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Home My WebLink About196-186STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS "`L::'_sEZI4aP=L-,) cEB 19 2m' 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Reenter Susp Well ❑ Other: CO261B Whipstock ❑� 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number. Development p Strafigraphic❑ Exploratory ❑ Service ❑ 196-186 3. Address: P. 0. Box 100360, Anchorage, 6. API Number Alaska 99510 50-103-20204-01-00 7. Property Designation (Lease Number): 8. Well Name and Number. ADL 25531 KRU 3H -23A 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 9,875 feet Plugs measured None feet true vertical 6,114 feet Junk measured None feel Effective Depth measured 9,875 feet Packer measured 7,475 feet true vertical 6,114 feet true vertical 4,958 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 " 121' MD 121' TVD SURFACE 4,175 feet 9 5/8 " 4,216' MD 3186' TVD PRODUCTION 9,305 feet 7 " 9,341' MD 6197' TVD LINER 2,400 feet 41/2 " 9,875' MD 5988' TVD Perforation depth: Measured depth: 9550-9600 feet True vertical depth: 5973-5994 feet Tubing (size, grace, measured and true vertical depth) 3.5" J-55 7,507' MD 4,980' TVD Packers and SSSV (type, measured and true vertical depth) PACKER -BAKER C-2 ZXP Liner Top 7,475' MD 4,958' 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: SHT-IN U Subsequent to operation: SHUT-IN 14. Attachments (niquired per 20 AAC 25.070, 25.071, &25,283) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El 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: 318554 Authorized Name: Contact Name: Ryan McLaughlin James Ohlin er contact Email: ryan.mclaughlin@cop.com Authorized Title: Staff CTD Engineer Authorizetl Signature: Date: Q l'q`� Contact Phone: (907) 265-6216 Form 10.404 Revised 4/2017 ✓ / Z .2/2011? Submit Original Only ,041zeABDMSFEB 2 0 2019 KUP PROD WELLNAME 31-1-23A WELLBORE COrWC►� Well Attributes Max Angle & MD OPAjas;w 3H-23 TO AWska. Inc. 1.eBName mlhteAPIMM WdIWre3ums dfl MD KBI KUPARUK RAER UNIT 501032020400 PROD 5834 3,819.29 MDIm(tl BI J,635:0 Gommenl N25(ppm) pate L'awlo, Entl Oale MGM SSSV NIPPLE 140 10/22/2016 Last W0: 31.09 Rlg Release pa4 220/1994 3K -a. slum's Is n so PM Last Tag wnira vnemnr faaWan Mnolanon peptx nlKRl Ene Oa'e WenMreLast Moo By teal Tag: 3H-23 iennaB Last Rev Reason Mnoulm End Dale WdIM,e WI MM ey HANGER 27.0 REVREASON'. CORRECT GLVTABLE(WeIViewlSsue), TAG&H25 I I'A.,tRt .,annan Casing Strings CCND Desnlplion oDllnl Ip On) Top IXKBI Sel OepIM1 IXKBI Bel Dep'M1 . WbLan (L..GMe CONDUCTOR 16 15.06 42.0 121.0 121.0 6258 N-00 TOp TMue WELDED Casbp Oesnipticn ODjin) 0fln) Top MKBI Se'peplM1 lkKBI 9N Deplh (Npj,.. VhM1en 11... GraN SURFACE 9518 8.92 41.3 4216.3 3,185.] 36.00 J-55 Top iM1reeO BTC Caslnp OesnlWan Opllnl ID6nl Top IkKB) Sel peplM1 (DKD) $et OegM1 (NDL_ WIM1en (l.. Gratle PRODUCTION ] 6.28 36.3 9,341.0 6,19>3 26.00 L -BO TOp TM1rOod BTGMOD Tubing Strings Tubing Desmlpa- So MI 112D11nI Top(XKBI Set DeplM1 (II.. SeI DepIM1 jNU11... W1(IGMj G�BBp TUBING 3112 2.99 2].0 ].506.6 4,9]96 980 JSS TOp Gannttlbn EVE SRO Completion Details CONWCTOR:420-1210 Top T'.) IDp Incl Top(GNB) (k K6)°I I'em Des Nominal ID (in V. 27.0 0.14 HANGER WKM GEN VI TUBINGNANGERGan 3500 MPFLE: Sn24 507.4 507.3 1.11 NIPPLE AMCO DSNIPPLE 2812 7,4724 4,960.5 56.30 NIPPLE AM OO NIPPLE NO GO (MILLED OUTT 2.80'j 1-8-2019 -ASSY 2800 ],4]9.5 4,9645 56.26TEAL BAKER GBH- 22 LOCATOR SEAL ASSEM Y; ALSOO 4' 3000 GAS GET;$M3.9 ,R 10• STROKE. STABBED INTO LINER TIEBACK Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) ToIRE) Top Incl Top (M1KB) (ryKB) fl GOs Com Run Date (Olin) 4,988A 3,614.4 ] Fish front 1, " Go. over shot 2w ere lost& on"'2/L201 0.000 1 lGrapple 1 was At..Hed in pM ratchet. Lost oappel could Ee on W"2 or k8 B%h. Mandrel Inserts Tr mi N TOPRKRI T-p(1R) (SKBI Maxe MWel on(1n) a- calve ryce Uan Pmsa TVPo On) TRO Rnn (pail Run Dale COm suePACE', als�,vaa- 1 .13.9 2.6438 MERIA TMPD 1 GAS LIFT GLV BK MERLA TMPD 1 GASLIFT GLV BK 1198] ed Fat, 4996.0 FN3 6,299.3 4,326. M RI.A TMPD 1 AS LIFT GLV K Z214192g988036144 D99] SDipP GASLE-L,ma MFM 4 ),427.3 4,935.6 CAMCO MMM 112 GAS LIFT OV RK 019 Notes: General & Safety GAS LIFT. S.M3 Ene Da'e Annolarnn 1/1512019 N(1TE'. View Schemmit, cal Alaska5 amatic 10. GAS LET. 7.4P3 NIRPLE:],4]24 SEFLAs3Y:T,4T9.e RiOIXICTp N, Y.36.341.n LINER. J,1>S4A,BT50� KUP PROD WELLNAME 3H -23A CO DAP' fillips ell Attributes pkld Name wake R ugnrxt w 2� Alaska.Im. �uf mnafwenmpANr ems, L...F WELLBORE 3H-23AL1 JN.z9u1. v1srz91912 11m FN Last Tag sl.aa neun994 vmlwlsmemeli[(xluall _ Mnofation Lest Tag: Casing Strings oepin (nKeI Ene Oaf, I- Leat M. D, i9NRau HANGEAL1 R. zv.9 eezinOOssmlanon OD (I SLOTTED LINER 2310 m11N rop lnNa) s,mepth(nK9) set Depth lTw)... 1.99 9,516.6 12.466.0 6,018.3 Wellen (I Grad, 4.fi0 L-00 rep Thread STL Liner Details Top(NKOI Top (TVOI(nKRi TaOlecl rl Ihm Oea NOminal 10 (im 5, 9.1 fi4.44 SLEEVEE VE NT SLEEVE 1.000 Notes: General & Safety End Dareamolata� 01151201 N TE'View chemafi<w/AIaSNeSUemati<10.0 CONO=TOR; U0.121.0 .G'.;.14 GAS UFT; J,E1J.9 SURFACE: FM; 4,96LO OAS LIFT. I A9.0 .UFT43f9.3 OAS UWI 74Zl.3 NIPPLE; 7.4Ra SEAL ASSY; Z4M5 P0.000LTgN; J4.19.3J1.0 CTO Z W Lwr 9,51&6 WERE,. Esee LINER; 7. S B750 K15LOTTED LINER; 9,51&6 z.+59p Operations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTime End Time Our (hQ Phase Op Code Ad" Code Time P -T-% Operation Start Depth (%KB) End Depth(ftKB) 1/10/2019 1/10/2019 3.00 MIRU MOVE RURD P Continue RD checklist, secure stack, 0.0 0.0 02:00 05:00 chain off reel, empty all pits, continue trucking items/product to 3H -Pad, disconnect majority of PUTZ 1/10/2019 1/10/2019 3.00 MIRU MOVE RURD P Compete RD checklist, breakdown TT 0.0 0.0 05:00 08:00 hard-line, secure stairs & landing, disconnect PUTZ 1/10/2019 1/10/2019 -1 50 MIRU MOVE RURD P7- Peak trucks arrive, load up shop & half 0.0 0.0 08:00 09:30 -way house 1/10/2019 1/10/2019 2.50 MIRU MOVE RURD P Pull sub & pits off well, jeep up, secure 0.0 0.0 09:30 1200 well 1/10/2019 1/10/2019 7.00 MIRU MOVE MOB P Move to 3H -Pad (stopped at KOC for 0.0 0.0 12:00 19:00 Boeing flight) 1/10/2019 1/10/2019 3.70 MIRU MOVE MOB P Arrive on 3H -Pad 19:00 hrs, drop off _0 0 0.0 19:00 2242 jeeps, sub &pits spotted, mats laid _1_/l (-50 min to lay mats for sub & pits) 01201-9 1/11/2019 1.30 MIRU WHDBOP NUND P NU BOP 0.0 0.0 22:42 00:00 Rig Accept 1/10/19 @ 2400 hrs 1/11/2019 1/11/2019 2.50 MIRU WHDBOP KURD P Continue RU checklist, spot tiger -tank, 0.0 0.0 00:00 02:30 hook up PUTZ, blowdown steam, drop stairs & landings, spot shop & half- wayhouse 1/11/2019 1/11/2019 2.00 MIRU WHDBOP RURD P Complete RU checklist, energize 0.0 0.0 02:30 04:30 Koomey, unlock injector & reel, begin MU tiger -tank hard-line, grease tree & tangos, grease Romeo & Bravo valves 019 1/11/2019 2.50 MIRU WHDBOP PRTS P PJSM , fluid pack lines, perform shell 0.0 0.0 04:30 04:30 07:00 test 1/11/2019 1/11/2019 6.20 MIRU WHDBOP BOPE P Begin BOPE test (witness waived by 0.0 0.0 07:00 13:12 Matt Herrera ofAOGCC) **_250 psi low 114800 psi high 1/11/2019 1/11/2019 1.30 MIRU WHDBOP PRTS P PT PDL's and TT line, Blow down, 0.0 0.0 13.12 1430 raise mast 1/11/2019 1/11/2019 2.80 SLOT WELLPR CTOP P Skid injector to floor, Remove UQC. 0.0 0.0 14:30 17:18 Cut CT connector, cut 17' of pipe, re - head, pull test to 40K, re -head eline & test 1/11/2019 1/11/2019 2.00 SLOT WELLPR CTOP P MU panel to adjacent wells, pre -load 0.0 0.0 17.18 19:18 PDL, bleed down IA for -45 min (down to 910 psi, plan to continue bleeding after setting WS) 1/11/2019 1/11/2019 1.00 PROD? WHPST PULD P PJSM, PD BHA #1 WS Assembly 0.0 74.0 19:18 20:18 Difficulty opening master valve, open swab one, attempt to open master again, no good, open swab 2, pressure up on master from above (1000 psi), open master (870 psi below master) 1/11/2019 1/11/2019 1.00 PROD1 WHPST PULD T Attempt to bleed off PDL, unable, FVS 74.0 0.0 20'18 21:18 not MU in tool striing, equalize PDL, open rams,suck tools into PDL, shut swab 2, install FVS 1/11/2019 1/11/2019 0.80 FROD1 TRIP P PD BHA #1 slide in cart, check pack- 0.0 74.0 21:18 22:06 offs, MU to coil, tag up, set counters 1/11/2019 1/12/2019 1.90 PROD1 WHPST TRIP P RIH wit BHA #1 74.0 8,955.0 22:06 00:00 019 019 0.10 PROD1 WHPST TRIP P Continue RN w/ BHA #1 8,955.0 9,355.0 00:00 00:00 00:06 oa:os 1/12/2019 1/12/2019 0.20 PROD1 WHPST DLOG P Log K1 for -7' correction 9,355.0 9,403.0 00:06 00:18 Page 1/9 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Time End Time Dur (hQ Phase Op Code Aclrviy Code Time P -T -X Operation Start Depth (ItKa) EnO Depm (11<1) 2/2 1/12/2019 1/12/2019 0.20 PROD1 WHPST TRIP P PUW = 40K, PUH to HRZ 9,403.0 8,990.0 00:18 00:30 1/12/2019 1/12/2019 0.80 PROD' WHPST