 1.94 bpm out, choke open, stall at 10,343', PUW = 41 K, continue drilling ahead 2/15/2019 2/15/2019 1.80 PROD1 DRILL DRLG P Drilling, CWT =9.85K, circ =4207, 10,356.0 10,356.0 11:00 12:48 -100% returns, begin stacking weight, though no increase in motor -work, slacking pipe in hole, PU to breakover, PUW = 43K, zero rip counter, again stacking weight @ 10,356', atempt again, PUW = 43K, again stack weight at 10,356', PUW = 47K Confer w/ town, decision made to PU 10' (full rate), PUW = 50K, no success, make multiple attempts. Appear to be hitting bottoms though no motor -work 2/15/2019 2/15/2019 1.70 PROD1 DRILL CIRC T Thaw product, build 50 bbl Drilzone 10,356.0 10,356.0 12:48 1430 pill for potential bit balling 2/15/2019 2/15/2019 0.60 PROD1 DRILL CIRC T Begin pumping 25 bbl Drilzone pill, 5 10,356.0 10,356.0 14:30 15:06 bbl mud spacer, follow by 25 bbl Drilzone, bit just off bottom, PU & go to drilling 2/15/2019 2/15/2019 1.90 PROM DRILL DRLG T Drill ahead to 10,361'& stall, PUW = 10,356.0 10,380.0 15:06 17:00 43K, continue drilling ahead. Circ = 3941 psi, open choke, 99% returns, 15 -20 fph, -100 psi motor -work, again begin to stack weight, building 30 bbl Drilzone, PUW = 42K 2/15/2019 2/15/2019 0.60 PROD1 DRILL DRLG T Stacking coil weight and not making 10,380.0 10,377.0 17:00 17:36 hole. PU to 10,369', Ct Wt 40.6 k lbs, 4 more pick ups to get restarted with decreasing PU weight. Restarted, drilling ahead slowly with pickups to 10,377' where the motor stalled. 2/15/2019 2/15/2019 1.20 PROD1 DRILL DRLG T Unable to Pick up after stall, Pull up to 10,377.0 10,377.0 17:36 18:48 70 k Ids, bleed coil back to 0. work pie, work CT pressure up to 2000 psi, work pipe to 70 k. No movement, no indication of circulation. 2/15/2019 2/15/2019 0.70 PRODt DRILL DRLG T Dog house discussion, manually pump 10,377.0 10,377.0 18:48 19:30 up injector circuits. Cycle pipe up to 80k squatting up to -10 k, pulling speeds up to 100 ft/min, no movement. Consult w engineering. Work pipe to 90%- 90,000 lbs. squatting,varying running speed. no movement. Consult town again. Page 5/8 Report Printed: 5/1 412 01 9 r Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (MB) End Depth(%KB) 2/15/2019 2/15/2019 1.50 PROD? DRILL DRLG T Online with the pump in attempt to 10,377.0 10,377.0 19:30 21:00 shear the 2500 psi circ port above the motor. Well started taking fluid @ 0.4 bpm and 2800 psi. Worked pipe to 80k while pumping, no movement or indication burst disc burst. Increase rate to 2.5 bpm and 7000 psi. No indication of shear circ sub opening, no indication of the flow disconnect in the liner disconnecting. Start additional generator 2/15/2019 2/15/2019 0.60 PROD1 DRILL DRLG T Cycle rate to 3 bpm and 7000 psi 13 10,377.0 10,377.0 21:00 21:36 times with no indication of shear/ shift in liner running assembly. 2/15/2019 2/15/2019 1.30 PROD1 DRILL DRLG T PJSM, drop 5/8" ball, launch with 3100 10.377.0 10,288.0 21:36 2254 psi, hear indication of launch, chase @ 1.8 bpm, Ct 5500 psi, WH 200 psi. Cut rate with 26 bbls away to 0.45 bpm. @ 41 bbls away, surge rate from 0.25 bpm to 2.5 bpm. At 4340 bbls away, CT to 5800 psi, Walk pressure up to 7300 psi. after - 2 minutes saw pressure fall to 1300 psi. PUH to 10288 (technically 10086'), established circulation @ 2 bpm, CT 2763 psi, WH 246 psi. 7300 ""Top of fish - 10159' CTMD. 2/15/2019 2/16/2019 1.10 PROD1 DRILL CIRC T Park and reset counters after dropping 10,288.0 10,050.0 22:54 0000 off drilling liner Circulate bottoms up X2 while creeping up hole slowly. CT 2736 psi, WH 228 psi, 2.01 bpm in / 1.95 bpm out. 2/16/2019 2/16/2019 0.90 PROD1 DRILL CIRC T Continue to circulate bolooms up 10,050.0 10,720.0 00:00 0054 2/16/2019 2/16/2019 0.30 PROD? DRILL DISP T Pump 9.9 KW fluid to the nozzle 10,096.0 10,086.0 00:54 01:12 2/16/2019 2/16/2019 1.50 PROM DRILL DISP T POOH displacing well to 9.9 ppg KW 10,086.0 237.0 01:12 0242 fluid. full returns. 2/16/2019 2/16/2019 1.40 PROD1 DRILL PULD T LD BHA 3, less drilling liner left in 237.0 0.0 02:42 0406 hole. Hole fill <1 bbl/hr 2/16/2019 2/16/2019 7.70 PROD1 DRILL WAIT T Wait on a -line, 0.0 0.0 04:06 11:48 Confer w/ town, decision made to cut fish w/ chemical cutter at 10,325' 2/16/2019 2/16/2019 1.90 PROD1 DRILL ELNE T SLB a -line arrives at rig, PJSM, RU e- 0.0 7-0- 11:48 -2 1342 line, get tools to rig floor /16/20-19 2/16/2019 1.30 PROM DRILL ELNE T PJSM,PU a -line tools 0.0 0.0 13:42 15:00 2/16/2019 2/16/2019 1.00 PROD1 DRILL ELNE T RIH w/ chemical cutter, PUH to log K1, 0.0 10,330.0 15:00 16:00 arrive at cutting depth, make cut in 3.5" FlushMax pipe at 10,330' (CCL depth of 10,319', a -line tension drops from 1170 Ibf to 878 Ibf, wiat 5 minutes, RIH to release dogs 2/16/2019 2/16/2019 1.00 PROD1 DRILL ELNE T POOH w/ e -line 10,330.0 0.0 16:00 17:00 2/16/2019 2/16/2019 1.70 PROD1 DRILL ELNE T Lay ]own E -line tools and clear the rig 0.0 0.0 17:00 1842 floor 2/16/2019 2/16/2019 1.70 PROD? DRILL PULD T PJSM, PU BHA R4, fishing assembly. 0.0 236.0 18:42 2024 2/16/2019 2/16/2019 1.50 PROD1 DRILL TRIP T RIH, Ct PU Wt@ 10,099' CTMD 42 k 236.0 10,155.0 20:24 21:54 Ibs, PUH 37.5 k lbs. Page 618 Report Printed: 5/14/2019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (lir) Phase Op Code Activity Code Time P -T -X Operation Start Depth (WB) End Depth (fIX8) 2/16/2019 2/16/2019 0.10 PROW DRILL TRIP T Run into fish @ - 30 f lmin. Set down 10,155.0 10,155.0 21:54 22:00 on fish at 10155' CTMD. S/D ^ 3k lbs, PU to 50 k lbs, Fish on! Pull into 60k, Jar fired, pulled free, 2/16/2019 2/17/2019 2.00 PROD1 DRILL TRIP T POOH with fish. CT wt 38k lbs and 10,155.0 396.0 22:00 00:00 slowly dropping. 2/17/2019 2/17/2019 2.00 PROD1 DRILL PULD T LD BHA #4, fishing BHA. 396.0 165.0 00:00 02:00 2/17/2019 2/17/2019 1.00 PROD? DRILL PULD T LD flish, hanger assembly, and 6 full 165.0 710- 02:00 03:00 joints plus 1 partial cut jpint of 3.5: Flow Max. "' Left 61.00' offish in hole, partial 7.74' joint #2 3.5 Flush max, full 27.64' joint Flush Max, XO burst disc, motor and bit. 2/17/2019 2/17/2019 1.40 PROD1 DRILL CTOP T Clean floor, skid cart, no wire in site, 0.0 0.0 03:00 04:24 1 Stab on and pump slack back. 2/17/2019 2/17/2019 2.10 PRODi DRILL CTOP T Unstab, skid cart, pick up hydraulic 0.0 0.0 04:24 06:30 cutter, cut 296' of pipe to find a -line, cut additional 4' for a total of 300' cut 2/17/2019 2/17/2019 1.70 PROD1 DRILL CTOP T Bevel & ream pipe, install CTC, pull 0.0 0.0 06:30 08:12 test 2/17/2o 99 2/17/2019 1.30 PRODi DRILL CTOP T Install UOC & re -head a -line, pressure 0.0 0.0 08:12 09:30 test CTC test wire, greater than 1800 mega ohms and 69.5 ohms. 2/17/2019 2/17/2019 0.50 PROD1 DRILL CIRC T Pump coil volume forward @ 2.5 bpm 0.0 0.0 09:30 10:00 2/17/2019 2/17/2019 0.90 PR0D1 DRILL PULD T PU BHA#5 Nozzle, slide in cart, MU 0.0 53.0 10:00 10:54 to coil, tag up, set counters 2/17/2019 2/17/2019 1.90 PROD1 DRILL TRIP T RIH w/ BHA#5, begin sending drilling 53.0 10,280.0 10:54 12:48 fluid 2/17/2019 2/17/2019 0.20 PROD1 DRILL DLOG T Log K1 for -8' correction 10,280.0 10,299.0 12:48 13:00 2/17/2019 2/17/2019 1.30 PROD1 DRILL TRIP T Continue RIH &jog WS tray multiple 10,299.0 10,312.0 13:00 14:18 times, pumping 2 bpm (TOWS to 10,312'), pump two 5x5 sweeps 2/17/2019 2/17/2019 1.70 PROD1 DRILL TRIP T POOH, displacing to 9.9 ppg KWF, 10,312.0 53.0 14:18 16:00 flow check, good 2/17/2019 2/17/2019 0.50 PROD1 DRILL PULD T PJSM, LD BHA #5 (break off nozzle) 53.0 0.0 16:00 16:30 2/17/2019 2/17/2019 0.40 PROD? DRILL PULD T PU BHA#6 WS Fishing Assembly 0.0 66.0 16:30 16:54 (BOT hook), slide in cart, MU to coil, tag up, set counters 2/17/2019 2/17/2019 1.70 PROD1 DRILL TRIP T RIH w/ BHA#6 66.0 9,845.0 16:54 18:36 2/17/2019 2/17/2019 0.20 PROD1 DRILL DLOG T Tie into the K1 for a -2.5' correction 9,845.0 9,879.0 18:36 18:48 PU Wt 40 k lbs 2/17/2019 2/17/2019 0.70 PROD1 DRILL PULL T Continue to RIH, Wt check above WS 9,879.0 10,315.0 18:48 19:30 @ 10239'40 k lbs. RIH from 10300 to 10315'@ 5 ft/min cycle pipe across tray jetting with hook oriented neutrally @ 194, 190, 200, and 180 ° ROHS wile pumping 2 bpm, 1.8 bpm returns, 10.1 ppg EMW @ the window. PU above WS, orient hook to 14° ROHS. RIH, stack 2.5 k WOB @ 10309.9' PU, up to -3.0 k lbs WOB, broke back, suspect fish on, 2/17/2019 2/17/2019 2.20 PROD1 DRILL TRIP T POOH, orientertumed off, 90 ft/min 10,315.0 70.0 19:30 21:42 I 2/17/2019 2/17/2019 0.90 PROD1 DRILL PULD T Stand back upper BHA, LD fishing 70.0 0.0 21:42 22:36 I BHA and fish -(whipstock) Page 718 Report Printed: 5/1412019 o Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time EM Time Dur (hr) Phase Op Code Activity cme Time P -T -X Operation Stan Depth (MS) End Depth (WB) 2/17/2019 2/17/2019 0.70 PROD1 DRILL PULD T PU BHA#7 clean out assembly, 0 ° 0.0 62.5 22:36 23:18 motor with D331 bit, 2.7" no go. inspect pack offs, good. 2/17/2019 2/18/2019 0.70 PROD1 DRILL PULD T RIH 62.0 3,267.0 23:18 00:00 2/1812019 2/18/2019 1.10 PROD1 DRILL TRIP T Continue to RIH. 3,267.0 9,842.0 00:00 01:06 2/18/2019 2/18/2019 0.20 PROD? DRILL DLOG T Tie into Ki for + 6'correction 9,842.0 9,864.0 01:06 01:18 2/1812019 2/18/2019 0.20 PROD1 DRILL CIRC T Contine to RIH, milling fluid at the bit 9,842.0 10,329.0 01:18 01:30 @ 10302'. SID @ 10,329, stall, PU 42 k lbs 2/18/2019 2/18/2019 1.00 PROD1 DRILL CIRC T RBIH, 1.84 bpm in, 1.80 bpm out, free 9,842.0 10,326.0 01:30 02:30 spin 421 psi, 10.04 ppg EMW a@ the window. SID 10,326', stall, PU 42 k lbs. RBIH, start taking weight @ 10,325.96'. Motor work, no ROP, hard tag. 2/18/2019 2/18/2019 1.00 PR0D1 DRILL CIRC T Perform jetting passes from 10320 to 10,326.0 10,317.0 02:30 03:30 10300. Turn coil over to seawater 2!18/2019 2/18/2019 1.20 PROD1 DRILL DISP P Seawater at the bit, wash from 10300 10,317.0 4,436.0 03:30 04:42 to 10320 x2. POOH chasing seawater uphole. Park w 25 bbis of seawater above the bit, open EDC. POOH 2/18/2019 2/16/2019 1.30 PROD1 DRILL DISP P LRS, rigged up and PT'd to 4500 psi, 4,436.0 70.0 04:42 06:00 start pumping 40 bbis diesel to the coil @ 2 bpm, 4400 psi. 2/18/2019 2/18/2019 0.70 PROD1 DRILL PULD P PJSM, PUD BHA#7 70.0 0.0 06:00 06:42 " 395 psi SITP 2/18/2019 2/18/2019 1.50 DEMOB WHDBOP RURD P Jet stack, & sucked out, freeze protect 0.0 0.0 06:42 08:12 -tree, clear floor 2/1812019 2118/2019 1.50 DEMOB WHDBOP RURD P lWork RD checklist, freeze -protect tree, 0.0 0.0 08:12 09:42 blow -down PUTZ, break off TT line (hard-line still MU) 2/18/2019 2/18/2019 1.30 DEMOB P Break -off MP line, lock -out injector, ND 0.0 0.0 09:42 11:00 IVVHDBOP INUND BOPE Rig Released: 2/18/19 @ 11:OOAM Page 818 Report Printed: 5/14/2019 Well History ii -10 1qw-m-ringill API / UWI Legal WeliName Fleld Name 5002923010 Ili -10 KUPARM RIVER UNIT Well TypeOriginal KB/RT Elevation (ft) Well Status Development 114.25 EXPEND Left START DATE is from Daily Ops and Right Start Date represents the Job Start Legal slalt Dale WeliName Lasl24hr Sum AFEIRFE Rig Supervisor Job Type Start Data 5/9/2019 1J-10 (PRE CTD) T POT (PASSED), T PPPOT (PASSED), IC POT 10411108 RICHWINE, DRILLING SUPPORT - 9/16/2018 (PASSED), IC PPPOT (PASSED), TREE VALVE TEST: BRUCE,DHD CAPITAL SSV/MV/SV POSITIVE (PASSED) SSV/MV/SV NEGATIVE Field (PASSED). Supervisor 4/17/2019 1J-10 RAN IN HOLE W / 3.78" PACKER DRIFT UNABLE TO WORK 10411108 IMM, DRILLING SUPPORT - 9/1 612 01 8 PAST 6970' POOH AND PICKED UP A 3.5" JSN AND WEARE LARRYWells CAPITAL TAGGING @ 9845' AND UNABLE TO MAKE ANY Supervisor PROGRESS PUMPING @ 2 BPM POOH 4/16/2019 1J-10 RAN IN HOLE W / 3" WIN JETTED FROM 10100' TO 10326' 10411108 IMM, DRILLING SUPPORT - 9/16/2018 RKB PUMPED 250 BBLS OF FLOVIS @ 2.5 BPM CHASED LARRYWells CAPITAL BOTTOMS UP OUT OF HOLE .TO SURFACE GEL WAS Supervisor COMING BACK CLEAN FREEZE PROTECT WELL 4/15/2019 1J-10 RAN IN HOLE W / 3" DJN JETTED TO FISH 10326' RKB W / 10411108 IMM, DRILLING SUPPORT- 9/16/2018 150 BBLS OF FLOW VIS 290 SL SEAWATER RAN BACK IN LARRYWells CAPITAL HOLE W / 2.88" VENTURI APPEARS THAT WHEN WE DRY Supervisor TAGGED IT PLUGGED THE BOTTOM OF VENTURI. RAN BACK IN HOLE W / VENTURI. AT SURFACE W / VENTURI RUN #2 THE VENTURI IS FULL AND WITH LOTS OF ROCKS 4/14/2019 1J-10 RAN IN HOLE W /A2.88" VENTURI PUMPING @ 2 BPM 10411108 IMM, DRILLING SUPPORT - 9/16/2018 TAGGED AT 10320 RKB PULLED OOH AND THE VENTURI LARRYWells CAPITAL EXTENSION WAS PACKED W / HEAVY CLAY Supervisor 4/11/2019 1J-10 RAN IN HOLE W 12.3" JSN AND CLEANED OUT TAG @ 10411108 IMM, DRILLING SUPPORT - 9116/2018 10308 CTM MADE SEVERAL UP DOWN PASSES W GEL LARRYWells CAPITAL AND CHASED BOTTOMS UP TO SURFACE, Supervisor 3/16/2019 1J-10 TAG IN TBG @ 9820' RKB WITH 3.63" MAGNET. BAILED 10411108 FAMA, DRILLING SUPPORT- 9/16/2018 SPONGY MUD FROM 9820' TO 9848' RKB. -478' FROM P2P JAKE,Wells CAPITAL SET DEPTH. LAY DOWN DUE TO WIND, IN PROGRESS. Supervisor 3/15/2019 1J-10 RIH WITH 3.80" STRING MILL AND CARBIDE TAPER MILL, 10411108 APPLEHANS, DRILLING SUPPORT- 911612018 TAG AT 10292' CTMD, 10312' RKB. MILL DOWN TO 10330' AARON,Wells CAPITAL RKB, PU TO 10280' RKB, DRY DRIFT DOWN TO 10327' RKB. Supervisor FREEZE PROTECT WELL. READY FOR DIGITAL SLICKLINE. 3/14/2019 1J-10 SPOT UNIT IN, CUT 300' PIPE MAKE UP TOOLS. JOB IN 10411108 APPLEHANS, DRILLING SUPPORT- 9/16/2018 PROGRESS. AARON,Wells CAPITAL Supervisor 3/9/2019 1J-10 RAN 3.70" & 3.60" BROACHES TO 10,311' RKB (UNABLE TO 10411108 FAMA, DRILLING SUPPORT - 9/16/2018 WORK DEEPER). TAGGED @ 10,314' RKB WITH 3.63" JAKE,Wells CAPITAL MAGNET (RECOVED THIN METAL DEBRIS). JOB Supervisor POSTPONED FOR UNIT MAINTENANCE. 3/8/2019 1J-10 BRUSHED & FLUSHED TBG FROM 10,198' TO 10,328' RKB. 10411108 FAMA, DRILLING SUPPORT- 9/16/2018 DRIFTED TBG WITH 3.78" SWAGE, 5'x 1.875", 3.67" JAKE,Wells CAPITAL SWAGE TO 10,317' RKB (UNABLE TO WORK DEEPER). Supervisor TAG @ 10,313' RKB WITH 3.695" LIB (POSSIBLE COLLAPSED LINER). RAN 3.70" BROACH TO SAME; PULLING HEAVY FOR -300' UP HOLE. IN PROGRESS. 3/4/2019 1J-10 RUN 3.76" P2P LOWER PACKER UNABLE TO PASS 10317' 10411108 WORTHINGT DRILLING SUPPORT- 9/16/2018 RKB W/ PACKER WORK PACKER DOWN LIGHTLY UNABLE ON, CAPITAL TO PASS PACKER METAL SHAVINGS IN SETTING BRYCE,Wells ADAPTER, RAN 3.76" SWAGE 5' WB & 3.78" SWAGE TAG @ Supervisor 10325' RKB (RECOVER METAL DEBRIS IN SPANGS, RAN 2.70" SWAGE & CCL TAG @ 10328' RKB. JOB POSTPONED DO TO COIL WORK ON 1J-160. 2/24/2019 1J-10 BRUSH AND FLUSH TBG TO TAG @ 10,323' SLM. 10411108 FERGUSON, DRILLING SUPPORT- 9/16/2018 DRIFTED w/ DMY PATCH TO SAME, PULLED PDS SID,Wells CAPITAL CALIPER FROM 10,323' SLM TO SURFACE. JOB Supervisor COMPLETE. Page 1115 ReportPrinted: 511412019 AidnobL Well History ii-10 Left START DATE is from Daily Ops and Right Start Date represents the Job Start Slatl Date egal WelMal I Last24hr Sum AFE I RFE Rig Supervisor Job Type Start Date 2/18/2019 1J-10 TAGGED TD @ 10,341' RKB W/3.61" CENTRALIZER; DRIFT 10411108 RICHWINE, DRILLING SUPPORT- 9/16/2018 W/ 3.63" X 21' BAKER DMY WHIPSTOCK DOWN TO 10,341' BRUCE,DHD CAPITAL RKB. JOB SUSPENDED DUE TO HIGHER PRIORITY Field WORK. WILL RETURN TO INSTALL GAS LIFT VALVES. Supervisor 2/18/2019 1J-10 Continue to RIH with clean out assembly, clean to set-down at WCD.K23.NC3 Scott DRILLING SIDETRACK 2/10/2019 10,326', POOH, displace well to seawater & freeze-protect, 5.01.CT Kiser,Wells PUD BHA#7, jet stack, flush surface lines, work RD checklist, Supervisor ND BOP CTD Rig Released: 2118/19 @ 11!00AM (on NO of BOPE) 2/17/2019 1J-10 LD BHA#4, fishing BHA. LD Fish. Pump slack back. Cut 300' WCD.K23.NC3 Scott DRILLING SIDETRACK 2/10/2019 of pipe, re-head, test wire, pup slack forward. Pick BHA#5 up 5.01.CT Kiser,Wells clean out assembly w nozzle. RIH, tum well over to Power Supervisor Pro, jet whip stock tray, chase sweeps out of hole. POOH CTD turning well over to 9.9 ppg KW fluid. LD BHA#5 over a dead well. PU BHA#6, whipstock fishing BHA. RIH, wash over tray down to 3031 5'with hook turned out. Rotate hook to 14 ° ROHS, pull WS free and POOH. LD BHA#6 and fish over a dead well. PU BHA, motor and D331 clean out assembly. RIH to midnight depth of 3267'. 2/16/2019 1J-10 CUT TUBING AT 10330'. GOOD INDICATION OF CUT. 10411108 FAMA, DRILLING SUPPORT- 9/1612018 STANDBY FOR RIG TO VERIFY PIPE IS FREE. JAKE,Wells CAPITAL Supervisor 2/16/2019 1J-10 Continue to circulate bottoms up. POOH displacing well to 9.9 WCD.K23.NC3 Scott DRILLING SIDETRACK 2/10/2019 ppg KW. Lay down BHA#3 less drilling liner assembly left in 5.01.CT Kiser,Wells well. Rig uo E-line. RIH and chemical cut 3.5" flush max Supervisor drilling liner below the whipstock @ 10,330'. POOH with a-line. CTD Rig down a-line. PU BHA#4, fishing BHA. RIH and tag fish @ 10155' CTMD. Hit one jar lick 18 k lbs over. Pull free, POOH with fish. 2/15/2019 1J-10 Jet stack while fuming well over to milling fluid. Pick up BHA WCD.K23.NC3 Scott DRILLING SIDETRACK 2/10/2019 #3. RIH and tum well over to milling fluid. Pass through 5.01.CT Kiser,Wells window and drill from 10,336'to 10,356'. Stacking weight with Supervisor no motor work, unable to drill ahead. Pump drilzone sweep CTD and able to drill ahead to 10,380. Stacking weight again, PU & restart, drill to stall @ 10,377' Unable to pick up. Work pipe up to 90,000 Itis with no success. Attempt to shear circ sub with no success. Attempt to flow release from drilling liner with no success. Pump 5/8" ball and sear release from drilling liner at 7200 psi. Circulate bottoms up. Top offish - 10159' CTMD. 2/14/2019 Mill 3.80" exit window in liner. Perform reaming passes, dry WCD.K23.NC3 Scott DRILLING SIDETRACK 2/10/2019 drift - clean. POOH painting flags and displacing well to9.9 5.01.CT Kiser,Wells 11J-10 ppg kill weight fluid. Lay down BHA#2 over a dead well. Supervisor CTD 2/13/2019 1J-10 Continue to displace well to 9.5 ppg KW fluid, POOH and LD WCD.K23.NC3 Scott DRILLING SIDETRACK 211012019 BHA#1 over a dead well. Pick up 4 joints of PH6, cut and boot 5.01.CT Kiser,Wells wire, stab injector and pump slack forward. Unstab, recover Supervisor and cut 132'e-fine. Install BH CTC, pull and PT, stab on and CTD pump 7/8" ball and retrieve. LD 4joints of PH6. PU BHA#2, window milling assembly. Tum coil over to milling fluid. Pump 45 bbls poly swell down the annulus, hesitate squeeze 43 bbls away. RIH, dry tag TOWS @ 10312'. Verify returns at milling rate. Mill 3.80 exit window to midnight depth of 10313.5 2/12/2019 1J-10 Test BOP's, PT PDL's & TT liner, PD BHA#1, RIH, log WCD.K23.NC3 Scott DRILLING SIDETRACK 2/10/2019 formation for -5' correction, & flush well, squeeze 150K _SRV 5.01.CT Kiser,Wells pill to parts, POOH,while turning over well to 11.8 ppg KW fluid. Supervisor Unable to surface KW fluid @ 2000'. Mix and pump 9.5 ppg CTD KW. 2111/2019 Complete move [0 1J-Pad, spot sup & pits over well, RU, NU WCD.K23.NC3 Scott DRILLING SIDETRACK 2/10/2019 BOPE 5.01.CT Kiser,Wells 11J-10 Supervisor Rig Accept: 2/11119 @ 21:30 his CTD Page 2115 Report Printed: 511412019 McLaughlin, Ryan From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, February 20, 2019 9:17 AM To: McLaughlin, Ryan Subject: [EXTERNAL]KRU 11-10(PTD 201-071, Sundry 319-030) Close out whipstock sundry Follow Up Flag: Follow up Flag Status: Flagged Ryan, Please submit a 10-404 to close out this sundry since the well will be returned to production after drilling was discontinued after the window for the first lateral was milled. A sundry for an operations shut down is not required. However, in the 10-404 submission, please include the daily drilling report, operations report for patch setting, a schematic and an explanation of the operations that occurred under this sundry as well as future plans to return to the well. When drilling resumes, a new sundry for setting the whipstock will be required. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer Slate of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeoD(&alaska.gov CONFIDENTIAM NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@alaska.aov From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Tuesday, February 19, 2019 3:47 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Ohlinger, James J <lames.J.Ohlinger@conocophillips.com>; Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: 1J-10 Operations Summary Hello Victoria, While drilling the 1J-101-1 lateral with our Liner Drilling BHA, we became stuck in the Kalubik at a depth of 10,362' MD. We dropped a ball to release off of our liner drilling BHA, then proceeded to rig up E -line to make a chemical cut at a depth of 10,330' MD. After a successful cut was made, we pulled the liner drilling BHA out of hole to a depth of 10,330' MD leaving the rest of the fish in hole (20' of liner, motor, drill bit). After this we ran in hole and pulled the whipstock that was set at 10,301' MD and cleaned the hole out to a depth of 10,326' MD. Plan forward is to set a patch over the window that was milled at 10,301' MD and return the well to production in the interim between coming back and making another attempt to drill the permitted laterals. I am planning on submitting a 10-404 to close out the whipstock. Current CTD schematic of 1J-10 is attached. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 ,0T -D qo/ Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, May 10, 2019 8:19 AM To: McLaughlin, Ryan Subject: RE: KRU 1J-10(PTD 201-071, Sundry 319-030) Close out whipstock sundry Thanx From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Friday, May 10, 2019 8:12 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: KRU 11-10(PTD 201-071, Sundry 319-030) Close out whipstock sundry Victoria, We were unsuccessful in setting a patch on 1J-10 so we plan to return to the well with CDR3 and attempt to re -drill the well. I plan on submitting a 10-404 with operations to date to close out the whipstock Sundry and will submit a new 10- 403 for setting a whipstock and rigging up CDR3. I've attached our last correspondence for your reference. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 WELL LOG TRANSMITTAL #905533952 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Drift Record: 1J-10 Run Date: 3/4/2019 20107 30 73 2 April 30, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1J-10 Digital Data in LAS format, Digital Log Image file 50-029-23010-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com *e: 0�)�! Wry Signed: RECEIVED MAY 0 8 2019 Anrncc VS -11. PROACTIVE DIAGNOSTIC SERVICES, INC. WELL LO TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection (Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Pdsanchorage(&memorvloo.com 1) Caliper Report 24 -Feb -19 1J-10 CD 2) Jewelry Log 24 -Feb -19 1J-10 CD Signed : Print Name: 20 1071 RE%C**E1 V ED MAR 222019 AOGCC 50-029-23010-00 50-029-23010-00 Date. V U Z Z61 I PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE.MEMORVLOGCOM WEBSITE: WIMN.MEMORYLOG.COM D,\Achiva\MastarTemplateFil,,,Templates\Distibutnn,Tie mittalSheato\Conor PlollSpa_TTansmitdoc. VS -11. PROACTIVE DIAGNOSTIC SERVICES, INC. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection (Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Jewelry Log Signed Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 pdsanchoragea-memorvlog com 24 -Feb -19 1J-10 CD 24 -Feb -19 1J-10 CD 201071 30484 PPrc mn MAR 2 2 2019 AOGCC 50-029-23010-00 50-029-23010-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(0).MEMORYLOGCOM WEBSITE:WWW.MEMORYLOG.COM D \Acheee AlmtutT.�mplot-Yile.,\T.:mp;nra\DistribvHo�dTrmsmiMalS},-=ts ConocoPLi➢Sps_T�. mitdco 70 1071 30484 Memory Multi -Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1J-10 Log Date: February 24, 2019 Field: Kuparuk Log No.: 14370 State: Alaska Run No.: 2 API No. 50-029-23010-00 Pipe Description: 4.5 inch 12.6 Ib. L-80 IBT J NSCT Top Log Interval: Surface Pipe Use: Tubing and Liner Bottom Log Interval: 10,336 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS: This caliper data is correlated to the PDS jewelry log dated February 24, 2019. This log was run to assess the condition of the tubing and liner with respect to internal corrosive and mechanical damage and to assess the condition of the liner in the vicinity of the mill -out window prior to setting a patch over the window. The caliper recordings indicate the liner appears to be in good condition with respect to wall penetrations, areas of cross-sectional wall loss or I.D. restrictions in the vicinity of the mill -out window. A 3-D log plot of the caliper recordings across the mill -out window is included in this report. The caliper recordings indicate the 4.5 inch tubing and liner logged appears to range from good to fair condition, with a maximum recorded wall penetration of 23% in a line of corrosion in joint 296 (9,504 ft). Recorded damage appears as a line of pits and line corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing and liner logged. This is the second time a PDS caliper has been run in this well and the 4.5 inch tubing and liner have been logged. A comparison of the current and previous log (October 29, 2007) indicates an increase in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint -by -joint basis between logs is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion 23 296 9,504 Ft. (MD) Line Corrosion 23 50 1,624 Ft. (MD) Line Corrosion 22 51 1,641 Ft. (MD) Line Corrosion 21 40 1,311 Ft. (MD) Line Corrosion 20 302 9,710 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. C. Goerdt C. Waldrop S. Ferguson Piv.,c7,iv. ci,gnosrk Service ;,'rc. i F . 3or J?69, Rt= ,nrS, TX 77.4S7 cone: !231; 131-710- �j (S£3) 563 9035 .: (231 4.-,1-7125 E-mail PDSAna1vsls2rnemorvloo corn ?ri_ic_ Bay Fie'ti 71` a Fri^rr CD,) i5^ P07 F,, ESQ)-2314 ,�� PDS Multifinger Caliper 3D Log Plot �� Company: ConocoPhillips Alaska, Inc. Field : Kuparuk Well: 1J-10 Date : February 24, 2019 Description : Detail of Caliper Recordings Across Mill -Out Window in 4.5 Inch Liner. JRS� Well: Field: Company: Country: 11-10 Kuparuk Conoco Phillips Alaska, Inc. USA PDS Report Cross Sections Survey Date: February 24, 2019 Tool Type: UW MFC 40 No. 217958 Tool Size: 2.75 No. of Fingers: 40 Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (9.2'- 10,335.5') Well: 1)-10 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 24, 2019 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 11 50 1,608 100 3,200 GLM 1 150 4,812 t c GLM 2 6,415 t a v GLM 3 7,995 GLM 4 9'622 GLM 5 10,323 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 320 Maximum Recorded Penetration ji Comparison To Previous Well: 1J-10 Survey Date: February 24, 2019 Field: Kuparuk Previous Date: October 29, 2007 Company: Conoco Phillips Alaska, Inc. Tool Type: UW MFC 40 No. 217958 Country: USA Tubing: 4.5"12.6]b L-80 IBT Overlay Maximum Recorded Penetration (mils) 0 50 100 150 200 250 1 20 45 70 95 Mi 117 142 E Z 167 e 192 QM2 214 — 239 oun 1-- 261 ram s- CLM5-30Y�- February 24, 2019 October 29, 2007 Difference Difference in Maximum Penetration (mils) -50 -25 0 25 50 0 k3i -4 .2 0 2 4 Approximate Corrosion Rate (mpy) F— —r_Co osionRate copy), LTop 10�__ ts J Overall _4_v_erageeI3 I_1_ _ Median i 3 1 1 Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT 3.958 in. 9 ft. 9,992 ft. 4.5 in. 12.6 ppf L-80 NSCT 3.958 in. 9,992 ft. 10,336 ft. Damage Configuration (body) too 80 60 40 20 0 Isolated General Line Other Hole/ Pitling Corrosion Corrosion Damage Pos. Hole Number of io nts damaged (total = 101) 5 0 96 0 0 Damage Profile (%wall) Penetration body Metal loss body 0 50 100 GLM 1 (1:30) GLM 2 (4:00) GO,i 3 (1:30) GLM 4 (12:30) GLM 5 (4:00) Bottom of Survey = 320 PDS Report Overview (Xy�s Body Region Analysis Well: 1J-10 Survey Date: February 24, 2019 Field: Kuparuk Tool Type: UW MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA No. of Fingers: 40 Analyst: Waldrop Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT 3.958 in. 9 ft. 9,992 ft. 4.5 in. 12.6 ppf L-80 NSCT 3.958 in. 9,992 ft. 10,336 ft. Damage Configuration (body) too 80 60 40 20 0 Isolated General Line Other Hole/ Pitling Corrosion Corrosion Damage Pos. Hole Number of io nts damaged (total = 101) 5 0 96 0 0 Damage Profile (%wall) Penetration body Metal loss body 0 50 100 GLM 1 (1:30) GLM 2 (4:00) GO,i 3 (1:30) GLM 4 (12:30) GLM 5 (4:00) Bottom of Survey = 320 5 PDS Report Joint Tabulation Sheet Well: 1J-10 Survey Date: February 24, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhikips Alaska, Inc. Pipe Description 4.5 in. 12.6 ppf 4.5 in. 12.6 ppf L-80 IBT Tubing L-80 NSCT Liner Nom. ID Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 9 ft. 9,992 ft. 3.958 in. 0.271 in. 9,992 ft. 10,336 ft. Joint No. Jt. Depth (Ft.) Pen.jPen. Upset (in.) Pen. % Metal Loss % Min. Damage Profile I.D. Comments (% wall) (in.) 0 50 100 .1 9 6 1 4 Pu 1 11 0 8 1 3.92 1.1 43 0 7 1 1 Pup 1.2 53 0 10 2 3.94 Pu 1. 