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Home My WebLink About182-156WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϮϭϱϲϬͲ^Ğƚ͗ϯϲϭϯϴJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 THE STATE ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 F-07 Permit to Drill Number: 182-156 Sundry Number: 319-469 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ww .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, Price Chair DATED this It day of October, 2019. 3BDMS- OCT 17 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS F1"%J is B vii L.K.0 NOV 2 7 2019 A 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: WHIPSTOCK❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Exploratory ❑ Stratigraphic❑ Service ❑ 182-156 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-20830-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25662 KRL) F-07 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 8,060 feet Plugs measured None feet true vertical 6,717 feet Junk measured None feet Effective Depth measured 7,210 feet Packer measured 6972, 7320, feet true vertical 6,006 feet true vertical 5810, 6097 feet Casing Length size MD TVD Burst Collapse CONDUCTOR 45 feet 16 80' MD 80' TVD SURFACE 2,225 feet 10 3/4 " 2,259' MD 2189' TVD PRODUCTION 8,013 feet 7 8,045' MD 6705' TVD Perforation depth: Measured depth: 7184-7458 feet True Vertical depth: 5984-6212 feet Tubing (size, grade, measured and true vertical depth) 3.5 " J-55 7,347' MD 6,119' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER FHL PACKER 6,972' MD 5,810' TVD PACKER - OTIS WD PERM PKER 7,320' MD 6,097' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: e e e e m I Subsequent to operation: 1381 944 3004 1300 174 14. Attachments (required per 20 AAC 25.070, 25.071, 825.283) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 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: 319469 Authorized Name: James Ohlinger contact Name: James Hayes Authorized Title: Staff CTD Engineer contact Email: James.C.Hayes@cop.com Authorized Signature: Date: �� 16 Contact Phone: (907) 263-6927 Form 10-404 Revised 4/2017 rrc /Z/`6/!✓ RBDMS A�J DEC 0 2 2019 Submit Original Only 1 F-07 WHIPSTOCK DTTM JOBTYP SUMMARYOPS START 10/29/19 DRILLING Continue to work rig down checklist on 1 R-23. Trucks on location @ SIDETRACK 8:45am. Load shop and half way house, pull sub & pits off well, jeeped & move to 1 F -Pad, spot over well, RU & NU BOP, grease tree valves, 10/30/19 DRILLING Complete greasing valves, flood up and pass shell test @ 01:00. Test SIDETRACK BOPE 6 hrs, witness waived by Jeff Jones AOGCC. PT ODS PDL and tiger tank line. PU & PD BHA #1, window milling assembly. 0.6 ° AKO motor w/ NS short shank reamer and DSM. RIH flushing well with seawater. Turn well over to milling fluid. Mill 2.80" exit window in 7" casing off NS tandem wedge 7,204'-7209.76'. 10/31/19 DRILLING Continued milling window exit off NS Tandem Wedge 7,209.8' to BOW SIDETRACK 7,212', and rat hole 72297, performed 4 reaming passes at as milled, 30L, 30R, and 1800 from milled, dry drift exit (clean), POOH, chasing sweeps to surface, PUD BHA #1, mills in gauge, install nozzle and jetted BOPE, PD 2.40 ako build assembly BHA#2, RI H, tagged early, logged formation @ discovered counters off +122', drilled ahead from end of rat hole 7229.7' to 7713'. KUP PROD WELLNAME 1F-07 WELLBORE 7F-07 CUnOCUPhilli S Well Attributes Max Angle & MD TD i" FMI Itl Nesse (Wellboredvmd Irhou"re 6d<uc s. MO gi.aI Act Dr. aft., F�aBka,(t X;. IK PARIIKRIVFR UNIT SBnJaJrlRippn porn w conn en n and W0: 1F -0r , Iluachga23nIXie. Last Tag - - ._._... Vistat whim clacpW) lmnamtlan I Depth(RKIR Em Oafe wenbone " tMoo ay HMGER; z64 "". ......... Last Tag: END (EST 62'RAT HOLE) I),520.6 joi 1F-0] Conddvv Last Rev Reason AnnoMmn End Uah Wenlwre Lea Moa ev Rev Tenonn: Set Whipstock 1022/2019 1F-0) famaj Casing Strings Gamin Description DONOUCTOR OB(in) IUpn) i6 1525 Top Upi 6N depth UJOES Sel paplhlNB1... W11In(I...oni Top Thread 35D 80.0 800 65.00 H40 WELDED CONDUCTOR;3ad 0 eeslnp Descripxon SURFACE OD tun) ID he) 10314 9.95 Top( ... I Set -arm meta I Set Depth tato)... WtlLen(I... G.S. I Top Threatl 34.2 2,258.7 2,1890 45.50 K-55 ISLITT taming Damendme PRODUCTION OD tin) ID Un) 7 623 Top inKBl 9a Depm jamid set D.plh mo)....n O...Gratle rod rmend 32.1 8,0450 6704.5 2600 K-55 BTC SURFACE; 34.2-2,867 Tubing Strings GAB LET Manhel; J,618< Tubing Description 3.5"TUBING-2019 TWO Slnnp Ma... 3112 IDtin) 299 rod lnNa) 284 Set Depth (fl.. 1,248.1 bet Oeplh tato)(... 6037.3 Wtllbllg 930 Gmtle L-80 Tap Connection EUE Completion Details GAS UFT MaMreF 4,16e.4 Top "Off rap lnka) (Axe) I Top incl rvomma PI sem Dm Com to (in) 284 284 0.13 HANGER EMC 11"x312"Gen 5 Tubing Hanger Wl SO EUE Bre Lift Nread 2.900 GAB LIFT Messrs: 521.7 6,947.1 5,789.5 3584 LOCATOR Baker gbh-221ocator sub 3.000 6,9481 5,)90.3 35.82 SBE Baker 8040 seal assembly 21.73'OAL+2'Off tag 3.980 6,950.1 5,)92.0 35.80 SBR Dakar 8040 PBR 4.000 GAs LIFT MmtrN: e.oa.o 7.9720 5,809.8 3554 PACKER Baker FHL pecker 6983' 2.930 7,014.3 5,8443 3509 NIPPLE - X RES3 In's 2.813EX nipple ProBe N: 727A-0-0W/RH 2.813 installed GAS LIFTManamF. B,5A7 7.18].4 5,987.0 34.03 TANDEM WEDGE Northern Solutions 3112" x 95/8" Tandem Wedge Assembly 2.992 Gs6Un Mvssml', 111 ),201.4 5,998.6 33.97 NIPPLE -X REP 312"x2.813"Xmould Profits IBM.) 2.813 LOCATOR; Satin 7,207. 6,0034 33.98 TAND M WEDGE Nanhern Solutions 312"x9SUB" Tandem Wedge Assembly 2.992 BBE A., -mv a,550.1 7,221.2 6,015.0 33.99 NIPPLE -X HES 31/2"x2.813"X nipple Prone IS 2813 PACHER; 4972.0 NIPPLE -X',]0(1.9 Tubing Deacription TUBING-RW01984 (after 2918 RWD) StMg Ma... ID (in) 312 299 Top MSB) ],2)84 SetDepth tR. 7,346.6 Sal"PIM1 (No)t... 6,1189 Wt(IdR) 9.30 Fred J-55 Top Connection BTCIPC Completion Details ,a FVN) Top (USES "NON "Ind Nominal (°) No. Des Cam Dunt 7318.9 9096.0 34M LOCATOR OTIS STRAIGHTSLOT LOCATOR 3.000 ),320.1 6,0970 3400 PACKER OTIS WD PERMANENT PACKER 4.000 TANDEM WEDGE: ],3240 8,100.2 33.99 MILL OTIS MILL OUT EXTENSION .35 ],340.1 6,113.5 3394 NIPPLE-XN OTIS 2.81" XNS POLISHED BORE NIPPLE w/2.77 NO GO 2813 NIPPLE -X7814 ),345.9 61184 3393 SOS OTIS SHEAR UT UB, ELMD TTL@733'doing PPR Fan 44)0 TANDEM WEDGE: 7,Y b 3I2v2.b RPERF: 7.1a4.67,2MO (PERF.v840T7 40 Other In Hole (Wireline retrievable plugs, valves, pumps, fish; etc°) - TO. c.4xD',],1040 Isar Wdbe?SVB To nKB ) Top nvD) MSE) To; lnol P) pez Com 0.un Dol to(in) rvwPLE-x:7.2zT2 xo Tnmem-TONn 7221,.1 RwFBcrxn; ].Y21 D ],208.8 /. 