DLOG P Log CCL from HRZ down to 9446', set 8,990.0 9,446.0 00:30 01:18 down 5K CWT at 9446', PUW = 39K, RBIH, again stack 5K CWT @ 9446', PUW = 40K, decision made to POOH & PU cleanout assembly 019 1/12/2019 1.70 PROD1 WHPST TRIP T POOH, tag up, PJSM 9,446.0 74.0 01:18 01:18 03:00 1/12/2019 1/12/2019 1.50 PROD1 WHPST PULD T PUD BHA#1, checks failed, close 74.0 0.0 03:00 04:30 EDC, begin PUD w/ failed checks " whipstock shear pin came out with sheared fork retaining pin. HOT SHOT whip -stock to BOT for redress and return to CDR3 1/12/2019 1/12/2019 2.00 PROD1 WHPST PULD T PD BHA#2 FCOAssembly, slide in 0.0 62.0 04:30 06:30 cart, check pack -offs, MU to coil, tag up, set counters 1/12/2019 1/12/2019 1.70 PROD1WHPST TRIP T RIHw/BHA#2&clean-outto WS 62.0 9,340.0 06:30 0812 setting depth 1/12/2019 1/12/2019 0.30 PROD1 WHPST DLOG T Log K1 for -5.5. PUW=33K 9,340.0 9,361.0 08:12 08:30 1/12/2019 1/12/2019 0.80 PROD1 WHPST TRIP T Continue in well, Mud at bit 9434'. see 9,361.0 9,622.0 08:30 09:18 slacking with slight motor work 9575. PUH then go right through to 9588. PUH. RBIH to 9622' 1/12/2019 1/12/2019 0.60 FROM WHPST TRIP T 9622, PUH to run CCL pass, 1.9 BPM 9,622.0 8,987.0 09:18 09:54 @ 3641 PSI FS, BHP=3367 1/12/2019 1/12/2019 1.00 PROD1 WHPST DLOG T 8987', Run CCL to 9620. Bad data 8,987.0 9,620.0 09:54 1054 from 9500' down. PUH and relog 1/12/2019 1/12/2019 2.30 PROD1 WHPST TRIP T 9620', Trip out, 1.82 BPM EDC closed. 9,620.0 44.0 10:54 13:12 At 1620' hale started unloading frac sand. Slowed pull speed. Performed jag from 500' back to 900'. PUH to 150 feet and jog back into 500'. Shaker cleared up. Open EDC tag up and space out 1/12/2019 1/12/2019 2.20 PROM WHPST POLO T PJSM, PUD BHA #2 difficulty with DS 44.0 0.0 13.12 1524 PDL (frozen up), switch to ODS PDL& carry on 1/12/2019 1/12/2019 1.60 PROD1 WHPST PULD T PD BHA#3 WS Assembly, slide in 0.0 75.0 15:24 17:00 cart, MU to coil, tag up, set counters 1/12/2019 1/12/2019 1.70 PROD1HA#3 WHPST TRIP T RIHw/B 75.0 9,365.0 17:00 1842 1/12/2019 1/12/2019 0.30 FROM WHPST OG P Log K1 for -7' 9,365.0 9,417.0 18:42 19:00 1/12/2019 1/12/2019 0.20 PROM WHPST TRIP P Continue RIH, PUW =37K from 9,417.0 9,558.0 19:00 19:12 9500', arrive at set depth, shut down pumps, close EDC, bring on pumps, shear @ 3500 psi, WS set, set down 5.51K, good, PUW = 36K 1/12/2019 1/12/2019 1.80 PROD1 WHPST TRIP P POOH w/ BHA #3, open EDC, PJSM 9,558.0 63.0 19:12 21:00 1/12/2019 1/12/2019 1.00 PROD1 WHPST P Begn PUD BHA#3, pull test SL, 63.0 0.0 21:00 2:00 22:00 parted ODS SL 1/12/2019 1/12/2019 1.00 PROM WHPST PULD P Work to free froze -up SL on DS PDL, 0.0 0.0 2200 2300 unable to free with significant effort 1/12/2019 1/1312019 1.00 PROD? WHPST PULD T Drop lower section of ODS PDL, wire 0.0 0.0 23:00 00:00 - 15' up in next section, begin to break off second section Page 219 Report Printed: 211912019 Operations Summary (with Timelog Depths) 3H-23 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 (ftKB) End Depth(fIKB) 1/13/2019 1/13/2019 2.50 RF WHPST PULD T Continue breaking down ODS PLD, 0.0 0 00:00 02:30 find SL, threads on upper swivel are .0 stripped, re -head SL, reassemble PDL 1/13/2019 1/13/2019 0.90 PROD1 WHPST PULD P PJSM to re -group, complete PUD BHA 0.0 0.0 02:30 0324 #3 1/13/2019 1/13/2019 1.40 PROD1 WHPST PULD P PD BHA #4 Window Milling Assembly 0.0 75.0 03:24 0448 (0.6° AKO motor, 2.80" string reamer, & 2.80" window mill), slide in cart, check pack -offs, MU to coil, tag up, set counters 1/1312019 1/13/2019 1.80 PROD1 WHPST TRIP P7_ RIH w/ BHA#4 75.0 9,365.0 04:48 06:36 1/13/2019 1/13/2019 0.20 PR051 WHPST 15 -LO -G- P 9365 Log K7 for -7', PUW=35K, Close 9,365.0 9,387.0 06:36 06:48 EDC 1/13/2019 1/13/2019 0.40 PROD1 WHPST TRIP P Continue in, Drytag pinch point @ 9,387.0 9,561.0 06:48 0712 9560, PUH bring pumps online at 1.87 BPM @ 3687 PSI FS, BHP=3308. Call pinch point @ 9561 1/13/2019 1/13/2019 5.20 PROD1 WHPST MILL P Pumping pinch point 9561. Mill 9,561.0 9,567.0 07.12 1224 window per BOP rep. Call mill exit @ 9567.7 1/13/2019 1/13/2019 1.90 PROD? WHPST MILL P 9567.7, Time mill 2.3 feet past -mill 9,567.0 9,570.0 1224 14:18 for string reamer to work 1/13/2019 1/13/2019 1.o0 PROD1 WHPST MILL P 9570', Drill rathole down to 9583 9,570.0 9,583.0 14:18 15:18 1/13/2019 1/13/2019 2.40 PROD1 WHPST REAM _EA Start reaming passes. As drilled, 30L, 9,583.0 9,583.0 15:18 17:42 30R and 180° out of as drilled, dry drift, clean, tag bottom of rat -hole 1/13/2019 1/13/2019 2.20 PROD1 WHPST TRIP P POOH, continue rebuilding DS PDL, 9,583.0 74.0 17.42 1954 PJSM, open EDC 1/13/2019 1/13/2019 1.60 PROD? WHPST PULD P PUD BHA #4, string reamer _& mill 74.0 0.0 19:54 21:30 came out 2.80" no-go 1/13/2019 1/13/2019 1.50 PROD?DRILL PULD P PD BHA#5 Build/Turn Assembly (2.2° 0.0 72.0 21:30 2300 AKO motor & RB Hughes bit), slide in cart, check pack -offs, good, Mu to coil, tag up, set counters 1/13/2019 1/14/2019 1.00 PROD1 DRILL TRIP P Begin RIH w/ BHA#5 72.0 4,600.0 23:00 0000 1/14/2019 1/14/2019 0.80 PROM DRILL TRIP P Begin RIH w/BHA #5 4,600.0 9,355.0 00:00 0048 1/14/2019 1/14/2019 0.30 PR0D1 DRILL DLOG P Log K1 for -7.5' correction, PUW = 9,355.0 9,412.0 00:48 01:06 36K 1/14/2019 1114/2019 0.20 PROD1 DRILL TRIP P Continue RIH, resume reassembling 9,412.0 9,583.0 01:06 01:18 DS PDL 1/14/2019 1/14/2019 0.40 PROD1 DRILL DRLG P Drilling, FS = 470 psi @ 1.9 bpm, 9,583.0 9,622.0 01:18 01:42 CWT =14K, WOB=1K, WHP=313 psi, circ = 4300 psi, dp = 726 psi BHP = 3333 psi (rate out = 1.75 bpm, 10.7 ppg) BHP = 3449 psi (rate out = 1.44 bpm, 11.2 ppg) BHP = 3557 psi (rate out = 1.41 bpm, 11.4 ppg) PU to grab to new numbers, PUW = 35K Page 319 ReportPrinted: 2119/2019 r, Operations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stag Time End Time Dur (hr) Phase Op Code Activity ivity Code Time P -T -X Operation Depth (ftKB) End Di (ii 1/14/2019 1/14/2019 1.80 PROD1 DRILL DRLG P Drilling, FS = 467 psi @ 1.9 bpm, 9,622.0 9,864.0 01:42 03:30 CWT = 12.9K, WOB = 1.3K, annular = 3565 psi, WHIP = 275 psi, circ = 4186 psi, dp = 652 psi, rate out = 1.55 bpm (increasing), continue to increae ECD at window No resistivity until 9682', MWD made adjustments & resolved issue 1/14/2019 1/14/2019 1.10 PROD1 DRILL DRLG P Drilling, 1.9 bpm in, 1.76 bpm out, 9,864.0 9,960.0 03:30 0436 CWT = 11.6K, WOB = 2.2K„ annular = 3697 psi, WHP = 333 psi, circ = 4181 psi, PUW = 34K from 9867 psi, drill to called EOB at 9960' Baker screen freezing -up, PU to reboot 1/14/2019 1/14/2019 2.20 PROD1 DRILL TRIP P Call EOB, POOH, PUW = 35K, open 9,960.0 66.0 04:36 06:48 EDC, AVG DLS 34.9° for build secion 1/14/2019 1/14/2019 1.00 PROD' DRILL PULD P Tag up and space out, PUD BHA #5 66.0 0.0 06:48 07:48 1/14/2019 1/14/2019 0.20 PROD1 DRILL PULD P P/U Bit, Motor, agitator, and FVS. 0.0 0.0 07:48 08:00 Make up to toolstring and scribe 1/14/2019 1/14/2019 0.80 PROD1 DRILL PULD P PD BHA#6, Lateral dilling BHA 0.0 78.0 08:00 0848 with .5° AKO motor, new HCC P104 bi center, and agitator, make up to coil and surface test. 1/14/2019 1/14/2019 1.50 PROD1 DRILL TRIP P RIH BHA#6, Test agitator@596', 78.0 9,360.0 08:48 1018 Continue in hole. 1/14/2019 1/14/2019 0.10 PROD1 DRILL DLOG P 9360 Tie into K1 for -7.5', PUW=35K 9,360.0 9,385.0 10:18 1024 1/14/2019 1/14/2019 0.20 13ROD1 DRILL TRIP P Continue in well 9,385.0 9,585.0 10:24 10:36 1/14/2019 1/14/2019 0.20 PROD1 DRILL DLOG P Log the RA@9565.5', 9,585.0 9,616.0 10:36 10:48 TOWS=9557.15 1/14/2019 1/14/2019 1.20 PROD1 DRILL TRIP P Continue in well, Tag up @ 9960' and 9.616.0 10,064.0 10:48 1200 drill. 