62 10 1 .9 Pup2 68 . 7 1 3.92 3 100 0 0.03 11 1 3.93 4 132 0 0.02 B 1 3.92 5 164 0 0.02 7 1 3.92 6 196 0 0.03 9 2 3.91 7 228 0 0.03 11 3 3.93 8 1 260 0 0.02 2 3.93 9 1 292 0 0.03 11 2 3.92 10 1 324 0 0.02 9 1 3.92 11 1 356 0 0.03 9 1 3.93 12 1 388 0 0.04 13 3 3.91 13 1 419 1 0 0.04 13 1 2 3.92 14 451 0 0.04 16 1 2 3.92 Shallow Line Corrosion. 14.1 483 0 0.04 14 1 3.92 Pu 14.2 489 0 0 0 0 3.84 CAMCO 6 NIPPLE 14.3 490 0 0.02 7 2 3.89 Pu Lt. De osits. 15 496 0 0.04 15 2 3.91 Shallow Line of Pits. 16 528 0 0.03 10 1 3.92 17 559 0.04 0.05 18 3 3.92 Shallow Line Corrosion. 18 1 0 0.04 14 1 3.94 19 623 0.05 0.04 16 2 3.93 Shallow in of Pits. 20 655 1 0.04 0.05 20 3 3.94 Line Corrosion. 21 686 0.05 0.05 18 1 3 3.93 Shallow Line Corrosion. 22 71 0.05 .05 19 2 3.93 Shallow in Corrosion. 23 750 0 0.04 15 2 3.92 Shallow Line of Pits. 24 2 0 0.04 15 1 3.94 Sha low f its. 25 814 .03 12 1 .93 26 846 0 0.04 16 2 3.93 Shallow Line Corrosion. 27 7 0 0.02 8 1 3.93 2 09 0 5 17 2 3.94 Shallow in Corrosion. 29 941 0 0.05 17 3 3.93 Shallow Line Corrosion. 30 7 0 0.04 14 2 3.93 31 1005 0.04 0.04 14 2 3.93 32 0 7 0 0.04 13 1 .91 33 1 8 0 0. 4 14 1 3.93 34 1100 0 0.02 7 1 3.94 5 113 0 0.03 11 1 2 36 11 0 0.03 11 3 3.94 37 1196 0.05 0.05 17 1 3.93 Shallow Line of Pits. 8 8 0.05 0.04 15 i 4 Shallow Lin of Pits. 39 1 0 0 0.04 15 1 3.93 Shallow Line of Pits. 40 1291 0 0.06 21 3 3.94 Line Corrosion. 41 1323 0.04 16 1 4 hallow Line Corrosion. 42 1355 0 0.04 13 2 3. 4 43 1387 0 0.02 8 1 3.93 Penetration Body Metal Loss Body Page 1 jiS. PDS Report Joint Tabulation Sheet Well: 1J-10 Survey Date: February 24, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 4.5in. 12.6 ppf 4.5 in. 12.6 ppf LSO IBT Tubing LSO NSCT Liner Nom. ID Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 9 ft. 9,992 ft. 3.958 in. 0.271 in. 9,992 ft. 10,336 ft. Joint No. Jt, Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. Damage Profile I.D. Comments (% wall) (in.) 0 50 100 44 14 9 0.0 8 1 .94 1 0 0.05 18 3 3.93 Shallow Line Corrosion. 3 0.05 0.0 17 1 3.93 Shallow Line o Pits. 15 0 0.03 12 1 3.93 7 0 0.03 11 3 3.9 79 0.05 0.0 18 1 3. Shallow Line o Pis. 8 0.05 0.06 23 4 3.90 Line Corrosion. 9 j531703 5 0.06 22 4 3.91 Line Corrosion. 71 0 0.04 15 2 Shallow Pitting. Lt. Deposits. 03 0.04 0.04 16 2 3.93 Shallow Line Corrosion. 0 0. 4 15 4 3.9 Shallow Lin of Pi . 67 0 0.0 17 1 3 Shallow ine f Pits. 99 0.05 0.05 20 3 3.91 Line Corrosion. 31 0 0.04 13 3 2 58 18 0.05 .05 1B 1 3.94 hallow in of Pits. 59 1895 0 0.04 16 2 3.95 Shallow Line of Pits. 192 .05 5 19 2 4 hallow Lin f Pits. 61 1959 0.05 0.05 17 1 3.93 Shallow Line of Pits. 62 1991 0 0.05 17 2 3.94 Shallow Line Corrosion. 63 2 0.04 .04 1 1 3 hallo in of Pits. 64 2055 0.05 0.05 19 1 3.94 Shallow Line of Pits. 65 208 0 4 13 1 195 66 118 0 003 11 3. 3 67 2150 0 0.02 7 1 3.94 68 2182 0 .03 11 1 . 2 69 2215 0 0.04 15 3 3.93 Shallow ine of Pits. 70 2246 0 0.02 8 1 3.91 71 22 0.14 . 3 1 1 3.94 72 2310 0 0.04 14 3 3.94 73 2341 0 0.03 10 2 3.92 74 373 0 4 14 2 3.95 75 2405 0 0.03 1 1 3.95 76 2437 0 0.02 7 2 3.95 7 4 0 0. 4 15 4 Shallow Lin f Pits. 78 2500 0 0.03 13 1 3.95 79 2531 0 0.03 11 3 3.94 80 2563 0 .04 15 3.93 Shallow in f Pits. 81 2595 0 0.04 14 2 3.93 8 2627 0 0.2 8 1 2 8 6 0 3 11 1 . 4 84 2691 0 0.03 11 1 3.94 8 27 2 0 0. 4 14 3 .9 8 27 4 0 0. 12 3 3.92 87 2787 0 0.04 14 3 3.94 88 2818 0 0.03 10 8 2850 0 0.0 10 90 2882 0 0.04 14 91 2914 0 0.03 13 2439 2945 0 0.0 9 93 2978 0 0.04 13 Penetration Body Metal Loss Body Page 2 ji-�s PDS Report Joint Tabulation Sheet Well: 1J-10 Survey Date: February 24, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 4.5 in. 12.6 ppf LBO IBT Tubing 4.5 in. 12.6 ppf L-80 NSCT Liner Nom. ID Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 9 ft. 9,992 ft. 3.958 in. 0.271 in. 9,992 ft. 10,336ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. Damage Profile I.D. Comments (% wall) (in.) 0 50 100 94 3009 0 0.05 17 2 3.96 Shallow Line Corrosion. 95 3041 0 0.03 10 1 3.92 96 3073 0 0.03 12 2 3.94 97 3105 0 0.04 13 3 3.94 98 3136 0 0.05 17 3 3.93 Shallow Line of Pits. 99 3168 0 0.04 15 4 3.93 Shallow Pitin . 100 3200 0 0.03 11 2 3.93 101 3232 0 0.03 9 1 3.95 102 3263 0 OA2 8 1 3.94 103 3295 0 0.03 13 1 3.94 104 3327 0 0.03 10 2 3.94 5 3359 0 0.03 11 3 3.94 106 3390 0 0.03 13 1 3.94 107 3422 0 0.04 13 3 3.93 108 3453 0 0.02 8 1 3.94 109 3485 0 0.04 15 1 3.94 Shallow Line of Pits. 110 3516 4 15 3 Shallow Line of Pits. 111 3549 0 0.05 17 3 3.95 Shallow Line Corrosion. 112 3580 0 0.04 14 3 3.96 113 3612 0 0.04 15 2 3.94 Sbal[Qw Line of Pits. 114 3644 0 0.03 11 1 3.94 115 3676 0 0.04 16 3 3.93 Shallow Pitting. 115.1 3708 0 0.03 11 2 3.93 P 115.2 3713 0 0 0 0 3.86 CLM 1 LATCH @ 1:30 115.3 3721 0 0.02 8 1 3. 4 Pup 116 3727 0 0.04 14 3 3.93 117 1 3759 0 1 0.03 11 3 3.93 118 1 3790 0 0.03 12 1 2 3.93 119 3822 0 0.02 8 1 1 3.95 120 3854 0 0.05 17 3 3.92 Shallow Line of Pits. 121 3887 0 0.04 14 1 3.94 122 39180 0.04 14 3 3.94 123 3950 0 0.05 17 2 3.92 Shallow Line of Pits. 124 3982 0 0.03 13 1 3.94 125 4014 0 0.03 13 2 3.93 126 4046 0 0.03 11 1 3.93 127 4078 0 0.03 9 2 3.93 128 4110 0 0.04 14 2 3.94 129 4141 0 0.02 8 1 3.93 130 4173 0 0.05 1 t3 3 3.91 hallow Line Corrosion. 131 4205 0 0.04 15 3 3.94 Shallow Line of Pits. 132 4237 0 0.03 10 2 3.95 133 4269 0 0.04 14 4 3.95 134 4301 0 0.03 12 2 3.95 135 4333 0 0.04 13 3 3.94 4364 0 0.03 12 2 4 4397 0 0.03 11 3 3.93 11140E 44 0 .0 10 1 3 4460 0 0. 11 1 .92 4493 0 0.03 13 3 3.92 Penetration Body Metal Loss Body Page 3 ii -4s Well: Field: Company: 1J-10 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 24, 2019 Analyst: Waldrop Pipe Descripbon 4.5 in. 12.6 ppf LSO IBT Tubing 4.5 in. 12.6 ppf LSO NSCT Liner Nom. ID Body Wall Top Depth 3.958 in. 0.271 in. 9 ft. 3.958 in. 0.271 in. 9,992 ft. Bottom Depth 9,992 ft. 10,336 ft. Joint JL Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min, I.D. (in.) Comments Damage Profile (% wall) 0 50 100 141 4525 0 0.03 13 1 3.93 142 4557 0 0.03 12 2 3.94 4 45 0 0.03 1 2 3.95 144 4620 0 0.04 14 2 3.94 145 4652 0 0.04 15 3 3.94 hallow ine tPits 14 4684 0 0.03 13 3 .94 147 4716 0 0.04 14 2 3.95 148 4 4 0 CTQ2 1 3.94 14 478 0 0.04 14 3 . 3 150 4812 0 0.02 9 1 3.94 1 1 4844 0 4 16 3 .94 Sh II w Lin rosion. 152 4876 0 0.03 9 1 3. 4 153 4908 0 0.03 11 1 3.94 154 4939 0 0-02 8 1 .94 155 4971 0 0.03 10 2 3. 156 5003 0 0.02 9 1 3.93 157 5035 0 0. 10 3. 4 158 5067 0 1 0.03 13 3 3.9 159 5098 0 0.03 10 1 3.95 160 5129 0 0.04 13 3. 2 161 5161 0 0.03 11 1 3.93 162 5192 0 0.04 16 3 4 Shall w Line 1--s- oi163 163 5 4 0 0.02 t31 3.94 164 5255 0 0.03 10 1 3.93 165 5287 0 0.02 8 1 3.93 166 5318 1 0 0.o4 13 1 3.9 167 5350 1 0 0.02 9 2 3.94 168 5382 1 0.02 8 1 3.94 169 5414 1 0 0.03 12 1 3.93 170 5446 0 0.04 14 3 3.93 171 5478-0 0.03 10 1 1 3.92 172 5507 01 0.03 10 1 7 1 3.94 173 55390 0.03 10 9 3.93 174 71 0.03 70 1 3. 4 175 5603 1 0 1 0.02 9 1 1 3.93 176 5635 0 0.04 14 3 3.94 177 5667 0 0.0 11 3. 4 178 5699 0 0.02 8 1 3.94 179 5731 0 0.04 13 1 .9 180 5762 0 0. 4 14 1 3 181 5793 0 0.04 14 2 3.92 182 5825 0 0.03 12 3 .91 1 5857 0 004 13 3 3.92 184 5889 0 0.03 11 1 3.94 185 5921 0 1 0.03 10 2 3.93 186 1 5953 D I 0.04 13 3.92 1 187 1 5984 0 0.03 3 13----!-- 3 3.93 6904 188 0 0.04 13 1 3.93 189 6048 0 0.0 72 1 .93 190 6078 0 0.04 13 3 3.94 Penetration Body Metal Loss Body Page 4 i4S Well: Field: Company: 1J-10 Kuparuk ConocoPhillips Alaska, Inc PDS Report Joint Tabulation Sheet Survey Date: February 24, 2019 Analyst: Waldrop [��4.5 ription . 12.6 ppf 4.5 in. 12.6 ppf L801BT Tubing L80 NSCT Liner Nom. ID Body Wall Top Depth 3.958 in. 0.271 in. 9 ft. 3.958 in. 0.271 in. 9,992 ft. Bottom Depth 9,992 ft. 10,336 ft. Joint No. Jr. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 191 6110 0 0.02 7 1 3.94 192 6142 0 0.04 i4 -L 3 1 3.92 193 6174 0 0.05 18 1 3 1 3.93 S allow Line of Pits. 194 6206 0 0.04 14 1 1 3.93 195 6238 0 0.05 17 3 3.93 Shallow Line of Pits.. 196 6270 0 0.03 13 3 3.93 196.1 6301 0 0.04 15 2 3.91 Pup Shallow Line of Pits. 1 6.2 6307 0 0 0 0 3.87 2(LATCH@4:00 119 1 5 0 0.05 17 2 3.86 Pu Shallow in Corrosion. Lt. Deposits. 197 6320 0 0.04 13 2 3.92 1 6352 0.04 1 2 3.93 Sh ow Line f Pits. 199 6384 0 0.05 17 3 .9 Shallow Line of Pits. 200 641 5 0 0.04 15 3 3.93 Shallow Line of Pits. 201 447 0 0.04 1 2 3.93 Sh II w Line of Pis. 202 4 9 0 0.03 10 3 1.92 203 651 1 0 0.04 16 2 3.93 Shallow Line of Pits. 204 43 0 0.05 17 1 .92 Shall ine of Pi s. 205 657 0 0. 4 16 2 3. Shallow ine of Pits. 206 6607 0 0.04 16 3 3.92 Shallow Line of Pits. 207 66 0 3 11 Z . 3 208 6670 0 0.04 16 2 3.92 Shallow Line of Pits. 20 700 0 0.05 17 4 .92 Shallow Line C rr si n. 210 67 2 0 4 15 3. Shallow Line of Pi 211 6764 0 14 3 3.93 212 7 011 2 .9 213 6827 0 14 2 3. 214 6859 0 14 4 3.94 215 6891 0 11 2 .9 16 692 0 12 3.92 217 6952 0 13 1 3.93 218 6984 016 j16 1 3. Shallow Line of Pits 19 7016 0 14 3 3.92 220 7045 0 10 1 3.92 221 7077 016 4 3:92 Shallow ina of Pits. 222 7109 0 1 3 3 223 7140 0.04 6 3 3.91 Shallow Line Corrosion. 224 717 013 1 3. 2225 7204 0 9 3 3.92 226 7235 0 0.04 14 2 3.91 227 7267 0 0.04 14 2 3.92 228 7299 0 0.04 16 2 3.92 Shallow Line of Pits. 229 7331 0 0.04 15 2 1 -92S -hallow Line of Pits. 230 7362 0.04 0.05 17 3 `1 91 Shallow Line of Pits. 231 7394 0 0.04 13 3 3.91 4 5 0 0.03 12 3 74 6 0 0.04 15Sh II w ine of234 7488 0 0.04 14520 0.l 5 0.05 18 t2- h Ilow Line551 0 0.04 14 237 7583 0 003 11 9, 'Penetration Body Metal Loss Body Page 5 ji4s Well: Field: Company: 1)-10 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 24, 2019 Analyst: Waldrop Pipe Description 4.5 in. 12.6 ppf LSO IBT Tubing 4.5 in. 12.6 ppf LSO NSCT Liner Nom. ID Body Wall Top Depth 3.958 in. 0.271 in. 9 ft. 3.958 in. 0.271 in. 9,992 ft. Bottom Depth 9,992 ft. 10,336 ft. Joint No. A Depth (Ft.) Pen. Ll pset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. 1. D. (in.) Comments Damage Profile (%wall) 0 50 100 8 7615 0 005 17 4 -3.93 Shallow Line ofPits. 239 L 7647 0 0.03 10 2 3.93 40 1 7678 0 0.03 10 3 3.89 Lt. DepsitS. 241 1 7710 0.04 0.05 17 4 3.92 Shallow Line of Pits. 42 7742 0 0.03 11 1 .92 2A3 7774 0 R02 9 2 3192 244 78060 0.04 15 1 3.91 Shallow Line of Pits. 45 7835 83 0 .02 8 1 .9 246 7867 0 0.04 13 247 L7899 1 o 0.04 14 2 3.92 248 7931 0 1 (L 2 8 1 249 7963 0.04 14 3.91 250 7995 0 0.04 15 4 3.92 Shallow Line of Pits. 251 8027 0 0. 4 13 3. 1 251.1 8059 0.02 Pu 251.2 8064 0 0 0 0 3.88 GLM 3 LATCH @ 1:30 251. 8072 0 0.04 2 3. 7 Pu osit . 52 078 0 0.04 14 2 3.92 253 8109 0 0.02 7 1 3.93 254 al4l 0 0.04 14 2 3.93 255 8173 0 0.04 35 4 3.93 Shallow Line of Pits. 25 8205 0 0.04 14 3 3.93 257 6237 0 0.03 11 3 3.92 258 8269 0 0.02 8 2 3.91 259 1 8301 0 0.03 11 2 3.92 260 1 8332 0 0.04 13 3 3.93 261 1 8362 0 1 0.02 8 1 3.92 262 1 8394 1 0 0.04 14 3 3. 263 1 8426 1 0 1 0.04 14 1 3.93 264 1 8457 1 0 0.05 19 3 3.93 Shallow Line Corrosion. 265 89 0 0.05 17 4 3.23 1 Shallow PittmR. 266 1 8521 1 0 0.04 13 1 1 3.92 267 1 8554 1 0.05 0.05 17 3 1 3.88 Shallow Line Corrosion. Lt. De osits. 268 1 8586 1 0 0.04 15 3 3.94 Shallow ine of Pi 269 8617 0 0.02 7 1 3.88 1 t. De osi s. 270 8649 0 0.03 12 2 3.93 271 8681 0 0.04 13 3 3.93 272 8713 0 0.02 9 2 3.93 8745 0 0. 16 4 Sh II w Lin rro ion. 74 87 6 0 0.03 11 1 3.91 275 8808 0 0.04 16 3 3.92 Shallow Line of Pits. 276 8840 0 20 .93 in f Pits. 277 8872 0 0.03 10 1 .92 278 8904 0 0.04 15 3 3.92 Shallow Line of Pits. 279 8935 0 13 2 .93 2 8967 0 0. 4 16 3 .93 Shall ine of Pit . 281 8999 0 0.04 15 3 3. 2 Shallow Line of Pits. 2 9031 0 .03 1 3 90 83 9062 0 0. 12 3 4 284 9094 0 0.03 1 102 3.92 Penetration Body Metal Loss Body Page 6 Ji4-s Well: Field: Company: 1J-10 Kuparuk ConocoPhidips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: February 24, 2019 Analyst: Waldrop Pipe Description 4.5 in. 12.6 ppf 4.5 in. 12.6 ppf L801BT Tubing L80 NSCT Liner Nom. ID Body Wall Top Depth 3.958 in. 0.271 in. 9 ft. 3.958 in. 0.271 in. 9,992 ft. Bottom Depth 91992 ft. 10,336 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % in. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 284.1 9125 0 0.04 13 1 1 3.93 Pu 284.2 9131 0 0 0 1 0 3.88 GLM 4 LATCH @ 12:30 2b4.3 9138 0 n.n3 3.9 Pup Lt. Deposits. 285 9144 0 0.03 13 1 3.92 286 9176 0 0.03 11 1 3.92 287 9208 0 0.04 15 3 3.92 hallow Line of Pits. 288 9240 0 0.03 13 3 3.93 2 9 9272 0 12 2 3.9 29 9303 0 0.05 17 3 3.92 Shallow Line of Pits. 291 9335 0 0.04 15 3 3.93 Shallow Pitfin . 292 9367 1 0 0.04 13 1 3.91 293 9399 110 0.03 11 2 3.93 294 9431 1 0 0.04 14 3 3.94 295 9463 0 0.04 13 3 3.92 296 9495 0.04 0.06 23 2 3.91 1 1 ine Corrosion. 297 9526 0 0.04 14 13.92 298 58 0.05 17 3 3.93 Sh.lInw Lin Corrosion. 99 9590 0 0.03 12 2 3.94 300 9622 0 0.04 15 2 3.92 Shallow Line Corrosion. 301 54 0 0.03 11 1 .92 302 9686 0 0.06 20 2 3.92 Line Corrosion. 303 1 9718 1 0 0.03 1 2 3.91 304 7 0 .0 8 1 .92 305 9782 0 0.03 10 1 3.92 306 13 0 .02 3.92 307 9845 0 .04 13 2 307.1 9877 0 0.04 16 2 3.91 Pu Shallow Line Corrosion. 307.2 2 0 0 0 0 3.85 5 LAT H@ 400 307.3 98 0 0. 11 1 7 Pu t. De osits. 308 9896 0 0.05 17 2 3.92 Shallow Line of Pits. 308.1 1 99280 Q.02 6 1 3.94 Pu 308.2 1 9934 0 1 0 0 4 CAMCO DB NIPP 308.3 1 9935 1 0 1 0.02 7 1 3.89 Pup Lt. De osits. 309 1 9941 1 0 0.02 8 1 3.91 309.1 1 9973 1 0 0.02 8 1 3.90 Pu 309.2 1 7 0 3.81 UAKER SEAL ASSEMBLYMULESHOE 309.3 9992 0 0 0 0 3.79 B KER ZXP LINER TOP PACKER 309.4 10000 0 0 0 0 3.80 LINER HANGER 1 10008 0.04 16 3 3.87 h Ilow Line Corrosion. Lt. Denosits. 11 1 03 0 0.02 7 1 3.90 312 10069 0 0.02 8 2 3.90 313 10101 0.02 9 2 1 3.89 1 Lt. Deposits. 314 10131 0 1 0.02 8 1 1 3.91 315 10162 0 0.02 9 2 3.90 316 10191 0 0. 28 1 3.8 Lt. De. 17 10221 0 0.05 20 2 3.84 Line Corrosion. Lt. Denosits. 318 10251 0 0.03 10 1 386 Lt. De osits. 319 1028 0 0. 11 3.82 Lt. Deposits. 319.1 10310 0 0 0 3.58 TOP OF THE ILI Ot JTWINDOW 319.2 10323 0 0 0 0 3.90 BOTTOM OF THE MILLOUT WINDOW Penetration Body Metal Loss Body Page 7 ji—�s PDS Report Joint Tabulation Sheet Well: 1J-10 Survey Date: February 24, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhilips Alaska, Inc. Pipe Descripfion Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT Tubing 3.958 in. 0.271 in. 9 ft. 9,992 ft. 4.5 in. 12.6 ppf L-80 NSCT Liner 3.958 in. 0.271 in. 9,992 ft. 10,336 ft. Joint Jt. Depth Pen. Pen. Pen. Metal in. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (in.) (in.) % (in.) 0 50 100 320 1 230 1 .04 14 1 3.79 Lt. O—eiposits. Penetration Body Metal Loss Body Page 8 PDS Report Cross Sections Well: 1J-10 Survey Date: February 24, 2019 Field: Kuparuk Tool Type: UW MFC 40 No. 217958 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Cross Section for Joint 296 at depth 9,504.241 ft. Tool speed = 47 Nominal ID = 3.958 Nominal OD = 4.5 Remaining wall area = 98% Tool deviation = 53° Finger = 40 Penetration = 0.062 in. Line Corrosion 0.06 in. =23% Wall Penetrations HIGH SIDE= UP Wiis IJ-10 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: _ 4.5 in. 12.6 ppf L-801BT PDS Report Cross Sections Survey Date: February 24, 2019 Tool Type: UW MFC 40 No. 217958 Tool Size: 2.75 No. of Fingers: 40 Cross Section for Joint 50 at depth 1,624.221 ft. Tool speed = 50 Nominal ID = 3.958 Nominal OD = 4.5 Remaining wall area = 96% Tool deviation = 39° Finger = 6 Penetration = 0.062 in. Line Corrosion 0.06 in. = 23% Wall Penetrations HIGH SIDE= UP KUP PROD WELLNAME 1J-10 WELLBORE 1J-10 ConoeoPhllllps $RAttribukes Max Angle a MD TO AYl'AiL rx[. FIHa Name WINila. V,. KUPARUK RIVER UNIT 5OW92301000 en Wellbore5plux n[I I.1 MD I.KBI aed, IRKBI PROD 6].SB 3,1%84 10,845.0 Cammenl NIS 1ppml BBBV: NIPPLE 40 De[e gnnotallon Epo Data K84M lnl Rig Raleaso Dale gf10/2016 Last\"/O: 2'BIZ008 35.74 51242001 10 t3 LastTag sic fariea Annabel IDepin lnke) iina Dae wMman Leal Mad 6y Uad Tag:RKB 10,348.03(1]201] 1b10 pproven nu.,el:.vge-c Last Rev Reason Mandl all walmme Lastedoney Rev Reason, 6M Whipstock ZO/2019 smal 1J-00 Jl Casing Strings .••.••••••••......... ........ ........ .................. ...... ..In, omadpuon oD inl 10 firl CONDUCTOR 19.12 Top lineal Sxoepin lanai srt Dept TaId... wDien(L..... Tap Thea 35.0 1200 1200 91.50 H40 WELDED C..Ins Deaarlpdon 09(1n) IS (in) SURFACE 85/8 8. &i Top IRKBI SeloeptlRKDI Stl pepIn lTYDI... Men ll.. Ore de iap Threw 345 6,995.3 3,995.4 4000 L -W BTC Caaing Deeenplian 00 ped Io (in) PRODUCTION ) E.G. Top IRKBI SNDept IRK81 S.Do pin lTYD1.., wVLan I1.. Oreae Top Tnrwd 317 10,230.8 5,9M.9 26.00 L-80 aTC-M1I00 <OriOJCTOR, I9 G-I]CO Ceding Desarip[ion OO IM IO IIn LINER 41/2 3.96 TapIKK61 SNDept flKB) SMDgoIn ITVD)... WLLen N.., Orede Top need 9,06'2 10,843.0 6,324.] 1260 L80 NSCT Liner Details N'ps1.E:5C-d Top Idan Top ITAIInKOI TopinMl°I Norrunal to Nem Oes Cam lnl g,9B]2 576 )0 53.74 TIEBACK BAKER PgCKER B TIEBACKSLEEVE 4438 B,B852 5,79 ,6 53.87 PACKER BAKER ZAP LINER TOP PACKER 4438 ces urr. a,rEg e 9,989.2 5,800.0 53.66 HANGER BAKER LJNER HANGER 4.500 10,327,7 e004] 53.86 NIPPLE CAMCO'D'NIPPLE- DRILLED OUTTO 3.8T 3.830 DURING ATTEMPT TO PULL FISH ZL2008 WORKOVER 10 520.7 6,118.5 51.81 NIPPLE OTIS XN'NIPPLE w.'NO Go,3812"PKG BORE, 3.']25 T.111%,1111- 3.)25" pb[Na Tubing Strings Tuning Oaccnpnon aang of ID (In) TUBING 412 3.88 Top IRKeI sN O.pm ln.. sA Dept Tm)r'. w10MR1 Orad. TopconnttNor. 2No 9891,) 5,8015 12.60 L80 IBT Completion Details .A C„'IE.- -. ,... I TaPITbDI Topmai nominal To Mae) InKBI IS Ile. Des Com 1011n1 29.8 See 0.01 HANGER EMC GEN V TUBING HANGER 4500 508.0 5080 1.9 NIPPLE CAMCO DB-6NIPPLE w/J.B)S TOPNOGO PROFILE 38)5 IT 9,933.4 5,7670 5388 NIPPLE CAMCODBNIPPLEM13.812PROFILE-DRIU DOUTT03.07 3.830 DURING ATTEMPT TO PULLFISH 2/82008 WORKOVER _ 9,957 S,]&i8 53.]0 LOCATOR BAKER GBH -22 LOCATOR 3858 9,979.9 5,744.5 5369 SEALASSY BAKER SEALASSEMBLYWPULESHOE 3,958 Other In Hole (Wireline retrievable plugs,: valves, pumps, fish, etc.) TIPOVD, Tell Top (DID) IRKeI 1°1 I Des Cam Run data ID llnl 10,301.0 5,986.0 5388 WM1lpstock HIM42450412' MONO -BORE XL WHIPSTOCK Z7/2019 a, urT,a=.,,E WITHFISHNECK. OAL153T 2PIPTAGS INSTALLED AT 10313'. - 10,400.0 6,0448 52,94 FISH PERFGUNPERFGUN DROPPED 724/01, TOP 192008 10,532, LENGTH 34.9, MAX 00 3,63': WORKED TO RETRIEVE THRUB29N1. WELLSHUTINB FREEZE e..,, a PROTECTED. W-BATSUBLEFTONTOPOF E -UNE TOOL 1025209: Fish PuIIeB up 110,312' CTMD 602005: Tagged Fish ge 10339RKB 1/192008Taggdd FisM1 @ 10301' SLUM 2/&2000 WORKOVER TO PULL FISH - ONLY PUSHED _ IT DOWNHOLE FROM 10312' TO 10400' Loc 1-T a a/P: Perforations 8 Slots Lk 111 spot omr ToplKKel Otm IRKe) Ta0i eM ITyDI MB) Gnkaa IDne Deb (an 1 Cam 10,446.0 10,468.0 8,92.] 6,084.9 C3,tJd0 ]/182001 6.0 ENa RE APERF 33/B'FINE, PJ chgs, fi0deg Ph 10,658.0 10,870.0 6,205.0 6,217.8 A-5, 1J-00 6'iZ2W16.O IPERF 2.5'H30 BH80P Frac Summary 7. oVCTrC.;f A1o:Ioa- sial... 6/162001 Pnppanoasl9nea hbl PNPPanlln Pann.11-lt) y la+,alo ' ll Sean Oah Topa--IRKeI BMI10,618.0 .1 1 6/182001 10,650.0 Llnk to Flultl Syslem VOICiYnlanll VOI Blurrylobll Mandrel Inserts M NI on Tap ITMO) Nlve Deep Pon.,. 1RORun N Top IRKBI 1".) Ni Model DD (in) Sary Type lyse Ilnl Ipa9 Run9rta Com 1 3,723,8 25584 CAMCO KBG-2 1 GASLLFT GLV BN 0188 1X80 12112019 430 2 6,311.] 3,7230 CAMCO KBG-2 1 GAS LLFT OV BN 0250 0.0 1202018 ):30 +I. ",I ,T 3 8,088.2 4,62).0 CAMCO KBG2 i GAS LIFT DMV BK 0000 00 320/209 590 4 9,132.6 5,283.0 CAMCO KBG-2 t GASIJFT DMV BK 0000 IS 523291 415 9,0622 5,]388 AMCKBG-2 1 GASIJFT DMY BK OG00 00 ^vB2014 ]:00 Notes: General S Safety End Data Apnalalbn ^_ 4/2008 NOTE. WRKOVER DONE TO PULL FISH, MILLED NIPPLES, UNSUCCESSFUL, PUSHED FISH DOWNHOLE 9/292010 NOTE: View Schematic w/ Alaska 5chematiC9.0 p" 1 I 0 Ukda. 1. 11 I CIII C- PTD toy —a -7J Loepp, Victoria T (DOA) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Wednesday, February 20, 2019 3:49 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 1J-10(PTD 201-071, Sundry 319-030) Close out whipstock sundry Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria, I will be sure to get all of those documents to you once the patch has been set. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, February 20, 2019 9:17 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: [EXTERNAL]KRU 1J-10(PTD 201-071, Sundry 319-030) Close out whipstock sundry Ryan, Please submit a 10-404 to close out this sundry since the well will be returned to production after drilling was discontinued after the window for the first lateral was milled. A sundry for an operations shut down is not required. However, in the 10-404 submission, please include the daily drilling report, operations report for patch setting, a schematic and an explanation of the operations that occurred under this sundry as well as future plans to return to the well. When drilling resumes, a new sundry for setting the whipstock will be required. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(�alaskaoov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at 19071793-7247 or Victoria.Loeno@oloska.aov From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillins.com> Sent: Tuesday, February 19, 2019 3:47 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Ohlinger, James J <James.J.Ohlinger@conocophiIli ps.com>; Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Haggerty -Sherrod @contractor.conocophillips.com> Subject: 1J-10 Operations Summary Hello Victoria, While drilling the 1J-101_1 lateral with our Liner Drilling BHA, we became stuck in the Kalubik at a depth of 10,362' MD. We dropped a ball to release off of our liner drilling BHA, then proceeded to rig up E -line to make a chemical cut at a depth of 10,330' MD. After a successful cut was made, we pulled the liner drilling BHA out of hole to a depth of 10,330' MD leaving the rest of the fish in hole (20' of liner, motor, drill bit). After this we ran in hole and pulled the whipstock that was set at 10,301' MD and cleaned the hole out to a depth of 10,326' MD. Plan forward is to set a patch over the window that was milled at 10,301' MD and return the well to production in the interim between coming back and making another attempt to drill the permitted laterals. I am planning on submitting a 10-404 to close out the whipstock. Current CTD schematic of 1J-10 is attached. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 PTD 20/-07/ Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, February 20, 2019 9:17 AM To: 'McLaughlin, Ryan' Subject: KRU 1J-10(PTD 201-071, Sundry 319-030) Close out whipstock sundry Follow Up Flag: Follow up Flag Status: Flagged Ryan, Please submit a 10-404 to close out this sundry since the well will be returned to production after drilling was discontinued after the window for the first lateral was milled. A sundry for an operations shut down is not required. However, in the 10-404 submission, please include the daily drilling report, operations report for patch setting, a schematic and an explanation of the operations that occurred under this sundry as well as future plans to return to the well. When drilling resumes, a new sundry for setting the whipstock will be required. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppeOalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loeoosolaska aov From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Tuesday, February 19, 2019 3:47 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Haggerty -She rrod @contractor.co nocophillips.com> Subject: 1J-10 Operations Summary Hello Victoria, While drilling the 11-101-1 lateral with our Liner Drilling BHA, we became stuck in the Kalubik at a depth of 10,362' MD. We dropped a ball to release off of our liner drilling BHA, then proceeded to rig up E -line to make a chemical cut at a depth of 10,330' MD. After a successful cut was made, we pulled the liner drilling BHA out of hole to a depth of 10,330' MD leaving the rest of the fish in hole (20' of liner, motor, drill bit). After this we ran in hole and pulled the whipstock that was set at 10,301' MD and cleaned the hole out to a depth of 10,326' MD. Plan forward is to set a patch over the window that was milled at 10,301' MD and return the well to production in the interim between coming back and making another attempt to drill the permitted laterals. I am planning on submitting a 10-404 to close out the whipstock. Current CTD schematic of 1J-10 is attached. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1J-10 Permit to Drill Number: 201-071 Sundry Number: 319-030 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aloskc.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this q - day of February, 2019. SCANNED FF'� 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 26 2RO RECEIVED JAN 2 5 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ r ions shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CO261 B Whipstock E]. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development Stratigraphic Service El❑ 201-071 3. Address: 6. API Number: PO Box 100360, Anchorage, AK 99510 50-029-23010-00 —00 113 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU U-110 Will planned perforations require a spacing exception? Yes ❑ No 1�1- ' 9. Property Designation (Lease Number): ;�,�, 10. Field/Pool(s): ADL 25660 A:K4 L 25661 Ku aruk River Oil Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,845' 6326' 10,843' 6324' 2315 N/A 10,400' Casing Length Size MD TVD Burst Collapse Structural Conductor 85' 20" 115' 115' Surface 6911' 9-5/8" 6938' 3991' Intermediate Production 10,199' 7" 1 10,231' 5944' Liner g76' 4-1/2"10,843' 6325' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10446'-10466', 10658'-10678' 6073'-6085', 6205'-6218' 4-1/2" L-80 9992' Packers and SSSV Type: Packer (Baker ZXP Liner Top Packer) Packers and SSSV MD (ft) and TVD (ft): Packer (9985'/5798') 12. Attachments: Proposal Summary ED Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 13 -Feb -19 OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. � Authorized Name: James Ohlinger Contact Name: Ryan Mcl-aug6 -s�� Authorized Title: Staff CTD Engineer Contact Email: Ryan. MCLau hlln CO .com //'�/f Contact Phone: 265-6218 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 0 30 Plug Integrity F-1BOPTest L� Mechanical Integrity Test ❑ Location Clearance ❑ Other: 50 P trs to 3 5-100 S . �Z S f fD 7`�vivlvlav Priv«� Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: /Q — qD7 Approved by: -4e4- APPROVED BY2- COMMISSIONER THE COMMISSION ate: tT4- 4111i'l ^ I L j�{a� p �roval. °' ht6 U 5 entsin onnand Form 10-403 Revised 4/2017 Approved application is valid for 2 'CT P1 \taf[� proval. �q�chments in Duplicate a. !R ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January23, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set a whipstock in the KRU 1J-10 (PTD# 201-071). Attached to this application are the following documents: - 10-403 Sundry Application for KRU 1J-10 - Operations Summary in support of the 10-403 Sundry Application - Proposed Pre -CTD Schematic - Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 1J-10 (PTD# 201-071) Summary for Sundry Background KRU Well 1J-10 is a Kuparuk producer equipped with 4-1/2" tubing and 4-1/2" production liner. The project targets stranded C -Sand resource to the south and east of 1J-10 into an area along the C -Sand margin south of existing production and injection. This project will involve drilling four CTD laterals from the 11-10 parent wellbore. The first lateral will kickoff from a mechanical whipstock set inside the 4-1/2" liner at 10,310' and will drill out 200' from the motherbore to straddle the Kalubik shale with Northern Solution's Liner Drilling BHA. The subsequent three laterals will target the Kuparuk C4 sand package with access gained from the 1J -10L1 lateral. Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock, obtain SBHP, C/O gas lift design 2. RU E -line: Caliper, set 4-1/2" monobore whipstock at 10,310' MD 3. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1J -10L1 Lateral (Straddle the Kalubik w/Liner Drilling BHA) a. Mill 3.80" window at 10,310' MD. b. Drill 3-3/4" lateral with ORCA liner drilling BHA to TD of 10,500' MD. c. Hydraulically release off 3-1/2" liner drilling BHA leaving TOL at 10,200' MD 3. 1J -10L1-01 Lateral (C4 sand - southeast) a. Set top of whipstock in 3-1/2" drilled in liner at 10,420' MD b. Mill 2.80" window at 10,420' MD c. Drill 3" bi-center lateral to TO of 15,200' MD. d. Run 2-3/8" slotted liner with aluminum billet from TO up to 12,300' MD. 4. 1J -10L1-02 Lateral (C4 sand -south) a. Kickoff of the aluminum billet at 12,300' MD. b. Drill 3" bi-center lateral to TD of 14,775' MD. c. Run 2-3/8" slotted liner with aluminum billet from TO up to 12,150' MD. S. 1J -10L1-03 Lateral (C4 sand - east) a. Kickoff of the aluminum billet at 12,150' MD. b. Drill 3" bi-center lateral to TD of 14,100' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 10,400' MD. 6. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 7. Obtain SBHP. 8. Return well to production. IJ -10 Proposed CTD Schematic 31/2" Cameo DM nipple @ 508' MD (3.875" min ID) 20" 81.5# H-40 shoe @ 120' MD 4_1/2" 12.6# IBT EUE and Tubing to surface 4-1/2" Cameo gas lift mandrels @ 1.-80 4-1/2" Cameo DB landing nipple @ 9933' MD (milled 3.87" min ID) shoe @ 6945' MD Baker 4-1/2"GBH-22 Locator Baker Seal assembly @ 9980' MD (3.958" ID) JL7 Baker Packer 8 Tie -Back Sleeve Baker ZXP Liner Top Packer @ 9985' MD (4.438" ID) Baker Liner Hanger 7" 26# L-80 shoe @ 16231' 0 s Cameo D -Nipple @ 10,328' MD (milled 3.67" ID) FISH @ Gun -330 Otis XNN-Nipple@10,521' u D(milled 3.725" ID) KOP @ 10,370' MD I Northern Solutions - ORCA Liner Drillina BHA Liner Hanger 3-1/Z'9.3# L -e0 Hyd511 KOP @-1 —0, 4-20' MD Burst Disc Sub 2-7/8" Motor 33/4" bit C -sand peds 10446' -10466' MD A -sand perfs w •'��. tddoum wp02 :5% TD -15,200 D 10656'-10678'16 11101.1 wp01 TD@-10,500'MD -- - -"' 4-1/2" @ 1012.6#L-80 Top of LNer0-10,200 MD --_-- ----- shoe ,843' MD 1J-101.1-02 wpOI TD14 116MD op of Billet @ 12,159 MD KUP PROD U-10 ConoeoPhillips Well Attributes Max Angle BMD TD Alaska, Inc, wxllw,e APRvwI FMa Name wenbo,e srMus 500292301000 KINARUK RIVER UNIT PROD ntl l') MDInKBI Act Bene (PIKE) 6].56 3.101.64 10 8450 JA ..=,L F -Date Last WO: 210/2008 KB�Gra 1111 Rig Rulme D+le 3511 524/2001 Co.-., NE(Ppm) DPe SSSV: NIPPLE 60 9I10201fi I - ID ant n0n 10:geea 6 Am e ica sc em nuc (aclull AnnyffiIon Deptn IXKB) Fna Date nenotatbn Lasl Moa By ENo DBte L, St Tag: RK. 10,348.0 32]201] Rev Reason TAG. GLV CAD. 12S Ppmven 3131201) HPNGEP, 796 Casing Strings crimp UCTOp0on OD 1in1 to pn TOP Intl35 ser Depth (n12 set Depth FIVE), wvL91 p._ Top Thinned H-40 CONDUCTOR 20 19.124 350 120.0 1200 91.50 H-40 WELDED Cads Description DID in) ID(in) Top IXKe) Set Noth(11M) Set Depth/TVD)... wt.11 Grade Top T r ....__..___.._...._......_.____ ....... SURFACE 85/ 0.835 345 89453 3,9954 40.00 L-80 BTC Carina OaavlPn- OD (in) /DRO Top (INKS, Set DeML(ft ) Ser Delam ITVDL-WVLMIL.Grses Top TMma PRODUCTION ] 6.2]6 31.] 10,2308 59444 26.00 L.00 BTC -MOD Cast- 0esmmt .on No (In) ID lin) TopIXKB) Set on"' (on, $et 0eptn(NDI... WVLen11...1-1 1.1 Tnrean LINER 4112 3.958 9.96].2 108430 6,324] 1260 L-00 NSCT Linger A@tpils ominal l0 COryOVCTO X', 35.0.1300 Top (NINE) Top (ND)7B7B) Top Inci F) rrem Dee in) AC 8.9622 S,TB].0 53]4 TIEBACK BAKER PACKER &TIEBACK SLEEVE 4,438 8.9862 5,797.6 5387 PACKER BAKER ZAP LINER TOP PACKER 4.438 MPPLE506.0 9,9892 5800.0 53.65 HANGER BAKER LINER HANGER 4500 10,3277 6,0017 53.05 NIPPLE CAMCOD NIPPLE- DRILLED OUT T03.87- 3,830 DURING ATTEMPT TO PULL FISH &02000 IMORKOVER 10.520.7 6,118.5 5181 NIPPLE ONS'XN'NIPPLE w/NO Go, 381"PKG BORE, 3.725 GASUPS:3II3e 3.725 ruffle Tubing Strings Tuning Cesapnoa smog Ma_. m8n) Fee NINE) Depm IX.. sN Cepm (ND) (_. wt Ibnp Grade ropconn«tion Sleet TUBING 6112 3.958 29. 9.991,] 5,801.5 12.60 1,80 IBT Completion Details GAS LI4T,6311./ - rvolnID Top(XKB) TopITVO)(aTopInd•1 lOCom (in) NFMCGENVTUBINGHANGER 4.500 296 296 0.01 HIN 5080 5080 1.97 PCMCODB-BNIPP.13875TOPNOG0PROFILE 3075 . 9,9334 5.78]0 5386 PCALICO UB NIPPLE w13812 PROFILE -DRLLED OUT 3.830 TO 3 87 DURING ATTEMPT TO PULL FISH 2182006 WORKOVER SDRFpEB3456sa53- 9 978 5,793.8 5370 LOCATOR BAKER GBH 32 LOCATOR 3.858 9,979.9 5,]94.5 5369 SEALASSY BAKER SEAL ASSEMBLY wI MULESHOE 3.958 GA6uFT,0,L56.z Other In Hole (Wirailne, retrievable plugs, valves, pumps, fish, etc.) TopIND) TopIncl Top KIND (a.) (.) Des Com Run O0. ID lln) 10,4000 68448 5294 FISH PERF GUN PERF GUN DROPPED 7124101, TOP 3/17/2008 10.532, LENGTH 34 4', MAX OD 363"', WORKED TO RETRIEVE THRU&29/01, WELL SHUT IN& GAS LIFT: 8.1326 FREEZE PROTECTED. 36' BAT SUB LEFT ON TOP OF E LINE TOOL 10252004: Fish Pullen up to10819' OTMD 6172005: Tagged Fish C 10338' RKB 11192008 Tagged Fish ®10301' SLM 2/02006 WORKOVER TO PULL FISH ONLY PUSHED IT DOWNHOLE FROM 10312' TO 10400' Gas uFT: Belix 2 Perforations & Slots anm Den NIPPLE: sai rop(dKB) Sam(XKB) Top(NO) @KB) Btm(N01 (AGE) IDne Date I..,. IT Type Co. 10,446.0 10.4660 0,0727 8.0848 03,1110 ]/19/2001 60 APERF 3310' PSD PJ chat, 60 deg ph 106580 106700 62050 62170 A-5. 1J-10 6112/2001 Lo /PERF I 2.5"HSO PIT &DP Stimulations & Treatments _ P..PPam Due". tl (lio) %opwm m Farmaeon lml Date LOLATOR:BB)07 6/16/2001 Stimulations & Treatments BEA -ASSY: 9.9799 Vol C"Ps Pump Endo Top ASB) San Rise) ..to 6tinnTrtlt Fluid (OOa Vol Slurry ReD 1 10,858.0 ID 670.0 6118/2001 Mandrel Inserts Ed as on Top Tied) Vi oush Portillo TRO Run Top("" MKIR Maya MOOet on (in) Sery Type Type on) (psi) Run OM Com 1 31723.8 2,558.4 BANKED KBG-2 1 GASLIFT GLV SK 0,180 1.1400 329/201) 4:30 PRODUCTION: 31.740=8 2 8,3117 3,)230 CAMCO KBG-2 1 GASLIFT OV BK 0.250 0.0 329/2017 730 3 8.060.2 4,62].0 CAMCO KBGZ 1 GAS LIFT DMY BK 0000 0.0 31292017 5.00 d 0132.6 5263.0 CAMCO TBG -2 1 GAS LIFT OMY BK 0000 00 5/232001 415 5 9,0022 5]368 CAMCO KBG-2 1 GASLI I -MY BK 0.000 0.0 2/92014 700 Notes: General 8r Saf4 End Dah Annotation2/8/2008 NOTE: WOPROVER DONE TO PULL FISH, MILLED NIPPLES; UNSUCCESSFUL, PUSHED FISH RSH:ds000 ..z= 9/29/2010 NOTE: View SchenDOES/Alaska Sclleensfc90 APERP,10446.0-10466.0- TEPP'108540106]60` , FR.,l1 ,,656.0 LINER', 9851.2-tO.IX30- Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC . ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 ."jrMj Anchorage, AK 99501 20 107 1 30305 WELL NAME 1B-1021 API # 50-029-23167.00 ORDERSERVICE # EOSH-00015 FIELD NAME DESCRIPTION I KUPARUK RIVER WL DELIVERABLE DESCRIPTION Caliper Ver2 DATA FINAL FIELD DATELOGGED Prints 1 -Jan -19 CD's 1 1J-10 50-029-23010-00 EOSH-00017 KUPARUK RIVER WL Caliper FINAL FIELD 17 -Jan -19 1 1H-119 50-029-23591-00 EOSH-00018 KUPARUK RIVER WL IPROF FINAL FIELD 18 -Jan -19 1 31-1-31A 50-103-20205.01 EOSH-00019 KUPARUK RIVER WL LDL FINAL FIELD 19 -Jan -19 1 3M-19 50-029-21737-00 EOSH-00020 KUPARUK RIVER WL LDL FINAL FIELD 20 -Jan -19 1 1H-116 50.029-23594-00 EOSH-00021 KUPARUK RIVER WL ]PROF FINAL FIELD 21 -Jan -19 1 1C-117 50-029-23027-00 EOSH-00022 KUPARUK RIVER WL RST-WFL FINAL FIELD 22 -Jan -19 1 AN 3 0 209 7 A Transmittaloeetc) ha, pt been nature confirms conthat a package (box, ozkl —O envelope, etc.) hay been received and the contents of the X (!%„J l package have been verified to match the media noted above. The Signature Date specific content ofthe CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this courier or sign/scan and email a copy t Sc Iumberger and CPAI. point. rter@slb.com Tom.Osterkamn@conocoohil ios.com SLB Auditor- -31A Schlumberger -Private Image~ ,'oject Well History' File Cover I:l" je XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c~C) 1_-0.7I Well History File Identifier RESCAN DIGITAL DATA [] Color items: J Diskettes, No. ¢:~ OVERSIZED (Scannable) [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL ~ WINDY [] [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~ WINDY Scanning Preparation ~ x30= &O BY: BEVERLY ROBIN VINCENT SHERY~WINDY Production Scanning Stage I PAGE COU.T FROM SCA..ED PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION:... YES Stage 2 IF NO IN STAGE 1 ~ PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDBT: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE:' Isl Quality Checked III IIIllllllllll 12/10/02Rev3NOTScanned.wpd ~ U COr1 ~ . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • SEP a 2 2aos Al~~k~ ~~I $~ C~~ ~~na..Co 'ssioa AnGhO~~ aa~-o71 ~~-10 ~.. ~"~ ~ _ . : ~l r :;~ Enclosed please find a spreadsheet with a list of wells from the Kupaxuk field (KRI~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23`a 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, .,~° ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • f ''h ~ `~ ~ ~ ~ ~~ ~ ~' ~;: ~" S ~ r~ , ~}~f~ ~ ~. 7(lr~.~ ConocoPhillips Ataska Inc. $'~~~:a~f,trP~ ~Mi P~?i. ~%4%~ ~.9E~"Cf. I,.vye4s{~,.~~Cp~~Ve ~,.A~O.~'. ~F~~%f`~ Eyi'.l Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date ell Name PI # TD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor ..,.,.., . Corrosion inhibitor/ sealant date bbls ft al __. 1J-03 50029230020000 2010240 22" N/A 22" N/A 4.1 8/29/2009 1J-09 50029230060000 2010440 28" N/A 28" N/A 6.2 8/29/2009 1J-10 50029230100000 2010710 12" N/A 12" N/A 2.3 8/29/2009 1J-133 50029233150000 2061060 3' N/A 3' N/A 23.8 8J30/2009 36-24 50103201450000 1901340 18" N/A 18" N/A 5.1 8/30/2009 1A-19 50029221110000 1901610 30" N/A 30" N/A 3.8 8/30/2009 2Z-04 50029209650000 1830860 19" N/A 19" N/A 3.5 8/30/2009 2Z-05 50029209560000 1830760 12" N/A 12" N/A 2.1 8/30/2009 2Z-07 50029209460000 1830640 9" N/A 9" N/A 8.5 S/30/2009 2Z-15 50029213620000 1851080 9" N/A 9" N/A 2.8 2Z-21 50029218770000 1881250 3' N/A 3' N/A 19.6 8/30/2009 Kuparuk Field ~i~r_~e 2ZPAD Page 1 of 1 • • Maunder, Thomas E (DOA From: Gober, Howard [Howard.Gober@conocophillips.com] Sent: Wednesday, May 28, 2008 10:02 AM To: Maunder, Thomas E (DOA) Subject: RE: KRU 1J-10 (201-071) Tom, The production tubing was not pulled on 1J-10. The workover was done through the 4-1/2" production tubing. We were attempting to recover a pert gun that is stuck in the 4-1/2" liner below the seal assembly. We did ND the tree and NU the BOP stack to the tubing head flange, but the tubing hanger was not pulled through the stack. Please let me know if you have any further questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell ~~~~~ ~U~ Howard.Gober@conocophillips.com p~~. ~~ ~ \CC~ fit- v~ ~~ ~C ~~r ~ri~°~v,~ ~ r ~~~® r ~ 2008 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, May 22, 2008 9:08 AM To: Gober, Howard Subject: KRU 1J-10 (201-071) Howard, 1 am reviewing the 404 submitted for the work performed in late January/early February on this well. On January 30 immediately after NU and testing the BOP, fishing commences with the TOF @ 10336'. When was the tubing pulled out of the well? I looked into our file and do not show any rig work since the well was drilled in late May 2001. Can you provide some details? Thanks in advance, Tom Maunder, PE AOGCC 5/28/2008 ~~ S RIE~EiilE® STATE OF ALASKA MAY 0 1 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERgTIONl~ska Oil & Gas Cons. Commissian 1. Operations Performed: Abandon ^ Repair Well ~ - Plug Perforations ^ Stimulate ^ Other nc rage Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ ' Exploratory ^ 201-071 / ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-2301 ~-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 29.6' - 1J-10 ' 8. Property Designation: 10. Field/Pool(s): _ ADL 25660 - Kuparuk River Field !Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10845' _ feet true vertical 6326' - feet Plugs (measured) Effective Depth measured feet Junk (measured) 10400' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 120' 120' SURFACE 6915' 9-5/8" 6945' 3995' PRODUCTION 10201' 7" 10231' 5944' PROD LINER 876' 4-1/2" 10843' 6325' Perforation depth: Measured depth: 10446'-10466', 10658'-10678' ' ' ' ' ~~ SUN ~ 2DD6 true vertical depth: 6073 , 6205 -6218 -6085 Tubing (size, grade, and measured depth) 4-1 /2" , L-80, 9979' MD. Packers & SSSV (type & measured depth) pkr= BAKER ZXP PACKER pkr= 9985' Camco nipple @ 508' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer Signature Phone Date ~~ ~~ haron A su D k 263-4612 P red Form 10-404 Revised 04/2006 ~~` ~ ~ t ~~ ~ ~ ~ ~I~ ~ ~ ~~~~ ~~,t/,,,submit Original Only~~ ,~I~AL ~l~i ~~ r• ~.y dg ~~~ r~ ConocoPhillips Time Log Summary Nle/rir7ew Web ReAOrtPng Well Name: 1 J-10 Job Type: RECOMPLETION I Time Loys _ _ Date From To Dur S . De th E De th Phase Code Subcode T COM 01/28/2008 00:00 01:00 1.00 _ _ MIRU MOVE RURD P _ Move Nordic 3 rig off of 1J-159. 01:00 03:00 2.00 MIRU MOVE OTHR P Prep location for rig -shoot grade and level. Han new tree for com letion. 03:00 04:00 1.00 MIRU MOVE RURD P Move in and spot rig. Set and level up ri . 04:00 06:00 2.00 MIRU RPCO OTHR P Accepted rig at 04:00 hrs. Continue to clean pits and prepare well for work over. 06:00 08:00 2.00 COMPZ RPCOti RURD P Spot / RU all support bldgs, make all connections. Make ready all equip for workover. 08:00 14:00 6.00 COMPZ RPCO NUND P PJSM, ND tree connections. Several valves leaking on tree. NU double valves to tree. MU kill lines /test. MU lubricator 1465 si on tb ull 14:00 16:30 2.50 COMPZ WELCT KLWL P PJSM, bullhead 150 bbls seawater do tbg. Initial 1465 psi, final 700 psi / 2 bpm. Stop pump. Press 500 psi. Monitor well, pump addtnl 100 bbls, identical pressures. Monitor well. Attem t bleed. Will not bleed. 16:30 00:00 7.50 COMPZ RPCOh PULD P PJSM, load pipeshed with 2-7/8 DP while WO re-wei hted brine for kill. 01/29/2008 00:00 01:00 1.00 COMPZ RPCOti SFTY P PJSM and service rig. 01:00 09:00 8.00 COMPZ WELC CIRC P Open well up w/ 960 psi. Begin pumping 168 bbls of 10.5 ppg kill fluid @ 2 bpm @ 960 psi. FCP @ 60 psi. SWI and monitor for 30 min. Had small influx of of 25 psi. Monitor we-I for 30 min and pressure gained to 350 psi. Mix and pump 50 bbl hi visc pill and follow w/ 118 bbls of 10.5 ppg Kill fluid. Monitor well. bleed to "0" osi. Well static. 09:00 12:00 3.00 COMPZ RPCO NUND P PJSM, Set BPV, ND prod tree, install blankin lu . 12:00 16:30 4.50 COMPZ RPCOti NUND P PJSM, NU BOPE, all related equip. 1~~~ 1 of 6 Time Logs ______ _ Date From To Dur S. De th E. De th Pha e Code Subcode T COM 01/29/2008 16:30 00:00 7.50 COMPZ RPCO NUND P PJSM test BOPE all com onents, 250 / 2500 psi. Witness of test waived by John Crisp - AOGCC Inspector - 1/28/08 at 2000. Lower set of pipe rams failed test. Swap out 2 7/8" LPR's w/ 4 1/2" rams, retest, failed. Pull ram blocks and prepare to break stack and remove single gate from stack. Seek variance from AOGCC on stack configuration, i.e. leaving non-functioning single gate in stack, no response, break out stack and start removal of LPR section. 01/30/2008 00:00 07:00 7.00 COMPZ RPCO NUND T ND stack, break out LPR assy, install spacer spool, reset BOP stack and ni le u .Pre are to retest breaks. 07:00 08:00 1.00 COMPZ WELC BOPE T PJSM, Re-test BOP body, spool, flan es 250 / 2500. Test successful. 08:00 09:00 1.00 COMPZ RPCO OTHR P PJSM, remove blanking plug, pull BPV, install tbg hgr neck thread rotector. Note well on vacuum. 09:00 11:00 2.00 COMPZ RPCOh PULD P Load shed with fish tool assy, BHA. Pre are, stra same. 11:00 14:00 3.00 COMPZ RPCOti PULD P MU BHA #1, GS spear assy, RIH same. 14:00 18:00 4.00 COMPZ RPCOh PULD P PJSM, flow check (vacuum), follow BHA with 2-7/8 work strin . 18:00 19:30 1.50 COMPZ RPCO CIRC P Fill hole w/ charge pump, 116 bbls, monitor well, fluid dro in . 19:30 00:00 4.50 COMPZ RPCO PULD P Continue RIH w/ fishing BHA #1 f/ 3800' - 7944' w/picking up 2 7/8" HT PAC DP from pipe shed. PU 113 klbs, SO 65 klbs. 01/31/2008 00:00 03:00 3.00 COMPZ RPCOh PULD P Cont RIH f/ 7947' - 10285', PU HU top ~~ h~ ~~ ~~`~ drive, cont single in to locate TOF. Tack. TOF 10336'. 03:00 04:00 1.00 COMPZ FISH JAR P PU, latched into fish. Attempt to jar / free fish, no success. String PU 145 klbs. Jar at overpull 35 klbs over, straight pull to 210 klbs, no movement, repeat x 5. Unlatch, prepare to displace lub. Well still on vacuum. 04:00 05:00 1.00 COMPZ FISH CIRC P Mix and pump 35 bbls 10 ppg brine w/ 0.6 %SafeLube down DP, chase w/ 25 bbls brine, pump 45 bbls 0.6% SafeLube down DP / Tbg annulus. BD top drive and prepare to resume 'arrin .Well still on vacuum. F°~ge 2 of 6 r~ Time Logs Date From To Dur 5 De th E. De th Phase Code Subcode T COM 01/31/2008 05:00 06:00 1.00 COMPZ FISH JAR P Latch back onto fish, start jarring action. String PU 140 klbs. Initiate jarring at 30 klbs over, work up to 45 klbs over. Straight pull t/ 225 klbs. Alternate jar, straight pull and down stroke w/ bumper jar on fish to loosen. @ 30 strokes, noted lack of jarring action on pick-up. Noted string wt of 125 klbs. Set down depth still 10336'. Repeat, no furtherjar action. Decide to POOH and check BHA. 06:00 12:00 6.00 COMPZ FISH TRIP P PJSM, POH 2-7/8 DP to BHA. 12:00 13:30 1.50 COMPZ FISH PULD P Flow check, hole full with 5-10 bph losses. LD BHA #1. No fish. Nothing lost in hole. Fish tool dams ed. 13:30 15:00 1.50 COMPZ FISH WOEQ P Clear floor, arrange pipe shed while wait on new tool. 15:00 16:30 1.50 COMPZ FISH PULD P _MU fish BHA #2, RIH same, flow check, losses 5-10 b h. 16:30 22:00 5.50 COMPZ FISH TRIP P Follow BHA with 2-7/8 DP, RIH t/ 10300 ft. 22:00 23:00 1.00 COMPZ FISH CIRC P kelly up, pump 50 bbls 10 ppg brine w/ 0.6 % SafeLube down dp, displace over fish w/ 20 bbls Blow down top drive, pump additional 10 bbls down backside, hole full. 23:00 00:00 1.00 COMPZ FISH JAR P Latch onto fish, begin jarring operations. Begin w/ 20 klbs overpull on jars w/ 70 klbs straight pull. Work up to 35 klbs and 90 klbs straight pull. Cont. jar /work string. Hold wt up various intervals. No success, Spear 02/01/2008 00:00 06:00 6.00 COMPZ FISH JAR P Jarring on fish. PU 135 klbs, SO 75 klbs. Jar 35 klbs over, Dead pull 230 klbs. No ro ress. Pum off fish. 06:00 08:00 2.00 COMPZ RIGMN OTHR P Blow down top drive, lay do 1 jt, hang blocks, S&C drill line. 08:00 08:30 0.50 COMPZ RIGMN' SVRG P Inspect and service top drive. 08:30 12:00 3.50 COMPZ FISH JAR P MU top drive, relatch onto fish and be in 'arrin o erations. Up force on jar, 35 - 40 klbs, Dead pull 90 klbs over. Free string wt PU 138 klbs, SO 78 klbs. Sheared off fish, unable to re-latch. Prepare to POOH and ins ect tools. 12:00 18:00 6.00 COMPZ FISH TRIP P PJSM, POOH w/ Fishing BHA #2, f/ 10336' - 582' TOC's. 18:00 20:30 2.50 COMPZ FISH PULD P PJSM, Break out and swap out accelerator and jars, C/O spear. Pulled spear showed apparant wear on collet but no dams a otherwise. 20:30 22:00 1.50 COMPZ FISH PULD P Remove old tools from floor, build up fishin BHA #3. Page 3 s~f 6 r~ Time Lo s Date From To Dur 5. De th E. De th Phase Code Suhcode T COM 02/01/2008 22:00 00:00 2.00 COMPZ FISH TRIP P TIH t/ 4814' MD. PU 80 klbs, SO 70 klbs. 02/02/2008 00:00 02:00 2.00 COMPZ FISH TRIP P TIH f! 4814' - 10300'. RU and pump 56 bbls to insure no obstruction in G s ear sub for unlatch. 02:00 04:00 2.00 COMPZ FISH OTHR P Attem tinq to latch onto fish. Tag up at 10336' and work i e. Multi le attempts failed to latch up on fish. Attempt to orient and wash down. No latch abort and re are to POOH. 04:00 09:00 5.00 COMPZ FISH TRIP P POOH for BHA #4 (Jar do assy) 09:00 10:30 1.50 COMPZ FISH PULD P Flow check, LD BHA #3. Fill hole, 65 bbls. 10:30 13:30 3.00 COMPZ FISH PULD P MU BHA #4 Jar Dn Ass , RIH same. 13:30 17:30 4.00 COMPZ FISH TRIP P Flow check, follow BHA with 2-7/8 DP to to fish 10336 ft. Kell u . 17:30 19:00 1.50 COMPZ FISH JAR P PJSM, flow check, commence jar do on fish w/ 20 klbs down. Jar fish free, follow with sin les 2-7/8 DP to 10402' and tag TOF. Set down on fish, no- o. 19:00 22:30 3.50 COMPZ FISH CIRC P Mix viscous pill to clean TOF. Mix additional brine, (9.8 ppg), pump sweep around to insure no debris on fish. 22:30 00:00 1.50 COMPZ FISH CIRC P Blow down top drive, prepare to POOH. POOH f/ 10402' - 8508'. 02/03/2008 00:00 05:00 5.00 COMPZ FISH TRIP P POOH to top of BHA #4. 05:00 05:30 0.50 COMPZ FISH PULD P Break out hammer sub, install ID grapple fishing tool prep to RIH w/ BHA #5, fishin ass . 05:30 10:00 4.50 COMPZ FISH TRIP P TIH w/ fishin BHA #5 to to fish at 10405 ft 10:00 12:30 2.50 COMPZ FISH JAR P Flow check, circ /clean TOF, engage and 'ar free. Pull up to "D" nipple at 10329. Can not drift D nipple. Jar do / free fish. 12:30 16:30 4.00 COMPZ FISH OTHR P RIH to 10405 ft. Drop ball, pump dn, press to 4100 psi, release safety disconnect sub. Confirm release. 16:30 17:00 0.50 COMPZ FISH OTHR P Flow check, rotate 2-7/8 string, record torque for mill parameter. Torque 2680 ft lbs. 17:00 17:30 0.50 COMPZ FISH TRIP P PJSM, flow check, static losses 3-7 bph with 9.6 ppg fluids. Blow down top drive, POH 2-7/8 DP for mill ass . 17:30 22:00 4.50 COMPZ FISH TRIP P POOH f/ 10314' - 577'. 22:00 23:30 1.50 COMPZ FISH PULD P UD DC's and Break out BHA #5, LD same. 23:30 00:00 0.50 COMPZ FISH PULD P PJSM, remove unnecesary eq from floor, Start PU of BHA #6. MU DC, boot basket, 3.833" string mill and accelerators. E'~ge~ of r~ Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 02/04/2008 00:00 01:00 1.00 COMPZ FISH PULD P Finish PU milling /fishing BHA #6. 01:00 02:00 1.00 COMPZ FISH PULD P RIH w/picking up DC's. 02:00 07:00 5.00 COMPZ FISH TRIP P Continue TIH w/ millina / fishina BHA _ at 9926 ft 07:00 08:00 1.00 COMPZ FISH MILL P Flow check, mill DS nipple to 3.833 ID. Re-cip /polish nipple, confirm thru bore clear. 2bpm / 1500 psi / 55 rpm. D namic losses 75 b h. 08:00 08:30 0.50 COMPZ FISH MILL P RIH t to DB ni le at 10377 ft. 08:30 10:00 1.50 COMPZ FISH MILL P Attem t mill out bore to 3.833. No ro ress, mill dulled out. 10:00 15:30 5.50 COMPZ FISH TRIP P PJSM, flow check, static losses at 10 b h. POH for mill. 15:30 18:30 3.00 COMPZ FISH PULD P Flow check at BHA, re-config BHA, MU new string mill on BHA #7. PU DC's. 18:30 00:00 5.50 COMPZ FISH TRIP P RIH w/ 2 7/8" DP f/ 582' - 9276'. 02/05/2008 00:00 01:00 1.00 COMPZ FISH TRIP P RIH f/ 9276' - 9909' 01:00 01:30 0.50 COMPZ FISH MILL P MU Top Drive, w/ pumping @ 2 bpm, run mill though profile @ 9926', re-dress. Profile clear, no catch. 01:30 02:00 0.50 COMPZ FISH TRIP P Cont RIH f/ 9941' - 10321', PU 117 klbs, SO 80 klbs. 02:00 03:00 1.00 COMPZ FISH MILL P MU TD, while circ @ 2 bpm and rotating @ 55 rpm, locate lower nipple 10342 DD, be in milling ops. Milled .7 ft w/ 3.1 k-ftlbs Tq. Repeat pass x 5 to verify bore clear. BD Top drive. 03:00 04:00 1.00 COMPZ FISH TRIP P RIH f/ 10353' - 10397, engage TOF., Latch on w/spear. PU, pull to nipple, unable to pull through nipple. Stick fish, be in ~arrin o s. 04:00 05:00 1.00 COMPZ FISH FISH P Jarring ops to either pull fish or drive back. Free fish downward using bumper sub. Drive fish back to 10395'. Release fish. 05:00 07:00 2.00 COMPZ FISH TRIP P PJSM. Start TOH w/ BHA #7 f/ 10,336' to 9843' standin back. 07:00 08:30 1.50 COMPZ RIGMN SVRG P Slip & Cut drill line. 08:30 09:30 1.00 COMPZ FISH TRIP P Continue POOH f/9843' to 8988' standin back drill i e. 09:30 17:30 8.00 COMPZ FISH PULD P Change of plans,;decision made to RD off of well. Continued to POOH f/8988' but started laying down drill pipe instead of standing back in derrick. POOH t/ 1873' w/ laying down 2 7/8" PAC DP. 17:30 18:30 1.00 COMPZ FISH TRIP P Trip in hole w/ previously pulled DP stands to continue la in out. gage a of fi Time Logs Date From To Dur S De th E. De th Phase Code Subcode T C OM 02/05/2008 18:30 22:00 3.50 COMPZ FISH PULD P _ POOH w/ laying down 2 7/8" PAC DP to to of BHA. 22:00 00:00 2.00 COMPZ FISH PULD P POOH, break out and lay down fishing /milling BHA. Offload tools from rig floor. 02/06/2008 00:00 08:30 8.50 COMPZ WELC NUND P PJSM, Pull wear ring (thread protector) from hanger threads,set BPV, Nipple down BOP's for rig move. ND stack, prep for storage. Reinstall sin le ate & chan a over on riser. 08:30 12:00 3.50 COMPZ WELC NUND P NU tree & adaptor flange. Test void to 5000K. 12:00 13:00 1.00 COMPZ WELC NUND P PJSM. test tree to 250/5000 psi. Pull 2 wa check. 13:00 14:00 1.00 COMPZ RPCO FRZP P RU Little Red Hot Oil unit and pump 35 bbls diesel freeze protect down tubing @ 2 BPM start @ 300 psi endin 0 si. 14:00 16:00 2.00 COMPZ WELL OTHR P Set BPV: Secure well. Move rig off well. Release rig @ 16:OOhrs 2/6/08. Move ri to 3H-16 F~~qe S of fi • 1 J-10 Pre-Rig and Post-Rig Events • DATE SUMMARY 8/30/07 T-POT (PASSED), T- PPPOT (PASSED), IC-POT (PASSED), IC-PPPOT (PASSED), FUNCTION TEST LDS. 8/31/07 SI-TIFL -PASSED 10/18/07 BRUSHED TBG TO FISH AT 10312' SLM. TAGGED DB NIPPLE AT 9933' RKB/9907' SLM WITH 2.87" GAUGE RING. IN PROGRESS. 10/19/07 SET EST AND GAUGES ON 3.812" DB LOCK WITH KOBE K/O (155" OAL, 1.7" MIN ID, REQUIRES 22"-25" EQ PRONG) AT 9933' RKB. "*""*NOTE: TOOL PROGRAMMED TO SHUT IN WELL AT 1330 HRS, 21 OCT; REOPENS AT 1330 HRS, 24 OCT.""""''` 10/25/07 PULLED DHSIT W/ GAUGES @ 9933' RKB 10/29/07 RAN CALIPER SURVEY FROM 10321' SLM TO SURFACE. **GOOD DATA**. JOB COMPLETE. 1/19/08 TAGGED BAITED FISH @ 10301' SLM WITH 3.75" LIB.SET 3.81 CAT SV IN NIPPLE @ 9933' RKB.PULLED STA #5 ORFICE VLV @ 9882' RKB.ATTEMPT TO PULL STA #2 LGLV,PULLED DOGS.IN PROGRESS. 1/20/08 PULLED 1" LGLV FROM STA #3 @ 8068' RKB.RIG DOWN FOR RIG JOB.IN PROGRESS 1/21/08 REPLACED LGLV'S FROM STA #1 AND #2 @ 3724' AND 6312' RKB W / 1" DV'S.SET STA #3 DV @ 8068' RKB.READY TO CIRCULATE THROUGH STA #5 @ 9882' RKB 1/22/08 CIRCULATE 190 BBL'S 9.6 BRINE FOLLOWED BY 155 BBL'S CORROSION INHIBITED SEAWATER DOWN TBG UP IA.PUMP 100 BBL'S DIESEL DOWN IA.ALLOW TO UTUBE.SET 1500# CSG SOV IN STA #5 @ 9882' RKB.TBG TEST TO 2500#.GOOD.PULL CAT SV FROM 3.81" NIPPLE @ 9933' RKB. ~ C., 1iVp~Z~ 2/20/08 HALLIBURTON VIDEO LOG WITH SIDE VIEW CAMERA. VIDEO TOP OF PERF N FISH AT 10400' AND MILLED OUT NIPPLES AT 9933' AND 10328' UTILIZING PUMPED NITROGEN. GOOD VISIBILITY. 