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Home My WebLink About177-053ORIGINATED TRANSMITTAL DATE: 3/18/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5330 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5330 1D-08 50029202660000 Plug Setting Record 6-Mar-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street lorna.c.collins@conocophillips.com Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 177-053 T40217 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.18 09:34:44 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 177-053 T38915 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 14:58:52 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Ila "%.f"n V F. FEB i 1 Ll/IS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operoons,shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Whipstock ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic❑ Exploratory ❑ Service ❑ 177-053 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number. 99510 50-029-20266-00-00 7. Property Designation (Lease Number): e. Well Name and Number: KRU 1 D-08 ADL 25650 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 6,880 feet Plugs measured 6550 feet true vertical 6.879 feet Junk measured None feet Effective Depth measured 6,550 feet Packer measured 6,294 feet true vertical 6,549 feet true vertical 6,292 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 52 feet 16 75' MD 75' TVD SURFACE 2,207 feet 10 3/4 " 2,230' MD 2230' TVD PRODUCTION 6,847 feet 7 6,869' MD 6868' TVD Liner 6,276 feet 5 1/2 " 6,295' MD 6294' TVD Perforation depth: Measured depth: 6384-6472, 6479-6484, 6636-6641, 6644-6652 feet True vertical depth: 6383-6471. 6478-6483, 6635-6640. 6643-6651 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 6,338' MD 6,337' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER'FB-1' PACKER 6,294' MD 6,292' 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: 334 1266 1,763 1207 221 Subsequent to operation: 1715 6003 4492 11263 1250 14. Attachments (required par 20 AAC 25,070, 25.071, s 25283) 15. Well Class after work: Daily Report of Well Operations 121 Exploratory ❑ Development EI 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: 318-575 Contact Name: William Long Authorized Name: William Long contact Email: William. R.Longc@cop.com Authorized Title: StaTD Engir, ff C ASignature I- - mlContactPhone: (907) 263-4372 uthorized Date: Form 10-404 Revised 4/2017 vl"�- RBEIMS 1 FEB 14 2019 �/ � Submit Original Only Conon Phillips Alaska, Inc. KUP PROD WELLNAME 1D-08 RIVER UNIT NIPPLE WELLBORE 1D-08 toaB.a "T'ssax. Last Tag VaN,B Nmatic lacE®II Annotation depa,IBKeI End pare WNIMne Laer MOs By ....................._..___ ......... Last Tag: ELMO TIED TO ON GR 6,5100 I I"sk'018 110-06 local I HANGER) pre CONDDGTGRI a6]50 Nepim SOBFACE: agzZMp J spoe's"Zi GASLsr;3.]4B.a Gas LET. e..a GM4UR5,33 GAS LIR: Saga Gas LIR:gMt LOCAroR: e.tw.z sEALAEST;B.1..I PACKERi&A3.] TIE thei Less 51Ra31R ®Bt wlelb.aass .BE Rai NIPPLE saes ve-GET3'i73 WHIvSTOCR:SaM.D IPERF Capp 0 Freve gaa.0 PERI: 9l7906.alli aLCG gssoo IPERF, gBYgoaval H- IPBRFi s.B4a.Oa.mi mooucTnm;n."MO Last Rev Reason AnnOUlion 1 Entl pale Wellbore last Mas By Rev Reason: Add milled out nipple 11"o'R 10-08 joii 1 1 Casing Strings Go, be.m.pbon pohn) her TOPlkea) set Depth Ser peMn Trial). WULen(I...Graae T,olmoaa CONDUCTOR 16 15.06 230 75.0 75.0 III 1140 WELDED Gsinp Descnplion Goer,' lolinl TopIkK01 set OeplM1 IM(B) eN peptl,INp1... WI O6...G,ade Top Threml SURFACE 103/4 9.79 228 22300 2,229.4 45.50 K-55 Chi D. on OD grad ID llnl TOp LMB) SeI DeptM1 IRKBI Pas Mprh(NO)... Yoom(1-1ofade Top TM1reel PRODUCTION ) 6.28 22.1 68fi90 8,86).5 2fi.00 J-55 BUTT Gamy Mxnpaon 00pn) ID lint Tap(WO) Bal Depth 1pKel sot expm(Nal.... 6...... Top Thrmd TIE BACK LINER 512n 512 428 19.1 6,295.5 6,2940 15.50 L-80 BTCM 31/2 @ 6128.69 Liner Details NominallD Top MD) Topin Venn KB) Top mail i I@m De. COR (in) 6,110.1 6,108.7 147 SBR BTC PIN x PIN CASING SEAL BORE RECEPTACLE 4000 6,lMJ 6,127.3 147 XO Reducing 5' BTC Box x 3112' EUE Pin cross Over sub 2.992 6,134.1 6,132.7 1.46 TUBING 3.5',9.38, L-80 EUE4cd8rd TubmgjihM 2992 6,175.0 6,1736 1.46 NIPPLE CAMCO DS LANDING NIPPLE 9 T111320 2,812 61W4 6,184.9 1.45 TUBING 3.511 L-80 EUE-Mod Bed Tubing joint 2.992 6,22)0 62255 1.27 GAS LIFT CAMCO Ml GLM B 195AE07 2.920 4. 6,244.5 1.14 TUBING 3.5', 9.38, L40 EUE-Mod Sod Tubing joint 2.992 6, 829 6,281.4 0.90 LOCATOR BAKER GBH -22 LOCATOR SUB 2.990 6284.1 6282fi 0.89 PBR BA 18040 SEAL ASSY w/3-6 Space Out 2990 Tubing Strings Tubing D*Ripaon slrinn Ma... 1plin) Top KING) Set Depth Set Depth TAG) I.. WI"no Grade Top E-mv- TUBING 9702014 3112 299 16.9 61232 6,121.8 930 L80 IBT Completion Details Top O'd Tawny Nominal Tapiffli (Neel (9 Mm Do, Cam IG fn) 165 164 0.05 HANGER FMC TUBING HANGER 2910 4929 4929 0.76 NIPPLE DS IANDING NIPPLE 2875 11,1092 6.102.8 1.47 LOCATOR BAKER LOCATOR SUB 2.992 6,105.1 6,1036 147 EAL AS Y BAKER 8040 SEALS WI J' -FT SPACE OUT 2.990 TUCinp Dexrlption Lbi,rO Ma.. Ip lint ToplkKBl set paPln m.. Eel gegen Irvpl L.. wrlpm) Grade Top Conn lion TUBING 3112 299 6293.) 63300 63365 920 N-80 BUTT Completion Details Top P, I TNw-1 Given.I Tap Me)("i PI Ibm an corn nbin) 6,2937 6,292.2 082 PACKER BAKER'F&1'PACKER 4000 62962 6,294) 0.81 SBE BAKER SFALBOREEXTENSION 4000 6.3255 6324.0 I O JB I NIPPLE CAMCO'D' Nil (Milled GNt e, 280' 1227Ii8) 2,800 6,33].3 633591 078 JVi BAKER WIRELINE ENTRY GUIDE Other In Hole (Wlreline retrievable plugs, valves, pumps, fish, etc.) s 1-.) Tap Incl Top XKB) op IRKBI 1') Dei Com Run Oale IO lin) 6,400.0 6.]98.5 0)> WHIPSTOCK NS HEW whlpslock 1/?2019 0.000 6.550.0 6,548.5 07) PWG Cast Iron Bridge Plug 5/14119)8 o.g6D Perforations & Slots shot We. TOp(TVD) BMnVDI Ishotsat Top lnKBl Btm laical (aKO) sti LiR. Zone Data ) Type Com 63840 64720 613825 6,4705 -. liall 4.0 IPERF 1D-08 64790 6484.0 64775 64825 C-210-0 SIBII97B 4.0 (PERF 6,6360 6,6410 6,634.5 IT sub AS, 10-08 SISI1978 4.0 (PERF 6,644.0 6,6520 66425 6650.5 A,5. 10-08 515119)8 4.0 JIPEHF Frac Summary stall wta Propacet DeeiOned gM pxpwnlln Farmatim lml 72]11918 air SGd0tle Top DenmlnKa) Btm@KB) Linua Fluidsy.tere Volekan(bhq vulslum10s11 1 712711978 6,3840 6481 Mandral Inserts at an H Tea (M(B1 ea Top OND) Valve lalan Pod Else TRP Run pON MB) Make Model 00(in) Sery Tyne Tres (Inl basil Run Deb Cam 1 2.541.4 2LHW.6 CAMCO NBC. 1 GAS LIFT GLV BTM 0188 1,224.0 122412018 2.9 2 3,786.3 3,785.2 CAMCO KB - 1 GAS LIFT OV BTM 0.250 0.0 122412018 2.9 3 4,688.3 4,687.1 CAMCO KB - 1 GAS LIFT DMY BTM 0.000 0.0 12242018 2.9 4 5,334.5 5,333.3 CAMCO l1 GAS LIFT DMY BTM 0.000 00 122312018 2.9 5 5,798.3 5,797.0 CAMCO ME - 1 GAS LIFT DMV 1 0BOD 00 124/2014 2.9 6 6,011.7 6,0103 CAMCO KBG- 1 GAS LIFT DMY 01 0000 0.0 J/24I2014 29 Notes: General & Safety End DeR Anndamn 12/2512002 NOTEWAIVERED WELL: IA X OA COMMUNICATION 818201 NOTE: View Sohemateep Alaska Sehavo iC9.0 2152019 I NOTE: View BChematiC AT Alaska SChemaliC 10.0 1D-08 Final CTD Completion 16" 65#H-40 shoe @ 75' RKB t-314" 45# K-55 shoe 2230' RKB IKOP @ 6396' MD C-santl per'$ 8384' - 6472' 8479' - 6484' T'26# J-55 shoe @ 6869' RKB 3.12"Tubing L -BD W! IBT 3`IW Larxiing DS Nipple @ 493' RKB (2.875" ID) 3.12" Carrico KBG Mandrel. @ 2541', 3766', 468a, 5335', 5798'.8012' V Seal Bore Receptacle W 4' pore @ 8110' RKB 5' V2'C...@8129'RKB Cam. DS Landing Nipple C 6175 RKB OD 2.813'1 Cam. GLM @ MT RKB Baker GBW22 Locator @ 6263' RKB Baker Bp DSeal Assembly @ 628e RKB Baker F&l Parker @ 6294' RKB Baker SBE @ 6296' RKB Cam. D Nipple @ 6328' (M9Ie4 Out- 2.80' ID) Baker WLEG @ 6337 RKB UPIded. 11 a 18(WRL) 1D-OBL7-O7 TD @ 9480' MD Top of Liner @ 6320' MD Billet @ 6474' MD . Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur(hr) Phase Op Code Activity Code Tare P -T -X Operation Start Depth (fit®) End Depth (WB) 12/31/2018 12/31/2018 2.00 MIRU MOVE RURD P Continue to follow RD check list, lift 0.0 0.0 16:00 18:00 landings and stairs, 12/31/2018 12/31/2018 2.00 MIRU MOVE RURD P Crew change, continue to work RD 0.0 0.0 18:00 20:00 checklist, trucks on location @ 18:15 pm, PJSM, hook up to pit module jack up and move to the entrance of the pad, install jeep. 12/31/2018 12/31/2018 1.20 MIRU MOVE RURD P Hook up truck to Sub Module, move 0.0 0.0 20:00 21:12 1 off well, install jeep, phone security 12/31/2018 12/31/2018 0.47 MIRU MOVE MOB P Pull onto access road 0.0 0.0 21:12 21:40 12/31/2018 1/1/2019 2.33 MIRU MOVE MOB P On spine road, head to 1D -pad 0.0 0.0 21:40 00:00 -1 1/1/2019 1/1/2019 75 MIRU MOVE MOB P Continue rig move to next location 1D- 0.0 0.0 00:00 01:45 pad 1/1/2019 1/1/2019 2.00 MIRU MOVE MOB P On location, remove jeeps, hookup 0.0 0.0 01:45 03:45 truck to drilling sub module, spot over well 1/1/2019 1/1/2019 1.75 MIRU MOVE MOB P Spot in rig mats, spot pit module next 0.0 0.0 03:45 05:30 to drilling sub, phone out scaffold crew to rig up in cellar, pusher headed to retrieve shop from 3C -pad. 1/1/2019 1/1/2019 -3.5 0 MIRU MOVE MOB P Work on Rig Move check list, secure 0.0 0.0 05:30 09:00 all landings, walking surfaces, and cellar floor, hook up PUTZ (inter- connect).Rig up steam lines / heaters. Scaffolding crew rig up scaffolding in pits, tool house on location, rig up tiger tank line placing tiger tank off drillers side along well row. 1/1/2019 1/1/2019 4.00 MIRU WHDBOP NUND P Nipple up BOP stack, tighten tree 0.0 0.0 09:00 13:00 bolts, valve crew service tree. Service rig valves in preparadon4 for BOPe lest, Rig Accept 12;00 1/1/2019 1/1/2019 1.00 MIRU WHDBOP NUND P Complete prepping for BOPe test. 0.0 0.0 13:00 14:00 Line up and fluid pack rig. Obtaint shell test 1/112019 1/1/2019 6.00 MIRU WHDBOP BOPE P Start full initial BOPE test. Test 0.0 0.0 14:00 20:00 witnessed by Adam Earl, AOGCC. Fail lKoorney pass on upper blind shears, test # 4, Test PVTs, Gas detectors, and 1/1/2019 1/1/2019 1.00 MIRU WHDBOP CTOP P BOPe test complete. PT TT line 0.0 0.0 20:00 21:00 1/1/2019 1/1/2019 1.50 MIRU WHDBOP OTHR P PJSM R/U and pull BPV, 350 PSI 0.0 0.0 21:00 22:30 under plug, r/D and load out BPV crew 1/1/2019 1/1/2019 0.50 MIRU WHDBOP CTOP P Pressure test CTC 4000PSI, 0.0 0.0 22:30 23:00 1/1/2019 1/2/2019 1.00 MIRU WHDBOP CTOP P Altemp to bleed off well. All gas. Line 0.0 0.0 23:00 00:00 up to bull head. Pump 70 BBIs seawater down well. Well on vac 1/2/2019 1/2/2019 0.50 MIRUTHDBOP PRTS P Pressure test both PDL's 0.0 0.0 00:00 00:30 1/2/2019 1/272619 0.40 MIRU WHDBOP CTOP P Fill hose to determine loss rate, Unable 0.0 0.0 00:30 00:54 to fill hole 1/2/2019 1/212019 2.00 PROD1 RPEQPT PULD P PJSM, M/U NES HEW whipstock, P/U 0.0 85.9 00:54 02:54 coiltrak with gyro trek tool, MIU to coil and surface test. orient at surface to test gyro 1/2/2019 1/2/2019 1.40 PROD1 RPEQPT TRIP P RIH BHA#1 with NES HEW 85.9 6,300.0 02:54 04:18 whipstock, EDC open pumping min rate, choke closed, zero WHP Page 1110 Report Printed: 1/2112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Mme Dur (hr) Phase Op Coda Activity Code Time P -T -X Operation sten oepm (0KB) End Depth (N(B) 1/2/2019 1/2/2019 0.20 PROD1 RPEQPT DLOG P Log K1. Looks like -11' correction/ Geo 6,300.0 6,400.0 04:18 04:30 not confident with log 112/2019 1/2/2019 0.30 PROD1 RPEQPT TRIP P PUH to lag HRZ 6,400.0 6,050.0 04:30 04:48 1/212019 1/2/2019 0.30 PROD1 RPEQPT DLOG P Log HRZ. for -11' correction 6,050.0 6,191.0 04:48 0506 112/2019 1/2/2019 0.10 PROD1 RPEQPT TRIP P PUH to catch GLM in CCL log 6,191.0 6,095.0 05:06 0512 1/2/2019 1/2/2019 0.30 1 PROD1 RPEQPT DLOG P Log CCL 6095 to 6475 6,095.0 6,475.0 05:12 05:30 1/2/2019 1/2/2019 0.50 PRODt RPEQPT DLOG P Corralale CCL Log, PUH 6,475.0 6,394.0 05:30 06:00 1/2/2019 1/2/2019 0.20 5R551 RPEQPT TRIP P RBIH to set depth 6,394.0 6,405.0 06:00 06:12 1/2/2019 1/2/2oT9 0.50 PROD1 RPEQPT TRIP -F- Shut down pump, take Gyro Survey 6,405.0 6,405.0 06:12 06:42 1/2/2019 1/2/2019 0.75 PRODt RPEQPT TRIP P No correction, move up hole 1.0', 6,405.0 6,404.0 06:42 07:27 shut down pump, take Gyro Survey, Gose EDC Survey's, 168.1°, 168.2°, and 167.8° 1/2/2019 1/2/2019 0.30 PROD1 RPEQPT WPST P Set NS HEW Whipstock, bring pump 6,404.0 6,404.0 07:27 07:45 up to 0.5 bpm catch fluid, continue pumping 0.5 bpm up to shear pressure 2,100 psi, set down 5.0k, 1/212019 1/2/2019 1.10 PROD1 RPEQPT TRIP 5 POOH, PJSM for BHA change 6,404.0 86.0 07:45 08:51 1/2/2019 1/2/2019 0.30 PROO1 RPEQPT PULD P At surface, check well for flow, well on 86.0 86.0 08:51 09:09 a vac. bring c -pump on line 2.4 bpm losses. 1/2/2019 1/2/2019 0.30 PROD1 RPEQPT PULD P Unstab INJH, stand back 86.0 0.0 09:09 09:27 ColiTrak/GyroTrak tools. LD setting tools 1/2/2019 1/2/2019 0.50 PROD1 WHRPST PULD P PU/MU milling BHA with Weatherford 0.0 89.3 09:27 09:57 1.0 fixed bend motor. 1/2/2019 1/2/2019 1.65 PROD'I WHPST TRIP P Tag up zero counters, RIH 89.3 6,140.0 09:57 11:36 1/22019 1/212019 0.20 PR651 WHPST DLOG P Log the HRZ, correction of minus 6,140.0 6,206.0 11:36 11:48 12.0', PUW 33 k 1/212019 1/22019 1.20 PROD1 WHPST TRIP P Continue IH, circulating 100 bbl High 6,206.0 6,380.0 11:48 13:00 vs Pill (148 k LSRV) 1/2/2019 1/2/2019 0.30 PROD1 WHPST CIRC P Continue pumping High Vs Pill 6,380.0 - 6,380.0 13:00 13:18 112/2019 1/2/2019 0.75 PROD1 WHPST TRIP P Shut down pump, take Gyro -Surveys, 6,380.0. 6,380.0 13:18 14:03 171.5°, 171.6', and 168.9°, satisfied with TF, RIH tag HEW @ 6,400' 1212019 1/2/2019 0.75 PROD1 WHPST TRIP P PUH 8.0', Take Gyro -Surveys, 161.4°, 6,380.0 6,399.8 14:03 14:48 173.2°, 171.4°, bring pump online, creep inhole to 6399.8' 112/2019 1/212019 5.10 PROD1 WHPST WPST P Start milling window 1.81 bpm @ 6,399.8 6,402.5 14:48 19:54 3,600 psi, Diff --915 psi, WHP=O, BHP=2,759. IA=O, OA=144 1/22019 1/212019 0.90 PROD1 WHPST WPST P Call bottom of window, Continue time 6,402.5 6,403.0 19:54 20:48 milling 1 foot for string reamer to ecit 12/2019 1/2/2019 1.10 PROD1 WHPST MILL P Mill rathole to 6426, 1.85 BPM @ 6,403.0 6,426.0 20:48 21:54 3300 PSI FS, BHP=2937 1/2/2019 1/2/2019 0.60 PROD1 WHPST REAM P Back ream up through window as 6,426.0 6,388.0 21:54 22:30 drilled. Shut down pump @ 6399'. Tahe gyro survey. Trio in 9 feet to check previous gyro survey - Good 1/22019 112/2019 0.30 PROD1 WHPST REAM P Ream down as drilled, 1.83 BPM @ 6,388.0 6,408.0 22:30 22:48 3237 PSI FS Page 2110 Report Printed: 1/2112019 Operations Summary (with Timelog Depths) 1 D-08 Ccnnocorndups Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Tine DiY fir)Plase Op CaOe ACAvity Code Time P-T.X operation Start Depth (fto) End Depth(WEI) 1/212019 1/2/2019 0.20 PROD1 WHPST REAM P 6408, Backream window 30R of as 6,408.0 6,399.0 22:48 23:00 drilled, PUW=33K 1/2/2019 1/2/2019 0.20 PROD1 WHPST REAM P Roll TF to as drilled, Ream down to 6,410.0 6,399.0 23:00 23:12 6410. Backream up at 30L of as drilled to 6410 1/2/2019 1/2/2019 0.40 PROD1 WHPST REAM P Roll TF to as drilled. ream down. 6,399.0 6,412.0 23:12 23:36 Orient to 180 of as drilled. Take gyro survey to confim toolface. Back ream up, PUW=32K 1/2/2019 1/2/2019 0.30 PROD? WHPST REAM P Back ream up, PUW=32K. 1.83 BPM 6,412.0 6,399.0 23:36 23:54 1/2/2019 1/3/2019 0.10 PR0D1 WHPST TRIP P Dry drift window clean. Tag TO to 6,399.0 6,426.0 23:54 00:00 confirm whipstock in place, Start -PR-0DWFHPST POOH 1/3/2019 1/3/2019 0.10 WPST P Stop at 6388, take gyro survey - Good 6,426.0 6,388.0 00:00 00:06 1/3/2019 1/3/2019 0.90 PROD1 WHPST TRIP P POOH for build section BHA #3 6,388.0 82.0 00:06 01:00 1/312019 1/3/2019 0.60 PROD1 WHPST PULD P PJSM. Flow check well. Lay down 82.0 0.0 01:00 01:36 BHA #2. Mill out @ 2.79 No Go. reamer out @ 2.79 No Go 1/3/2019 1/3/20 19 0.70 PROD1 DRILL PULD P PIU BHA #3 with 2.4°AKO motor 0.0 75.0 01:36 02:18 1/3/2019 1/3/2019 1.30 PROD1 DRILL TRIP 3 Trip in well, EDC closed. Pumping min 75.0 6,130.0 02:18 03:36 rate 1/32019 1/3/2019 0.20 PROD1 DRILL DLOG P Log HRZ for -11.5' 6,130.0 6,167.0 03:36 03:48 1/32019 1/3/2019 0.10 PROD1 DRILL TRIP P Continue in well 6,167.0 6,374.0 03:48 03:54 1/3/2019 1/32019 0.50 PROD1 DRILL DLOG P Stop for gyro survey, Get oriented to 6,374.0 6,424.0 03:54 04:24 171 degrees from true north, PUW=34K 1/3/2019 1/32019 0.60 PROD? DRILL TRIP P Continue in well, clean pass through 6,424.0 6,420.0 04:24 05:00 window, take weight @ 6424. PUH. RBIH to 6420'. take gyro TF survey. - PUH 10', RBIH to 6420 and resurvey 1/32019 1/3/2019 0.70 PRODt DRILL DRLG P Gyro shows 184' from true north. 6,420.0 6,454.0 05:00 05:42 Bring pumps online 1.82 BPM @ 3070 PSI FS, BHP=2882 1/3/2019 1/3/2019 0.50 PROD1 DRILL WPRT P BHA is held up in the window, minus 6,454.0 6,454.0 05:42 06:12 3.0 k, PUW 36 k 1132019 1/32019 0.80 PROD1 DRILL DRLG P OBD, 1.78 bpm at 2,633 psi, DiN=403 6,454.0 6,480.0 06:12 07:00 psi, WHP=O, BHP=2955, IA=O, OA=171 1/32019 1/3/2019 0.20 PROD1 DRILL WPRT P TD with Gyro tool 6,480', PUW 36 k, 6,480.0 6,379.0 07:00 07:12 PUH 1/3/2019 1/3/2019 0.20 PROD1 DRILL WPRT P Obtain check shot from GyroTrak to 6,379.0 6,379.0 07:12 07:24 confirm operational 1/3/2019 1/3/2019 1.30 PROD1 DRILL TRIP P POOH, w/no-rerums 6,379.0 75.0 07:24 08:42 1/3/2019 1/3/2019 0.30 PROD1 DRILL PULD P LD GyroTrak tools on a dead well 75.0 0.0 08:42 09:00 1/32019 1132019 0.70 PROD1 DRILL PULD P Adjust AKO on motor from 2.40° to 0.0 0.0 09:00 09:42 2.46° 1/3/2019 1/3/2019 0.60 PROD1 DRILL PULD P PU/MU standard build section BHA #4 0.0 72.2 09:42 10:18 1/3/2019 1/3/2019 1.20 PROD1 DRILL TRIP P RIH 72.2 6,130.0 10:18 11:30 1/3/2019 1/3/2019 0.20 PROD1 DRILL DLOG P Log the HRZ correction of minus 11.5' 6,130.0 6,183.9- 11:30 11:42 Page 3/10 Report Printed: 1121/2019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTime End Time Dur (hr) Phase Op code ily Ac Code Time P-T-% Dpenniam Depth Stan(ftlol) End Depth (ftKB) 1/3/2019 1/3/2019 0.20 PROD? DRILL TRIP P Close the EDC, PUW 33 k 6,183.6 6,183.0 11:42 11:54 1/3/2019 1/3/2019 0.10 PROD! DRILL TRIP P Continue IH through window clean 6,183.0 6,480.0 11:54 12:00 1/3/2019 1/3/2019 1.00 PROD1 DRILL DRLG P OBD, 1.88 bpm at 3,248 psi, Diff-403 6,480.0 6,580.0 12:00 13:00 psi, WHP=92, BHP=3,157, IA=O, OA=173 1/3/2019 1/3/2019 0.20 PROD1 DRILL WPRT P7- PUH, lower pump rate to 1.5 bpm to 6,580.0 6,580.0 13:00 13:12 1 1 attempt higher build rate. 1/3/2019 1/3/2019 3.00 PROD1 DRILL DRLG P BOBD, 1.51 bpm at 2,586 psi, 6,580.0 6,750.0 13:12 16:12 Diff-406, WHP=125, BHP=3,158, [A=O, OA=174 1/3/2019 1/3/2019 0.20 PROD1 DRILL WPRT P TD Build section, PUH for logging RA, 6,750.0 6,445.0 16:12 16:24 PUW 34 k 1/3/2019 1/3/2019 0.20 PROD1 DRILL WPRT P Shut down TF, 220" ROHS, log the 6,445.0 6,379.0 16:24 16:36 RA, marker scued by parent WB perfs, continue PUH 1/312019 1/3/2019 1.40 PRODt DRILL TRIP P Open EDC, Continue POOH 6,379.0 82.0 16:36 18:00 1/3/2019 1/312019 0.70 PROD1 DRILL PULD P At surface, flow check well, cew 82.0 82.0 18:00 18:42 change out 1/3/2019 1/3/2019 0.50 PR0D1 DRILL PULD P Unstab injector. Lay down motor, FVS, 82.0 0.0 18:42 19:12 and bit 1/3/2019 1/3/2019 1.50 PROD1 DRILL SVRG P Service reel, horse head Inc. counter. 0.0 0.0 19:12 20:42 Inspect injector. Pull choke B and Micro motion apart. Change out pack offs 1/3/2019 1/3/2019 1.00 PROD1 DRILL PULD P Dial motor to .5 and scribe. M/U BHA 0.0 78.2 20:42 21:42 #5 with agitator, USR, and Hycalog 3211 M-A2. Makeup to coil and surface test 1/312019 1/3/2019 1.30 PRODt DRILL TRIP P RIH BHA#5, Surface test agitator 2 78.2 6,130.0 21:42 23:00 1 470' 1/3/2019 1/3/2019 0.20 PROD1 DRILL DLOG P 6130'. Log HRZ for-11', PUW=33k, 6,130.0 6,185.0 23:00 23:12 RIW=24K 1/3/2019 1/312019 0.70 PRODt DRILL TRIP P Continue in well, Log RA and 3 nearby 6,185.0 6,750.0 23:12 23:54 spikes, continue in. Set down in build @ 6627, 6637, 6664, 6695, and 6717. Back ream up hole cleared up. Had to work 6746 down to EOB @ 6750 1/3/2019 1/4/2019 0.10 PROD? DRILL DRLG P 6750', Drill, 1.89 BPM @ 3974 PSI 6,750.0 6,754.0 23:54 00:00 FS, BHP=3246, RIW=17.2, DHWOB=2.8K 1/4/2019 1/4/2019 0.30 PROD1 DRILL DRLG P 6754', Drill. 1.9 BPM @ 3974 PSI FS, 6,754.0 6,770.0 00:00 00:18 BHP=3256, Choke closed 1/4/2019 1/4/2019 0.10 PROD1 DRILL WPRT P 6770', BHA wiper to check weights 6,770.0 6,770.0 00:18 00:24 and pressures, PUw=34K 1/4/2019 114/2019 0.80 PROD1 DRILL DRLG P 67701, Drill, 1.9 BPM @ 3924 PSI FS, 6,770.0 6,839.0 00:24 01:12 BHP=3290 114/2019 1/4/2019 0.10 PROD1 DRILL WPRT P 6839', BHA wiper, PUW=33K 6,839.0 6,839.0 01:12 01:18 1/4/2019 1/4/2019 0.30 PROD1 DRILL DRLG P 6839', Drill, 1.9 BPM @ 3924 PSI FS, 6,839.0 6,863.0 01:18 01:36 BHP=3358 1/4/2019 1/4/2019 1.30 PROD1 DRILL TRIP T 6863 tool not responding to inputs. 