1.87 BPM @ 4984 PSI FS, BHP=3764, Start new mud down coil 1/14/2019 1/14/2019 2.40 PROD1 DRILL DRLG P New mud all around, PIU to get new 10,064.0 10,247.0 12:00 1424 drilling parameters, 1.88 BPM @ 4892 PSI FS, BHP=3706, Holdinf 11.8PPG at window 1/14/2019 1/14/2019 0.10 PR0D1 DRILL WPRT P Pull BHA wiper, PUW=45K 10,247.0 10,247.0 14:24 14:30 1/14/2019 1/14/2019 1.10 PROD' DRILL DRLG P 10247', Drill, 1.86 BPM @ 4656 PSI 10,247.0 10,294.0 14:30 1536 FS, BHP=3800PSI, RIW=5.9K, DHWOB=2.1K 1/14/2019 1/14/2019 0.30 PROD? DRILL WPRT P Wiper to 9900', PUW=39K 10.294.0 10,294.0 15:36 15:54 1/14/2019 1/14/2019 1.90 PROD1 DRILL DRLG P 10294', Drill 1.88 BPM @ 4605 PSI 10,294.0 10,400.0 15:54 17:48 FS, BHP=3749 1/14/2019 1/14/2019 0.60 PROD? DRILL WPRT P 10400', Wiper to 9600', PUW=38K 10,400.0 10,400.0 17:48 18:24 1/14/2019 1/14/2019 4.30 PROD? DRILL DRLG P 10400', Drill, 1.9 BPM @ 4707 PSI 10,400.0 10,780.0 18:24 2242 FS, BHP=3719, RIW=9.8K, DHWOB=I.SK /2019 1/14/2019 0.70 PROD1 DRILL WPRT P Wiperto 10,000' with sweeps, PUW- 10,780.0 10,780.0 2 2324 40K /2019 [23:24 1/15/2019 0.60 PROD1 DRILL CIRC P Lost i generator, PUH & circluate 10.780.0 10,780.0 0000 bottoms up, get gen back on-line, RBIH Page 4/9 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stasi Time End Time Dur(hr) Phase Op Code Aarvity Code Time P-T-x Oparalion Stan Depth (ftKB) End DepM dtKB) 1/15/2019 1/15/2019 O 1.00 PROD1 DRILL DRLG P Drilling, CWT = 7K, WOB = 1K, 10,780.0 10,830.0 00:00 01:00 annular= 3780, WHIP = 237 psi, circ = 4785 1/15/2019 1/15/2019 2.90 PROD1 DRILL DRLG P Drilling, CWT =6K, WOB=1.6K, 10,830.0 10,983.0 01:00 0354 annular= 3773 psi, WHP = 221 psi, circ = 4819 psi, PU's as required to maintain weight transfer, PUW = 45K, pump 5 x5 sweeps 1/15/2019 1/15/2019 0.30 PROD1 DRILL -5—RI G P Drilling, diffcutly w/ weight transfer, 10,983.0 10,983.0 03:54 04:12 many PUS, annular = 3766 psi, WHP = 255 psi, circ = 4773 psi, continue to have propant over shaker(-20% - 30% over lateral) " Phase 3 called @–3:50AM, allow sweeps to exit bit, then pull into cased hole 1/15/2019 1/15/2019 0.50 PROD1 DRILL TRIP T Pull into cased hole, PUW = 38K 10,983.0 9,515.0 04:12 04:42 1/15/2019 1/15/2019 6.70 PROD1 DRILL CIRC T Slowly pull up to top of 4.5", 9,515.0 9,515.0 04:42 11:24 circulating, waiting on weather (Phase 3), log K1 for... 1/15/2019 1/15/2019 0.10 PROD1 DRILL CIRC T Open EDC, pump at 2.5 bpm for 4 min 9,515.0 9,515.0 11:24 11:30 (test for (1J-10 liner release) Circ = 4805 psi, bore = 3582 psi, annular = 3539 psi, dp = 50 psi Close EDC 1/15/2019 1/15/2019 6.50 PROM DRILL CIRC T Continue circulating at 0.5 bpm 9,515.0 7,691.0 11:30 1800 1/15/2019 1/15/2019 0.50 PROD1 DRILL CIRC T Phase 2 called, crew change, PJSM in 7,691.0 9,341.0 18:00 1830 dog house 119 1/15/2019 0.20 PROD? DRILL DLOG T RIH, tie in for+3.5' correction. 9,341.0 9,389.0 18:308:30 1842 1/15/2019 1/15/2019 0.50 PROD? DRILL TRIP T RIH, window and build clean. 9,389.0 10,983.0 18:42 1912 1/15/2019 1/15/2019 2.90 PROD1 DRILL DRLG P CT 4638 psi, @ 1.83 bpm in 1.80 bpm 10,984.0 11,209.0 19:12 2206 out, BHP 3799 psi - 11.8 ppg EMW @ the window, Delta P 1040 psi, WH 200 psi, IA 946 psi, OA 87 psi. RIH Wt 1.5 k lbs OBD, CT 10.8 k lbs, WOB 1.5 k Ibs. ROP 77 ft/hr 11,051' PU Wt 38 lbs 11,090' PU Wt 38 k lbs 11,115' PU Wt 40 k lbs -5x5 sweep 11,185' PU W140 k lbs 11,193' PU Wt 43k lbs 2019 1/15/2019 0.20 PROD? DRILL WPRT P PU, 43k Ibs -500' wiper, pulled early 11,209.0 10,711.0 E22: 22:18 #1 only 200' drilled 2019 1/15/2019 0.20 PROD? DRILL WPRT P RBIH, RIM Wt 9.5 k IDS 10,711.0 11.209.0 22:30 Page 519 Report Printed: 2/1912019 . Operations Summary (with Timelog Depths) Til 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time our (hr) Phase Op Code Ac Activity Code Time P -T-% Operaaon Stan Depth (ftK8) End Depth (M<13) 1/15/2019 1/15/2019 0.40 PROD1 DRILL DRLG P CT 4681 psi, @ 1.80 bpm in 1.82 bpm 11,209.0 11,238.0 22:30 22:54 out, BHP 3786 psi - 11.8 ppg EMW @ the window, Delta P 1102 psi, WH 220 psi, IA 953 psi, OA 137 psi. RIH Wt 9.5 k lbs OBD, CT 8 k lbs, WOB 1.3 k lbs, ROP 72 ft/hr 11,233' PU Wt 42 Ins, Having trouble drilling, added' 2ppb alpine drill beads to high vis pill, pumped 10 bbls 1/15/2019 1/15/2019 0.10 PR0D1 DRILL WPRT P PU WT 42 k lbs, 100' having a hard 11,238.0 11,238.0 22:54 23:00 time drilling, bypass screens, Add - 2 ppb alpine drill beads to high vis pill pit, RBIH 1/15/2019 1/16/2019 1.00 PROD? DRILL DRLG P CT 5040 psi, @ 1.90 bpm in 1.90 bpm 11,238.0 11,277.0 23:00 00:00 out, BHP 3807 psi - 11.8 ppg EMW @ the window, Delta P 1207 psi, WH 201 psi, IA 955 psi, OA 146 psi. OBD, CT 4 k lbs, WOB 0.7 k lbs, ROP 60 ft/hr 11,256' PU Wt 39 k Ibs - pumped 10 bbl beaded pill, regained CT wt 5-6 k lbs, and able to drill aheadw 1.3 k WOB, gamma dropped at the same time. Continue to drill ahead, sending - 10 bbl beaded pill every - 100 bbls. 1/16/2019 1/16/2019 4.00 PRODi DRILL DRLG 15 CT 4796 psi, @ 1.95 bpm in 1.95 bpm 11,277.0 11,599.0 00:00 04:00 out, BHP 3877 psi - 11.8 ppg EMW @ the window, Delta P 1049 psi, WH 186 psi, IA 963 psi, OA 182 psi. OBD, CT 2 - (-7) k Ibs, WOB 0.2 - 1.3 k lbs, ROP 60 ft/hr Struggling with weight transfer, beads seem to be working some but are short lived. Weight transfer with beads in he 4.5" lose weigh transfer and ROP as soon as beads are out of the 4.5". 1/16/2019 1/16/2019 0.30 PROD1 DRILL WPRT P TU, 41 klbs ,-800'wiper#2 11,599.0 10,800.0 04:00 04:18 1/16/2019 1/16/2019 0.20 PR0D1 DRILL WPRT P RBIH 10,800.0 11,590.0 04:18 04:30 1/16/2019 1/16/2019 0.50 PROD1 DRILL WPRT T Issue with orientor, amping up turning 11,590.0 11,5900 04:30 05:00 either direction with no signs of rotating or rotating very slowly. Troubeshoot. 1116/2079 1/16/2019 2.80 PROD1 DRILL TRIP T POOH for new tools, open EDC, tag 11,590.0 78.0 05:00 07:48 up, PJSM 1/1612079 1/16/2019 1.20 TR-ODI TUPULD T PUD BHA#6, checks failed, close 78.0 0.0 07:48 09:00 EDC, switch to PUD w/ failed checks, bit came out a 1-1 1/16/2019 f111/2019 1.30 PROM DRILL BHA #7otor, RB 0.0 78.0 09:00 8 T7]��C heck pack - counters Page 6/9 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stag Time End Time Our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (flKB) End Depth(ftKB) 1/16/2019 1/16/2019 1.80 PROD1 DRILL TRIP T RIH w/ BHA#7 78.0 9,360.0 10:18 1206 Shallow test agitator: depth = 537', 1.9 bpm, circ = 5150 psi, dip = 1250 psi 1/16/2019 1/16/2019 0.10 PROD? DRILL DLOG T Log K1 for -7.5' correction, PUW = 9,360.0 9,395.0 12:06 12:12 35K 1/16/2019 119 0.70 PROD1 DRILL TRIP T Continue RIH, RIW = 11K 9,395.0 11,599.0 12:12 12:542:54 1/16/2019 1/16/2019 1.60 PROD1 DRILL DRLG P Drilling, FS = 1147 psi @ 1.9 bpm, 11,599.0 11,699.0 12:54 14:30 CWT = 7K, WOB = 1.2K, annular = 3837 psi, WHP = 174 psi, circ = 4862 psi, PUW = 40K, struggling w/ weight transfer, pump 10 bbl beaded pill, avg ROP = 63 fph New mud at bit at 11,600' (PowerPro System #2) 1/16/2019 1/16/2019 0.20 PR0D1 DRILL WPRT P 200'wiper, PUW=41K 11,699.0 11,699.0 14:30 1442 1/16/2019 1/16/2019 1.60 PROD1 DRILL DRLG P Drilling, CWT=2K,WOB=.9K, 11,699.0 11,756.0 14:42 1618 annular = 3854 psi, WHP = 298 psi, circ = 4916 psi, PUW = 45K from 11,723', difficulty getting weight to bit, pump 10 bbl beaded pill, PU's to stay drilling, avg ROP = 37 fph begin building 50 bbl 2%/2% lube pill 1/16/2019 1/16/2019 3.20 PROD DRILL DRLG P Drilling, CWT =6K, WOB =,8K, 11,756.0 11,938.0 16:18 19:30 annular = 3895 psi, WHP = 288 psi, circ = 4749 psi ROP 57 ft/hr 1/16/2019 1/16/2019 0.30 PROD1 DRILL WPRT P PU Wt37 k bs, Wiper trip #1 - 800' 11,938.0 11,107.0 19:30 19:48 1/16/2019 1/16/2019 0.30 PROD1 DRILL WPRT P RBIH 11,107.0 11,938.0 19:48 20:06 1/16/2019 1/16/2019 2.60 PROM DRILL DRLG P CT 5113 psi @ 1.91 bpm iF-,1 91 bpm 11,756.0 12,115.0 20:06 2242 out, BHP 3876 psi - 11.8 ppg EMW @ the window, Delta P 1199 psi Drilling, CWT = -6 to 1 k Ibs, WOB = 1.83 k, ROP, WH 283 psi, IA 962 psi, OA 187 psi 1/16/2019 1/17/2019 1.30 PROD1 DRILL DRLG P Started rotating the HOT whiledrilling 12,115.0 12,152.0 22:42 00:00 ahead in experimental drilling for lower doglegs. CT 5113 psi @ 1.91 bpm in, 1.91 bpm out, BHP 3876 psi - 11.8 ppg EMW @ the window, Delta P 1199 psi Drilling, CWT = -6 to 1 k Ibs, WOB = 1.83 k, ROP, WH 283 psi, IA 962 psi, OA 187 psi 1/17/2019 1/17/2019 3.40 PROD? DRILL DRLG P Continue to continuously rotate the 12,152.0 12,340.0 00:00 0324 HOT while drilling ahead in experiment, drilling for lower dog legs. CT 5188 psi @ 1.92 bpm in, 1.90 bpm out, BHP 3876 psi - 11.8 ppg EMW @ the window, Delta P 1199 psi. Drilling, CWT = -6 to 1 k lbs, WOB = 1.83 k, ROP = 55 ft/hr, WH 283 psi, IA 962 psi, OA 187 psi - 5 surveys with an average dog leg of 2.9° - previously had been averaging 7.5 ° 1/17/2019 1/17/2019 0.20 PROD? DRILL P PU Wt 39 k lbs on wiper#2- 800' 12,340.0 11,540.0 03:24 03:36 7, 1/17/2019 1/17/2019 0.30 PROM DRILL WPRT P RBIH 11,540.0 12,340.0 03:36 03:54 Page 719 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) %io 3H-23 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EndTimeCur (hr) Phase Op Cotle Activity Code Time P-T-X Operation Stan Depth rKB) Entl Depth(fIKB) 1/17/2019 03:54 1/17/2019 1.10 PROD1 DRILL DRLG P Continue to continuously rotate the 12,340.0 12,401.0 05:00 HOT - Blead IA from 770 to 845 psi CT 5188 psi @ 1.92 bpm in, 1.92 bpm out, BHP 3975 psi - 11.9 ppg EMW @ the window, Delta P 1230 psi Drilling, CWT = 10 k lbs, WOB = 0.9 It, ROP100 ft/hr, WH 155 psi, IA 845 psi, OA 255 psi 1/17/2019 1117/2019 2.40 PROD1 DRILL DRLG P Drilling, consistant dropin inclination 12,401.0 12,462.0 05:00 07:24 while oscillatiing HOT, confer w/ town, decision made to point up to 90' & resume HOT oscillation test, continue pumping 2 ppb beaded pills TD called at 12,462' 1/17/2019 1/17/2019 1.30 PR0D1 DRILL CIRC P PU off bottom, pump away beads, 12,462.0 12,462.0 07:24 0842 build HiVis pill, pump 10X10 TD sweeps, PUW = 35K 1/17/2019 1/17/2019 3.70 PR0D1 DRILL WPRT P Wiper