2/28/08 GAUGED TBG WITH 3.84" TAPERED SWAGE TO 9933' RKB TOP DB NIPPLE. RAN 3.87" G/R TO 8068' RKB, UNABLE TO PASS GLM. READY FOR CTU. 3/2/08 JOB POSTPONED DUE TO LATE ARRIVAL FROM ALPINE. PERFORMED WEEKLY BOP TEST. 3/3/08 MILLED DB NIPPLE @ 9933' RKB FROM 3.830" TO 3.870". TAGGED UP IN PACKER 9985' RKB UNABLE TO WORK THROUGH OR MAKE HOLE. POOH TO CHECK BHA, DISCOVERED MOTOR FAILURE, JOB IN PROGRESS. 3/4/08 Attempt to mill out D-Nipple @ 10328 RKB, Tagged up @ 10012 CTMD, Unable to mill through obstruction, appears to be moving, Will rtn in A.M. with venturi. 3/5/08 Perform Millout of D-nipple, RIH with venturi on first run, very little solids in basket, RBIH to .taa of 10008 CTMD Milled through obstruction continued on to nipple @ 10313 CTMD Milled out to 3.87, Freeze protected Well, Turned over to S/L. 3/13/08 TAGGED FISH @ 10383' WLM. IN PROGRESS 3/14/08. RECOVERED METAL SHAVINGS FROM TOP OF FISH W/ MAGNET, ATTEMPT TO LATCH FISH @ 10383' WLM. IN PROGRESS 3/15/08 RAN MAGNET 8~ BAILED METAL SHAVINGS, ATTEMPT TO LATCH FISH, PICTURE OF F/N. IN PROGRESS 3/16/08 BAILED SOLIDS FROM F/N, ATTEMPT TO PULL FISH 3/17/08 SET 3.5" G-HYDROLIC SPEAR W/ BAIT SUB @ 10386' WLM, ATTEMPT TO PULL FISH. IN PROGRESS 3/18/08 MOVED FISH UP FROM 10373' SLM TO 10354' SLM. (( BAITED HYDRAULIC GS SPEAR STILL ENGAUGED INTO FISH--34.5" OAL )). 3/20/08 MOVE FISH UP HOLE FROM 10362' SLM TO 10354' SLM. RIG DOWN FOR UPCOMING RIG JOB. 3/23/08 RIG UP BRAIDED LINE. BEAT ON FISH @ 10338' BLM FOR 3 HOURS W/ NO MOVEMENT (NOTE: OAL OF FISH IN HOLE W/ BAIT SUB ASSEMBLIES IS 43' ). _ . 3/31/08 RIH WITH 3.5" G SPEAR A~TCIFJ-nm~fe~~~~R~t~ig0~ilf~T~BLE TO PULL FISH UP HOLE TO 9800' CTMD.RIH AGAIN TO CONFIRMED WE HAD FISH AND TAG @ 10,294' CTMD.STARTED POOH AND LOST FISH BETWEEN THE TWO NIPPLE DOWNHOLE.POOH AND FOUND METAL SHAVING AND SAND BETWEEN COLLETS THAT ALLOW THE FISH TO RELEASE AFTER SETTING DOWN.RETURN IN AM AFTER REBUILDING GS SPEAR. 4/1/08 MADE TWO ATTEMPTS TO RECOVER FISH AT 10348' CTMD, FIRST RUN UNABLE TO LATCH FISH, CHANGED OUT SPRING IN G SPEAR AND WAS ABLE TO LATCH ON THE SECOND RUN WITH A 6K JAR LICK UP BUT PULLED FREE OF FISHING NECK, TURN OVER TO SLICKLINE TO INVESTIGATE. (IN PROGRESS ) 4/2/08 TAGGED BAITED FISH WITH 3.60 IMPRESSION BLOCK (a~ 10319' SLM: CLEAN FISH NECK. LATCHED FISH WITH GR NO PROBLEMS. HIT FOUR 1500 LB OIL JAR LICKS BEFORE SHEARING GR. READY FOR CTU. 4/14/08 MADE FISHING RUN WITH BAKKE HAMMER, LATCHED FISH AT 10345' CTMD, HAMMERED UP FOR 1 HR AND CAUGHT STALL WITH HAMMER RIH TO RELEASE PSI ON HAMMER AND PUSHED FISH DOWN HOLE 15' TO 10360' CTMD, PUH LOOKED LIKE FISH WAS ON WHILE POOH, ONCE AT SURFACE CONFIRMED NO FISH, STAND BACK FOR THE NIGHT, RETURN IN THE AM (( IN PROGRESS)) 4/15/08 RIH WITH BAKKE HAMMER AND 2.50" G-SPEAR AND LATCH LOST PERF GUNS 10410' CTMD.QULLED UP HOLE AND STRUCK FISH INSIDE NIPPLE @.10328' MD.UNABLE TO MOVE FISH AFTER WORKING HAMMER FOR SEVERAL HOURS.RELEASE FROM FISH AND POOH,RETURN IN AM FOR ANOTHER TRY WITH JARS. 4/16/08 JARRED ON LOST TOOL STRING A TOTAL OF 40 UP LICKS AND 41 DOWN LICKS WITH NO MOVE~ENT,PUMP OFF FISH AND POOH.ESTIMATED TOP OF FISH (c7 10326' CTMD.LEFT WELL SHUT IN AND FREEZE PROTECT.JOB SUSPENDED. 4/28/08 SET CATCHER SUB @ 10309' SLM. PULLED SHEARED SOV @ 9882' RKB. IN PROGRESS. 4/29/08 SET GLV DESIGN @ 3724', 6312', 8068', AND 9882' RKB. PULLED CATCHER SUB @ 10309' RKB. JOB COMPLETE. ,~, # C~onc~~~Phillips ~#1~$~Ca, Ind. 1 J~ - API: 500292301000 TUBING SSSV Type: Nipple Iass7s, OD:4.500, ID:3.958) Annular Fluid: • KRU 1 J-10 Well T e: PROD An to TS: 53 de 10394 Orig 5/24/2001 Angle @ TD: 49 deg @ 10845 :om etion: Last W/O: 2/8/2008 Rev Reason: WORKOVER TO PULL FISH Casing String -ALL STRINGS uescn tan sae t o esottom i vu m ~raae i nreaa CONDUCTOR 20.000 0 120 120 91.50 H-40 WELD SURFACE 9.625 0 6945 3995 40.00 L-80 BTC PRODUCTION 7.000 0 10231 5944 26.00 L-80 BTC-mod PROD LINER _ ~Tubin String -TUBING _-__ Size Top _4 500 0 _ Perforations Summary --. Interval TVD 4.500 9967 ottom TVD 9979 5794 _ Zone Status Ft 10843 6325 12.60 L-80 NSCT -- - Wt Grade Thread 1260 L 50 IBT __ _ SPF Date T Comment 10446 - 10466 6073 - 6085 C-3 20 6 7/19/2001 APERF 3 3/8" PSD PJ chgs, 60 deg h 10658 - 10678 6205- 6218 A-5 20 6 6/12/2001 (PERF 2.5" HSD BH & DP Stimulations Interval & Treatments Date T e __ Comment 10658 - 10678 6/16/2001 FRAC 'A' SAND FRAC, 64M# BEHIND PIPE; 6.2 PPA ON PERFS _ ---.. Gas LiR MandrelsNalves - --- St MD TVD Man Mfr Man Type __ V Mfr V Type V OD Laich Port TRO Date Run Vlv Cmnt 1 3724 2559 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 1/22/2008 2 6312 3723 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 1/21/2008 3 8068 4627 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 1/21/2008 4 9133 5283 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 5/23/2001 5 9882 5737 CAMCO KBG-2 CAMCO SOV 1 0 BK 0.000 0 1/22/2008 (7iher (plugs, equip. etc.) -JEWELRY _- De th TVD T e Descri lion 508 508 NIP CAMCO'DB-6'ni lew/3.875'to NO GO rofile 9933 5767 NIP CAMCO 'DB' nipple w/3.812 profile - DRILLED OI ATTEMPT TO PULL FISH 2/8/2008 9992 5802 SEAL BAKER SEAL ASSEMBLY W/MULESHOE Outer (plugs,, equip.Letc.)_ LINER JE_ WELRY De h TVD T e Descri lion 9967 5787 SLEEVE-TB BAKER TIE-BACK SLEEVE _._.. sh -FISH De th Description 10400 PERF GUN Perf :10446-10466) - ID 4.438 PACKER 4.375 NIPPLE -DRILLED OUT TO 3.83" DURING ATTEMPT TO 3.830 'J8/2008 PPLE w/No Go, 3.812" PKG BORE, 3.725" rofile 3.725 3.958 __ _- ---- Comment PERF GUN DROPPED 7/24/01, TOP 10,532', LENGTH 34.4', MAX OD 3.63"; WORKED TO RETRIEVE THRU 8/29/01. WELL SHUT IN & FREEZE PROTECTED. 36" BAT SUB LEFT ON TOP OF E-LINE TOOL 10/25/2004: Fish Pulled upto10,312'CTMD 6/7/2005: Tagged Fish @ 10339' RKB 1/19/2008 Tagged Fish @ 10301' SLM 2/8/2008 WORKOVER TO PULL FISH -ONLY PUSHED IT DOWNHOLE FROM 10312' TO 10400' FRAC ;10658-10678) Pert ;10658-10678) • Memory Multi--Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1J-10 Log Date: October 29, 2007 Field: Kuparuk Log No.: 7199 State: Alaska Run No.: 1 API No.: 50-029-23010-00 Pipet Desc.: 4.5" 12.6 Ib. L-80 IBT lap Log Intvl1.: Surtace Pipet Use: Tubin Bot. Log Intvll.: 10,330 Ft. (M©} Insuection Tvue : Corrosive & Mechanical Damaae lnsnection ~ • COMMENTS ' This log fs tied info the Camco Nipple ~ 9,933' (Driller's depth). This log was run to assess the condition of the 4.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing interval logged is in good condition with respect to ' corrosive damage, EXCEPT a wa{i penetration of 47% recorded in pup joint 309.3 (~ 10,005'. The damage appears in the form of isolated pitting. No areas of significant cross-sectional metal loss or significant I.D. restrictions are recorded. 4.5" Tubing -MAXIMUM RECORDED WALL PENETRATIONS: isolated Pitting (47%) Jt 309.3 @ 10,005 Ft. (MD) No other areas of significant cxoss-sectional metal loss (> 10°k) are recorded. 4.5~ Tubing -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: ~ No areas of significant cross-sectional meta! loss (> 8%) are recorded. ' 4.5" Tubing -MAXIMUM RECORDED ID RESTRICTIONS: .. .. . No significant LD. restrictions are recorded. X01-~~-I ~cS6~/~l ~ Field Engineer: Wm. McCrossan Analyst: 8. Qf Witness: C. Kennedy PraActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 ~,~ Rhone: (281) or (888) 565-9085 Fax: 0811 565-1369 E-mail: PDS~umemorylog.com Pr udhoe Bay Field Office Phone: (907) 659-2307 Fax: (9071 659-2314 ~o~ Q ~ ZQ~~ :~faska Oil ~ C~as t,cr~s. t~mmissio~ ' A~chara~e c 1 ~-- W -` ell: Field: 11-10 ' Co spry; y~ Kuparuk oco~illips q-ask a, Inc. USA Tubing: 1 0 0 0 0 0 & Thread Damage profile--" (°~ wall) ~ Penetration body 0 ~~~~ metal loss body ~ 50 Penes`='~ ' loss 52 28 269 70 1 ,,, 1 01 ~~rrosion co~royon ~ir~ hole /Puss cO°o~n ible hole ' Number of 'oi 1 ~ 1 1 -~_ 0 0 PAS Report Overvi ew Body Region Anal S. Survey Date: Y ~S Tool Type; October 29, 2007 Tool Size: MFC 40 No. 040970 No, of Fin 2.75 Anal gers: 40 Nom.ID 8. I 3.958 ins Nom' Upset 4.5 ins UPper len. Lower Fn:__ CLM CI_M 2 CLM 3 CLM 4 CLM 5 B_.pom of Survey. 3 Analysis Overview pa$e 2 0 0 Damage Configuration ( body ) • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L$0 IBT Body Wall: 0.271 in Upset WaN: 0.271 in Nominal I.D.: 3.958 in Wel: 11-10 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: October 29, 2007 Joint No. Jt. Depth (Ft.) f'<~n. t ll7set (Ins.) Pen. Body (Ins.) Pc~n. % McU~I Loss °~o Min. LD. (Ins.) Comments Damage Profile (% wall) 0 50 100 1 7 O 0.01 ~ 1 3.89 1.1 39 ti 0.02 6 ' 3. 9 PUP 1.2 a 0.01 ~1 I 3.90 PU 1.3 58 a 0.01 ~ _ 3.91 PUP 6 u 01 1 I 3.9 3 96 t) 0.00 1 3.89 4 12 t) 0.01 4 ' 3 90 5 160 a 0.01 3 ' 3.90 6 192 U 0.01 4 I 3.88 7 22 t) 0.01 ' I 3.90 6 U 0.01 ~ I 3.90 2 [) 0.01 3 3.89 10 319 a 0.01 3 I 3.89 11 351 l~ 0. 1 ; 1 3.91 1 3 3 c) 0 01 4 s 3.90 13 415 t) .O1 ; i 3. 0 4 447 U 0.00 1 I .90 14.1 479 t) . 0 1 I 3.91 PUP 14. 484 U U t) .88 m Ni le 14.3 487 a 0.02 t~ _ 3.8 PUP 15 492 t 1 0.01 ,' _ 3.91 16 524 U .01 _ 3.91 17 55 l) 0.01 ~ ~' 3.91 18 587 0 0.01 l 3.90 19 61 l) 0 ti I .91 20 650 U 0.01 a 1 3.91 1 68 t) 0. 1 5 ~' 3. 22 714 c~ 0.01 2 3.91 3 7 u .01 ' 3.90 24 778 O 0.01 3 I 3.91 5 810 U 0.01 2 I 3.90 26 842 t) 0.01 4 1 3.90 27 874 t) 0.01 3 I 3.91 28 905 t) 0.01 3 1 3.91 9 937 t) 0.01 j _' 3.89 30 969 U 0.01 S _' 3.90 1 1001 l) 0.01 3 91 32 1033 t) 0.01 2 I 3.90 3 1064 O 0.0 1 I 3.90 34 1096 t) 0.01 ; I 3.91 35 11 8 U 0.01 4 1 3.90 36 1161 O 0.01 ~ 1 3.91 37 1192 U 0.00 1 I .91 38 1224 U 0.01 2 I 3.91 39 1256 t) 001 4 I .91 40 1287 U 0.01 5 1 3.90 41 1319 u 0 01 2 I 3.90 42 1351 (~ 0.01 4 _ 3.91 3 13 3 O .01 2 I 3.91 44 1415 t > 0.01 2 I 3.91 Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 IBT Wel: 1 J-10 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 29, 2007 Joint No. Jt. Depth (Ft.) Ne~n. Upset (Ins.) Pen. Body (Ins.) Nc~n. `%, Met;~l loss °%~> Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 45 1447 U 0.01 Z I 3.89 46 1478 t t 0. 1 3.9 47 1511 i t 0.01 <l i 3.91 48 1543 a 0.01 4 3.91 49 1575 c t 0.00 I 1 3.88 50 1604 t 1 D. 1 _' I 3.92 51 1635 a 0.01 ; I 3.90 52 1667 r t 0.00 1 1 3.88 53 1699 ~> 0.0 1 1 3.90 54 1731 l t 0.01 I 3.9 55 1763 t) 0.01 ' 1 3.91 56 1795 a 0.00 I .90 7 18 7 tt 0.01 ~ I 3.91 58 18 9 u 0. 1 s - 3.91 59 1891 U 0.01 4 1 .91 60 1923 c t 0.01 :.' I 3.91 61 195 U 0.0 } ~ 3.91 62 1987 r t 0. 1 ~' I 3.91 63 2019 t t 0.00 I 1 3.91 64 2051 r t 0.01 Z I 3.92 65 2083 (t 0.01 ~1 1 3.90 66 2114 U 0. 1 4 1 .89 t. D i 67 2147 t) 0.01 I 3.92 68 2178 U 0.00 1 1 3.91 69 2 1 1 I t 0. 1 4 .91 70 2242 (t 0.01 4 1 3.92 71 2274 I1 0. 1 2 I .91 72 2305 i t 0.01 -1 I 3.90 73 23 7 U 0.01 ~1 3 3.9 74 2369 0 0.01 ~ 1 3.93 75 2401 U 0.01 ~ I 3. 0 76 2433 tt 0.01 4 1 3.91 77 2465 U 0.01 4 1 3.91 78 2496 U 0.01 4 1 3.92 79 527 tl 0. 1 3.91 80 2560 a 0.01 -1 I 3.91 81 591 t t 0.01 i _ 3. 1 82 2623 U 0.01 4 I 3.90 83 2655 U 0.01 2 1 3.90 84 2687 t) 0.01 2 1 3.92 85 2718 U 0.00 1 I 3 92 86 2750 tt 0.00 1 2 3.91 I 7 2783 a 0.01 2 1 3.9 88 2814 U 0.01 2 1 3.89 89 2847 U 0.0 ; ? 3.92 90 2878 a 0.01 5 I 3.90 91 2910 l1 0.01 a 1 3.91 92 2941 U 0.00 1 I 3.92 93 2974 1t 0. 1 l 1 3.92 94 3005 r~ 0.01 3 1 3.92 __ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 IBT Wel: 1)-10 Body Wall: 0.271 in Field: Kuparuk Upset Wafl: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 29, 2007 Joint No. Jt. Depth (FtJ f'c~n. llpet ilns.) Pen. Body (Ins.) Nc~n. % ~1~~tal I~~,s ,, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 5 038 U 0.01 ~ I 3.92 30 U 0.01 4 3.92 97 3101 ll 0.01 3 I 3.91 98 313 t i 0.01 4 1 3.91 9 3165 l1 .02 7 3.92 100 3196 U 0.01 4 1 3.91 101 32 8 Q 0. 1 4 1 3.91 10 3260 l) 0.01 ~ 1 3.92 10 3291 U 0.01 ! I 3.91 104 33 3 U .O1 4 1 3.92 105 3355 a .03 1 U 8 .91 1 6 33 7 t) 0.01 4 1 90 107 3418 U 0.01 ~> 1 3.91 108 3450 It 0.01 3 1 3.92 109 481 t) 0.01 3.9 110 3514 U 0.00 1 :' .9 111 3545 U 0.01 ~l I 3. 11 3577 U 0.01 ~ 1 3.93 113 3609 0 .01 4 1 3.91 114 3640 l) 0.01 (~ 1 3.90 115 367 ct 0. 0 I 2 3.89 115.1 3704 (t 0.01 ~ 1 3.89 PUP 115. 3710 tl 0 O t) N A G M 1 ch 4:30 115.3 3718 U 0.01 5 1 3.92 PUP 37 U 1 ' 1 117 3756 ~) 0.01 Z 1 3.91 118 3787 U 0.01 a 1 3.93 119 3819 U 0.01 Z 1 3.93 1 0 3851 O 0. a 1 3. 3 121 3883 Ct 0.01 Z 1 3.92 122 3915 U 0.01 4 1 3.91 123 3947 U 0.01 ; 1 3.92 124 3979 U 0.01 4 1 3.92 125 4011 ~ 0.01 ' s 3.91 126 4043 t) 0.01 ; 1 .91 127 4074 11 0.01 Z 1 3.91 1 8 41 6 ~l 0.01 4 1 3. 2 129 4138 0 0.01 z 1 3.91 30 4170 U 0.01 4 1 9 131 4202 U 0.01 ~' 1 3.93 1 2 423 U 000 1 1 3.9 133 4266 0 0.01 4 1 3.92 134 4298 U 0.01 ? 1 3.91 135 4329 0 0.01 l 2 3.92 13 436 U 0.01 4 1 . 2 137 4393 tt 0.01 3 1 3.91 13 4425 ct 001 2 1 3.9 139 4457 i t 0.00 I I 3.90 40 4489 !' 0.01 ~ 3.92 141 4521 ~ ~~ 0.01 3.92 Penetration Body Metal Loss Body Page 3 i • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 I BT Wel: 1 J-10 Body Wall: 0.271 in Field: Kuparuk Upset WaN: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 29, 2007 Joint No. Jt. Depth (Ft.) I'r~n. Lllnc~i (In,.) Pen. Body (Ins.) Pc~n. %> ~tc~~il I~,t ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 142 4554 ~) 0.01 4 3.91 143 458 ~ ~ .00 1 I .9 144 4618 (~ 0.02 6 1 3.93 14 4649 ~ ~ 0. 1 ~ 1 3.94 146 4681 ~> 0.01 5 _' 3.91 147 4712 (~ 0.01 ~ I 3.92 148 4745 (I 0. 1 ; I 3.91 149 4777 U 0.01 4 _' 3.90 150 9 ~) 0. 2 1 3 91 151 4841 U 0.01 6 I 3.91 15 487 O 0.0 1 U I 3.9 1 3 4904 U 0 01 _' I 3.91 154 4935 U 0.01 I .92 155 4968 l~ 0.01 a 3.93 1 5000 (~ 0.01 4 1 3.9 157 5 32 c ~ 0.01 3 _> 3.93 58 5064 (~ 0. 1 4 4 3.91 159 5D96 U 1 4 I 3.93 160 126 O .01 4 1 3.91 161 5157 U 0.01 4 1 3 91 162 190 ~ ~ 0.01 5 ? 3.93 1 3 5221 a 0. 1 I 3.91 1 5 53 t~ 0.01 3 1 3.92 165 5283 ~ I 0.00 1 1 3.92 166 315 U 4 1 .91 167 5347 ll 0.01 2 1 3.92 168 5 79 U 0.0 6 1 3.92 169 5411 ~ ~ 0.00 1 I 3.92 170 5443 t 1 0.01 -1 I 3.91 171 5475 ~ ~ 0.02 (~ 1 3.90 172 5504 (~ 0.01 Z 1 3.91 173 5536 ~ ~ 0.01 4 I 3.93 174 5568 U 0.01 4 1 3.93 175 5601 ~ ~ 0.02 (~ I 3.89 176 5632 ~ ~ .01 4 I .92 177 5664 t~ 0.01 ~' I 3.93 17 6 ~ 1 0. 1 ~1 I .91 179 5728 t~ 0.01 -3 I 3.92 180 5760 U 0.01 4 I 3.91 181 5791 l~ 0.01 S 1 3.91 182 8 3 a 0.01 4 1 .90 183 5855 tl 0.01 4 1 3.91 1 5 6 U .01 ~ 1 3.92 185 5918 O 0.00 1 _' 3.92 186 5950 U .01 4 3.91 187 5982 U 0.02 (~ ,' 3.92 188 6014 ~ ~ 0.01 3 I 3.91 189 6046 U 0.01 4 1 3.93 6076 ~! 0.01 2 I 3.93 191 6108 (~ 0.02 6 I 3.92 Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBT Wel: 1J-10 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConoooPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 29, 2007 Joint No. Jt. Depth (Ft.) I'en. Uptic°t (Iii,.) Pen. Body (Ins.) Nen. %> ~1c~tal I Usti ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 19 6140 a .01 Z I 3. 2 193 6172 t ~ .00 1 I 3.92 19 6 02 l~ 0.01 2 I 3.91 195 62 tl .01 ~I '~ 3.9 196 626 U 0.01 ~1 I 3.9 196.1 6299 t1 0.01 ~ 1 3. 1 PUP 96. 6305 t t 0 U u N A GL 2 Latch ~ 7:3 196.3 6313 U 0.02 7 I 3.92 P P 197 63 9 U 0.01 5 I .9 198 6 5 t l 0.01 -1 I 3.9 1 9 638 t l 0.01 3 ' 92 00 6414 U 0.01 ' I 92 1 6446 II 0.01 I 3.92 2 2 6476 U 0.01 -1 3.91 0 509 U 0.01 t I .92 04 6541 U .01 4 I 93 5 574 t l 0. 1 ~ I .93 604 U 0. 1 4 1 .9 07 66 7 (~ 0.01 4 1 3.90 208 6667 U 0.01 t I .90 209 6697 t l 0.01 I 3.91 210 6730 a 0.01 ~ I 3.92 11 6761 U 0 01 ~' I 3 92 212 6794 U 0.01 4 1 3.90 1 6 U 0.0 2 1 3.9 214 6856 ~) 0.01 4 I 3.92 215 6889 C) 0. 1 ~ 3.90 216 6919 t1 0.02 t3 I 3.91 17 69 0 U 0.01 4 I 3. 218 6981 U 0.00 1 I 3.92 219 7013 t 1 0.01 4 I 3.9 220 7043 a 0.02 b I 3.91 221 7075 t) 0.01 i I 3.92 222 7106 U 0.01 4 ~ 3.92 23 7138 t? 0. 1 4 I 3.92 224 7169 t t 0.01 -1 I 3.92 20 U .01 ' 1 226 7233 t1 0.01 Z 1 3.93 27 7264 t? 0.00 1 1 3.92 228 7297 tt 0.00 I 1 3.92 29 7 28 tt 0 1 4 I 3. 2 230 7359 U 0.00 1 I 3.91 2 1 739 a .01 4 I 3.92 232 7423 tt 0.01 -1 3.91 33 7455 t t 0. 1 ~ I 3.92 234 7486 tl 0.01 3 I 3.92 235 7517 t I 0.01 -1 ~ 3 92 36 7548 tl 0.00 1 I 3.92 2 7 75 1 U 0.01 -1 I 3.89 238 7613 a 0.01 S ~ 3.91 Penetration Body Metal Loss Body Page 5 • • PDS REPORT )DINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBT Body Wall: 0.271 in Upset Wall: 0.271 in Nominal I.D.: 3.958 in Wel: 1J-10 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: October 29, 2007 Joint No. Jt. Depth (Ft.) I'~•n. l 11 nc t (Inc.) Pen. Body (Ins.) Pen. °/, ~tctf~l loss °i~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 239 7645 ~) 0.01 1 t 3.92 240 676 (I 0 t) 1 3.90 2 1 7707 (1 00 1 ~' 3.91 242 773 a 0.01 4 1 3.9 243 7772 ~ ~ 0.0 -1 I 3.91 244 7804 ll 0.01 ~ I 3.9 45 7832 U 0.01 2 I 3.92 246 7865 a 0.01 3 1 3.92 47 7896 U 0.0 ? I 3.92 248 79 0 u 0.01 Z I 3.92 249 7962 tt 0. 1 3 I 3.92 250 7993 11 .01 3 I 3.91 51 8025 t~ 0.02 6 ~' 3.90 1 1 8 57 (~ 0. 1 ~ I 3.91 UP 251.2 806 (~ 0 l) U N A GLM 3 Lat h ~ 5:00 2 1.3 8071 ~ ~ 0.02 I 3.89 P P 252 807 U 0.01 ~~ 1 3.91 253 8107 U 0.00 1 1 3.91 54 8141 ~~ 0.01 5 1 3. 1 255 817 i! 0.01 5 1 3.92 2 8204 ~ I 0.01 4 1 .9 257 8 37 U 0.01 3 2 3.90 2 8 8269 ~) 0.01 ; (1 3.92 259 8299 t~ 0.01 z 1 3.91 331 U .01 4 1 3.91 261 8360 ll 0.01 Z 1 3.89 2 8393 U 0. 1 4 7 3.91 263 8425 O 0.01 4 1 3.92 264 84 6 U 0.01 2 1 3.9 265 8488 11 0.01 Z 1 3.89 266 8520 11 0.01 3 1 3.91 267 8553 i t 0.01 ~' 1 3.91 268 884 (~ 0.00 1 I 3.93 269 8616 U 0.01 4 1 3.91 2 0 8647 a .00 1 1 3.92 271 8679 ~) 0.01 4 t 3.92 72 8711 (~ 0.0 2 .91 273 8744 ~ ~ 0.01 j 1 3.91 274 8775 i ~ 0,01 2 I 3.91 275 8807 ~ I 0.00 1 ~ 3.90 7 883 7 O 0.00 1 ! 3. 1 277 8870 ~I 0.01 4 1 3.92 2 78 8903 U 0.01 4 1 3. 3 279 8935 t~ 0.01 2 1 3.92 280 8966 (1 0.01 4 I .93 281 8997 (> 0.00 1 1 3.92 282 9030 (~ 0.00 1 Z 3.90 283 9060 ~? 0.01 ? I 3.91 284 9092 0.01 1 I .9 284.1 9124 0.01 ~ 3.91 PUP _ Penetration Body Metal Loss Body Page 6 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 IBT Wel: 1 J-10 Body Wall: 0.271 in Feld: Kuparuk Upset WaM: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 29, 2007 Joint No. Jt. Depth (Ft.) I'rvi. 1 ll~,et (In..) Pen. Body (Ins.) Pen. °/, McGrl I oss `~'~ Min. LD• (Ins.) Comments Damage Profile (% ~'~l) 0 50 100 84. 91 0 ~) 0 O N A M 4 Latc ®4:15 84.3 91 8 U 0.0 7 I .90 P P 285 143 a 0.01 ~ 1 3.91 286 9176 (~ 0.01 -1 1 3.92 287 9 06 a 0.01 > 1 3.90 288 9 39 U 0.01 ~ 1 3.9 9 9272 ~~ 0.01 3 1 .93 290 9302 ~~ 0.01 2 1 3.92 91 9335 l) 0.01 2 1 3.91 2 2 936 l1 .0 ~ 1 3.91 93 9398 U 0.01 4 1 3. 0 294 9429 U 0.01 ~' I .93 295 9462 ~ ~ .02 ~ 3.90 6 9493 ~ ~ 0.01 3 1 3.90 2 7 526 (~ 0.01 4 U 3.92 298 95 7 ~~ 0.01 2 I 3. 4 99 588 U 0.01 2 I 9 300 96 2 ~~ 0. 1 2 1 3.9 301 9653 ~ ~ 0. 1 4 1 3.92 302 9684 i 1 0.01 2 1 3.93 303 718 i~ 1 3 1 3. 2 4 9749 ~~ 0. 1 4 I 3. 2 30 9780 t ~ 0.01 4 1 .91 3 9812 (~ 0.01 Z 1 3.92 307 844 (~ 0 00 I 1 3. 1 307.1 9876 t~ 0.00 I 1 3.93 PUP 307.2 9882 ~~ O 0 N A LM 5 at h@ 7fl0 307.3 9891 a 0.00 1 1 3.91 PUP 308 9896 ~) .01 2 1 3. 1 308.1 9927 (~ 0.01 a I 3.90 PU 08. 9934 ~~ 0 U ~! 3.81 Camco Ni le 308.3 9936 (~ 0.01 2 I 3.88 PUP 09 940 (1 0.00 1 1 3.89 309.1 9972 U 0.00 1 :.' 3.87 PUP 3 9.2 9979 O 0 (1 0 .96 B ker Se I A 309.3 10001 U 0.13 -17 3 3.90 PUP Isolated "di 310 100 7 (~ I ~' 3.86 Lt. e i . 311 10039 t~ 0.00 I t 3.89 312 10068 n 0.00 1 I 3.88 313 10101 t ~ 0.00 1 s 3.88 314 10131 ~) .0 1 1 3.89 315 10161 ci 0.00 1 I 3.90 316 0189 ~~ 0. 1 ~ 1 .89 317 10219 ~ ~ 0.00 1 1 3.90 31 10 5 U 0. 0 1 I 3 9 319 10280 U 0.00 1 1 3.91 320 1 3 0 (1 0.01 2 l 3.90 Penetration Body Metal Loss Body Page 7 ~~ PDS Report Cross Sections ,u Well: 1)-10 Survey Date: October 29, 2007 Field: Kuparuk Tool Type: MFC 40 No. 040970 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country; USA No. of Fingers: 4U Tubin 4.5 ins 12.6 f _L-80 IBT Analyst: B. Qi Cross Section for Joint 309.3 at depth 10005.36 ft Tool speed = 67 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 97 Tool deviation = 65 ° Finger 19 Penetration = 0.128 ins Isolated Pitting .13 ins = 47% Wall Penetration HIGH SIDE = UP •i • Cross Sections page 1 { GonocoPhillips Alaska, Inc. TU 00:4 ID:3. SURI (oa OD:9 Wt;4 ~RODUC (o-1i ooa wt2 c,~ MarMreU (sosa~l Ga MandreVS (966z 5 (99335 OD:5 SLEEVi (9967_c OD:S PROD LI (9967-1C OD:4. Wt1: 9 (9992-9 OD:S. PERF 10312-10 OD:3. 1032810 OD:4. 1oa4s-1o 10521-10 OD:4.. 1065810 Fl 1085810 • KRU 1J-10 __ _-- ~ -~ API : 500292301000 Weil T : PROD A le TS: 53 d 10394 BiNG 33SV T NI le Ori Com lotion: 5x24/2001 An a TD: 49 10845 79. Annular Fluid : Lest W/O: Rev Ranson: P II Choke ~~ rents Ref D te: st U ate: 9/23/2006 ~) Last Ta :10339 FI H TD: 1 ftK8 last Te Dote : 8/2005 Max Hole An le: 68 3102 Ca ' 3 ' - ALL STRING S Desc ' lion Size To Bottom ND Wt Grade Thread CONDUCTOR 20.000 0 120 120 91.50 H~0 WE SURFACE 9.625 0 8945 3995 40.00 L-80 BTC ACE 945 PRODUCTION PROD LINER 7.000 4.500 0 9987 10231 10843 5944 8325 26.00 12.60 L-80 L-80 BTC-mod NSCT S.ooj © Tubin Strin -TUBING S' To Bottom TVD Wt de Thread 4.500 0 9979 1 6o IBT Perforetiona 3umme - Interval ND Zone S tus Ft SPF Dete T Comment ooo, Loo) © - _ - 10448 - 10466 8073 -6085 C3 20 6 7/19/2001 APERF 33/8' PSD PJ chps, ~ dap 10658 - 106 6205 -6218 A-5 20 6 6/1 1 IP RF 2.5• HSD BH 8 DP I ~` Stimulations 8 Treatments s Lm ~ Interval Date T Comment 'ahe -- 10658 - 10678 6/16/2001 FRAC P F 3 ©~ Gas M end elves °~~ ~ St MD ND Man Mir Men Type V Mfi V Type V OD Latch Port TRO Dete Run Vh Cmnt 1 2 3 4 3724 6312 8068 9133 2558 3723 4627 5283 CAMCO CAMCO CAMCO CAMCO KBG-2 KBG-2 KBG-2 KBG-2 CAMCO CAMCO CAMCO CAMCO GLV GLV GLV DMY 1.0 1.0 1.0 1.0 BK BK K BK 0.156 0.188 0.188 0.000 1233 1282 1253 0 10/29/2001 6/28/2001 10/282001 523/2001 5 9882 5737 CAMCO K8G-2 CAMCO OV 1.0 K 0.188 0 10/302001 O er lu s i .etc. - E I` De TVD T escri lion ID ~ LAt 508 NIP CAMC -6' nl w/3. 75' to NO O rofil 875 ahe -- 3 787 NIP CA CO 'DB' i le w/3. 12 le 3. 12 5 © ~ 9992 SEAL BAKER SEAL ASSEMBLY W/MULESHO 3.958 ~' ~ Other ui .etc. -LINER JEWELRY D th TVD T D 'lion ID 9967 5787 SLEEVE-TB BAKER TIE-BACK 8LEEVE 4.438 NIP 9885 5798 PKR BAKER ZXP PACKER 4.375 934, 10328 NI CAMCO'D' NIPPLE 3.813 X30) 10521 6 119 NIP OTIS 'XN' NIPPLE w/No Go 3.812' PKG BORE 3.725' rofile 3.7 10841 6 323 8HOE 3.858 Fish -F ISH De th D Com nt ;_7g 968, 1~) 10312 PERF GUN PERF GUN DROPPED 724/01, TOP 10,532', LENGTH 34.4', MAX OD 3.83"; WORKED TO RETRIEVE THRU 8/29101. WELL 8HUT IN 8 FREEZE PROTECTED. 10252004: Fish Pulled up to10,312' CTMD 6/7 T Fi 1 KB Gerterel Notes JER Da te Note 543, 7232 001 Left 38' bet sub on to of E-Fns cool i00, 60) J1L 593, ),30) SUN 546, .30) NIP 529, i00) 'art ~) NIP i22, 00) 'ert > 78) AC 78) ~ - 0- e e ~~, \.¡" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs _Inserts\Microfihn _ Marker. doc 1.-C. L1VVU. 1"-UYQ1Ul\. 1J YYCU lC::>Llllt:;J ) ) Subject: Re: [Fwd: Kuparuk IJ Well Testing] From: John Hartz <jack_hartz@admin.state.ak.us> Date: Wed, 10 Aug 2005 13:10:58 -0800 To: Brian Seitz <Brian.Seitz@conocophillips.com> CC: Thomas E Maunder <tom_maunder@admin.state.ak.us> -- d-O \ -0 ~~ dO ( - 0 L{ ~ ,.JO \ - o'\. \ Brian, Your request appears to be an operational necessity for a short period until the 1J Pad facility is commissioned. Your proposal to test 1J-03 and test 1J-09 & 1J-10 if monitoring data indicate performance changes is acceptable. Notify me if th~ schedule is significantly delayed beyond November 1. Thank you for the notification. Jack Hartz, P.E. Sr. Reservoir Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave. Suite 100 Anchorage AK 99501 907-793-1232 Fax: 907-276-7542 SCJ\NNED ¡ð¡UG 11 2005 Thomas Maunder wrote: Jack, For your reply. Tom -------- Original Message -------- Subject: Kuparuk 1J Well Testing Date: Wed, 10 Aug 2005 09:02:50 -0800 From: Seitz, Brian <Brian.Seitz@conocophillips.com> To: tom maunder@admin.state.ak.us CC: ë·p·Fl..·....p·r·õ·d···..·Eiig·r·......-;¿·ri:i..2..6..9·~~·ë·õ·rlõ'ë'ophill ips. com>, "Spenceley, Neil" .::::.~.~..~...~....:.._~..~...?p.~.~.9..~..~.~.y..~.s.:.?..P.:g.qg.p..þ..~..~...~...~.P!?....~...~..?.~.?.:., II John stone, S am 'I <Sam.Jotmstone@conocophillips.com> Tom- The three existing Kuparuk producing wells on 1J pad are currently tested monthly as twinned well tests using the test facility on 1D pad. In addition, we obtain single well tests every 6 months with a portable test separator to verify individual well production. In mid-September, these wells will be tied into the new 24" production line recently installed from 1J pad to CPF-1 and we will lose our ability to test the wells through the 1D pad facility. The new 1J pad separator is scheduled to be placed in service on November 1, 2005. CPAI requests a waiver from the monthly well testing requirement for wells 1J-03, 1J-09, and 1J-10 until the new 1J test facility is in service. We will be testing 1J-03 with a portable test separator following a coiled tubing sidetrack scheduled for August, and will retain the option of testing 1J-09 and 1J-10 should pressure and temperature trends indicate significant changes in well performance. Please let me know if this plan is acceptable, or give me a call if you wish to discuss it in further detail. Regards, Brian Seitz CPF-1 Lead Drillsite Petroleum Engineer 265-6961 8/1 0/2005 1: 17 PM Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2926 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 07/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 1B-10 i ~)- I ~c~.~'~ SBHP 07/21/03 1C-27 ~ ~'-~,,,_~/_~'~) TEMPIPRESS SURVEY 07/22/03 1 1D-140 ~)~ ~ ~'% L~:~ SBHP 07/22/03 1 1J-10 ~'~,~,'~",~'--~ (SBHP 07121/03 1 2B-01 ,~<~ ~1"~'\,,~ PRODUCTION PROFILE .07/19/03 1 2B-02 I~[- I,~, ~-~. PRODUCTION PROFILE 07/20/03 1 2B-14 1~' ~ t \ PRODUCTION PROFILE 07/23/03 1 2E-11 ~ ~,t.j..~.~.~ PRODUCTION PROFILE 07/18/03 1 3K-08 \ ~~ '~--~'1~ LDL 07/25/03 1 3M-03IOi~~ I~-~ LDL 07/24/03 1 3S-19 ~'~_'~-('~,,~ PERFIJEWELRY/& INITIAL SBHPS 07/11/03 · DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Permitto Drill 2010710 MD 10845 ×,~ TVD DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. KUPARUK RIV UNIT tj-10 Operator CONOCOPHILLIPS ALASKA INC 6326. ~'~ Completion Dat 6/12/2001 ~' Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-23010-00-00 UlC N REQUIRED INFORMATION Mud Log No Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~edia Fmt Name Log Log Run Scale Media No ~ C Pdf I L~B~- C Pdf ~ C Pdf ~3'"- C Pdf R Ver LIS Verification Ind Induction/Resistivity Por Porosity Por Porosity Ind Induction/Resistivity D R ~Survey Directional Survey Interval Start Stop R R Directional Survey }~"~'~u rvey SBHP/PSP Cement Bond Log/ PSP/SCMT 1 175 10796 final 175 10845 final 175 10845 final 175 10845 final 175 10845 FINAL FINAL FINAL FINAL FINAL 10502 10694 FINAL 9965 10732 (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Nurpber Open 11/7/2001 C.~t~458 Open 11/13/2001 ~-.A'O465 Open 11/13/2001 ~3'~65 Open 11/13/2001 ~65 Open 11/13/2001 ~ CH 6/11/2001 OH 6/11/2001 OH OH CH CH 6/11/2001 6/11/2001 6/22/2001 7/13/2001 Comments MWD Survey, Digital Data Directional Survey, Paper Copy Directional Survey, Paper Copy IIFR Survey, Digital Data 10502-10~ 9965-1073~ Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received?~ Analysis R ~.c~.iv~.d ? Daily History Received? Formation Tops Permitto Drill 20107t0 MD 10845 Comments: TVD DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. KUPARUK RIV UNIT 1J-10 Operator CONOCOPHILLIPS ALASKA INC 6326 Completion Dat 6/12/2001 Completion Statu I-OIL Current Status 1-OIL APl No. 50-029-23010-00-00 UIC N Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To; State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 02, 2001 RE: MWD Formation Evaluation Logs 1J-10, AK-MM-10136 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, 6900 Arctic Blvd., Anchorage, AK 99518 1J-10: Digital Log Images 1 CD Rom RECEIVED h OV 1 5 2001 Alaska Oi~ & Gas Cons. Commis,~io~ .g~cb~rage WELL LOG TRANSMITTAL To-' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska October 31,2001 MWD Formation Evaluation Logs 1J-10, AK-MM-10136 1 LDWG formatted Disc with verification listing. API#: 50-029-23010-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED NOV 0 7 2001 ~ Oil & Gas Cons. Commis~on Anchorage STATE OF ALASKA i~''r ALA KA OIL AND GAS CONSERVATION COM ~,,.,81ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~] Gas D Suspended 0 Abandoned D service D 2. Name of Operator ~ _ _ ,. 