6,004) 33.98 Inner Wedge 3 Inner Wedge Make Assemblyr set top at ]2043'Tied in to Kt Marker (7208.8' tied in Completion). DAL 121' Max 002.625' 1022/201 9 0.999 assmnsD urvER wITH ORANGE PEEL WEDGE 9OTTOM-Tmme ?be1 7,2210 6,014.8 33.99 RockScreen -777-lock Sl F Ock Green wl 188 slats 5" DAL) 82512019 0000 7,254.0 6,042.2 34.01 Broken Blast )268019 0.000 IPEHF; 7.255.67.8007 RPERF', 7,850.7.ZeRC RIUgS from Original RPERF: 7,26. 67,830 Tom. Completion RPERF.?8.6?81.0 amend... RmPamm� ohamd beenumn; 7,254.0 a ;300.0 6,080.3 3405 CHEMICAL CUT 2.625 Chemical Cut 7/42019 2.992 CHEMIaLCUT,?sxio 57323.0 6IDI 33.99 M BAKER H1 CEelI HIL IA1NIbH WI BALL 611312019 1.130 PRODUCTION -Msssm, RETAINER- REMAOVED, 2.77"00 X 1.16' LENGTH TGRS GUTTED LOCATOR; ].31.9 Perforations & Slots PPCKER:7.98.1 Shot CEMENT RETAINER- GUTTED; 7, 390 MILL', Tax Top (RSB Bnn KB ) In ) Too RVD) Btri Me) (nKBI Dens (.he. Lurked Zone Date ) Type Com 7,184.0 72440 5,984.1 6,033.9 C4,1F-0 1012111982 120 (PERF 5" Vann Guns ],184.0 7,2440 5,984.1 60339 C4, 1F-0) 91111984 12.0 RPERF 5"OA; 90 deg ph NIPPLE-xrv', T346i ],255.0 ),260.0 6,043.0 6,04].2 UNITS, IF -0] 1021/1982 120 (PERF 5°Vann Guns 7,255.0 ),250.0 8,043.0 6047 2 UNIT B, IF -0) 9/1/19M 12.0 RPERF 5"DA; 90 deg ph sos;?315.a ],288.0 ],282.0 6,0538 6,065.4 UNIT B, IF -07 1012111982 12.0 (PERF 5"Vann Guns 7,268.0 ],282.0 6,053.8 6,085.4 UNIT B, iF-07 9(1(1900 12.0 RPERF TDA SOD ph ),3930 7,405.0 6,157, 9167.4 A4 021/1982 , 1F-0] 1 12.0 (PERF 5"Vann guns 7,393.0 7,4050 5,157.5 91674 A4, 1F-07 10110/2006 6.0 RPERE Z.b HSD HJ RD , 60 deg. IPERF,7,30067,40RO ph RPERF. z3e3w.4a.o 7,420.0 1,446.0 9119.9 6,2016 A4, 1F-07 1112111982 12.0 (PERF 5- Vann guns FRAC h6PN 0; T3W 0 IPENF; 7.4acn7,4,ia 0 7,453.0 ],4560 92075 1 9211.6 A4, 1F-07 1021/1982 12.0 WERE 15' Vann guns Frao Summary sten (PERF', 7,45367,4560 $23/2000 Dak pmpwdt oe:gdea nb) Propludtm Formallod Ob) 6ptl 1 Sinn Dab Top 91232000 ],1840 DePA VOUD B1m (1ME) ),244.0 LinFm Fuuitl Sysl¢m voicas bbd volslurai Sten 10/2]2006 Dale pmppant p¢sgn A he respond In Formation ple Ltd lzmmF ],ID268.B8.4 1V# 1 Bbd Dam TOPOept BUREB Beepti 10278006 ],393.0 7458.0 Linkm Fluididetom VolCkan(bbg VOI SIurry(bbg PRODUCTON;32.1d.046.0� KUP PROD WELLNAME 1F-07 WELLBORE 7F-07 ConocoPhillips ^" wasMa, Irr. o.la6on Bna Dab Last WO' ]I3012p19 1F4G 1111srme23903PM Mandrel Inserts v.-uss'mwobcwm) a1 .6 ........................ HARDER; 254 .... ......_.. an N Taf1VD) Valva Lzlcb Po(iSitt TRO Run To kB PIR 1 take)241 Make skindIAG 00(In) Sery Tye Type (psi) Run Deb Com 2,619.4 2,484.6 Cameo MMG 112 GAS LIFT GLV RK 0.1 0.188 1 1,265.0 IMMO19 2 4,189.8 3,680.2 Camco MMG 11/2 IGAS LIFT JGLV RK 0.188 1,251.0 &19/2019 3 5,277 4,491.1 Camco MMG 1112 GAS LIFT GLV RK 0.188 7,242.0 &1812019 4 6,022.0 5,082.1 Camco MMG1112 GAS LIFT GLV RK 0.188 1,2350 81192019 5 6,550.] 5,4]6.5 Camco MMG 112 GAS LIFT GLV RK 0.186 1,22].0 &192p19 CONDUCTOR...— ..6 6,921.8 5,769.1 Cemw MMG 112 GASLIFT OV RK 0.188 0.0 8/18/2019 7 7,3010 6,081.6 MIS OVALD 1 PROD DMV 6K 0.000 0.0 926/2006 PTM ucdo 9URFACE:342-22I mans Let GA3 LIFT MaMM: 2.6191 Sam eBSlbl e due W GAB UFT Mmtre[a.1aB OTanga a peel at WBLIFT WMre1: 5218.] BTM Of lin r Notes: General & Safety GAS LIFT MCMmII 8 M 0 End Oah Annadtlon 8/28/2019 NOTE: View Schema tic Wl Alaska Schemattc100 WB LIFTR I', a,6A] GA3 UFT...; a,P210 LOCATOR; 401]1 71 SEE; S, BBs:4AmI PACK( R;B4O]20 NIPPLE - X 7,M4.3 TANDEMWECGE', 1,19].4 NIPPLE - Y 7.2014 TANDEM WEDGE;7 3 REflF;DGI]244.0 IPERF', 7,181.0.1,2440 FRACG9PNG;]'.- 1B40Ntt/W P—,Rd': WY: >.2LW.a NIPPLE - X 7M1.2 XO TFreaa.-Ing; ],2711 Rakeaeen: 7.O YBLGTTEO 32LINER WITH ORANGEPEELWEDGE BOTTOM-Tudina ],2H.1 PERF: 7.256.G7,2001 RPERF: 7.2S67,M0.0.1 IPENF].2a9.0-],2G2.0 ` NPERF;],MG7 SO I &ebn S. an.M1cm Ongnal Cninsl>.Yv4.0 CHEMICALCIR;7,0000 PRODUCTION -MII', ].3M 6 LOCATOR, 7.3159 PACRER:T,asdl LEMENTRETAINER- GME0;7,323.0 MILL: 73240 NIPPLE-XN;7.3W.1 BOB; ],3459 IPERF', 7mspG74fb.0 RPERF: 1.&7,f05.0 FRACA D; 7m)0 IPEPF:],W.G]4a a (PERF; 7,,03.67,459,0 Ltd1 lawal;>,m2G0M59 PRODUCTION: 32.1A,0450� k �§ 2= C / R2 wy6! y— � NF-, : \ ) ( ®!_�}/\z\ a ol:e 2 ; \| \\\k/ - §t/// - ,e 6\ . om, \r(;§ k �§ 2= C / R2 wy6! y— � NF-, : \ ) ( a ol:e \| - - ,e 6\ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 90 DDC 25 280 rCT yL4 r P75 1. Type of Request: Abandon ° Plug Perforations- Fracture Stimulate ° Repair Well ° Operations shutdown, Suspend ° Perforate ° Other Stimulate ° Pull Tubing ° Change Approved Program Plug for Redrill ° Perforate New Pool ° Re-enter Susp Well ° Alter Casing ° Other: _Whipstock 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ° Development X . Stratigraphic ° Service ° 21>97S".j L, 3. Address: PO Box 100360, Anchorage 6. API Number: AK 99510 50-029-20830--00 /t rz(- 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 F-07 Will planned perforations require a spacing exception? Yes ° NcX 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25652 1 Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,060' 6,717' 7,210' 6,006' 2,352 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' 121' Surface 2,225' 10-3/4" 2,259' 2,189' Production 8,013' 7" 8,045' 6,705' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3-1/2" L-80 7,248' Packers and SSSV Type: Baker FHL Packer Packers and SSSV MD (ft) and TVD (ft): 6,972' MD / 5,810' TVD 12. Attachments: Proposal Summary Wellbore Wellbore schematicA 13. Well Class after proposed work: Detailed Operations Program ° BOP Sketch ° Exploratory ° Stratigraphic° Development Service ° 14. Estimated Date for✓ 15. Well Status after proposed work: Commencing Operations: 10/28/2019 OIL WINJ ° WDSPL ° Suspended ° GAS ° WAG ° GSTOR ° SPLUG 16. Verbal Approval: Date: Commission Representative: GINJ ° Op Shutdown ° Abandoned ° 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 07 1 Authorized Name: James Ohlinger Contact Nat Hayes Authorized Title: Staff CTD Engineer Contact Email: James. C. Hayes(@cop.com Contact Phone: 263-6927 Authorized Signature: Date: COMMISSION OSE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (� 0/ 1 Plug Integrity ° BOP Test ° Mechanical Integrity Test ° Location Clearance ° Other: >IBDMS�-F' OCT 17 2019 Post Initial Injection MIT Req'd? Yes- No Spacing Exception Required? Yes. No Subsequent Form Required: /0—+04 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: n _+ ,7-`C, (o/I��I �1 PP P�! hh�d - 2� h 000dddnnn YYY Su14001, bmit Form and F 10-4d3 Revised 4/201 A roved a a to r for i moot s from the date of approval. Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct. 9'h, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set an Inner Wedge in KRU 1F-07 (PTD #,21$-9Tin or er to drill two CTD laterals using the coiled tubing drilling rig, Nabors CDR3-AC. -- Attached to this application are the following documents: — 10-403 Sundry Application for KRU 1 F-07 — Operations Summary in support of the 10-403 sundry application — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6927. Sincerely, James C C Hayes ✓�� ConocoPhillips Alaska Coiled Tubing Drilling Engineer /�r�>� /,.io 0 2(J7-73) CTD Sumi Summary of Operations: KRU well 1F-07 is equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C -sands to the north and south of 1 F-07. The laterals will increase C -sand resource recovery and throughput. A recent rig workover installed tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge in the tandem wedge. CDR3-AC will mill a window in the tubing and casing at 7,210' MD and the 1 F -07L1 lateral will be drilled to TD at 10,500' MD, targeting the C -sand to the north. It will be completed with 2- 3/8" slotted liner with a billet will be ran from TD up to 7,600' MD. The 1 F-071-1-01 lateral will ge drilled by CDR3-AC and kicked off the liner top billet at 7,600' MD, the 1 F-071_1 liner top. The lateral will be drilled to a TD of 9,800' MD targeting the C -sand to the south. It will be completed with 2-3/8" slotted/blank liner from TD up into the 3-1/2" tubing at 7,205' MD with a deployment sleeve. CTD Drill and Complete 1F-07 Laterals: November 2019 Pre -CTD Work 1. RU Slick -line: Drift tubing and set X -lock in lower X -nipple @ 7,221'. 2. RUE -line: Set inner wedge. 3. Prep site for Nabors CDR3-AC. Rin Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 F-071_1 Lateral (C4 sand -North) SI5"073 a. Mill 2.80" window at 7,210' MD. b. Drill 3" bi-center lateral to TD of 13,300' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 7,600' MD. 3. 1 F-071-1-01 Lateral (C4 sand -Southeast) a. Sidetrack 3.0" hole at 7,600' MD. i b. Drill 3" bi-center lateral to TD of 9,800' MD. c. Run 2%" slotted/blank liner with deployment sleeve from TD up to 7,205' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production Page 1 of 1 10/11/2019 :§ \\ ( �& R) ( t0 Ln rl MN W A� I_ 1 LL Z J D 0 >_ Y � " CC Q o CL Q � 3 CL Y o oCa` YW> i r O ca" a � Y Q. IL 0 U 0 c 0 V Barrels of Oil per Month or Barrels of Water per Month � N O OO O O O O O N O O O N O N N ollem 110 -seg Jo y;uow aad („j�W„) seg;o;aai a1gn:) puesnoyl 0 0 O O O O O O O O O O � N O OO O O O O O N O O O N O N N ollem 110 -seg Jo y;uow aad („j�W„) seg;o;aai a1gn:) puesnoyl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforale New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: PACKER REMOVALE3 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service ❑ 182-156 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-029-20830-00-00 7. Property Designation (Lease Number): 9. Well Name and Number: ADL 25662 K RU 1F-07 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 8,060 feet Plugs measured None feet true vertical 6,717 feet Junk measured None feet Effective Depth measured 7,357 feet Packer measured 6972, 7320 feet true vertical 6,128 feet true vertical 5810, 6097 feet Casing Length size MD TVD Burst Collapse CONDUCTOR 45 feet 16 80' MD 5858' TVD SURFACE 2,225 feet 10 3/4 2,259' MD 6090' TVD PRODUCTION 8,013 feet 7 8,045' MD 1836' TVD Perforation depth: Measured depth: 7184-7458 feet True Vertical depth: 5984-6212 feet Tubing (size, grade, measured and true vertical depth) 3.5 " J-55 7,347' MD 6,119' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER FHL PACKER 6,972' MD 5,810' TVD PACKER - OTIS WD PERM PACKER 7,320' MD 6,100' TVD SSSV -NONE 1,863' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments (required per 20 PAC 25.070, 25.071, 3 25.283) 15, Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-284 Contact Name: Gary Eller Authorized Name: Ga Eller Contact Email: J. Gary Eller@cop.com Authorized Title: Well isor Authodzed Si nature: Date: -u- ypt Contact Phone: (907) 263-4172 Form 10-404 Revised 4/2017 _J v77- 9/✓ 1�gDMS SEP 0 4 2019 Submit Original Only g "/91 1 F-07 PACKER REMOVAL (FAILED ATTEMPT) DTTMST.JOBTYP SUMMARYOPS 6/13/19 DRILLING TAG W/ 2.65" GAUGE RING W/ CCL TAG @ 7520' RKB 62' OF RATE HOLE TIE INTO TBG SUPPORT- TALLY, RUN 2.78" x 11.5' DUMMY CEMENT RETAINER DRIFT TO 7340' RKB, STRING CAPITAL SHOT SEAL ASSEMBLY W/ 5' x 160 GRAINS PER FT @ 7323' RKB, LOG GAMMA RAY FROM 7520' RKB TO 6900' RKB, SET 2.76" BAKER H1-035 CEMENT RETAINER WITH OUT BALL @ 7323' RKB (ME). READY FOR CTU. IN PROGRESS. 6/23/19 DRILLING RIH WITH HES HYDRA -BLAST PRO CUTTINT TOOL, TAG GUTTED RETAINER AT 7323' SUPPORT- RKB, PUH 2' COME ONLINE WITH 100 MESH SAND IN 35 PPG LINEAR GEL AT .5 BPM, CAPITAL USE GAS LIFT TO MAINTAIN 1:1 RETURNS, SWAP TO FRESH WATER FLUSH AND POOH, F/P TBG TO 3000' CTMD, JOB IN PROGRESS. 6/24/19 DRILLING RIH WITH 2.13" HIPP-TRIPPER, TAG RETAINER AT 7323' RKB, HAMMER DOWN TO SUPPORT- 7326.7' RKB BUT UNABLE TO PUSH RETAINER ANY FURTHER, F/P TBG WITH DIESEL, CAPITAL READY FOR E -LINE, JOB IN PROGRESS. 6/25/19 DRILLING RIH WITH PDS CALIPER. TAGGED 7322'. LOGGED FROM 7322' TO 6900'. SUPPORT - CAPITAL 6/27/19 DRILLING RIH WITH HES ABRASION CUTTER, TAG @ 7322' RKB, PU 7', BATCH UP WATER 35LB SUPPORT- GEL, AND SAND, START PUMPING SAND DOWN COIL, AFTER 6BBLS SAND EXITED CAPITAL OUT THE NOZZLE OUR CIRC PRESSURE WENT FROM 3300 PSI TO 4400 PSI AND THEN FELL OFF TO 1430 PSI. FINISH PUMPING SAND, POOH TO CHECK TOOLS. AT SURFACE FOUND THE TOOLS DISCONNECTED. JOB RESTART IN MORNING. 6/28/19 DRILLING RIH RECOVERED DISCONNECT AND ABRASION CUTTING TOOL, OOH MAKE UP SUPPORT- ABRASION CUTTING TOOL, RIH, TAG GUTTED CMT RETAINER 7322' RKB, PU 7', 7315' CAPITAL PUMP .5 PPG 100 MESH SAND TO CUT TUBING. EVERYTHING LOOKED GOOD. POOH. OOH TOOLS ALL LOOKED GOOD. MAKE UP GUTTED RETAINER. FOUND SMALL PIECES OF HYDRATED SAND BALLS ON DISCONNECT. PIC IN ATTACHMENT. JOB IN PROGRESS. 6/29/19 DRILLING RIH WITH JAR'S AND BID] HIPP-TRIPPER, TAG AT 7322' RKB, HIPP-TRIPP FOR A SUPPORT- TOTAL OF 5 HRS. DID NOT SEE ANY MOVEMENT. GOT 6 JAR HITS DOWN, NO CAPITAL MOVEMENT. READY FOR ELINE. 7/1/19 DRILLING DRIFT w/ DUMMY E -LINE CUTTER, 2.64" CENT,6' WB,2.71" GAUGE RING TO CEMENT SUPPORT- RETAINER @ 7323'RKB. DIFFICULTY DRIFTING OVERSHOT @ 7156RKB, TOOK CAPITAL MULTIPLE ATTEMPTS TO SKIP THROUGH. IN PROGRESS. 7/2/19 DRILLING PERFORMED HES CALIPER LOG FROM 7323' RKB TO 6662' RKB; SET 3.5" SLIP STOP SUPPORT- CATCHER @ 7019' RKB; PULLED GLV'S & SET DV'S @ 6596', 6068', & 5262' RKB. IN CAPITAL PROGRESS. ,A91ft, KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 /��/�� w- C , 1,-'r' Well ConoeoPhilhps Alaska. Inc. KUPARUK comment SSSV: Attributes mO4 „s„ � •••_ .