to swab valve,jog 4.5" 12,462.0 78.0 08:42 1224 1/17/2019 1/17/2019 1.80 PR0D1 DRILL WPRT P RBIH 78.0 9,350.0 12:24 1412 1/17/2019 1/17/2019 0.10 PR0D1 DRILL DLOG P Log K7 for-7' correction 9,350.0 9,389.0 14:12 14:18 1/17/2019 1/17/2019 0.10 PROD1 DRILL TRIP P Continue RIH 9,389.0 9,540.0 14:18 14:24 1/17/2019 1/17/2019 0.20 PR0D1 DRILL DLOG P Confirm 11.9 ppg kills well (allow to 9,540.0 9,540.0 14:24 14:36 drop to 11.7 ppg), shutdown pumps, close choke MD = 9539', TVD sensor = 5947', annular = 3613 psi, EMW = 11.7 ppg 'Reboot Orion 1/17/2019 1/17/2019 1.10 5ROD1 DRILL TRIP P Continue RIH, clean through window, 9,540.0 12,466.0 1436 15:42 stack CWT at 12,421', PUW = 37K, confirm TD @ 12,466', PUW = 39K 1/17/2019 1/17/2019 3.00 7ROD1 DRILL DISP P Lay LRP & KWF to surface, pulled 12,466.0 78.0 15:42 18:42 heavy at 12,410', up to 49K CWT & - 4.6K WOB, POOH paintig flags, yellow 9548.26' and white, 6578.30' 1/17/2019 1/17/2019 1.30 PROD1 DRILL PULD P At surface, flow ceck good, losses - 3 78.0 0.0 18:42 20:00 bbl/hr. Unstab injector, check pipe, -0.212" wall thickness with wear and flat spot back 12-15' measured 0.05" question results because of wear pattern on pipe. PUD & LD BHA#7 1/17/2019 1/17/2019 0.40 COMPZN CASING -130-PE P Perform BOP functon test. 0.0 0.0 20:00 20:24 1/17/2019 1/17/2019 0.60 COMPZI CASING PUTS P Prep floor for running liner. PJSM, 0.0 0.0 20:24 21:00 1/17/2019 1/18/2019 3.00 COMPZI CASING PUTB P PU ALl completion, 89 joints 2-3/8" 0.0 0.0 21:00 00:00 STL slotted liner, 1/18/2019 1/18/2019 1.20 COMPZI CASING PUTS P Continue to PU AL1 completion, 89 0.0 2,946.5 00:00 01:12 joints 2-3/8" STL slotted liner, 1/18/2019 1/18/2019 0.20 50MPZ1 CASING PUTB P Clean floor post making up liner. 2,946.5 2,946.5 01:12 01:24 1/18/2019 1/18/2019 0.70 CO=CASINGPULD P PU BHA#8, AL1 linnet running 2,946.5 2,994.9 01:24 0206 assembly, check pack offs, good. Swap out Baker floats, stab injector, bump up set counters. Page 8/9 ReportPrinted: 2/1912019 Operations Summary (with Timelog Depths) Rig: NABORS CDR3-AC 3H-23 Time Log SOU• r mAt, n Start Time 1/18/2019T18/2019 End Time Cur(hr) Phase Op Cotle Activity Cotle Time P -T -X OeraUon Start Depth (nKa) End Depm (rtKe) 02:06 0324 1.30 COMPZI CASING RUNL P RlH with ALl liner 2,994.9 9,492.0 12466' PU Wt 35 k lbs, tie into window flag for -9.8' correction 1/18/2019 03:24 1/18/2019 06:12 2.80 COMPZI CASING RUNL P Continue to RIH 9,492.0 12,217.0 10821' S/D - PU Wt 39 k lbs 11,092' S/D - PU Wt 39 k Ibs 11434' PU 55 k Ibs -10 k WOB 11637' PU 54 k lbs - -14 k WOB Multiple times at 11928' 1/18/2019 06:12 1/18/2019 0.80 COMPZI CASING TU NL P Crew change, continue working liner 12,217.0 12,466.0 07:00 to bottom, begin pumpng down back- side, arrive on bottom, bring up pumps, release off liner, PUW = 37K, BOL = 12,466', TOL = 9518.6' 1/18/2019 07:00 1/18/2019 0.50 COMPZI CASING DLOG P Obtain SBHP (depth change after 12,466.0 9,493.0 0730 dropping off liner to EDP) Depth = 9493, TVD sensor = 5941.9', annular = 3602 psi, EMW = 11.66 ppg (-25 min test) 1/18/2019 1/18/2019 2.40 COMPZI CASING DISP P Open EDC, displace well to seawater 9,493.0 2,500.0 07:30 0954 1/18/2019 09:54 1/18/2019 1.50 COMPZI CASING FRZP P PJSM, diesel freeze protect well from 2,500.0 42.0 11:24 2500'to surface, tag up, PJSM 1/18/2019 1/18/2019 1.10 COMPZI CASING PULD P PUD BHA #8, 1016 psi below master 42.0 11:24 1230 0.0 1/18/2019 1/18/2019 0.70 DEMOB WHDBOP CIRC P MU nozzle, jet stack, break -off noule, 0.0 0.0 12:30 1312 clear floor 1/18/2019 1/18/2019 0.30 DEMOB WHDBOP CTOP P Pull checks 13:12 13:30 0.0 0.0 1/18/2019 1/18/2019 2.30 DEMOB WHDBOP CTOP P Wrap & epoy a -line, stab on, pump 0.0 0.0 13:30 15:48 slack back (3 cycles, up to 5600 psi), break off injector MU hydraulic cutter, cut 119' pipe total, RD cutter 1/18/2019 1/18/2019 2.70 DEMOB WHDBOP CTOP P7_ File & ream pipe, install CTC, pull test 0.0 0.0 15.48 18.30 to 35K, install UQC, re -head a -line 1/18/2019 1/18/2019 3.00 DEMOB WHDBOP CTOPP Pull and replace upper blind shear 0.0 0.0 18:30 21:30 rams - note, did not pressure test, pits de -inventoried. 1/18/2019 1/19/2019 2.50 DEMOB WHDBOP CTOP P Work rig down check list, DTH called 0.0 0.0 21:30 00:00 to R/D hard line and remove TT Handed control of both adjacent producers back to Pad Operator Jeanine, nipple down and secured BOP stack " rig release at midnight - Page 919 Report Printed: 2/19/2019 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE. - .. RESCAN Color items- Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Odginal- Pages: Other - Pages: DIGITAL DATA a Diskettes, No. Other, No/Type 'OVERSIZED .Logs of various kinds Other Complete COMMENI~: Scanned by: B,,~.~, M~r~-D;r~(~ Lowell TO RE-SCAN Notes: Date: /s/ III • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 pFc., March 9, 2012 ''.;,,,,,„;(:w414,:i7;0\1!)4t,, A, Commissioner Dan Seamount A.inol Q:i 2t kla' Cora Corild3ci Alaska Oil & Gas Commission i AiT'Ibr,10T, ! 333 West 7 Avenue, Suite 100 ----____ ____. _______ Anchorage, AK 99501 1 C I 6 - (cB, Commissioner Dan Seamotmt: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement 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 in the fall of 2011. The corrosion inhibitor/sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Since,. , MJ veland ‘ ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc" Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuperuk Field Date 3 -09 -2012 3A,3G,3H,3K PAD Corrosion Initial top of Vol. of Dement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTO # cement Pump cement date inhibitor sealant date ft bbls ft gal 3A-17A 50029226910100 2101130 3'6" NA 13" NA 5.95 2/14/2012 3G-20 50103201410000 1901230 SF NA 24" NA 3.83 2/14/2012 311-17 50103200810000 1870990 19" NA 19" NA 3H-21 50103200940000 1880080 8" NA 15" NA 4.25 2/14/2012 3H --23A 50103202040100 1961880 6" NA 12" NA 8.38 2/14/2012 3K-102 50029233780000 2071650 SF NA 16" NA 6.8 2/14/2012 . ~ s • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 f ~~~~.~ Ju1y 18~ Goo7 .''~'~y~~y~fii~M'~ h~'t}' ~ , Mr. Tom Maunder Alaska. Oil & Gas Coxnmission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~ x V V~, V . ~`~ /~..3R ~~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRI~. Each of these wells was found to ha.ve a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annulax 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 June 26th, 2009. The corrosion inhibitor/sealant was pumped June 30~' & July 16th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. - Please call MJ Loveland or Perry I£lein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor ~ ~ `~ i ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-ofF Report of Sundry Operations (10-404) Kuparuk Field Date 7/18/09 3H, 31 & 3Q PAD Weil Name APi # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft ~ al 31-07 500292154900 1860390 3' NA 3' NA 8.92 7/16/2009 3H-04 501032007600 1870760 30" NA 30" NA 13.6 7/16/2009 3H-08 501032008000 1870800 17" NA 17" NA 3.4 7/16/2009 3H-11 501032009100 1871240 27:' NA 27" NA 6.37 7/16/2009 3H-19 501032009000 1871330 17" NA 17" NA 5.95 7/16/2009 3H-21 501032009400 1880080 8" NA 8" NA 1.27 7/16/2009 3H-23A 501032020401 1961860 6" NA 6" NA 1.27 • 7/16/2009 3H-24 50103202350U 1960150 6" NA 6" NA 1.27 7/16/2009 3H-31 501032020500 1940190 13" NA 13" NA ~ 2.97 7/16/2009 3H-33 501032057800 2081130 19" NA 19" NA 5.52 7/16/2009 3Q-03 500292222100 1911260 SF NA 5" NA 0.9 6/30/2009 3Q-06 500292168300 1861950 43' 6.30 26" 6/26/2009 6,8 6/30/2009 3Q-08A 500292168101 1971930 SF NA 6" NA 1 6/30/2009 3Q-09 500292167400 1861860 SF NA 6" NA 1 6/30/2009 3Q-10 500292167500 1861870 15' 2.50 18" 6/26/2009 6.8 6/30/2009 3Q-11 500292167600 1861880 37' 4.30 23" 6/26/2009 7 6/30/2009 3Q-14 500292166500 1861770 46' 5.10 23" 6/26/2009 7 6/30/2009 3Q-22 500292262500 1951860 SF NA 19" 6/26/2009 6 6/30l20U9 oN OR BEFORE C:LO~IV~[LM-DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory 96-186 MWD SRIFf 96-186 DGR/RES-TVD 96-186 DGR/RES-MD 96-186 7937 96-186 MWD SRVY T DATA PLUS ~r~PERRY GR/RES ~7610.70-9875.0 Page: 1 Date: 01/21/99 RLTN RECVD 02/12/97 FINAL 03/20/97 FINAL 03/20/97 1 03/20/97 04/29/97 10-407 ~-COMPLETION DATE DAILY WELL OPS R /~ /// /~ / TO //!~/¢?/ Are dry ditch samples required? yes ~ ~o~ And received? Was the well cored? yes ~o_~_~Analysis & description received? A_re well tests required?~yes ~Received? Well is in compliance I~itial COMMENTs ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 28, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3H-23A (Permit No. 96-186) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent operations to sidetrack KRU 3H-23. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad 1997 ORIGINAL , STATE OF ALASKA ' ALASK~ OIL AND GAS CONSERVATION C~,,4MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ...... ClassificatiGn of Service Well ..... [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-186 :~. Address ....................... 8. APl Number ..... P. o. Box 100360, Anchorage, Alaska 99510 50-103-20204-01 4. Location of well at surface 9. Unit or Lease Name 1019' FNL, 281' FWL, Sec. 12, T12N, R8E, UM ' : ......... -"-'"-'"* '~I Kuparuk River Unit ~ '- ......... ;-':' ~ ~,~-..~-:.'.~ ~ 10. WellNumber At top,of productive intervali/ ........ ;"" ~;' '~"' '"" ......... f ~~/J" 1039 FNL' 1450'FWL'Soc'2'T12N'R8E'UM ¢ /-~~¢~.{ i~~i 3H-23A At total depth -Y- ' i 1; Field and P0Ol ....... 729' FNL, 1352' FWL, Sec. 2, T12N, R8E, UM.- ,-_,--.-~__~-i--.~X"_:_/ _ -_--. _. _ _~"~~ Kuparuk River i8-. i~Jew~-ion-in f-~t (indicate KB, DF~ etc~) 16. Le~'§e"D'esignati0n and Serial No. RKB 70', Pad 38' GLJ ADb 25531, ALK 2657 12. Date Spudded12/20/96 Jil 3' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re I 16' N°' °f C°mpleti°nS12/23/96 1/29/97 N/A MSLI One 1'7. Total Depth (MD+TVD)118'. Plug Back Depth (MD+TVD)il 9. DirectiOnal SurVeyl20. D~'~th Where SSSV set~21. Thi'~J~ness of Permafrost ........... 98751" 6!'1_91 FT~ 9781' 6077' FT~ [~Yes i-lNo I N/A MD./ 1650'(Approx.) 22. Type Electric or Other Logs Run CH/Resistivity 23. CASING, LINER AND CEMENTING RECORD CASING SE-I-rING DEPTH HOLE SIZE VVT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED ..... ~--~" - .... 621~ ....... ~-_4~- ..... ~-rL ..... i-~ ii 24" F2-(~- SX c~-n~n~ 9.625" 36# J-55 st~'rf. 4216' 12.25" 900 sx ASlII, 600 sx Class G cement 7" 26# L-80 Surf. 7635' 8.5" '2-~b-~--(;-f~ G-~'~-m~-~ 4.5" 12.6# L-80 7475' 9875' 6.125" 311 sx Class G cement ... 24. perforationS open to ProdGctic~n (MD+TVD of TOP and Bottom '25. ' TUBiNG REcoRD ....... and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7507' 7489' MD TVD MD TVD ..................................................................................................................... 9550'-9600' 5978'-5999' 4 spf 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH iNTERvAL (UD) AMOUNT & KIND OF MATER~AL UsED 9550'-9600' Pumped 7719# of 20/40 proppant, 180M of 12/18 proppant, and 13,581 # of 10/14 proppant. ~71 " PRODUOT;~N T~ST ................ '~ate"First Production iMethod of Operation (Flowing, gas lift, etcl) ........ i Gas Lift 2/3/97 Date of Test iNcurs Tested PRODUCTION FOR OIL-BB~ GAS-MCF WATER-BBb CHOKE SiZE i GAS-'~I~-~ATIO 4/13/97 i 6.2 TEST PERIOD ' 310 241 4 176 i 741 Fi~-~-T-~ibii~-~i~-~-i-~---Pr-e~-s-i~-r~ CALCULATED · OIL-BBb '~X§:M~i= .......... W-~T~:BB-[ ......... Oi[-G-~X-~f~:AP-i*(d~R) ................................. Press. 15~ .. 715 24-FlouR RATE 1088 806 16 =23° '~8. ' ..... C~RE' DATX ..... L. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. APR 2_ 9 ]997 4las/,,,a .0il .& Gas C0~s. ¢0_r~Bjsslu. Form 10-407 Rev. 07-01-80 0RIGINAL Submit In Duplicate 29. Geologic Mark Formation Tests ! Measured I True Vertical InclUde interval tested, pressure data, all fluids recovered I,Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 9513' 5961' Bottom Kuparuk C 9544' 5974' Top Kuparuk A 9544' 5974' Bottom Kuparuk A 9669' 6028' Annulus left open - freeze protected with diesel. 31. List of Attachments .............................. Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .L~L~ I. ~..,,- Title I.~,~ ~,,,.,E¢_...~ Date Prepared By Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 APR 29 1997 ~nchoraoe KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3H-23A(W4-6)) WI~ I. JOB SCOPE JOB NUMBER 3H-23A PERFORATE, PERF SUPPORT 1231961934.5 UN[I' NUMBER UNIT # 1 DATE DAILY WORK 01/18/97 PERFORATE "A" SANDS F/9550 - 9600' ELM DAY OPERATION COMPLEFE ~ SUCCESSFUL 2 NO I YES Initial Tbg Press [ Final Tbg Press Initial Inner Ann 200 PSI[ 0 PSI 500 PSI DAILY SUMMARY KEY PERSON APC-GRIGSBY SUPERVISOR BLACK Final Inner Ann [ 0 PSI I Initial Outer Ann [ 0 PSI I Final Outer ~ 0 PSI WORK IN PROGRESS TO PERFORATE "A" SANDS F/9550 - 9600' ELM TIME 08:45 LOG ENTRY MIRU SWS (BAILEY & CREW). TGSM - PERFORATING SAFETY, WEATHER & JOB OVERVIEW. MU GUN ASSEMBLY (10' HSD/GR/CCI_4rWT) TL - 25'. PROBLEMS WITH TOOL MU. PT BOPE TO 2500 PSI. 13:00 RIH W/GUN ASSEMBLY #1. WORKED PAST SPOT @ 6700' ELM AND GOT DOWN TO 9370' ELM. COULD NOT GET BELOW 9370' ELM. POOH F/TOOL CHANGE. 16:15 MU GUN ASSEMBLY #2 (20' HSD/GR/CCL) TL - 30'. PT BOPE. 19:30 RIH W/GUN ASSEMBLY #2 TO 9470' ELM WITH TROUBLE SPOTS ALL THE WAY DOWN, COULD NOT GET BELOW 9470' ELM. POOH F/TOOL CHANGE. 22:00 MU GUN ASSEMBLY #3 (PETROLJNE ROLLER/20'HSD/PETROLINE ROLLER/GR/CCL) TL- 38'. PT BOPE. RIH W/GUN ASSEMBLY #3. WIP ARCO Alaska, Inc. A KUPARUK RIVER UNIT WELL SERVICE REPORT WI~ I. JOB SCOPE 3H-23A PERFORATE, PERF SUPPORT DAILY WORK PERFORATE DATE 01/19/97 DAY 3 OPERATION COMPLETE YES SUCCESSFUL YES Final Tbg Press [ Initial I~mer Ann 1300 PSI 200 PSI Kl(3H-23A(W4-6)) Initial Tbg Press [ 0 PSI JOB NUMBER 1231961934.5 UNIT NUMBER UNIT # 1 KEY PERSON SUPERVISOR APC-GRIGSBY BLACK · Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSII 500 PSII 500 PSI DAILY SUMMARY PERFORATED "A" SAND INTERVAL F/9550 - 9600' ELM W/2-1/2" BH CHARGES @ 4 SPF W/180 DEG PHASING- 2 SPF @ 169 DEG F/HI SIDE & 2 SPF 11 DEG F/LO SIDE ( DUE TO USE OF PETROLINE ROLLERS ORIENTATION MAY NOT HAVE OCCURRED ). TIME 00:00 03:30 06:45 10:45 13:00 15:15 LOG ENTRY RIH W/GUN ASSEMBLY #3 (PETROLINE ROLLER/20' HSD/PETROLINE ROLLER/GR/CCL) TL -38 TO 9740' ELM W/NO PROBLEMS. TIE INTO 12/23/96 LINER TALLY & 12/24/96 SPERRY SUN ROP/GR/DIL. PERFORATE F/9580 - 9600' ELM W/2.5" BH @ 4 SPF W/180 DEG PHASING (MAY NOT HAVE ORIENTED DUE TO USE OF ROLLER CENTRALISERS) POOH. ALL SHOTS FIRED. MU GUN ASSEMBLY #4 (SAME AS ASSEMBLY #3). PT BOPE. RIH TO 9740' ELM & TIE IN. PERFORATE F/9560- 9580' ELM W/2.5" BH @4 SPF W/180 DEG PHASING (MAY NOT HAVE ORIENTED DUE TO ROLLER CENTRALISERS). POOH. ALL SHOTS FIRED. MU GUN ASSEMBLY #5 (PETROI_JNE ROLLER/10' HSD/PETROLINE ROLLER/GR/CCL) TL-22'. PTBOPE. RIH TO 6750' ELM. COULDN~ WORK PAST. POOH TO MODIFY TOOL ASSEMBLY· MU GUN ASSEMBLY #6 (WT/ROLLER/10' HSD/ROLLER/GR/CCL) TL-26'. PT. RIH W/GUN ASSEMBLY #6 TO 9740' ELM & TIE IN. PERFORATE F/9550 - 9560' ELM W/2.5" BH @ 4 SPF W/180 DEG PHASING 0VIAY NOT ORIENF DUE TO ROLLERS). POOH. ALL SHOTS FIRED. RD SWS & SECURE LOCATION TURN WELL OVER TO PRODUCTION FOR FRAC TREATMENT. Date: 2/11/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3H-23A RIG:NORDIC WI: 0% SECURITY:0 WELL ID: AK8421 TYPE: AFC: AK8421 AFC EST/UL:$ 887M/ 1037M STATE:ALASKA API NUMBER: 50-103-20204-01 AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:12/20/96 START COMP: FINAL:12/27/96 12/11/96 (D1) TD: 9360' (9360) SUPV: DEB DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 WO LUBRICATOR TO PULL VR PLUG Move rig from iF pad to 3H pad. Accept rig @ 2030 hrs. 12/10/96. 35,351 CUM:$ 35,351 ETD:$ 0 EFC:$ 922,351 12/12/96 (D2) TD: 9360' ( SUPV: DEB o) DAILY:$ MW: 12.6 VISC: 43 PV/YP: 15/14 APIWL: 7.1 ~U BOPE Prepare to kill well. Inject mud to flush out tail and perfs. Monitor well. Well dead. NU BOPE. 37,091 CUM:$ 72,442 ETD:$ 0 EFC:$ 959,442 12/13/96 (D3) TD: 9360'( SUPV:DEB o) DAILY:$ MW: 12.6 VISC: 47 PV/YP: 15/16 APIWL: 7.0 WEIGHT UP MUD TO 12.6 PPG NU and test BOPE. POH with 3.5" tubing. Started coming wet, monitor well, slow flow out of tubing and annulus. Weight up mud in pits to 12.6 ppg. 35,861 CUM:$ 108,303 ETD:$ 0 EFC:$ 995,303 12/14/96 (D4) TD: 9252'( SUPV:DEB 0) DAILY:$ MW: 12.9 rISC: 47 PV/YP: 17/22 APIWL: 4.5 LOAD DP INTO PIPE SHED Continuing to have well control problems. Condition and weight up mud to 12.9 ppg. Monitor well, static, no flow, no loss. POH with tubing. 37,035 CUM:$ 145,338 ETD:$ 0 EFC:$ 1,032,338 12/15/96 (D5) TD: 7955'( SUPV:DEB 0) DAILY:$ MW: 9.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MIXING MILLING MUD RIH with retainer. Set cement retainer @ 7955' Inject cement to P&A well. CIP @ 2230 hrs. 12/14/96. Pump pill. 53,352 CUM:$ 198,690 ETD:$ 0 EFC:$ 1,085,690 12/16/96 (D6) TD: 7955'( SUPV:DEB 0) DAILY:$ MW: 9.8 VISC: 91 PV/YP: 10/46 APIWL: 6.5 POH TO CHECK SECTION MILL RIH with milling tools. Start milling @ 7755' MD. Work and jar stuck pipe. POH to check section milling tools. 