7. Permit Number Phillips Alaska, Inc. ' ¥1~['11~ 201-071 3. Address_ ~.,, . 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~ 50-029-23010-00 4. Location of well at surface __~~ I 9. Unit or Lease Name '~ ' "~'~' '~ Kuparuk River Unit 1996' FSL, 2536' FEL, Sec. 35, T11N, R10E, UM (ASP: 558673, 5945808) At Top Producing Interval '" _L~__/' 376' FSL, 1155' FWL, Sec. 27, T11N, R10E, UM (ASP: 551772, 599417) _ ~= ,"'~~ lO. WelllJ_10Number At Total Depth ~_..'",. ~,~,.;¢''~,~' ~. 11. Field and Pool 541' FSL, 847' FWL, Sec. 27, T11N, R10E, UM (ASP: 551462, 5949580) Kuparuk River Field ~' 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 29.6' feetI ADL25660 ALK 470 12. Date Spudded 13. Date T.D. Reached 14..Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 29, 2001 May 20, 2001 -J~001,,~~ ~1 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10845' MD/6326' TVD 10749' MD/6262' TVD YES ~] No D'1 Nipple @ 508' feetMD 1586' (approx) 22. Type Electric or Other Logs Run GR/Res/Neu Dens, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 120' 24" 460 sx AS I 9.625" 40# L-80 Surface 6945' 12.25" 741 sx AS Lite & 488 sx LiteCRETE 7" 26# L-80 Surface 10231' 8.5" 178 sx Class G 4.5" 12.6# L-80 9967' 10843' 6.125" 127 sx Class G 4.5" tie-back 9967' 10843' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 9979' 9985' 10658'-10678' MD 6205'-6223' TVD 6 spf 10446'-10466' MD 6073'-6085' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10658'-10678' 64M$ behind pipe, 6.2 ppg on perfs, left 39M# . in wellbore 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 14, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 7/14/2001 6 hrs Test Period > 91 580 0 176I 5312 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 230 psi 510 24-Hour Rate > 342 2348 7 25 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A JUL 2 3 Z001 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE /D Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all lluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 10394' 6041' Base Kuparuk C 10472' 6089' Top Kuparuk A 10629' 6187' Base Kuparuk A 10746' 6262' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Dire?ti0nal Survey 32. I hereby ce?~ that the?ollowing~/tm~ and correct to the best of my knowledge. Questions? Todd aushovlc 265-6974 Signed Title Interim Drillin,q En,qineerin,q Supervisor Date Tom Brockway INSTRUCTIONS Prepared by Sharon AIIsup-Drake 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 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". RE C E ~VE D Form 10-407 JUL Alaska Oil & Gas Cons. Commission Anchorage ~" OPERATIONS SUMMARY 'i' 1J-10 Rpt Date 04/27/01 12:00 AM 04/28/01 12:00 AM 04/29/01 12:00 AM 04/30/01 12:00 AM 05/01/01 12:00 AM 05/02/01 12:00 AM Comments Jackup rig and and remove mats, Move rig over 1J-10. Set rig down on mats. Close up cellar Start nipple up of diverter. Take on water in pits Finished N/U diverter system. Insatlled mousehole, put strip-o-matic over hole, changed air slips + iron roughneck + mud bucket over to 5" DP. P/U 5" DP & function test annular preventer & knife valve, OK. Mixed mud. Bring elevators, subs & crossovers to rig floor. Finished mixing spud mud. Built berms, pre-spud walk around, & check list. Spot ball mill & rockover tank. Worked on drawworks. PJSM & worked on washing wind walls. Changed washpipe & packing, general rig maintenance, changed oil in rotary table, checked all auger flights + bearings, replaced bearing & connecting shaft on main auger. Serviced ball mill & pre Mixed additional mud volume while waiting on parts to repair drawworks. Work on drawworks & repaired @ 11:00 hrs. Picked up BHA & function test diverter system & accumulator, OK. PJSM, P/U BHA, changed stab blade & make up 8" motor w/1.5 setting. Program MWD, P/U rest of BHA. Tagged bttm @ 98', hard digging @ 120', drld f/120 - 183'. AST0 ART 1-1/4 hrs. Saver sub backed out, retorqued same. Drld f/183 - 274'. AST0 ART 1-1/4 hrs. Worked hole to make connection, gravel sloughing in. Drld f/274 - 365'. AST0 ART 1-1/4 hrs. Circulate hole clean. Pumped out 3 stds of HWDP in order to run NMDC's. RIH w/8" DC's. Drld f/365 - 457'. AST0 ART 1 hr. Drilled 12-1/4" hole f/457 - 2515',/AST=I 1.25 & ART=6.5 hrs. At report time circulating Hi Density sweep around, sweep= 11.6 ppg. Finished circ'g hole clean. Flow checked well, OK. Pumped 11.6 ppg slug. Pulled 3 stds on trip tank and had tight spot @ +/- 2315'. Attempted to work thru with up to 40,000 lbs overpull 3 times, no luck. Tried to slowly rotate w/slow pumps, hole trying to pack off. Raised flowrate on up to drlg rate & pumped/rotated out to DC's. No problems. TIH & had tight hole @ 780' & 850'. Had to work the spots with slow gpm & slow rotation. Finished TIH. Washed/reamed last std to bttm. Drld 12-1/4" hole f/2515- 4100'. Circ bottoms up & pumped hi-density sweep. Sweep does not load the scalpers any, but it does increase the fine solids on the main shakers. Flow checked well, OK. Pumped 11.6 ppg slug & POOH. POOH f/4100 - 1817'. Last couple of stands in hi dogleg area & req'd quite a bit of working to clean up. Started to try & swab so decided to pump/rotate out. Pumped/reamed out f/1817' - 276'. Flow chk'd well at DC's, OK. Handled BHA. L/D 3 steel DC's. P/U LWD tools & changed out bits. PJSM and Sperry loaded nuclear sources into LWD collars. PJSM, P/U flex DC and RIH. Tight spot @ 1978 - 2164' & others between 2600 - 3900'. Worked thru all without pump (pushing ball of cuttings in front of bit?). Washed & reamed last std to bttm, had 30' of soft fill. Drld 12-1/4" hole f/4100 - 4138'. AST=0 & ART= 0.25 hrs. i OPERATIONS SUMMARY 1J-10 05/03/01 12:00 AM 05/04/01 12:00 AM 05/05/01 12:00 AM 05/06/01 12:00 AM 05/07/01 12:00 AM 05/08/01 12:00 AM Rotate/circulate & reposition drillstring in order to get Casandra QC surveys. Drld 12-1/4" hole f/4138 - 4774' (3037' TVD). AST=2.25 & ART=3.5 hrs. Drld 12-1/4" hole f/4774 - 5925'. AST=4 & ART=12 hrs. Circ'd & pumped hi-density sweep. Cim'd until hole clean. Flow chkd well, OK. Pumped slug. POOH for wiper trip. Final Injection report for 1J-03 = 31932 BBL POOH to 2309' - Wipe thru tight spots f/2309' to 1939' 30-50K drag, Back ream f/1939' to 1570', Pull to 276' Monitor well, Service rig RIH to btm.- No tight spots Circ. btm's up Drill f/5925' to 6740' ART=8.25 hrs AST=2.0 hrs Drill f/6740' to 6960' ART=2 hrs AST= 0 Pump sweep, Circ. hole clean, Monitor well POOH (SLM-no correction), Pumped out thru 6-7 degree doglegs f/2074' to 1793' due to over pulls & swabbing Remove Sperry-Sun RA Sourses, Down load & Lay down LWD's, MWD & Motor Pick up Holeopener & BHA Service top drive RIH to 6960'- No problems Pump sweep, Circ. & cond. mud f/csg., Monitor well Dry pipe POOH - pulled good Stand back BHA, Lay down 8" flex DC's, Stab, Bit sub, Holeopener, Clear rig floor. PJSM, Rig up to run 9-5/8" csg. PJSM, Run 9-5/8" csg., Circ. ann. vol. @ 2400', Run 9-5/8" csg., took wt. @ 3650'- work thru OK, Run to 4106'- pipe stopped Attempt to work pipe past 4106'- no good, Circ. & balance mud f/dry job, Rig to lay down csg., Pump dry job. PJSM, Lay down 3 jts csg., Change elevators and bails, Lay down fill up tool Lay down 9-5/8" csg.(Left 1 centralizer blade and 2 stop collars in hole) Heat & Lay down float collar joints, Rig down csg. equip., Clean rig floor. Cut drlg. line 94', Service rig Pick up holeopener BHA RIH to 4356' (Took wt. @ 2116' & 2200'- Rock table & fell thru, No indication of obstruction @ 4106' where csg. stopped) Precautionary back ream f/4356' to 3400' & ream back down to 4356'-( No indication of obstruction at any time) RIH to 6960'- No tight spots- hole in good shape Pump sweep, Circ. & cond. mud Monitor well, Wipe hole to 3400' - had 50K pulls @ 6750' & 5873' - 30K pull @ 5054'. IH- Wash & ream 4909'-5193' 5755'-6035', 6693'-6960' (Hole very free while reaming) Pump sweep Circ. & cond. mud f/csg. Monitor well, Pump dry job, Blow down top drive, POOH- Pulled 50K over f/6693' to 6600'- No other pulls Stand back BHA, Lay down holeopener & 8" DC's Clean & clear rig floor, PJSM, Rig to run 9-5/8" csg. Run 9-5/8" csg. to 2400' Circ. btm's up Run 9-5/8" csg to 4884' (No problems going past 4106', where csg. stopped on first attempt) Circ. btm's up OPERATIONS SUMMARY l' 1J-10 05/09/01 12:00 AM 05/10/01 12:00 AM 05/11/01 12:00 AM 05/12/01 12:00 AM Run 9-5/8" csg. to 6909' Make up hanger & landing jr. Work csg. loose & work to btm.- unable to work csg. after landing hanger Circ. & cond. mud f/cmt job PJSM f/cmt, job Pump 20 bbls fresh water- 10 bblsCWl00-Test lines to 3500 PSI- 10 bbls CWl00- Drop btm plug- 50 bbls MudPUSH @ 10.5 ppg- Mix & pump lead cmt. Mix & pump total of 741 sxs ASLite lead cmt. @ 10.7 ppg, Followed by 488 sxs LiteCRETE tail cmt. @ 12.0 ppg, Drop top plug, Displace cmt. w/10 bbls wash water + 507.7 bbls mud, Bump plug, Floats held OK, Had good circ thru out job & 118.8 bbls cmt returns Lay down cmt. head, Landing jr., Change elevators & bales, Rig & wash out diverter stack Nipple down diverter stack Install & Make up well head- Test to 1000 PSI f/10 min. Install & nipple up BOP & related equip. Rig & test BOP 250 PSI Iow & 5000 PSI high- waived by AOGCC Chuck Scheve, Install wear bushing, Clear floor Pick up 8-1/2" BHA Pick up 39 jts. 5" G DP Finish picking up 5" DP RIH tag float collar @ 6861' Circ. btm's up Rig & Test 9-5/8" csg. to 3000 PSI- no good- Press. bled t/1750 PSI in 10 min., Check f/surface leaks & equip., Retest csg.- still no good Monitor well, Dry pipe, POOH to BHA Stand back BHA, Down load LWD & stand back same Make up Baker packer, Pick up BHA, RIH & set @ 1014', Test down DP to 3000 PSI - no good - bled to 1900 PSI in 5 min., Test down ann. to 3000 PSI - held OK. RIH- packer stopped @ 2347', Attempt to set packer above 2347'- no good, Circ btm's up to balance mud Dry pipe POOH- left packer in hole ( unscewed f/3-1/2"1F XO sub) Service rig Wait on fishing tools Make up fishing tools RIH to 2347' Latch onto fish Dry pipe POOH- recovered fish Lay down fish & fishing tools Make up Baker packer & RIH & set @ 3500', Test down DP to 3000 PSI- no good, Test csg. to 3000 PSI- OK Blow down lines, RIH & set packer @ 6856' Rig & test 5" X 9-5/8" ann. to 3000 PSI f/30 min.- OK Dry pipe, POOH & lay down Baker packer Make up bit, Load LWD, RIH t/float collar @ 6864' Drill out float collar, Cmt., Shoe, 15' cmt., 35' new hole t/6995' Change over to new 8.4 ppg mud Rig & perform LOT- EMW- 12.7 ppg Perform PWD base line Drill f/6995' to 7142' ART= I hr AST= .5 hr Drill f/7142' to 7291' ART= .5hrs AST= .5hrs Take Casandra survey check shots Drill f/7291' to 8674' ART= 8hrs AST= 2.25hrs Pull 2 stands, Circ & work pipe while change out swivel packing, RIH 2 stands Drill f/8674' to 9170' ART= 4hrs. AST= 0 OPERATIONS SUMMARY 1J-10 05/13/01 12:00 AM 05/14/01 12:00 AM 05/15/01 12:00 AM 05/16/01 12:00 AM Pump sweep, Circ. hole clean for short trip Monitor well, Dry pipe, Wipe hole to shoe @ 6945'- 35K drag f/7570' to 7500' Slip & cut drilling ling 85', Service rig RIH to 9170'- No problems Pump sweep, Circ. btm's up - trip gas 2350 units Drill f/9170' to 9265' ART=I.5 hrs AST= 0 Cycle pumps to change log modes on Sperry-sun LWD Drill f/9265' to 9532' ART= 1.5 hrs AST= 1 hr. (Start scheduled mud wt. increase t/9.8 ppg @ 9425' Finish weighting up mud pits t/9.8 ppg Drill f/9532' to 10247' (7" TD) ART= 5.5 hrs AST= .75 hrs ( Connection gases 400- 800 units, Begin mud wt increase to 10.1 ppg @ 10200') Circ. & increase mud wt. 10.1 ppg (Had 4700 units gas on last connection while drilling- mud wt. cut f/9.9 to 9.4 ppg) Raise mud weight to 10.1 ppg Monitor well, Wipe hole f/10247' to 9014'- Good fill up, Drag 10- 30K Circ. btm's up (trip gas 4900 units), Pump sweep, Raise mud weight to 10.8 ppg in 2 stages ( back ground gas 10- 50 units) Monitor well, Wipe hole f/10247' to 8954'- Good fill up, Max drag 20K Circ. btm's (trip gas 180 units), Pump sweep & circ hole clean Monitor well, Wipe hole f/10247' to shoe @ 6945'- hole in good shape, no fill Circ. btm's up (trip gas 200 units), Pump sweep, Circ. hole clean & cond. f/7" csg. Monitor well, POOH POOH from shoe, hole fill good, SLM. PJSM, lay down 3 flex collars + drain motor + break off bit. Down load MWD tool, pull tool out of hang off sub. Lay down stab + motor + MWD's + pony collar & clear/clean floor. PJSM, pull wear bushing & rig up to run 7" casing. Picked up float eqpt + centralizers & check floats, OK. Continued running casing. Broke circulation & circulated @ 3236'. Ran 7" csg to 5280', broke circulation & ran 7" csg to 6906'. Circulated at 9-5/8" shoe & conditioned mud. Continued running 7" csg. Broke circ @ 8530'. Made up 7" csg hgr + landing joint. Land 7" casing no fill. Broke circulation slowly eased pumps up to 7 bpm & reciprocated casing. Circulated 1-1/2 bottoms up & laid down fill up tool. Rigged up cementing head. Continued circulating with rig pump & reciprocating casing. Still working on mud rheology for cemen Circulated, shakers clean & conditioned mud such that PV=19 & YP=15 & MW=10.9 Tested cmt lines, fixed leak & tested to 4000 psi, OK. Pumped 20 bbls of PreFlush, released Bttm Plug, pumped 30 bbls of MudPush @ 12 ppg + 36 bbls of Class G cmt w/GasBIock @ 15.8 ppg. Released Top Plug & pumped 2-3 bbls of cmt & 2 bfw. Displaced with rig pump at 80 spm (7 bpm) until last 21 bbls of displacement. Last 21 bbls displaced @ 3 bpm. Bumped plug 16 stks early. Pressured up from 600 - 3500 psi, held 5', OK. Bled off. R/D cmt head, released landing jt & L/D same, R/D fill up tool + csg bails & spider/elevator. R/U drlg bails & elevator. OPERATIONS SUMMARY 1J-10 05/17/01 12:00 AM 05/18/01 12:00 AM 05/19/01 12:00 AM P/U test jt + 7" packoff. Drained stack. Confirmed all 8 hold down bolts extended out. Ran/landed 7" packoff. Tightened hold down bolts & confirmed thru wing valve that packoff was in proper place. Tested between FS seals & lower debris seal to 5000 psi PJSM - laid down all 5" drillpipe & drlg jar + accelerator. Pulled mousehole, made up & installed test plug. PJSM- changed out lower VBR to 4" pipe ram. Changed topdrive saver sub from 4- 1/2" IF to HT-38. Changed over pipe handling eqpt to 4". Installed test jt & filled BOPE + choke manifold with water. Tested all pipe rams blind ram TIW choke manifold valves + ISBOP & top drive ISBOPs to 250 psi & 5000 psi. Tested annular to 250 psi & 3500 psi. Accumulator test. Pulled test plug. R/D test eqpt. Ran & set wear bushing. Finished picking up 45 jts of 4" HT38 drill pipe & racking them in the derrick. PJSM -Picked up new 6-1/8" bit + motor + directional MWD + LWD tools. M/U kelly hose & shallow test MWD tools & load nuclear sources. Picked up remainder of BHA. Finished picking up 4" drill pipe to 9520'. Circulated one pipe volume. Rigged up & tested 7" csg to 3500 psi for 30', OK. Bled off slowly. Washed down to 10,145', float collar. Cementer supposedly pumped 2-3 bbls of cement behind the top plug., could not tell too much with the PDC bit & motor. Cleaned out FC + 85' cmt + FS + rathole + 4' of new formation. There was cement between the float eqpt & no indication of any below shoe. This gave us 20' of rathole after drlg 4' of new hole to 10251 '. Circulating mud clean and getting the weight balanced out. We had pretreated mud for calcium contamination .... ir-respective of this we had about 10 minutes of thick mud. YP is very Iow now due to Bicarb + some Desco used. Finished circ'g & getting mud wt uniform. Conducted L.O.T. test to 12.8 ppg EMW. Performed test with the same result. Able to pump in at 0.5 bpm at a steady 810 psi. Circ'd and worked pipe periodically while monitoring well & discussing options with town. Circ'd & conditioned mud for upcoming cement squeeze. The YP had dropped to below 10, as this is the mud we cemented the casing with.., bumped up the YP some. Flow chkd well, OK. Pumped slug. POOH & racked BHA. Laid down the hang off collar & pulser. Serviced TDS + dwwks + crown. M/U 4" muleshoe & RIH with 4" open ended dp to TD @ 10,251'. Cir¢'d mud system & evened out mud wt for balanced cmt job. Held PJSM & installed DS cmt lo-torque & cmt line & tested same to 4000 psi, OK. Mixed & pumped 30 bbls of cmt as follows: Pump 15 BFW + 30 BCMT + 5 BFW + 81 BMUD. 30 bbls of Class G cmt @ 15.8 ppg w/108 cc fluid loss & 3hr-50' T.Time. Pulled 10 stands slowly - 3-4 min/std. Pipe dry. Circ'd down dp & reciprocated & rotated pipe @ 100 rpm @ 96 spm. Finished circ'g dp & annulus clean of cement. Closed upper pipe rams. Sqzd 10 bbls of cmt away @ .3-.4 bpm @ 850-1425 psi. Did this hesitation sqz 4 times w/ total fluid pumped = 10 bbls. Shut well in w/1410 psi. After 4 rhs= 790 psi. OPERATIONS SUMMARY t',' 1J-10 05/20/01 12:00 AM 05/21/01 12:00 AM Bled off press to trip tank & rec'd 0.6 bbls Therefore, total sqzd away = 9.4 bbls. POOH w/4" dp. P/U BHA & upload Sperry Tool (1hr) + surface test MWD tools. PJSM - Load nuclear sources to LWD tools. TIH to 9233'. Just above pt where cmt was circ'd from sqz string. Precautionary washed/reamed f/9233 - 10,251'. Had soft cmt @ 9787' & green cmt @ 9867' & hard cmt fl 10,100'. Drld 6-1/8" hole f/10251 - 10261' MD / 5961' TVD. Circ'd hole clean for F.I.T. Pulled 1 stand back into csg. R/U & performed F.I.T. to 990 psi @ 10251' / 9556' TVD - 14.0 ppg EMW. Pressure build never broke trend. Circ'd while swapping new CLEAN 11.4 ppg mud into system. Finished displacing hole to new mud. Drld f/10261 - 10396'. AST-0 & ART-2.75.. Got 5000 units of gas (did not look like 5000 units though, more like 3-400 units). Flow chkd, OK. Circ'd bttms up, OK. Drld f/10396 - 10479'. AST=1.5 & ART-1.5. Started getting dramatic losses. Initially 180 bph. Started adding BaroFibre & losses slowed to 60 bph. Stopped the Barofibre & added BaroSeal and losses reduced to manageable levels. Static losses @ 6 bph. Drld f/10479 - 10575'. AST-0 & ART-3. Static losses now zero. LCM plugged up suction lines. Cleared same. (( only adding 1 bag BaroSeal/ 10min.)) Drld f/10575 - 10845' TD. ART=6.5 & AST--0.5. Control drld f/40-50 fph to avoid increased mud losses. Circ'g and cleaning up hole. Flow checked well, slow decreased but still flowing some., circ'd bottoms up to confirm OK. All fine, no gas. Pumped to shoe @ 75 spm & 50-70 rpm. Hole took 19bbls. No bad spots. Monitored well, OK. TIH to TD. Circ'd and pumped 2 hi density sweeps (13.4 ppg). Pumped @ 70 - 85 spms... with minor mud losses of 4-6 bph. Circ'g all the LCM out of the wellbore across finer shaker screens. Monitored well, static. Pumped/rotated out to shoe, OK. Circ'd 2 bottoms up at shoe., to make sure anything we pumped from the open hole was out of the well. Flow chk, OK. Pumped slug (2ppg over mud wt). POOH & SLM. PJSM - laid down nuclear sources and the LWD & MWD tools + jars + flex collars, etc. Downloaded LWD data. PJSM - R/U to run 4-1/2" liner. Ran 27 jts of 4-1/2" 12.6 ppf L-80 NCST liner with 2 jts between float cllr & landing cllr. Ran XN nipple & Camco D nipple. All jts have straight blade centralizers + 1 stop cllr midway at each jt. M/U 4-1/2" dual cone hydraulic hanger. Made up top drive & filled string. Topdrive + blocks = 62000 & liner wt = 8000 lbs (very light). TIH with 4-1/2" liner having to run slow to keep from looSing too much mud. Had load of mud delivered yesterday just in case of heavy losses. Breaking circ every 2000' and circ'g 4-1/2" liner annulus vol in order to help to make sure everything is clean OPERATIONS SUMMARY 1J-10 05/22/01 12:00 AM 05/23/01 12:00 AM 05/24/01 12:00 AM TIH with 4-1/2" 12.6ppf L-80 NSCT liner to 10,214'. While running liner, chkd floats, OK. Fill dp every 10 stds. Had to run slower to keep from loosing mud. Total loss during run +/- 20 bbls. Broke circ every +/- 2000' and circ liner annulus volume Circ'd @ shoe. M/U plug drop head. TIH w/plug drop head on and tagged bttm @ 10,845', no fill. Worked circulation rate up slowly from 1.7 - 4 bpm without losses. Over 4 bpm and losses. Reciprocated liner thruout, 210k up & 115k down. Conditioned mud rheology for cmtg. PJSM - Tested cmt lines - 5000 psi, OK. Pumped 20 bbls of PreFlush + 20 bbls of MudPush + 27 bbls of cmt. Released dp wiper plug. Sheared liner wiper plug, OK. Bumped plug and pressured up to 3000 psi to set hgr, OK. Pressured up to 4000 psi & set Ii Circulated conventionally 2 dp volumes & 2 annulus volumes. Indications of some cement in returns, actual amount is debatable. Flow chkd well, OK. Pumped slug. POOH laying down 4" HT-38 dp. Laid down remainder of 4" HT-38 drill pipe. Jts 125 to 311. Laid down liner running tool & TIH w/8 stands of 4" dp in derrick, laid down\ same. Released hold down bolts, retrieved wear bushing. R/U tbg tongs + elevators. PJSM. Ran 4-1/2" completion jewelry + 4-1/2" 12.6 ppf L-80 IBT tubing. Pumped slug due to overflowing out top of tubing. R/U chart recorder & TIW valve, etc. Tested 7" csg + 4-1/2" liner to 3500 psi for 30 min, OK. Circ'd at 4 bpm and displaced all water based mud from tubing & tubing/csg annulus. Total seawater pumped 870 bbls. P/U 1 jt tbg & R/U to pump. Idled pumps @ 30 spm & lowered seal assy into tieback receptacle. Pressured up as 1st seal entered, bled off press. Measured in and-have full stroke of 12' seal assy. P/U space out pups, placed under I single of tubing below tubing hanger. Landed 4-1/2" tubing hanger. Secured lock down bolt. R/D tbg running eqpt. Pressured tbg, bled down to 500 psi, pressured tbg x csg annulus. Shear valve in bttm GLM sheared at 3200 psi after a couple of attempts. R/U to freeze protect well. Pumped 90 bbls of diesel to freeze protect well to 2200' TVD / 2500' MD. Let equalize. R/D. L/D landing jt. FMC installed BPV. Blew down lines. PJSM, slipped & cut 136' of drlg line. Changed topdrive back to 5" from 4". N/D stack & stand back on stump. N/U 4-1/2" x 5M X-Mas tree. Removed BPV. Installed 2 way check valve. Tested tree & hanger seals to 5000 psi, OK. Removed 2 way check valve. Installed BPV and secured well. Finished injection of all mud pits fluids, etc. @ 18:00 hrs. RIG RELEASED OPERATIONS SUMMARY 1J-10 6/12/01 6/16/01 7/18/01 Good cement found @ logged interval (17442' to 9965'). TD @ 17442. Perforation interval 10658 ft to 10678 ft. BSHP stop counts @ 10668 & 10645 ft. Gradient 0.43 psia/ft Pumped initial A sand frac. Well locked up in breakdown stage with gel on the perfs. Surged it open, able to pump into it again. Pumped scour and datafrac, gel not XL'ing in datafrac. Made adjustments, pumped second datafrac, brought out more water. Redesigned job based on second datafrac, targeted TSO at 50 minutes into job. Saw TSO 52 minutes into job, had NWBSO 50 bbls later in 6-10 ppa ramp stage. Placed 64M# behind pipe, 6.2 ppa on perfs. Left 39M# in wellbore. "C" sand perfs completed. Perforated interval 10446' - 10466', good shot indication. Used 20' of 3 3/8" HSD, 6 spf PJ chgs 60 deg phasing, lost gun at 628'. Left 34.1' of fired perf gun & tool string in the hole. Kuparuk River Unit North Slope, Alaska Kuparuk ~J Pad, Slot IJ-~O ~J- ~0 MWD Job No. AKMMI0136, Surveyed: 20 May, 2001 SURVEY REPORT 6 June, 2001 Your Ref: 500292301000 Surface Coordinates: 5945808.06 N, 558673.32 E (70° t5' 45.1692"N, Kelly Bushing: 1~4.25ft above Mean Sea Level 149° 3~' 32.4260" VI/) DRILLING SERVICES A Halliburton Company S.rvey Ref: svy9551 Sperry-Sun Drilling Services Survey Report for 1J-10 MWD Your Ref: 50029230'1000 Job No. AKMMfOf36, Surveyed: 20 May, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -114.25 100.00 0.050 275.490 -14.25 205.18 0.110 275.620 90.93 292.92 0.180 286.350 178.67 381.01 0.240 284.310 266.76 473.95 1.480 267.860 564.99 2.780 266.220 662.69 4.940 262.800 752.37 9.730 260.660 846.79 14.010 263.830 940.65 14.980 268.130 1033.80 16.910 272.290 1128.96 20.760 272.110 1222.81 23.230 272.040 1316.75 26.510 277.870 1410.41 29.750 281.460 1503.61 30.570 285.920 1596.97 33.340 292.540 1691.39 38.940 298.290 1785.33 45.110 299.300 1882.16 49.730 300.150 1971.22 55.320 300.630 2066.94 60.430 300.800 2161.05 64.000 301.430 2255.59 64.450 303.170 359.69 450.66 548.13 637.06 729.44 820.31 909.87 999.92 1086.93 1172.16 1254.76 1335.35 1414.58 1490.82 1560.57 1626.07 1680.24 1731.12 1774.98 1816.10 Vertical Depth (ft) 0.00 100.00 205.18 292.92 381.01 473.94 564.91 662.38 751.31 843.69 934.56 1024.12 1114.17 1201.18 1286.41 1369.01 1449.60 1528.83 1605.07 1674.82 1740.32 1794.49 1845.37 1889.23 1930.35 2348.16 63.680 300.530 1856.59 1970.84 2442.70 63.280 300.780 1898.80 2013.05 2535.64 63.660 300.260 1940.31 2054.56 2629.42 62.790 304.270 1982.57 2096.82 2723.57 62.580 303.340 2025.78 2140.03 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5945808.06 N 558673.32 E 0.00 N 0.04W 5945808.06 N 558673.28 E 0.02 N 0.19W 5945808.08 N 558673.13 E 0.07 N 0.41W 5945808.12 N 558672.91E 0.15 N 0.72W 5945808.20 N 558672.60 E 0.15 N 2.11W 5945808.20 N 558671.21E 0.04 S 5.48W 5945807.98 N 558667.84 E 0.72 S 12.02W 5945807.25 N 558661.30 E 2.43 S 23.34W 5945805.44 N 558650.00 E 4.96 S 42.58W 5945802.77 N 558630.78 E 6.58 S 66.00W 5945800.97 N 558607.37 E 6.43 S 91.57W 5945800.92 N 558581.80 E 5.25 S 122.27W 5945801.85 N 558551.10 E 3.98 S 157.39W 5945802.85 N 558515.96 E 0.45 S 196.69W 5945806.08 N 558476.64 E 7.03 N 240.19W 5945813.22 N 558433.09 E 18.13 N 285.65W 5945823.96 N 558387.54 E 34.48 N 332.20W 5945839.95 N 558340.87 E 58.52 N 382.34W 5945863.60 N 558290.53 E 88.82 N 437.41W 5945893.47 N 558235.23 E 124.18 N 499.30W 5945928.35 N 558173.07 E 159.93 N 560.24W 5945963.62 N 558111.85 E 201.33 N 629.91W 5946004.47 N 558041.86 E 244.35 N 701.17W 5946046.94 N 557970.26 E 289.84 N 773.13W 5946091.87 N 557897.96E 333.77 N 843.83W 5946135.25 N 557826.92 E 376.90 N 916.60W 5946177.81N 557753.81E 419.13 N 988.23W 5946219.48 N 557681.85 E 463.80 N 1059.01W 5946263.60 N 557610.72 E 510.34 N 1128.52W 5946309.60 N 557540.86 E Dogleg Rate (°/'~OOft) 0.050 0.057 O.O85 0.069 1.347 1.429 2.222 5.349 4.584 1.543 2.407 4.046 2.632 4.356 3.902 2.560 4.780 6.928 6.607 4.815 6.291 5.341 3.839 1.724 2.696 0.485 0.646 3.928 0.906 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 0.00 0.04 0.18 0.39 0.70 1.93 4.82 10.27 19.44 35.23 55.13 77.75 105.38 136.96 173.29 215.19 260.51 309.28 364.84 427.69 498.94 569.53 650.49 733.62 818.52 901.57 986.08 1069.16 1152.64 1235.88 MWD Magnetic 6 June, 2001 - 7:34 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-10 Your Ref: 500292301000 Job No. AKMMfOf36, Surveyed: 20 May, 200f Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings Northings (ft) (ft) (ft) (ft) 2816.42 63.620 302.130 2067.79 2182.04 2911.53 64.970 301.130 2109.04 2223.29 3006.17 66.450 296.620 2147.99 2262.24 3101.63 67.580 292.870 2185.27 2299.52 3194.19 67.350 296.910 2220.76 2335.01 3291.32 65.980 298.060 2259.23 2373.48 3383.21 65.950 294.460 2296.67 2410.92 3475.53 64.910 293.510 2335.06 2449.31 3569.60 64.760 299.090 2375.08 2489.33 3666.35 62.790 298.760 2417.83 2532.08 3755.91 62.520 302.940 2458.99 2573.24 3852.37 63.010 303.310 2503.13 2617.38 3947.50 