- Id Name Welllsom PPVUWI Wellbore smaua MD1 81 Pc[Btm( B) RIVER UNIT 500292083000 PROD 4.83 5,)0000 8,0600 NONE <025(PPm) 9110/2016 AL..IWO: 8I17c018 4059 (n) qa MleKDab ,Fm.amrm,suU:w PM Last VeMlecMmelb (asEull Last Tag Mr.. Deign Me) End Gae I Asubmie Laid MW BY Tagc RKB (EST 62' RAT HOLE) 7.520D 61132019 T -L, condilw -------xnxGER;o,-- Last Rev Rev Reason AnnOtalbn EM Gale W.A. Out M. By Reas.n'.IosMIINew GLD 8120/2019 1F-0, jnansen8 Strings Gescnpnon oGlml ID IIn) TOPvmP $emepm lnnGl sa 0An We., ll... --- Top Tn,eN 16 1525 35.0 80.0 1800 6500 IT WELDED Gescrlplbn OU (nl lin Top Ia") set.........-'eivVol... WV6n p...G F Top Tnnea 10314 9.95 34.2 ?258.] 2,189.0 45579 K-55 BUTT OD Ila 5281 32Aej 8045.0 duel 6,�a46m mD1 2500n BTC nreaa cox0ucroa:xomD Casing Casing CONDUCTOR Cazlnq SURFACE PROOUDCTIONon Tubing Strings Descnpllon Sbing Ma... to 1n1 Top Me) Sal Gean (ft.. 5e10epM (NOj (.. WIIIbMI G,etle TOp Conneclian 35"TANDEM 3112 299 0.0 72481 0;31.3 9.30 LA0 CUE SURFACE ]4.232Sa]�- Tuninq WEDGE CTD Oaq LIFT; 2,Mge SIDETRACK Completion Details Nominal Tov 0,D) TOPmnI Ihm Ma Com in (m)GAS Top IN(BI IMLB) P) 0.1 01 000 HANGER FMC 11' x 3112' Gen 5 Tubing Hanger 97135' EUE 8rtl Lift Nreatl 2900 LIFTIatm9 GASUFTI5.216] 6,947 1 5,789.5 35.84 LOCATOR Bakergbh-221ocaor Sub SWO 6,948.1 57911.3 35,82 B (San ore Baker 80-405ealassembly 21.,3'OAU2'o Mg ].98 Extension) GASUFT:6.0020 4000 6,950.1 5,7920 3580 SB(Seal Son, Baker 80x0 PBR Receplade) 6,972.0 5,809.8 35.54 PACKER Baker FHL packer 698' 2.931 7,014) 5,844.3 35.119 NIPPLE RES 3 Ice x28IY'X nipple rofile (,,)Tff7-,-'FT-W7PPr 813 installed GASUFT:e55n] oern SOluBons J12"x9518"Tantlem Wetlge Assembly 2,992 7,1824 5,987.0 34 NM WEDGE GAS LIFT', 6.5216 LCCATORI6.PC74 a.Isw awe F.wmimc: gam, SMc(Eml Gas R ; - PAcxakilece 7,2016 5,998.6 33.97 NIPPLE HES312'x2. 13°X nipple Profile( N;) 2.813 7,20].2 6,003.4 33.98 TA EM No mem Solutions 312'x9518" Tandem Wedge Assembly 27992 WEDGE 7,1212 6,015.¢ 3398 NIPPLE HES 312" x 22813"X nipple Prolie IBM) 281 2992 ),223,1 6016.6 3399 . SL D NEN WITH NIPPLE.].wu ORANGE PEEL WEDGE BOTTOM ADe (NO)L..9 IONN J -55e BTC eoran TUBMG sail n 84 3MV2 Mr.. lot ),D84e) ]] 681Irt. EPA (after 2018 RWO) Completion Details N. -mal rop (ND) TOP Incl rop (ince) (n A. (°I Ibm Dos ],3189 QO 0 34.00 LOCATOR Can ID D.)TANDEM OTIS STRAIGHT SLOT LOCATOR .000 WEDGEt]a8T4 NIPxE; Tarr TANDEM WEDGE; 7w2,\.-4.79790 IPEer:TvOrio to FRACSPNR7.,Ba0 RPERP.Tsga7.2a4.o NIEPIE:]..2 xo TMases]322.t)345.9 33 $1-0TTED LINER WRN OBANGE PEEL WEDGE ], 0.1 60 ].0 34.00 PACKER OTSWD PERMANENT PACKER 4.350 ), 24.0 6,10 .2 .99 MILL ], 0.1 6,11 .5 94 NIPPLE 6,118.4 33.93 505 OTI$MILL OUT ERTEN ION OTIS 2.81"%NS POLISHED BORE NIPPLE wl275"NO GO 2.813 IB HEAR UT SU .ELMD TTL 7 .ring R on 44)0 3/22/2118 BOTTOM;].2]31 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TOP Me) 7254.0 roplrvm (in B) 6,042.2 Tnp incl Eli 3401 ar mean IaSt Rings hom Original COm Run Gab ]261201 N(m) O.OD1 RPERF;] 25 s.DTMAl PERF,].i%LL7.al0.Od 1PERF,42m67,.0 RPERF; ].aG W.PG0 amen east RrGs,mm Ong.a cw,aamn.0= a CHEMICAL cur 7.=,O 7, 00.0 6,0 5 Mas Completion E AL CDT 2.625 Chemical CUL )142019 .992 PROOUGT..:Ism B ],3230 6,0994 3399 RETAINER L REMAOVED, 277 OD X 116' LENGTH 61131201 1130 LOCATOR:].3189 GUTTED PACNER;7.3201 CEMENTRETNNER- GL REO: ],3A0 Perforations& Slots SnOI Deni MILL;).%R0BM NgPEU%7Aa1 sob:Isar. m raeM (iV01 bnalsrrp0 .re Top XtlMA-1(nMean K81 IBNN LNka42one Dab 1 IM(B) 21/1902 120 IPERF 5'Vann Guns 7184 7,2440 5,984.1 6,03J.9 C4, 1F-0] 911/1984 120 RPERF 5"DA; 90 deg 7911 7,255. 7,2600 00430 .04). UNIT e, IF -97 1 2111 12.0 IPERF 5'Vann Guns 7,255. ),2fi0.o 6, 0 6,04]. UNIT B, IF -0) 911/1984 12.0 RPERF 5"DA; Otleg ph nn ],268. ],282.0 6,0538 8,065.4 UNIT B, IF -07 1 2111 120 IPERF 5- V. Guns 7,26 .0 7,2820 6053.8 6,0654 UNIT 8,1F-07 1/1984 120 BEER F 5"DA; 90 deg ph RPERF', 7AD.a?40BO 7,393.0 ],4050 619.5 6,167.4 AA, lF-07 1012111 12.0 IPERF s'Venn guns 7,39 .0 7,4050 611 .5 616)4 AA, 1F-07 1 1012006 6. RPERF P^" IPERF;].39307, 0 7,4 .0 ),4460 6,179.9 6,2018 M.1F-0] 1012111882 12.0 IPERF 5"Vann guns FRm A-eANo: ].ano 7,4 .0 7,4580 6.0].5 8.211.8 A�4, 1FA] 102111982 1201PERF 5"Vann guns IPERF', 7seraTMBO Frac Summary Samoan pmpWnt Deslpne411N PmpMntln FormatlO11 1b1 IPERF;]4`3.6],45B0 912320079 ya cMan (bMl vO1sl.rrylbbq BN% Bx menoWe T.0s, Mi Mses) Lin4lo Fluia sa..ysbm 1 92312000 7,184.0 7,244.0 Pmppant;did roppa saidDens Pntln Fwmatlpn (lel 102712006 .......s, VOl SW-Mb9 I.. Gbn Dah TOP-3lE"M(N 7.4 INNB) LNhb FluW 3yadm 1 1012712006 7,393.79 )ase.¢ PRooucn mr 32.1 d,0a50� KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 ConomPhillips All Inc. ¢m.Bzrmle lads a+Pm Mandrel Inserts Vweuledanutic laa¢p SL tl Top(N0) Valor La1M Pati TRORun .......................... ��- - NPNGER;01 N Tap (619 (RNs) L•'alla MG OD (in) Sery TyPe Typa Ilnl I2 Run Mh torn 1 2.4016 Camco MMG 112 GAS LIFT GLV RK 0.188 1,265.0 B 19 .119.d 2 4,18a8 3,880.2 Camco MMG 112 LIFT LV RK 0.186 1?51.0 &192019 3 5, 18]4,491.1 Oamro MMG 1112 GA LIFT GLV RK 0.1 8 1,202.0 8/1812019 d 6, 0 5,082.1 Cam. MMG 112 IGAS LIFT GLV RK 0.188 t?350 81191201 5 6,5507 5,476.5 Camco MMG 112 GAS LIFT GLV RK 0188 1,2270 8n92019 69.1 mco 57Da MMG 1112 GAS LIFT OV R K 01M 0 0 811812019 ],301.6 6, 01.fi OTIS TV—ALD 1 PROD DMV BN 0.000 0.0 91262006 conpumoR: as.oaoo6,9218 ] plo0 in meM rel SURFACE;..,2537- Inam essibl e due GFa LIFT: 3.Stea to Oran9 0 e peel G44 LIFT: 11 W B at BTM of GASLIFT; S�1B7 Notes: General & Safety End DaU, Innnubron W1N1984 I NOTE: WO GAB L". N..0 911012010 NOTEView SCM1emeec Wl Alaska CM1emetiC9.0 GASLIF EeoS1T WE LIFT; N. B LOCATM:aali.l SSE ISrI&n ELelmenl: 4e a 1 SSR ISwI bx RaupM1:'+1: S,iB11.1 PACKER: 6,9T1.0 NIPPLE', 7.0143 TANDEMWEDGI T.I e]a NPPLE: 71014 TANDEM WEDGE:?A 2 IPERF IAN.6]3a.0 FM CdANO: ].16aa RFERF;7,nN0-7. MAPLE', 7,22, 2 38SLOTTEOLININ IIN OR EPEELWEDGE BOTTOM:].. RPERF; 7.i 7.260 0` IPERF,7M0-7M0d (PERF, ' 7.2613 ?.M RPERF. T.RS.OI,Ri.O aroMan BYE Riga Rwn pplr W CallpbVn: T35a.0 , CNEMICPL CUT; PRODUCTION, 7X16 LOCATOR: 7.3189 PRCYER: 7.3YL1 CEMEMRETNNER- GOTTED: ]..0 MILL 7.aN.0 NIPPLE 73 W.1 SOE 7.315.9 MAI ].Si.D]..0 IPERF: G7,N5.0 FRAC ASIND, 7 S10 jj [I PERF', 7,QG O -7.M30 IPERF.7...G1,45130 PRODYCTION; W 16,0450� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing [2) Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well Re-enter Susp Well ❑ Other: CTD SETUP 2. Operator Name: ConocoPhilllps Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Exploratory ❑ Stratigraphic❑ Service ❑ 182-156 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-20830-00-00 