6,863.0 6,455.0 01:36 02:54 Tool face at 9OR going left. Pressures normal, Check shots within tolerance. DD recommends tripping for inspection 1/4/2019 1/4/2019 0.20 PROD1 DRILL PULD T POOH, At surface, Flow check well 6,455.0 84.5 02:54 03:06 Page 4/10 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Erb Tim Dix (h0 Phew OP Code Activity Code rme P -T -X Operation Start Depm (W) End Depth (M®) 1!412019 1/4/2019 0.60 PRODt DRILL PULD T Unstab injector, Back off quick 84.5 0.0 03:06 03:42 connect. Inspect BHA. Motor OK. Bit out 1-1. Put motor on bench and increase AKO setting. Double check all scribes. Tool out on scribe 1!4/2019 1/4/2019 0.60 PROD1 DRILL PULD T PIU BHA #6 with .59° motor, Make up 0.0 78.2 03:42 04:18 to coil and surface lest 1/4/2019 114/2019 1.30 PROD1 DRILL TRIP T RIHBHA#6 78.2 6,130.0 04:18 05:36 19 1/412019 0.20 PRODt DRILL DLOG T Log the HRZ correction of minus 12.0' 6,130.0 6,175.0 05:36 05:36 --/4/2019 05:48 1/4!2019 1.20 PROD1 DRILL TRIP T Continue IH, setting multiple set 6,175.0 6,863.0 05:48 07:00 downs, work pipe to bottom from 6,765'to 6,863' 1/4/2019 1/4/2019 1.00 PRO1)1 DRILL DRUG P OBD, 1.88 bpm at 4,163 psi, Diff=890 6,863.0 6,913.0 07:00 08:00 psi, WHP=346, BHP=3,330, IA=O, OA=179 1/4/2019 1/4/2019 0.25 PROD1 DRILL WPRT P Geo/DD Wiper up hole, PUW 33 k, 6,913.0 6,913.0 06:00 08:15 1 RBIH 1/4/2019 1/4/2019 0.75 PROD1 DRILL DRLG P BOBD, 1.87 bpm at 4,025 psi, 6,913.0 6,971.0 08:15 09:00 Diff=890 psi, WHP=306, BHP=3,295, IA=O, OA=179 1/4/2019 1/4/2019 0.20 PRODt DRILL WPRT P BHA wiper up hole, PUW 35 k 6,971.0 6,971.0 09:00 09:12 1/412019 1/4/2019 3.20 PR0D1 DRILL DRLG P BOBD, 1.87 bpm at 4,078 psi, 6,971.0 7,260.0 09:12 12:24 Diff -890 psi, WHP=306, BHP=3,457, IA=O, OA=179 1!4/2019 1/4/2019 0.25 PROW DRILL WPRT P Wiper to the EOB 6,750', PUW 39-k 7,260.0 6,750.0 12:24 12:39 1/4/2019 1/4/2019 0.30 PROW DRILL WPRT P Wiper back in hole, RIW 18 k 6,750.0 7,260.0 12:39 12:57 1/4/2019 1/4/2019 0.75 PROD1 DRILL DRLG P BOBD, 1.88 bpm at 4,350 psi, 7,260.0 7,342.0 12:57 13:42 Diff --890 psi, WHP=306, BHP=3,717, IA=O, OA=179 1/4/2019 1/4/2019 0.15 PROD1 DRILL WPRT P Geo/DD wiper up hole, PUW 34 k 7,342.0 7,342.0 13:42 13:51 1/4/2019 1/412019 2.75 PR551 DRILL DRLG P BOBD, 1.88 bpm at 4,303 psi, 7,342.0 7,650.0 13:51 16:36 Diff -740 psi, WHP=324, BHP=3,316, IA=O, OA=179 1/4/2019 1/412019 0.60 PR0D1 DRILL WPRT P Wiper to the window, PUW35k 7,650.0 6,410.0 16:36 17:12 1/4/2019 17:24 9 0.20 PRODt DRILL DLOG P Log the 3 peaks correction of 6,410.0 6,444.0 17:12 17:24 1/4/2019 1/412019 0.60 PROD1 DRILL WPRT P Wiper back to bottom. tight spots 7367 6,444.0 7,650.0 17:24 18:00 through 7400 1/4/2019 1/4/2019 1.40 PROW DRILL DRLG P 7650', Drill, 1.9 BPM @ 4103 PSI FS, 7,650.0 7,646.0 18:00 19:24 BHP=3397, RIW=14.9K, DHWOB=3.3K 1/4/2019 1/4/2019 0.20 PROD1 DRILL WPRT P 7846, Stall, BHA Wiper, PUW=39K 7,846.0 7,846.0 19:24 19:36 1/4/2019 1/4/2019 2.50 PROD1 DRILL DRLG P 7846', Drill, 1.9 BPM @41T8 PSI FS, 7,846.0 8,025.0 19:36 22:06 BHP=3443 1/4/2019 1/412019 0.60 PROD1 i DRILL WPRT P 8025', Wiper to EOB with sweeps, 8,025.0 8,025.0 22:06 - 22:42 PUW=37K, tight area 7365 to 7400 1/4/2019 1/5/2019 1.30 PRODt DRILL DRLG P 8025', drill, 1.88 BPM @ 4258 PSI FS, 8,025.0 8,076.0 22:42 00:00 BHP=3291 1/512019 1/5/2019 0.90 PR531 DRILL DRLG P 8076', Drill, 1.88 BPM @ 3966 PSI 8,076.0 8,163.0 00:00 00:54 FS, BHP=3966, RIW=I3.OK, DHWOB=I.9K WHP=326 1!5/2019 1/5/2019 0.10 PROW DRILL WPRT P Pull BHA wiper, PUW=37K 8,163.0 8,163.0 00:54 01:00 Page 5110 Report Printed: 1/2112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Smit Time End Tina Dw(m) Phase Op Cotle Activity Code Time P -T -X Operation Stat Depth (ftKa) End Depth(Po(B) 1/5/2019 1/5/2019 1.70 PRODt DRILL DRLG P 8163', Drill 1.87 BPM @4079 PSI FS, 8,163.0 8,323.0 01:00 02:42 BHP=3358 1/5/2019 1/5/2019 0.10 PROD1 DRILL WPRT P BHA Wiper, PUW=37K 8,323.0 8,323.0 02:42 02:48 1/5/2019 1/5/2019 1.10 PROD1 DRILL DRLG P 8323', Drill, 1.88 BPM @ 4061 PSI 8,323.0 8,425.0 02:48 03:54 FS, BHP=3346 PSI 1/5/2019 1/5/2019 0.70 PROD1 DRILL WPRT P 8425', Wiper to 7625 with sweeps, 8,425.0 8,425.0 03:54 04:36 1 1 1 PUW=36K 1/5/2019 1/5/2019 4.00 PRODt DRILL DRLG P 8425', Drill, 1.88 BPM @ 4091 PSI 8,425.0 8,825.0 04:36 08:36 FS, BHP=3347 115/2019 1/5/2019 1.00 PROD1 DRILL WPRT P Wiper up to the window, 35 k 8,825.0 6,410.0 08:36 09:36 1/5/2019 1/5/2019 0.20 PRODt DRILL DLOG P Log the RA Peaks, correction of plus 6,410.0 6,465.0 09:36 09:48 1,01 1/5/2019 1/5/2019 1.00 PROD? DRILL WPRT P Wiper back in hole, RIW 2Tk 6,465.0 8,825.0 09:48 10:48 1/5/2019 1/5/20191.60 PROD1 DRILL DRLG P BOBD, 1.85 bpm at 3,492 psi, 8,825.0 8,891.0 10:48 12:24 Diff --878, WHP=180, BHP=3,189, IA=O, OA=180 1/5/2019 1/5/2019 0.50 PROD1 DRILL DRLG P Hard spot, Heavy pickup 65 k, work to 8,891.0 8,891.0 1224 12:54 drill ahead, phone town engineer 1/5/2019 1/5/2019 1.80 PROD1 DRILL DRLG P OBD, 1.89 bpm at 3,313 psi, -Diff-606 8,891.0 8,913.0 12:54 14:42 psi, WHP=O, BHP=2,793, IA=O, OA=179 1/5/2019 1/5/2019 0.50 PROD1 DRILL WPRT P Town engineer called TD, pump TD 8,913.0 8,913.0 14:42 15:12 sweep 1/5/2019 1/5/2019 1.00 PROD1 DRILL WPRT P Wiper up hole to the window 6,100' 8,913.0 6,130.0 15:12 16:12 1/5/2019 1/5/2019 0.30 PR0D1 DRILL DLOG P Log the HRZ correction of plus 1.5' 6,130.0 6,154.0 16:12 16:30 1/5/2019 1/5/2019 0.20 PRODt DRILL WPRT P RBIH 6,154.0 6,900.0 16:30 16:42 1/5/2019 1/5/2019 0.20 PROM DRILL WPRT P PUH for static pressure survey 6,900.0 6,379.8 16:42 16:54 1/5/2019 1/5/2019 0.30 FROM DRILL WPRT P Perform static pressure survey, 6,379.8 6,379.8 16:54 17:12 6329.67 TVD Sesor, Annular P EMW 1 min 2,786 psi 8.47 ppg 5 min 2,770 psi 8.42 ppg 10 min 2,768 psi 8.41 ppg 15 min 2,768 psi 8.41 ppg 1/5/2019 1/5/2019 1.40 PROD1 DRILL WPRT P RIH to confirm TD, Tight spos 6912, 6,379.8 8,912.0 17:12 18:36 7400, 7960, and 7973 1/5/2019 1/52019 0.40 PROD1 ff R I FLL WPRT P Tag Corrected TD @ 8912'. PUH 8,912.0 8,912.0 18:36 19:00 1 waiting on beaded liner running pill 1/5/2019 1/5/2019 2.10 PROD1 DRILL TRIP P Trip out pumping beaded liner running 8,912.0 86.0 19:00 21:06 pill 50 BBIs, Paint flags @ 6508 and 3878 1/5/2019 1/512019 0.50 PROD1 DRILL OWFF P At surface, Flow check well, PJSM 86.0 86.0 21:06 21:36 1/5/2019 1/5/2019 0.70 PROD1 DRILL PULD P Unstab injector, Lay down BHA# 6 on 86.0 0.0 21:36 22:18 dead well 1/5/2019 1/5/2019 0.70 COMPZI CASING RUR- P Prep floor to run liner 0.0 0.0 22:18 23:00 1/5/2019 1/62019 1.00 COMPZ1 CASING PUTB P PIU BHA#7 with non pried bullnore, 2 0.0 300.0 23:00 00:00 As blank liner, 78 Jts slotted 2 3/8" liner, 3.63' pup, and 9' liner top billet. Perform Kick while running liner after 6 joints in hole. 1/6/2019 1/6/2019 2.90 COMPZI CASING PUTB P Continue picking up L1 completion 300.0 2,432.8 00:00 02:54 Page 6/10 Report Printed: 1121/2019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stant Depth SWTime End Tana our(hr) Phase Op Code Activity Code Time P -T -X Operation (Me) End Depth (WS) 1/6/2019 1/6/2019 0.80 COMPZ1 CASING PULD P PIU coiltrak M/U to completion. Set 2,432.8 2,477.0 02:54 03:42 pipe slips. M/U to coil and surface test. Change out pack offs and floats in UQC 116/2019 1/6/2019 2.00 COMPZI CASING TRIP P RIH BHA#7 L1 completion. EDC 2,477.0 8,912.0 03:42 05:42 Closed. Correct -7.7' correction @ 3800' EOP flag 1/6/2019 1/6/2019 1.00 COMPZI CASING TRIP P Work pipe to bottom from 8,831', TD 8,912.0 6,390.0 05:42 06:42 Flag 5.0' from horse head, Liner on bottom, line up down the coil, bring pump up 1.89 bpm at 3,700 psi, Diff -1,200 psi, PUW 32 K. Stop and remove liner length from counters, PUH above window, 34 k pulling up through window 116/2019 1/6/2019 0.25 COMPZI CASING TRIP P POOH 6,390.0 6,110.0 06:42 06:57 1/6/2019 1/6/2019 0.20 COMPZI CASING DLOG P Log HRZ correction of+2.5' 6,110.0 6,148.0 06:57 07:09 1/6/2019 1/6/2019 1.00 COMPZI CASING TRIP P Continue POOH 6,148.0 44.2 07:09 08:09 1/6/2019 1/6/2019 0.50 COMPZ'I CASING PULD P At surface, Check well for flow (pass), 44.2 44.2 08:09 08:39 6 bbVhr loss rate - Note: Inspect Coil 0.124inch flat spot @ 8.0' up from CTC 1/6/2019 1/612019 0.25 COMPZI CASING PULD P LD setting tools 44.2 0.0 08:39 08:54 1/6/2019 1/6/2019 1.25 PROD2 STK PULD P PU/MU Ll -01 Build Assembly, Load 0.0 62.6 08:54 10:09 BHI database 1/8/2019 1/6/2019 1.30 PROD2 STK TRIP P RIH, w/Kickoff-Drilling BHA #8, 2.5° 62.6 6,125.0 10:09 11:27 motor and RB bi-center bit 1/6/2019 1/6/2019 0.20 PROD2 STK DLOG P Log the HRZ correction of -10' 6,125.0 6,138.0 11:27 11:39 1/6/2019 1/6/2019 0.30 PROD2 STK TRIP P Continue IH, tag TOB @ 6,474' 6,138.0 6,474.0 11:39 11:57 1/6/2019 1/6/2019 1.50 PROD2 STK KOST P PUH, 32 k, 1.89 bpm at 3,247 psi, 6,474.0 6,477.0 11:57 13:27 Diff --478 psi, WHP=228, BHP=3,168, IA=O, OA=172, time milled 1.0'@ tfph, 2.0' @ 2 fph, and 3.0' @ 3 fph, 1/6/2019 1/6/2019 0.75 PROD2 DRILL DRLG P Increased controlled drilling to 15-20 6,477.0 6,490.0 13:27 14:12 fph, then 20-30 fph, 1/6/2019 1/6/2019 2.10 PROD2 DRILL DRLG P Drill ahead @ 1.89 bpm at 3,152 psi, 6,490.0 6,578.0 14:12 16:18 Diff -428 psi, WHP=190, BHP=3,128, IA=O, OA=176 1/6/2019 1/6/2019 0.15 PROD2 DRILL WPRT P PUH PUW 32 k, Dry drift KOP (clean) 6,578.0 6,450.0 16:18 16:27 1/6/2019 1/6/2019 0.15 PROD2 DRILL WPRT P RBIH 6,450.0 6,578.0 16:27 16:36 1/6/2019 1/6/2019 4.40 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 3,123 psi, 6,578.0 6,717.0 16:36 21:00 Diff --527 psi, WHP=60, BHP=3,100, IA=O, OA=178, At 6622 lower pump rate for DLS, 1.52 BPM @ 2335 PSI FS, BHP=3150 1/612019 1/6/2019 0.10 PROD2 DRILL WPRT P 6717, BHA wiper, PUW=34. Raise 6,717.0 6,717.0 21:00 21:06 pump rate back to 1.88 BPM 1/6/2019 1/6/2019 2.00 PROD2 DRILL DRLG P 6717', Drill, 1.88 BPM @ 3151 PSI 6,717.0 6,855.0 21:06 23:06 1 1 1 1 1 1 FS, BHP=3193 1/6/2019 1/7/2019 0.90 PROD2 DRILL TRIP P 6855'• Call end of build, Avg DLS= XX, 6,855.0 2,095.0 23:06 00:00 1 I Trip for lateral BHA 117/2019 1/7/2019 0.50 PROD2 DRILL TRIP P Continue trip out of well 2,095.0 78.0 00:00 00:30 i I Page 7110 Report Printed: 112112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code AcUvily Code Time P -T -X Operation (ftl(B) End Depth (111](8) 1/7/2019 1/7/2019 0.60 PROD2 DRILL PULD P Flow check well, PJSM Unstab 78.0 0.0 00:30 01:06 injector. UT CT, Min wall thickness .116. PJSM lay down BHA #8 11712019 1/7/2019 1.00 PROD2 DRILL PULD P PIU BHA #9 with .5° AKO motor, 0.0 80.3 01:06 02:06 Strider and HCC TX25207 bi center. Make up to coil and surface test. Check packoffs, 1/7/2019 1/72019 1.40 PROD2 DRILL TRIP P Trip in hole, Test strider @ 550'. 80.3 6,130.0 02:06 03:30 Continue in well. 1/7/2019 1/7/2019 0.20 PROD2 DRILL DLOG P Log HRZfor-11', PUW=22K 6,130.0 6,185.0 03:30 03:42 117/2019 1/7/2019 1.00 PROD2 DRILL TRIP P Continue in well, Clean pass through 6,185.0 6,855.0 03:42 04:42 window and past billet. Stacking @ 6823 Hard to get started @ 6855. Stacking out 11712019 1/72019 3.80 PROD2 DRILL DRLG P 6855', Drill, 1.9 BPM @ 3460 PSI FS, 6,855.0 7,015.0 04:42 08:30 BHP=3212, WHP=223, RIW=19.7K, DHWOB=2.4K 1/7/2019 1/7/2019 0.10 PROD2 DRILL WPRT P Stall motor, PUW 35 k, restart 7;015.0 7,015.0 08:30 08:36 1/7/2019 1/7/2019 1.80 PROD2 DRILL DRLG P BOBD, 1.9 bpm at 3,296 psi, Diff --511, 7,015.0 7,223.0 08:36 10:24 WHP=153, BHP=3,172, IA=O, OA=170 117/2019 117/2019 0.10 PROD2 DRILL WPRT P Stall motor, PUW 36 k, restart 7,223.0 7,223.0 10:24 10:30 1!7/2019 1/72019 0.20 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 3,296 psi, 7,223.0 7,255.0 10:30 10:42 Diff --508, WHP=136, BHP=3,171, IA=O, 0A=1 70 117/2019 1!72019 0.30 PROD2 DRILL WPRT P Wiper up hole, PUW 36 k 7,255.0 6,855.0 10:42 11:00 177/2019 117/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole to 6,588', RIW 20 k 6,855.0 7,255.0 11:00 11:18 1/72019 1!7/2019 4.30 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 3,296 psi, 7,255.0 7,655.0 11:18 15:36 Diff --508, WHP=136, BHP=3,171, IA=O, OA=170 117/2019 1/7/2019 0.50 PROD2 DRILL WPRT P Wiper up hole to the EOB, PUW 33 it 7,655.0 6,855.0 15:36 16:06 177/2019 1/7/2019 0.30 PROD2 DRILL WPRT P Wiper back in hole to 6,588', RIW 20 k 6,855.0 7,655.0 16:06 16:24 117/2019 1/7/2019 4.70 PROD2 DRILL DRLG P BOBD, 1.89 bpm at 3,400 psi, 7,655.0 8,050.0 16:24 21:06 Diff --690, WHP=136, BHP=3,171, IA=O, 0A=1 79, stall motor 7,963' and 7,972' 1/7/2019 117/2019 0.70 PROD2 DRILL WPRT P Wiper up hole, PUW 33 k 8,050.0 6,130.0 21:06 21:48 117/2019 1/7/2019 0.20 PROD2 DRILL DLOG P RBIH, Log the HRZ correction of plus 6,130.0 6,198.0 21:48 22:00 1 0.5' 1/7/2019 1/7/2019 0.80 PROD2 DRILL WPRT P Wiper back in hole, RIW 20 k, 6,198.0 8,050.0 22:00 22:48 '•* Note: Bobble @ 7,860' 1/7/2019 1/7/2019 0.70 PROD2 DRILL DRLG P BOBD, 1.88 bpm at 3,400 psi, 8,050.0 8,099.0 22:48 23:30 Diff -672, WHP=95, BHP=3228, IA=O, OA=167 1/7/2019 117/2019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=39K 8,099.0 8,099.0 23:30 23:36 11712019 1/8/2019 0.40 PROD2 DRILL DRLG P 8099', Drill, 1.86 BPM @ 3433 PSI 8,099.0 8,125.0 23:36 00:00 FS, BHP=3250. RIW=18K, DHWOB=I.8K 1/8/2019 1/8/2019 2.80 PROD2 DRILL DRLG P 8125', Drill 1.86 BPM @ 3433 PSI FS, 8,125.0 8,450.0 0000 0248 1 1 BHP=3256 Page 8/10 Report Printed: 1/21/2019 „ Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depsn Start Torre End7M W (III) Phase op code Ac i ' Code My 11me P -T- X OpereOmt J3) (8Xe) End Depth (fIKB) 1/8/2019 1/8/2019 0.60 PROD2 DRILL WPRT P Wiper to 7650 with sweeps, 8,450.0 8,450.0 02:48 03:24 PUW=37K, Clean trip up and down 1/8/2019 1/8/2019 2.60 PROD2 DRILL DRLG P 8450', Drill, 1.9 BPM @ 3671 PSI FS, 8,450.0 8,590.0 03:24 06:00 BHP=3327, RIW=12K, DHWOB=2.8K 1/8/2019 1/8/2019 0.10 PROD2 DRILL WPRT P 8590', BHAwiper, PUW=39K 8,590.0 8,590.0 06:00 06:06 1/8/2019 1/8/2019 3.30 PROD2 DRILL DRLG P 8590', Drill, 1.9 BPM @ 3507 PSI FS, 8,590.0 8,850.0 06:06 09:24 BHP=3298, RIW=13.9K, DHWOB=I.9K 118/2019 1/8/2019 0.70 PROD2 DRILL WPRT P Wiper to 8000', PUW=38K 8,850.0 8,850.0 09:24 10:06 1/8/2019 1/8/2019 1.70 PROD2 DRILL DRLG P 8850', Drill, 1.89 BPM @ 3540 PSI 8,850.0 9,036.0 10:06 11:48 FS, BHP=3322 1/8/2019 1/812019 0.10 PROM DRILL WPRT P 9036, Pull BHAwiper, 100', PUW=38K 9,036.0 9,036.0 11:48 11:54 1/8/2019 1/8/2019 1.30 PROD2 DRILL DRLG P 9036', Drill, 1.89 BPM @ 3540 PSI 9,036.0 9,141.0 11:54 13:12 FS, BHP=3327 1/8/2019 1/8/2019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=40K 9,141.0 9,141.0 13:12 13:18 1/8/2019 1/8/2019 3.20 PROD2 DRILL DRLG P 9141', Drill, 1.89 BPM @ 3595 PSI 9,141.0 9,250.0 13:18 16:30 FS, BHP=3361 1/8/2019 1/8/2019 1.30 PROD2 DRILL WPRT P 9250', PUW=40K, wiper to TT with tie 9,250.0 6,140.0 16:30 17:48 into HRZ to +0.5 correction, 1/8/2019 1/8/2019 1.50 PROD2 DRILL WPRT P RBIH, RIW = 13K 6,140.0 9,250.0 17:48 19:18 1/8/2019 1/8/2019 3.50 PROD2 DRILL DRLG P Drilling, FS = 683 75 psi @ 1.8 bpm, 9,250.0 9,436.0 19:18 22:48 CWT =5.2K, WOB =1.I K, BHP= 3358 psi, WHIP = 192 psi, circ = 3732 psi 1/8/2019 1/9/2019 1.20 PROD2 DRILL DRLG P Drilling, CWT = 1.6K, WOB = 1.4K, 9,436.0 9,469.0 22:48 00:00 BHP = 3386 psi, WHP = 210 psi, circ = 3796 psi, pump 1 0x1 0 sweeps, drilled to midnight depth of 1/9/2019 1/912019 0.50 PROD2 DRILL DRLG P Drilling, CWT =4.3K, WOB =.4K, drill 9,436.0 9,480.0 00:00 00:30 to planned TD of 9480' 1/9/2019 1/9/2019 1.20 PROD2 DRILL WPRT P Wiper to tubing tail, PUW = 40K, slight 9,480.0 6,130.0 00:30 01:42 negative WOB pull at 6760' 1/9/2019 1/9/2019 0.30 PROD2 DRILL DLOG P Log HRZ for +1'correction, RIH to 6,130.0 6,390.0 01:42 02:00 1 1 window 1/9/2019 1192019 0.60 PROD2 DRILL CLOG P Confirm 8.6 ppg kills well 6,390.0 6,390.0 02:00 02:36 Pumps off, MD -bit = 6390', TVD sensor 6337.9', Annular = 2803, EMW = 8.5 ppg, increase MW by 1/10 ppg to 8.8 ppg, PUW = 33K 1/9/2019 1192019 1.40 PROD2 DRILL WPRT P RIH, confirm TD at 9480', PUW = 40K 6,390.0 9,480.0 02:36 04:00 1/9/2019 1/9/2019 2.60 PROD2 DRILL TRIP P Lay in LRP (50 bbl), follow by DuoVis 9,480.0 78.0 04:00 06:36 to surface pumping pipe displacement (8.8 ppg) Paint EOP flags at 6360'& 3180' 1/9/2019 1/9/2019 1.50 PROD2 DRILL PULD P Flow check, LD BHA #9 78.0 0.0 06:36 08:06 1/9/2019 1192019 0.50 PROM DRILL BOPE P Perform BOPE function test 0.0 0.0 08:06 08:36 1/9/2o19 1/9/2019 0.50 COMPZ2 CASING RURD P Prep floor to run liner, UT CT check 0.0 0.0 08:36 09:06 flatspots 1/9/2019 1/9/2019 4.00 COMPZ2 CASING PUTB P PJSM, P11.1BHA#10 Li -01 completion 0.0 3,160.5 09:06 13:06 with non ported bullnose, 104 Jts slotted 2 3/8" liner, 11.89' Pup, and shorty deployment sleeve Page 9110 ReportPrinted: 1/2112019 Operations Summary (with Timelog Depths) 1 D-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time Dur(nh Phase Op Code Activity coda lime P -T -X Operator, $tart Depth (Wtl) End Depth(Itika) 1/9/2019 1/9/2019 0.30 COMPZ2 CASING RURD P R/D tubing longs, Rig up little jerks. 3,160.5 3,160.5 13:06 1324 Make up pup joint ontop of liner 1/9/2019 1/9/2019 1.00 COMPZ2 CASING PULD P Skid injector to floor, change out floats 3,160.5 3,204.7 13:24 14:24 in UQC, Check packoffs. M/U coiltrack to coil and surface test. Tag up to stripper and set depths 1/9/2019 1/9/2019 0.80 COMPZ2 CASING TRIP P RIH BHA#10 3,204.7 6,317.0 14:24 15:12 1/9/2019 1/9/2019 0.10 COMPZ2 CASING DLOG P Correct to EOP flag to -12.8, 6,317.0 6,304.0 15:12 15:18 PUW=50K 1/9/2019 1/9/2019 1.00 COMPZ2 CASING TRIP P Continue in well, clean trip to TO @ 6,304.0 9,480.0 15:18 16:18 9480, PUW=50K. Set back down. Pumps on 1.5 BPM Release from liner. PUW=32K 1/9/2019 1/9/2019 0.10 COMPZ2 CASING TRIP P PUH remove liner length ledt in hole 9,480.0 6,299.0 16:18 16:24 from counter 1/9/2019 1/9/2019 0.50 COMPZ2 CASING SIPB P Stop, Perform static pressure test 6,299.0 6,299.0 16:24 16:54 Sensor TVD=6178', BHP=2784 PSI after 30 min 1/9/2019 1/9/2019 1.10 DEMOB WHDBOP TRIP P Trip out of well 6,299.0 42.0 16:54 18:00 1/912019 1/9/2019 0.90 DEMOB WHDBOP PULD P Flow check, PJSM, LD BHA #10 42.0 0.0 18:00 18:54 1/9/2019 1/9/2019 0.90 DEMOB WHDBOP DISP P MU nozzle, bullhead seawater to 0.0 0.0 18:54 19:48 window, 2 bpm 1/912019 1/9/2019 0.60 DEMOB WHDBOP FRZP - PJSM w/ LRS, bullhead 30 bbl diesel 0.0 0.0 19:48 20:24 freeze -protect, 1 bpm 1/9/2019 1/9/2019 1.50 DEMOB WHDBOP CIRC P Jet stack, clear floor, PJSM 0.0 0.0 20:24 21:54 1/9/2019 1/9/2019 1.10 DEMOB WHDBOP MPSP P RU lubricator, set BPV, RD lubricator, 0.0 0.0 21:54 23:00 clear floor Note: 215 psi below master valve 1/912019 1/10/2019 1.00 DEMOB WHDBOP RURD P Blow down surface lines, boro-scope 0.0 0.0 23:00 00:00 stack, work RD checklist 1/10/2019 1/10/2019 2.00 DEMOB WHDBOP NUND P Suck out stack, lock -out koomey, 0.0 0.0 00:00 02:00 continue RD checklist, NO BOP Rig Released 1/10119 (� 2:00 AM Page 10110 ReportPrinted: 112 112 01 9 M LC) C) r - C, c� X _N O b O n N n 8 w 6 m E w 9 OVi N a�¢ C O 9 n� TV FE i s THE STAR GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 • Alaska Oil and Gas $CARM DE; 2b ?0! Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 D-08 Permit to Drill Number: 177-053 Sundry Number: 318-575 Dear Mr. Ohlinger: Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 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, Hollis S. French Chair DATED this day of December, 2018. RBDMSi DEC 2 12018 • ; 1 J -q-y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ :6p�i `stT&8Yiwn ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Whipstock_❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development Q ' Stratigraphic ❑ Service ❑ 177-053 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-20266-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1D-08 ' Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25650 Kuparuk River 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): 6880 6879 6550 6549 3033 6550 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 52' 16" 75' 75' Surface 2207' 10-3/4" 2230' 2230' Intermediate Production 6847' 7" 6869' 6868' Liner 6276' 5-1/2" 6295' 6294' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6384-6472,6479-6484,6636- 6383-6471,6478-6483,6635- 6641, 6644-6652 6640, 6643-6651 3-1/2" L-80 6123' Packers and SSSV Type: Baker FB -1 Permanent Packer Packers and SSSV MD (ft) and TVD (ft): 6294 MD / 6292 TVD 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: 1/2/2019 OIL E 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: William Long Authorized Title: Staff CTD Engineer Contact Email: William. R. Lon COP.com /,2/� 111$, Contact Phone: 263-4372 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: i-, � - S 19 Plug Integrity ❑ BOP Test � Mechanical Integrity Test ❑ Location Clearance ❑ Other: c'J p 7-fs U .j ,j -,,I �rvr�Lvl a !p rt v -)t 7- r� QTS 7�— " Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: lZ Z1 T fo1IN`A°L.00 \Form 10-403 Revised 4/2017 Approved applicato� n li the date of Submit Form and Dwt8cfintnfj wuplicafe ��vvww f� 7--Zt-elf ✓ 0 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 20, 2018 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 to set a whipstock and applications for permits to drill two laterals out of the KRU 1 D-08 (PTD# 177-053) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in January 2019. The objective will be to drill two laterals KRU 1 D-081_1 and 1 D -08L1-01 targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry application are the following documents: — 10-403 Sundry Application for KRU 1 D-08 — Operations Summary in support of the 10-403 sundry application — Proposed CTD Schematic — Current Well Bore Schematic Attached to permit to drill applications are the following documents: — Permit to Drill Application Forms (10-401) for 1D-081_1 and 1D-081_1-01 — Detailed Summary of Operations — Directional Plans for 1 D-081_1 and 1 D-081_1-01 — Current wellbore schematic — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 1 D-08 PTD #10-053)CTD Summa for Sun ( Summary ry Summary of Operations: KRU well 1 D-08 is a Kuparuk C Sand producer equipped with 3-1/2" tubing, 7" production casing, and a 5" tieback liner. The CTD sidetrack will utilize two laterals to target the C -sands to the northeast and southwest of 1 D-08. The laterals will improve recovery and target resource not produced by the existing wellbore. CDR3-AC will set a high expansion wedge, a type of whipstock, in the 7" casing. A window will be milled in the production casing that the L1 lateral will be drilled out of. The lateral will be completed with 2-3/8" slotted liner from TD up to the L1-01 lateral kick off point with an aluminum billet for kicking off. The L1-01 lateral will be kicked off from the L1 lateral and drilled to TD. It will be completed with 2-3/8" slotted liner from TD to inside of the window. CTD Drill and Complete 1 D-08 Laterals: Pre -CTD Work 1. RU Slick -line: Conduct dummy whipstock drift. Install new gas lift design. 2. RU Service Coil: Mill out "D" nipple. 3. RU E -line: Caliper 7" casing and 3-1/2" tubing. 4. Prep site for Nabors CDR3-AC. r5 Rig Work 1. MIRU Nabors CDR3-AC rig using 2 coil tubing. NU 7-1/16 BOPE, test. �J 2. 1 D-081_1 Lateral s a. Set high expansion wedge at 6420' MD. b. Mill 2.80" window at 6420' MD. -- - c. Drill 3" bi-center lateral to TD of 9300' MD. d. Run 2-3/8" slotted liner with an aluminum billet from TD up to 6666' MD. 3. 1D-081-1-01 Lateral a. Kickoff the aluminum billet at 6666' MD. t2�w b. Drill 3" bi-center lateral to TD of 9700' MD. c. Run 2-3/8" slotted liner from TD to inside the window. 4. Freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Return to production Page 1 of 1 12/20/2018 113-08 Proposed Completion 16" 65# H-40 shoe @ 75' RKB 10-3/4" 45# K-55 shoe @ 2230' RKB JKOP @ 6420' MD C -sand perfs 6384'-6472' 6479'-6484' 7" 26# J-55 shoe @ 6869' RKB 3-1/2" Tubing L-80 w/ IBT 3-1/2" Landing DS Nipple @ 493' RKB (2.875" ID) 3-1/2" Camco KBG Mandrels @ 2541', 3786', 4688', 5335', 5798', 6012' 5" Seal Bore Receptacle w/ 4" bore @ 6110' RKB 5"x3-1/2" Crossover @ 6129' RKB Camco DS Landing Nipple @ 6175' RKB (ID 2.813") Camco GLM @ 6227' RKB Baker GBH -22 Locator @ 6283' RKB Baker 80-40 Seal Assembly @ 6284' RKB Baker FB -1 Packer @ 6294' RKB Baker SBE @ 6296' RKB Camco D Nipple @ 6326'(2.75" ID) Baker WLEG @ 6337' RKB 7" Cast Iron Bridge Plug (6550' RKB) 11D-081-1-01 TD @ 9,700' MD Top of Liner @ 6320' MD ------------------- 1 D -08L1 TD @ 9,300' MD ---- Top of Aluminum Billet @ 6666' MD • 4111 et, Ln _ r o,'.W N T om a, 'o v Y O E t— O U Y E > p - N co co c ° a0+ O v a` ° v c c CI-9 O a 0 Q 0 O• J W O coo CO r r r r ' CU 0 6 m W t) r r .- E - z -o ° v1 Q y y C C C C L -° ++ L. v, �, z:-.2 0 0 oz co to to ? 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IR�7 4,toO 0) N N CO N N O N - O O O COM E IN a N N N N N N N V1 S •L n ._Q. 0) 0) M 0) an o) 0) C 0 a N N O N N N N 01 O O O O O O L.CD O U pp N u) O v) N v) Y +' 0 0 C .� d 0u l0 F E v m • a C Z sc QQ u, z .- E E v a`Ji Q o v co ro ~ 61 e-1 O r co M O M a+ a1 C Y Y 9 Z ,� S z N M N O O +.. N au cu iyeq = 2 vi. Q O `+ W O N 0 N M W Z QJ O O W C } h = C, N f.