47,995 CUM:$ 246,685 ETD:$ 0 EFC:$ 1,133,685 12/17/96 (D7) TD: 7955' ( SUPV: DEB 0) DAILY:$ MW: 9.8 VISC: 103 PV/YP: 11/57 APIWL: 6.0 SECTION MILLING @ 7670' POH with MBHA %1, had drag all the way. Found blades not fully retracted. RIH with milling BHA %2. Tag tight spot @ 7734'MD. Start milling section @ 7635' MD. Mill section from 7635' to 7670' 40,173 CUM:$ 286,858 ETD:$ 0 EFC:$ 1,173,858 12/18/96 (D8) TD: 7955'( SUPV:DEB MW: 9.8 VISC: 100 PV/YP: 11/55 APIWL' 6.0 W.O. CEMENTERS TO ARRIVE(WOW) Mill section from 7670' to 7685'. Work kelly and single up to top of section. Work and ream back down, push bird nest Date: 2/11/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 DAILY:$ 12/19/96 (D9) TD: 7955' ( 0) SUPV:DEB DAILY:$ 12/20/96 (D10) TD: 7794' ( 0) SUPV:DEB DAILY:$ 12/21/96 (Dll) TD: 8458' (664) SUPV:DEB DAILY:$ 12/22/96 (D12) TD: 9113' (655) SUPV:DEB DAILY:$ 12/23/96 (D13) TD: 9769' (656) SUPV:DEB DAILY:$ 12/24/96 (D14) TD: 9875' (106) SUPV:DEB DAILY:$ 12/25/96 (D15) TD: 9875' ( 0) SUPV:DLW DAILY:$ 12/26/96 (D16) TD: 9875' ( 0) SUPV: DLW DAILY:$ to bottom. Pump visc sweep and circulate around. POH with MBHA %2. RIH with OEDP. Wait for cementers to arrive - delayed by Phase 2 weather. 44,362 CUM:$ 331,220 ETD:$ 0 EFC:$ 1,218,220 MW: 9.8 VISC: 75 PV/YP: 12/40 APIWL: 7.4 SLIP & CUT DRILLING LINE Pump cement. Test BOPE. OK. RIH with HWDP. 86,117 CUM:$ 417,337 ETD:$ 0 EFC:$ 1,304,337 MW: 9.6 VISC: 43 PV/YP: 12/27 APIWL: 6.8 DRILLING/SLIDING @ 7794' RIH with BHA %1. Tag cement @ 7320' Drill out cement from 7320' to KOP @ 7640' Kick-off and drill from 7640' to 7702' Test formation to 1030 psi over 9.6 ppg mud using test pump, no leak-off. Drill from 7702' to 7794' 52,571 CUM:$ 469,908 ETD:$ 0 EFC:$ 1,356,908 MW: 9.8 VISC: 44 PV/YP: 12/22 APIWL: 6.0 CLEAN UP 5 BBL MUD SPILL Drill from 7794' to 8458' Clean up mud spill. 53,938 CUM:$ 523,846 ETD:$ 0 EFC:$ 1,410,846 MW: 11.4 VISC: 45 PV/YP: 17/19 APIWL: 5.5 DRILLING RBIH 9 stands. Wash through tight spots at 8068' and 8163'. Drill from 8458' to 9113' 63,461 CUM:$ 587,307 ETD:$ 0 EFC:$ 1,474,307 MW: 12.1 VISC: 45 PV/YP: 23/21 APIWL: 4.0 DRILLING Drill from 9113' to 9456' Test formation to 13.5 ppg EMW, no leak off. Drill from 8456' to 9769' 62,034 CUM:$ 649,341 ETD:$ 0 EFC:$ 1,536,341 MW: 12.4 rISC: 47 PV/YP: 23/18 APIWL: 4.0 POH Drill from 9769' to 9875' TD. Monitor well, slow flow. RBIH to 9875' Circulate bottoms up, oil and gas cut at bottoms up to 11.4 ppg. Weight up to 12.4 ppg mud. Monitor well, static. 54,997 CUM:$ 704,338 ETD:$ 0 EFC:$ 1,591,338 MW: 12.4 VISC: 46 PV/YP: 23/18 APIWL: 4.0 RIH W/4.5" LINER Run 4.5" liner. 61,477 CUM:$ 765,815 ETD:$ 0 EFC:$ 1,652,815 MW: 12.4 VISC: 46 PV/YP: 23/18 APIWL: 4.0 POH Continue to run 4.5" liner on 3.5" DP to 20' of bottom @ 9875'. Pump cement. CIP @ 0923 hrs. Run 3.5" single completion. 99,120 CUM:$ 864,935 ETD:$ 0 EFC:$ 1,751,935 Date: 2/11/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/27/96 (D17} TD: 9875' ( 0) SUPV:DLW DAILY: $ MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Continue re-running 3.5" single completion. Stab into PBR @ 7475' Test 4.5" liner hanger to 3500 psi for 30 min. OK. N/D BOP's, test pack off to 5000 psi, OK, N/U tree test to 3500 psi OK. Release rig @ 0400 hrs. 12/27/96. 87,212 CUM:$ 952,147 ETD:$ 0 EFC:$ 1,839,147 End of WellSummary for Well:AK8421 St RY-SUN DRILLING SERVICES ANCHOPJ~GE ALASKA PAGE ARCO ALASKA INC KUPARUK RIVER UNIT / 3H-23A 501032020401 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 122496 MWD SURVEY JOB NUMBER: AK-MM-60198 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 7610.70 5038.32 4968.22 55 0 N 46.06 W .00 3739.09N 3467.65W 4614.85 7640.00 5055.19 4985.09 54 42 N 46.33 W 1.27 3755.67N 3484.94W 4635.90 7748.81 5118.29 5048.19 54 45 N 30.50 W 11.86 3824.91N 3539.84W 4718.53 7842.98 5170.65 5100.55 57 53 N 18.19 W 11.37 3896.14N 3571.90W 4796.12 7937.46 5220.31 5150.21 58 41 N 21.05 W 2.71 3971.82N 3598.89W 4876.43 8032.52 5268.09 5197.99 60 57 N 19.27 W 2.88 4048.96N 3627.19W 4958.52 8125.94 5313o64 5243.54 60 41 N 22.53 W 3.06 4125.14N 3656.28W 5039.94 8219.22 5359.46 5289.36 60 28 N 24.54 W 1.89 4199.62N 3688.72W 5120.75 8313.77 5405.16 5335.06 61 43 N 21.97 W 2.72 4275.66N 3721.38W 5203.12 8408.71 5449.48 5379.38 62 38 N 18.68 W 3.21 4354.39N 3750.53W 5286.98 8501.34 5492.34 5422.24 62 14 N 19.15 W .62 4432.07N 3777.15W 5369.07 8586.52 5532.31 5462.21 61 47 N 23.24 W 4.27 4502.19N 3804.34W 5444.13 8689.19 5581.33 5511.23 61 10 N 23.68 W .72 4584.95N 3840.25W 5533.88 8786.07 5628.47 5558.37 60 36 N 26.66 W 2.75 4661.54N 3876.24W 5617.79 8879.62 5673.58 5603.48 61 44 N 23.03 W 3.61 4735.90N 3910.65W 5699.08 8974.53 5718.09 5647.99 62 19 N 25.68 W 2.54 4812.25N 3945.22W 5782.31 9068.67 5761.68 5691.58 62 30 N 25.02 W .65 4887.65N 3980.94W 5865.00 9161o51 5804.65 5734.55 62 21 N 24.66 W .38 4962.33N 4015.51W 5946.65 9254.26 5847.47 5777.37 62 39 N 21.13 W 3.39 5038.11N 4047.51W 6028.57 9348.59 5889.79 5819.69 64 3 N 16.49 W 4.64 5117.89N 4074.66W 6112.83 9444.00 5931.18 5861.08 64 32 N 16.19 W .59 5200.39N 4098.85W 6198.77 9537.23 5971.35 5901.25 64 24 N 14.34 W 1.80 5281.54N 4121.00W 6282.82 9630.40 6011.65 5941.55 64 20 N 17.92 W 3.47 5362.23N 4144.33W 6366.78 9724.63 6052.58 5982.48 64 9 N 18.40 W .50 5442.87N 4170.78W 6451.65 9800.74 6085.89 6015.79 63 55 N 18.51 W .34 5507.79N 4192.45W 6520.08 9875.00 6118.54 6048.44 63 55 N 18.51 W .00 5571.03N 4213.62W 6586.77 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6985.06 FEET AT NORTH 37 DEGo 6 MIN. WEST AT MD = 9875 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 342.34 DEG. TIE-IN SURVEY AT 7,610.70' MD WINDOW POINT AT 7,640.00' MD PROJECTED SURVEY AT 9,875.00' MD S1 .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC KUPARUK RIVER UNIT / 3H-23A 501032020401 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 122496 JOB NUMBER: AK-MM-60198 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7610.70 5038.32 4968.22 8610.70 5543.74 5473.64 9610.70 6003.12 5933.02 9875.00 6118.54 6048.44 3739.09 N 3467.65 W 2572.38 4521.77 N 3812.74 W 3066.96 494.58 5345.29 N 4138.98 W 3607.58 540.62 5571.03 N 4213.62 W 3756.46 148.88 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RY-SUN DRILLING SERVICES ANCHOR3%GE ALASKA PAGE ARCO ALASKA INC KUPARUK RIVER UNIT / 3H-23A 501032020401 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 122496 JOB NUMBER: AK-MM-60198 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7610.70 5038.32 4968.22 3739.09 N 3467.65 W 2572.38 7665.74 5070.10 5000.00 3770.70 N 3499.58 W 2595.64 23.26 7841.99 5170.10 5100.00 3895.37 N 3571.58 W 2671.89 76.25 8036.66 5270.10 5200.00 4052.36 N 3628.41 W 2766.56 94.68 8240.93 5370.10 5300.00 4216.88 N 3696.47 W 2870.83 104.27 8453.54 5470.10 5400.00 4392.10 N 3763.30 W 2983.44 112.62 8665.91 5570.10 5500.00 4566.26 N 3832.06 W 3095.81 112.36 8872.28 5670.10 5600.00 4729.96 N 3908.10 W 3202.18 106.38 9086.91 5770.10 5700.00 4902.31 N 3987.78 W 3316.80 114.62 9304.15 5870.10 5800.00 5079.93 N 4062.61 W 3434.05 117.24 9534.34 5970.10 5900.00 5279.01 N 4120.36 W 3564.24 130.19 9764.79 6070.10 6000.00 5477.15 N 4182.20 W 3694.68 130.45 9875.00 6118.54 6048.44 5571.03 N 4213.62 W 3756.46 61.77 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 0 Ft I L..I_i IM G S ~: I::IL~I C E S WELL LOG TRANSM1TFAL To: State of Alaska March 19, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 3H-23A, AK-MM-60198 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 3H-23A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-20204-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20204-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Comp&ny o IR I I_1_1 RI G S ~ I=~/I r' ~= S WELL LOG TRANSMIlWAL To; State of Alaska March 19, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor ~ko ~.[C.~~ 3001 Porcupine Dr. r2t~ ~ Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 3H-23A, AK-MM-60198 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20204-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company i"l i:! I L.I_ I RIr= February 11, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 3H-23A Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 3H-23A Tie in point 7,610.70, window point 7,640.00', interpolated depth at 9,875.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company TONY KNOWLES, GOVERNOR ~SI~ OIL AND CONSER¥~TION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 27, 1996 Mike Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3H-23A ARCO Alaska, Inc. Permit No. 96-186 Sur. Loc. 1019'FNL, 281'FWL, Sec. 12, TI2N, R8E, UM Btnmholc Loc. 682'FNL, 1361'FWL, Sec. 02, T12N, R8E, UM Dear Mr. Zanghi: Enclosed is thc approved application for permit to redrill thc above referenced well. The permit to rcdrill does not exempt you from obtaining additional permits required bx' lax,,' from other govenm~ental agencies, and does not authorize conducting drilling operations until all other required permitting determinations arc made. 