7. Property Designation (Lease Number): S. Well Name and Number: ADL 25662 K RU 1F-07 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 8,060 feet Plugs measured None feet true vertical 6,717 feet Junk measured None feet Effective Depth measured 7,357 feet Packer measured 6972, 7320 feet true vertical 6,128 feet true vertical 5810, 6097 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 45 feet 16 80' MD 80' TVD SURFACE 2,225 feet 10 3/4 2,259' MD 2189' TVD PRODUCTION 8,013 feet 7 8,045' MD 6705' TVD Perforation depth: Measured depth: 7184-7458 feet True vertical depth: 5984-6212 feet Tubing (size, grade, measured and true vertical depth) 3.5" J-55 7,347' MD 6,119' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER FHL PACKER 6,972' MD 5,810' TVD PACKER - OTIS WD PERM PACKER 7,320' MD 6,100' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Priorto well operation:SHUT-IN Subsequent to operation: I SHUT-IN 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 10 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil E] Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-250 Contact Name: Dusty Ward Authorized Name: DustyWard Contact Email: DUsty.Ward@COp.COm Authorized Title: Sr. Wells Engineer ^� $_ t� Contact Phone: (907) 265-6531 Authorized Si 3 -.'1 nature: Date: Form 10-404 Revised 4/2017 V7 I— 'I I9/'j/sR BDMS. AUG2 9 2019Submit Original Only7 Conoco✓Phillips Alaska. Inc. KUP PROD WELLNAME 1F-07 UNIT WELLBORE 1 F-07 1GN..103:33'.itPM -- - Last Tag Yasin xlwroo[ la[MU Amoral pepM IR1(BI Eird Dads, I WellBoreteat Mao BY ....................... HANGER, S.<.... Last Tag. RKB (EST 52' RAT HOLE) 7,5 6/132019 1F-07 condijw Last Rev Reason AnIgYMn 1 EM Do. We1188h Last Mou By Rev Reason: Installed RockScleen 8252019 I1F-0] zedusej Casing Strings Casing Desmposm 1013 (an) ID pn Top Im"d sol DgNn goal Ser Boon m1ft-IsvLen g._anoe T., Imee CONDUCTOR 16 15.25 350 800 80.0 6500 H40 WELDED coupucroR:xam.o Alain,..o,on --ts.l ID(inl Tap lryKBl BM DeMn IBKeI SN OePn RVOF...n(I... Oo raOe TOP Tn1uE SURFACE 10 Y4 9.95 34.2 2,258.] 2,1890 4550 K55 BUTT Caing samooponOp 11.)nlist Tap(N{B) .DepM IM E) se doom (rvD1... wuLen p...araae Top TMaa] PRODUCTION 7 626 72.1 8.0450 6,]045 26.00 K-55 ETC Tubing Strings sURFhGE: said.(-- UFT, 2,18m. Is! no..... Putin string Ma... 3.5 "TANDEM J1/2 WEDGECTD SIDETRACK IDIiM 299 Top INKe) 28.9 7m"min(ft16e+ )248.1 Dep+n IrvD L.. 6,0373 wIgM11 9.30 aaae L -BO Top conne[non EUE Completion Details w$l1FT'A,+aga Top M01 I Topinol Nominal Top ofiti IRKBI B Ihm pons Com mlinl 4 28.4 0.13 HANGER FMC 11"x312" Gen 5 Tubing Hanger W/ 3.5" LEE 8rd Litt Urnied 7 90D risos UFT: sxa.] 69471 5,789.5 35.84 LOCATOR Baker gbh-2210cator sub 3000 8, 1 5,]90.3 35.82 SBE Baker 8040 seal assembly 217SDAL 42D lag 3980 6950.1 5,792.0 35.80 SBR Baker 80-40 PER 4.000 CMAUFT: e.oz20 6,9]20 5.8098 3554 PACKER Baker FHL pecker 6983 2930 7,014.3 5,844.3 3509 NIPPLE "x2.813" X dipole Prole SN )2727A-WgRHC 2813 installed cost-o"'L o.] 718)0 698].0 003 TANDEM NoMem Solu9ons 312"x9518" Tandem Wedge Assembly 2.992 WEDGE 7,2014 69986 73.97 NIPPLE HES 312". 2.813" X nipple Profile( N) 2.813 GM4 LIFT: sole ],207.2 60034 3396 IMMIX- Northern Solutions 312"x95/8"Tandem Wedge Assembly 2.992 1 WEDGE LO...B.WZ] 1 SBE: sise.1 7,2212 60150 33.99 NIPPLE HES 31 x 2.813" X nipple Profile (SN 2.813 saR'. B.esn+ vACKeRIea]20 ],223.1 6, 16.6 33.99 D Linked 275" ION, 755, Tell IOMd Pup Jt 2.800 LINER WITH ORANGE PEEL NIPPLE. 70143 WEDGE BOTTOM Tubing Discussion Ma...1011n) TUBING-RW0191M Jenny12 2.99 (after 2018 HAD TOPgIK8) ],2]8.4 SH DapM all: 7,3066 peon lTVDI1... B,1t89 WIgMe 9.30 J-55 j Tap ConnecWn BTC IPC Complegon Details Top TV Top Incl Nominal Top lZ811 MKe) fl Ile. pe[ Co. ID (in) TANDEM veeoGE, 7,1BTa NIPPLE_, 7" TANDEM wspGE,7,gT].z ],]18.9 fi0960 34.00 LOCATOR T STRAIGHT SLOT LOCATOR 3. ],320.1 ,09].0 3400 PACKER OT WO PERMANENT PACKER 4000 FRACC-B `d-;:2a.o (PER F:),18a.0.],3a s.0 ],324.0 ,1002 33.9 MILL O I MILL OUT EXTENSION 4.350 RPERF', T+U.o-T2a.0 7,340.1 6,113.5 33.94 NIPPLE OTI 81" XNS POLISHED BORE NIPPLE.12,75"NO GO 2.813 NIPPL.I 12 xo bass. 1..22y1 RMs[rax,;].Y1f0 7,345.9 6,1180 3393 S S TI H UT UB, EL 'during PPR on 4.470 31222008 3]3$LOTTIEDUNER WRH PEELWEDOE Other In Hole (reline retrievable plugs, valves, pumps, fish, BCORANGE EOTTOM. TiodI Top IND) Top ln[I roofers, ,9181 I'1 Oes Cam Run pale If (in) IPERF:T3 05 7200 RPERF:l,23507.ia10� 7,221.0 6, 148 33.99 RockSI,sEn 75"X-lockwl -Ro aeenw. slots(5T OAL) 252019 0000 PERF, Tzw0.].m1.0 `` RPERF:T,me.pT"I'd e.a, Bba Rrysnan owns Tzsa.a a OUT. 73go 0 7,254,6 6,642 34.61 Broken Ba51 Rings hom Original CompletionCHEMICAL -E 7262019 9.999 PRODUCTION', 7,331 a 7.300.0 6.01111 3405 CH QU77L CUT -CE 2.625 CIIemiral CUL 7142019 2.992 7,3230 6,09.4 ]3.99 MEN BAKER H I CE ME NT RETAINER W/BALL 6/132019 1.7130 - 30LOCATOR:]31es LOCATOR 7.A. PACKEI RETAINER- GUTTED REMAOVED, 277" 00 x 1.16' LENGTH CEMENTRETNNER- GUTTEp:7,3230 Perforations Bt slots MILL', 7,3240 -for Cans BIVa_ 1 L12t!j1F-07f lh pah (sn IMM TyTroiaCom Top(nKB) Dandruff) todift NIPPLE:7,sw.1 )184.0 7,244.0 5.984.1 6,0339 C4. 1021/1982 12.0 (PERF 5-Vonn Guns ),1840 7,2 6984.1 6039 C4,1F-07 91111980 12.0 RPERF 757,degph S. 134s.e 7,2550 ],260.0 6,043.0 70472 UNIT B, IF -07 1W2111982 12D (PERF 5"Vann Guns 7,260 7,255 0 6.04 .0 3.0 6,0472 UNIT B 07 PE , 1F-gt/1980 12.0 RRF 5" DA; 9D tleg -ph ;268.0 7,282.0 6,0538 fi3Ofi54 UNITS, IF -07 1021/1982 12.0 (PERF 5 -Vann Guns; 7268.0 7.29-0 6.053.8 6,0654 UNIT B, IF -07 &111984 12.0 RPERF 5"DA; deg ph ],3930 7,405. 6,157.5 6,1674 A4, 1F-0] 1021/1982 12. (PERF 5"Vannguns (PERF: 7.M 0-7,006b RPERF: ],393.0].a150 7,3930 7,405. 6.15].5 5,1574 A4, 770 10WXW2006 6. RPERF .5"H D deg. ph F PACAdM'D:],34A0 7,4 0 ],4415.0 6179.9 6,20. A4, IF -07 10121/1982 12.0 (PERF 5"Vann Buns PERF 743o7,4ae.o 7,45.0 ),458.0 ,2075 8,211. A-0, 1F-07 1021/19B2 120 11 IS"Vann guns IFERF:7,4113.0-0.4al. Frac Summary 9232000 PmpPentoeslgme006) Pmpment In Formals. ilii SK* 1 $un Dme Top pepM 9tl(BI Ban lBKe) Lima W FlUm sysdm VO LMn Tube Vol slurry(bag 9/212000 ],1840 ],2440 PRODUCTION. 32.Issas O Conoco`Phillips Alaska, Inc. KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 Ann°dlbn EM OaIe La5tW0' 77302019 IFm, evWime3:ss:.z PM Free Summary VeNslacnemerc(ectgl Stan Duke 1W272006 Pgppnt 0esgnM 1101 Proppant In F°emaapn YIN ............