{ C O f9 .7 Owl O O 0 C/9 a La Q 0— H a a 1 1- STATE OF ALASKA ALA, OIL AND GAS CONSERVATION COMM, ,ION REPORT OF SUNDRY WELL OPERATIONS RECEIVizU pR 2 4 201 1. Operations Performed: Abandon I— Repair well r% -o Rug Perforations F Perforate f Other Alter Casing F%W Pull Tubing F%,W Stimulate - Frac h Waiver F Time Extension Change Approved Program f— Operat. Shutdown f— Stimulate - Other r Re-enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F4 Exploratory (` ' 177-053 3. Address: 6. API Number: Stratigraphic f Service f P. O. Box 100360, Anchorage, Alaska 99510 _ 50-029-20266-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 i 1 D-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): op caliper Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured _ 6880 feet Plugs (measured) 6550' true vertical 6879 feet Junk (measured) none Effective Depth measured 6550 feet Packer (measured) 6294 true vertical 6549 feet (true vertical) 6294 Casing Length Size MD TVD Burst Collapse CONDUCTOR 52 16 75 75 SURFACE 2207 10.75 2230 2230 PRODUCTION 6847 7 6869 6868 TIE -BACK LINER 6276 5.5 6295 6294 Perforation depth: Measured depth: 6384-6472, 6479-6484, 6636-6641, 6644-6652 1-4 r True Vertical Depth: 6383-6471, 6478-6483, 6635-6640, 6643-6651 Tubing (size, grade, MD, and TVD) 3.5, L-80, 6123 MD, 6122 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FB -1 PACKER @ 6294' MD and 6294' TVD RBDMT 6 ZUt NIPPLE - CAMCO DS NIPPLE @ 492 MD and 492 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): no stimulation or cement squeeze during this workover 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 15. Well Class after work: Copies of Logs and Surveys run Exploratory I— Development F% ' Service I— Stratigraphic i- 16. Well Status after work: Oil, Wo Gas I— WDSPL I - Daily Report of Well Operations XXX GSTOR h WINJ f._ WAG I-" GINJ fv SUSP I— 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: 314-007 Contact Brett Packer (d) 265-6845 Email J.Brett. Packer(a)_conocophillips.com Printed Name Brett Packer Title Supervising Workover Engineer Signature i��tty �� Phone: 265-6845 Date Form 10-404 Revised 10/2012 411l &fV1# Submit Original Only KUP PROD 1w, MIS 1 D-08 Alaska, Inc.Wellbore conocOF hfflipS%olCommentJH2S(PP-) Well Attributes Max Angle & MD TD APVUWt Fieltl Name Wellbore Status 500292026600 KUPARUK RIVER UNIT PROD ncl (') MD (RKB) Act Bt. (ftKB) 2.89 2,100.00 6,880.0 Date SSSV: TRDP 100 926/2011 Annotation End Date KB te-Gro (R) Rig Release Da Last WO: 33.00 5/14/1978 1D -08A 0142:24:46 PM Vertical schematic(actual) ---- ------ -- --- CONDUCTOR; 230-75.0 Nipple; 492.911 Jr SURFACE, 228-2.2300 Gas Lift Mandrel; 2,541.4 Gas Lift Mandrel; 3,786.3 Gas Lift Mandrel; 4,6883 Gas Lift Mandrel; 5.334.5 Gas Lift Mandrel; 5,7983 Gas Lift Mandrel; 6,011.7 512" Ti. Back Liner, 19.1- 6,295.5 (PERF; 6.384 0-6.4720 FRAC; 6,384.0 (PERF; 6.x79 66.484.0 PLUG; 6,550.0 IPERF; 6,636.0-6,641.0 IPERF; 6,644.0-6,652.0- ,644.0-6,652.0PRODUCTION; 22.1-6,869.0 PRODUCTION; - - I Annotation Depth (ftKB) End Date Annotation Last Tag: SLIM 6,395.0 4/8/2014 Rev Reason: GLV C/O, PULL PLUG/CATCHER, Last Mod By hipshkf End Date 4/9/2014 TAG Casing Strings Description Colin) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Grade Top Thread UCTOR 16 15062 23.0 75.0 75.0 65.00 H-40 WELDED Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... WVLen(I... Grade Top Thread CE 103/4 9.794 22.8 2,230.0 2,229.4 45.50 K-55 Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... WVLen p... Grade Top ThreaoUCTION 7 6.276 22.1 6,869.0 6,867.5 26.00 J-55 BUTT Description OD (in) ID (In) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... WVLen 11... Grade Top Thread ie Back Liner 5 12 4.283 19.1 6,295.5 6,294.0 15.50 L-80 BTCM Details Nominal ID (ftKB) Top (TVD) (ftKB) Top Incl I') Item Des Co. (in) 6,110.1 6,108.7 1.47 SBR 5" BTC Pin x Pin Casing Seal Bore Receptacle w/ 4.000 4.0" Bore 6,134.1 6,132.7 1.46 Tubing 3.5", 9.3#, L-80 EUE-Mod 8rd Tubing joint 2.992 6,175.0 6,173.5 1.46 DS Nipple Camco 2.813" ID'DS' Landing Nipple # T111320 2.813 6,186.4 6,184.9 1.45 Tubing 3.5", 9.3#, L-80 EUE-Mod 8rd Tubing joint 2.992 6,227.0 6,225.5 1.27 Mandrels Camco 3-1/2" x 1-1/2" MMG GLM # 195AE07 1.000 6,246.0 6,244.5 1.14 Tubing 3.5", 9.3#, L-80 EUE-Mod 8rd Tubing joint 2.992 6,282.9 6,281.4 0.90 Locator Baker GBH -22 Locator Sub 2.990 6,284.1 6,282.6 0.89 PBR Baker 80-00 Seal assembly w/ 3 -ft Space out 2.990 Tubing Strings Tubing Description String Ma... ID (in) Top (PIKE) Set Depth (ft.. Set Depth (ND) (... Wt (I t) ra. Top Connection Tubing 31/2 2.992 0.0 6,123.2 6,121.8 9.30 L80 IBT Completion Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (') Item Des Com (in) 16.5 16.4 0.05 Hanger FMC TC -IA -EMS. 11"x3-1/2 EUE top w/3-1/21BT 2.910 Bottom w/ 4 -ft x 3-1/2", 9.3#, L-80, IBT-M Pup joint 492.9 492.9 0.76 Nipple Camco 2.875"'DS' Landing Nipple Ser# 7711308 2.875 500 -ft 6,104.2 6,102.8 1.47 Locator Baker Locator Sub 2.992 6,105.1 6,103.6 1.47 Seal Assembly Baker 80-40 Seals w/ 7 -ft space out 2.990 Other In Hole (Wireline retrievable plugs, valves,: Pumps, fish, "etc•) Top (ttK8) Top (ND) Top Incl (ftKB) (°) be Co. Run Date ID (in) 6,550.0 6,548.5 0.77 1 PLUG Cast Iron Bridge Plug 5/14/1978 0.000 Perforations & Slots Shot Dens Top (TVD) Btm (TVD) (shotsR Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date t) Type Co. 6,384.0 6,472.0 6,382.5 6,470.5 C-4, C-3, C- 5/8/1978 4.0 IPERF 2, 1D-08 6,479.0 6,484.0 6,477.5 6,482.5 C-2,10-08 5/8/1978 4.0 IPERF 6,636.0 6,641.0 6,634.5 6,639.5 1 A-5, 1D-08 5/5/1978 4.0 IPERF 6,644.0 1 6,652.0 6,642.5 I 6,650.5 A-5, 1D-08 5/5/1978 4.0 I (PERF Stimulations & Treatinents Min Top Depth (ftKB) Max Btm Depth (ftKB) Top (TVD) (ftKB) Bim (ND) (RKB) Type Date Com 6,384.0 6,484.0 6,382.5 6,482.5 FRAC 7/27/1978 FRAC KUPARUK SANDS 32,000# 20/40 SAND CARRIED BY 21,000 GALLONS OF TREATED DEISEL OIL. Mandrel Inserts St ad on Top (TVD) Valve Latch Port Size TRO Run N Top (ftKB) (ftKB) Make Model OD (in) Sery Type Type (in) (psi) Run Date Com 2,541.4 2,540.6 CAMCO KBG 1 GLV BTM 0.156 1,217.0 4/3/2014 2 3,786.3 3,785.2 CAMCO KBG 1 GLV BTM 0.156 1,222.0 4/3/2014 3 4,688.3 4,687.1 CAMCO KBG 1 GLV BTM 0.188 1,257.0 4/3/2014 4 5,334.5 5,333.3 CAMCO KBG 1 OV BTM 0.250 4/3/2014 5 5,798.3 5,797.0 CAMCO KBG 1 2n3/2 4/ 2014 6 6,011.7 6,010.3 CAMCO KBG 1 DMY 3/24/2014 Notes: General & Safety End Date Annotation 12/252002 NOTE: WAIVERED WELL: IA X OA COMMUNICATION 8/8/2010 NOTE: View Schematic w/ Alaska Schematic9.0 9/11/2012 NOTE: FOUND TUBING LEAKS @ 4922' RKB AND 5061' RKB w/ ELINE LDL 1 D-08 WELL WORK SUMMARY PRE -RIG WELL WORK DATE SUMMARY 1/24/2013 ATTEMPT TO RIG UP ON 1 D-08 FOR A SPECTRAFLOW LDL. UNABLE TO GET RUNNING IN HOLE AT A REASONABLE TIME, DUE TO SURFACE EQUIPMENT FAILURES AND LATE START BECAUSE OF PHASE CONDITIONS. LEFT EQUIPMENT SPOTTED ON LOCATION FOR TOMORROW. JOB IN PROGRESS. 1/26/2013 LOG LEAK DETECT USING SPFL AND TEMP TOOLS PUMPING DOWN IA INTO FORMATION. LEAK FOUND BETWEEN 5057' AND 5060' PUMPING AT 0.5 BPM AT 1900 PSI. LOG CORRELATED TO TUBING DETAIL RECORD DATED 12 MAY 1978 AT 4901' GLM. 1/28/2013 (AC EVAL) TxIA DDT PASSED 8/28/2013 (PRE-RWO) : FT LDS (IN PROGRESS). 8/29/2013 (PRE-RWO) : MIT -OA (PASSED) TO 1800 PSI, UPPER POT -T (PASSED), UPPER PPPOT-T (PASSED), LOWER POT -T (PASSED), LOWER PPPOT-T (FAILED), POT- IC (FAILED), PPPOT- IC (PASSED). 1/10/2014 LOGGED TEMPERATURE SURVEY FROM SURFACE TO 6326' PULLED A CORRELATION PASS FROM 6300' TO 6100' 1/13/2014 PERFORMED GYRO SURVEY FROM SURFACE TO PLUG AT 6326' AND BACK TO SURFACE. LOG ZEROED AT K.B. JOB COMPLETE. 1/19/2014 Bail Fill f/ 6267'- 6274' SLM. In Progress. 1/20/2014 Bail Fill f/ 6274'- 6295' SLM. In Progress. 1/22/2014 BAILED FILL f/ 6295' TO CATCHER @ 6299' SLM. PULLED OV @ 4901', GLV @ 4291' RKB. IN PROGRESS. 1/25/2014 PULLED GLVs @ 3297', 1872'& DV @ 6217' RKB. SET DVs @ 4901' & 4291' RKB. IN PROGRESS. 1/26/2014 SET DVs @ 3297'& 1872' RKB. BAILED FILL OFF CATCHER @ 6325' RKB; PULLED 2.78" CATCHER. PULLED 2.75" CA -2 PLUG @ 6325' RKB. IN PROGRESS. 1/27/2014 MEASURED BHP @ 6400' RKB: 3190 PSI. BRUSHED & FLUSHED TBG. SET 2.75" CA -2 @ 6325' RKB, SET CATCHER ON PLUG. READY FOR BPV. ' Time Log & Summary ConocoPhillips We/!view Web Reporting Report i Well Name: 1 D-08 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/11/2014 5:30:00 PM Rig Release: 3/24/2014 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 3/07/2014 24 hr Summary Release Nordic rig 3 from ID -102, Back off well and set down on 1D -Pad. Swap out 11" 5M Class III BOPE while constructing 2 -ft ice pad lift for 1 D-08 RWO 17:00 19:00 2.00 MIRU MOVE NUND P PJSM, Remove 11" 5M Class III BOPE from cellar 19:00 22:00 3.00 MIRU MOVE NUND P PJSM, MU mud X and stack 13-5/8" 5M Single gate in cellar. 22:00 00:00 2.00 MIRU MOVE NUND P Load upper portion of 13-5/8" 5M Class III BOP stack in cellar and begin torquing with Sweeney Wrench. 3/08/2014 Continue to Torque up 13-5/8" 5M Class III BOPE while constructing 2 -ft ice pad lift for 1 D-08 RWO and decommission of well 00:00 06:00 6.00 MIRU MOVE MOB P Continue to load and build 13 5/8" BOPE in cellar. 06:00 07:00 1.00 MIRU MOVE MOB P Load new tree in cellar. 07:00 00:00 17.00 MIRU MOVE MOB T Wait on pad prep. C/O charge pump #1. C/O hi/lo drum lever. Rig maintenance. 3/09/2014 General rig maintenance while waiting on pad prep. Ensure full studs for 13 5/8" and torque. Inventory mud pump equipment and screens. 00:00 00:00 24.00 MIRU MOVE OTHR T Continue to wait on pad prep, Construction of 2' lift around 1 D-08. Service rig equipment. 3/10/2014 Continue to wait on ice pad to cure, Suspend operations due to cold weather effect, release off cold weather effect and start moving system warm up. Build cellar box, lay out T -mats and stage wellhead equipment behind rig. Wait on weather (-36F) 00:00 04:00 4.00 MIRU MOVE OTHR T Standby waiting on ice pad lift to cure 04:00 13:30 9.50 MIRU MOVE OTHR T Standby waiting for cold weather variance to lift 13:30 15:30 2.00 MIRU MOVE OTHR T Wait for rig moving system to warm up due to cold weather operational shut down. 15:30 21:00 5.50 MIRU MOVE MOB P PJSM Build cellar box, lay out containment. Stage T -mats. Stage wellhead equipment behind rig. Load lubricator. Continue to warm up rig moving system. 21:00 00:00 3.00 MIRU MOVE OTHR T Cold weather shut down. Wait on weather; -36 below. Page 1 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment D3/11/2014 24 hr summary Continue to wait on weather. Stage rig mats. Inspect area. Remove T -mats and staged equipment behind well. Extend 2' pad to accomodate equipment behind well and create egress. Re -stage T -mats and wellhead equipment behind well. MIRU over 1 D-08. Level rig. Stage auxillary equipment load pits. R/U to pull BPV, 1 st attempt fail. 00:00 02:30 2.50 MIRU MOVE OTHR T Continue to wait on weather (-35F) 02:30 06:00 3.50 MIRU MOVE MOB P Stage rig mats on ice pad to prep for rig. Prep rig to pull over well. 06:00 08:00 2.00 MIRU MOVE MOB T Inspect well. determine more gravel/pad needed for egress and to stage equipment behind cellar. 08:00 09:30 1.50 MIRU MOVE MOB T Remove equipment and T -mats from around the well. 09:30 12:00 2.50 MIRU MOVE OTHR T Build up gravel pad behind well. 12:00 15:00 3.00 MIRU MOVE MOB T PJSM. Restage T -mats and equipment behind well. Move rig over 1 D-08. RIG ACCEPTED 17:30 15:00 17:30 2.50 MIRU MOVE MOB P Move rig over 1D-08. RIG ACCEPTED 17:30 17:30 19:30 2.00 MIRU MOVE MOB P Shim and level rig. 19:30 22:00 2.50 MIRU MOVE MOB P Stage equipment around rig, High -Line trailer, mud shack, cuttings box. Rig up hardline and Kill tank. 22:00 00:00 2.00 MIRU WHDBO MPSP P PJSM. R/U to pull BPV. Test lubricator seals to 1000 psi. Attempt to pull BPV. 3/12/2014 Pull BPV. R/U circulating line. Bleed off gas cap. ISITP 30, ISICP 0. Circulate 289 bbls of 9.6 ppg NaCl brine around. ICP 280 holding 200 psi on choke, FCP 650. Flow check - static. Install BPV. N/D tree, N/U BOP. Install 2-7/8 x 5-1/2" VBR in lower and upper pipe rams. Function pipe rams, not cycling completely. Troubleshoot rams while loading, drifting, and strapping 3-1/2 DP. 00:00 01:00 1.00 MIRU WHDBO MPSP P Pull BPV. L/D lubricator. 01:00 03:30 2.50 MIRU WELCTI RURD P Rig up circulating lines in cellar. Blow air through kill line and check for leaks. PT kill line. 03:30 07:30 4.00 MIRU WELCTI KLWL P PJSM Bleed gas cap from tubing and IA. ISITP 30, ISICP 0 displace hole to 9.6 ppg NaCl at 5 bpm @ 280 ICP and 650 FCP while holding 200 psi back pressure on CM. 289 bbls pumped 284 bbls returned. 07:30 08:00 0.50 MIRU WELCTI OWFF P Monitor well for flow - No Flow 08:00 08:30 0.50 MIRU WELCTI RURD P R/D circulating hoses 08:30 09:00 0.50 MIRU WHDBO MPSP P PJSM. Set BPV. 09:00 13:00 4.00 MIRU WHDBO NUND P N/D tree. Disassemble and pull through floor due to limited space behind cellar. 13:00 17:00 4.00 MIRU WHDBO NUND P N/U 13-5/8" BOP stack. 17:00 21:30 4.50 MIRU WHDBO NUND P Install 2 -7/8" by 5-1/5" VBR's in LPR and UPR. Function test rams; not fully cycling. Page 2 of 12 Logs _Time Date From To Dur S. De th E. Denth Phase Code Subcode T Comment 21:30 00:00 2.50 MIRU WHDBO EQRP T Troubleshoot BOPE. Load, drift and strap 3-1/2" liner. Load Baker fishing tools. D3/13/2014 Continue troubleshooting VBR's. Steam BOP stack. VBR's appear to be cycling. C/O seals on blind ram door. R/U and test BOPE 250/3600 psi witnessed by Jeff Turkington. Pull blanking plug and BPV. M/U spear and engage tubing hanger. Unseat hanger with 50K. Pick up to 127 K to disengage seals. Unable to disengage seals. Attempt to reseat hanger to L/D spear. Will not reseat — 1.5' high. Back out spear. M/U landing joint. Pick up 20K over, circulate hole volume x2 at 8 bpm with ICP 780 psi FCP 800 psi.. 00:00 09:00 9.00 MIRU WHDBO EQRP T Continue to troubleshoot BOP rams. Suspect ice; steam BOP stack. Function test rams, appear to be holding. Blind ram door seal leaking. C/O seal on blind ram door. 09:00 17:00 8.00 MIRU WHDBO BOPE P Shell test BOPE @ 250 / 3,600 psi. Call AOGCC and begin Initial BOP Test @ 250 / 3,600 psi on rams and 250 3,500 psi on Annular w/ 3-1/2 and 5-1/2 Test joints. Test was witnessed by Jeff Turkington. Test 1 Blind rams, Kill #13, CM - 11, 12 &4, 3-1/2 IF Dart Valve, Hyd TD, Test plug - High test had grey lock leak Test 2 Blind rams, Hyd Kill, CM - 10, 9, 10, & 3, 3-1/2 IF Floor Valve, Man TD, Test plug Test 3 Blind rams, Hyd Kill, CM - 5, 2 & 8, 3-1/2 8rd Floor Valve, Test plug Test 4 Lower Pipe rams & Test plug w/ 3-1/2 Test jt Test 5 Annular, Man Kill, CM 5,6 & 2, Test plug w/ 3-1/2 Test jt -High test failed - fix test hose leak Test 6 Upper Pipe Rams, Man Kill, Hyd Choke, Test plug w/ 3-1/2 Test jt Ram door bolt leak on high test failed Test 7 Lower Pipe Rams, Test plug w/ 5-1 /2 Test jt Test 8 Annular, Man. Kill & Man. Choke Test plug w/ 5-1/2 Test jt Test 9 Upper Pipe Rams, Man. Kill & Man. Choke Test plug w/ 5-1/2 Test jt Test 10 Upper Pipe Rams, Choke Valve #1, Test plug w/ 5-1/2 Test jt 17:00 19:00 2.00 MIRU RPCOM MPSP P Suck out stack. Pull blanking plug, pull BPV. Page 3 of 12 Logs _Time Date From To Dur S. Denth E. De th Phase Code Subcode T Comment 19:00 19:30 0.50 COMPZ RPCOM FISH P M/U spear and engage tubing hanger. 19:30 20:30 1.00 COMPZ RPCOM THGR P BOLDS, unseat hanger w/ 50K wt. dropping 10K. 20:30 21:30 1.00 COMPZ RPCOM PULL P Attempt to pull tubing from seals. Max pull 162K (35K block wt). Unable to pull tubing from seals. 21:30 22:30 1.00 COMPZ RPCOM THGR P Attempt to reland hanger to unspear. Unable to reland - 1.5' high. Release hanger from spear. M/U pups and engage tubing hanger. 22:30 00:00 1.50 COMPZ RPCOM CIRC P R/U to circulate 9.6 ppg with 1% Safe -Lube. P/U 20K over and circulate at 8 bpm; ICP 780 FCP 800. 3/14/2014 While waiting on E -line (timed out) Continue circulating 2 x hole volume holding 20K overpull (17"). Attempt to slack off to neutral pipe weight. Slack off 14" - hanger took weight. Picked up 20K over (-1 "). Suck out stack. Observed sand on top of hanger. Observed control line coming up around hanger and resting on top. R/U E -Line. RIH with magnet. POOH, R/D E -line. Reciprocate pipe. R/U E -line and RIH to determine free point (6,293'). POOH. RIH with E -Line string shot; fire off. POOH with string shot. M/U and RIH with RCT cutter. 00:00 00:15 0.25 COMPZ WELCTL CIRC P Continue circulating 9.6 ppg NaCl brine with 1% Safe -Lube 2 x hole volume at 8 bpm holding 20K over pull (17"). 00:15 09:00 8.75 COMPZ RPCOM ELNE P While waiting for Timed out Eline crew, S/D pumps and attempt to slack off to nuetral weight. Slack off 14", hanger took weight. Unable to travel down. PU 20K over (-1"). Suck out stack. Observe sand on top of hanger. Observe control line wedged between hanger and stack. Stand by for Eline 09:00 12:00 3.00 COMPZ RPCOM ELNE P Eline arrived on location, postion pipe for RU, Spot equipment. 12:00 14:30 2.50 COMPZ RPEQP- ELNE P PJSM with HES crew. Load tools, R/U equipment. RIH with magnent to 6300'. 14:30 15:00 0.50 COMPZ RPEQPI ELNE P POOH. R/D E -Line. Work pipe 160K up 50 K down. Hanger hanging up in stack. 15:00 22:30 7.50 COMPZ RPEQPI ELNE P R/U E -line. RIH to determine free point at Baker packer (6,293). POOH. RIH with HES string shot to 6,275' and fire shot. POOH. 22:30 00:00 1.50 COMPZ RPEQP- ELNE P L/D E -line string shot. M/U RCT. RIH and coorelate to 6, 275'. 3/15/2014 Cut tubing at 6,275' and POOH with E -line. Stand E -line back. Pick up on tubing. Hanger catching on the stack. Work tubing max 127K up weight. Pull hanger to floor and L/D. Observed 1/3 of retainer ring for hanger junk ring on top of hanger (early suspected control line). R/D E -Line. CBU, NFT. POOH with 3-1/2" tubing to 1974'. M/U storm packer and RIH t/ 111' (storm packer depth). Set storm packer, release and POOH with packer setting tool. PJSM. N/D BOPE. Remanents of snap ring on top of tubing hanger. Observed 12 psi on OA in - 60 minutes. Bleed off. Shut in and observe 6 psi in 30 minutes, bleed off. Shut in, observe 3 psi in 30 minutes. Page 4 of 12 Logs _Time Date From To Dur S. De th E. Denth Phase Code Subcode T Comment 00:00 01:00 1.00 COMPZ RPEQP- ELNE P Cut tubing at 6,275' and POOH with E -line. Stand back E -line 01:00 02:30 1.50 COMPZ RPCOM PULL P Pick up on tubing 46" with 90K PUW increase to 127K with 1" travel. Work hanger to the floor. Max pull 127K. Two control line connected. Observed retainer ring for hanger junk ring on top of hanger, which was earlier suspected as control line. 02:30 03:30 1.00 COMPZ RPCOM RURD P L/D hanger. R/D E -line. 03:30 04:00 0.50 COMPZ RPCOM CIRC P CBU @ 3bpm 140 psi. 04:00 04:30 0.50 COMPZ RPCOM OWFF P NFT - good no flow 04:30 14:00 9.50 6,240 1,974 COMPZ RPCOM PULD P POOH from 6,240 -ft to 4,263 -ft, lay down Bal - 0 - Nipple. RD SLB and offload Spooling Unit. Continue to POOH from 4,263 -ft to 1,974 -ft with 52k string wt with blocks and 17k pipe w/o blocks. 14:00 15:30 1.50 1,974 2,093 COMPZ RPCOM PACK P PJSM, PU, Make up and RIH w/ Baker 7" Storm packer to 111 -ft (center of element) and tbg tail @ 2,093 -ft. Release off storm valve. POOH. 15:30 17:00 1.50 2,093 106 COMPZ RPCOM PRTS P Drain stack and inspect top of casing stub, seen remnants of tbg hanger snap ring inside of tbg spool. Fill Stack and close blind rams, pressure up to 2,500 psi for 10 minutes - high pressure grease zerk on TBG head flange began to leak. Bleed off pressure and load with grease. Retest @ 2,500 psi for 10 minutes - good test. Bleed off and drain stack - conduct negative test. 17:00 19:00 2.00 106 COMPZ WHDBO NUND P PJSM N/D BOPE. 19:00 20:30 1.50 COMPZ WHDBO OWFF P PJSM N/D tubing head. Rig down OA hose. Check gauge on OA; noted 12 psi in —60 minutes. 20:30 00:00 3.50 COMPZ WHDBO OWFF P Bleed OA to 0. Shut in and monitor pressure, builds to 6 psi in 30 minutes. Bleed for 30 minutes, shut in and monitor. Build to 3 psi in 30 minutes. Bleed for 1 hour. 3/16/2014 Continue to monitor OA and bleed. Rig up Little Red Services and fill OA with Diesel (4 bbls). Monitor OA. Rig down lines. Attempt to pull tubing head. Steam tubing head. Rig up FMC Enerpac; RIH with test joint and RILDS. Pull 40K with top drive, use Enerpac to push 40K. Tubing spool free. N/U 13 5/8" flange and Hydratight. Allow 7" casing to grow (20-3/4" growth). Rig down Hydratight. M/U Baker Fishing Spear. Run in and engage 7" casing. Attempt to retrieve casing slips pulling 40K. Unable to retrieve slips. 00:00 06:00 6.00 COMPZ WHDBO RTWH P Continue to monitor OA pressure and bleed off. Continue to gain 4 - 4.5 psi every 30 minutes. Page 5 of 12 Logs _Time Date From To Dur S. DeiDth E. DeiDth Phase Code Subcode T Comment 06:00 10:00 4.00 COMPZ WHDBO RTWH P Shoot OA fluid; too shallow to determine fluid depth. Spot LRS & vac truck. R/U to fill OA with diesel. PT surface lines. Fill OA with diesel at 1/4 bpm. 4 bbls to fill. 10:00 11:30 1.50 COMPZ WHDBO RTWH P Monitor OA and cellar. No pressure build up. 11:30 12:00 0.50 COMPZ WHDBO RTWH P R/D and vac out lines. 12:00 17:30 5.50 COMPZ WHDBO RTWH P Rig up to pull tubing spool with winch. Unsuccessfull. Steam spool while waiting on FMC tool. M/U test joint, RIH and run in lock down screws. Install FMC plates and Enerpac. P/U 40K over with top drive and 40K with Enerpac. Tubing spool pulled free. L/D tubing spool. 17:30 20:00 2.50 COMPZ WHDBO CUTP P PJSM R/U 13 5/8" flange and Hydratight. Allow casing to grow. 20:00 22:30 2.50 COMPZ WHDBO CUTP P M/U Allow 7" casing to grow with hydratight system. Total growth 20 3/4". R/D Hydratight. 22:30 00:00 1.50 COMPZ WHDBO CUTP P PJSM. M/U Baker Spear tool. RI and latch on to 7" casing. P/U 35K on casing to attempt and retrieve the casing slips. 3/17/2014 Continue to work 7" casing slips, attempt to retrieve. Unable to retrieve casing slips. Pick up 50K over on 7" casing and set in old slips (7" stretch). L/D BHA #3 casing spear. Cut casing with Wac's cutting tool. Bring in new casing head and warm up in cellar. 4 point BOP stack while wait on Pack -offs and bushing to get machined at Prudhoe to be able to use old casing slips. Install new pack -offs and bushing. N/U wellhead, test pack -offs to 240/3400 psi for 10 minutes. N/U BOPE and inspect ram cavities. 00:00 02:30 2.50 COMPZ WHDBO PULL P Continue to work 7" casing slips. Unable to free slips. No movement up. FMC measures void and discuss options with town. Decision to use old slips and machine bushing to fit. 02:30 03:30 1.00 COMPZ WHDBO HOSO P PU on casing 50K over calculated string weight to shoe and set in slips. Total stretch with 50K over 7". 03:30 12:00 8.50 COMPZ WHDBO OTHR P Remove casing head from cellar. Bring new casing head inside and heat. Lay down BHA #3 ( Spear for fishing 7"). Cut off 7" stump (23") with wachs cutter. Jack up rig and open cellar doors and clear cellar of un needed well head equipment. Bring "New" well head TBG spool into cellar for prep work. 4 point 13-5/8 BOP stack, install mouse hole and lay down 3 jts of New 3-1/2 DP for inspection. Pull mouse hole, Remove stack and set back. 12:00 16:30 4.50 COMPZ WHDBO WWSP P PJSM. Install machined pack -off and bushing. N/U new casing head. 16:30 17:00 0.50 COMPZ WHDBO DHEQ P Test pack -off 250/3400 psi for 10 minutes. Page 6 of 12 Logs _Time Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 COMPZ WHDBO OTHR P Load test plugs and wear rings in pipeshed 18:00 23:30 5.50 COMPZ WHDBO NUND P Load test plugs and wear rig. Install test plug. N/U BOPE. 23:30 00:00 0.50 COMPZ WHDBO OTHR P Inspect BOP ram cavities 3/18/2014 Complete BOPE inspection, shell test 250/3600 psi. Pull test plug, RIH 98' pull storm packer. Continue to POOH with decompletion from 1927'. P/U BHA #5 with 6 1/8" Shoe, wash pipe, pack off, 3 1/2" grapple, 4 3/4" jars & 9 DC. TIH down to Top of fish @ 6274'. Circ B/U prior to latching fish, 8 bpm @ 1780 psi light sand and scale over shakers. 00:00 01:30 1.50 COMPZ WHDBO OTHR P Continue visual inspecting BOP rams. Close ram doors. Observed 1/4" gouge on Bore of 13 5/8" BOPE stack. 01:30 03:30 2.00 COMPZ WHDBO DHEQ P Test tubing head and storm packer to 250/2500 psi. Grey lock leak 1st test. 03:30 05:00 1.50 COMPZ WHDBO BOPE P Shell test BOPE to 250/3600 psi. Grey lock and ram door leak on first high. Grey lock leak on second high. 05:00 06:30 1.50 COMPZ WHDBO OTHR P Pull test plug, Set wear ring and lay down setting tool. 06:30 08:30 2.00 0 1,987 COMPZ WHDBO PULL P PU storm packer retrieving tool and 3 jts of 3-1/2 DP. Engage Storm packer, open storm valve, No Pressure, Release packer and POOH from 106 -ft. packer depth and 2,093 -ft TBG tail standing back DP and laying down packer. Off load baker storm packer. 