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 Contrnission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Co~ru~pector on the North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION dlffEnclosurcs CC: Department of Fish & Game. Habitat Section xv/o cncl. Dcpartmcnt of Environmcntal Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill X lb Type of Well Exploratory ~--I Slratigraphic Test [] Development Oil X Re-Ent~y n Deepen ~] Service n Development Gas n Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 70', Pad 38' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25531, ALK 2657 4. Location o! well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 1019' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 968' FNL, 1450' FWL, Sec. 02, T12N, R8E, UM 3H-23A #U-630610 At total depth 9. Approximate spud date Amount 682' FNL, 1361' FWL, Sec. 02, T12N, RSE, UM 12/03/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15, Proposed depth (MD and TVD) property line 3H-19 9930' MD 968' @ Tar~let feet 10' @ 550' MD feet 2560 6144' TVD teet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 7760' feet Maximum hole angle 62.8° Maximum surface 2620 psig At total depth (TVD) 3275 18. Casing program Settin~l Depth size Specitications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6-1/8' 4-1/2" 12.6# L-80 NSCT 2325' 7605' 5031' 9930' 6144' 300sxs ClassG 19. To be completed for Redrill, Re-entry, and Deepen Operations. R!CE! v ~'- ~) Present well condition summary Total depth: measured 9360 feet Plugs (measured) true vertical 6212 feet NOV t 1996 Effective depth: measured 9252 feet Junk (measured) Alaska 011 & Gas Cons. Commission true vertica 6129 feet Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 1 6' 200 SxAS II 121' 121' Surface 4175' 9-5/8' 900 sx ASIII, 600 sx Class G 4216' 3186' Intermediate Production 9300' 7 ' 250 sx Class G 9341 ' 6197' Liner Perforation depth: measured 9092'-9122' MD true vertical 6006'-6029' TVD 20. Attachments Filing fee X Property plat ~] BOPSketch X Diverter Sketch ~ Drilling program X Drilling fluid program X Time vs depth plot r-~ Refraction analysis [] Seabed report r-~ 20 AAC 25.050 requirements X 21. Ihe"~' ~-'~re by certify th/~~, at the foregoing is true and correct to the best of my knowledge/~/~ ,/~//~'~ ~/~-~"~/~T //~/--~:2////'/7 Signed itle Drill Site Develop. Supv. Date ~ Commission Use Only Permit Number '[ APl number ..... I Approval4ate.~ ~ ~ ! I See cover letter for .~ -,""~ I 5 0-/0 ~ - ~ <:~ ''7- o ~ -- 0 J I //---,,,z, / '~7,g'I other requirements Conditions of approval Samples required ~ Yes ~] No Mud iog required E] Yes J~] No Hydrogen sulfide measures [] Yes r-I No Directional survey required [] Yes [--I No Required working pressure for BOPE [~ 2M [~. 3M ~ 5M ~ 10M n 15M Other: OrJ~o/~a/~io~.o ~y by order of Approved by David W. J0hJ-ist0~. Commissioner the commission Date //"' Fnrm 1~-4~1 R~.v 7-24-R.Cl RHhrnit in trinlinntP. REDRILL PLAN SUMMARY Well 3H-23A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location: MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: Producer 1019' FNL, 281' FVVL, SEC 12, T12N,R8E, UM 968' FNL, 1450' FVVL, SEC 02, T12N,R8E, UM 682' FNL, 1361' FWL, SEC 02, T12N, R8E, UM 9930' 6144' Nordic Rig 2 12-03-96 14 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Section in 7" casing 9.3 >25 15-35 85-95 20-30 30-40 8.5-9.5 Kick off to weight up 9.3-9.5 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.9 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: Ddlling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csa/Tba -- -- 4-1/2", 12.6#, L-80, NSCT Tubing 3-1/2", 9.3#, J-55, EUE Length Top (MD/'rVD) Btm (MD/TVD 2325' 7605'/5031' 9930? 6144' 7576' 29?29' 7605'/5031' Cement Calculations: Casina to be cemented: -- 4-1/2" in 6-1/8" open hole Volume = 300 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 51%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,620 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.5 ppg EMW. With an expected formation pressure in the Kuparuk of 3500 psi and a gas gradient of 0.11 psi/ft, this shows that formation breakdown would not occur before a surface pressure of 2,620 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 3H-23A, will kick off out of the 7" casing below both the K-10 and K-5 intervals. The casing around the kick-off window will be squeezed with cement prior to drilling out, which should isolate the K-10 and K-5 from the sidetrack operations. Nevertheless, even If not isolated the K-10 and K-5 intervals should be able to handle the expected mud weights to be used for this sidetrack. Off-set ddlling data shows that wells in the area of 3H-23 were drilled to TD with 10.9 - 11.7 ppg mud without any loses. The kick-off point in 3H-23A is below any zones which would be of pressure concem prior to weighting up for the Kuparuk interval. None Directional: KOP: Max hole angle: Close approach: 7760' MD / 5121' TVD 62.8° (in sidetrack portion) No Hazards Page 2 Loclclincl Proaram: Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CCL Notes: All drill solids generated from the 3H-23A sidetrack will be hauled to CC-2A in Prudhoe Bay forgrind and inject. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 3H-23A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: 1. RU slickline unit. RIH tag fill. RIH and dummy off all GLMs, leave deepest GLM open. 2. Set BPV in tubing. Install VR plug in annulus valve if necessary. WORKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits w/kill weight mud. Cimulate well to kill weight mud. Ensure well is dead. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH standing back tubing and laying down all jewelry. . PU DP and RIH with cement retainer. Set retainer at 7965' MD. Pump cement squeeze below retainer into A Sand perfs filling 7" casing to bottom A Sand perf / top of fill. Unsting from retainer and circulate well to milling fluid. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. POOH standing back DP. 6. RIH w/section mill. Cut a 50' section in the 7" casing from 7765' - 7815'. POOH w/mill. . RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. POOH. . . 10. 11. 12. RIH w/6-1/8" bit, mud motor, MWD / LWD, and steerable ddlling assembly. Dress off cement to top of section. Kick-off well and directionally drill to total depth as per directional plan. Short tdp to window in casing. POOH. R E C E IV E D Run 4-1/2" liner to TD w/150' of ovedap to top of milled section. NOV ? '1 1995 Cement liner. Set liner hanger and liner top packer. POOH w/DP. Alaska 011 & ~ Cons. C0mmis~i0n Pressure test casing and liner lap to 3500 psi for state test. Anchorage RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 14. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 12 days Expected Case: 14 days Upper Limit: 20 days No problems milling section, ddlling new hole, or running completion. Difficulties encountered milling section, or ddlling new hole. WSI 11/19/96 Page 4 ARCO ALASKA, Inc. Structure: Pad 5H Well : 25A Field : Kuparuk River Unit Location : North Slope, Alaska Cre~ted by finch FOR B ISk~CSON Dote plotted : 8-NOV-96 Plot Reference is 25A VER$.~8 (Oepth Shifted), Coordinot ..... in feet ref ...... lot ~2~A. 4350 I TD LOCATION: 682' FNL, 1561' FWL SEC. 2, T12N, RSE 342.77 Azimuth 6609'(T0 TD) **Plane of Proposal*** 4950- 5100 5250 <- West (feet) 4200 4050 5900 5750 5600 3450 I I I I I I I I I I I · TARGET LOCATION: 968' FNL, 1 450' FWL SEC. 2, T12N, RSE TARGET TVD=5989 TMD=9592 DEP=6309 NORTH 5331 WEST 4111 5400 KOP- SIDETRACK PT TVI)=Si21 TMD=7760 DEP=4711 54.36 56.20 DLS: 7.00 deg per 100 ft 58.56 EOC TVD=5327 TM0=8145 DEP=5025 61.56 5550 MAXIMUM ANGLI~ 62.77 DEG 5700 TOP UNIT A2 5850 6000 6150 SURFACE LOCATION: 1019' FNL, 281' FWL SEC. 12, T12N, RBE 3300 I I Cas[n 5700 5550 5400 5250 5100 4950 4800 465O 4500 4350 420O 4050 3900 5750 z C30TVD=5470 TMD=8458 DEP=5300 TARGET ANGLE 62.77 DEG TMD=9592 DEP=63 BASE HRZ TVD=5770 TMD=9115 DEP=5883 K-1 MARKER TVD=5885 TMD=9365 DEP=6107 TOP UNIT D TVD=5970 TMD=9550 DEP=6272 TOP UNIT C'[VD=5978 TMD=9568 DEP=6288 BASE KUP SANDS TVD=6052 TMD=9730 DEP=6431 TD TYD=6144 TMD=9930 DEP=6609 6300 4650 4800 4950 5100 5250 5400 5550 5700 5850 6000 6150 6300 6450 Vertical Section (feet) -> Azimuth 542.77 with reference 0.00 N, 0.00 E from slot #25A 6600 6750 7-1/16" 5000 PSI BOP STACK I ANNULAR PREVENTER 7 6 PIPE RAM I · I I ' 5 BLIND RAM~ I MUD CROSS 4 3 P PE RAM I 1 J ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE UNE VALVES. CLOSETOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOq-TOM PIPE RAMS. TEST BO3-FOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULLOF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIllING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11" - 3000 PSI CASING HEAD 2.11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS 6.7-1/16"- 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16" - 5000 PSI ANNULAR PREVENTER RECEIVED NOV 21 1996 Alaska 011 & ~s Cons. Commission Anchorage NORDIC RIG g2 LEVEL 1 z 12'-.I' 28'-6' 12'-4.' 