__ HANGER', M4 EV# SIa.Date Top 0ept01fBLBl efm lM(BI LIn, P, FNM.,stem VM Cyan leap V°I blueryryEp I 102)2006 7,393.0 7,458.0 Mandrel Inserts s ^i N T°y11VD) Valor LNN P°nSW TRO T°Pall(B 91KBt Mahe vieuMING Sery Type (.0 Run C°m 1 2,619.4 ,484.6 Camro MMG 1 70 1 GAS LIFT GLV LV RK 01 .188 ,255 1,2fi50 81202m9 19 conoucroa;Eom.o 2 4,189.8 3,660.2 Camro MMG 112 GAS LIFT GLV RK 0.188 1,251.0 8/192019 3 5,2167 4491.1 Camco MMG 112 GAS 177 GLV RK 01M 1,242.0 &182019 4 6.M0 5,082,1 Cam-. MMG ll2 GASLIFT GLV RK 0.188 1,235.0 87192019 5 6,5W.7 5,4]65 Camco MMG 1 V2 GAS LIFT GLV RK 0.188 1, ).0 87192019 suRFACP.31.x-22se.7� 8,921.8 5769.1 Camco MMG 112 GABLIFT OV RK 0.188 00 6/182019 W LIFT: 2 .194 7 30760816 OTIS TV—AL--D 1 PROD UM—Y— BK 0.000 00972612006 mG uc90 man4 rel ae3L1FT:4.18R8 inaa :Eaw e due M to G96LIFT;5,2167 omng e peel at GAE uFT...Mo BTM u i.n r Notes: General & Safety G43 LIFT:aW7 Em Oafa Ann°iaron 812612019 NOTE'.Vlew&hln,ab,Wl Alaska ScSematic10.0 GPB LIFT; 6,9218 LCEAEk. 8,99]1 4919.1 am B 68R;. PgCI(ER; 8,9]20 o NIPPLE. lun1 3 TPNOEMWEOGE;7.18)A NIPPLEaA19 TM.EM..Ge7,a112 FRAC CSAND. ], 181.0 IPERF: 7,1890] 2M0 RPERF: ].IB90].2M.0 NIPPLE. 7.221.2 XO MW e; 7,222,1 Rmukunan:],2210 3,S3L0TTEOIINERWITR ORANGE PEEL WEWE WTTOM; 7,2b1 IPERF: 7.255, 6].2620 RPERF,7,255.0),26C0� IPERF,],2BA0],i1.0 ` I RPERF: ],M07,=X EW BWi Rup M1gn p= Cu,npgBn,7.E40 a CREMICPICVT, 7Ap0 ..10..7301.: , L..M ],316 PMRER; CEMENTRENER-- GVT]E0:7M 0.0 MILL; 7...0 NIPPLE 7 310.1 306;],365.9 IPERF;],821.0],I06a RPERF, 7, M.G7,4050 FRACA- ND: "No IPERF:7.9MW.0 IPERF:],a53.07.458.0 PRpOVCTION: 32.1 d, W 5,0� Operations Summary (with Timelog Depths) IF -07 • Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur(m) Phase Op Cotle Activity cme Time P -T -X Opudpi Start Depth (WS) End DepN (ftKa) 7/20/2019 7/21/2019 24.00 MIRU MO VE MOB P RID -Derrick and mud pits Move Pits 00:00 00:00 and Rig Sub Base f/1 B- U1 F Pad camp and shop and Raise drrrick 7/21/2019 7/21/2019 4.00 MIRU MOVE MOB P Continue Rigging up derrick and pit on 00:00 04:00 1F-07 except Rig g @ 04:OOAM 7-21-19 7/21/2019 7/2112019 15.00 MIRU RPCOMP KLWL P R/U Sow back, to arm and tubing 04:00 19:00 Pulled BPV and Tubing pressure 1600 psi L/D Iub and R/U to pump 9.8 brinr Pump 3 bbls w/ 1560 psi W/ well bore fill of gas continue pump 9.8 brine 2X around Shut down and monitor well f/ 2 hrs stat out w/ 50 on Ann and 60 on tubing after 2 hrs by bleed down 2 bbls every 20 mins pres on tubing 0 and arm 0 when at 0 monitor 1 hr no build up and Set BPV and Test U 1000 psi F/ Below All good 7/212019 7/22/2019 5.00 MIRU RPCOMP NUND P N/D FMC Master Valve and adapter 19:00 00:00 flange, N/U BOP 7/22/2019 7/222619 5.50 MIRU RPCOMP NUND P Continue N/U BOP 00:00 05:30 7/22/2019 7/22/2019 1.50 MIRU RPCOMP RURD P Ru to test BOPE purge system, MU 05:30 07:00 dart and TIW valves for BOP test 250/2500 PSI. State AOGCC representative Lou Laubenstein waived witness. 7/22/2019 7/222019 5.00 MIRU RPCOMP BOPS P7— Test BOPE 250/2500 07:00 12:00 Test 1: B/R, CMV 1,2,3,16 Dart valve Test 2: B/R CMV 4,5,6 HCR kill, Test 3: B/R CMV 7,8,9, Manual kill, Test 4: Super choke, manual bean choke Test 5: B/R CMV, 10,11, Manual kill, Upper IBOP Test 6: B/R, CMV 12, 13, Lower IBOP Test 7: Annular, CMV 15 (12,13,8) Test 8 UPR, CMV 14 Test 9: UPR, HCR Choke Test 10: UPR, Manual choke Test 11: Lower Pipe rams Test 12 Koomey 7/22/2019 7/22/2019 2.50 COMPZN RPCOMP RURD P Pull Blanking plug withtest joint and 12:00 14:30 LID test joint and blanking plug, attempt to pull BPV, gas seen in stack, attempt to blled gass off under plug. Unable to bleed off gas. 7/22/2019 722/2019 3.00 COMPZN RPCOMP CIRC P PJSM for circulating and R/U to 14:30 17:30 circulate, Displace well @ 3 bbls min w/360 psi with 9.9+ brine w/ No issues 7/22/2019 7/22/2019 2.00 COMPZN RPCOMP THGR P Shut down And monitor well 30 mins 17:30 19:30 Ok Pull BPV and Monitor well R/U Pulled Hanger to Floor PUW 82K no issues I/D hanger and Monitor well All good 7/22/2019 7/23/2019 4.50 COMPZN RPCOMP TRIP P POOH and Stand Back 3 1/2" 9.3# 19:30 00:00 EUE 8rd L-80 and SLM out lost rate 23 bbls hr 7/23/2019 7/23/2019 1.00 COMPZN RPCOMP TRIP P Continue to Stand Back Tot of 71 00:00 01:00 Stands in Derrick and LID Seal Assy 7/23/2019 7/23/2019 2.00 COMPZN RPCOMP BHAH P Clean up Floor,Set Wear Ring bushing 01:00 03:00 and Load pipe shed W/ BHA# 1 7/23/2019 7/23/2019 2.00 COMPZN RPCOMP SHAH P P/U Baker BHA# 1 03:00 05:00 Page 114 Report Printed: 8/1/2019 Operations Summary (with Timelog Depths) 1 F-07 Rig: NABORS 7ES Job: RECOMPLETION Time Log Slav Depth Start Time End Time Da (he) Phase Op Code Activity Cove Time P -T -X Operation (ftKB) End Depth^8) 7/23/2019 7/23/2019 8.00 COMPZN RPCOMP PULD P Continue PIU 3 1/2" HT 38 D.P single 05:00 13:00 in hole T/ 6970' 7/23/2019 7/23/2019 1.00 COMPZN RPCOMP FISH P PUW 125K SOW 102K RIH slow and 13:00 14:00 Latch up @ 6970' Pick up T/ 225K and Release PKR and work -string free after PKR free 132K PUW 7/23/2019 7123/2019 5.00 COMPZN RPCOMP CIRC P Monitor well and Circ out Gas Bubble 14:00 19:00 out Through Choke Manifold @ 3 BBIs min W/ 455 PSI fuild loss 30 bbis Hr Open up to Well and Monitor Well continue CBU Down Flow line w/ no Issue 7/23/2019 7/2412019 5.00 COMPZN RPCOMP PULL POOH and Stand Back 3 1/2" HT 38 19:00 00:00 Work -String 7/24/2019 712412019 2.00 COMPZN RPCOMP PULL P Continue POOH and Stand Back 3 180.0 00:00 02:00 1/2" HT 38 Work -String 7/2412019 7/24/2019 3.50 COMPZN RPCOMP BHAH P Stand Back 4 314 D.0 and LJD Pkr 180.0 220.0 02:00 05:30 and Tail pipe easy w/3 1/2" EUE 8rd Tubing W/poor boy over shat. Install bowl protector. Clean up Foor. M/U BHA# 2 W/ 3 1/2' over shot basket grapple. 7/24/2019 7/24/2019 1.00 COMPZN RPCOMP SVRG P Grease and service rig. 220.0 220.0 05:30 06:30 7/24/2019 7/24/2019 4.50 COMPZN RPCOMP TRIP P TIH with BHA -2 and 3-1/2" DP from 220.0 7,022.0 06:30 11:00 220' to TOF at 7156' wash over cut joint to 7161' PUW=140 SOW=104 Free Tq=3600 ft/lbs. PUH to 7096 PUW=190K work pipe free. cont to PUH to 7022' 7/24/2019 7/24/2019 0.50 COMPZN RPCOMP CIRC P Complete CBU W/9.9 ppg brine 7,022.0 7,022.0 11:00 11:30 7/24/2019 7/24/2019 0.50 COMPZN RPCOMP OWFF P OWFF for 30 minutes. 7,022.0 7,022.0 11:30 12:00 7/24/2019 712412019 7.00 COMPZN RPCOMP TRIP P POOH racking back 3-1/2" DP to fish. 7,022.0 12:00 19:00 7/24/2019 7/24/2019 2.00 COMPZN RPCOMP BHAH P Stand Back BHA# 2 LID Baker Over 19:00 21:00 shot w/cut joint on 7/24/2019 7/25/2019 4.00 COMPZN RPCOMP PULL P Continue L/D blast Rings Joint R/U 21:00 01:00 PESI Tools And L/D Bast joints Lost! 2'orl5' blast rings lost recover all tubing parts Clean up floor and R/D PESI tools Load BHA# 3 on Rig Floor 7125/2019 7/252019 1.50 COMPZN RPCOMP BHAH P Continue M1U BHA# 3 Clean out Run 00:00 01:30 1 71271.60 7/25/2019 7125/2019 6.25 COMPZN RPCOMP TRIP P Continue RIH w/ 3 1/2" HT 38 Work - 01:30 07:45 String F/ 271.60 T/7260' set down I OK, Worked scraper from 6943' to 7023' 5 times. 