62.110 302.910 2546.97 2661.22 4030.12 61.190 301.360 2586.20 2700.45 4157.12 59.840 304.450 2648.72 2762.97 4251.09 60.860 303.640 2695.21 2809.46 4347.61 61.210 303.160 2741.95 2856.20 4440.54 64.380 302.560 2784.43 2898.68 4534.67 66.320 302.630 2823.69 2937.94 4626.05 65.350 302.660 2861.10 2975.35 4720.90 64.100 302.780 2901.59 3015.84 4811.58 63.240 301.190 2941.82 3056.07 4904.94 63.700 303.440 2983.52 3097.77 4999.75 64.550 303.840 3024.90 3139.15 5095.75 64.720 307.020 3066.03 3180.28 5190.83 64.070 301.390 3107.15 3221.40 5284.61 62.880 303.360 3149.03 3263.28 5472.24 61.640 301.570 3236.37 3350.62 5566.22 62.890 300.450 3280.11 3394.36 5659.92 62.740 301.380 3322.91 3437.16 Global Coordinates 555.12 N 1198.17W 5946353.82 N 600.05 N 1271.14W 5946398.19 N 641.68 N 1346.66W 5946439.22 N 678.44N 1426.46W 5946475.37 N 714.41 N 1503.99W 5946510.73 N 755.57 N 1583.11W 5946551.27 N 792.69 N 1658.35W 5946587.80 N 826.82 N 1735.06W 5946621.34 N 864.52 N 1811.35W 5946658.44 N 906.50 N 1887.31W 5946699.83 N 947.28 N 1955.58W 5946740.07 N 994.15 N 2027.41W 5946786.38 N 1040.26 N 2098.13W 5946831.94 N 1078.94 N 2159.69W 5946870.14 N 1138.97 N 2252.50W 5946929.44N 1184.69 N 2320.17W 5946974.63 N 1231.17 N 2390.67W 5947020.57 N 1276.01N 2460.09W 5947064.86 N 1322.09 N 2532.16W 5947110.38 N 1367.06 N 2602.36W 5947154.80 N 1413.42 N 2674.52W 5947200.60 N 1456.47 N 2743.45W 5947243.11 N 1501.13 N 2814.03W 5947287.21N 1548.38 N 2885.05W 5947333.92 N 1598.66 N 2955.72W 5947383.64 N 1646.85 N 3026.59W 5947431.27 N 1691.77 N 3097.45W 5947475.64 N 1780.91N 3237.54W 5947563.69 N 1823.76 N 3308.84W 5947605.98 N 1866.58 N 3380.35W 5947648.25 N Eastings (ft) 557470.86 E 557397.54E 557321.70 E 557241.62 E 557163.81E 557084.37 E 557008.84 E 556931.87 E 556855.29 E 556779.01E 556710.42 E 556638.23 E 556567.15 E 556505.29 E 556412.01E 556343.99 E 556273.13 E 556203.36 E 556130.93 E 556060.38 E 555987.87 E 555918.60 E 555847.67 E 555776.29 E 555705.23 E 555633.99 E 555562.78 E 555422.00E 555350.37 E 555278.53 E Dogleg Rate (°/100ft) 1.614 1.707 4.616 3.805 4.O39 1.781 3.578 1.465 5.371 2.059 4.156 0.612 1.017 1.991 2.370 1.319 0.566 3.459 2.062 1.062 1.323 1.835 2.212 0.974 2.998 5.383 2.268 1.072 1.698 0.897 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 1318.41 1403.94 1490.16 1577.87 1663.20 1752.38 1836.24 1919.98 2005.O4 2091.82 2171.25 2256.69 2340.79 2413.32 2523.46 2604.68 2688.77 2771.12 2856.41 2939.52 3025.01 3106.09 3189.38 3274.29 3360.31 3445.52 3529.19 3694.76 3777.83 3861.08 6 June, 2001 - 7:34 Page 3 of 6 Dr#IQ,est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-lO MWD Your Ref: 50029230~000 Job No. AKMMfOf36, Surveyed: 20 May, 200'/ Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 5754.74 62.800 301.940 3366.30 3480.55 5850.82 63.200 302.250 3409.92 3524.17 5941.95 64.690 301.040 3449.95 3564.20 6035.32 64.670 300.810 3489.88 3604.13 6130.05 63.780 301.580 3531.07 3645.32 6222.87 64.860 299.470 3571.30 3685.55 6310.96 65.650 299,820 3608,17 3722.42 6408.81 64.830 297.970 3649.15 3763.40 6503,67 64.620 298.610 3689.66 3803,91 6598.64 63.580 298.280 3731.14 3845.39 6693.62 64.320 299.120 3772.85 3887.10 6787.41 65.210 298.710 3812.84 3927.09 6880.40 64.050 297.430 3852.68 3966.93 6966.16 64.350 295.400 3890.01 4004.26 7024.78 64.540 299.480 3915.30 4029.55 7118.18 63.030 299.250 3956.56 4070.81 7209.87 60.230 299.110 4000.12 4114.37 7302.45 57.930 299.040 4047.69 4161.94 7398.87 55.360 300.740 4100.71 4214.96 7488.91 52.170 301.810 4153.92 4268.17 7593.13 51.930 301.470 4218.01 4332.26 7677.20 51.470 301.110 4270.12 4384.37 7772.98 51.530 297.930 4329.75 4444.00 7867.97 52.560 294.630 4388.19 4502.44 7960.57 51.690 296.360 4445.04 4559.29 8053.67 50.740 295.240 4503.36 4617.61 8147.54 51.230 296.730 4562.45 4676.70 8250.40 52.020 298.360 4626.31 4740.56 8340.14 51.290 297.610 4681.98 4796.23 8430.76 50.600 297.080 4739.08 4853.33 Local Coordinates Global Coordinates Northings Eastings ' Northings Eastings (ft) (ft) (ft) (ft) 1910.84 N 3452.11W 5947691.94 N 555206.43 E 1956.32 N 3524.63W 5947736.86 N 555133.55 E 1999.27 N 3594.33W 5947779.26 N 555063.52 E 2042.64 N 3666.73W 5947822.07 N 554990.78 E 2086.82 N 3739.70W 5947865.68 N 554917.47 E 2129.30 N 3811.76W 5947907.59 N 554845.09 E 2168.87 N 3881.28W 5947946.62 N 554775.25 E 2211.81 N 3959.07W 5947988.95 N 554697.14 E 2252.46 N 4034.60W 5948029.01 N 554621.29 E 2293.15 N 4109.72W 5948069.12 N 554545.86 E 2334.13 N 4184.56W 5948109.51N 554470.70 E 2375.15 N 4258.83W 5948149.95 N 554396.12 E 2414.69 N 4332.96W 5948188.91 N 554321.68 E 2449.04 N 4402.11W 5948222.72 N 554252.26 E 2473.40 N 4449.03W 5948246.72 N 554205.16 E 2514.49 N 4522.05W 5948287.24 N 554131.81 E 2553.82 N 4592.48W 5948326.02 N 554061.08 E 2592.42 N 4661.89W 5948364.07 N 553991.37 E 2632.53 N 4731.72W 5948403.64 N 553921.23 E 2670.22 N 4793.79VV 5948440.84 N 553858.87 E 2713.33 N 4863.75W 5948483.41 N 553788.57 E 2747.59 N 4920.13W 5948517.23 N 553731.93 E 2784.52 N 4985.34W 5948553.65 N 553666.43 E 2817.66 N 5052.49W 5948586.26 N 553599.03 E 2849.11 N 5118.47W 5948617.20 N 553532.81 E 2880.70 N 5183.80W 5948648.28 N 553467.23 E 2912.66 N 5249.36W 5948679.73 N 553401.43 E 2949.95 N 5320.85W 5948716.46 N 553329.65 E 2982.98 N 5383.00W 5948749.00 N 553267.24 E 3015.30 N 5445.50W 5948780.84 N 553204.49 E Dogleg Rate (°ll00ft) 0.529 0.506 2.024 0.224 1.191 2.356 0.967 1.910 0.649 1,139 1.113 1.028 1.762 2.160 6.287 1.632 3.O57 2.485 3.045 3.670 0.345 0.642 2.599 2.946 1.749 1.386 1.339 1.461 1.045 0.887 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 3945.22 4030.62 4112.33 4196.63 4281.81 4365.38 4445.35 4534.19 4619.97 4705.40 4790.72 4875.55 4959.57 5036.74 5089.61 5173.38 5254.03 5333.44 5413.93 5486.43 5568.46 5634.33 5709.25 5784.09 5857.10 5929.61 6002.49 6083.12 6153.50 6223.87 6 June, 2001 - 7:34 Page 4 of 6 Dr#lQ,est 2.00.08.005 Sperry. Sun Drilling Services Survey Report for 1J-10 MWD Your Ref: 500292301000 Job No. AKMM10136, Surveyed: 20 May, 2001 Kuparuk River Unit Measured Depth (ft) Sub-Sea Depth (ft) Vertical Depth (ft) 8528.27 51.710 298.290 4800.24 4914.49 8623.73 53.910 301.550 4857.95 4972.20 8716.66 53.160 298.730 4913.19 5027.44 8809.01 52.420 299.080 4969.03 5083.28 8905.77 51.990 300.740 5028.34 5142.59 8999.46 51.980 299.390 5086.04 5200.29 9091.92 51.650 298.630 5143.20 5257.45 9184.93 50.870 295.470 5201.41 5315.66 9278.67 51.160 298.210 5260.39 5374.64 9371.54 50.930 299.060 5318.78 5433.03 9464.34 52.190 301.060 5376.47 5490.72 9559.28 53.420 300.720 5433.87 5548.12 9652.84 54.830 301.580 5488.69 5602.94 9748.58 54.260 300.110 5544.23 5658.48 9847.75 54.170 299.290 5602.22 5716.47 9935.02 53.850 298.780 5653.51 5767.76 10028.80 53.520 296.420 5709.05 5823.30 10121.00 53.240 296.480 5764.05 5878.30 10166.00 52.950 297.040 5791.07 5905.32 10317.30 53.990 294.470 5881.14 5995.39 10413.90 52.760 295.790 5938.77 6053.02 10512.90 51.920 298.120 5999.26 6113.51 10605.80 50.660 299.470 6057.36 6171.61 10704.60 49.950 299.440 6120.46 6234.71 10781.00 49.380 299.330 6169.91 6284.16 10845.00 49.380 299.330 6211.58 6325.83 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3050.59 N 5512.75W 5948815.60 N 553136.97 E 3088.54 N 5578.62W 5948853.04 N 553070.80 E 3126.07 N 5643.24W 5948890.06 N 553005.89 E 3161.62 N 5707.63W 5948925.11N 552941.23 E 3199.74 N 5773.90W 5948962.71 N 552874.66 E 3236.72 N 5837.78W 5948999.19 N 552810.50 E 3271.96 N 5901.34W 5949033.94 N 552746.67 E 3304.96 N 5965.93W 5949066.43 N 552681.82 E 3337.85 N 6030.93W 5949098.82 N 552616.57 E 3372.46 N 6094.31W 5949132.93 N 552552.91 E 3408.87 N 6157.21W 5949168.85 N 552489.73 E 3447.70 N 6222.11W 5949207.17 N 552424.53 E 3486.92 N 6286.99W 5949245.88 N 552359.35 E 3526.90 N 6353.94W 5949285.35 N 552292.09 E 3566.76 N 6423.82W 5949324.66 N 552221.90 E 3601.03 N 6485.55W 5949358.45 N 552159.90 E 3636.04 N 6552.51W 5949392.93 N 552092.68 E 3669.00 N 6618.77W 5949425.38 N 552026.17 E 3685.20 N 6650.89W 5949441.33 N 551993.91E 3738.01N 6760.38W 5949493.28 N 551884.01E 3770.92 N 6830.57W 5949525.64 N 551813.57 E 3806.44 N 6900.43W 5949560.61 N 551743.44 E 3841.34 N 6963.95W 5949595.02 N 551679.64 E 3878.73 N 7030.15W 5949631.89 N 551613.16 E 3907.30 N 7080.89W 5949660.07 N 551562.19 E 3931.10 N 7123.25W 5949683.53 N 551519.66 E Dogleg Rate (°ll00ft) 1.493 3.565 2.570 0.856 1.427 1.135 0.738 2.779 2.293 0.754 2.166 1.327 1.681 1.385 0.677 0.598 2.058 0.308 1.186 1.528 1.680 2.047 1.768 0.719 0.754 0.000 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 6299.81 6375.79 6450.47 6524.01 66OO.43 6674.19 6746.86 6819.38 6892.21 6964.43 7037.06 7112.60 7188.30 7266.19 7346.61 7417.21 7492.76 7566.73 7602.71 7724.16 7801.58 7879.93 7952.41 8028.41 8086.63 8135.20 Projected Survey 6 June, 2001 - 7:34 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-fO MWD Your Ref: 500292301000 Job No. AKMMlOf36, Surveyed: 20 May, 200~ Kuparuk River Unit North Slope, Alaska Kuparuk tJ Pad All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 114.3' MSL. Northings and Eastings are relative to 1996' FSL, 2536' FEE Magnetic Declination at Surface is 26.204° (22-Apr-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1996' FSL, 2536' FEL and calculated along an Azimuth of 298.100° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10845.00ft., The Bottom Hole Displacement is 8135.98ft., in the Direction of 298.893° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 10845.00 6325.83 3931.10 N 7123.25W Comment Projected Survey Survey tool program for I J-10 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 10845.00 6325.83 Survey Tool Description MWD Magnetic 6 June, 2001 - 7:34 Page 6 of 6 DrillQuest 2.00.08.005 Kuparuk River Unit North Slope, Alaska Kuparuk fJ Pad, Slot ?J-10 1J-10 Job No. AKZZf0138, Surveyed: 20 May, 2001 DEFINITIVE S UR VEY REPORT 5 jUne, 2001 Your Ref: 500292301000 Surface Coordinates: 5945808.06 N, 558673.32 E (70* 15' 45.1692"N, Kelly Bushing: 114.25fl above Mean Sea Level 149° 31' 32.4260" W) sp,=.r',r',~/-.un. DRILLING SERV'ICES A Halliburton Company Survey Ref: svy9548 Kuparuk River Unit Measured Depth (ft) Incl. 0.00 0.000 100.00 0.050 205~18 0.110 292.92 0.180 381.01 0.240 473.95 1.480 564.99 2.780 662.69 4.940 752.37 9.730 846.79 14.010 Azim. 0.000 275.490 275.490 286.510 283.510 267.530 265.870 262.470 260.340 263.580 940.65 14.980 267.940 1033:80 16.910 272.080 1128.96 20.760 271.810 1222.81 23.230 271.780 1316.75 26.510 277.620 Sub-Sea Depth (fi) -114.25 -14.25 90.93 178.67 266.76 359.69 450.66 548.13 637.06 729.44 820.31 909.87 999.92 1086.93 1172.16 Vertical Depth (ft) 0.00 100.00 205.18 292.92 381.01 473.94 564.91 662.38 751.31 843.69 Sperry-Sun Drilling Services Survey Report for 1J. lO Your Ref: $00292301000 Job No. AKZZI0138, Surveyed: 20 May, 2001 934.56 1024.12 1114.17 1201.18 1286.41 1410.41 29.750 281.170 1254.76 1369.01 1503.61 30.570 285.590 1335.35 1449.60 1596.97 33.340 292.110 1414.58 1528.83 1691.39 38.940 297.680 1490.82 1605.07 1785.33 45.110 298.600 1560.57 1674.82 North Slope, Alaska Kuparuk 1,1 Pad Local Coordinates Global Coordinates . Northings Eastings Northings Eastings fit) (ft) (ft) (ft) Dogleg Vertical Rate Section (°ll00ft) 0.00 N 0.00 E 0.00 N 0.04 W 0.02 N 0.19 W 0.07 N 0.41 W 0.15 N O.72 W 5945808.06 N 558673.32 E 0.00 5945808.06N 558673.28 E 0.050 0.04 5945808.08 N 558673.13 E 0.057 0.18 5945808.12 N 558672.91E 0.086 0.39 5945808.20 N 558672.60 E 0.069 0.70 Comment AK-6 BP IFR-AK 1882.16 491730 299.500 1626.07 1740.32 1971.22 55.320 299.730 1680.23 1794.48 2066.94 60.430 299.800 1731.12 1845.37 2161.05 54.000 300.170 1774.98 1889.23 2255.59 64.450 301.890 1816.09 1930.34 0.14 N 2.11W 5945808.19 N 558671.21 E 1.346 1.92 0.07 S 5,48W 5945807.95 N 558667.84 E 1.429 4.80 0,79 S 12.02W 5945807.18 N 558661.31 E 2.222 10.23 2.57 S 23.32W 5945805.31 N 558650.02 E 5.349 19.36 5.19 S 42.55W 5945802.54N 558630.81 E 4.586 35.10 2348.16 63.680 299.180 1856.58 2442.70 63.280 .299.550 1898.80 2535.64 63.660 299.260 1940.31 2629.42 62.790 303.570 1982.57 2723.57 62.580 302.460 .2025.78 6.89 S 65.97W 6.83 S 91.54W 5.80 S 122.24W 4.70 S 157.37W 1.34S 196.68W 5945800.65 N 558607.41 E 1.555 54.95 5945800.51 N 558581.83 E 2.404 77.53 5945801.31 N 558551.13 E 4.047 105.10 5945802.14 N 558515.99 E 2.632 136.61 5945805.19 N 558476.65 E 4.358 172.87 5.93 N 240.21W 16.78 N 285.73W 32.83 N 332.39W 56.40 N 382.76W 86.08 N 438.18W 5945812.12 N 558433.07 E 3.892 214.69 5945822.62 N 558387.46 E 2.539 259.96 5945838.30 N 558340.68 E 4.736 308.68 5945861.48 N 558290.13 E 6.871 364.21 5945890.72 N 558234.49 E 6.601 427.07 1970.83 2013.05 2054.56 2096.82 2140.03 120.71N 500.48W 5945924.86 N 558171.92 E 155.62 N 561.90W 5945959.30 N 558110.23 E 195.86 N 632.24W 5945998.98 N 558039.57 E 237.46 N 704.34W 5946040.03 N 557967.15 E 281~35 N 777.29W 5946083.34N 557893.86 E 323.64N 848.98W 365.12 N 922.70W 405.95 N 995.14W 449.57 N 1066.58W 495.14 N 1136.72W 5946125.08 N 557821.85 E 5946165.98 N 557747.80 E 5946206.24 N 557675.04 E 5946249.30 N 557603.27 E 5946294.33 N 557532.78 E 4.820 498.34 6.280 568.96 5.339 649.97 3.809 733.17 1.706 818.19 2.761 901.35 0.549 985.92 0.495 1069.05 4.206 1152.61 1.071 1235.95 5 June, 2001- 12:17 Page 2 of 6 DrillQ~esf 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-10 Your Ref: 500292301000 Job No. AKZZ10138, Surveyed: 20 May, 2001 Kuparuk River Unit Measured Depth (ft) Incl. 2816.42 63.620 301.810 2911.53 64.970 299.890 3006.17 66.450 295.330 3101.63 67.580 293.970 3194.19 67.350 293.900 Sub-sea Depth (ft) 2067.79 2109.04 2147.99 2185.26 2220.74 vertical Depth (ft) 2182.04 2223.29 2262.24 2299.51 2334.99 3291.32 65.980 294.890 2259.21 2373.46 3383.21 65.950 294.290 2296.64 2410.89 3475.53 64.910 293.770 2335.02 2449.27 3569.60 64.760 297.010 2375.03 2489.28 3666.35 62.790 299.400 2417.79 2532.04 3755.91 62.520 300.270 2458.93 2573.18 3852.37 63.010 300.300 2503.07 2617.32 3947.50 62.110 300.460 2546.91 2661.16 4030.12 61.190 300.880 2586.14 2700.39 4157.12 59.840 303.890 2648.66 2762.91 4251.09 60.860 302.580 4347.61 61.210 302.510 4440.54 64.380 301.260 4534.67 66.320 300.890 4626.05 65.350 300.500 2695.15 2741.89 2784.37 2823.63 2861.04 2809.40 2856.14 2898.62 2937.88 2975.29 4720.90 64.100 301.180 2901.54 3015.79 4811.58 63.240 300.840 2941.76 3056.01 4904.94 63.700 302.410 2983.46 3097.71 4999.75 64.550 302.910 3024.83 3139.08 5095.75 64.720 303.330 3065.96 3180.21 303.120 302.100 300.670 300.330 300.110 5190.83 64.070 5284.61 62.880 5472.24 ' 61.640 5566.22 62.890 5659.92 62.740 3107.05 3148.93 3236.27 3280.00 3322.81 3221.30 3263~18 3350.52 3394.25 3437.06 Local Coordinates Northings (ft) 539.19 N 583~12 N 623.06 N 659.71 N 694.40 N 731.23 N 766.15 N 800.34 N 836.64 N 877.84 N 917.42 N 960.67 N 1003.36 N 1040.45 N 1099.64 N 1144.39 1189.82 1233.46 1277.61 1320.17 Global Coordinates Eastings Northings Eastings (ft) (ft) (ft) 1206.84W 5946337.83 N 557462.32 E 1280.41W 5946381.18 N 557388.41 E 1356.83W 5946420.53 N 557311.68 E 1436.70W 5946456.56 N 557231.53 E 1514.84W 5946490.63 N 557153.12 E 1596.06W 5946526.83 N 557071.61 E 1672.37W 5946561.15 N 556995.03 E 1749.05W 5946594.75 N 556918.08 E 1825.96W 5946630.65 N 556840.90 E 1902.44W 5946671.05 N 556764.10 E 1971.45W 5946710.09 N 556694.79 E 2045.51W 5946752.76N 556620.39 E 2118.34W 5946794.89 N 556547.23 E 2180.88W 5946831.49 N 556484.40 E 2274,23W 5946889.94 N 556390.59 E 2342.54W 5946934.16 N 556321.94 E 2413.72W 5946979.03 N 556250.40 E 2483.90W 5947022.12 N 556179.89 E 2557.17W 5947065.71N 556106.27 E 2628.86W 5947107.71N 556034.25 E 1364.14 1406.01 1449.81 1495.84 1543.24 1590.22 1635.44 1721.93 1764.15 1806.10 2702.50W 5947151.10 N 555960.27 E 2772.16W 5947192,42 N 555890.29 E 2843.28W 5947235.67 N 555818.83 E 2915.09W 5947281.14 N 555746.66 E 2987.74W 5947327.97 N 555673.64E 3059.47W 5947374.39 N 555601.55 E 3130.15W 5947419.06 N 555530.53 E 3271.90W 5947504.44 N 555388.10 E 3343.57W 5947546.10 N 555316.10 E 3415.59W 5947587.49 N 555243.76 E Dogleg Rate (°/'~00ft) 1.282 2.307 4.661 1.767 0.258 1.693 0.597 1.238 3.121 3.009 0.914 0.509 0.958 1.200 2.321 1.627 O.368 3.615 2.092 1.131 1.469 1.006 1.583 1.014 0.433 0.712 1.599 0.944 1.368 0.263 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 1318.55 1404.14 1490.36 1578.08 1663.35 1752.34 1836.11 1919.86 2004.89 2091.66 2171.18 2256.88 2341.24 2413.88 2524.10 2605.44 2689.63 2772.09 2857.52 2940.80 3026.47 3107.64 3191.01 3276.04 3362.45 3447.85 3531.50 3697.28 3780.39 3863.68 5 June, 2001.12:17 Page 3 of 6 DrillQ.est 2.00.08.005 SPerry-Sun Drilling Services Survey Report for 1J-10 Your Ref: 500292301000 Job No. AKZZ10138, Surveyed: 20 May, 2001 Kuparuk River Unit Measured Depth (ft) Incl. 5754.74 62.800 301.130 5850.82 63.200 300.990 5941.95 64.690 299.680 6035.32 64.670 299.800 6130.05 63.780 300.340 6222,87 64.860 298.500 6313.96 65.650 298.440 6408.81 64.830 297.630 6503.67 64.620 297.320 6598.64 63.580 296.950 Sub-Sea Depth 3366,2O 3409,82 3449,85 3489,78 3530,97 3571,19 3609,32 3649,05 3689,55 3731,03 Vertical Depth (ft) 3480.45 3524.07 3564.10 3604.03 3645.22 3685.44 3723.57 3763.3O 3803.80 3845.28 6693.62 64.320 296.540 3772.74 3886.99 6787.41 65.210 296.450 3812.73 3926.98 6880.40 64.050 296.110 3852.57 3966.82 6966~16 64.350 295.400 3889.90 4004.15 7024.78 64.540 294.920 3915.18 4029.43 3956,44 4000,01 4047,58 4100,60 4153,81 7118.18 63.030 296.160 7209.87 60.230 298.630 7302.45 57.930 299.070 7398.87 55.360 301.940 7488.91 52.170 302.540 4070.69 4114.26 4161.83 4214.85 4268.06 7593,13 51,930 302,360 4217,90 4332,15 7677,20 51,470 302,090 4270,01 4364,26 7772,98 51,530 299,020 4329,64 4443,89 7867,97 52,560 297.090 4388,07 4502,32 7960,57 51,690 297,280 4444,92 4559,17 8053,67 50,740 297,100 8147,54 51,230 297,960 8250.40 52,020 299,020 8340.14 51.290 297,660 8430,76 50.600 297.760 4503,24 4562,33 4626,19 4681,86 4738,96 5 June, 2001- 12:17 4617,49 4676,58 4740,44 4796,11 4853.21 Local Coordinates Northings Eastings (ft) (ft) 1849,04N 1893,21N 1934,55 N 1976,42 N 2019,16 N 3488,15W 3561,48W 3632,14W 3705,42W 3779,25W 2060,24 N 2099,68 N 2140,16 N 2179,74 N 2218,70 N 3852,11 3924,83 4000,85 4O76,96 4152,98 W W W W W 2257,10 N 2294,95 N 2332,15 N 2365,70 N 2388,18 N 4229,19 4305,11 4380,45 4449,99 4497,86 2424,3O N 2461,40 N 2499,71N 2540,56 N 2579,29 N 4573,46 4645,09 4714,65 4784,04 4845,46 2623,39 N 2658,57 N 2696,67 N 2731,88 N. 2765,27 N 4914,81 4970,62 5035,16 5'101,26 5166,28 2798,44 N 2832,15 N 2870,62 N 2904,03 N 2936,75 N 5230.83 5295.50 5366.37 5428.31 5490.61 W W W W W W W W W W W W W W W W W W W W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5947629,87 N 555170,87 E 5947673,46 N 555097,19 E 5947714,25 N 555026,22 E 5947755,55 N 554952,61 E 5947797,71N 554878,45 E 5947838,22 N 554805,27 E 5947877,09 N 554732,25 E 5947916,98 N 554655,91 E 5947955,96 N 554579,50 E 5947994,33 N 554503,17 E 5948032,14 N 554426,68 E 5948069,39 N 554350,45 E 5948106,01 N 554274,83 E 5948139,01 N 554205,03 E 5948161,12 N 554156,99 E 5948196.65 N 554081.11E 5948233.19 N 554009.20 E 5948270.96 N 553939.34E 5948311.26 N 553869.63 E 5948349.52 N 553807.91 E 5948393,07 N 553738,22 E 5948427,82 N 553682,13 E 5948465,41N 553617,30 E 5948500,11N 553550,93 E 5948532,99 N 553485,65 E 5948565.65 N 553420.85 E 5948598.86 N 553355.91E 5948636.77 N 553284.74 E 5948669.70 N 553222.54 E 5948701.94 N 553159.99 E 0.959 0.436 2.083 0.118 1.071 2.132 0.869 1.161 0.369 1.150 0,870 0,953 1,290 0,823 0,807 2,008 3,865 2,518 3,645 3,583 0.268 0.602 2.509 1.934 0.953 1,031 0,883 1,115 1,440 0,766 Page 4 of 6 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 3947.91 4033.4O 4115.21 4199.57 4284.82 4368,45 4451,17 4537,30 4623.07 4708,49 4793,80 4878.6O 4962,58 5O39,73 5092,54 5176,25 5256.90 5336,31 5416,76 5489,19 5571,13 5636,94 5711,81 5786.70 5859.79 5932.35 6005.28 6085.91 6156.29 6226.66 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-10 Your Ref: 500292301000 Job No. AKZZ10138, Surveyed: 20 May, 2001 Kuparuk River Unil Measured Depth Incl. 8528.27 51.710 299.060 8623.73 53.910 300.140 8716.66 53.160 297.830 8809.01 52.420 298.590 8905.77 51.990 298.300 8999.46 51.980 297.980 9091.92 51.650 297.440 9184.93 50.870 297.630 9278.67 51.160 298.560 9371.54 50.930 300.200 Sub-Sea Depth (ft) 4800.12 4857.82 4913.05 4968.90 5028.20 5085.90 5143.06 5201.26 5260.24 5318.63 9464.34 52.190 299.660 5376.32 9559.28 53.420 299.060 '5433.71 9652.84 54.830 298.380 5488.54 9748.58 54.260 298.540 5544.08 9847.75 54.170 297.710 5602.07 9935.02 53.850 296,760 10028.80 53.520 295.920 10121.00 53.240 295.340 10166.00 52.950 295.120 10317.30 53.990 293.730 296.220 297.520 298.940 298.960 298.600 10413.90 52.760 10512.90 51.920 10605.80 50.660 10704,60 49.950 10781.00 49.380 10845.00 49.380 298.600 5653.35 5708.89 5763.89 5790.91 5880.97 5938.61 5999,09 6057.19 6120.29 6169.74 6211.41 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 4914.37 4972.07 5027.30 5083.15 5142.45 5200.15 5257.31 5315.51 5374.49 5432.88 5490.57 5547.96 5602.79 5658.33 5716.32 5767.60 5823.14 5878.14 5905,16 5995.22 6052.86 6113.34 6171.44 6234.54 6283.99 6325.66 2972.89 N 5557.40W 3010.45 N 5623.51W 3046.67 N 5688.88W 3081.44 N 5753.69W 3117.86 N 5820.92W 3152.67 N 5886.01W 3186.46 N 5950.35W 3220.00 N 6014.68W 3254.32 N 6078.96W 3289.74 N 6141.88W 3326.01 N 6204.88W 3363.08 N 6270.79W 3399.51N 6337.27W 3436.67 N 6405.84W 3474.59 N 6476.78W 3506.91 N 6539.57 W 3540.44 N 6607.28 W 3572.45 N 6674.00 W 3587.78 N 6706.55 W 3638.04 N 6817.25 W 3670.76 N 6887.52W 3706.18 N 6957.43W 3740.46 N 7021.30W 3777.26 N 7087.82W 3805.29 N 7138.86W 3828.55 N 7181.52W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5948737.55 N 553092.92 E 5948774.60 N 553026.52 E 5948810.31 N 552960.87 E 5948844.57 N 552895.79 E 5948880.46 N 552828.28 E 5948914.77 N 552762.92 E 5948948.06 N 552698.32 E 5948981.10 N 552633.73 E 5949014.91 N 552569.19 E 5949049.84N 552505.99 E 5949085.61N 552442.72 E 5949122.18 N 552376.52 E 5949158.08 N 552309.75 E 5949194.71N 552240.90 E 5949232.08 N 552169.66E 5949263.90 N 552106.63 E 5949296.90 N 552038.65 E 5949328.39 N 551971.68 E 5949343.48 N 551939.01E 5949392.87 N 551827.93 E 5949425.04 N 551757.41 E 5949459.91 N 551687.22 E 5949493.69 N 551623.09 E 5949529.97 N 551556.28 E 5949557.61N 551505.02 E 5949580.53 N 551462.19 E 1.541 2.475 2.156 1.035 0.504 0.269 0.581 0.854 0.831 1.395 1,432 1.390 1.618 0.611 0.685 0.954 0.803 0.589 0.754 1.009 2.429 1.342 1.806 0.719 0.828 0.000 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 6302.60 6378.61 6453.33 6526.88 6603.34 6677.15 6749.82 6822.37 6895.23 6967.43 7040.08 7115.68 7191.49 7269.47 7349.92 7420,52 7496.05 7569.98 7605.92 7727.24 7804,64 7882.99 7955.48 8031.49 8089.72 8138.30 Projected survey 5 June, 2001,12:17 Pag® 5of6 DrillQuest 2.00.08.005 sPerrY'sun Drilling Services Survey Report for IJ-10 Your Reft 500292301000 Job No. AKZZf0138, Surveyed: 20 May, 2001 Kuparuk River Unit . All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 114.3' MSL. Northings and Eastings are relative to 1996' FSL, 2536' FEL. Magnetic Declination at Surface is 26.204° (22-Apr-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1996' FSL, 2536' FEL and calcUlated along an Azimuth of 298.100° (True)i Based upon Minimum CurvatUre type calculations, at a Measured Depth of 10845.00ft.' The Bottom Hole Displacement is 8138.30ft., in the Direction of 298.063° (True). North Slope, Alaska Kuparuk 1J Pad Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 10845.00 6325.66 3828.55 N 7181.52W Comment Projected sUrvey Survey tool program for 1J-10 From To Measured Vertical Measured Vertical Depth Depth Depth Depth ~(ft) (rt) (ft) (ft) 0.00 0.00 10845.00 6325.66 Survey Tool Description AK-6 Bp_IFR-AK 5 June, 200f - 12:'/7 Page 6 of 6 DrillQuest 2.00.08.005 7/9/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1267 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Well Job # Log Description Date BL Sepia CD Color ~1C-133 ~_Z¥-,O'~' 21312 SCMT 06/18/01 1 1J-09 ZO(" ~¥ 21311 SCMT 06/05/01 1J-10 ~,,0(- 0~! 21306 SCMT 0611~01 1 3H-11 / ~-/~ 21314 USIT 06/14101 1 3H-~ /~?-IZy 2~3~4 USlT 06/14/0~ 1 3K-20 ~1'~ 21313 SCMT 06118101 . ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. RECEIVED 'JUL 1 3 2001 ~Oii&oasC°ns.~n ~mchmage 6/21/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-571t ATTN: Sherrie NO. 1242 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color f ~J-lO ~.ot '~l I SBHP 06/t2/01 1 1 1~1-11 j~,~-~'~ PROD PROFILE/DEFT 0610710t I 1 '3J3-19 l~?.0r)o 21280 RST 05125101 I 1 1 ~L-305 I~- Z~ 21289 SCMT 05115101 I i DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. RECEIVED JUN 22 2001 ALaka~&G~s.~ 05-Jun-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-10MWD Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 10,845.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JUN 11 2001 Alaska Oil & Gas Cons. An~omge IJ-10 Cement summaries Subject: 1J-10 Cement summaries Date: Mon, 16 Apr 2001 14:56:13 -0800 From: "Todd J Mushovic" <tmushov@ppco.com> To: tom_maunder@admin.state.ak.us CC: "James A Trantham" <jtranth@ppco.com> Tom, Here are the planned cement summaries for 1J-10. Please let me know if there is anything else that you need. Thanks Todd J. Mushovic Drilling Engineer Phillips Alaska inc. (907) 265-6974 - office (907) 240-5740 - cellular (See attached file: 1J-10 Surface Cementing Summary.doc)(See attached file: 1J-10 Liner Cementing Summary.doc)(See attached file: 1J-10 Intermediate Cementing Summary.doc) 1J-10 Surface Cementing Summary. doc Name: 1J-10 Surface Cementing Summary.doc Type: WINWORD File (application/msword) Encoding: base64 1J-10 Liner Cementing Summary.doc Name: 1J-10 Liner Cementing Summary.docI Type: WINWORD File (application/msword)1 Encoding: base64 1J-10 Intermediate Cementing Summary.doc Name: 1J-10 Intermediate Cementing Summary,doc Type: WINWORD File (application/msword) _Encod in_____g :~a~e~, 1 of I 4/16/01 3:59 PI~ 1J-10 Kuparuk Well Surface Cement loads and CemCADE* summary. Use 45% excess below the Permafrost and 250% above. Drilled with 12 1/4" bit. 9 5/8', 36 #casing TMD 7004', Single Stage Design. Tail Slurry TOC is ~ 4715' MD ( 800' above the West Sak top). Base of the Permafrost at 1477' MD Volume Caks: Pump 20 bbls CW100 Preflush, 50 bbls MudPUSH ×L Spacer ~ 10.Sppg. Cement from MD to 4715' with LiteCRETE @12.0 ppg and from 4715' to surface with ASLite @10.7 ppg Lea, d..Slu.rry.,.Requirements: ^SLite ~ 10.7 ppg, Class G + 50%13124, 9%1344, 0.4%1346, 30%1353, 1.5%S1, 1.5%1379 - 4.44 ft3/sk (4715'-1477') x 0.3132 ft3/ft x 1.45 (45% excess)= (1477') x 0.3132 ft3/ft x 3.50 (250% excess) = 1470.5 ft3+ 1619.1 ft3 = 3089.6 ft3/4.44 fl3/sk = 1470.5 ft3 1619.1 ft3 3089.6 ft3 695.9 sks - Round up to 700 sks Have 260 sks of additional Lead on location for Top Out/2n~ stage, if necessary Tail. Slur~LReouirements: LiteCRETE @ 12.0 ppg - 2.40 ft3/sk (7004'-4715') x 0.3132 ft3/ft x 1.45 (45% excess) = Shoe Joints: (80') x 0.4341 ft3/ft = 1039.5 R3 + 34.7 ft3 = 1074.2 ft3/2.40 ft3/sk = 1039.5 ft3 34.7 ft3 1074.2 ft3 447.6 sks - Round up to 450 sks BHST = 99 deg F (BHST calculated using a gradient of 2.6 °F/100 ft. below the permafrost) CemC~E*.Summarv: Fluid sequence: Establish circulation using FW. Pump 20 bbl CW100 Preflush, Drop Bottom Plug. Pump 50 bbls 10.Sppg MudPUSH XL Spacer, 700 sks (554 bbl) ASLite Lead, 450 sks (192 bbl) LiteCRETE Tail. Drop Top Plug. Displacement is approximately 535 bbls. Circulation: Circulation and cementing at or less than 8 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Run dye marker in the spacer to provide insight into the decision to open the port collar or performing a top job. Expected pressure to bump the plug is 700 psi. At 7 bpm, expect 30 minutes of u-tubing after dropping the top plug. Recommended Conditi0.ned ~.Mu,d Prope~gs! 10.0 ppg, Pv = 15 or under, Ty = !5 or under. 