08:30 09:30 1.00 1,987 1,987 COMPZ RPCOM OTHR P Change over from 3-1/2 IF DP equipment to 3-1/2 TBG equipment 09:30 13:00 3.50 1,987 0 COMPZ RPCOM PULL P POOH laying remaining 3-1/2 De Completion from 1987 -ft to cut jt. Total measurement recovered 6,255.72 -ft and 14.74 -ft of cut jt 199. Found holes in TBG and scarring on last 25 joints ( 5,480 -ft to 6,256 -ft) Offload the same. 13:00 14:00 1.00 0 0 COMPZ WELLPF OTHR P Change over from 3-1/2 TBG equipment to 3-1/2 IF Drill pipe equipment 14:00 15:00 1.00 0 309 COMPZ WELLPF PULD P PJSM, PU BHA #5 (5-3/4" OS w/ 6.125" OD Reverse saw tooth shoe) 15:00 22:00 7.00 309 6,250 COMPZ WELLPF PULD P Continue to RIH w/ BHA #5 picking up 3-1/2 Drill pipe. 22:00 00:00 2.00 6,250 6,274 COMPZ WELLPF FISH P Circ B/U pumping 8 bpm @ 1900 psi. - sand/scale in B/U sample. P/U weight 125K, down 120K. Establish SCR - wash down over fish, tagging fill @ 6259', work pipe a couple of times. Roll 10 RPM, pumping 2 bpm. TOF 6274'- slowly rotate over cleaning fill down to pack -offs in fishing BHA. [ Page 7 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 3/19/2014 24 hr summary POOH will Seal Assembly. PU BHA #6 - 3 1/2" mule shoe stinger with 7" scraper assembly. TIH down to top of PKR at 6,288'. Unable to sting into PKR with mule shoe assembly. Attempt multiple times, decision made to POOH. Slip and cut drill line. POOH with BHA #6. Inspect BHA mule shoe. Observed 2" cut/ peeled back section on bottom of mule shoe. Cut 2 7/8" stinger to resemble recovered seal assembly. M/U BHA #7. 00:00 02:00 2.00 6,274 6,284 COMPZ WELLPF FISH P Begin jarring on Fish, P/U 90K over during jar licks, following by straight pull up to 225K. Fish came free on hit # 14. P/U 15 ft, 125K, Roll pumps 1 bpm, set back down pressure increase as seals engange PBR. 02:00 03:00 1.00 6,284 6,270 COMPZ WELLPF CIRC P P/U 5 ft, pump sweep to clean well @ 8 bpm / 1800 psi. 30 minute no-flow check. 03:00 05:45 2.75 6,270 309 COMPZ WELLPF TRIP P TOOH with fishing BHA # 5 with fish standing back DP. 05:45 08:00 2.25 309 0 COMPZ WELLPF PULL P POOH w/ Fishing BHA #5 and lay down fish. Break down overshot. Offload fishing tools. OAL = 27.80-ft - fish, 10.15-ft x 4" OD seal assy, 13.6-ft TBG stub. 08:00 08:30 0.50 0 0 COMPZ WELLPF OTHR P Clean and clear work area 08:30 09:00 0.50 0 0 COMPZ WELLPFSFTY P Held 30 minute PJSM on PU, MU and RIH w/ BHA #6 (Casing Scraper) 09:00 10:15 1.25 0 324 COMPZ WELLPF PULD P PU, MU and RIH w/ 7" Casing Scraper Assembly to 324.31-ft 10:15 13:00 2.75 324 COMPZ WELLPF TRIP P Trip in hole with BHA #6 from 324-ft to 6,293 13:00 15:00 2.00 COMPZ WELLPF OTHR P Attempt to engage mule shoe into PBR. Pump 3 - 8 BPM. Max set down 10k. Work string multiple times. Unsuccessful , no entry. 15:00 18:30 3.50 COMPZ WELLPF SLPC P Slip and cut drill line . 18:30 22:00 3.50 COMPZ WELLPFTRIP P TOOH from 6000' to surface. Lay down BHA #6. 22:00 00:00 2.00 COMPZ WELLPF PULD P Inspect mule shoe on BHA #6. Observed damage to bottom of mule shoe. 2" cut lip rolled back , indication of possible tag on top of PKR. Cut new muleshoe on 2 7/8" stinger to resemble old seal assembly. 3/20/2014 TIH with BHA #7. Locate SBE at 6,293'. Wash down through SBE at 2 BPM. No-Go at 6,305'. Pump sweep and circulate out sand and scale. POOH side ways, laying down 3 1/2" drillpipe. Lay down BHA #7. Jet / flush out stack clean. RU and perform weekly BOPE test. State test waived witness by Lou Grimaldi. 00:00 01:00 1.00 0 276 COMPZ WELLPF PULD P P/U BHA #7 with 2 7/8" Mule Shoe and 7" Scraper. 01:00 04:00 3.00 276 6,286 COMPZ WELLPF TRIP P Trip in hole with BHA #7. Page 8of12 Time Logs Date From To Dur S. DeiDth E. De th Phase Code Subcode T Comment 04:00 04:30 0.50 6,286 6,305 COMPZ WELLPF FCO P P/U weight 125K. Slowly RIH down 6293' Light tag, small bobble made an additional 1.5' down to 6295'. Set down 5K start pumping, pressure build up. P/U 5 ft and start washing down pumping 2 bpm. Washed down through PKR down to 6305' No-go out on X -over. 04:30 06:00 1.50 6,304 6,304 COMPZ WELLPF CIRC P P/U pump rate to 8 bpm, pump 30 bbls sweep, sit on bottom and circulate out debris. 06:00 06:30 0.50 6,304 6,304 COMPZ WELLPF OWFF P Monitor well for flow - no flow Blow down top drive 06:30 15:30 9.00 6,304 0 COMPZ WELLPF PULL P PJSM, POOH laying down 3-1/2 DP 15:30 18:00 2.50 0 0 COMPZ WELLPF MPSP P Clean up rig floor, pull wear ring, set test plug. 18:00 20:00 2.00 0 0 COMPZ WELLPF CIRC P PJSM - Wash/Jet BOPE stack Shell test: CV #11 leaked, regrease choke skid. Shell test held. 20:00 00:00 4.00 0 COMPZ WHDBO BOPE P PJSM on testing BOPE. Test 250/3500 psi. Test waived by Lou Grimaldi. Test #1: Blind rams, Kill, UKC and 3 1/2" dart valves. CV # 4, #11 and #12. Test #2: Blind rams, Manual kill, LKC, FOSV. CV #7, #9, #10 and #3. Test #3: Lower pipe rams, 5 1/2" TJ, CV #5, #8 and #2. 3 1/2" 8rnd FOSV. Test #4: Annular preventer, 5 1/2" TJ. HCR Kill. CV # 5,#6 and #2. Test #5: UPR 5.1/2" TJ, HCR Kill. CV #5, #6, #2 and #1. Test #6: LPR 3 1/2" TJ. Test #7: Annular preventer, 3 1/2" TJ. HCR Kill. CV #5, #6 and #2. Test #8: UPR, 3 1/2" TJ. HCR kill and MC. Test #9: UPR 3 1/2" TJ. HCR kill and Choke. D3/21/2014 Completed BOPE test. RU E -Line and perform Gyro/GR/CCL and caliper logs. RD tool s and equipment. Load and tally 5 1/2" liner. PU/ TIH with 5 1/2" , 15.5#, L-80, BTC -Mod, liner 00:00 01:30 1.50 COMPZ WHDBO BOPE P Continue BOPE test. 250 / 3500 psi. Draw down test : start 2950 / end 1400 / 24 secs - 200 psi / full recovery 142 secs. Pull test plug. 01:30 04:00 2.50 COMPZ EVALWE NUND P ND flow nipple and NU shooting flange on top of the annular. 04:00 07:00 3.00 COMPZ EVALWE RURD P PJSM with Eline group - start R/U eline lubricator and pack offs. PU and MU gyro tools, PT lubricator @ 500 psi - good test Page 9 of 112 Time Logs Date From To Dur S. De th E. Denth Phase Code Subcode T Comment 07:00 09:30 2.50 0 6,290 COMPZ EVALWE ELOG P Run gyro data logging tools w/ GR from 6,290 -ft to surface, RD GyroData. 09:30 16:00 6.50 0 6,290 COMPZ EVALWE ELOG P RU and RIH w/ Caliper Logging tools w/ GR/CCLto 6,290 -ft log to surface. RD E -line. 16:00 18:00 2.00 0 0 COMPZ EVALWE NUND P PJSM, ND Shooting flange, NU Flow Nipple and install riser. 18:00 19:00 1.00 0 0 COMPZ RPCOM OTHR P Lay out 5-1/2 liner completion as per run order and verify. 19:00 00:00 5.00 0 3,500 COMPZ RPCOM PUTB P PJSM on PU 5-1/2 liner .TIH with 5-1/2 liner completion as per run order. Observed down drag starting, from joints #26 to #42. Performing wt check every 10 joints with 2k over pull. This information also corresponds with the caliper log information from the un centered 3D log shows a significant dogleg around 1,575 -ft to 1,620 -ft. The log shows to have helical damage to 1,880 -ft 3/22/2014 Continue TI with 5 1/2" , 15.5#, L-80, BTC -Mod, liner to SBE at 6,293'. Tag and space out liner. Spot corrosion inhibiter followed by diesel. Land liner. MU Baker RBP, set & test. ND BOPE. Set casing slips, cut excess casing, Jnt #143 = 24.51' in hole. Install 5 1/2" pack -off. RILDS. Pressure test 250/3500 psi. NU Tubing Head spool and BOPE. Retrieve RBP. PU and RIH with 3 1/2" completion to 861'. 00:00 04:00 4.00 3,500 6,293 COMPZ RPCOM PUTB P ContinueTIH with 5-1/2 liner completion as per run order. 04:00 05:00 1.00 6,293 6,305 COMPZ RPCOM PUTB P P/U weight 163K, down 97K. Locate top of SBE @ 6293'. Roll pumps could not slide in. P/U 3 times, rotate pipe in 1/4 turns, stop pumping - bumped in slowly TIH down to 6305' tag no-go. P/U string weight. Pressure test plug/seals to 2000 psi/good. Space out 3'ft. Mark pipe. 05:00 06:30 1.50 6,289 6,305 COMPZ RPCOM CIRC P Pick up out of seals, Line up fluid lines, reverse circ 32 bbls of 9.6# corrosion inhibited brine, followed by diesel to 2500'. Strip down through bag, tag no-go @ 6305' P/U to space out mark +3ft. 06:30 07:00 0.50 6,305 6,300 COMPZ RPCOM PRTS P Pressure test plug & seal assembly to 3500 psi/10 minutes. Good test. Bleed down to zero. Break off pup joints and set up for RBP run. 07:00 07:30 0.50 0 0 COMPZ RPCOM OTHR P Changer over equipment to Rih w/ 3-1/2 PH -6 TBG 07:30 09:00 1.50 0 0 COMPZ RPCOM PACK P PJSM, PU and RIH w/ 5-1/2 Baker Model 'G' Plug on 3-1/2 PH -6 to 60 -ft and set. POOH and lay down PH -6 and retrieving head. 09:00 10:00 1.00 0 0 COMPZ RPCOM PRTS P RU and PT RBP at 1,000 psi for 15 minutes, good test. RD test equipment. Page 10 of 12 Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T Comment 10:00 10:30 0.50 0 0 COMPZ RPCOM OTHR P Drain BOP stack and suck fluid from inside 5-1/2 Casing. 10:30 11:30 1.00 0 0 COMPZ WHDBO NUND P ND BOPE and set back 11:30 13:30 2.00 0 0 COMPZ WHDBO CUTP P Land FMC (C-21) 10" x 5-1/2" Skirted Casing slips, Cut 5-1/2 CSG w/ wachs cutter, lay down 19.3 -ft of jt 144. Install 10" x 5-1/2" Gen IV Temp Pack off. RILDS. 13:30 14:30 1.00 0 0 COMPZ WHDBO NUND P NU 11" 5M studded bottom x 11" 5M Top Flange with 2 outlet valves. 14:30 15:00 0.50 0 0 COMPZ WHDBO DHEQ P PT Pack off at 250 psi for 10 minutes, 3,500 psi for 10 minutes. 15:00 17:00 2.00 0 0 COMPZ WHDBO NUND P NU BOPE 17:00 19:30 2.50 0 0 COMPZ WHDBO BOPE P Install 11" Test plug. Shell test BOP stack at 250 / 3,600 psi. Pull Test plug. 19:30 20:30 1.00 0 COMPZ WHDBO BOPE P Attempt to blow down hard line. Froze outside of rig. Break line on 4" iron, found ice plug. Thaw. - ret -est line to 2500 psi. Strap and tally 3.5" completion jewelry. 20:30 22:00 1.50 0 0 COMPZ RPCOM PACK P PU retrieving head on 3-1/2" PH -6 . RIH and retrieve 5-1/2" Baker Model 'G' Plug at 60 -ft. POOH and lay down PH -6 and retrieving head with 'G' Plug attached. Rig down tools and equipment. 22:00 00:00 2.00 0 861 COMPZ RPCOM RCST P PJSM on PU and RIH with 3 1/2", 9.3#, L-80, IBTM SCC completion tubing to 861' as/per plan. 3/23/2014 Continue TIH with 3 1/2" completion as per running order. Locate PBR @ 6118', No go @6137'. Up and down weight 85K. P/U and space out 7'. Pull out of PBR, lay down two joints, P/U space out pups (25') & tubing hanger. Spot 90 bbls of 1 % corrossion inhibited brine behind pipe down to seal assembly. Land tubing and hanger with 7ft space out, RILDS. Test tubing to 3000 psi/30 minutes, Test IA 3500 psi/30 minutes, bleed down SOV @ 1600 psi. Set TWC, test 100 psi. Decommission 13 5/8" BOPE stack for cold storage. ND BOPE & NU WH adapter & flange. 00:00 07:00 7.00 861 6,128 COMPZ RPCOM PUTB P TIH with 3 1/2" Completion as per procedure and tally to 6,128 -ft 85k up wt, 85k do wt. 07:00 08:00 1.00 6,128 6,105 COMPZ RPCOM HOSO P No-go, space out 7 -ft, and PU to verify seal location w/ charge pup. PU install space out pups and hanger. 08:00 08:30 0.50 6,105 6,105 COMPZ RPCOM CRIH P Drain stack, Fill 13-5/8 BOP to pickle stack for decommissioning with CRW 132 1% by volume 9.6 ppg Brine. Close Annular. 08:30 09:30 1.00 6,105 6,105 COMPZ RPCOM CRIH P Reverse circulate 86 bbls of corrosion inhibited 9.6 ppg brine. Followed by 23 bbls brine from pits, 4 BPM, 780 psi. s Page 11 of 12 Logs _Time Date From To Dur S. DeiDth E. De th Phase Code Subcode T Comment 09:30 11:00 1.50 6,105 6,105 COMPZ RPCOM HOSO P PJSM on RU hoses and manifolds. Land tubing hanger in wellhead. RILDS. RU hoses and manifolds. Pressure test tubing to 3000 psi for 30 min. Good test (charted). Bleed down pressure on tubing to 2500 psi. 11:00 12:00 1.00 6,105 6,105 COMPZ RPCOM CRIH P While holding 2500 psi on tubing, pressure test IA to 3500, hold for 30 minutes. Good test. Bleed IA to 0, bleed tubing to 0. Pressure up on IA and shear out SOV at 1600 psi. 12:00 12:30 0.50 6,105 6,105 COMPZ RPCOM SFTY P Flow check, 30 minutes. Static. 12:30 14:00 1.50 6,105 0 COMPZ RPCOM MPSP P Rig down equipment and set TWC. Test below to 1000 psi / 15 minutes. 14:00 20:30 6.50 0 0 COMPZ WHDBO RURD P De- commision 13 5/8" BOPE stack, remove rams & prep for storage. 20:30 22:30 2.00 0 0 COMPZ WHDBO NUND P ND and rack back BOPE. 22:30 00:00 1.50 0 0 COMPZ WELCTL WWSP P NU adapter flange and tree. 3/24/2014 NU Tree, test 250/5000 psi, pull TWC, freeze protect, Set BPV, RDMO. Swap BOPE from 13 5/8" to 11" stack. ***Rig Release 18:00 hrs*** 00:00 03:00 3.00 0 0 COMPZ WELCTL NUND P NU Tree , test 250/500 psi . Pull TWC 03:00 05:00 2.00 0 0 COMPZ WELCTL FRZP P PJSM - R/U LRS, freeze protect well with 42 bbls of diesel, shut in let well swap. RD LRS, install BPV. 05:00 07:00 2.00 0 0 COMPZ WELCTL MOB P Dress Tree, secure cellar. 07:00 10:00 3.00 0 0 COMPZ MOVE DMOB P PJSM - Move rig off Ice pad. Shuffle rig mats due to grade of ice ramp. 10:00 15:00 5.00 0 COMPZ WHDBO NUND P Stage rig on location. Remove 13 5/8" stack. 15:00 18:00 3.00 COMPZ WHDBO NUND P R/U 11" Stack into cellar. Prep to move rig to 1 C -pad. ***Rig Release 18:00 hrs*** Page 12 of 12 1 D-08 WELL WORK SUMMARY POST RIG WELL WORK 4/3/2014 ASSIST VLV CREW IN PULLING BPV. PULLED SOV & SET OV @ 5334' RKB. PULLED DVs @ 4688', 3786'& 2541' RKB; SET GLVs . MITT TO 2500 PSI ( PASS) ATTEMPT PULL CATCHER (SD HIGH @ 6278' SLM). IN PROGRESS. 4/4/2014 BAIL FILL & DEBRIS FROM 6281'— 6289' SLM. IN PROGRESS. 4/5/2014 BAIL FILL & PULLED CATCHER @ 6319' RKB; ATTEMPT EQUALIZE CA -2 PLUG @ 6325' RKB. IN PROGRESS. 4/6/2014 BAIL FILL & PULLED CA -2 EQ PRONG @ 6325' RKB; ATTEMPT PULL PLUG BODY @ SAME. IN PROGRESS. 4/7/2014 BAIL FILL & PULLED CA -2 PLUG BODY @ 6325' RKB. IN PROGRESS. 4/8/2014 DRIFT TBG WITH 2.25" BLR & TAG @ 6395' SLM; MEASURED BHP @ 6400' RKB (3115 PS). JOB COMPLETE WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 X11- o53 zAo11�'tz> DATA LOGGED "k/ ?,/2014 M K BENDER March 26, 2014 RECEIVED APR 0 2 2014 RE: Multi Finger Caliper (MFC): 1D-08 AOGCC Run Date: 3/21/2014 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1D-08 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20266-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: 'Z NEVJ Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Free Point Log, String Shot Record, Tubing Cut Record: 1D-08 Run Date: 3/14/2014 L -I -V -off -2-4k\ o& DATA LOGGED A 12 /2014 M K BENDER March 24, 2014 RECEIVED APR 0 2 2014 ,AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1D-08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20266-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING --AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: A �7-1124 Signed: ri WELL LOG TRANSMITTAL DATA LOGGED b\/'Sd2014 M K BENDER To: Alaska Oil and Gas Conservation Comm. January 13, 2014 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED RE: Temperature Survey: 1 D-08 JAN 3 0 2014 Run Date: 1/10/2014 n OGC^ The technical data listed below is being submitted herewith. Please address any problems or V concerns to the attention of: Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1D-08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20266-00 Temperature Survey Log 1 Color Log 50-103-20313-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: '60 SCORED \c\\-6;\ //;,,„ THE TAE u., • 333 \Ness Scverlih Avenue Ci<)VI:IZNOR SI:P.N PP,RNI;I,L Anchorage Alaska 99501-3572 Wain 907 279 X 433 ,A1Ac Pcr ;. 7..':' 7542 Jonathan Coberly SCANNED MAY 0 7 2014 Wells Engineer -Z --3 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1D-08 Sundry Number: 314-007 Dear Mr. Coberly: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, Se Cathy P.v erster Chair DATED this Z dray of January, 2014. Encl. 1. • STATE OF ALASKA L1; R c Le ii, AL :A OIL AND GAS CONSERVATION COMM1_,,IO AtiZ01r T S APPLICATION FOR SUNDRY APPROVALS 1 Z l 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well • Chang ,'..o d ogram r Suspend r Rug Perforations r Perforate r Pull Tubing FY, Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r ,Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development F. 177-053 • 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 ' 50-029-20266-00• 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1 D-08 • 9.Property Designation(Lease Number): 10.Field/Pool(s)0 N. ADL 25650• Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6880 • 6879 • - 6550' • 6549' 6326,6550" none Casing Length Size MD TVD Burst Collapse CONDUCTOR 52 16 75' 75' SURFACE 2207 10.75 2230' 2230' PRODUCTION 6847 7 6869' 6868' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): • 6384-6472,6479-6484,6636-6641,6644-6652 6383-6471,6478-6483,6635-6640,6643-6651 3.5 N-80 6338 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER'FB-1'PACKER • MD=6294 TVD=6292 NO SSSV 12.Attachments: Description Summary of Proposal .p' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/10/2014 • Oil r ' Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly @ 265-1013 Email: Jonathan.Coberly(cilconocophillips.com Printed Name 1;) ,4C— n JbonathaCoer Title: Wells Engineer Signature Phone:265-1013 Date /-4,...ZOly Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3V'{- CGU—( Plug Integrity r BOP Test 'PI Mechanical Integrity Test r Location Clearance r Other: pL S O 3 S , RB ` MAY 0 7 q 14 6017 Spacing Exception Required? Yes ❑ No IZ Subsequent Form Required: g 4 / l� 9 APPROVED BY Approved by: ll/ •-6,7 COMMISSIONER THE COMMISSION Date:l 7--q-1/•pprove. application Is valid tor 12 months trom th date of approval. Form 10-403(Revised 10/2012) ifo i Submit Form and Attachments in Duplicate RECEIVED J rl N 07 ?° ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 6,2014 Commissioner Dan Seamount State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to workover the Kuparuk Producer 1D-08(PTD# 177-053). Well 1D-08 was completed into the Kuparuk C-sand interval in 1978. The well has no previous workover history. In August 2012 the well was shut in due to a failed TIFL. Tubing leaks were identified at 5,061' RKB and 4,922' RKB on 9/11/2012. Further diagnostics were conducted and a CMIT TxIA failed on 11/28/2012. The casing leak was located to be at between 5,057'RKB and 5,060'RKB. A leak rate of 0.5 bpm was established at an injection pressure of 1,900 psig. It was also determined that the IC packoff and tubing packoff fail pressure tests. The well remains shut in with a plug in the tubing tail that is currently untested due to the casing failure. By bringing this producer back online it is expected that the well will produce between 139 bopd and 160 bopd. The plan is to install a new 5 '/2"tie-back liner to the surface and install a 3 Y2"gas lift completion within it. The purpose of this rig workover is to install a barrier that will replace the currently failed production casing. The new 5 '/2" x 7" annulus will be able to be monitored for signs of pressure communication during production. Please advise us on any new wavering requirements because of this completion design. If you have any questions or require any further information,please contact me at 265-1013 or Jonathan.Coberly@conocophillips.com. Sincerely, Jonathan Coberly Senior Wells Engineer CPAI Drilling and Wells 1D-08 Rig Workover, Install 5 %2" Tie-Back Liner with 3 1/2" Gas Lift Completion (PTD# 177-053) Current Status: The well is currently shut in with a plug in the tubing tail. It has identified leaks in the tubing and production casing. The PPPOT-T and POT-IC packoff tests fail. Scope of Work: Pull the existing gas lift completion,install a 5 '/2"tie-back liner to surface,and install a 3 ''/z"gas lift completion inside the tie-back liner. General Well info: MASP: 2,034 psi(using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Kuparuk C-Sand—2,674 psig/6,398' TVD (8.1 ppg EMW)measured 1/15/2011. A new SBHP is planned pre-rig. Wellhead type/pressure rating: FMC ARCO PBU Gen III/5,000 psig Nordic 3 BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT TxIA—Failed 11/28/2012 TIFL—Failed 8/30/2012 MITOA—Passed 8/30/2012 PPPOT-T,POT-IC—Fail 8/29/2013 Well Type: Producer Estimated Start Date: February 15,2014 Production Engineers: David Lagerlef/Dana Glessner Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly@conocophillips.com) Proposed Pre-Rig Work: Slickline: 1. RU slickline. Pull catcher and plug. 2. Obtain new SBHP via Panex gauges. 3. Set plug and catcher. 4. Pull all GLV's/OV's and replace with DV's. Leave bottom GLM open. 5. RDMO slickline. Other: 1. Set BPV within 24 hours prior to rig arrival. Proposed Procedure: 1. MIRU. Pull BPV. 2. Circulate workover fluid. Conduct no-flow test. Install BPV. ND tree. 3. Install blanking plug. NU BOPE. Function and PT BOPE to 3,000 psig. Pull blanking plug. Pull the BPV. 4. MU landing joint. BOLDS. PU on hanger. Circulate workover fluid. POOH w/3 'h"completion. (If the seal assembly will not pull free, cut tubing above the SBE and POOH w/tubing.) MU storm packer. Set storm packer in production casing. PT storm packer. 6. ND BOPE. BOLDS. ND tubing head. Change packoffs. RILDS. PT packoffs. NU new casing head. NU BOPE.Test the casing head/BOPE flange break to 3,000 psig. 7. Retrieve storm packer. POOH w/remaining tubing. Make fishing trip to retrieve tubing stub if necessary. 8. Still under discussion: RIH w/casing scraper assembly. Cleanout production casing. POOH. RU E-line. Caliper and gyro casing. RD E-line. 9. RIH w/ tie-back liner assembly. Engage SBE. Space out. Pull out of SBE. Reverse circulate corrosion inhibited brine and diesel. Engage SBE. PT the 5 'h"tie-back liner to 3,500 psig. 10. Set the tie-back liner in slips. RIH and set RBP. PT the RBP. POOH. 11. ND BOPE. Cut excess casing. Install casing packoffs. RILDS. PT packoffs. NU tubing head and BOPE. PT BOPE/tubing head flange break to 3,000 psig. RIH and retrieve RBP. POOH. 12. RIH with gas lift completion tubing. 13. Engage seal assembly into SBE. Space out. Reverse circulate corrosion inhibited fluid. Land the tubing hanger. RILDS. 14. PT the tubing to 3,000 psig. Bleed tubing to 2,500 psig. PT the IA to 3,500 psig. Shear the SOV. 15. Pull landing joint. Set two way check valve. Pressure up on the IA to test TWC. 16. ND BOP. NU tree. PT tree and tubing hanger packoffs. Pull the TWC. 17. Freeze protect with diesel. Set BPV. 18. RDMO. Proposed Post-Rig Work: Slickline 1. RU slickline. 2. Pull BPV. Pull the SOV. Run gas lift design. Pull catcher. Pull CA-2 plug. 3. RD slickline. Other 1. Reset the well houses and flow lines. 2. Turn well over to Operations. • 1.-- Thi KU P 1 D-08 COnOcoPhillips ° *W11 ' Well Attributes Max Angle&MD TO Inc. Wellbore APYUWI Field Name Well Status Mel(°) MD(RKB) Act Btm(ftKB)laska, 500292026600 KUPARUK RIVER UNIT PROD 2.89 2,100.00 6,880.0 Comment H2S(ppm) Date Annotation End Date KB.Grd(It) Rig Rebase Date Well conra:-tDoa.4n22013728:@AM SSSV:TRDP 100 9/26/2011 Last WO: 33.00 5/14/1978 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,420.0 1/15/2011 Rev Reason:DRILL DEPTHS/DATES osborl 4/12/2013 HANGER,20 ---... MEL" ..."- Casing Strin s Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 23.0 75.0 75.