73'-0" I 25'-0" I STAIRS _ EMSCO F-800 ~ PUMP .. ,,, 40-57 ~ ~ ~ 40-57 REMOVN~.E I~P EN~.OSURK I EMSCO F-800 ~ TRIPLEX MUD I PUMP SPIRAL · , _ STAIRS - CONTROL ~CONSOLE 36'-0' 8'-6' 53'-0' 8'-6' =!- 8'-0' ~ NORDIC RIG~ LEVEL 2 NORDIC RIG LEVEL 3 UNE SPOOL WATE~ TANK ./~LYCOL TANK o C~ ~ o ~ · USq]D~ ~dR HEATER !"1-1 HYORAUUC MUD TANK 75O BBLS SPIRAL STAIRS 7'--11' -'-' CHOKE: MANIFOLD LOFFICE STATE OF ALASKA Ai2~SKA OIL AND GAS CONSERVATI°N COMMiSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well _ Change approved program _ Operation Shutdown__ Re-enter suspended well _ Plugging ~ Time extension Stimulate Pull tubing_ Variance _ Perforate _ Other Plugback for Sidetrack 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1020' FNL, 282' FVVL, Sec. 12, T12N, R8E, UM At top of productive interval 1809' FNL, 1309' FWL, Sec 2, T12N, RSE, UM At effective depth At total depth 1675' FNL, 1166' F'WL, Sec. 2, T12N, R8E, UM 12. Present well condition summary Total Depth: measured (approx) true vertical 9360' 6212' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 80', Pad 39' GL, 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-23 9. Permit number ~)4-18 lO. APl number 50-103-20204 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured (approx) true vertical Length 80' 4175' 9300' measured 9092'- 9122' 9252' 6129' Size 16' 9-5/8' 7' feet Junk (measured) feet None Cemented Measured depth True vertical depth 121' 121' 200 sx 900 sx ASIII 4216' 3186' 600 sx Class G 250 sx Class G 9 341' 61 97' 13. 14. 16. true vertical 6006' - 6029' Tubing (size, grade, and measured depth) 3.5', J-55 tubing with tail @ 8985' Packers and SSSV (type and measured depth) Baker FB-1 packer @ 8965' MDI Camco TRDP-4E SSSV @ 1892' Attachments Description summary of proposal ~ Detailed operation program __ Contact William Isaacson at 263-4622 with questions. Estimated date for commencing operation 1 2/03/96 If proposal was verbally approved Name of approver Date approved Service Alaska 0il & Gas Cons uo:;~rmssi0n Anchorage 15. Status of well classification as: Oil X Gas _ BOP sketch Suspended 7. I hereby certify.,tl'),at the foregoing is true and correct to the best of my knowledge. S i~ned -"~"~'/'/~.-~//~'//~ Title Drill S~te Development Supv Date FOR COMMISSION USE ONLY / ICondition;l~;a~nPt?gVr~l:y No/~ify Commissio ~t tVec~e~r witness . Mechanical Integrity~..~ ~; Approved by the order of the Commiss~ ~ ~...,~-~..~'~ j ~~-.-...~mmissioner Form 10-403 Rev 06/15/88 IApproval No. SUBMIT '1~1 TRfPLICATE . . ..... WELL PERMIT CHECKLIST COMPANY PROG~:~ 0 de~ r~1 ~ 0 W~ ~ ~ ~. dis~ ~ r~ ~ FIE~ & P~L ~./~ CD IN~ C~SS ~~ / .... /~? ~ GEOL~ ~~ UN~ .~//~ O~FF SHORE ~ ~DMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. -E-N-GINEERiNG - .. Permit fee attached ........................ Y N Lease number appropriate ................... Y N Unique we, name and number ................. yIN Well lcx:~ted in a defined pool .................. Y N Well located proper distance from ddg unit bounda7 ..... Y N Well located proper distance from other wells ......... Y N Sufficient acreage available in drilling unit. .......... Y N If deviated, is wellbore plat included .............. Y N Operator only affected party .................. Y N Operator has appropriate bond in force ............. Y N Permit can be issued without conservation order ....... Y N Permit can be issued with°ut administrative appr°vai''' /i iN Can Permit be approved before 15-day wait. ....... N ._ .. -- REMARKS GEOLOGY --- ,~ DATE / 14. Conductor string provided ................... Y N 15. Surface casing protects ail known USDWs .......... Y N 16. CMT' vol adequate to circulate on conductor & surf csg .... Y N 17. CMT vol adequate to fie-in long string to surf csg ...... .~N 18. CMT will cover ail known productive horizons ......... 19. Casing designs adequate for C, T, B & ~ ..... 20. Adequate tankage or reserve pit. ............... 21. If a re~ldll, has a 10-403 for abndnmnt been approved .... Y N 22. Adequate we"bore separation proposed ............ (~ N 23. tf diverter required, is it adequate ................ 24. Ddlling fluid program scherr~tic & equip list adequate .... 25. BOPEs adequate .............. ..,,, ......... t~N _ 26. BOPE press rating adequate; test to -,~,~ psig..(.y~N 27. Choke manifold complies w/APl RP-53 (May 84) ....... ~<~N ~j,, v 28. Work will occur without operation shutdown .......... (~,N, 29. Is presence of H2S gas probable ............... (_y,/N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potentiai overpressure zones ....... Y,,~ //../,/-/' ,~ 32. Seismic analysis of shallow gas zones ............ ./Y N - ' 33. Seabed condition survey (if off-shore) .......... .~.. Y N 34. Contact name/phone for weekly progress repoT.. . .//... Y N lex~Iomtory on~,j / GEOLOGY: ENGINEERING: JDH ~ COMMISSION: DWJ JDN TAB'~--~ Comments/Instructions: HOW4~ - A.'~FQR~ my Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Mar 14 22:18:43 1997 Reel Header Service name ............. LISTPE Date ..................... 97/03/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/03/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Con~uent Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 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 1 AK-MM-60198 B. HENNINGSE D. BREEDEN 3H-23A 501032020401 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 14-MAR-97 12 12N 0SE 1019 281 70.10 69.60 38.40 OPEN HOLE CASING DRILLERS , ECE,vmo MAR 20 't99Z Alaska Oil & ~as Cons. Comaissio~ Andyne 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 7635.0 6.000 9875.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. THE WELL KICKED OFF OUT OF A WINDOW MILLED IN 7" CASING FROM 7635'MD, 5048'TVD TO 7685'MD, 5077'TVD. 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWP4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND BILL ISAACSON OF ARCO ALASKA, INC. ON MARCH 12, 1997. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9875'MD, 6114'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. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 7620.5 RPD 7620.5 RPM 7620.5 RPS 7620.5 RPX 7620.5 GR 7620.5 ROP 7640.0 $ STOP DEPTH 9820 0 9820 0 9820 0 9820 0 9820 0 9813 0 9875 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 7640.0 9875.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 RPX MWD OHM~ 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 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 7620.5 38 9918 1 6945 0 4744 0 3859 1 5398 5 7508 0 9109 First Max Mean Nsam Reading 9875 8747.75 4510 7620.5 511.264 124.738 4386 7620.5 2000 6.97659 4400 7620.5 2000 6.37929 4400 7620.5 2000 14.8756 4400 7620.5 2000 13.1165 4400 7620.5 1993.36 58.2544 4471 7640 8.698 2.09312 4400 7620.5 Last Reading 9875 9813 9820 9820 9820 9820 9875 9820 First Reading For Entire File .......... 7620.5 Last Reading For Entire File ........... 9875 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comraent 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 FET 7620.5 9820.0 RPD 7620.5 9820 . 0 RPM 7620.5 9820 . 0 RPS 7620 . 5 9820 . 0 RPX 7620.5 9820.0 GR 7620.5 9813.0 ROP 7640.0 9875.0 $ LOG HEADER DATA DATE LOGGED: 23-DEC-96 SOFTWARE 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: 54.7 MAXIMUM ANGLE: 64.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): ISC 4.88 SP4 5.01 / DEP II 2.17F MEMORY 9875.0 7640.0 9875.0 TOOL NUMBER P0617SP4 P0617SP4 6.130 6.1 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: NON DISPERSED 12.10 45.0 9.3 7OO 4.0 1.300 .611 1.200 1.600 63.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .6 REMARKS: THE WELL KICKED OUT OF 7" CASING AT 7,640'MD (5,051'TVD) AND WAS DRILLED TO TD AT 9,875'MD (6,114'TVD). $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP1 MWD 1 FT/H 4 1 68 4 2 GRC1 MWD 1 AAPI 4 1 68 8 3 RPX1 MWD 1 OHMM 4 1 68 12 4 RPSl MWD 1 OHMM 4 1 68 16 5 RPM1 MWD 1 OHMM 4 1 68 20 6 RPD1 MWD 1 OHMM 4 1 68 24 7 FET1 MWD 1 HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 7620.5 9875 8747.75 4510 7620.5 ROP1 5.7508 1993.36 58.2544 4471 7640 GRC1 38.9918 511.264 124.738 4386 7620.5 RPX1 1.6945 2000 6.97659 4400 7620.5 Last Reading 9875 9875 9813 9820 RPS1 0.4744 2000 6.37929 4400 RPM1 0.3859 2000 14.8756 4400 RPD1 1.5398 2000 13.1165 4400 FET1 0.9109 8.698 2.09312 4400 7620.5 7620.5 7620.5 7620.5 9820 9820 9820 9820 First Reading For Entire File .......... 7620.5 Last Reading For Entire File ........... 9875 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/03/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File