1J-10 Well Intermediate Cement loads and CemCADE* summary. Use 75% excess. Drilled with 8 1/2" bit. 7", 26 #casing TMD 10121'. TOC~ 9321' (800' Shoe Tack). Volume Calcs: Pump 20 bbls CWl00 Preflush, 30 bbls MudPUSH XL Spacer ~ 12.0ppg. Cement from 10121' MD to 9321' with Class G + adds ~15.8 ppg _,Slurry,, Requirements,: 15.8 ppg Class G 0.2%D46, 0.3%D65, 0.1%1)800 - 1.17 ft3/sk (adjust retarder to give 3-4 hours thickening time) 7", 26# x 8 1/2" OH: (10121'-9321') x 0.1268 ft3/f~ x 1.75 (75% excess) = 177.5 f~3 Shoe Joints: (80') x 0.2148 ft3/l~ = 17.2. ft3 Total Volume = 194.7 ft3. 194.7 R3 / 1.17 ft3/sk = 166 sks - Round up to 170 sks BHST = 148 deg F (BHST is calculated assuming 2.6 °F/100 ft. gradient below the permafrost,) CemCADE* Summa~: Fluid sequence: Establish circulation using FW, 20 bbl CWI00 Preflush, Drop Bottom Plug, 30 bbls 12.0 ppg MudPUSH XL Spacer, 170 sks (35 bbls) Class G + adds, Drop Top Plug. Displacement is approximately 384 bbls. Circul,ati0n: Circulation and cementing at or less than 7 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls ofdisplacement for bumping the plug. Expected pressure to bump the plug is 1400 psi. At 7 bpm, expect no u-tubing after dropping the top plug. Centrali,zers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recglnmended Conditiooe~,,Mu, d Properties: 10.0 ppg, Pv = 1. 5 or under, Ty = 15 or under. 1J-10 Kuparuk Well, Liner Cement loads and CemCADE* summary. Use 60% excess. Drilled with 6 1/8" bit. 4 1/2", 12.75 #casing TMD 10809'. TOC~ 9771' (200' over top of liner top). Liner Top ~ 9971' Previous casing 7", 26#, 10121' TMD. 4", 14# DP, 150' liner lap. Volume Calcs: Pump 20 bbis CWI00 Preflush, 20 bbls MudPUSH XL Spacer ~ 13.0ppg. Cement fi.om 10809' MD to 9771' with Class G + adds ~15.8 ppg Slurry_ Reauirements: 15.8 ppg GasBLOK w/Class G + D53, D600, D135, D800, D047, D065, per lab testing - 3.5 to 4.5 hour thickening time, Yield = 1.2 113/sx 4 1/2", 12.75# x 6 1./8" OH: (10809'-10121') x 0.0942 113/11 x 1.60 (60% excess) = 103.7 113 4 1/2", 12.75# x 7", 26#: (150') x 0.1044 113/t~ = 15.7 fl3 7", 29#: (200') x 0.2148 ft3/11 = 43 tt3 Shoe Joints: (80') x 0.0855 ft3/ft = 6.8 f~3 Total Volume = 169.2 113. 169.2 113 / 1.2 ft3/sk = 141 sks - Round up to 150 sks BHST = 159 deg F (BHST is calculated assuming 2.6 °F/100 ft. gradient below the permafrost.) CemCADE* Summa~: Fluid sequence: Establish circulation using FW, 20 bbl CW 100 Preflush, 20 bbls 13.0 ppg MudPUSH XL Spacer, 150 sks (32 bbls) Class G + adds, Drop Top Plug. Displacement is approximately 120 bbls. Circulation: Circulation and cementing at or less than 3 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 2 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1200 psi. At 3 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Cond,i,ti0,n, ,ed Mud pr0p,e ,rties,: 13.0 ppg (preferably lower), Pv = 15 or under, Ty = 15 or under. ALASKA OIL AND GAS COS~SERYATIO~ COMHISSIOS~ James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P.O. Box 100360 Anchorage Alaska 99510-0360 Re: Kuparuk River Unit 1 J- 10 Phillips Alaska, Inc. Permit No: 201-071 Sur Loc: 1996' FSL, 2536' FEL. Sec. 35, T1 IN, R10E, UM Btmhole Loc. 530' FSL, 876' FWL, Sec. 27, T1 IN, R10E, UM TONY KNOWLES, GOVERNOR 333 W. TTM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dear Mr. Trantham: Enclosed is the apprOved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for well 1J-10 until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production easing annulus of a well approved for annular disposal on 1J must Comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to "d~ill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must'be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole; Notice may 'be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE CO~S$ION DATED this ,, ,!;~..~ '&::x_ ,,,,~,a'"" of April, 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA '~' .~KA OIL AND GAS CONSERVATION COMM[',. _,,ON PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work: Ddll ~] Reddll r'l I lb. Type of well. Exploratory [~ Stratigraphic Test [~ Development Oil [~] Re-entry ~] Deepen [~I Service g] Development Gas r-] single zone [~] Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 34 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25660 ALK 470 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1996' FSL, 2536' FEL, Sec. 35, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1555' FNL, 570' FEL, Sec. 34, T11N, R10E, UM 1J-10 #59-52-180 At total depth 9. Approximate spud date Amount 530' FSL, 876' FWL, Sec. 27, T11N, R10E, UM April 20, 2001. $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 570' @ Targe feetI 1J-09, 160' at 300' feet 2560 10809' MD / 6316"rVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.03,5 (e)(2)) Kickoff depth: 500 MD Maximum hole angle 64° Maximum surface 2806 psig At total depth (TVD) 3477 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantily of Cement Hole Casln~l Wel~lht Grade couplin~l Len~lh MD TVD MD TVD (include sta~le data) 24" 16" 62.6# H-40 Welded 80' 115' 115' 115' 115' 460 sx AS 1 12.25" 9.625" 40# L-80 BTCM 6823' 115' 115' 6938' 3991' 700 sx AS Lite & 450 sx LiteCrete 8.5' 7" 26# L-80 BTCM 10002' 115' 115' 10117' 5891' 170 sx Class G 6.125" 4.5" 12.75# L-80 8rdEUEMod 838' 9971' 5802' 10809' 6316' 150 sx GasBIok 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) tree vertical feet Effective Depth: measured feet Junk (measured) ' true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface ProductionRECEIVED Uner APR 1 2 ZOO1 Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [~] Property Plat D BOP Sketch r-~ Dive,er Sketch D Drilling program r~ Drilling fluid program [~ Time vs depth plot D']Refraction analysis g] Seabed report D 20 AAC 25.050 requirements 21. I hereby certyy that the foregoing Is true and correct to the best o! my I~owledge ' Questions? Todd Mushovic 265-6974 Signed ~ Title: Driiii. g Engi, eetf.g Supervisor Date' I L Ja PreD~r~d by Sharoq ~411su~-Drak~ '"-~ Commission Use Onl) Perm, Number I APlnumber I Appr°valdateF"/~¢/ Seecoverletter -~---~/'- 0 ~'/) 50- 43~_.~ ---' ~..~::> / ~ ' for other requirements Conditions of approval Samples required D Yes r~ No Mud Icg required ~1 Yes [] No Hydrogen sulfidemeasures ~1 Yes D No Directional surveyreqalred .~ Yes D No D~M; D~M; ~[L~ I--I ,OM;FI O Required working pressure for 8OPE Other. .... [~ BY Approvedby #~1~ _~C~r~e. r_~ T thecommlssion Date . ~ · Form 10-401 Rev. 12/1/85 · Submit in triPlicate Kuparuk Producer KRU 1J-10 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 150' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/6938 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 8. Directionally drill 8-1/2" hole to base HRz (10117' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 9. Run 7" 26.0# L-80 BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pUmped for isolation in accordance with Rule 20 AAC 25.030 10. Nipple up BOPE and test to 5000 psi. Record results. 11.. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 12. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to'exceed 16.0 ppg' EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 13. Drill 6-1/8" hole to well total depth (+/- 10809' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 14. Run open hOle e-line or drill pipe conveyed logs as needed. 15. Run and cement 4-1/2" 12.75# L-80 HMC liner and Baker ZXP hanger/packer assembly. Set packer +/- 150' above intermediate, casing shoe to provide appropriate liner lap. 16. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 17. Run and land 4-1/2" tubing. 18. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up prodUction tree. pUll BPV. Install test plug, Pressure test production tree. Pull test plug. Secure well. 19. Freeze protect well. Set BPV. Release rig and turn well over to productiOn. 20. Clean 'location and RDMO in preparation for coiled tubing cleanout and perforating. ORIGINAL TJM, 4/11/00, v2 DRILLING I[~.dlD PROGRAM, PRESSURE cAL~dLATIONS, & DRILLING AREA RISKS KRU 1J-10 Drilling Fluid Properties: Spud to 9-5/8" Surface Casin~! Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 8.5-10.2 16-26 25-50 100-200' 10-20 15-40 7-15 9.5-10 6-8% Drill out to 7" Intermediate Casin[I 8.8-9.8 5-25 8-25 35-55 3-10 10-15 5-15 8.5-9.5 6-8% Drill Out to TD 11.3-13.0 25-35 2O-3O. 50-65 4-7 4-8 8-10 8.0-8.5 4-7% Drillin.q Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank' Fluid Flow Sensor Fluid Agitators *Spud mud shOuld be adjusted to a FV between 180-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the approPriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: One'p°ssibility exist for the possible maximum anticipated surface pressure (MASP) seen by the surface casing string along the 1J-10 well path. 1) MASP can be calculated using an expected leak-off of 15.4 ppg EMW (0.80 psi/ft) and a gas gradient of 0.11 pSi/fi. This shows that formation breakdown would occur at a surface pressure of 2754 psi. The leak off . EMW was chosen based on an open hole LOT on well, 1J-09, taken to 15.4 ppg (0.80 psi/fi). MASP = (3991 ft)(0.80 - 0.11) = 2754 psi ORIGINAL Phillips Alaska, Inc. will test the ,JP equipment to 5000 psi prior to drilling o 't of surface casing. The maximum anticipated pressure for the intermediate casing string would be 2806 psi as calculated below. 1) If surface shoe LOT is higher than expected and the well is drilled out of surface casing to TD, the MASP can be calculated based on a reservoir pressure of 3450 psi at 6100' TVD (0.57 psi/ft) and a gas gradient of 0.11 psi/ff. In this case, MASP would occur at 2806 psi. MASP = (6100 ft)(0.57 - 0.11) - 2806 psi Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing if an intermediate string is needed. Based on the anticipated pressures shown, a maximum mud weight requirement for this well is established based drilling to TD from surface casing. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 11.4 ppg can be predicted as the maximum mud weight needed to safely conduct rig operations, assuming a TVD of 6100'. MW = [(6100 ft)(0.57)+150]/6100/.052 = 11.4 ppg In order to allow for a long string design, the minimum LOT in the HRZ or surface casing shoe must be greater than ECD (equivalent circulating density) with a 11.4 ppg drilling fluid as modeled or as measured with the Pressure While Drilling (PWD) sub, plus adequate safety margin. Well Proximity Risks: The nearest existing well to 1J-10 is 1J-09. As designed, the minimum distance between the two wells would be 160' at 300' MD. !J-09 is a Kuparuk prOducer that has recently been drilled but not completed. ., Drillinq Area Risks: Risks in the 1J-10 drilling area include surface interval hydrates, lost circulation, and potential borehole instability in and below the permafrost zone as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and rheological properties which safely appropriate gas breakouL Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic gas injection. These gas pressure risks are mitigated with mid-HRZ LOT's and the well being top set above the D-shale based upon those results. Annular Pumpin.q Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.). The 1J-10 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. At the end of drilling operations, a request for 1J-10 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 1J pad, per regulation 20 AAC 25.080, will be submitted. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's ORIGINAL open below the shoe or pota ,.,,ndustrial water wells within one mile of u receiving zone. enclosed directional drilling plan for other formation markers in this well. Reference the Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi 7" 26 L-80 3 BTCM 5,410 psi 4,599 psi 7,240 psi 6,154 psi 4Y2"* 12.75 L-80 2 8rd EUE Mod 7,500 psi 6,375 psi 8,430 psi 7,165 psi *ifneeded Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAO 25.080 (h). ORIGINAL PHILLIi $ Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 April 12, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 1J-10 Surface Location: Target Location: Bottom Hole Location: 1996' FSL, 2536' FEL, Sec. 35, T11 N, R10E 1555' FNL, 570' FEL, Sec. 34, T11 N, R10E 530' FSL, 876' FWL, Sec. 27, T11 N, R10E Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 1J-10. The well will be drilled and completed using Nabors 16E. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1J, or hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated, contacts for reporting responsibilities to the Commission: A) Completion Report Sharon AIIsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Jeff Harrison, Geologist 265-6315 If you have any questions or require further information, please contact Todd Mushovic at (907) 265-6974 or James Trantham at (907) 265-6434. Sincerely, James Trantham Drilling Engineering Supervisor American Express' Cash Advance Draft 126 ,~,~ ~7~,'/ /2/ ~t Issued by Integrated Payment Systen~ Inc. Englewood, Colorado P~yable ~t Norwest B~nk of Grand Junction - Downtown, N~ Grand Junction, Colorado ': &O P i, DDhOD': 55 NOT VALID FOP, AMOUNT OVEP, $1000 /~/S.~,HARON. A~r.suPeq~RAK~ ,,,O ~ ? 5000 5 ~,'O ~ ~ N ' River ~~~ ~Kuparuk i~.~. ~ '~" ~' OSAL REPORT Your Ref: per Preliminary plan "IJ/1L Version #1" (3-29-01) Surface Coordinates: 5945808.10 N, 558673.30 E (70° 15' 45.0527" N, 149° 31' 32.4618" W) Kelly Bushing: 114.30ft above Mean Sea Level DRILLING ~I=RVIr' I= ~; A Halliburton Company Proposal Ref: pro9425 Sperry-Sun Drilling Services Proposal Report for 1J-10 (wp01) Your Reft per Preliminary plan "IJ/1L Version #1" (3-29-01) Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates G~_l"~_~r~~ ~- 'Dogleg Depth Incl. Azim. Depth Depth Northings Eastings N~~-~ ~i~s Rate (fi) (fi) (fi) (fi) (ft) _ *~' ~_.._ ~*~{h) (°ll00ft) o.oo o.ooo o.ooo -114.30 0.00 0.00 N 0.0~59458~0 N~ 558673.30 E oo.oo o.oooo.o oo.oo o.oo o.oo 200.00 0.0000.000 85.70 2o0.0o 0.00 N .~ ~0~ E 5945808.10 N 558673.30 E 0.00 ~00.00 0.0000.0~ 1~5.70300.00 0.~ ~ ~0 E 594580~.~ 0 N 5586~.~0 E 0.00 oo.oo o.oooo.ooo o.oo_ o.oo o.oo ~oo.oo o.ooo o.~ ~.~.~o ~oo.oo~ ~~~o.oo~ ~.~.o~.~o~ ~.~.~o~ o.oo ~oo.oo ~.ooo =~.~~.~~~~~=~~o.~ s =.~w ~.~o~.~ ~.~o.~~.oo 1000~00 16;231 207;205 ~ 870;61 993;01 11~27S 65;59 W 5945790~32 N 558607;80 E 4;00 1097.38 20.000 270.~6 972.15 1086.45 11.79 S 95.85 W 5945795.57 N 5585W.54 S 4.00 11~.00 20.083 270.~1 974.61 10~.91 11.78 S 96.75 W 5945795.57 N 558576.65 E 4.~ 1200.~ 23.394 276.710 1067.49 1181.79 9.27 S 1~.65 W 5945797.79 N 558539.73 E 4.00 1300.00 26.884 281.323 1158.02 1272.32 2.51 S 1400.00 30.491 284.931 1245.73- 1360.03 8.47 N 1476.88 33.320 287.214 1311.00 1425.30 19.75 N 1500.00 34.179 287.835 1330.22 1~.~..52 23.62 N 1600.00 37.922 290.231 1411.06 1525.36 42.86 N 175.55 W 222.25 W 261.28 W 273.53 W 329.12 W 5945804.22 N 5945814.84 N 5945825.81 N 5945829.59 N 5945848.39 N Vertical Section 1700.00 41.707 1800.00 45.522 1900.00 49.361 2000.00 53.217 2100.00 57.088 292.255 1487.86 1602.16 293.998 1560.25 1674.55 295.526 1627.87 1742.17 296.888 1690.40 1804.70 298.118 1747.53 1861.83 66.09 N 93.21N 124.08 N 158.56 N 196.46 N 388.77 W 452.17 W 519.03 W 589.01 W 661.78 W 5945871.16 5945897.78 5945928.13 5945962.06 5945999.40 0.00 0.00 0.00 0.00 0.00 0.00 1.96 7.82 17.58 21.70 31.83 52.55 79.00 79.80 113.53 558497.77E 4.00 153.68 558450.99 E 4.00 200.05 558411.87 E 4.00 239.79 558399.60 E 4.00 252.41 558343.85 E 4.00 310.51 558284.03 E 4.00 374.07 558220.41 E 4.00 442.78 558153.32 E 4.00 516.30 558083.07 E 4.00 594.27 558010.01E 4.00 676.31 North Slope, Alaska Kuparuk 1J Pad Comment SHL: X=558673.3, Y=59.,~5.~808.1 (1~c~_ FSL & 2536' FEL, SEC ~ -T11N- R10E) Begin Dir @ 3.00°/100 ft: 500.00 ft MD, 500.00 ft TVD Continue Dir @ 4.00°/100 ff: 833.33 MD, 831.64 ft TVD Base Permafrost 11 April, 2001 - 11:30 Page 2 of 10 DrillQuest 2.00.08.005 SPerry-Sun Drilling Services Proposal Report for 1J-10 (wp01) Your Reft per Preliminary plan ,'IJ/1L Version #1" (3.29-01) 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 35O0.00 300.069 1976.10 2090.40 300.069 2019.91 2134.21 4.0 4 00.069 20 .7 64.014' 300.069 2107.54 ~1.8,1j~ ~.014 300.069. 215~~ 64.0~4 00o.080 04.014 ~.0~4 800.08~ -2870.~ ~.74 552.00N 1280.95W 5946350.10 N 3600.00 64.014 300.069 3700.00 64.014 300.069 3800.00 64.014 300.069 3900.00 64.014 300.069 4000.00 64.014 300.069 4100.00 64.0141 300.069 4200.00 64.014 300.069 4247.59 64.014 300.069 4300.00 64.014 300.069 4400.00 64.014 - 300.069 2414.25 2458.07 2501.88 2545.7O 2589.52 2633.33 2677.15 2698.00 2720.96 2764.78 2528.55 2572.37 2616.18 2660.00 2703.82 2747.63 2791.45 2812.30 2835.26 2879.08 597.04 N 1358.75W 5946394.53 N 642.08 N 687.11 N 732.15 N 777.19 N 822.23 N 867.27 N 912.31N 957.35 N 1002.39 N 1047.43N 1092.47 N 1137.51N 1158.94 N 1182.55 N 1227.59 N 557856.93 557778.79 557700.65 557622.51 557544.37 557466.23 557388.08 557309.94 1436.54W 5946438.96 N 557231.80 E 1514.33W 5946483.39 N 557153.66 E 1592.12W 5946527.83N 557075.52 E 1669.92W 5946572.26 N 556997.38 E 1747.71W 5946616.69 N 556919.24 E 1825.50W 5946661.12 N 556841.10 E 1903.29W 5946705.55 N 556762.96 E 1981.08W ', 5946749.98 N 556684.82 E 2058.88W 5946794.42 N 555606.67 E 2136.67W 5946838.85 N 556528.53 E 2214.46W 2292.25W 2329.28W 2370.05W 2447.64W 5946883.28 N 556450.39 E 5946927.71N 556372.25 E 5946948.86 N 556335.06 E 5946972.14 N 556294.11E 5947016.57 N 556215.97 E 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 762.03 831.41 850.94 940.78 1030.61 1120.45 1210.29 1300.12 1389.96 1479.80 1 569.63 1659.47 1749.31 1839.14 1928.98 2018.82 2108.65 2198.49 2288.33 2378.16 2468.00 2557.64 2600.59 2647.68 2737.51 North Slope, Alaska Kuparuk 1J Pad Comment End Dir, Start Sail @ 64 2278.26ft MD, 1949.42lt, vD Top Ugnu 11 April, 2001 - 11:30 Page 3 of 10 DrillQuest 2.00o08.005 Sperry-Sun Drilling Services Proposal Report for 1J-10 (wp01) Your Reft per Preliminary plan "IJ/1L Version #1" (3.29-01) KuparUk River Unit Measured Depth (ft) Incl. Sub. Sea Depth (ft) 4500.00 64.014 300.069 2808.59 4600.00 64.014 300.069 2852.41 4700.00 64.014 300.069 2896.23 4800.00 64.014 300.069 2940.04 4900.00 64.014 300.069 2983.86 5000.00 64.014 5100.00 64.014 5200.00 64.014 5213.00 64.014 5300.00 64.014 5400.00 64.014 5500.00 64.014 5514,26 64.014 5518.83 5600.00 64.014 64.014 2922.89 556137.83 2966.71 556059.69 3010.53 555981.55 3054.34 555903.41 3098.16 555825.26 5700.00 64.014 5800.00 64.014 5900.00 64.014 6000.00 64.014 6100.00 64.014 300.069 3027.67 3141.97 Vertical Local Coordinates Global ~r~_ ~_~_ ~ Dogleg Depth Northings Eastings ~'i~ ~ ~s Rate 1317.66 N 2603.4~ ~g47105.44 N 1362.70 N ~~_ ~947149.87 N 1407,74" ~ -.~7~.~§947194.30" 1452,7_~~._ ~W - 5947238,73 N ~~ 29~.59 W 5947263.~6 N ~542~N ~ 2~2.~9 W 5947327.60 N ~~ ~ 3070.~ 8 W 594~372.03 N ~5 N 3080.29 W 5947377.80 N 300.069 3071.49 3185.79~ 00.0 9 300.069 3121.00 300,069 3159,12 3oo.069 I[325 .00 89.30 300.069 ~32~.57 3404.87 300.069 3334.38 300.069 3378.20 300.069 3422.01 300.069 3465.83 300.069 3509.65 3448.68 3492.50 3536.31 3580.13 3623.95 6200.00 64.014 300.069 3553.46 3667.76 6300.00 64.014 300.069 3597.28 3711.58 6400.00 64.014 300.069 3641.09 3755.39 6481.95 64.014 300.069 3677.00 3791.30 6500.00 64.014 300.069 3684.91 3799.21 1632.94 N 3147.97 W 5947416.46 N 1677.98 N 1723.02 N 1729.44 N 1731.5O N 1768.06 N 1813.09 N 1858.13 N 1903.17 N 1948.21 N 1993.25 N 2038.29 N 2083.33 N 2128.37 N 2165.28 N 2173.41 N 3225.76 W 3303.56 W 3314.65 W 3318.20 W 3381.35 W 3459.14 W 3536.93 W 3614.72 W 3692.52 W 3770.31 W 3848.10W 3925.89W 4003.69W 4067.44W 4081.48W E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 555747.12 E 0.00 555668.98 E 0.00 555590.84 E 0.00 555580.68 E 0.00 555512.70 E 0.00 5947460.89 N 555434.56 E 0.00 5947505.32 N 555356.42 E 0.00 5947511.66 N 555345.27 E 0.00 5947513.69 N 555341.71E 0.00 5947549.75 N 555278.28 E 0.00 5947594.19 N 555200.14 E 0.00 '5947638.62 N 555122.00 E 0.00 5947663.05 N 555043.86 E 0.00 5947727.48 N 554965.71E 0.00 5947771.91N 554887.57 E 0.00 5947816.34N 554809.43E 0.00 5947860.78 N 554731.29 E 0.00 5947905.21N 554653.15 E 0.00 5947941.62 N 554589.11 E 0.00 5947949.64N 554575.01E 0.00 Vertical Section 2827.35 2917.19 3007.02 3096.86 3186.70 3276.53 3366.37 3456.21 3467.88 3546.04 3635.88 3725.72 3738.53 3742.63 3815.55 3905.39 3995.23 4085.06 4174.90 4264.74 4354.57 4444.41 4534.25 4607.87 4624.08 North Slope, Alaska Kuparuk 1J Pad Comment Base Ugnu (K13) T1 (West Sak Target), 50.00 Radius. Geological Top West Sak Base West Sak (WSlO) DrillQuest 2. 00.08.005 11 April, 2001 - 11:30 Page 4 of 10 Sperry-Sun Drilling Services Proposal Report for 1J-10 (wp01) Your Reft per Preliminary plan "IJ/1L Version #1" (3,29-01) Kuparuk River unit Measured Depth (ft) 6600.00 6700.00 6800.00 6900.00 6938.41 7000.00 7100.00 7200.00 7234.36 7300.00 7400.00 7500.00 7541.83 7600,00 7700.00 Sub-Sea Vertical Local Coordinates Gl~i~r~-~.'~ ~ogleg Incl. Azim. Depth ~t~ ~-~ ~-"~'*~t) (°ll00ft) Depth .orthing, Easting, ~~ ~. ~ ~~, Rate (ft) . (ft) (fi) ' (fi) 64,014 300.069 3728.72 3843,02 2218.45 N 4159.27~ 59479~7 N 554496.87 E 0.00 64.014 300.069 3772.54 3886.84 2263.49 N 4237.0~~94803~0 N 554418.73 E 0.00 64.014 300.069 3816.35 3930,65 2308.53 N ~~ ~48082.94 N 554340,59 E 0.00 64.014 300.069 3860.17 3974,47 2353,57 N ~ l~ir3~~ 5948127.37 N 554262.45 E 0.00 o.oo 62.797 299.852 3904.57 4018.87~~ ~9__~N 4470.24W 5948171.56 N 554184.51E 2.00 58.850 299,113 4002.05 '~1~6.3~ ~ 2484.31 N 4622.21 W 5948256.32 N 554031.87 E 2.00 58.172 298.979 4020~0~~ ? 2498.54 N 4647.82 W 5948270.35 N 554006.15 E 2.00 52.114 4195.65 -- 4309.95 2618.32 N 4869.74 W 5948388.40 N 553783.30 E 2.00 52.114 297.690 4231.37 4345,67 2639.65 N 4910.39 W 5948409.41 N 553742.49 E 0.00 52.114 297.690 4292.78 4407.08 2676.33 N 4980.28 W 5948445.54 N 553672.32 E 0.00 7800.00 52.114 297.690 4354.19 7900.00 52.114 297.690 4415.60 8000.00 52.114 297.690 '4477.01 8100.00 52.114 297.690 4538.42 8200.00 52.114 297.690 4599.83 8300.00 52.114 8400.00 52.114 8500.00 52.114 8600.00 52.114 8700.00 52.114 297.69O 297.690 297.690 297.69O 297.69O 4661.24 4722.65 4764.06 4845.47 4906.88 4468.49 4529.90 4591.31 4652.72 4714.13 4775.54 4836.95 4898.36 4959.77 5021.18 2713.00N 5050.16W 2749.68 N 5120.05W 2786.35 N 5189.93W 2823.03 N 5259.82W 2859.70N 5329.70W 2896.37 N 2933.05 N 2969.72N 3006.40 N 3043.07 N 5399.59W 5469.47W 5539.36W 5609.24W 5679.13W 5948481.67 N 553602.15 E 0.00 5948517.80 N 553531.98 E 0.00 5948553.93N 553461.81E 0.00 5948590.06N 553391.65 E 0.00 5948626.18 N 553321.48 E 0.00 5948662.31N 553251.31E 0.00 5948698.44N '. 553181.14 E 0.00 5948734.57 N 553110.97 E 0.00 5948770.70N 553040.80 E 0.00 5948806.83N 552970.63E 0.00 Vertical Section 4713.92 4803.76 4893.59 4983.43 5017.94 5072.98 5161.08 5247.52 5276.81 5332.18 5414.97 5495.79 5528.99 5574.90 5653.82 5732.74 5811.66 5890.58 5969.50 6048.43 6127.35 6206.27 6285.19 6364.11 6443.03 North Slope, Alaska Kuparuk 1J Pad Comment Begin Dir @ 2.00°/100ft· 6938.41lt MD, 3991.30ft TVD 9-5/8' Casing C80 (K10) End Dir, Start Sail @ 52.114° · 7541.83ft MD, 4309.95ft TVD 11 April, 2001-11:30 Page5oflO DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Proposal Report for 1J-10 (wp01) Your Reft per Preliminary plan "IJ/1L Version #1" (3-29-01) Kuparuk River Unit Measured Depth 8800.00 8900.00 8924.93 9000.00 9100.00 9200.00 9300.00 9305.98 9400.00 9500.00 9600.00 9700.00 9794.50 9800.00 9900.00 9994.80 10000.00 10100.00 10116.93 10200.00 Local Coordinates Incl. Azim. Northings Eastings 52.114 52.114 52.114 52.114 52.114 297.690 4968.28 5082.58 3079.75 N 5749.01_,,~594! N 297,690 5029.69 5143.99 3116.42 N 5818.9~94! N 297.690 5045.00 5159.30 3125.56N ~~~ ~48888.0gN 297.690 5091.10 5205.40 3153.10N ~ ~_.'~'~~948915.22 N 297.690 5152.51 5266.81 3189._?~N -~ ~W-- 5948951.34 N W 5948987.47 N 52.114 297,690 5275.33 5389.63~ ~263.~..N~~'~ 6098.44W 5949023.60N 52.114 297.690 5279.00 5393.30~ '~N 6102.61W 5949025.76N 52.114 297.690 5336.74 ~'~ ~gN 6168.32W 5949059,73N 52.114 297.690 5398.15 _~Z~ ~ 3336.47N 6238.20W 5949095.86N 52.114 297.690~20~i~63~7 3409.82 N 6377.97 W 5949168.12 N 52.114 297.690~~0(~[-~'~-5693;~~'~'~=~=~-"-~" 3444.48N 6~dd.02W 5949202.26N 52.114 297,690 ~l~l~la~8~ 5696.68 3446.49N 6447.86W 594920425N 5643.78 ~ 5758.08 3483.17N 6517.74W 5949240.38N 52.114 297.690~ 52.114 297.690 5702.00 .5816.30 3517.93 N 6583.99W 5949274.63N 52.114 297.690 5705.19 5819.49 3519.84 N 6587.63W 5949276.50N 52.114 297.690 5766.60 5880.90 3556.52 N 6657.51W 5949312.63N 52.114 297.690 5777.00 5891.30 3562.73 N 6669.35W 5949318.75 N Sub-S. ., (ft) (ft) (ft) (fi) ~' ) t879~.09 52.114 297.690 5828.01 5942.31 3593.19 N 6727.40W 5949348.76 N Dogleg Rate (onooft) 552900.47 E 0.00 552830.30 E 0.00 552812.81E 0.00 552760.13 E 0.00 552689.96 E 0.00 552619.79 E 0.O0 552549.62 E 0.00 552545.43E 0.00 552479.46E 0.00 552409.29 E 0.00 552339.12 E 0.00 552268.95 E 0.00 552202.64E 0.00 552198.78 E 0.00 552128.61E 0.00 552062.09 E 0.00 552058.44E 0.00 551988.28 E 0.00 551976.40 E 0.00 551918.11 E 0.00 10247.20 10300.00 10361.19 52.114 297.690 5857.00 5971.30 3610.50 N 6760.39W 52.114 297.690 5889.42 6003.72 3629.87 N 6797.28W 52.114 297.690 5927.00 6041.30 3652.31N 6840.05W 5949365.82 N 551884.98 E 0.00 5949384.89 N 551847.94 E 0.00 5949407.00N 551805.00 E 0.00 10400.00 10450.76 52.114 297.690 5950.83 6065.13 3666.54N 52.114 297.690 5982.00 6096.30 3685.16 N 6867.17W 6902.64W 5949421.02 N 5949439.36N 551777.77 E 0.00 551742.15 E 0.00 Vertical Section 6521.95 6600.88 6620.55 6679.80 6758.72 6837.64 6916.56 6921.28 6995.48 7074.40 7153.33 7232.25 7306.83 7311.17 7390.09 7464.91 7469.01 7547.93 7561.30 7626.86 7664.11 7705.78 7754.07 7784.70 7824.76 North Slope, Alaska Kuparuk 1J Pad Comment C5O c4o (K5) C30 (K2) C20 (HRZ Midpoint) 7' Casing Base HRZ K1 Marker Top C4 Target - T2 (Top C4), 250.00 Radius Geological Top C3 11 April, 2001 - 11:30 Page 6 of 10 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Proposal Report for 1J-10 (wp01) Your Reft per Preliminary plan "IJ/1L Version #1" (3-29-01) Kuparuk R,ver Un,t Measured Sub-Sea Vertical Local Coordinates Gl~l~r~~' ~- ~Dogleg Depth Incl. Azim, Depth Depth .orthings Eastings .~~_ -_.~_ ~~ Rate (ft) (fl) (ft) (fl) (fl) ~. ~~ ~ ~::~t) - (°/lOOft) 6908.33_~ 10460.53 52.114 297.690 5988.00 6102.30 3688.74 N 6909.4..~.~. '~94944~9 N 551735.30 E 0.00 10463.78 52.114 297.690 5990.00 6104.30 3689.93 N ~ '~. '~. '~_._ 49~.06 N 551733.01 E 0.00 10500.00 52.114 297.690 6012.24 6126.54 3703.21 N .~ ~~'~'949457.15 N 551707.60 E 0.00 10600.00 52.114 297.690 6073.65 6187.95 3739.8~ ~ ~W ' 5949493.28 N 551637.43 E 0.00 ~ 10613.60 52.114 297.690 6082.00 6196.30 ~~ 7016.44W 5949498.19 N 551627.89 E 0.00 ~ 10700.00 52.114 297.690 6135.06 6249.36 ~ ~ ~776:'-~-N~'- 7076.82 W 5949529.41 N 551567.26 E 0.00 ~ 10727.59 52.114 297.690 6152.00 6266.30 ~'~.