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String WE..String...String Top Thrd SURFACE 103/4 9.794 22.8 2,230.0 2,229.5 45.50 K-55 CONDUCTOR, I Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 2375 PRODUCTION 7 6.276 22.1 6,869.0 6,867.5 26.00 J-55 BUTT `Tubing Strings I Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String W. String... String Top Thrd TUBING 1t. 31/2 2.992 20.0 I 6,338.0 6,336.5 I 9.20 N-80 BUTT GAS LIFT 1,673it. Completion Details IF Top Depth I f /TVD) Top not Nora- Top(RKB) (ftKB) r) Rem Description Comment ID(In) 20.0 20.0 0.18 HANGER TUBING HANGER 3.500 2,012.3 2,012.1 3.66 NIPPLE CAMCO BAL-0 NIPPLE 2.813 6,259.0 6,257.6 0.79 NIPPLE CAMCO WP-1'NIPPLE 2.810 6,289.6 6,288.1 0.78 SEAL ASSY BAKER SEAL ASSEMBLY 3.000 6,293.7 6,292.2 0.78 PACKER BAKER'FB-1'PACKER 4.000 6,296.2 6,294.7 0.78 SBE BAKER SEAL BORE EXTENSION 4.000 1 ,, 6,325.5 6,324.0 0.78 NIPPLE CAMCO'D'NIPPLE NO GO 2.750 NIPPLE,2,012 111V 6,337.3/ 6,335.9 0.78 WLEG BAKER WIRELINE ENTRY GUIDE 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) • Top Depth . IND) Top not Top(ftKB) (RKB) C) Description Comment Run Date ID(in) 11 6,325.5 6,324.0 0.78 PLUG 2.75"CA-2 PLUG 9/6/2012 0.000 6,550.0 6,548.5 0.77 PLUG Cast Iron Bridge Plug 5/14/1978 0.000 SURFACE,_-_A L Perforations&Slots 232,230 ---- Shot Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (4KB) (KKB) _ Zone Dria (sh... TYpe Comment Gas LIFT,7 6,384.0 6,472.0 6,382.5 6,470.5 C-4,C-3,C-2, 5/8/1978 4.0 IPERF 3,29 10-08 psi: 6,479.0 6,484.0 6,477.5 6,482.5 C-2,1D-08 5/8/1978 ' 4.0(PERF 6,636.0 6,641.0 6,634.5 6,639.5 A-5,1D-08 5/5/1978 4.0 IPERF ,29t 4 GAS LIFT, 6 - _--- ,644.0 6,652.0 6,642.5 6,650.5 A-5,1D-08 5/5/1978 4.0 IPERF Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth GAS LIFT, Depth Depth (TVD) (ND) 4.901 (RKB) (RKB) (RKB) (ftKB) Type Date Comment I 6,384.0 6,484.0 6,382.5 6,482.5 FRAC 727/1978 FRAC KUPARUK SANDS 32,000#20/40 SAND CARRIED BY 21,000 GALLONS OF TREATED DEISEL OIL. • GAS LIFT Notes:General&Safety 5.412 IIIIIEnd Date Annotation 12/25/2002 NOTE:WAIVERED WELL:IA X OA COMMUNICATION - 8/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, 9/11/2012 NOTE:FOUND TUBING LEAKS @ 4922'RKB AND 5061'RKB w/ELINE LDL 5,631 GAS LIFT,_ II_ TUBING P. 6,,223 223 ra NINIPPLE,6,259 ----N ON SEAL ASSY, 7 L PACKER,6,294 •=".. -,--. 566.6,296 ( MI IIII mu NIPPLE,:326326 PLUG,6. re • WLEG,8,337 ..1 (PERF, 6,384 FRAC,6,472IIII Mandrel Details MERE, ■ Top Depth Top Port % 6,47 ,484 - (ND) Incl OD Valve Latch Size TRO Run N...Top(RKB) (RKB) (°) Make Model (in) Sery Type Type (in) (Dai) Run Date Com... PLUG,6,550 1.11..-.11111111 1 1,872.8 1,872.5 1.65 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,210.0 7/312010 8:00 2 3,297.4 3,296.3 0.74 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,220.0 7/31/2010 5:00 RF, -_ 6.63sfiPE.w1 _ Erl 3 4,291.4 4,290.2 0.46 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,258.0 7/312010 7:00 /PERF, }s• 4 4,901.5 4,900.4 1.93 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 9/6/2012 5:00 6,644-,652 5 5,412.3 5,411.0 1.12 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/17/1997 7:30 6 5,830.9 5,829.5 1.83 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/17/1997 10:30 7 6,217.5 6,216.0 0.79 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/17/1997 1:00 PRODUCTION. 226.869-N J 1 TO,6830 I ConocoPhillips Well: 1D-08 2014 RWO PROPOSED COMPLETION API: 500292026600 PTD: 177-053 (j\- -- DS f 2.875"'DS'Nipple Wellhead: FMC PBUGeiS`I / Conductor Casing: """t101t 16"65#H-40 Welded 1— Surface Casing Cement Shoe w/Arctic Pack Surface Casing: 10.75"45.5#K-55 Ja 5Ct q5 Production Casing: j r'b 7"26#J-55 Buttress 3'5 4— Production Casing Leak at-5,060'RKB Production Liner: 5.5" 15.5#L-80 BTCM SCC J Production Tubing: 3.5"9.3# L-80 IBTM SCC DS 4— 2.813"'DS'Nipple 4— Baker 4"ID SBE w/Seal Locator \.C7 �— Baker FB-1 Permanent Packer w/SBE o 2.75"CAMCO No-Go'D'Nipple w_EG f- Wireline Entry Guide 4— CIBP Last Updated: 6-Jan-14 Updated by: J. Coberly Ferguson, Victoria L (DOA) From: Coberly,Jonathan <Jonathan.Coberly@conocophillips.com> Sent: Thursday,January 16, 2014 3:40 PM To: Ferguson,Victoria L(DOA) Subject: RE: KRU 1D-08 WO (PTD 177-053, Sundry 314-007) Attachments: FMC ARCO PBU Gen 3 retrofit to FMC Gen 5.pdf; SKMBT_C364e14011615180.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, We currently have an FMC ARCO PBU Gen Ill and we are retrofitting this well adding an FMC ARCO PBU Gen 4 casing head (13-5/8"x 11"w/slips for 5-1/2" liner) and an FMC Gen 3 tubing head (11" x 11" w/mandrel hanger). I have attached the current and retrofitted schematics. The retrofit schematic is for the earlier completed 1C-10, but the equipment is identical. The old PBU schematics are hard to come by, but I can send you a better one if one becomes available. Please let me know if you have any questions. Thanks, Jonathan Coberly Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1504) Anchorage,AK 99501 Phone:907-265-1013 Cell:907-538-8398 From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@)alaska.gov] Sent: Tuesday, January 14, 2014 10:57 AM To: Coberly,Jonathan Subject: [EXTERNAL]KRU 1D-08 WO (PTD 177-053, Sundry 314-007) Jonathan, Please send FMC Gen Ill and FMC Gen I wellhead schematics. Thanx, Victoria Ferguson Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferauson(p.alaska.gov 1 `i I ,, ,.., ;ii.,, , ,,,,Thr , s , ... 4 , ((cN , , it 40) GI kik,---ib _ ,, ,....„_,.. i , .,_. ..„. .,) .„.„ ,._.), 111111111111 ' 4' Generation 5 Wellhead System 1.00 Date: 04/14/2013 iimmo 3g311/ Rig: Nordic Ill -�:'�• a 1.50 v Well Number: KRU:IC-10 ■I*4k*ti 1.00 I 0 1 1.50 3 1/8"5000 Fig. IP- IIIII i 114 A 7-7)'.'0. 0 1.50 _*...!.. mom A--- 3"H BPV L3"HBPV .68 11"5000 Fig. ► 1� a I• o u 4uyiu,u..y1111r o -'N (•1•• (cFMC Ill 2.22 II ) 11 O 11" 5000 Fig, ► \l_._4111 71L-L111-11LL-111L11 J_'' � FMC • iLJ��LLLJJJ j- 11x13 ( I: I I. 2.35 n--1> i � n-n n n n--n rr-n . ..ie._.___H.,_ 13 5/8"5000 Flg, *► IIIuyu u 11_11" cfezi l FMC a< Z F 13x20 ( 'y►;{9 :'�' 2.11 J It I 111 IIII 11 II 1111 111 II 20" Fig. ertf O i=lis 9 LL-U LL—LI LL-Ll LL_Ll J1 FMC ( ) 1.85 J 1 o ,l, • • - -er • I Aims .- - a t4; • I . . r . . • • - CGGE.i, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: SpectraFlow Log/ Water Flow Log: 1 D-08 Run Date: 1/26/2013 a V� APR 032013 A 0 G C C, April 1, 2013 k-7-- D53 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1D-08 Digital Data in DLIS format, Digital Log file, Interpretation Report 1 Replacement CD 50-029-20266-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. 9EQ Date: Signed: NIL- • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 RECEIVED Commissioner Dan Seamount NOV fl 9 ?nl'l Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 r 7 - 0 S 3 Anchorage, AK 99501 / Alaska 011 & Gas Cons. C r oission 1 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was 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 on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 2011. 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. Sincerely, „ ' ? , E 1r 13 201; 1/1614Y? bdter Martin Walters ConocoPhillips Well Integrity Projects Supervisor sr ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26/11 1A,1B,1C,1D, 1E & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -22 50029221270000 1910030 SF N/A 18" N/A 2.55 10/18/2011 WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 2'10" _ N/A 2'10" N/A 6 10/16/2011 WSW -03 50029208170000 1821420 12" 1.00 20" 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A 1 10/17/2011 1C -170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 1C -174 50029231400000 _ 2030270 7' 1.00 8" 09/11/2011 14.8 10/15/2011 1C -190 50029231360000 2030030 9'4" 1.50 8" 09/11/2011 15.2 10/16/2011 0 ..∎41 D -08 50029220266000 1770530 5'2" 1.20 6" 5/28/2011 3.8 10/15/2011 1D-12 50029229480000 1990840 18" N/A 18" N/A 3.4 10/15/2011 1D-41 50029232880000 _ 2051880 _ 16" N/A 16" N/A 3.55 10/15/2011 1D-123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4.4 10/15/2011 1E -11 50029207870000 1820510 22" N/A 15" N/A 1.2 , 10/17/2011 1Y -09 50029209350000 1830520 7' 2.00 5" 09/12/2011 1.7 10/18/2011 l~ 7.007 08/30/07 DnnaR>wl'~ ,JW~", ~..,\""",,;, NO. 4398 SCANNED SEP 18 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ¿l Field: Kuparuk Well Log Description Date BL CD Color Job# 2H-02 11846438 INJECTION PROFILE t )ï:l' 1"'64 - C)-:r~ 08/21/07 1 2P-427 11846437 INJECTION PROFILE (), (' ,!:)r--. ~ - H"'¿ 08/20/07 1 1A-07 11850429 INJECTION PROFILE l) ('. '1r I - ~9 08/22/07 1 10-08 11850427 SBHP SURVEY I~ -(').ç~ 08/20/07 1 3A-09 11850426 GLS ¡q /-ICJq 08/20/07 1 2W-09 11850428 INJECTION PROFILE U IC- I W - .;) 1'1 08/21/07 1 1 L-17 11839642 INJECTION PROFILE Ure" q / - r....L..f? 08/23/07 1 2M-13 11839643 PRODUCTION PROFILE 08/24/07 1 1G-04 11837494 INJECTION PROFILE (), I' . 1~:1. -/1",/ 08/24/07 1 2N-350 11839644 DDL 9bl - /.-:},.ç 08/25/07 1 2N-350 11839645 PMIT ..01.. / - ,'=} .") 08/26/07 1 1A-05 11839646 INJECTION PROFILE l J:í('_ I<,(/-/ÞI-I 08/27/07 1 2H-15 11837498 INJECTION PROFILE () í c... I Sf4 - ,...,'>rl~ 08/29/07 1 2A-04 11839649 INJECTION PROFILE i) -:if'. /1rt/ - ð.~~ 08/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ARCO Alaska, Inc. Date: January 30, 1989 Transmittal #: 7417 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk KUparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted-herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 B - 0 8 Kuparuk Well Pressure Report 1 2 - 0 4 - 8 8 Both Sands 1 B, 0 2 Kuparuk Well Pressure Report I 0- 2 8 - 8 8 Amerada 1 H - 0 3 Kuparuk Well Pressure Report I 1 - 2 2 - 8 8 Amerada 1 D - 0 8 Kuparuk Well Pressure Report I 1 - 2 5 - 8 8 Both Sands I C- 0 4 Kuparuk Well Pressure Report 1-27-89 Amerada .. Receipt Acknowledged: ........................... Date: ---, ........ DISTRIBUTION: D&M State of Alaska Unocal Chevron Mobil SAPC ARCO Alaska, inc. Date: September 21, 1988 Transmittal #: 7296 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. I L- 0 4 Kuparuk 3 B - 1 3 Kuparuk Fluid Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid /' 1 D- 0 8 Kuparuk Fluid -0 3 Kuparuk Fluid - 0 6 Kuparuk Fluid Kuparuk Fluid · Kuparuk Fluid , 1 E-0 2 . Kuparuk Fluid Receipt Acknowledged: Level Report 9 - 0 6 - 8 8 Level Report 9 - 0 5 - 8 8 Level Report 9 - 0 5 - 8 8 Level Report 9 - 0 5 - 8 8 Level Report 9 - 0 1 - 8 8 Level Report 9- 01 - 8 8 Level Report 8 - 3 1 - 8 8 Level Report 8 -3 1 - 8 8 Level Report 8 - 3 1 - 8 8 Level Report 9 - 1 7- 8 8 Level Report 9 - 1 7- 8 8 Casing Casing Casing Casing Casing Tubing Casing Casing Casing Casing Casing EC IV D ,, ~a~!:~ ~i~ & Gas Cons. Commiss!~n .......................... ~. ~. e :^nchora~a DISTRIBUTION: D&M State of Alaska Chevron Unocal Mobil SAPC / ./ Dr~ll S~te lA Drill Site 1C Well No. ATTACHMENT I I KUPARUK RIVER UNIT Production Logs. "lA-4 "~1A-5 X'iA_7 ~IA-9 ~1A-11 '~1A-12 '~1A-14 '~ 1A-15 ",,lA-16A Wel 1 No. Log Date 7/6/83 10/29/83 2/8/82~ 517182/ 1125182~-- 3/23/83 / 1/19/83"~ 3/21/83/ 3/8/82 4/1/82 6/5/82 5/11/82~. Drill Site Well No. ~ Date 18 ~iB-1 12/26/81 ~18-2 6/25/81 '~18-3 11/16-18/81"-> ') '~ 3/12/82./ ~'~ ~'18-6 11/18/81~, "~ 9/I0/82/ ~'"' ~18-7 11/23/81 ~iB-8 12/28/81",~ "~ 8/4/82/ ~' '-18-9 -- 6/24/82.__->T' %. 813184-' ~ Log-Date 5/8/81 7/13/81 ~/8/8~-> 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 1D Well No. Log Date '""'~ID- 1 1/80""> ~ ~ 5/23/83/ '""1D-3 8/5/80 ' 1D-4 N7/30/BO"x, Q-- ~, 8/13/80/ '~ ~lD-5 6111/81 ... ~iD-6 6/9/81 L.... ' ~lD-7 6/8/81 '-' '"~11~-8 (ws-8) 5110178 ' ~' _ . o ~ . . . _ 10-2 RECEIVED FEB 2 1 1988 .. , -'.,:'-;- _-., ::~;]-:. Alaska 011 & Gas ~on~, Commission ':~ ;-'.' ,.:.-:-~,--:"--;L'%: "~ :-.? '~:"?,,~'>:- - - - . .. ~ ..... _ ~ ,~..:..~.,: _.,~-_.~-. - o,~..: -.. ARCO Alaska, Iy Post Offi~ .sox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO:5296 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLEKK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE DATA ~1C-4 '- 07-23-85 --~ 1C-5" 07-29-85 '~1C-5,~-' 07-30-85 "~iC- 6 ~ 07-25-85 "'~lC- 6 07-24-85 '~-iD- 8 -'~ 07-30-85 -'~ 1H- 3-''' 07-30-85 --~iR-5' 07-05-85 -'"11{- 6 07-06-85 '-"' 1R-8-~ 07-U8-85 1Y-10- 07-27-85 1Y-11-' 07-28-85 2A-2 .-' 07-04-85 2B- 13" 07-30-85 2U-14" 06-30-85 2U-14 ..... 07-01-85 2U-15. 07-08-85 2V-2 07-27-85 2V-2- 07-28-85 2W-7- 07-26-85 ~2W-7- 07-27-85 2X-15~ 07-09-85 · 2X-15 ~ 07-04-85 2Z-l' 07-05-85 ~2Z-6' 04-08-85 '~3B-7 ~ 06-27-85 3B-8~ 06-28-85 3B-8 ~' 06-27-85 '~ 3B-9 / 07-18-85 3B-11 07-20-85 3B-12" 07-21-85 3C-11 ~' 07-29-85 STATIC BHP PBU PBU STATIC BHP STATIC BHP STATIC BHP STATIC BHP DHP & MISC. BHP & MISC. STATIC BHP & STATIC BHP END OF PBU 'C' SAND STATIC BHP PRESS UP, E DATA 'A' SAND PBU 'A' SAND PBU PRESSURE TEST & HISC. 'A' SAND PBU 'A' SAND PBU 'A' SAND ONLY PBU 'A' SAND PBU FLOWING BHP & FLUID I.D. FLOWING BHP & TEMPERATURE BRP SURVEY & MISC. STATIC BHP STATIC BHP & MISC. STATIC BHP & MISC. BHP & MISC. STATIC BHP & HISC. BHP SURVEY & MISC. STATIC BHP & MISC. STATIC BHP ~ MISC. RECEIPT ACKNO~4L~.DGED: BPAK* B. CURRIER CHEVRON* D & ~4' DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON HOBIL* PHILLIPS OIL* NSK CLERK J. RATRMELL* ' ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompanY CAMCO DRESSER ATLAS DRESSER ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DRESSER ATLAS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO DAT~'~sk~ ¢~, _~.~ Ar-,,',h .... , STATE OF 'AL'ASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, Iy~' Post Offi~ _,ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5292 R~TURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARL THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE kECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. K U PARU K 1B-I.. ~lB-2. 1C-4 1C_6-~'. - 1D-SJ --1H-3 --.iQ..13-~ ", 1Q_14--~ '"lQ-15 ~lQ-16~ 1R_5~-'' 1R_6/ "1R- 7/ ~2A-2 ~2W-7'"" ~V-3 ~2W-15" 3B-! 3B_2~. -3B-3 -3B-3~ ~3B-4-' ~3B-5 -'~' -3B_6~-- ~3B-7- 3B-7~ 3B-8~ -3B-~ ~3~-10~ -3B-11 ~ 3B- 12 3B-13. '3B-14 RECEIPT WELL PRESSURE REPORT--ENVELQPE FACE DATA 05-30-.85 CAMCO ~3B- 15 . 05- 3 0- 85 CAMCO 05-16-85 CAMCO 07- 24- 85 CAMCO 07-25-85 CAMCO 07- 30- 85 CAMCO 07-30-85. CA/4CO 06- 24- 85 CAHCO 06-23-85 CAMCO 06- 2 1- 85 CAMCO 06- 21- 85 CAMCO 07- 05- 85 CAMCO 07-06-85 CAMCO 07- 06- 85 CAMCO 07- 08- 85 CAMCO 07-04-85 OTIS 07-26-85 DRESSEt~ 07-11-85 OTIS 08-04-85 OTIS 06-14-85 ???? 06-14-85 CAMCO 06-28-~5 OTIS 06-15-85 CAMCO 06-15- 8 5 CA~CO 06-26-85 CAMCO 06- 26- 85 CAMCO 06- 28- 85 CAMCO 06- 27- 85 CA~4CO 06-28.-85 OTIS 07-18- 85 CA~CO 07- 20 - 85 C AJv]C O 07- 20- 85 CAMCO 07- 21- 85 CAMCO 05-29-85 OTIS 05-29-85 OTIS ACKNO~4LEDGED: BPAE* B. CURRIER CHEVRON* D & M* DISTRIBUTION: DRILLING W. PAShER L. JOHNSTON EXXON ~,XJB IL* PHILLIPS OIL* NSK CLERK J. RATHMELL* 05-28-85 OTIS 3B-16--" 05-28-85 OTIS ~ 3C-11.'~' 07-29-85 CAMCO STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. ~s a Subsidiary of AtianticRichfieldCompany RETURN TO: ARCO Alaska, l~rc Post Of~ ox 100360 Anchorage, Alaska 99510-0363 Telephone 907 276 1215 DATE: 08-16-85 TRANSMITTAL NO: 5254 ARCO ALASKA, INC. KUPAi{UK OPER~'ION~ ENGINEERING RECORDS CLERK " ATO-1115B P.O. BOX 1U0360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING RECEIPT AND RETUR/~ PRESSURE FINALS CAHCO lB-3 1D-8 1E-5 1H-6 1L-2 1L-5 lQ-6 lQ-9 2A-5 2A-5 2C-4 2F-7 2F-8 2F-9 2G-1 2G-1 2U-5 2U-6 2U-7 2U-8 2X-'10 OTIS 2A-2 2U-t4 2V-2 2V-5 2V-13 2V-14 2W-7 3B-3 3B-8 IT~]S. PLEASE ACKNO~LEDGE ONE SIGNED COPY OF THIS TRANSMITTAL. PBU ' 04-21/22-85 STATIC 04-29-85 PBU 04-26-28-85 STATIC 04-29-85 ?BU 04-24/25-85 PBU 04-28/29/85 PRESSURE FALL OFF 05-07-85 PBU 05-12/13-85 PRESSURE FALL OFF 04-21/22-85., STATIC 05-05-85 PBU 04-24/25-85 PBU 04-14-85 PBU 04-19/20-85 PBU 04-13/14-85 STATIC 04-17-85 PBU 04-29-85 STATIC 05-02-85 STATIC '05-03-85 STATIC 05-04-85 STATIC 05-04-85 PBU 04-25/26-85 STATIC 07-04-85 'PBU '' 06-30-85 PBU 07-27-85 PBU 06-25_85~ STATIC 06-22-85 STATIC 06-22-85 P~U 07-26-85 STATIC. 06-28-85 STATIC 06-28-85 RECEIPT ACKNU~LEDGED: :~pAE*~ B. CURRIER Ci~EVRON* D & M* DISTRIBUTION: DRILLING W. PASHER L. 'JOHNSTON EXXON 'HOBI L* PHILLIPS OIL* NSK CLERK J. RATHMELL* .STATE OF ~ASKA* SOHIO* UNION* ~.TUL[N/VAULT ARCO Alaska, Inc. Post Office . 100360 Anchora§e. A!aska 99510-0360 Telephone 5;07 27C 1215 DATE: 05-2 9-85 TRANSMT~,,~ ~, ~ . ~,.~,~. NO 5201 RAN .~.,IITTED EC£IPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-11iSB P.O. BOX 100360 A~,~HORAGE, AK 99510 HERE~/ITH ARE Tile FOLLOWING ITEMS. PLEASE ACKN~''~ p'~'~.''.~um RETUF-C~ ONE SIGNED COPY OF TiIIS TPJANSMiTTAL. EQUENCE OF EVENTS ACID AND FLUID DATA ONE COPY OF EACH) Q-4/ACID STIMULATION-'C B-12 LEAK DETECTION -- SAND 05-17-85 04-16-85 EQUENCE OF EVENTS/WSR'S QRRECTED PSI 3NE COPY OF EACH) SBHP 04-29-85 ' SBHP 04-29-85 CAMCO CAMCO :EIPT ACKNONLEDGED' CURRIER* :VRON* M* DRILLING L. JOHNSTON MOB i L * NSK' CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OiL* J. RATHMELL* DATE: /~v.~ Oii & Gas Cons. commission ,, , Anchorage STATE 0";"' ALASKA* SOH lO '~': UNION* K. TULl,>?/VAULT ARCO Alaska, Inc7 Post officer 100360 · Anchorage,",~.;aska 99510-0360 Telephone 907 276 1215 TO- DATE' AF'F:IL "" I '""'~- .'_-' $ '.; 'F R(-'-; N£H '-" ..... ~ , ~A;_ NO ::>f 4 TM ;-',F:CO ALASKA: IN'C, ATTN' RECORDS CLEF:I< ATO-i i r, F! ~:, ,"~ v i '":; "'.' -" .'"', j" .~ .. , :_' -,,_, ...: ._. :.. _j' . .... . At'.J. CHh F-:'AG E AK o°~i :-~ .-*,~ :. j z ,,-' .-,' - ~' ' ! f ' I R, fll, 2;' r-' T)F r-' I-I,--B'.EI.,I];TH ARE TI-IF F_._, ...... ,..]iN[; Ill'EH,? F:'L~A E ACI:.'.~-'''~''' ..... ~, i'~.,..J¥'~. ~....,, ..y;_. RETUF.:H Oi"E ""'"C-L!ED P. OF'Y OF THIS TF;.:F',h!SH'~T'FAL " BI-'IF' ,',TATIC STATIC E:HF' STATIC B'HF' STATIC. BHF' S'TAT.T.r'.._. [-:,I-IF-' -,-' T >. -r ,r r- BHF' ~ CE,' ~. THT]; C STATIC BHP SOE/STATIC STATIC BFIF' SOE/Z.. TAT]: C STATZC Bi--IP .... ~ TATT.r' DATA D A T A I)ATA DATA !) A T'A DATA B I"t F:' DATA _r:-,, I..! F' DATA BFIF' ;..ii il'° STATIC T:;HF' DATA ~,OE/' A ' ~: r.i,,-:.,...' F'BU STATIC F,'H -. · J' L~t--." I 4.''.. F'BU DATA SI"AT]i~'',... ._F: t.-! F:' i)ATA ~-:'i"f'~TIP. .... r..,L.,r:,,, :, DATA ,?0 E./.~ f? F.i: F'B'U [',;:',,Ti-'.; .£0£/F'BU 'C' SAND /2,5/85 ,"~ ~ / "' 5 /'-'-"/o,.-.. 1241'3',5 /'-'~/85: o/ii I ,/~:' · -'/~ I/R 21 ~, 01',2:5 ~' :' !1 --. '..--. /~ U/0~'-' ")/0 ~ ~, ·.. ,. :J ._ ~,./ '" i'~ ~.2 .- ~' / "';'7 · -'/ ~ :' 4. :"' ~ ;' ./' .:-' ~: .",',./ ~) ...' ,-.., T,", .,_ L' L', t' Z (3 N DRII.. L it',!G - W, F'F"; S I-IE F: , ' r!!..J;,, ~ T r',:, ~: vy. Ri..J ~.. ~-. ...,... !'4=:- I '...':~ L-.-"-. .... f"i{~ ~ :.r. !.. F'H ~ I_I._ T F':? ~ ~.' f"l ,r? F', !,' '',.~ NS:-. ,.. ........ ,..,, J,. RATHn::'L;. ARCO Alaska, inc. i~ a Subsidiary ot Atlanli·RichlieldCompany . ARCO Alaska, In~' Post Office,.. ,.,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4992 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. STATIC'BHP REPORTS WSW f/24 12/29,28/84 1H-4 ~11/25/84 1C-4 12/05/84 lB-2 12/03/84 ~D~s .... 12/06/84 /cat SEQUENCE OF EVENTS Static BHp 12/29,28/84 · SBHP 11/25/84. Static 11/26/84 S[a[id BHP 12/05/84 Static BHP 12/03/84 St'atic BHP 12/06/84 Receipt Acknowledged: B. Currier BPAE Chevron D&M · . Drilling Geology Mobil NSK Ops. DISTRIBUTION W. Pasher 'G. Phillips Phillips Oil J. Rathmell Sohio Union Well Files ARCO Alaska, Inc. is a subsigli~ry of AllanticRichfieldCompam¥ KUPARUK 13,r~l NEER! NG D. ~¥. Bose/Shelby J. Matthews' TranSmitted herewith are the roi lowly: PLEASE NOTE. BL - BLUELINE, S - SEPIA, F FILM, T - TAPE, IFr/~::l<]k~¥1 FiaGED: . PLEASE RE]I)i~ RECE! Fr TO: AR~ ALASKA, IKt3. ATT'N: SHELBY J. MA~B~.S - ATO/1115-B: P. O. BOX 100360 A",,'QJL)RAGE, Al(. 99510 -. Atlantic Ritchfield Company Arco Alaska, Inc. .To..'j . _ Wm. Van Al'en/Sate of AK . . · Date:' 31 AUgust, 1983 TR_4R S}TT TTAL EXTENSION/EXPLORATION' -. Transmitted herewith are the following: Mud logs f'rom the~ folio.wing wells- lA-5''~' 8-11-81 · 1A-8-<~est Sak 12) 7-22-78 1B-5~West Sak 7) '11-2Z-77 lC'-4_ l-l-81 1C-5 × 2-9-81 1C-6i .3-1.-81 1D-4-' 12-31-79 1D-8~WeSt Sak 8) 4-7-78 1F-5j' 8-20-82 1G-4~ 10-12-82 1H-3~ 7-24-82 1H-6J 5-19-82 1Y-14 J 2-4'83 2C-6 7-8-83 2C-7.~ .. ~ .. 6-29-83 2X-2 / 7-2-83. 2Z-4- I ....... 6-10-83 Also'· included is an expanded core' log from well 2X-2,-"7-2'-83. A blueline copy and a Sepia is provided for each well.. . .. · R.~. eipt Acknowledge: R'gturn receipt, to: Arco Alaska, Inc. Attn: %MMXM~D~AX E. McAlister P.O. Box 100360 Anchorage, AK 99510 · · Date: Prepared by: B.BY~ne llORTi~ ~LOPE EiiGI~IEER[i;G TRAi~SHITTAL ~ -~ ~ J. O. Pa:.:elex/~:nn Simonsen DATE' ~/"- ~- E~ z_~ HELL,:'""F',,-,,. _ Transmitted here:.:ith are the'following' -,.. PLEASE I:OTE' BL - BLUZL!~iE, . S - SEPi~, F - FlU.i, T - TAP; _~=E."- :SETU2;~ f.',ECE:?T TO' ARCO AI_ASiS,1, I"~ ATI'~I' A;;;i SI:':n''q-',.u,t~,'-,l P.O. BOX 360 '""'""~'"'- A'< Ca~lO DATE' /".!lc!iota[]3 · AFA/3I 1 ' " .(~' STATE OF ALASKA "¢ ALASKA ~.'-' AND GAS CONSERVATION CE~..,,,.~SSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 77-53 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 50- 029-20266 4, Location of well at surface 600'FNL, 600'FEL, Sec 23, T11N, RIOE, UM 9. Unit or Lease Name Kuparuk 25650 At Top Producing Interval Same as above 10. Well Number 1D-8 (W.Sak 8) At Total Depth Same as above 11. Field and Pool Kuparuk River Field ..5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 108 RKB ADL 25650 Kuparuk River 0il.. Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completio'ns 4/7/78 4/22/78 5/14/78 _- feetMSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness o¢ Permafrost 6880' 6880' 6550t 6550t YES []X NO [] 2012 feet MDI 1650' (approx) ,, 22. Type Electric or Other Logs Run DIL/SP/GR~ BHCS/GR/CAL, FDC/CNL/GR/CAL, . Hicrolog, CBL/CCL/Velocity Survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf. 75'(GL) 30"' 475 sx Arcticset II emt. 10 3/4" 49.5# B, ltt K-55 Surf 2227' 13 3/4 2400 sx Permafrost cmt. 7" 26# Butl ;]-55 Surf.' 6868' 9,.7/8" 3'50 sx C'lass'G _ 24. Perforations open to Pr°~106tion (MD+TVD of Top and Bottom and 25. TUBING REcoRD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ~ !/2" ~37' A29~' . 6479 ' -6484' ', 6384'-6472' w/4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. *6636 ' -6641 ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED '6644' -6652 ' . ....... ., , ,, *Below Plug & Part in casing- , · : ,. ' ,, 27. ' PRODUCTION TEST Date F, irst .Production .'Method,..of. Operation (Flowing, gas lift, etc..) " 12/17/81 I Flowiro ....... :" Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OI L RATIO 8/5/78 90 TEST PERIOD. [[~ 27~ 720..... 1" 263 . Flov~ T~bing Casing. Pressure CALCULA~E'D. ~ OIL-BBL, GAS=MCF ' 'WA~/-~R-BBL OIL GRAVITY-APl (corr) -Press..315 r,__ __ 24-HOUR RATE?'I~ 730 , 192 -. ?~.F, . 28. COP E DATA , . 'Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A ' ' ' " ' ....... '. :- MAR 1 5 1982 . . , . . ~.~as~ 0il & 6a~ Cons. ~ommi~io. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE , , _ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk River Form. 6383' " 6383' Base Kuparuk 6722 ' 6722' River Form. , , 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed , Title A~'ea Ops. Engr. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 SOHIO CONRDENT!AL April 8, 1981 ., Mr. Gary Plisga Sohio Alaska Petroleum Company 3111C. Street Anchorage, Alaska 99503 Re: Our Boss Gyroscopic Survey Job No. Boss-16775 ~/0'~'''~ ~ag Delta_~8_ (SEC27 TI2N R16E) _ Wildcat Field North Slope, Alaska Survey Date: 4/5/81 Operator: John Samec Dear Mr. Plisga: Please.find enclosed the "Original" and eight (8) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giVing us· this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/pr Enclosures NOV 1 9 : ~ SPERRY-SUN wELL'suRVF_'~YING COMPANY '. ,: ANCHORAGE, ALASKA I SOHIO ALASKA &ETR:OLEUM: COMP~.A~.N,,_Y. ........... SAG DELTA NO. 8 SEC 27 T12N R1GE cOMPUTATION DA'yE WILDCAT FIELD APRIL 6, 1981 ........ Z:.]~.]..~:: ~::.L .: COURSE . CqURSE . 'DOG-LEG MEASURED VERTICAL VERTICAL I~CLINATION DIRECTION SEVERITY DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IO0 PAGE DATE OF SURVEY APRIL 5, 1981 BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-16775 KELLY BUSHING ELEV. : 4~.70 i OPERATOR-CHARLESiHOFFMANN RECTANGULAR NORTH/SOUTH COORDINATES VERTICAL EAST/WEST SECTION 300 300.00 251.30 O 26 S 88. 0 E .39 .50 S .98 E -. AO0 399.99 351.29 0 39 S 75.89 E .25 .65 S 1.92 E -. ~ .......~..~_,". ........ ,,~.5_L._a~ ..... o_ .i8 s 50.~0 E .~,i ._96 s 2;68 -_- -. ~00 899,98 851.28 0 9 S 5q.80 E .06 1.28 S ~000 999.98 95z.28 0 ~ s 55.59 E .03 ~.~5 s ~.56 E -. L~o_o 1099.9.8 ~0~.2~ 0 ~ N 76.~0 E .~7 ~.50 S ~.~8 E -. 200" '~":~ ';~2-~ .... 0 5. :-'.~: ~J'~5 .'f ~ :.:':-Tz:~ .. ,'ZS.: E:... -. ~ o o .~ ~ ~ ~. 5 :~..,~.~ ......... o. _: 7_/: ;;:.,':.':~__z ~_,:: ..... ~.. 1500 1~99.98 1451.2e 0 22 N 2.50 E .55 1600 1599.98 1551.2R 0 6 N 2. e E .26 1.06 S 4.78 ~ -. 1700__ 1699.98 1651.28 ~_0 1.9_ ............. ~__~1~_~9. _.E~_ .29 O0 O1 6D 77 62 58 75 89 90 82 90 10 1800. 1900 2 o_o._o__ 2100 2200 2300 2AO0 ' I .2500 I 2600 L~..~ 1799:. 97 17"51.2,7 18 '26 2099,94 2051..2A 2199.94 2151.24 2299.9~4 2251 23 9 9 · :.~?:.'. 235 ~ · 2 A ......... ......... · 27 ......... ;.!;:::~ii:2 ,:68 :N'..i::" ...:" ~ · 97 E · 40 3.86 N 5.~1 '-' · 61 4.84 N 5,76 E · 30 5.21 N 5.73 E 89 47 21 27 86 2-7 2700 2800 2900 3000 2>. ~.?-:~;~:.i:?:,~!:;::L:~.A.L.~_~.~ ............ .......... o ..... ~ ~ ........... '.U_ .~]~'2'A--~ .......... "!___-J3 :~ .... ~ ......... :::i~i:i::!,. ~.2;,;.~ ':..., 2699.92 2651.22 0 45 N 59.90 E .33 7.88 N 2799.91 2751.21 0 57 N 28.39 E .50 8.95 N 2899,82 2851,12 ~ ~7 N 17,10 E 2,37 12,44 ~ 2999.56 2950.86 A 51 N 15.10 E 1.57 19.28 N' ..:.6.75 7.62'K 8.59 9.8~ 11,79 . . 20. 02 88 56 B NY ................ SAG DELTA NO. 8 ,SEC,. 27 T12N R16E COMPUTATION DATE WILDCAT FIELD APRIL 6, 1981 ............... ::i _,,~]U_B-~SE.A:.:./.,.-- ..... COURSE, MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN C 0 U RS E .............. DQG~L£,6.:.~.i.:. ~:i .~ .... i_ ._LO T..A.L DIRECTION SEVERITY RECTANGULAR COORDINATES DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST PAGE .. 9_A_T_E__ O£~,%U P,_V F._Y__AP_E_I L__5_~_3,~ ~. 1. ' BOSS GYROSCOPIC SURVEY ,JOB NUMBER BOSS-16775 ~F...L LY_.J~iL$_I:LLN_. G_E]-!..V_, : OPE RA TOR-CHARLES HOFFMANN VERTICAL SECTION ~+oo ~,-s~2.85 ~.~5 ~ 2~ u 8.2~ u ~.~ ~8.~ N ~.TA E 3500 3~89.2~ 3440.54 16 21 N 8.60 W 1.88 115,12 N 5.83 E 3600 ~5fl~,50 ..... 3,~~0 ............... 19 ....... 2 ........... N__~7~_.~O_.~ .2_..7,3 ...... 1.~.5.25__ N ...... 1._73 .F 3700 .:~6:7'~- '56: 21 5A .'." '2.52.: ~:7.:..~ ~ ~ n ~: :: ~:;.. s?~:~:o: ,:' ~ ~ ::::.:~; ::::?~ ?.::~~: :2~, ................. 2a .... :.5. ~ ::::::::::::::::::::::::::: :~ ............ ~::-l~ :~ :-~ :.: ~: :;:~;'~:. ~ ~r:.~ .,.:.~ e: ~.. N' ~;;~:::? :.: ~": ~: ::~:::: ::' ~: ~:.S~:: :. ~ .... ~00 ~9~9.~0 SSO0.70 2~ ~ N ~. ~ ~ .~ SOT.S~ ~ ~.S~ ~ ~0~0 ~99~.~ ~5.~ ~S ~S ~ ~.~0 ~ ~.52 ~2~.~ N S.~S ~ 4. $ 00 :4. 225':0:7::i.:.::i:;::.:?.¥-! i ~ 176:' 37 20 57.:: :.:: N:: 'i:'5 '9.0. :E ,96' :: '::i::: ::': :. 425 "05 $ ° ~.._4._~LO_O... ~ ...: ::::..4. '< _ ' _ :: :' ........ L.2-,._~_!.;. ':: :':i .. ~5_8 .9:' ~500 ~41~.56 4365.86 16 15 N 8.19 E 2.36 488,31 N 13, q600 q510.7~ qq62.05 15 ~ N 8.89 E .71 515.¢2 N 17, 09.E. 31,15 4.8 E ;6:4.0 114,98 178.08 216.75 $04..76 ~26.5~ 86/E...:.- ..... 4._5_6)3.,8 74. E 4.86,~9 81E 51~,79 1.3 10 29:: .' :: ;.'.:N; 13;80 2"'61' : 559,67:ii.:'::i'iN?:i!!:'~ii~i?ii:!ii;::;!; 26,40:.:.E: 8 45 '~:i!~ :'::: N: 2'0-:~9 :.:;E ':: 2,"05' 57 5.64. !. 2 ~;" E 10 2 N'19.50 E ,65 598,80 N 39,72 E lO 1 N 1~.10 E .~ 607.0~ N 4.Z.5~ E ,~ ~ o o:.: ::':' o :o' ~ ~, 5050 4952.05 4.903.35 5100 5001.28 4952.5~ 65,41 E 71.26 E ........ 7,7,,20 r. :83'~6£' 538__,_~ & 558 .~.,5,, 575, ~ 5 9_._0_._8. 4. 599,21 607,71 616,39 64.3:13 .6.6_L ~6 ~ 680.21 698.60 7 k6_:~ 2 75q,88 SO' Io AL : : . ANCHORAGE, ALASKA"L: .. ;:L~= U_~IQ_'. ' ASKA · P':ET~:OL~'UM. COMPANY ._j,.]~..~..~ '..~_.i...L ..... i ........ C.£=2 ...... ..~]L~:.'t :.-.:ii12' :;:.i:.'Li:!ii:DA'!E:i::OF SURVEY APR IL 5,~ \ SAG DELTA NO. 8 SEC 27 T12N RIGE COMPUTATION DATE BOSS GYROSCOPIC SURVEY ~ILDCAT FIELD APRIL 6, 1981 dOB NUMBER BOSS-16775 ~.. _~A~SKA ..... ~ .................. KELLY BUSHING ELEV. = 48.70 ' "~ :::. '"L::'~:.~:..:'~ ~:L". : "CHARLES:,,.~OFFMANN ~ : A COURSE COURSE DoG-LELG~.:~'::.~ ~:'.L:?~:~:,~?~:~TO:TAL: '.: ": .,:~ :~,':.' '.,: MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEPTH DEPTH : DEPTH DEG MIN DEGREES DEG/ZO0 NORTH/SOUTH EAST/WEST ~ ' ~ ::~'":'?~:~ ::::":'~,.~:~-;~:~:~ ~5:~?;:~?'~¢~::~?:~;~:;;~0f3~ :N::L~:~:~:~:::;::~::~:~::' 89..73': ~ ::. : PAGE i981 VERTICAL SECT ION 752,40 768.84 796. ~ 63'00 6183,18 6134,48 6 29 N 23,20 E ' 1,15 ~.~ o 0. ,... 6_2 82._.~~~_,3_~ ........... 5 '.26 ........... N ._29_,.5_0__E 650.0i" 6382,21 .?::'6"3,'~3:-51- 5 4 N 29~10 5 .-'-36 6600...~ ~648.1,83-':::...:...¥:T::.~:.:6-~55,13 4 54 N ~'2,.79 E ..""36 6800 6681,1~ 6632.4~ q 20 N ~0,50 E ,65 .801,21 N 110,91 E 808.75 910,53 N .. 115,~+7_ E818,55 818..' 53::.i':: N.-~i.?:ii%:'!:: '"..':. 1 ! 9 · 9 6 E 8 27,0 3 B3~. 8~.DD ~.3~ N ~A.~ E 8~.~ 6900 6780.86 6732.16 4 19 N ~2.59 E 70_0_0.._ 6_8,8~0_._56 ......683_!.:_8.6 .............. ~. ,26,_ N 41.90 E 7 i 0 0 <.-:'. '---': 6.9 8 0 ~ .2. '9.r':i ?. "i?iiii!:?-:6. '9 3 1 ' 5 9 3 5 5 7 2 o o .,:.:!.'?i:::::::";?::'o:s o?.~i..o .9 :Q!??;:::i:ii~O:S:l:. ~ o. s 2 2 7400 7279.85 7231.15 2 22 N 38,~0 E 7500 7379.77 7331.07 2 7 N 37.59 E .16 ,14 · N 40. 9 'E · 68 .33 ,24 fl45.03 N 139.24 E 855.66 850.69 N 144,38 E 861.90 5 6 ,-08i--:.:.i N;<:i?i.!.';:i.::::..i:!. ~:.~ 1.49 * 30 E 8 67.8 5 6'0'.7i9.':'i::! N?'i:i?::~!ii::-.':.'?~ 153 ;',5 8 "E.-: 873.05 8_6_~:.,:'~':9.~;!:N.:!ii:.!:ii':::;ii:?i:;?,;::'.'1.5.7., 0 A_.. E.. ':... 877./~ 3 871.30 N 162.25 E ' 88~.52 7600 7~7':),.71 7431,01 I 55 N 36.90 E .20 874,12 N 164.40 ~7.90_0 'ii.:77ff/~'!!;'::60?:i~?'f!!:i!'?77~O'i,.90 1 ' 22:".'/' 'i::N""28,50' E'.::":: .. '" · ~2 .:..':'ii7881~'::::''2§;ilN'':::?ii,:'i:i!i:::: ' 168.55 -*~ ................. = "' :~-'~"~'"~ "~ ............. · ...........~.,~-~ .... ~ ....... ~.-.,,:-...,,,~..~.....a,.~.~.,._..~......~ .... ...... ~ .... , ................................ ,, ....... 8oo0 787,:).57 7~30.~7 ~. 5 N 26.~9 E .29 ~.15 N Z~9.55 8100 7979.56 7930.8G 1 1 N 25.39 E .07 884.81 N ~70.S7 8200 807~.54 ~030.84 0 55 N 35.20 E .19 886.29 N 171.22 8300 8179'53 ",..:-'~" 8130,83 ................ 0 ...... 5i ........ ~'-'~';"~'9 E '" ,-~8 88-7'.47'.:~::'N 172,21 8 ~00 :' .-.. -. ~ 27 9.:5 2'.:::: :] ::.~:;f.: 8 23 0.82 0 q 7 N 59 · 5 ~ E · 2 ~ 888.3~ <. N ~ 7 3 · 3 ~ ~o- :.':::":~:.:: ~:~:.s::~'~-,"s'~./~,?:':~;.'::8':~O. ~ ~ o ~ s .2; - . , ....., , ..... ......~ ..,..,.~ ~ ~ ~.' ~ ..................... 8600 8479.50 R430.~0 0 36 N 80, 0 E .13 8700 8579.50 8530.80 0 37 S 82.30 E .19 8800. ~679,49 8630,79 .... 0 .28 S 69,69 E ,18 8eO0 87~D'~'~'~" - 0 £8- s 6~,80 E .04 . .. 887.58 892, - 895.16 897,17 898.92 900.49 E 901.79 E 902,7fl R88,86./Ni .......... :,: .... !.7~,5.~.:.;~ ..........903,4fl ~89,12 N 175.67 E 903,8~ 889.1~ N 176.7~ E 903.99 888,92 N 177,66 E 903,8g 888.60 N 178,43 E 903,65 ' :.... i SPERRY-SUN WELL SURVEYING COMPANY L._ ~.:' AN CHOR A GE, A L ASK A S~H I. O_AL AS SAG DELTA NO. 8 SEC 27 T12N R16E COMPUT'ATi"~'N-6ATE WILDCAT FIELD APRIL 6~ 1981 PA~E BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-16775 Al AgKA .................................. ~~USHIN.G F'LEV., .... =. __q~8_.!O__E..T_L___ : ' ~ : -: :' HOFFMANN .· : ' :: '.:- .......... COU R S E.. C OUR S,E .......... D,O_G,~Z.L.E.G-~ ' ~ ' ' ~~L. , . MEASURED VERTICAL VERTICAL INCLI'NATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEP.TH BEG MIN DEGREES DEG/~O0 NORTH/SOUTH EAST/WEST SECTION 0 12 S 22.80~:.E .~j~ 887.89 N '~' ' 179,20 S 903.0A -9~00 9179.A7 91DO.7T' ' 0 ~9 . S 22.39 W. .25 886.15 N 178.~5 E 901.z~ 9400 9279.46 92~0.76 0 58 S'12. 0 W .21 B84.GA N 177.88 E 899.65 .. 9500 ~379~._~.5 ...... 9~3.~..~ .................... 0.. 50 S ..... 1.8.9.~ ........... .i5 ...... ~.~OB~ 1 5 8.9 9 E 8 3 $900 9779.38 · 9750.68 0 52 S 22.89 W .15 87G.2~ U 175,71 E 891.06 10000 9879.~5 9830.65 l' ~6 S ~0.19 W .91 87~.19 N 17A.6~ E 888.90 . .~]OO ..... 99Z_BL..3] : __~.~_3 0... 61..' ....... 1 . 47_ ...... .... S ..... 30...ig~ .................0.2 ....... ~._~9._N 1 1 ~3- 'S..~G,89~:W.. .18 169.96 E 880.78 10500 10S79.15 10330.~3 .2 S S 48.29 ~ .61 861.89 N l~.i7 E io~oo io~z~,o~ io~o,~ i ~. s ~,~o ~ .~ ~.~ ~ l~,~o ~ ~v~.~ io~oo':~-?~ i~'o6~'~":'~.~:.~;l'o~:.~'~&"~' .......... ~ ~ ~9,~ ~u ~ E . .., . ~ .. . . · ~ · ....... 10900 .T:'~L?i.: .'I 0:7~T8'86...:::~' :.::.~lOT50:- 16 2 25 .:S' 64 '59'W · 52'...-: ~ ~ ;:.:':~.~C..::855.50. N 867., iiioo io978.7.A iogso.oA i Ao N 85.20 ~ .55 854.05 N 1~6.~9 E 865.S2 ~1200 1107~.70 110~0.00 1 5~ N 89.20 ~ .25 954.20 N 1~.57 E 865.29 11500::" 9 ' 85 1 35 N 71,2'9. ~ · · 13 ,9 G ':' ..... ~ ~ ~ o n:::.::.~. ~ ~.~,..8.1~ ............... i . ~ s ...... ~N_. ~ S..;,O-~.:=-..... ~' ._ZO_... ' ::: .: ':?: ;~S'.7:· 0 .~l.~m~ E..~ .~, ~ ~._6 6 .... /~11700 11578.4-6 -i1529.76 1 38 N 56.10 W .30 858.~ N 129.22 E 867.75 :"~' 11800 11678.~ ' 11629,7~ 1 32 N ~5,29 W ,~1 860.18 N 127.07 E 8G9.23 1 51 N 3~.' 0 'U'~ ': ::~::~:":~'31 :~../:~'1'2~'.~0:. E- 873.21 ........................ ~ ...... · . . . ~. ...... . ,.., '~ ':' ~' ' ~ SPERRY-SUN WELL SURVEYING :COMPANy MP NY DATE OF:'SURVEY A=RIL 5, SAG DELTA NO. 8 SEC 27 T12N R16E " COMPUTAIT-ioN- DATE BOSS GYROSCOPIC SURVEY-- ~ILDCAT FIELD ~ APRIL 6, 1981 JOB NUMBER BOSS-1G775 KELLY BUSHING ELEV. = PAGE 1981 q8.70 FT. ':::.::: ~u.E?.:; .:, ..... s_U__B..~.~E.A' .................... L.:.C~uRs:E..:}_:.~ Co..UR.SE .... O0 G-LEG : : ;": TOTAL ......... MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/iO0 NORTH/SOUTH EAST/WEST SECTION 12q00 12278,07 12229,37 2 6 N 23,70 W ,13 877,96 N 117,14 =' 885,. 12500 12378,01 12329.31 1 53 N 18,29 W ,28 881.22 N 115.88 E 888,77 ,. .... 1.2..6_07 :.,1,.P,.~.7_7_,~5 ........... ~_2_.~_.~2,,.?._,_~f ................ 2 ........ 0 .N.., 21._~.20_W .15 884.4'3 N 114.73 E 891.82 ! ' ' : ":::":':"'::' ' ' "! ::":::':'?;': ! ; i: : · . ' HORIZONTAL DISPLACEF!ENT = 912.~1 FEET AT NORTH, G DEG. 56 MIN. EAST l" ' :~H:E..;:CALCULA.TiION?i~D:~EDURES-:ARE BASED ON'-'T'HE uSE::'OF THREE:.:::DI:MENSIONAL :RADIt AT MD = 13250 CUR,:i.VA:TURE., MET HOD. ..'i.::~i '~- .:'::-'. , AN~HbRAGE*', ALASKA. i' ' ~'.'??'~ . · L__SJD.B.I.O !~igi'"-PF(T':':.R'~ .Q~P_AN.Y ................ L.,..] ....... * ............... · ........... ~.' ......... i .......... ..... 2_-'~2- ......... DATi~':iii:..LOF .... SURVEY APRIL .5,_ 1~_ ~ S~G DELTA NO. 8 SEC 27 T12N R1GE COMPUTATION DATE J ~ILDCAT FIELD ' ' ' APRIL 6, 19R1 dOB NUMgER BOSS-16775 ~ : KELLY BUSHING ELEV. : 48~70 FT. TRUE SUB-SEA TOTAL ' , MF~RFD VFRTI~I v ERdmAn.. ~E CI_A N G U L AR~_~Q~. I ~]~S.___~..~ v D VFRT :' O E P::~.~::::?:.';.;:".:?.~:~?cD:~H~.~c.~ ~:~?DE'P'T H:?'-." "::"T N- 0 R T H / S 0 U T H EA S.T'.~ WES T.: ~.: :~ DIFFER ~;~'E?? ...~...::~ .::.c~..;:;..t~..~:.... ,. ..~..-_:_..,:....... :,:.::~:~.~.~;:... :... ~000 999.98 95~.28 1.~5 S q.56 E 2000 1999.95 1951.25 2.68 N ~.97 E. .05 ~Oo.o,~.'.:-::L.;;:~.L~<~'~:~,:~':~:~::*o.:?~'~· ~:~,~'~::~.~sOo"-;7o :- ~o7 , ' -:'. .... ~' :~' ~,~ '-'- :'-' .-' · · "~-".'-"' ": -.~'~ ,.... 7000 ~880.56 6831.86 850.69 N 14~.38 E ~19.~A 5.50 8000 7879.57 7830.87 ~83.~5 N 169.55 E ~20.~3 , 9000 ~879.~9 __8~,,0_',.7~ ...888 · 2 ~_._N ......1A8_..9_l~ 1_.~_~. _ ,09 j '-' 10 0 0 O; :.:'?.;.~"8~;~.~5~;~;:~F~:~?:..~9.~.3 0;'65 874 .l 9 N~;:.'~;~.;:~'..~'"':; 1' 74,6 3... ~,-::-~ ? .. ;~..~,.;...'t 2'0.6 5 ..~ : ;~;~::'..?~:..::.':1'5,'~:'-:.'-{'....' ...... z ~5 ,"-'"~" '-.-'~ ' :.,..' ' -'' ~ · 26 N .", '. ::....;...1~ 9 .-;75 .. E. '-::".'::. ,:',,-;;?:.:;,".-,:.":t 21.21 ,. ..... ::;.;.~ ..::~'.':'¥,,'?~/.?:L~ 56 .'"" '"'."? 13000 12877.71 12829.01 897.82 N 111.84' E 122o29 .63 13250 13127,58 13078.88 905.61 N 110,30 E 122.~2 o13 THE CALC, ULA:~c:tONii~C;/~i'RO:6=~i~i~RES ARE ATURE .METt4OD, L._S_O_I:LtO:.A~L'A_S~i':::.RE~Ro. LEU.F.I, COMPANY : "'D:A'~E OF .$UR vEY APR IL 59 1981 SAG DELTA-NO. 8 sE~ 27~{'~N ....... Ri6-E ................................... ~-66-~DTAT'I'ON 'DAT~ ~ILDCAT FIELD APRIL 6~ [98[ JOB NUMBER BOSS-Z6775 ALASKA ==, -. ~ ...................... 2 ........................ KELLY BUSHING ELEV. = 48.70 FT. TRUE SUB-SEA TOTAL ,, MEAS_URED VERTICAL VERTICAL R;ECTANGULAR COORDINATES MD-TVD VERTICAL ~8,70 0,00 .DO S ,02 E 48 1/.+8 348 448 548 648 148,70 100,00 ,08 S ,$7 .__.2~8__,_70 . _2__QO .,~0.0_ ........... ,46 S ,62 ~.~?. ~,,:8::,:~.o. i:.,.. ;..:.. ~:E~,. 6'0 S-i-' "-' '=.'5 2-'-s ............... i-:'-~T~ :.::'::??~.":~si:;:.'~.o'i'"::i:::':'.':'::?i;:?oo,-o'o :,'.." : ' .' . 7~ s ' 2."+:~': ...... _,o_'~o7_~-'..o_:'..-,.:.=.:: ............. ~_. ~ ~..s__' ..... ~., ~ 648,70 600,00 1.17 S 3.32 · 00 ,00 · 00 ,00 · 00 ,00 748 ~: 48 948 1048 . ..j~ 1248 1448 748o70 700.00 848.70 800.00 948.70 ..... :.~' ~.900 · 00 1;:o 4'8 ,~'7:o ~.::: ....<!~!!i:: 1'.o o,o. o o 1248,70 1200,00 1348.70 1300.00 1548 1648 ....... 1.748 ..... . · 98 S 3.88 E ........... 1.19..$ ................. _~...,.. ! 1.36 S 4.~,2 E 1,53 S 4,7"0' E 1.46 S 5,06 E i.45'" s ............. 5-","~-2 E 1.6,3 S 5.20 E · 02 ,00 · 02 ,00 · 02- ' ,02 .02 .02 ,'00 · 00-,:. ' ,00 ,00 ':': .:i ::' "' :i:L: i .: ANCHORAGE' ALASKA SAG DELTA NO. 8 SEC 27 T12N R16E ....... CoMpu'TA'~'~-j'N"'DA~'~' WILDCAT FIELD . APRIL G~ 1~81 JOB NUNBER BOSS-16775 TRUE SUB-SEA TOTAL , MFAR~JRFD VFRTTCAI ~L.~__RECTA~I ULAEL COORDINATES MD TVD VFDT?PAI ', . ~ : .....~- ...... , ................ ~ .................. ,G ............................... r~v ........... 1948 1~48.70 1900.00 2.15 N 4.93 E .04 .01 2048 2048.70 2000,00 3.19 N 5.06 E .05 .01 · .:~ ~2 ~ ~ .:;~:' 0 o':::~..'~C:~ -:: ~. 5. ~ ~ ~t . :~,.::~ ~.:: ~.~..~.-oo::,.:: ' ' 2548 25~8.70 2500,00 6.69 N 6,~ E .07 .00 26~8 2648.70 2600.00 7.53 N 7.06 E .08 ~: 28.. o o::. T :~:'::~'9"'8 ~:~N e :"O'~S~E.~;:~.~'.: ~ ~'i~1~ :: : :::~;~:' ~ ::::~.< ':~.: .~.~:'~: ~0'2 ..'~..~:~:':.'::~ :~ ~'.:. ~ .:.'~" ~150 3148,70 3100,00 36.88 N 13,29 E t.5~ .85 32.51 3248.70 ~200,00 54,98 N 13,32 E . ~,16 1,64 SDER~-Y""S'~-~-"~-LL SURVEYING COMPANY ANCHORAGE, ALASKA t--~OJ:LLO--A~L-~'S~~E~M":--¢-O-~-P-A~Y DATE OF SURVEY APRIL 5, 1981 SAG DELTA NO. 8 SEC 27 T12N -~-i-6"~ ................. co'MPu'~ATI'oN"'DA~'~ WILDCAT FIELD APRIL 6, 1981 JOB NUMBER BOSS-16775 ~~ASK..'~ ...................... KELLY BUSHING ELEV. - 48.70 "- ., ' _ - ,,';,?:'/' ';OP.ERA::~:OR~C HAR LES ,'.HOF~ MA NN ........ VALUES FOR EVEN lO0 FEE:T. OF-SUB:SEA ,,, ..... PAGE . ~ FT. TRUE SUB-SEA - TOTAL · MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES i' DEPTH ~;' MD-TVD VERTICAL ~..... r5776 /:'::?c;??.'::'-.c'?;:;.?:' :; ·" :.::.;..." ..'..: ,..., .... ' :...:..... ;. . ....... ............ 3887 3848.70 3800.00 257.21 N 6.69 ~999 ~ 325' ;'.-.'":;?¢::~..42 4535 4A~8,70 4400,00 498.~6 N A639 4548,70 ASO0.O0 525.51 N l~,~G E 3,76 5046 5~8 50~8,70 5000,00 6~5,~ N ~5,08 E 52~9 5Z~8,70 5ZO0,O0 · 652.~7 N - 50.63 E 5_ 5_z_ 5 _ 8.70 5200.00 650.58 N E 5f153 ".' 53~ 8:~7'0"':i;:::~?;:!-':~T~-~;O''~'O~'-~ ....................... 668'.~'i--~~' ' .%"~";~A' 7' ' · '. , ' :' '"<', "":· · ~ .''' '-.:* ~eO¢ ~ 5555 .... ' 5A.~8.*.70:':;.-.';"..~;-..5400,00 687.~'&~.::'; -"~, ~ ~ . ',". ,L:,: ..:.. '` ...-.;.': ,'- ' - ;':"'>>: ;;::,;(-' . ~ ~ ~ '. t~ ;. '; '.. ' ~ ~ ~'~' '~ .... ; .5657 55~8';..~0~.?; j:.~.~? .;..;.755D 0,00 " 705 · Z 5'..~ N-' ':'.:..- '-: ;.:.74,.57 ~'E 38.68 10.90 50.52 11.8~ 60.99 10.47 6 9 -30:i..?:;?;?~:i:ii?i:.:;:!!!:i?~ii'i::ii!~;;.:i ;:i:: !.!'.:::. 8,'3.2 .:'~ 7 6-" :. 6' "::..?: 86.86 90.62 93.37 .. 9,5 , ... 1~,,..8 ~. ::::.' :.?' 9 ;:23 97~,:::9 ' 46 99.q. 7 1.57 lOl.ll 1.6~ 102.91 1.79 10 ~+ · 7 6 1 06.6:0.~i~i:~<i:!:?~. : ' 'i"~ '~ ANCHORAGE, ALASKA SAG DELTA NO. 8 SEC 27 T12N R16E COMPUTATION DATE WILDCAT FIELD APRIL 6, 1981 COMPANY. ":; :.. ?:;.'!:. ' ' PAGE 10 D ATE .OF..,..SURV EY_, A,P R.IL_.D_~__L~.~ JOB NUMBER BOSS-16775 ___X.~..R.IJS.HING.ELE.~.__.~ ...... TRUE SUB-SEA TOTAL MFA. S. tlRFD VFB. LLC.A,~LCAL ..... BECTANGULAR___CO. OR.DZ.N.~T. ES. ..... _.MD. nTVD VERT LCAL 5860 5748.70 5700,00 740.52 N 87.30 E 111.87 1,72 6~66 6~8.70 6300.00 815.92 N 118.51 S 117.65 6566 6~8.70 6~00.00 823.60 N 122.89 E ~1.8.0~ 7068 69~8,70 6900,00 85~.~9 N 147,82 E ~19.65 ,29 7168 7048,70 7000,00 859,40 N 152,36 E 119,85 ,22 ....... 72.6.8 .......... 7 !_4._8._,~.~.&0_,..0,.0_ ........ 86 3.6 7 _.. N~..~!_56,~.0~. E ____L&O_,_~2 ................ · l ~.. .... '~ ,, . 7 3.6 8:: :7 0 0 ::::. 8 6 7.2 0 N , :::.'::': :':~?:~ 5 9.~'0 E-t:::: - t. 2 0 · ~ 2 . i LS_OJ~O: A-L:AS~KA;i PETR:OL::;~EU~r:I~..._~C.~_N~_~i~,~N.X .............. i ............................... : ........... DATE .... OF.'~'.S.U..R..V. EY; ~ADR I L 5, 1981 ' SAG DELTA ~. 8 SE~ 27 T12N R1GE COMPUTATION DATE WILDCAT FIELD APRIL 6, 1981 JOB NUMBER BOSS-16775 ALASK~ . . KELLY BUSHING ELEV, = ~8,70 FT, :. : ' ............ : .......... - ...... ~- '. ~-:. '.,~; :~:~'' OpeRATOR "CHARLES~ ]HOFF MA~N TRUE SUB-SEA TOTAL M E A S .UiR E~D , ,VERTICAL VERTICAk RECTANGULAR COORDINATES MD-TVD ' VERTICAL ;D'Ep~T Fill i~i~F't:~?. ' .~ ~ O'R¥ H'! S'O'u"T~:.~:. ':i !::~i;~:~'!~"~F'~i ii;~;' D:t~-E R ~NC E¥~;i~i~!!iili~i.~;:;i!~:?~;ORRiE!CTi. I. ONi~;i:ii ~:'~..; 7769 7648.70 7600.00 878.32 N 166.98 E 120.36 7869 7748.70 7700.00 R80.59 N 168.19 E 120.~9 7969 ..... 78A~ 70 ....... Z&O.O_,,.E..O~ .........8.82...65 ._N... J_6.9~.,~_8_.E , ~1~.~2 ' 8569 82~8.70 8200.00 888.13 N ~72.97 E ~20.~8 .01 ~,t69 8~8.70 ~oo.oo ~.0~ N - ~75.~ E ~20.50 .0~ 8969 88q8,70 8800,00 888,35 N 178.87 E 120,51 ,00 9069 89q8,70 8900,00 887,99 ~ 179.16 E 120,51 887.5~ N ~79.~5 E ~20 52 O0 ~ L6 9 ~ O~. 7 o 9 o o o ~ ~ o " .... 8'~"6-~; 55~ ;' :,;::..~.~:?~ ?z:78~'.5-0~,~'~: E;;:~ ~; .. 1~e o ~ I SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE, ALASKA ~. " PAGE O_A T E ~O.F. S~U R V~E Y A P..R I~ .5, .... k9_81 SAG DELTA NO. 8 SEC 27 T12N R16E COMPUTATION DATE ~ WILDCAT FIELD APRIL 6, 1981 dOB NUMBER BOSS-16775 A l A s K A K E_L L.Y_.JP~U SH_I~~, .. ,= ..... ~Rj~~,~ : ................. .............. "::: : TOR'CHARLES "OFFNANN TRUE SUB-SEA TOTAL R T): C.&~V_EL~T_I.C.A.L ....... R£C T ANG..UL A.R .... CO.OR D I.NA.I_E$_____M.D.~T ,V D V E R T I C A L PT H'.~i.::~:,:i:NORTH ZSOU TH EA S T/WE'S Tii:.'i: ~ D I O:°-io: O:.S~!:.=, ::: ~ ~:. ~ ~, ~.~. ~.z.:.~ ........ _,.~7 7.:' ~.~.!i.i:~ ~,~: .... ,:,' ........ 9669 9548.70 9500.00 880 9769 9648..70 9600,00 878 . _~_9.&F, 9 ..... 9_Z.,ZLS.._7_O .... 9_LO~O_._O,.O .................. 876 ..:i0069 0~:.:. .'::~. 872 10269 101/+8.70 10100.00 ~ 10369 102/+8.70 10200,00 R _ .1 o~.69______-L~_~8_.~L__j~_.5.0.O.._O.O ...... 8 10.56.9 .....10448:~'.~70 ..:~.:~: ~-:~iilo ~0 0 .:00 8 1066 9:"105 t~.8-' 7';0-:-.>'!:?~!:1'05 O0.00 8 10869 10748.70 10700.00 8 10969 108q8.70 10800.00 8 67.26 N 170.~5 E 120.77 .OZ~ 65.03 N 168.82 E 120.81 .04 62.6 i~N ....... 1._66,.,~99__~_ . 1._2,.0__.~_5 · .0 $ 58.95 N ".-.'l'61.1q .E '- 120.97' .':."~ .06 5.7.. ~.6.....~ .............. 1_57~..~.2--E_---_~.~ 21 · 0/+ .....i:--:._.:~.~,!.:~::...?~:.i:!:?~.. .......... ', ...0_6 ......... 5~.0~ N Z5~.38 E ~2~.~Z .07 ' ;:' A N C H 0 R A G E $ A L A S K A ' ]:::':. ??:. ': · i' "A;L:S'KA:;:IPE.TR' O:LEUt" H 0 COMPANy_ ............................................ .................... n Tr~n~ EY.;.APRIL 5, 1,81 SAG DELTA NO. 8 SEC 27 T12N R16E COMPUTATION DATE WILDCAT FIELD APRIL 69 1981 ,JOB NUMBER DOSS-15775 KELLY BUSHING ELEV. = ~,70 PAGE 1'3 FT. TRUE SUB-SEA TOTA'L · M ~,A ~U R,E D, V.E_RTICAL .... ,V ~ R T I..C_~ RECTANGULAR COORDINATES MD-TVD 11570 11~8.70 11~00.00 856.65 N 132.59 E 121.~8 11670 115A8.70 11500.00 857.95 N 129.93 E 121.52 VERTICAL .04 ~1.1648.70 11600.00 859.61 N 127.64 E 121.56 ' 12170 12048.70 12000.00 870.0~ N 120.96 E 121.76 .07 12~70 ~21~.70 ~2100.00 ~7~.52 ~ ~i~.~2 E ~21.~ .08 ~70 1,2~8.70 12200.00 87~.97 ~I 117.58 E 121.91 .07 ~ 2,+~ '.:: i~;~4 $,:~: 7 o.:~;~ :{~:~'.0'; oo-, ..... '7' 7'~;-~ ~'~'o~ 0'%['--: ..... fl ~" l"e" ~-"'. '~.;:: ?;.; 12570 O0 ~: '.885'~.8 N 115.~0 E" 12770 126~8.70 12600.00 890.69 N 11-~.26 E 122.17 .07 12870 127~8.70 12700.00 893.80 N 112.6~ E 122.22 .05 !_a970 128q8.70 12800:00 896.92 N 112:0'2 E 122.28 .05 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN .THE .NE..~.REST 20 FOOT MD (FROM' RADIUS OF CURVATURE) POINTS SPERRY-SUN WELL SUr~VEYING COMPANY...~''I~. ' . PASE ~ ~ ANCHORAGE9 ALASKA · ~~OL-E-~£OM,P,~N¥-. .................................................. DA.TE OF..SURVEY. APR IL 5.~~ , S~G DELTA NO. ~ SEC 27 T12N R16E COMPUTATION DATE WILDCAT FIELD APRIL G~ 1981 dOB NUMBER BOSS-16775 ~gKA ............................. KFI LY RUSHTNG EI_~V, .: 48,7fl FT~ TRUE SUB-SEA TOTAL MFaRIIRFD VFRTTrAI V E P,_T_[.C AL ....... R E C IA N G ULA R.___C_O.O.R.D.IALA IE S i D~P T~ :--',~'~??...?~,.~E~p:~y:.H~:-~?~?~;~?'D~ p T H . NOR TH/SOUTH ~,/.-' EA:sT/WE ST MA RKE ~: ~,. ~' 10112 9991.30 99z~2.60 871.17 N 12800 12677.81 12629.11 891.59 N . 1 P R 49 1. P. 7. ~ A, 79 _ .!_26_7,8_,.09 89.3, ],2__... N 13001:'!!'i?i; ~ii]i:? 128 7 8.':"71 i?i~L':.:!..:-~'i 2:830" 01 ...... 897,86 N":: 1325 905.61 N 172.87 E 9 5/8"' SHOE 113.08 E SURVEY DEPTH L1,2,.7~_E ...... EL U ~ .T D .. -?:1.11.8:4 E 7" LINE '1101,30 E TOTAL ,. R.~LLER .. :, ., ! SOHIO ALASKA PETROLEUM COMPANY '-- .... ' ..... '-~,:: ....... SAG DELTA 'NO,, 8 SEC 27 T12N R16E ,/"~A _L .............................. · .................................... ... STRATIGRAPHIC SUMMARY . i ] DERIVED USING DIL DEPTHS AND SPERRY SUN SURVEY DATA i"i ................. --'''~'M.ARK' :;~i ; :ME'ASuRED DEPTH -''--''TVD-'"'";"':i' ' TO WELLHEAD · - :. BKB BKB SUB'SEA mm m, imm mm m' mm,mm m mim rolm m mim il, mlmmm! mm m m mi lmm m mm m Im mm m Il m Imm m Ilim mm imm m, Imm Im Imm il m Imm imm m Iml m m o · SEC '27' T12N R16E 9220.76 177.91E 7" LINER TOP 9390 9269.q6 --, ...................................... !;272'6o7.9 7" LINER SHOE 13001 12878°71 TOTAL DEPTH DRILLER 13250 15127°58 172.87E 113.0.~ 112,7 Ill,84E llO,30E 99~2'.60 12629,11 1-2678.09 12830,01 15078.88 897.86N 905,61N l,_ . .... ''''''--''''"'''''''--.''"'----'''----'-- ~.--~:' ';'",:":"":: ""'--" "-" '" · --m ,,. t II llmIllliilllIil/ imf III I '22~)COMPUTERi::i;..PR.~SPE:RJ'Y";'-.. S.~U.N...T. HREE DIMENSIONAL: RADIUs: 'OF'.:CORVATUREo . . DATA CALCULATION AND, INTERPOLATION Bg-'""~'A'DIU-~-'O'~'--~"O~'9-~'f0-R-~ ..... ' ....... · ~ ! I I I I ! i I i illliI ii i I IIi ! IIIIi i IIliI I II IIai II I iii Ii ii I !! iii iilI II i I i i I i i I II COMPUTATION 'D'ATE APRIL.6~ -198~ "D.-A T E'.:: 0 F: .'::$' U'R'VE Y: A PR I L 'BOS$-1'6775 KELLY BUSHING ELEV° 5, 1981 = 48.70 FT. TRUE NORTH SAG 8 Re: Our Boss Gyroscopic Survey Job No. Boss-16775 Sag Delta #8 (SEC27 TI2N R16E) Wildcat Field North Slope, Alaska Survey Date: 4/5/81 Operator: John Samec Horizontal Projection Scale 1" = 200' SURFACE LOCATION (3308WEL0375SNL) ARCO Alaska, Inc.m~]~ Post Office E~ ,60 Anchorage, Alaska 99510 Telephone 907 277 5537 June 29, ~ Mr.- Hoyl e Hami 1 ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' Renaming Former West Sak Wells Dear Sir- ARCO Alaska, Inc. has recently changed the names of three of its West Sak wells to Kuparuk wells. The changes are as follows' Old Name API# New Name 50-029-20237 Kuparuk 18,5 50-029-20266 Kuparuk D-8 "~-T~t Sak #12 50-029-20313 Kuparuk A-8 If these changes meet your approval, we will begin immediately to' refer to these wells under their new names on future state permits and reports. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG-sp CC' D. S. Smiley D. Sampert J. Pawelek S. Jaime J. Merritt RECEIVED JUL 0 1 1981 011 & 6as Cons. Commission ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieidCompany RADIUS OF CURVATURE METHOD OF COMPUTATION '_~~E_~_ FOR GLDD BY FM LINDSEY 6 ASSOC RECORD OF SURVEY · " ': : :' '. :, · ::' ' TRUE DEPTH DEPTH .SEA ANGLE DIRE( D M DEG, DISTANCE ANGLE DEG/IOOFT D M S : _.S.~.C. T_ I O.'i_ D I 0 0 W :. 0,000 C'.O0 2705 0 0 2705,00 2656.30 N O,OOE 0,00 S 0.00 W 0.00 $ 0 0 0 W 2837 2 30 2836.95 2788,25 N31.00E 2.74 N 0.76 E 2.84 N 15 30 0 E 0,000 O,OO 3023 5 Z~5 3022,46 2973,76 N13,00E Z5,09 N 5,~5 E ~5,95 3053' 6 30 3052.29 3003.59 N 9,00E ~B,2~ N 5,~6 E ~9,~2 _~084 7 !5 .... 3C93.06 ~034,36 N 6,00g 21,91 N 6.24 E 22,79 N20.58 5Z E N 20 22 5 £ N 19 44 53 E N 18 50 11E N 17 31 45 E N k5 54 17 E N14 22 55 E N t2 53 ,6 E N.9 53 19 E 3368 14 0 3361.63 3312.93 N 8*OOW 76.16 N 6.57 g 76.44 N 4 56 5 E 3461 15 15 ' 3451.61 3402.91 N'8.00W ' 99.41N 3.30 E 99.47 N 1 54 21E 3584 18 0 3569.46 3520.76 N 6.00W 134.34 N 0.97 W 134.34 N 0 25 4 W 211 500 568 5O6 ~24 682 94.5 096 748 344 241 9.99 i5.63 3i*41 47.26 75.89 97.g8 3678....21 15' '..3657,99 3609,29 ~`:~N~::::7:~:~?:::~::~:16.5~:7~:::~::~N:.~:::.::::::::::::::::::::::::::::::::::::::::::: : :165,76 N 1 34 26 3955 26 30 3908.6'6 3859.96 N 1.OOE 283.05 N 7.65 W 283.15 N '1 32 59 4048 25 30 3992.24 39~3.54 N 6.00~ 323.7~ N 5.%7 W 323.77 N 0 5~ ~3 ~Z~? ZD 0 ~075,Z~ ~0Z6,5~ N 6.00g ~60.90 N ~.26 W 360.90 N 0 ~2 2 W · , ,3,,460 W . · :::~.306 W 0,815 W le466 W 2,7/.+7 161,25 195,66 275,47 315,79 352.97 · ., E 2.066 389,15 , :. CONFIDI NTIAI .' .. DRIFT V~E ~ ~-~'~'-f ,TOTAL ~'~NATES C [ ~ ~ 0 ~ ~ S SEVERITY DEPTH ANGLE DEPTH GEA DIREC ' D1 STANCE ANGLE DEG/~OOFT D M DEG. . , ~ D M. S SECT ]..6:39 4606, 15 0 4514.99 /+466,29 NiO,OOE 509.35 N /+817 9 0 4723.2/+ 4674,54 N].4,00E 552.64 N 28.64 E 553.38 N 2 58 0 E 2.817 __4_9_66 _9_ 45 4870,35 482]~,55 N15,00E 576,13 N 34.71 · · .............. ~5 '11;~ E:. ~ 0.562 8 11 0 5413,29 5364.59 N17,00E &70,94 N 62.93 E 673,89 N 5 21 31 E 0,112-- 5734 11 0 5625,32 5576,62 N19,0OE 710,1/+ N 75,67 E 5____95210 0 5839.67 5790,97 N2'2 , OOE 6168 7 45 0.461 6475 5 30 ].,042 430.72 747.35 N 89,58 E 752.70 N 6 50 7 E 6053 · 07 5004'37 :ii:.~ N23'* 0OE';i ::: '::: 77 8' 1'3; :N ;. :? i02'~:':3:i:3;!i':"E!i~;i: :::~ 78/+' 83 i:~N· 7 31: E 6358'00 6309'30:ii: N27'OOE:~' ~:i'i:!810'22::"N'i' ?N-/.~8' ].4 ],5 6539.23 6~90,53 '..N29,-OOE ::8'24,93: N;:'/; ~7 E · ~ 546,77 602.14 b59.50 6657 5 0 7119 3 30 853,28 N ].44,23 E 865.38 N 9 35 40 E 7642 2 0 874,61 N 157.~1 E 888,64 N 10 11 47 E 8167 1 30 889,02 N 164,~3 5 90/+,08 N 10 28 2~ E 88/+2 0 15 6999.95 7522.33 80/+7.09 8721.99 6951,25 N39,00E 7473.63 N24.00E 7998,39 N28,00E 8673.29N76'O!OE,~'~' :..; ].7.2"22'E 91~.,59 N '].0' 5:31': 2~' E 0.73~ 0,27~ 0.325 0.287 0.095__ THE FOLLOWING THREE ARE TOT¢O 9240 0 a5 9119.98 9071.28 N76.00E 896.02 N 175,59 E 913.06 N 11 5 16 E 9559 1 0 9438.94 9390.24 N76,00E 897.20 N 180,32 E 915-14 N 11 21 50 E 9921 0 '/+5 9800'90:. 9752e20. N76.00E.: ::~:8::98.53 N.: ..:i::1:8'5:i:68 E::':i ::.:917,52 N..:ii'l::~:,40 33 g 0.125 912.99 o. o 7 9_ks _t_t_. 0.069 ~;17.52 10131 0 45 10010.88 9962.18 N76.00E 899.20 N 188.35 E 918.71 N 11 49 49 E 0.000 918.71 :BOTTOM HOLE CLOSURE :: 91'8.':71 "FEET' ~' ' . : :.' .... ., .. · .:~: ~ .... A.T :.: ~1 :. 11 :i::.;i4 9 ':49 ~:;:ii:.:E:. .':: :::::::::::::::::::: :F: ;::~:~:'!':: :: ::i:::--'::: ::: :-!;: ·' · · . . . FEB 8] NEASURED DEPTH 149 240 349 449 549 ~"' 649 749 8~_9 949 1049 1249 1349 __14 1549 1649 1749 1849 1949 2049 2149 2249 2349:::': 2a49 2549 149, 100 0 0 0.00 S 0,00 W 249, 200 0 0 0,00 S OeO0 W .. ~. 3 ~.. ~3oo.. · ..... .---o "-'"o'.-'--"~"..~:.:'":".~--'~::.::'::' .......... ' ....... '.:' .... ~ ....... 4 ...... .... "':" """'?"' ''~'':'' .......... '""' '"'::' ...... ::~'; ': ''~ :':::" ' ' ' ; ,¢., u ~ '"~ O' ' 00 W . ~. 549, :. 500 :' : f'] ?.0 0................:...............:..:......:......~.:~ :.......:.:...,....:...::.., :...: ...-.0 ,. 00 S '::~.: .:'-...-i~."-..:::' 0,00 W.': 649, 600 0 C 0,00 S 0,00 W 749, 700 0 0 0,00 $ 0,00 ~ '~ ~::' '": ~ 'iii!!!ii'i:!!i~?ili i:i!~: :::'~:: ilili]i!:!:iI !!::i i:i~!:~iiiil :i! ~~ ii]~!~:i;" !'!'"'"':';':il 0._0_0 W .::.::~ ... :...i: .', . i'!i!:::: ::: i]:ii:.'?i::': i 'i..ii ':]~ 0" O0 W ; '': ' 0'.00 W :1 0,00 S 0.00 W 249, 1200 0 0 -- 1349, 1300 0 0 0,00 S 0,00 W !.,449, 1400 0 0 0.00 $ 0,00 W 1~500:.'.-..:~ ~.~.~:..~:~:::iii:::!~.~?:!~!:~:~:i:.~.:%:!?~:!~:~.:::i~?~.~!:~::~:~ :~'::.i~!/': i "-: O, O0 $ O. OO w 15.4:9...~ '~ o "-!':-::.'.;(f?' ':'~'~:: ~::~::, '...:~:'! i'"'"'::.:': o..:'o s -":. ' t6~9. 6o'-."::o...'-:.' · · .... ' ...........: --'" ' ............. 0,00 W 1749, 1700'" ' 0:'.: '0~'00 S' "0.0.0 1849, 1800 0 0 0,00 S 0,00 W 1949, 1900 0 0 0,00 $ 0,00 W 2049, 2000 0 0 0,00 $ 0,00 W 2149, .:~ 21.00.: ... :..'-'-:::.0' ~.. : : ':'.0:'-'. ~: ::~. ....... .i . O, O0 22'49.' ~:'..Z'ZoO.-. :'~::.:.?i:"o"'::'-' :. i~:."-... '.:-..':!:..-".~o.:::-':~'/~:~-:-!i.: i//(:!!i!:i'.'.:.:.~-.-:~'i.:?i::..::: 0:.oo'''a. '..::- o.oo w . - :S:"f':,.." :: '"" 0 · O0 2349. ':-:..:'- 2300- :'::-.-~i-:'::.::...i:! 0:::: :':::--..":~'.i:::~:i.!~':.."::.i'-" !:i:.:.~::':0' i:":'$"'-::~/'i!:-:..::"~i;..' 0.00 W 2449. 2400 0 0 0,00 S 0,00 W 2549, 2500 0 0 0,00 $ 0,00 W 2649, 2600 0 0 _2_649 · 0,00 S 0,00 2749 · 2749..-:2700 ...:..":. 0::.' :.-:. ; O. : '~ : :'" 0'31 N,. 0.02 3049 3049, 3000 0 0 17.79 N 5.68 E 3150 3149. 3100 1 1 31.25 N 7.07 E ____ 3zsz ~Z49, ~ZO0 3 2 50,11N 8,28 E . ::" 3355 .::' ::~: .~,: '33~ 9 · ::-~::~.:~?::::! 3300 '!:.::i :": ::~ i z. 11 ~ !:. 3458 :113449e 3400 '9 : 3.41 E :. 3562 ' 7-67 N 0.24 W :~ ,,.' . · ·. .... . . .nl ll:lnl:MTI A I CONFIDENTIAL MEASURED ':::~' VERT, ICAL.~::::.$Ui~] : MD 7VD:' ' '": V ..................... 7268 71a9. 7100 119 0 860,11 N 149,36 E 7358 7249, 7200 119 0 864,39 N 152,14 E 75687468' ~ 13. 49:: ' .:::..:..!; ..:, 7300 .'i :::i.. :!: :i ..... , . ,.. , ....... . ........ , ..... . .......................................... . ......... . ....... . .... 7758 / 7649. 7600 ~9 0 878.4~9 N 7868 7749. 7700 7969. 78~9, 7800 12Q 1 884,11 N 161,79 E CONFIDENTIAL MEA 5UR ~ O '~:::t :'(.: t:.V E'R'T. IC :::CAL ::~.:.:.?-;:?f:;:::::::::::::: :: :::::::::: :::::::: :::::::::::::::::::::::::::: c. · ': """?": : '~' :)..:~.:.~:~:.:~.%: i /.:. '~ .: .. 3668 3649, 3600 19 6 .162,13 N 4,12 W 3~7_6 3749, 3700 27 8 203,57 N 7.79.. W .................... ~:: · : .:: : · :.:.?:::::::.. : . ......:..::::: ...... : ..:.::::.: ':. ,.: .......~.. . . 4218 4149, ~+100 69 8 390.54 N 2.06 E 4325 4535 4639 4843 4944 5147 5249 5452 5554 57~8 5860 6063 616a 6264 4249. 4200 76 7 427,62 N 6,61 E -- ~3-~-9-*.~ ~_9_.3ZLO 0_2 .. 6 444l- I 46L,_12 N 11t08 E 9.~:.l.,:~44ooI l:~:~s6 I : ~ ~ lS,zz ,~~':: ::,..:::: )4~o:: 'l:::'.l:.:: : .~'2': ~ :-l: ?:;~;~'::':?:.~::S'~ ~": 7l~. ':"N l~l'l '7':l~''ll~ zI .~ ill' :' :. .. ....... ss 'Sa ...... 4849. 4800 95 1 572.55 N ~.75 E ~949,. 4~0 97 2 589,33 N 38,~4 E , ~ ~49-; ~" :~5 ~0'0:' :'. ':' ~ 00':: ( · :r,: '"~'"': :.~: ~ ~9 N ' ~8 '"z z: 524~ ~ 5200 .~1 . ::.~..:-:?: :::640:~SfS.:.N .... .:..':..' 53,_6.4 5349, 5300 ~03 2 658,94 N 59,26 5~49, 5400 105 2 677,51 N 64,96 .E549_. E5~.Q_~07 . ~- . 696,~ N 70_,91 E 56~9. 5600 109 :- .. .... :::::::::::::::::::::::::::::: '-' "~714.~1.. N 77'15 5949. 5900 114 · 2 764.10 N 96.43 E 6049. 6000 115 1 777,58 N 102,10 E 6149, 6100 !~5 0 789. $~_ N _! 07 ,~_8 .~349' :r 6300' ~"117 .:~ ~.t. t ~..: ~N :':1.1~,88 -'6449'~ '~::: ~400 117 ~ '~: ~ :~"..i~23. E. 6549, 6500 117 0 825,61 N 125,49 E 6649e 6600 118 1 832.91 N 129e76 67~9, 6700 118. 0 839,50 N 133, ...~ "6949 e ...: :~.::::t~: 6900: . '~119 ' :':':~'"~ ~i:~' '..."~ ::~ '~.I'~:.'~' .~.~ '~:':~ :~:..: ~.~t?~.:t: 850'79~:t N' : '~ 1 $2,11 6666 6767 6c367 6967 7068 l!.~_~_ 6365 6466 .6566 SOH 0 ~NTER~OLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, -.- 1000 ~000. 95~. 0.00 5 0.00 W 2000 ~000. ~95~. 0.00 5 0.00 7000 6881. 6832. 8~7.27 N 139.~6 8000 7880. 7831. 88~.94 N 162.20 E . . . . //Atlantic~RichfieldCompany North Ameri~* Producing Division North Alasi~ .~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 15, 1978 Mr. Hoyle Hamil ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 \ SUBJECT~st Sak ~'Permit No. 77-1 West Sak Riv~P-State #7, Permit No. 77-53 Dear Sir: Enclosed please find our Sundry Notice of Subsequent RepOrt detaili.ng the work done on the above-mentioned wel 1. Very truly yours, F. M. Brown Di strict Dri 11 i.ng Engineer FMB' ml n Enclosures Form 10-403 REV. 1-10~73 Submit '1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposels.) 1. O,L ~ GAS [--'] WELLI~I WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 5. APl NUMERICAL CODE 50-029-20266 6. LEASE DESIGNATION AND SERIAL NO. ADL 25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME West Sak River State 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360, Anchorage, Al( 99510 A8 4. LOCATION OF WELL At surface 601- FEL & 600' FNL Sec 23, TllN, RIOE 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 30' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Kuparuk River Pool SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 23, TllN, RIOE 12. PERMIT NO. 77-53 )orr, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT ' MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SNOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEt Report results of multiple completion on Well ComDletlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all i~®rtlnent ¢letails, and give pertinent dates, including estimated.date of starting any proposed work. Began moving in equip for Frac treatment 7-27-78. Opened well for flow tst. Well flowing on 30/64 choke @ rate of 368 bbl oil/day, GOR 531, API Gvty 22.2. Flowing wellhead pres 145 psi. Cont flow tstg well. Did ball out job w/1.1 specific gvty balls. Pumped 4000 gal diesel w/lO% U-66, maximum pres 2800 psi. Job did not ball out. Flow tstd well. RU Dowell for fracturing treatment. Tstd lines, found bad hoses. Suspended job to repair equip. Began frac job. Pumped 167 bbl of Gel diesel spacer ahead. Pumped 167 bbl Gel diesel w/1 ppg sand @ 18.5 bbl/min rate. Pres 3600 psi. After 266 bbl pumped, increased sand to 2 ppg. Pres 3500 psi. After 369 bbl pumped, increased sand to 3 ppg. Pres 3400 psi. After 476 bbl pumped, increased sand to 4 ppg. Pres 3200 psi. Displ total treatment of 521 bbl w/6.0 bbl diesel. Shut well.in. Waiting on gel to break. Flowing well. Well flowed @ rate of 782 bbl/da~v,~ gas volume 257 MCFD, GOR 404, Gvty 26.3 API, Flowing well. Pres 235 psi on 48/64" choke. Cont flow .tstg Well, & taking bot.hOle pres sur. Well shut in for pres buildup. Final flow rate 916 bbl/day, gas volume 253 MCFD, GOR 276. Flowing wellhead pres 320 psi on 1" surf choke. Cont shut in pres buildup. Completed bot hole pres & temp sum. RD equip& suspended operations @ 0600 hr~-~i~.VED ,, ~{ianticRichfieldCompany North Ameri~' Producing Division North Alaska Jtrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 5, 1978 Mr. Hoyl e Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: West Sak River State #A8 Permit No. 77-.53 Dear Sir' Enclosed please find-a Sundry Notice outl'ini.ng our plans for the above-mentioned wel 1 ' Very truly yours, Frank. M. Brown Di strict Dri 11 i.ng Engineer' FMB:jh Enclosure RECEIVED JUL Approved Copy~ Returned Form 10-403 REV. 1-10~73 "Intentions" in Triplicate Submit & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for ~ch proposals.) ~' o,- i-;! GAS 1'-'1 WELL! ~1 WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 4. LOCATION OF WELL At surface 601' FEL & 600' FNL Sec. 23, TllN, RIOE 13- ELEVATIONS (Show whether DF, RT, GR, etc..) 30 RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20266 !6. LEASE DESIGNATION ANO SERIAL NO. ADL 25650 7. IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT, FARM OR LEASE NAME West Sak River State WELL NO. A8 10. FIELD AND POOL, OR WILDCAT Kuparuk River Pool '11.' SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 23, T11N, RIOE 12. PERMIT NO. 77-53 3ort, or Other Data NOTICE OF INTENTION TO-. TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF= WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTER I NG CAS lNG SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE, Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates~ including estimated date of starting any proposed work. To fracture treat the Kuparuk Sand with 32,000 lbs 20/40 sand carri'ed by 21,000 gallons of treated diesel oil. Perforations to be'treated are in the'top'portion of the sand between 6384' and 6484'. After treatment the w~ll will'be tested:for a period of approximately one week. ' Anticipated starting date is July 21, 1978 to be cQmpleted by August 1, 1978. RECEIVED 16. I hereby certify that the foregoing Is true and correct TITLE Di strict' DH11 ing Engineer .. DATE ,. (This space for State offlceeuse) . CONDITIONS OFZ~PROVAL, IF A~: .... See Instructions On Reverse Side DATE Approved Copy,,~ Atlantic~RichfieldC'ompany North Amer~'" ..... '~roducing Division North Alask[ .~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 27, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: West Sak River State A8 .... Permit Ilo. 77-53 Dear Sir: ~ '/ . Enclosed please find our Completion Report for the above-men- tioned well. The~coring and testing data will be sent as soon as possible. Very' truly yours, Frank M. Brown District Dril lng Engineer FMB: j h Enclosure CONFIDENTIAL D.!:STI:~t]]UTED TO: STATE OF ALASKA DI VI~,~ON OF OIL & CAS Si' gnature Date Title Form · OIL AND GAS CONSERVATION COMMITTEE ~,,~.~ i i iiii i ....... WELL cOMPLETION OR RECOMPLETION REPORT AND LOG ~. T OF W~LL: ............. O~L WELL WELL DRY Other b. TYP~ OF COMPLE~ON: ~ ~ wo~,~ ~ ~-~ ~ ~ ~'~' ~ Suspended WELL OVER EN BACK RESVR. Other ,,, .................. ~. NAME OF OP~RATOB At]antic RSchfie]d Company ADDRESS OF OPERATOR P. 0. Box 360. Anchoraua. ~]aska 99510 LOCATION OF WELL ~(~R-~po~'t location c]ea~ly and in accordance wit~ any S}ate requirements)* At su~ace 600'S & 600'W of N[ cr Sec. 23, IllN, RI0[, UM At top prod· Interval reported below Same as ~bove 4/7/78 I 4/22/78! 5/14/78 18. TOTAL D~'P'I'H, D & TVD [19. PLUG BACK MD & TVDr. IF 1VII3LTI~LE COM~L., ] 21. DEPTH I~OW 1V/.ANY* ROTARY TOOLS 6880'MD & TVD [ 6550'MD & TVD|, SJn,q]e [ Al], 22. PRODUCING INT~VAL(S), OF THIS' CO.MPLETIOBr---TOP, BOTTOM, Bra/VIE (NII~, AND 'CUD)* Top Upper Kuparuk Sand 6391'MD & TVD Base Lower Kuparuk Sand 6657'MD & TVD 5. API NUM_F,B.I~ CODE 50-029-20266 ADL 25650 7. IF INDIA.N, ALLOTTEE OR TRIBE NA/V~ 8. UAFIT,FA/~Vi OR LEASE NAME -Wes. t::-Sak~R4qe~.~. , , , ~. W1Wr,T. BrO. ~ F~ ~~L, ,OR ~T FruO~oe gay ~uparuK ~iv~r Oil Pnnl n. s~c., ~,, ~., ~., ~~ ~o~ O~IVE) Sec. 23, T1 IN, RIOE 12. PER1VIIT NO. 77-q~ 18:' ELEVATIONS ( 'D'F' RKB'' RT' GIt' 'ETc~*] 17' ELEV' CA$INGHEAD108' RKB INTERVALS DRILLED BY [ '~ CABLE TOOLS · 'WAS D~RECTIO,NA_L i SURVEY MADE i No ITYPE ELECTRIC AND OTHEI% LOGS RUN ' ' DIL/SP/GR, BHCS/,GR/CAL, FDC/CNL/GR/CAL, Microlog, CBk/CCL/Velocity Surv,ey ' CASING RECORD (Repo~i ali Strings set in well) ' CA$I-NG SIZE -/' WEIGHT; LB/FT. , GRA~E I DEPTH SET (M/)) , HOLE sIZE., CEB~NTIi~G RECOI%D A/VIO~T PULLED 16" t "165#' ~ H-,4,0 ,175',(G¢6u~d ~_evl 30' 475 sx:ArctJcset ,I,I cmt, 10-3/4" 45.5#'i'Bugt! K-55 I 2227' 113,3/4' 2400 .ax ?armafrost cmt. I I II ; l 27' TUBING R~OOH,D ...:. ' ....... j ............ . .., ,., , , :,, PERFORATIONS OPeN TO PRODUt21'ION (Interval, size and number) [ 29. ,,ACID, SHOT, F~A~CTURE, C'E/VlE. NT SQUElgZE, ETC. ' 6636' - 6641' ! D~"'U*~''' ..... ~ r".'"'/I 4 I /- ,-r .... ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct-well completion report end tog on all types of lands and leases in Alaska.' Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- · .meats given in ather spaces on this form and Jn any attachments. Items 20, and 22:: If this well is completed for separate production from more than one interval zone · (~nultiple completion), so state in item 20, and in item 22 show the prcJucing interval or intervals, , tgp(s), bottom(s) and name (s) (if any) for only the intervat reported in ~item 30. Submit a separate report '('page) on this form, adequately identified, for each' additional inte~ val to be seperately produced, show- ing the adlditional data pertinent to such interval. Item26: "Sacks Cement":_ Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 211: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. ~TION TESTS INCLUDING INTERVA.L 'TESTED, PRESSURE ~)ATA A/q'D RECOVERIES OF OIL. GAS, WATER AND..MUD 35. GEOLOGIC MAR KI~R~ 3/1. CORE DATA. ATTACll BRIEF DESCRIPITIONS OF LITHOLOGY. POROSITY. FRACTURES. API~A.RENT AND DETEC~I'Ei) SItOWS OF OIL, GAS OR WATEH. _ DIPS' NAME Top Upper Kuparuk Sand Base Upper Kuparuk Sand Top Lower Kuparuk Sand Base Lower Kuparuk Sand MEAS. 6391' 6500' 6643' 6657' V£RT. 6EPTH 6.391' 6500' '6643' 6657' DRILLING HISTORY WEST SAK RIVER STATE A8 API 50-029-20266, ADL 25650, Permit No. 77-53 Spudded well @ 0900 hrs. 4-7-78. Drld to'2260' Ran DIL/SP/GR, BHCS/GR/CAL logs. Ran 10-3/4" 45.5# K-55 csg set @ 2227', FC @ 21~6'. Cmtd w/2400 sx Permafrost cmt mixed to 14.9 ppg slurry.' Drld shoe &~tstd form to 11.5 ppg equiv. Drld to 6311'. Began coring, core #1 6322-635'5', rec 42'; core #2 6355'-6415', rec 58.5'; core #3 6415'-6475', rec 60'; core #4 6475'-6526', rec 29'; core #5 6526'-6551', rec 20..5' core #6 6551 '-6611", rec 50'; core #7 6611 '-6670', rec 59'; core #8 6670-6730', rec 54.5' Drld ahead to 6880'. Ran DIL/SP/GR, BHCS/GR/CAL & FDC/CNL/GR/CAL logs. Ran microiog. Ran RFT's. Took sidewall cores from 3478-6403' Ran 177 jts 26# J-55 7" butt csg. Cmtd w/15 bbls Sand-5 spacer, 13 ppg fo!lowed by 350 sx Class G cmt 12% salt, 0..05% CFR2, 0.1% HRT, 12,6 ppg followed by 2'25 sx Class G 10% salt, 1% C,FR2, 15.8 ppg slurry. Displ w/274 bbls mud. RIH w/RTTS tool, set @ 2118' Pres tst 7" csg, oki 'Pres tstd below 'RTTS, ok. POOH w/RTTS. Ran CBL/GR/CCL iogs. CBL i~'ndicated csg parted, w/5 jts dropping down hole 34". Bot of 7" @ part is 6634,. Recmtd '7" csg thrU holes @ 6300', 4.ho!es/ft. Set cmt ret'@ 6350' & tstd ok. Made down sqz 7" x '10-3/4" ann w/300 sx cmt. Released RTTS: Closed lower FO. Did Arctic Pack job. Perf'd 6300,6301' wi4 holes. Ran sqz stinger. Stabbed into top ret @ 6350'. Broke circ around 7" csg & out thru holes @ 6300'. Recmt 7" csg w/175 sx Class G cmt. Press tstd 7"; ok~ Drld cmt to 6312' Press tstd perfs @ 6300'. 1300 psi brOke down. Set EZ drl ret. Sqzd perfs ~/150 sx Class G cmt. Left 15 sx cmt on top of ret~ Drld 6312'. Press tstd perfs, ok. Drld to 6342'. Press tstd csg. Broke down O. 1400 psi. Set EZ drl ret @ 6220' Cmtd w/lO0 sx Class G cmt. Drld r'et & cmt to 6345'. Press tstd csg, ok. Drid ret @ 6350'. Drld cmt out of.csg. CO to 6677'. Ran GR/CBL/CCL. Ran velocity survey. Displ mud w/10..6 CaC12.~. 'Perf'd w/4'shotS per ft. 6644'-6652' & 6636'-664.1' Made up tst head. Set pkr @ 6562'. Ran 500' diesel cushion. ,Flowed well. Si well. Perf'd 6384'-6472', & 6479'-6484' w/4 shots per ft. Set pkr @ 6261'. Flowed well. SI well. LD tst assy. Ran.~gauge ring &'j'unk bskt. Set EZSV bridge plug @ 6550'. RIH w/Baker, pkr & comp assy: Pkr set @ 6289' w/tail @ 6337' Press tstd anu!, ok. NU & tstd tree. Displ tbg w/d!~esel' Pulled dummy valve. P~ess .tstd tbg. Ran 2.5" gauge ring. ~Set flapper valve-@ 2008.'. Tstd, ok. Installed & tstd tree cap, ok. Released rig. @ 0600 hrs 5/14/78. /la,~ticRichfieldCompa~('~ · ~r ~%.~ ( ;ore Description Report ARCo West Sak #8 · 1 1 Location Date Sec. 23 TllN R10E 6/20/78 Cor'---~ number Ilnterval lout Recovered 1-8 6311-6724 413 374 -- Depth Thickness Description 6311-6391 80' Shale, black to dark gray, fissle. _ -- 6391-6490 99' Sandstone, very fine to coarse grained brown, pqorly __ sorted, oil show. _ -- 6490-6504 14' Siltstone and coarse glauconite. Light brown to emerald green. Poorly sorted. -., 6504-6643 139' Interbedded silts and shales. 2" beds or less. _, -- 6643-6657 14' Sandstone, very fine grained, cross-bedded, brown, oil show. 6657-6724 67' Interbedded shales and silts. 1-2" beds, light brown to dark gray. · __ · _ · · .................................................. ~'_ :..~i ................................. --JUN 2-2-:1978 Anchorage Described by R. Tucker AR3B-2389 Core numberl_ 8 AtlanticRichfieldCompany North Ameri.~~''' ~roducing Division North Alask["' .otrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Harold C. Heinze Engineering Manager June 16, 1978 Mr. O. K. Gilbreth, Jr. Director Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: A well test summary and core descriptions of the West Sak No. 8 well are attached. The information is being submitted in a sealed envelope with the request and understanding that the data will be kept confidential in accordance with the provisions of AS 31.05. 035 (a) (1). We trust that this is satisfactory and is sufficient to meet your requirements. Sincerely yours, H. C. Heinze HCH/CWF/jb ' Attachments REC V, D JUN 2 1978, Division 0i Oii ,:¥< .:~:~s C~i~s~¥atioil Anch0ra~a WEST SAK NUMBER 8 TEST SUMMARY Repeat Formation Tests (RFT) (4/23/78 - 4/24/78) Schlumberger's Repeat Formation Tester was run on wireline before the hole was cased. Twenty pre-tests were attempted in the Cretaceous interval (@ 3714 and 3716' KB), the Upper Kuparuk Sand (@ 6412' KB), the Lower Kuparuk Sand (@ 6640, 6648 and 6650' KB), and the siltstone interval (from 6510 to 6600' KB). Interpretive pressure and flow data was obtained. This data was used to evaluate possible productive zones prior to setting casing. 'Liower Kuparuk Sands '(5/5'/7'8- 5/7/78) D.S.T. #1 The intervals from 6636 - 6641' KB and 6644 - 6652' KB were perforated with a four inch casing gun in 10.6 ppg calcium chloride water. During the initial flow period of 20 minutes, no surface pressure was noted. A Hewlett-Packard bottomhole pressure recorder was run and set at 6425' KB. The initial downhole flowing pressure was 967 psig. No formation fluids surfaced during the final flow period of 8.3 hours. The final downhole flowing pressure was 1613 psig. During a shut-in period of 12 hours, the bottomhole pressure increased from 1620 to 2426 psig. Wireline samples were taken at 6425' KB. The field measured gravity of the recovered oil sample was 11.8°API at 60° F. The downhole sample Was gaseous. When the drillstem assembly was reverse circulated, surface samples were caught. The gravity of one of these samples was 16.9°API at 68° F. The drillstem test chamber contained a small amount of oil and what is believed to be calcium chloride completion fluid. 