- ~ N 7096~10 W 5949539.37 N 551547.91 E 0.00 )~t 10800.00 52.114 297.690 6196.47 ~~ ~4N 7146.71W 5949565.54N 551497.10E 0.00 ~-~ 10809.01 52.114 297.690 6202.00 ~6.3-~ ~ 3816.54 N 7153.00 W 5949568.79 N 551490.77 E 0.00 ~;iRII data is in Feet Unless otherv~l~~ections and coordinates are relative to True Nort . ~'"'~'ertical depths are relative to RI~ l'~rra.3-'"~i/ISL. Northings and Eastings are relative to 1996' FSL, 2536' FEL. Magnetic Declination at SurfaCe is 26.219° (05-Apr.01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from 'As Planned' and calculated along an Azimuth of 298.100° (True). Based upon Minimum Curvature type calcUlations, at a Measured Depth of 10809.01ft., The Bottom Hole Displacement is 8107.49ft., in the Direction of 298.083° (True). Vertical Section 7831.18 7832.47 7835.O4 7863.62 7942.54 7953.27 8021.46 8043.24 8100.38 8107.49 North Slope, Alaska Kuparuk 1J Pad Comment Top C2 Top C1 Top B Shale Top A Sands Top Miluveach (Target Base) Total Depth · 10809.01ft MD, 6'316.,'. TVD 4-1/2' Liner 11 April, 2001 - 11:30 Page 7 of 10 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Proposal Report for 1J-10 (wp01) Your Reft per Preliminary plan "IJ/1L Version #1" (3-29-01) 'Kuparuk River Unit Measured Station CoOrdinates ~ '~t~- ~'- Depth 'TVD Northings Eastings Comment (ft) (ft) (fl) (ft) 0.00 0.00 0.00N 0.00E SHL: X=~~.~_ 5~08.1__~F~W~.~ (1996' FSL & 2536' FEL, SEC. 35-T11N-R10E) 500.00 500.00 0.00N 0.00E B ~el~~~0 ft: 500.00 ft MD, 500.00 ff TVD · 833.33 831.64 6.77 S 2821 W ~~r 0-~.~)0°/100 fi: 8.33.33 fl MD, 831.64 ft TVD {~ 2278.26 1949.42 ' 271:97 N 797.29~N ~--~Di~ Sailo~ 64.013°: 2278.26ft MD, 1949.42ft TVO I~i 7541.83 4309.95 2618.32 N ~~ ~nd Oir, StartSaJl @ 52.114 : 7541.83ft MD, 4..'.'.'.'.'.'.'.'.~.95ftTVO ~ Measured Vertical Sub-~ - ? Depth Depth Depth-';'- "Northings Eastings Dip Dip Dir. Formation Name (ft) (ft) (fi) (ft) (ft) D~. Deg. 1476.88 ' 1425.30 1311.00 19.75 N 261.28 W 0.000 0.446 4247.59 2812.30 2698.00 1158.94 N 2329.28 W 0.000 0.446 5213.00 3235.30 3121.93. 1593.75 N 3080.29 W 0.000 0.446 5518.83 3369.30 3255.00 1731.50 N 3318.20 W 0.000 0.446 6481.95 3791.30 3677.00 216528 N 4067.44 W 0.000 0.446 Base Permafrost Top Ugnu Base Ugnu (K13) Top West Sak Base West Sak (WS10) 7234.36 4134.30 4020.00 2498.54 N 4647.82 W 8924.93 5159.30 5045.00 3125.56 N 5836.32 W 9305.98 5393.30 5279.00. 3265.31 N 6102.61 W 9794.50 5693.30 5579.00 3~.~..48 N 6'H~..02 W 9994.80' 5816.30 5702.00 3517.93 N 6583.99 W 0.000 0.446 0.000 0.446 0.000 0.446 0.000 0.446 0.000 0.446 C80 (K10) C50 C40 (KS) C30 (K2) C20 (HRZ Midpoint) North Slope, Alaska Kuparuk 1J Pad 11 April, 2001 - 11:30 Page 8 of 10 DrillQuest 2.00o08.005 Sperry-Sun Drilling Services Proposal Report for 1J-10 (wp01) Your Reh per Preliminary plan "IJ/1L Version #1" (3-29-01) Kuparuk River 'Unit Measured Vertical Sub-Sea Depth Depth Depth .orthings Eastings Dip Dip Dir. For~~~ (ft) (ft) (ft) (ft) (ft) Deg. Deg. ~. FormationTops,Continued) i_~]~~ ~0247.20 5971.30 5657.00 3610.50 N 6?60.39 w~ ~0~446 K1 U~er 10361.19 6041.30 5927.00 3652.31 N 6~~0 -~'~=~'~0.446 Top C4 10450.7660~.30 5982.00 3685.~6N ~.~~ ~0 0.~ ;op 10460.53 6102.30 59~.00 36663~t~*~09.4~W 0.000 0.446 ;op Cl 104~.76 6104.30 5990.0o ~~ ~ *~11.74w 0.000 0.446 ;ope Sh=~e 10613.60 6196.30 6082:0.0 ~~ 7016.44 W 0.000 0.446 Top A Sands From To Measured Vertical Measured Depth Depth Depth (ft) (fi) (ft) Vertical Depth (ft) Casing Detail <Surface> <Surface> 6938.41 3991.30 <Surface> <Surface> 10116.93 5891.30 <Surface> <Surface> 10809.01 6316.30 9-5/8' Casing Casing 4-1/2' Liner North Slope, Alaska Kuparuk 1J Pad DrillQuest 2.00.08.005 11 April, 2001 - 11:30 Page 9 of 10 Sperry-Sun Drilling Services Proposal Report for 1J-10 (wp01) Your Ref: per Preliminary plan "IJ/1L Version #1" (3-29-01) Kuparuk River Unit Targets associated with this wellpath Target Name T1 (West Sak Target) ~ T2 (T°p C4) ~ t E~tr ordinates . N 3314.65 70° 140° 33' 08.0~0' ~0.05 70° ~40 ~' fi~.O2~O' North Slope, Alaska Kuparuk 1J Pad Target Target Shape Type Circle Geological Circle Geological 11 April, 2001 - 11:30 Page 10 of 10 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services "roposal Data - 1J- 10 - 1J- 10 (wpO" '§ 2278.26.1180.88. 64.'01 300'.07.. 194'9,43 862.98 27.1,97:.N ,-797.,2.9 W 4.00i..' 37.&24 . 831'.4. 6 5514.26 3236.00 64;01 30'0~07 336'7.30".'.!~7,87 1729.44 1~ 3314.65 W" 0~!00..' ?, ,i 6938.4111424.~51, '64.~i]. 300.0~.. 3991.3of;..'~24~'0012390.;87.,....... ':_ , ,. . .![4~22.53:.w~. . o.oo[ ,. 0.00[ .... 8 7541.83 603.42 52,1i 297~69 ~309..95:... 318,65.2618.32 N 48'69.74-'W 2.00-' '~89.02 · ;5529~.0: ................................................................... : .................................. ~_._a ......... ~.__ L ..... ORIGINAL r~rillt'J~ t~et Sperry-Sun Drilling Services '~.oposal Data - 1J- 10 - 1J- 10 (wpO~' [ i (f=) j ~.,~, ! . (o).. (f~,l .t. ':.~7_.'1 . .(ft) .... I (~'c) .lo/iOOf= (o)..~=~.~, L____~ .......................... L...~-.- ~.0~ ..... ' : :' _~. ':...l.:" .'(~C~.'.: .!'..~": ~ : ~ ,.~..._,..~-. ~. 'l ' · · ' '.." ::.;' (~) : z .:.co[ :.oc ' o.oo-~:4.3o[~.:~...:-,.:?'" 's~s~o~.~ ~5~3.~c ~1:,'.' '-.' ' ':: :.:':7 ::F: .... ~'~ t ; ............................. ~" '.'. '. ; .. , I ' ' t '. '' _ [ ..... ~ _- .... .._: · ......... :.~.:;~...~ , .~,. .. ... P . .. .......... ..:.... .. ~ ~o,?.~l -~.o~ ~.oo ~?..,o, ~72:~t-;~:6~15,.?,~,'s~' ..... · ...... :,, . '.., ,. ,, · ~ ' ,,'.~.,.....'' ...::'/:.?.......... 5 ~278.~6 [[80.88. 64.0[ 299.62 ~835,[3..:862;98~946073,85 ~ 5514.2~ 3236;0.0 .- 64.~0[ 299;62 ~:s~.oo"[~q~87~947~::.~ . .,..' , .. · 7' [ 6938.41J1424.15~,. . 6A.oiI. 299.62 3877.00[~, 62A'OO,.5948144.A3. ,,",,'..'. .. . NpS4232'.43' E; . 8 75A1.83 603.~2 52.11 29?7.24 4195.65 .3'18,655948388.A0 N553783~'.30 'I~ 2.00 189.02~' 5529,0 9 10361.19 2819'.3'6 52.1.1. 29'7.24 5927.00, 1'731'.355949407.00 ~551805.00 E'. 0'.00': ..... :~0.~.Q~::::77754'.1 .~_?..'__.].~..O._80.."_:..°!L__~_?.:._8~./._.5.~.:-3:~.L=_._9.?'.~! ?.0~'. ..... L__~:._~.... .... ,~5,~.o,?? ~: o ooi ..o:oo~ ..'e~o?.5 oo 275':0~'59A9568' .?g .............................. . ' . , .'. . ORIGIN'AL ~l~Br'~$/-sur'l. Kuparuk River Unit Kuparuk 1J Pad DrillQuesiTM ""'~'"° A'.".~%~.~' North Slope, Alaska 1J-10 (wp01) SHL: X=558673.3, Y:5945808.1 0 / (1996' FSL & 2536' FEL, SEC. 35-T11N-R10E) Current Well Prope~ies Well · 1J-10 in Dir ~ 3.~/100 fi' 5~.~ ff MD, ~0.00 ff ~D H~zo~ ~i~tes: Ref. Global ~inates: 5~808.10 N, 558673.30 E ' Ref. Stratum: 110.~ S, 117.53 W ' ontinue Dir ~ 4.~°/1~ ~: ~3.~ ff MD, 831.64 ff ~D Ref. G~mphi~l ~inat~: 70° 15' ~.0527' N, 149° 31' 32.~18' W ' 10~ -- ~ R~ El~afion: 114.~ a~ve Me~ Sea L~el I~ 114.3~ a~ve S~c~re ',~ No~ Refemn~: Tree Nodh ...... ~ -~ -~:;~:~ '"~ - - Uni~: F~t End Dir ~. Sail ~ ~ 013°'2278 26ff MD 1~ 4~ WD ~ '~ ~ "¢ ¢~' [ '~ :"~ ~' "~' i~ - ........... _'_- .......... : ...... B~in_* ~ 2'~°/1¢~__6~'4!" MD; 3'1_:3~ ~D ~== '' ': 5000 - ~ . ~ 066' FS~ & HSS' FW~ Sec. .. .. .. ...... . ~oo° - - .... · . ,,.. ... ~D~ ~1~ Total Dep~: 10809.01ff MD, 16.30ff ~ ~.O~'~D ~ J . (~0' FSL & 876' ~L, ~. 27-T11N-RIOE) J, I I I I I I I I I 0 1000 2000 3000 4000 5~0 6000 7000 8~0 9000 . ~ale: I i~h = 100~ Vedical Section '- .... ' · ' A z ~i; } u t~ ~' 2 9 ¢ i ,3 0 ('; i ~ ~.:~ ?,,J, ,i; ~ Kuparuk River Unit Kuparuk 1J Pad DriliQuest' ..... ~'- lq Current Well Properties Horizontal Coordinates: Ref. Global Coordinates- 5945808.10 N, 558673.30 E Ref. StnJcture · 110.63 S, 117.53 W Ref. Geographical Coordinates' 70° 15' 45.0527' N, 149° 31' 32.4618' W i~~ Reference is True North RKB Elevation- 114.30ft above Mean Sea Level ~,~ ,~// 114.30ft above Structure ~ ~ ---+~ ~ ~ North Reference · True North ~ ~_- Units' Feet -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 Total Depth: 10809.01ft MD, 6316.30ffTVD I 4-1~' uner (530' FSL & 876' FWL, Sec. 27-T11N-R10E) 10809.01' MD ~ ' 4000 ~ ~ls.~ wt) I 4000 '~ / '~. End Dir, Start Sail @ 52.114°: 7541.83ft MD, 4309.g5ff TVD 3000 T2 (TopC4)... 250' ~us Circle @ ~ / 6041.30 TVD, 3652.31 N, 6840.05 W '° 2278.25ff MD, I1040.4~t 'B/D Co tinue Dir 0 4.00°/100 It: / 833~33 ft MD, 831.64 ft TVD : iSHI_: ×=5§8673.3, Y=5~4§§08.1 (1 @~fi'IFSL & 253~' F~I_, Sec. 35-111N-R10[) -7000 '6000 -5000 -4000 -~000 -2000 -1000 0 1000 Scale: 1 inch = 1000ft Eastings ~l~mr~j-~_~. Kuparuk River Unit Kuparuk 1J Pad Drill uest' =RI[..I-IN. North Slope, Alaska 1J-10 (wp01) 1J-10 (wp01) Formations Measured Vertical Sub-Sea Current Well Properties~.. 1476.88 ' 131 1.00 131 1.00 Base Pennafi'os~ ' Wo,,' 1J-10 4247.59 2698.00 2698.00 ','op Ugnu i Hofizontsl Coordinates: 5213.00 3121.00 3121.00 Base Ugnu ¢'K13) Ref. Global Coordinatos · 5945808.10 N, 558673.30 I:: 5518.83 3255.00 3255.(10 Toll West Sak ROt. StrUcture · 110.63 S, 117.53 W : 6481.95 3677.00 3677.00 Base West Sak ~\VS 10) /,; ',.,,. RKB Elevation: 114.30ft above Mean Sea Level I 8924.93 5045.00 5045.00 C50 - - ' 9305.98 5279.00 5279.00 C40 ~ IC'~) 114.30ft above Structuro ~ 9794.50 5579.00 5579.00 C30 { K2) North Roferance: True North ~ 9994.80 5702.00 5702.00 c20 (HRZ Midpoim) 101 t6.93 5777.00 5777.(}0 Base IIP, Z units: Feet = 10247.20 5857.00 5857.00 K I Marker 1036 I_ 19 5927.00 5927.00 Top C4 1045(I.76 5982.00 5982.{)0 Top (73 10458.90 5987.00 5987.00 Top C2 10460.53 5988.00 5988.00 Top CI 10463.78 5990.00 5990.00 Top B Sh:dc 10613.60 6082_00 6082.00 Top A Sands ( ~ 10727.59 6152.00 6152.00 Top Miluvcach (Target Base) ~ Proposal Data for 1J-10 (wp01) ~ Vortical orig,n: RKB =114.3' MSL )mN Horizontal Origin: 1996' FSL, 2536' FEL Z Measurement Units: North Reference: True North Dogleg severity' Degrees per 100 feet ~ Vertical Section ~.lmuth: 298.100° Vertical Section Description: 'As Planned' Vertical Section Origin: 0.00 N,0.00 E ; , Measured Incl. Azlm. Vertical Northing$ Eaatinga Vertical Dogleg Comment Depth Depth Section Rate SILL: X=558673.3, Y=5945808.1 0.00 0.000 0.446 0.00 0.00 N 0.00 E 0.00 e99.6' FSL & 2536' FEL, SEC. 35-T11N-RIOE) g,n mr @ 3.00°/100 fl[: 500.00 fl MD, 500.00 ft TVD 500.00 0.000 0.446 500.00 0.00 N 0.00 E 0.00 0.00 Continue Dir @ 4.00°1100 fl: 833.33 ft MD, 831.64 ft TVD 833.33 10.000 256.500 831.64 6.77 S 28.21 W 21.70 3.00 End Dir, Start Sail @ 64.013°: 2278.26ft MD, 1949.42ft TVD 2278.26 64.014 300.069 1949.43 271.97 N 797.29 W 831.41 4.00 Begin Dir @ 2.00°/100ft: 6938.41ft MD, 3991.30ft TVD 6938.41 64.014 300.069 3991.30 2370.87 N 4422.53 W 5017.94 0.00 End Dir, Start Sail @ 52.114°: 7541.83ft MD, 4309.95ft TVD 7541.83 52.114 297.690 4309.95 2618.32 N 4869.74 W 5528.99 2.00 Total Depth: 10809.01ft MD, 6316.30ft TVD 10809.01 52.114 297.690 6316.30 3816.54 N 7153.00 W 8107.49 0.00 Single Well Target Data for 1J-10 Measurement Units: ft Coordinate Target Point 'rVD Northings Eastings Target SS ASP 4 ASP 4 Target Name Type Shape TVD Northings Eastings Shape T1 (West Sak Target) Entry Point 3367.30 1729.44 N 3314.65 W Circle 3253.00 5947511.66 N 555345.27 E Circle T2 (Top C4) Entry Point 6041.30 3652.31 N 6840.05 W Circle 5927.00 5949407.00 N 551805.00 E Circle Sperry-Sun Anficollision Report ( Date: 04/10/2001 Time: 17:38:29 Page: 1 Coordinate(NE) Reference: Vertical (TVD) Reference: Company: Phillips Alaska Inc. Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Well: 1J-10 (Plan), True Norlh Reference Well: 1J-10 (Plan) 1J-10:114.3' (79.7'+34.6') 114.3 Reference Wellpat~: 1J-10 (Plan) Db: Sybase GLOBAL SCAN APPLIED: All wellpaths within 200% 100/1000 of reference Reference: Plan: 1J-10 (wp01) & NOT PLANNED PR(~ Interpolation Method: MD Interval: 100.000 ft Error Model: ISCWSA Ellipse 1 Depth Range: 114.300 to 10810.266 ft Scan Method: Trav Cylinder North Maximum Radius: 1269.597 ft Error Surface: Ellipse Plan: 1J-10 (wp01) Date Composed: 0410612001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Summary < ............. Offset Wellpath > Site Well Wellpath Reference Offset ff ff Ctr-Ctr No-Go Distance Area ff ff Allo~mble Deviation warning . ft Kuparuk 1J Pad 1J-03 1J-03 Rig V1 114.300 114.300 161.411 Kuparuk 1J Pad 1J-09 1J-09 Rig V1 299.981 300.000 160.382 Kuparuk 1J Pad 1J-14 1J-14 Rig V0 499.986 500.000 560.712 0.001 161.410 Pass: Major Risk 2.529 157.855 Pass: Major Risk 5.091 555.623 Pass: Major Risk ORIGINAL Tray Cytinder Enor Surf.'e: Eilip6~l C~d,~ Wmmhg Ymlx~ Rules f WELL DETAILS +N/-S +E/-W N~Jxing Eaain~ LatitudeLongim~ S~ {Plzn) -110.6364 -117=~2~6 594580g.10~0 558~32000 70~15'45.170N 149'~31'37427W bYA Inlerpolalion Melhod'.MD Interval: 100.0000 Depth Range From: 114.3000 To: 10810.2659 Maximum Range: 1268.7911 Reference: Plan: IJ-10(wp01) SURVEY PR(3CJRAM E)~pth Fm I~pth To Sm'v~-y/Pbn Tool il4.3000 1(]810.2659Himed: IJ-10(wp01)VI MWD From Colour To MD 114 ~ 500 5OO 1000 1000 1500 1500 2000 2000 2500 2500 3000 35OO 3000 10000 11000 From Coiour ToM 114 500 500 1000 1000 1500 1500 2000 2000 .......2500 25OO 35OO 0 I J-09 (I J-09 Rig) 4000 3 6OOO . 3OOO 35OO 4OOO 7OOO 1000~ IIIXX 03 (i. I J-lO (l~n) ms: d. I)dnm: U-lO: I 143' {'/9.7'+34.6'} 114--~0~0 298.083' O.O000 ~ 114_~000 IJ-14 (,J-14 Pas). ~ lU,t ..... iJ-,O(w~0D Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [200ft/'m] ~ i J-lO (wpOl) (LI-IO (l~aa)/IJ-10 (l~n)) Creed BF I~Wayn~ Pran CheCked: Reviewed:.. Travelling Cylinder Azimuth ~AZI) [dog] vs Centre to Centre Separation [400ftfm] SBCTION DETAILS Sec k~ Inc AM TVD +NI-S +E/-WI~zg~ac~ VS~ Tnrg~ I 114..~0~0 0.0000~0 114..~00 600~0 0.fiO~O 0/~00O/~0 0.0000 i 500.~O30 O.0~0,{~O500.Ot~O 0.O0O0O,CO~O O.(~O O.~O 0.(}0~0 g33.33~3 10.{XIO ~ 831.6436 -6,7'/34 -2g.2134 3~00 256_q~O 21.7031 109(x5252 20~000 2'~EUO IC85.6149 -IZI230 .~5.6316 4.~O 25.912 7~.6656 22802555 64~2~ ~00.10~ 1950.7~7! 2~l.0414 -79~.~17 4~C0 37.809 ~c32.41~ 6 5514.8518 64.02g 2100.102 3367..~00 rF29.4700 -3314,65E0 0.0000~003'738,5531 0)39.7509 64.02~ ~00.1~t2 3991.3000 2371.0346 -4422~922 0.000OB(}O 5015.75~ $ 7544.4946 52.10~ 297.671 4310~ 2620.0066 -4871.0~1 2.000-170~O7 55~0.9409 9 10362.4971 5Z109 297.671 6041_~0t~ 3652.76~2 -6940~4~! 0,0000/~00 7754,gl63 1010~10.2~9 52.109 297.671 6316.-~N~0 3816.8697 -7153.60f~0 0.0000.~0$1(~.1794 WELL PERMIT CHECKLIST FIELD & POOL ~'.~,,'~ ADMINISTRATION WELL NAME ? ~7--/43 PROGRAM: exp dev ~X'... redrll serv wellbore seg ann. disposal para req ~ COMPANY _/~,,~.,~///,~;,~ r' GEOL AREA Y N Y N Y N Y N. Y N DATE INIT CLASS /~ ~u, / - ~,.'/ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............... ENGINEERING DATE Operator only affected party ................... Y N Operator has appropriate bond in force ............. Y N Permit can be issued without conservation order ........ Y N . 10. 11. 12. 13. _~' ? _f'3 UNIT# Permit canbe issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive hodzons ..... ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate weilbore separation proposed ....... ; ...... 23. If diverter required, does it meet regulations .......... 24. Drilling.fluid program schematic & equip list adequate.. ~ . . 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~'~3(:3(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ . 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y N (Y~ ON/OFF SHORE GEOLOGY 30. 31. 32. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ........ APPR DATE (B) will not contaminate freshwater; or cause drilling waste to surface; ' ' (C) will not impair meChanical integrity of the well used for disPosal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Permit can be issued wlo hydrogen sulfide measures ...... Y' N z/ Data presented on potential overpressure zones ....... ' ~/~N 4.,-'J! Seismic analysis of shallow gas zones. Seabed condition survey (if off-shore) ............. ' Contact name/phone for weekly progress reports [exploratory onl~ Y N Y N v~r~ P?z:)P~'P~~c~'?'o~ ' bo~.5'r~' ¢'-~ · 7'~-~(<~ bJ ~(:~w.--~l ~ Y N Y N Y N GEOLOGY: ENGINEERING:. ' UIC/Annular COMMISSION: .,,v,.. ...... Comments/instructions: 0 Z 0 c:~soffice\wordian~diana\checklist (rev. 111011100) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding informatiOn, information, of this nature is accumulated at the end of the file under APPENDIXi ., No 'special'effort has been made to chronologically. organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Oct 30 15:14:52 2001 Reel Header Service name ............. LISTPE Date ..................... 01/10/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/10/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ...... .UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-10136 P. SMITH G. WHITLOCK 1J-10 500292301000 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 30-OCT-01 MWD RUN 2 MWD RUN 4 AK-MM-10136 AK-MM-10136 T. MCGUIRE T. MCGUIRE M. THORTON M. THORTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 6 AK-MM-10136 P. SMITH R. ROSS 35 liN 10E 1996 2536 .00 114.25 79.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 12.250 16.000 120.0 2ND STRING 8.500 9.625 6945.0 3RD STRING 6.125 7.000 10230.0 PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL, WITH DUAL GAMMA RAY (DGR)UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUN 2 WAS DIRECTIONAL WITH DGR , EWR4, COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD RUN 3 WAS ABORTED DUE TO CASING TEST FAILURE. NO DATA WERE OBTAINED. 6. MWD RUN 4 WAS DIRECTIONAL WITH DGR AND EWR4. 7. MWD RUN 5 WAS DIRECTIONAL WITH DGR, EWR4, SLD, AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). AFTER DRILLING 4' OF NEW HOLE AND PERFORMING AN FIT, WHICH FAILED, THIS RUN WAS ABORTED. WHAT MINIMAL DATA WERE ACQUIRED WERE MERGED WITH MWD RUN 6. 8. MWD RUN 6 WAS DIRECTIONAL WITH DGR, EWR4, SLD, AND CTN. 9. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 10/29/01, QUOTING AUTHORIZATION FROM J. HARRISON WITH PAI. 10. MWD RUNS 1, 2, 4, 6 REPRESENT WELL 1J-10 WITH API%: 50-029-23010-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10845'MD / 6325.98'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SBD2 = SMOOTHED BULK DENSITY-COMPENSATED {LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR. SLDSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR THE BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY-LOG PROCESSING HOLE SIZES: MUD WEIGHTS: MUD SALINITY: FORMATION WATER SALINITY: 12.25" SPSF / 6.125" TNPS 9.6 PPG SPSF / 11.3 - 11.4 PPG TNPS 400 - 600 PPM CHLORIDES 13,000 PPM CHLORIDES FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 1 G/CM3 2.65 G/CM3 SANDSTONE 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 RPX RPS RPM RPD FET GR ROP NCNT FCNT NPHI RHOB DRHO PEF $ BASELINE CURVE FOR SHIFTS: START DEPTH 167.5 167.5 167.5 167 5 167 5 175 5 220 5 3990 0 3990 0 3990 5 4000 0 4000.0 4000.0 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 167.5 4100.0 2 3990.0 6960.0 4 6903.5 10246.5 6 10151.0 10845.0 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 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 ROP MWD FT/H 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 FET MWD HOUR 4 1 68 24 7 NPHI MWD PU-S 4 1 68 28 8 FCNT MWD CNTS 4 1 68 32 9 STOP DEPTH 10803.5 10803.5 10803.5 10803.5 10803.5 10796.5 10845 0 10748 5 10748 0 10748 0 10763 5 10763 5 10763 5 EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ NCNT MWD RHOB MWD DRHO MWD PEF MWD GR MWD CNTS G/CM G/CM BARN API 1 68 1 68 1 68 1 68 1 68 36 10 40 11 44 12 48 13 52 14 Name Service Unit DEPT FT ROP MWD FT/H RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU-S FCNT MWD CNTS NCNT MWD CNTS RHOB MWD G/CM DRHO MWD G/CM PEF MWD BARN GR MWD API Min 167.5 0 0 83 0 89 0 0 0 -1 76. 2082. 1. --0. 1. 19. 84 35 22 36 05 84 22 15 03 28 Max 10845 721.08 1671.53 2000 2000 2000 163.98 75.64 1187 30714.2 3.22 0.76 19.98 421.14 First Reading For Entire File .......... 167.5 Last Reading For Entire File ........... 10845 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Mean Nsam Reading 5506.25 21356 167.5 146.602 21250 220.5 15.9175 21273 167.5 22.5044 21273 167.5 33.9606 21273 167.5 53.7465 21273 167.5 2.62199 21273 167.5 32.3694 6913 3990.5 655.353 6916 3990 5576.68 6915 3990 2.26832 6793 4000 0.0801678 6794 4000 3.34788 6917 4000 94.2785 21243 175.5 Last Reading 10845 10845 10803.5 10803.5 10803.5 10803.5 10803.5 10748 10748 10748.5 10763.5 10763.5 10763.5 10796.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 167.5 4046.5 RPS 167.5 4046.5 RPM 167.5 4046.5 FET 167.5 4046.5 RPD 167.5 4046.5 GR 175.5 4054.0 ROP 220.5 4100.0 $ LOG HEADER DATA DATE LOGGED: 01-MAY-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.4099960327148 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: Memory 4100.0 175.0 4100.0 .1 67.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01932HRG8 EWR4 ELECTROMAG. RESIS. 4 PB01932HRG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 BOREHOLE CONDITIONS MUD TYPE: SPUD MUD MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 164.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3): .1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 5.000 MUD AT MAX CIRCULATING TERMPERATURE: 3.810 MUD FILTRATE AT MT: 5.100 MUD CAKE AT MT: 3.100 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 RPX MWD010 OHMM 4 1 68 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 68.0 91.4 68.0 68.0 Name Service Unit Min Max DEPT FT 167.5 4100 ROP MWD010 FT/H 0 585.37 GR MWD010 API 19.28 137.73 RPX MWD010 OHMM 2.54 1671.53 RPS MWD010 OHMM 3.28 1672.01 RPM MWD010 OHMM 3.11 2000 RPD MWD010 OHMM 3.78 2000 Mean 2133.75 159.826 71.2084 31.2655 48.3512 69.6631 108.267 Nsam 7866 7760 7758 7759 7759 7759 7759 First Reading 167 5 220 5 175 5 167 5 167 5 167 5 167 5 Last Reading 4100 4100 4054 4046.5 4046.5 4046.5 4046.5 FET MWD010 HOUR 0.22 9.05 0.717011 7759 First Reading For Entire File .......... 167.5 Last Reading For Entire File ........... 4100 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 167.5 4046.5 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 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: 2 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 3990.0 3990.0 3990.5 4000 0 4000 0 4000 0 4047 0 4047 0 4047 0 4047 0 4047 0 4054 5 4100 5 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 GAMMA RAY EWR4 CNP SLD $ ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN STOP DEPTH 6850.0 6850.0 6849.5 6859.5 6859.5 6859.5 6903.0 6903.0 6903.0 6903.0 6903.0 6910.5 6960.0 05-MAY-01 Insite 65.4099960327148 Memory 6960.0 4100.0 6960.0 59.8 66.3 TOOL NUMBER PB01932HRG8 PB01932HRG8 PB01932HRG8 PB01932HRG8 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 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 NPHI MWD020 PU-S 4 1 68 FCNT MWD020 CNTS 4 1 68 NCNT MWD020 CNTS 4 1 68 RHOB MWD020 G/CM 4 1 68 DRHO MWD020 G/CM 4 1 68 PEF MWD020 BARN 4 1 68 12.250 SPUD MUD 9.60 84.0 8.5 450 4.8 0 4 8 12 16 20 24 28 32 36 4O 44 48 52 6.500 4.580 4.500 6.500 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 65.0 95.0 65.0 65.0 Name Service Unit Min Max Mean DEPT FT 3990 6960 5475 ROP MWD020 FT/H 0 426.69 129.365 GR MWD020 API 30.41 140.25 81.8238 RPX MWD020 OHMM 2.47 72.35 10.6565 RPS MWD020 OHMM 2.52 89.76 11.5273 RPM MWD020 OHMM 2.51 83.43 11.6361 RPD MWD020 OHMM 2.81 86.59 12.5338 FET MWD020 HOUR 0.28 20.11 1.50087 NPHI MWD020 PU-S -1.36 66.72 31.0658 FCNT MWD020 CNTS 560.9 1187 733.971 NCNT MWD020 CNTS 2082.84 3336 2472.44 RHOB MWD020 G/CM 1.22 3.12 2.22709 DRHO MWD020 G/CM -0.1 0.76 0.0778147 PEF MWD020 BARN 1.03 4.26 2.23188 Nsam 5941 5720 5713 5713 5713 5713 5713 5713 5719 5721 5721 5720 5720 5720 First Reading 3990 4100.5 4054.5 4047 4047 4047 4047 4047 3990.5 3990 3990 4000 4000 4000 Last Reading 6960 6960 6910.5 6903 6903 6903 6903 6903 6849.5 6850 6850 6859.5 6859.5 6859.5 First Reading For Entire File .......... 3990 Last Reading For Entire File ........... 6960 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 6903.5 10190.5 RPX 6903.5 10190.5 RPM 6903.5 10190.5 FET 6903.5 10190.5 RPD 6903.5 10190.5 GR 6911.0 10198.0 ROP 6960.5 10246.5 $ LOG HEADER DATA DATE LOGGED: 13-MAY-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.1599960327148 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10247.0 TOP LOG INTERVAL (FT): 6960.0 BOTTOM LOG INTERVAL (FT): 10247.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION {DEG MINIMUM ANGLE: 50.6 MAXIMUM ANGLE: 64.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1990HWRG6 EWR4 ELECTROMAG. RESIS. 4 PBO1990HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE {IN): 12.250 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 48.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 4.4 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 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order 1.450 .850 2.100 1.250 Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 66.0 118.0 66.0 66.0 Name Service Unit Min Max DEPT FT 6903.5 10246.5 ROP MWD040 FT/H 2.21 721.08 GR MWD040 API 50.45 421.14 RPX MWD040 OHMM 1 1601.74 RPS MWD040 OHMM 0.89 1609.72 R?M MWD040 OHMM 0.84 2000 RPD MWD040 OHMM 0.35 2000 FET MWD040 HOUR 0.25 163.98 Mean 8575 163.448 131.353 3.38399 3.5166 5.86776 19.3689 3.73555 First Reading For Entire File .......... 6903.5 Last Reading For Entire File ........... 10246.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Nsam 6687 6573 6575 6575 6575 6575 6575 6575 First Reading 6903.5 6960.5 6911 6903.5 6903.5 6903.5 6903.5 6903.5 Last Reading 10246.5 10246.5 10198 10190.5 10190.5 10190.5 10190.5 10190.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NPHI NCNT PEF RPD RPX RPM FET RPS GR DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 10151 0 10151 5 10152 0 10165 5 10191 0 10191 0 10191 0 10191 0 10191 0 10198 5 10227 0 10227 5 10247 0 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 GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ 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 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: STOP DEPTH 10748 0 10748 0 10748 5 10763 5 10803 5 10803 5 10803 5 10803 5 10803 5 10796.5 10763.5 10763.5 10845.0 20-MAY-01 Insite 66.1599960327148 Memory 10845.0 10247.0 10845.0 49.4 54.0 TOOL NUMBER PBO2021GR4 PBO2021GR4 PBO2021GR4 PBO2021GR4 12.250 LSND 11.30 54.0 9.2 55O 3.8 1.800 72.0 1.030 131.0 1.400 72.0 2.350 72.0 $ 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD060 FT/H 4 1 GR MWD060 API 4 1 RPX MWD060 OHMM 4 1 RPS MWD060 OHMM 4 1 RPM MWD060 OHMM 4 1 RPD MWD060 OHMM 4 1 FET MWD060 HOUR 4 1 NPHI MWD060 PU-S 4 1 FCNT MWD060 CNTS 4 1 NCNT MWD060 CNTS 4 1 RHOB MWD060 G/CM 4 1 DRHO MWD060 G/CM 4 1 PEF MWD060 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Service Unit Min Max DEPT FT 10151 10845 ROP MWD060 FT/H 1.31 285.47 GR MWD060 API 32.9 286.62 RPX MWD060 OHMM 0.83 1636.48 RPS MWD060 OHMM 1.5 2000 RPM MWD060 OHMM 0.86 2000 RPD MWD060 OHMM 1.77 2000 FET MWD060 HOUR 0.64 147.74 NPHI MWD060 ?U-S 23.39 75.64 FCNT MWD060 CNTS 76.05 677.31 NCNT MWD060 CNTS 12084.2 30714.2 RHOB MWD060 G/CM 1.88 3.22 DRHO MWD060 G/CM -0.15 0.43 PEF MWD060 BARN 4.18 19.98 First Reading For Entire File .......... 10151 Last Reading For Entire File ........... 10845 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Mean 10498 50 7367 99 5966 10 5163 11 9104 62 7005 85 1121 13 9304 38 6134 278.974 20450.5 2.48811 0.0927002 8.68081 First Last Nsam Reading Reading 1389 10151 10845 1197 10247 10845 1197 10198.5 10796.5 1226 10191 10803.5 1226 10191 10803.5 1226 10191 10803.5 1226 10191 10803.5 1226 10191 10803.5 1194 10151.5 10748 1195 10151 10748 1194 10152 10748.5 1073 10227.5 10763.5 1074 10227 10763.5 1197 10165.5 10763.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/10/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/10/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Coraments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File