'upper &' L'ower Kuparuk' 'Sian'ds ' (5/7/'78' - 5/11/78 ) D.S.T. #2 The Upper Sand and the previously referenced Lower Sand were tested during the second drillstem test. The following Upper Sand intervals were perforated with a four inch casing gun: 6384 - 6472' KB and 6479 - 6484' KB. A Hewlett- Packard pressure recorder was run and set at 6370' KB. The initial flowing bottomhole pressure was 2314 psig. During a flow period of 48.6 hours, the average flow rate was about 742 BOPD with a GOR of 370. The crude oil gravity as measured 'in the field was 23.4°API. The gas specific gravity was 0.732 (air = 1.0). The crude was foamy with entrained gas. At various stages of the flow test, a defoaming agent and heat were added to the produced fluid. The final flowing pressure at 6370' KB was 1887 psig. The well was shut-in for 15 hours for pressure buildup analysis. The ini~~-~ shut-in bottomhole pressure was 1936 psig, and the fi~~i~V~D pressure was 3203 psig. JUf 2 2 A~hora~ At].antic Ric]~field Compan3~ North A]_ac-'~-~ ])ist--' ~ 1 ].Ct. State Of Alaska Division Of Oil And Gas Conservation 3001 Porcupine Drive Anchorage, Alaska TRANS:'.IITTAL Fr oln: R. A..,XicIntosh/North Geological 6-13-78 l)a re' Transr..:itted herewith are the following' West Sak River State #8 Final Prints, lblue!ine and 1 sepia each. Dual Induction Laterlog 2"5" Borehole Compensated Sonic' ~og 2"5" Proximity Microlog 2"5" Compensated Formation Density Log 5" Cement Bond Log ' 5" Cement Bond Log 2" Borehole Geometry Log 5" Compensated Neutron Formation Density Log 5" Mud!og 2" Run 1,2 Run 1,2 Run 1 Run 1 Run 1,2 Run 2 Run 1 Run 1 100-6880 ft. }:'~e c e i p t: a ckn o~.,~ 1 ed ge,: · }k~turn receipt to' Atlantic RiCt'~r/e].d Co~gt'~any North A].asl.ca District Att:n: District Geologist P.O. Box 360 Ancl~orage~ Alaska 99510 ,. · Dan P Nice Pro c_cs.;ea by: · /RichfieldCompany North American Producing Division North Alas¥ ;trict Post Office~ . 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 10, 1978 CONFIDENTIAL' D!STBIBLYrED TO~, S'!'ATE OF ALASKA 9I¥ISION OI~ OIL & O~ Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' West Mikkelsen State #1 Permit No. 78-17 ~--"~est Sak River State A ~8-~ Permit No. /7-53 'Iai ,",/ ,'-; =r-,r · ' '~"' ' ;_' v' _ . - --~ - _ ~ - L., ..;'.; :' "~: ' i;;, ' ' Enclosed please find the Monthly Report of Drilling Operations for the above mentioned wells. We consider these holes extremely tight and would appreciate your cooperation in placing this report in secured storage where it will receive minimum exposure. Please acknowledge receipt, of the attached report by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Very truly yours, Frank Fi. Bro. wn District Drilling Engineer /am Enclosures Signature Date Title Form ~o. P-4 (~ REV. 3-1-70 '~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING APl NUMERICAL CODE 50-029-20266 SUBMIT IN DUPLICATE 6. LEASE DESIGNATION AND SERIAL NO. ^DL 25650 AND WORKOVER OPERATIONS 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME ATLANTIC RICHFIELD COMPANY West Sak River State A 3. ADDRESS OF OPERATOR P.O~ Box 360~ Anchoraqe, AK 99510 4. LOCATION OF WELL 9. WELL NO. #8 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Kuparuk River Oil 11. SEC. T. R. M. (BOTTOM HOLE Pool OBJECTIVE) 600' FEL, 600' FNL, Sec 23, TllN, RIOE Sec 23, Tl lN, RIOE 12. PERMIT NO. 77-§2 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. REPORT OF OPERATIONS FOR THE MONTH OF APRIL 1978. Spudded well @ 0900 hrs. 4-7-78. Drld to 2260'. Ran DIL/SP/GR, BHCS/GR/CAL logs. Ran 10-3/4"4 5.5# K-55 csg set @ 2227', FC @ 2146'. Cmtd w/2400 sx Permafrost cmt mixed to 14.9 ppg slurry. Drld shoe & tstd form to 11.5 ppg equiv. Drld to 6311' Began coring, core #1 6322-6355', rec 42'; core #2 6355'=6415', rec 58.5'; .core ~3.6415'-6475', · rec 60'; core #4 6475-652.6', rec 29'; core #5 6526-6551', rec 20.5'; core #6 6551-6611', rec 50'; core #7 6611'-6670', rec 59'; core #8 6670-6730', rec 54.5' Drld ahead to 6880'. Ran DIL/SP/GR, BHCS/GR/CAL & FDC/CNL/GR/CAL logs. Ran microiog. Ran RFT's. Took sidewall cores from 3478-6403'. Ran 177 its 26# J-55 7" butt csg. Cmtd w/l.5 bbls Sand-5 spacer, 13 ppg followed by 350 sx Class G cmt 12% salt, 0.05% CFR2, 0.1% HRT, 12.6 ppg followed by 225 sx Class G 10% salt, 1% CFR2, 15.8 ppg slurry. Displ w/274 bbls mud. RIH w/RTTS tool, set @ 2118'. Pres tst 7" csg, ok. Pres tstd below RTTS, ok. POOH w/RTTS. Ran CBL/GR/CCL logs. CBL indicated csg parted, w/5 jts dropping down hole 34'. Bot of 7" @ part is 6634'. Recmtd 7" csg thru holes @ 6300', 4 holes/ft. Set cmt ret @ 6350' & tstd ok. Made down sqz 7" x 10-3/4" ann w/300 sx cmt. Released RTTS. Closed lower FO. As of April 30, did Arctic Pack job. Perf'd 6300-6301' w/4 holes. Ran sqz stinger.. Stabbed into top ret @ 6350'. Broke circ around 7" csg & out thru holes @ 6300'. RU to sqz. CONFIDENTIAL DI~SIO"* "-' C':', ~ ~ 14. I hereby certiorari/at th~otegojog is true and correct SIGNED.._~~A.~g. T~TLE, District Drilling Engine%l~TE 5/9/78 ~ n m NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. April 17, 1978 ¥,..APril 9, 1978 - I left Drill Site 1-18 w~z'e I had just finished Sak No. 8 at 10:30 AM w~.re I m~ to wi~ another BOP test. T(xty Zieto was the supexvisor for Arcx) on West Sak loca~. M~, ~ 10, ~1778 - At 9:00 ~4 ~ ~ starbed and the lower BOP ~ blew ~ ~L~ rs~a shaft. Work ~as started c~ gate at 9:15 PM and ~mn't ~m~~ un%~l 5:00 AM 4/11/78. - BOP ~ were resm~ at 5:10 AM and were am~,]~ ~ter ~as tested first to 2000 psi. 3000 psi. With the t~ pipe :mm still ~, the cutstde ~ a~ nmeb to 3000 psi anct ~ ~ ~ kelly to 3000 psi. ~ ~ kelly :~ four mute ~1.~ ~ t.,esb~ next to 3000 ps.t. ~ ~ a bail and ma~ ~ zead 2500 ps:L; this ,aas set: up to 3000 psi. The nittog~ bado.~ systea ~ ~ bottles with 1950, 1850, 1800, 1850. ~ ~.11 Drlg. Permit No. ~-~9~'~ Opera tor_~/? _/-_ ~ Satisfactory Yes No I tern (2) () (~ () () () () () () Al~.Ka Oil and Gas Conservation Committ. Field Inspection Report Wel 1/Platfm Sec~? l//~/ Represented by~d~//V ~J~!'~ Name & Number/~z_.~,~ pe Inspection SatisFactory Type Inspection ) Location,General Yes No Item (AO BOPE Tests 1. Well Sign 2. General Housekeeping 3. Reserve Pit-~open( )filled 4. Rig ( ) Safety/ Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data ( ) ( ) 7. Well Nos. , , , ( ) ( ) 8. Hrs. obser-- , , , () () 9. BS&W ,--, ,-- ( ) ( ) 10. Gr. Bbls. , ( ) Final Abandonment · ( ) ( ) 11. P&A Marker ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 13. Clean-up ( ) ( ) 14. Pad' leveled Total inspection Observation time__~/~ ~/days Remarks (A) () (~) () (~) () (x) () (~) () (~') () (x) () 15.'/~j'Casing set @ 2227 16. Te--~t f'luid-( )wtr.--]~(-)mud ( ) oil 17. Master Hyd. Control Sys..~w?____psig 18. Nm btls. ~. ,j~'m~,/~/~,~sig 19 R~mote ~rol§ - 20. Drill ing spool-_~"outlets 21. Kill Line-(X') Check valve 22. Choke Flowline (J~ HCR valve 23. Choke Manifold No. valvs//} fl gs/~' (~[) ( ) 24 Chokes-~)Re.mote(NPos.(~'~-dj (~) ( ) 25 Test Plu~-(~]Wellhd( )csg( )none ()~ ( ) 26. Annular Preventer,~Fj~.~psig (.~) ( ) 27. Blind Rams, ~_~zC_psi-_Q,' ~) ( ) 28. Pipe Rams ~,~__psi~ ( ) 29. Kelly & Kelly-cock ~'Jm~ psig ( ) 30. Lower Kelly valve ~---~sig (X) ( ) 31. Safety Floor valve~--~t~)BV (~)Dart Total number leaks and/or equip, failures. ~~ .~/~ :c' ~ ~ .... ~///~¢9~ Not~fY"in ,~-'~.days or ]when ready-----.:. Inspected by,~~/~ AtJanticRi~chfieldCompany North Ameri~/ :oducing Division North Alaska .=,~rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 2, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: ~J'~-~e~S-~'"-'sa~-~-i-~ ..... ...................................... ................ West Sak River State No. BIO Permit No. 77-54 Dear Sir' Enclosed please find three (3) copies of a certified location plat for the subject Wells. Very truly yours, F. M. Brown District Drilling Engineer /am Enclosures cc- File RECEIVED F E B - 6 1978 · DNINelt el Oil and Gas C;mme~.~,,~: 14 Protracted Section Line S89°33, 16"W 5279.50' 1 FLARE I SEWAGE1 PIT MUD PIT i 600' WELL CONDUCTOR WEST SAK No. 8 Y: 5 959 06:3.92 X: 560 491.98 LAT. 70° 17'55,407"N LONG. 149° 30' 36. 395" W 14 23 26 13 PROTRACTED SECTION CORNER Y: 5 959 669.25 !X: 561 086.90 LAT. 70° 18' 01.$13"N LONG. 149°30'18.908"w 0o27'40''' >-4 25 --NOTES-- I. VERTICAL CONTROL BASED ON BRITISH PETROLEUM M.S.L DATUM. 2. TOP OF GRAVEL PAD ELEVATION AT CONDUCTOR 70.7. :5. ALL BEARINGS AND DISTANCES ARE ALASKA'STATE PLANE ZONE 4. 4. FIELD WORK COMPLETED I/8 /78 CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERTY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. DATE SURVEYOR ARCO No. AFE 393665 .,, ~ , RECEIVED FEB - 6 ONlsJoll of 011 and Gas *'~" Anchorage HVL No. KUP-5-SAK-No. 8-78 ATLANTIC RICHFIELD CO AS - BUILT WE ST SAK No. 8 LOCATED IN NE I/4 OF PROTRACTED SECTION 23, TI !. N, R IQ,E_,~ U,M., AK PREPARED BY ' HEWlTT V. LOUNSBURY & ASSOC. 723 W. 6th AVE., ANCHORAGE, ALASKA DATE _ I / 78 CHKD. BY PC SCALE I": ~-00' FIELD BK. 77-118 1977 Sak River State A No. 8 ~ mchf~ C~p~y No. 77-53 A~c ~chf~el~ ~y P. O. ~ Anchora~, ~ '99510 are Depar~ of F~sh an~ ~a~. F.M.~ W. SakR. Stalm~A#8 Deo~oex 7, 1977 Form 10-~01 ' REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL ~] b. TYPE OF ~LL OIL GAS ~ ~LL ~ OTHER · , WELL ~ NAME OF OPERATOR Atlantic Richfield Company DEEPEN []] SINGLE ZONE [~], 3. ADDRESS OF OPERATOR P.0. Box 360; ^nchora§e, Alaska 99510 4. LOCATION OF WELL At surface 600'FEL, 600'FNL, Section 23, .TllN, R10E At proposed prod. zone Same as Above 13. DISTANCE IN MILES AND DIRECTION FROM NEAI~EST TOWN OR POST OFFICE* Approx 30 miles Northwest of Deadhorse SUBMIT IN TR rE (Other instructl% .a reverse side) I~RILTIPLE API No. 50-029-20266 6. LEASE DESIGNATION AND SERIAL NO. - ADL-25650 7. IF. INDIAN, ALLOTTEE OR TRIBE NA.~,tE 8. UNIT FARM OR LEASE NAME ~ West Sak River State.-~ 9. WELL NO. 8 10. FIELD AND POOL, OR %ILDCAT Prudhoe _Bay Kuparuk .River O' 11. SEC., T., R., M., (BOTTOM HOLE OBJEC'FIVE) Sec. 23, TI1N, RIOE 12. 14. BOND INFORMATION: Statewide Oil & Gas Bond #8011-38-40 (Federal Insurance Co.) mount $100,000 TYPE · Surety and/or No. ' ' I5. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) t 16. No. OF ACRES IN LEASE 4680' 2560 19' PROPOSED DEPTH 9000' 7500 18.'' DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT, CR, etc.) , i,Not, S0rveyed -., Approx 80' GL_ 17. Ne. ACRES ASSIGNED TOT,IS~LL 160 20. ROTARY OR CABLE TOOLS Rotary , 22. APPROX. DATE WORK WILL START . Februar_v 1, 197_7. 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE 'SIZE OF CASING WEIGIi~ ~ER'FOOT 'GRADE SETTING DEPTa .- Quantity of cement ' ' 32 16" 65 H40 80' GL Cmt to surf.- ADDrO× 35~" ft 131 i3'3/4 10"3/4" '45.5 K55 BTC 2200' Cmt to surf - A~rox !800 .~t. 3 9-7/8 ....... 7" '26' K55 BTC 7500' Circ cmt.~o surf vive - AoDrox ' .......... .I4'0,0:ft ' .' ,',, ............ The Atlantic Richfield Company proposes to: drill a Prudhoe Bay Kuparuk River Oil Pool developmeni well to approximately 7500'. Selected intervals will be logged, cored, and tested. A 20" 2000 psi annular diverter will. be installed on 16" conductor while drilling surface hole as per Division of Oil and Gas requirements. A 13-5/8" 5000 psi BOPE stack consisting of annular' preventer, blind ram preventer, and pipe ram preventer will be installed on surface pipe. The 13-5/8" 5000 psi BOPE will be tested on installation and weekly thereafter. Test pressures will be 3000 psi. The well will be completed with ~" 9.2 # N80. buttress tubing. Non-freezing fluids will be left on uncemented annul, i thru the permafrost interval. A certified survey plat will be submitted before spudding. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAbI: If proposal is to deepen give data on. present productive zone and proposed new productive zone, If proposal is to drill or deepen directionaUy, give pertinent data an.subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby ce~at the .Foregoing is True and qos/~,- Cl'his space for State office I [~ YES ~ NO I D YES [DIRE~IONAL SURLY REQUIRED ~RmT NO. 77-53 CONDITIONS OF APPROVAL, IF ANY: [~[ NO ! OTHER REQUIREMENTS: A.P.I, NUMERICAL CODE 50-029-20266 APPROVAL DATE Decelllber 7, 1977 ~ ~~.~~~ TITLE F~_mber APPOVED BY *See Instruction On Reverse Side DATE De~c--~r 3~ 1977 AtlanticRichfieldCompany North Ame~' ''~' 'roducing Division North Alasl~...,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1977 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Mineral and Energy Management 323 E. 4th Avenue Anchorage, Alaska 99501 Subject: West Sak River State Wells Lease and Well Names Dear Mr. Gilbreth: Please change the names of A~tlantic Richfield Kuparuk wells to include a lease identifier as follows: From: To: From: To: West Sak River Sta~t~J~=~r~.~~ West Sak River St~'te A8 <% West Sak River State 10 West Sak River State B10 The letter represents the lease and the number represents the first well on the lease. I hope this satisfies your request. Very ~truly yours, Frank M. Brown District Drilling Engineer FMB/HEM/jw Div. of Minerals & Energy. Anchorage, Ak. October 20, 1977 Atlantic Richfield Company P.O. Box 360 Anchorage, Alaska 99510 Re: LO/NS 77q36 LO/NS 77-111 ATTN: John Roots General Landman Gentlemen: The referenced lease Operations are approved subject to the ~ollowing stipulations: 1. The Spine road, pro~iding access to W. Sak ~7 & $, is the only permanent gravel roadaapproved. No permanent gravel roads ar~ to be constructed to nearby lakes to obtain water. 2. A 1200' x 400' gravel extraction site, known-as Gravel Site "B'', will be developed which will parallel the current otream bed. 3. This extraction site, outlined on the attached plat, will be located east of the atream and south of, and adjacent to.~ the Kuparuk gravel road in Section 8, TllI~, RllE, Umia~ Meridian. 4. A minimum of a fi0' leave strip(border) between the stream and the beginning of the extraction site will be maintained. 'No traffic will be allowed on this 50" leave strip. 6. No over-urden will ba placed on this 50' leave strip during the fir$t year .of operation. If their.~tudy of the stream Justifies pl.acing overburden on this leave strip, the State Department of Fish and. Game will so advise At~antic Richfield Company next year. ~. In developing the extraction site, overburden will be moved to the east of the gravel site, away from the mtream, and this displaced overburden will be mmoothed, sloped, contoured and revegetated to the satinfaction of a Division representative. Consimtent with our agreement with ARCO, the overburden (not the vegetative material) from Gravel Site'B $hould be utilized wherever possible in conjunction with the construction of the road and well site pad. 8. An initial area of 300' x 400' x a minim~u of 20' deep will be developed adJacenttOo the.Kuparuk gravel road within the 1200' x 400' gravel site. This . Atlantic Richfield P~ge 2 October 20 1977 area, as shown on the attached plat, will serve as an initial water reservoir for use in theKuparuk development, once gravel re, novel has ceased. 9. Vegetative material associated wifh the displaced overburden will be pushed to the outer ]tm~ts of the extractt&n site, so that it may later be available for use as a revegetation source. Blasting of the permanently frozen material is permitted as long as no damage occurs to t~.e vegetation and does not result in cratering. 10. The area around and below the fuel storage facilities shall hwae a dike ~urrounding it with impermeable membranes beneath OR the fuel storage facilities shall be of double wall construction. tt' The banks of watercourses shall not be altered. Stream crossings shall be .selected at Points where no alteration of the ~anks is necessary. 12. No equipment shall enter or cross active (open flowing) channels of watercourses. 13.~ }~vement of equipment through willow (salix) stands shall be avoided where possible. 14. Hultiple pass.es over the same tracts shall be avoided where conditions are such shat multiple pas~es will result in alteration of the vegetative cover. 15. All operating areas shall be maintained and, upon completion of the operations, left in a condition satisfactory to the Director. 16. Trail and campsites shall be kept clean. Water supply, waste water and solid waste disPosal systems must be approved by the Division of Air and Water Quality, Department of Environmental Conservation. 17. Campsites and/or~ storage and stockpiling of mate~Zal on the surface ice of lakes, ponds or rivers is prohibited. (~!~E~ OPEP~TIONS 0!~¥) 18. Any time after April 15,'1977, the use of ground contact vehicles shall be subject to termination within 72 hours of notification by the Director. 19. A completion report shall be submitted within 15 days upon termination of permit activities including the following information: a. All routes of travel and all campsites depicted on a USGS topo map.. b. Ail additions to original application. c. Statement of clean up activities. d. Time spent in each campsite. e. Methods of disposal of garbage and other camp debris. 20. The Kuparuk River will not be used as a secondary water source. Pothole lakes and snow melters are to be used as primary and secondary water sources. A separate application for the Kuparuk Rivet'will be necessary in the'event these water ~ources prove inadequate. Atlantic Ric1~ Company Page 3 October 20, 19 77 21. No petroleum products are to be stored within one-quarter (~/4) mile of a waterbody. Ail fuel'must be stored in a location where spills can be easily contained and retrieved. Permanent fuel storage areas shall conform with the Alaska Department of Environmental'Conservation requirements. 22. Applicant and contractors should be advised of our regulation (5 AAC 81.1B8) which pro~ibits making food items available to bears, wolves,' foxes and wolqerine. 23. If steep banks are encountered at watercourse crossings, snow ramps shall be constructed to assure the b~ks are not degraded. Snow (ice) ramps will be free of dirt or debris, and will be removed immediately after use or before breakup whichever occurs first. 24. All fuel tanks at. the well sites shall be placed within diked areas. 25. The inside surfaces of the diked areas shall be impermeable. 26. All hazardous substance :spills shall be reported and cleaned up as per 18 AAC 75.080. 27. All waste, test and clean-up oils shall be containerized, or disposed of in a manner approved by the DEC. 28. Drill muds shall be placed down hole if said hole is dry; otherwise, drill muds shall have a minimum of five (5) feet of backfill over them prior to abandoning the site. If the reserve pit is within one hundred (100) feet of a fish stream or water supply source, the pit shall have an impermeable liner. 29. Ail waStewater discharges shall meet the following monthly averages - 30 mE/1 BOD, 30 mg/1 suspended solids, and 200 fecal eoliforms/100 mls. If the sewage treatment plant can meet these standards as the effluent leaves the plant a s~mge lagoon will not be required, minimizing environmental impact and conserving resources. 30. Potable water shall meet the Alaska Driking Water Standards. Minimum treatment shall cmssist of disinfection and filtration to remove a 10 Micron size particle. · 31. All putrescible wastes and sewage sludf, e shall be incinerated in an approved unit. Wood, paper and cardboard may be open-burned (no item may be burned in a manner that will cause a black smoke emission). Tin cans shall be burned in the incinerator prior to disposal. The residue 'from the above refuse shall be buried in a "false start well hole", or if this is not possible, it may be buried in the pad or reserve pit. A minimum of five (5) fact of fill material shall be place~d over this residue upon completion of the operation. Non-burnable items such as drums, rubber, metals, batteries, etc., shall be backJ~auled to an approved location. Theme items ~hall not be buried. Atlantic Richfield Company ?age 4 October 20, 1977 32. Ice 'road construction shall begin only after the seasonal fro~t i~ the tundra and underlying mineral soils has re~ched a depth of 12 inches, and the average thickness of snow cover is at least 6 inches. 33. Ice road construction shall be accomplished in such a manner as to exclude tundr~ damage. This approval is mubJect to the letter from DF&G to Atlantic Richfield Company dated September 9, 1977, and the memorandum from DF&G to William Copeland, NCO0, dated September 27, 1977, (copies attached). Sincerely, Ethel ti. Nelson Land Management Officer Attchmt. Atlant~ichfieldCompany North Ame~ n Producing Division North Alas~ istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 6, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 --i _] ' ENG J 2 ENG J 3ENG I 4ENG ..... l-i~- O~OL --- J 2 ©EC)L j"3 C¢~;OL'--- J REV i-DRAFT j SEC ...... --~ONFER:- FILE: Reference' West Sak'River State No. 7 / ,'' West Sak River State" No 8 West Sak River State No. 10 Dear Si r' Enclosed in triplicate are requests for permits to drill two development wells and one exploratory well in the Prudhoe Bay Kuparuk Riv.er Oil Pool area. The required $100 filing fee for each of the three wells is also enclosed. The proposed casing program for West Sak No. 7 meets current Division of Oil and Gas requirements for Kuparuk surface pipe. The proposed surface casing for West Sak No's 8 and 10 is cur- rently being investigated to insure compliance with State post yield strain requirements. Appropriate engineering reports will be submitted to the State upon completion. Atlantic Richfield Company is presently preparing plans on how we propose to drill and to produce Kuparuk development wells. We look forward to discussing these plans with the State once the plans have been finalized. Very truly yours, ank M. Brown District Drilling Engineer FMB/.am EnClosures SURFACE DIVERTERSYSTEM To Sump 3" TO sump · To Somp To sump 1. 20" Bradenhead 2. 20" 2000 psi drilling spool 3. 20" 2000 psi annular preventer 4. 4" butterfly valves 5. 3" ball valves I I I I -/' I l I I ! I 1--- I I I I ! ! I I 30 i I I I ! I ! 1 I I I i I I ! ! i ]7 4- ! ! l~ ! i I I I I ! I 1 ! West I I I I ~ i I I i I I -1- I I I I I I I IO I I -I i i ! I I I I 15' I I I I I I I II Sak River State #8 . I I I I I ' ! I ! : t 1 Approximate Locati on-. I 1 I -I ! I et' I I l l l l l l ~ '~' [ I I L Scale 1" = I Mile RIOI~ 600'FEL, 600'FNL, Section 23, T11N, RIOE RII~' WEST SAK RIVER STATE N'o. ] ATLANTIC RICHFIELD COMPA[', PERMITS Company t~/ Yes No Remarks ce attached ..................... be located in a defined pool ........... ~ . . .... ~ a registered survey plat attached ~ 4. Is well located proper distance from property line ......... 5. Is well located proper distance from other wells ..... - ..... /~2,<, 6. Is sufficient undedicated acreage available in this pool ...... 7. Is well to be deviated ........ · ............... 8. Is operator the only affected party ................ 9. Can permit be approved before ten-day wait ............. ~/h,.~.¢ 10. Does operator have a bond in force ................ ,e/-~OE tl Is a conservation order needed .................. t2. Is administrative approval needed ................. 1.3. Is conductor string p~ovided .................... ~ 14. Is enough cement used to circulate on conductor and surface . . . .. ~ 15. Will cement tie in surface and intermediate or production strings . ,? 16. Will cement cover all known productive horizons .......... ~ 17. Will surface casing protect fresh water zones ........... ~ 18. Will all casing give adequate safety in collapse, tension & burst . Approval Recommended' Geol o, gy: Engi neeri ng: TRM JAX, JAL HHH ~JCM~ 19. Does BOPE have sufficient pressure rating - Test 20. Has DME~.~ approved Plan of Operation .~./d/~;l~.~o.~. Additional Requirements'~ ~.' ',x/~,_~g~_ ~/~-~ ~ Revised 11/17/76 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 APPENDIX. No 'special'effort has been made to chronologically organize this category of information. .o T !341 53::