7/25/2019 7/25/2019 4.50 COMPZN RPCOMP CIRC P Circulate vis sweep surface to surface 07:45 12:15 W/9.9ppg brine. 7/25/2019 7/25/2019 6.75 COMPZN RPCOMP PULD P POOH and L/D All HT 38 Work -string 12:15 19:00 7/25/2019 7/2512019 2.00 COMPZN RPCOMP BHAH PContinue L/D BHA# 3 and Clean up 19:00 21:00 Floor and Pull Wear Ring Bushing. 7/2512019 7/2512019 1.50 COMPZN RPCOMP RCST P R/U to run 3 1/2" 9.3# L-80 completion 21:00 22:30 Assy and load pipe shed w/ completion Assy 712512019 7/2612019 1.50 COMPZN RPCOMP RCST P M/U 3 1/2" 9.3# L-80 Completion Asst 22:30 00:00 as Plan M/U Tq 2600 Ib Mod Tubing Page 214 Report Primed: 811/2019 ANT% Operations Summary (with Timelog Depths) 1 F-07 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time Ertl Time our (m) Phase Op code Ad Ay Cade Time P -T-% Ope20on (ftK6) End Depth(ftKa) 7/26/2019 7/26/2019 8.00 COMPZN RPCOMP RCST P Continue RIH 31/2" 9.3# L-80 00:00 08:00 Completion Assy as Plan M/U Tq 2600 to Mod Tubing 7/26/2019 712612019 2.75 COMPZN RPCOMP HOSO P MU planned space out pups to string 08:00 10:45 8.19', 8.20', 4.19', 4.18' 24.76' OAL PU 1 jt and RIH tagged up at 7245' 15' off clean out tag depth. Swap pups out 1 Point. 7/26/2019 7/26/2019 0.25 COMPZN RPCOMP SFTY P PJSM for R/U E -line with Nabors AK 10:45 11:00 1 and SLB. 7/26/2019 7/26/2019 4.00 COMPZN RPCOMP ELOG P RU SLB E -line for correlation log. RIH 1100 15:00 with E -line GR/CCL correlation log, Verified 15' off tag depth from DP clean out run with E -line log and tubing tally.R/D E -line and have Standby for repeat logging run. 7/26/2019 7/26/2019 2.00 COMPZN RPCOMP RCST P Discussed with Dusty Ward plan 1500 1700 forward. P/U 2 joints and attempt to wash completion to depth. R/U to pump down tubing first per Baker rep recommendation. circulate at 3 BPM while RIH F/7203' T77249' unable to get any deeper. PUH to 7231'.PUW-88K Line up and reverse circulate 25 BBL'S at 3 BPM CP- 485 psi with a closed annular. RIH to 7249' SOW -70K unable to make it any deeper. PUH to 7210' PUW-88K circ down TBG at 3BPM 660 PSI Confirmed with Engineer to re -log to verfly depth. 7/26/2019 7/26/2019 1.00 COMPZN RPCOMP RURD P UD one joint. BTM of tubing string at 17:00 18:00 7230' RD Circ lines and RU E -line. 7/26/2019 7126/2019 3.00 COMPZN RPCOMP ELOG P RIH with Eline. T/7010' Tag HRC plug 18:00 21:00 @ 7010' Log up 200' and POOH and R/D SBL and R/U to Set top PKR 6968' 7/26/2019 7126/2019 1.00 COMPZN RPCOMP THGR P Drop Rod and Ball Set PKR and Test 21:00 22:00 same Test Tuibing 2500 PSI 5 mins All good Test Ann 1000 PSI 10 mins Bleed to 0 P/U and shear out 25K over Space out 1.6' Off no Go and M/U hanger and Landing joint 7/26/2019 7127/2019 2.00 COMPZN RPCOMP CIRC P Displace Well W/ 9.9+ brine pumping 22:00 00:00 down Back side @ 3 bbls mins WI 240 psi 7/27/2019 7/27/2019 2.00 COMPZN RPCOMP PRTS P Lower FMC Hanger Down RILDS Test 00:00 02:00 tubing T/3000PSI 5 mins All good Bleed down tubing t/1600 psi, Pres up on casing T/2500 PSI F/ 30 mins All Good Bleed down Tubing and shear out 1800 psi SOV Bleed off All pres TIO Blow Down All lines BOLD and Set BPV and test F/ Below T/1000 PSI Allgood 7/27/2019 7/27/2019 18.00 COMPZN RPCOMP NUND P N/D BOP Pull out All BOP rams and 02:00 20:00 NIU FMC Tree 7/27/2019 7/28/2019 4.00 COMPZN RPCOMP FRZP P Test FMC tree and R/U LRS and test 20:00 00:00 lines U 2000 psi displace 80 bbls diesel @ 3 MIS minw/ 450 psi and Shut down and U- Tub 1 hr All good and set BPV Blow Down All lines Page 314 Report Printed: 8/112019 Operations Summary (with Timelog Depths) 1 F-07 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Stars Time End Time our (hr) Phase Op Code Adivity Code Time P-T-X Operation (WB) End Death(RKB) 7/28/2019 7/29/2019 24.00 COMPZN MOVE DMOB P Clean up Tools and ship out clean up 00:00 00:00 pits and prep to move rig to east corner of pad Drain All fluids in pits 7/29/2019 7/30/2019 24.00 COMPZN MOVE MOB P Clean up Tools and ship out clean up 00:00 00:00 pits and prep to move rig to east corner of pad Drain All fluids in pits Move Pit to staging area on 1 F pad. 7/30/2019 7/31/2019 24.00 COMPZN MOVE DMOB P Conoco release Rig on the 00:00 00:00 Mobilisation on 1F pad and NaborsTime after Midnight 7-30-19 This is the last Report on 1 F pad Page 414 ReportPrinted: 8/1/2019 VS -11. ProActive Diagnostic Services, Inc. WELL LO TRANSM17 TAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907)793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection (Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: 31149 READ Cased Hole, Inc. RECEIVE® Attn: Diane Williams AUG 19 2019 130 West International Airport Road Suite C Anchorage, AK 99518 AOGCC Dianw. W illiamsgreadcasedhole.com 25 -Jun -19 1F-07 1 Report /CD 50-029-20830-00 Date : o ! ml PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM haps 'rude mdhole-my.sharepaim.corW erson idiane_williams read,aeedhole_coMDocomentxNe op'ConocoPhillipa_T..itdoa 9 8Z1 56 31149 CASED Multi -Finger Caliper HOLE Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1F-07 Log Date: June 25, 2019 Field: Kuparuk Log No.: 15689 State: Alaska Run No.: 3 API No. 50-029-20830-00 Pipe Description: 3.5 inch 9.3 Ib. L-80 EUE 8rd Mod Top Log Interval: 6,867 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 7,172 Ft. (MD) Pipe Description: 3.5 inch 9.3 Ib. J-55 FL4S Top Log Interval: 7,172 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 7,307 Ft. (MD) Inspection Type: Corrosive $ Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of the X Nipple at 7,066.8 feet (Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate significant wall penetration in an area of apparent mechanical damage in pup joint 221.4 at 7,168 feet, with a 23% cross-sectional wall loss recorded in the same area. A 3- D log plot of the caliper recordings across the interval from 7,090 feet to the end of the log is included in this report. No other significant wall penetrations, area of cross-sectional wall loss or I.D. restrictions are recorded outside the perforation intervals. The body region analysis and joint tabulation data for the 3.5 inch L-80 and J-55 tubing are combined. This is the third time a READ caliper has been run in this well, the second time the 3.5 inch tubing has been logged since RWO in 2018. Due to the short duration between the current and previous log (January 21, 2019) no comparison graph is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Apparent Mechanical Damage 78 221 A 7,168 Ft. (MD) No other significant wall penetrations (> 18%) are recorded outside the perforation intervals. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Apparent Mechanical Damage 23 221.4 7,168 Ft. (MD) No other significant areas of cross-sectional wall loss (> 10%) are recorded outside the perforation intervals. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. B. Suhanek HY. Yang B. Worthington READ Cased Hole Inc. / P.O. Box 1359, Stafford. TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica@readcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 F -ax: (907) 6S9 -;13,L4 CASED Multifin Cali 3D Lo Plot ---�� HOLE ger per g Company: ConocoPhillips Alaska, Inc. Field : Kuparuk Well: 1F-07 Date: June 25, 2019 Description : Detail of Caliper Recordings From 7,090'to the End of the Log Comments Depth Maximum Penetration Maximum I.D. 3-0 Log Image Map 1ft:175ft 0 % 100 2.5 inches 3.5 0° 0' 90° 180° 270° 0` Minimum I.D. 2.5 Inches 3.5 Average I.D. 2.5 inches 3.5 Nominal I.D. ..................................................... 2.5 inches 3.5 Joint 220 7100 I _- I 7110 Joint 224 7120 Apparent Shallow Mechanical -- - Damage 7130 7140 Pu 7150 i _. Pup --- - Non -sealing Overshot 7180 j Pup Apparent Mechanical Damage - 78% Wall Pen. - - 23% Wall Loss - - - 07.166• 7170 i 7180 Joint 222 Blast Joint Pertoratlons 7190 j - Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (6,867.2'- 7,317.4') Well: 1F-07 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: June 25, 2019 . Approx. 216 Tool Deviation ■ Approx. Borehole Profile 6,867 GLM 6 ELO G L � Z C L C O p, 220 Q 7,078 7,259 GLM 7-- 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey - 225.3 ■ Perforations Pipe Nom.OD _1% ICASED Grade & Thread Nom -ID Top Depth HOLE Body Region Analysis Well: 1F-07 Survey Date: June 25, 2019 Field: Kuparuk Tool Type: UW MFC 24 EXT No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Analyst: Yang Pipe Nom.OD Weight Grade & Thread Nom -ID Top Depth 3.5 in. 9.3 ppf L-80 2.992 in. 6,867 ft. 3.5 in. 9.3 ppf J-55 2.992 in. 7,172 ft. Damage Configuration (body) 10 8 6 4 -- 2 0 Isolated General tine Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole •rW.u. d(total r r Bottom Depth 7,172 ft. Damage Profile (% wall) Penetration body Metal loss body 0 50 100 GLM 6 (5:30) GLM 7 (10:30) Bottom of Survey = 225.3 Perforations Well: Field: Company: CASED HOLE 1F-07 Kuparuk ConocoPhilips Alaska, Inc. Joint Tabulation Sheet Survey Date: June 25, 2019 Analyst: Yang Pipe Description 3.5 in. 9.3 ppf 3.5 in. 9.3 ppf L-80 Tubing J-55 Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 6,867 ft. 2.992 in. 0.254 in. 7,172 ft. Bottom Depth 7,172 ft. 7,317 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 216 6867 0 0.02 7 2 2.96 216.1 6899 0 0.03 11 5 2.96 Pu 216.2 6909 0 0 0 0 2.91 GLM 6 Latch @ 5:30 216.3 6918 0 0.04 17 7 2.97 Pu Shallow Pittin 217 6928 0 0.02 7 4 2.96 217.1 6959 0.04 1 0.05 18 9 2.94 Pu Shallow Line of Pits. 217.2 696:5)0--t 0 2.93 Baker GBg22 Locator Sub 217.3 6965 0 0 0 0 2. 8 Baker 80.40 eal mbly 217.4 6977 1 0 1 0 0 0 3.00 BAKER 80.40 PBR 217.5 6983 1 0 0 0 1 0 1 2.91 Baker 4782 FHL 60K shear releasel Packer 217.6 6990 0 0.03 11 i 4 1 2.95 Pu 218 6994 0 0.04 14 8 2.96 21 7025 0 0.02 9 5 5 219.1 7057 0 0.03 11 5 2.95 Pu 219.2 7067 0 0 0 0 2.88 Halliburton 2.813 X Ni le Milled out to 2.87' 219.3 1 7068 0 0.03 137 2.96 Pu 220 7078 0 0.02 9 4 2.95 221 7107 0 C. 18 4 2.96 _ A arent Shallow Mechanical Damaee,_ 221.1 7138 0.04 0.03 11 4 2.95 Pu 221.2 7149 0.05 0.04 17 6 2.96 Pu Shallow Line of Pits. 221.3 7155 0 0 0 0 3.00 Non -sealing Overshot 221.4 7156 0 -Q. 26 23 2.9 J!un Anparent Mechaniggl Damage, 222 L223._ 224_ 225_ _ 2 5.1_ 7172 0 7202. 0 7230__. Q 7S9x_ 0' 7289 0 �_ 0.29 0.02 002 002 0. 3 100 + ,7 , 7 � , 12961Blast-I6 9 T 3 11 3 2.96 _2,95 2.94 2.94 Blast�oint Perforations. } -- -- j Blagt4 mint Perforations. Perforations.^ Blastloint. Perforations. Pu 225.2 7 93 0 0 0 0 2.89 GLM 7 Latch 010:30 225.3 7300 0 0 02 9 21 2.93 1 Pu Penetration Perforations Metal Loss Perforations Page i Penetration Body Metal Loss Body —_=: CASED HOLE Well: 1 F-07 Field: Kuparuk Company: ConocoPhillips Alaska, Inc Country: USA Cross-sectional Illustration Survey Date: June 25, 2019 Tool Type: UW MFC 24 EXT No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 221.4 at depth 7,168.470 ft. Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 78% Tool deviation = 36° Finger = 4 Penetration = 0.199 in. Apparent Mechanical Damage 0.20 in. = 78% Wall Penetration HIGH SIDE = UP =_� CASED HOLE Well: 1 F-07 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration Survey Date: June 25, 2019 Tool Type: UW MFC 24 EXT No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 221.4 at depth 7,168.440 ft. Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 77% Tool deviation = 36° Finger = 6 Penetration= 0.194 in. Apparent Mechanical Damage 23% Cross -Sectional Wall Loss HIGH SIDE = UP � KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 COIIOCoPhillips wenwnno tx MaxAngle&MD TD AlaskX, II1L. FkWName Wxlb2p➢IIDNI WeII1wr88hWs KUPARUKRIVER UNR 500292083000 PROD Pilon MO(N(a) Mahn(IIKRI 5.700.M B4O60.0 Canmad X391pPn) OMe MInWO EM SSSV: NONE 411 911012016 lad WO: &1>2018 Dab a9QdM 44Reka¢e WR 40.58 1021/1982 +Fav, mlrwtastem Aw Last Tag vM4slµMrnLLc leolup AWWW- DWIhMa) I EWD. I VMLL I unimway _-PANc6n1 rB'e Te9:7 LM 2018 -0) JM1anaen Last Rev Reason Mnofelbn EM Deb Welllcra Leda of By Rev REaaort Post CTD lnMnl New GLD 11 M2018 iF�p7 JM1xmen9 Casing Strings Gaaq DeecnWun oD pN ID pN T.F(mal ax Degh(ma) 6x DeptM1 jNp).,. KVlnn ll._ Gratle ZThread CONDUCT00. 16 15.25 35.0 80.0 KO 65.00 H-00 WElDEO CONdICTOR; 36.aa].a DIIN Ipllnl Top(aaal adD7"'-al 9x 0epM pV01... NVLan ll... amtle Tcp Taread Oeglgbn 1-,, SURFACE SURFACE 10314 9.85 31.2 2,158) 2,189.0 45.50 K-55 HUIT PROD CION n oD ON 6.28 roplKKB) BetDpMIM(e) 9d DepM1 (IVp)... 26., ... emtla ToplTrgE PRODUCTION ] fiR8 32.1 S.Od5.0 8.'04.5 28.00 055 BTC Tubing wings SURFACE; 842?269.7- TOM,peacOman atrHq Ift IDIN) Tw(flKB) Sx DepN IR. ad CePlli RVD) (... LYL(MIry (Yelp Top LonmcfMn TUBING -2016 RWO 3112 2.99 28.4 2162.3 5,966.2 9.30 L50 EVE Brtl Mod Completion Details GA6 LIFT: ;4122 P1.1 ) TOpTTVD) Ta �Lmn I�Oet Nomivl Tap(IIKa nID lin) A 2, 0.1 ANGER Tubing Har,er, FM C TC1A-E S10.86'O.U.WI3.SCIWH-B G Dna UFT: a.M. 8,9 .8 5,800.7 35.7 LOCATOR Locator ub, Baker, BH22IbOttom I@ motor SpemdoInJ 2910 6,%.8 E,801.5 35.68 SBE al Assembly, 8aun. (10811an91a=11.76,) 3.000 8,969.6 5,8(18.0 3 . PBR PER, Baker, 0.4 2. p -9 ons uFT:5889 6.9 .5 8-18-3 35.41 PACKER Packer, Baker, 7M -FHL (60KfiM1ear rdue") 2800 ],066.8 5, 74 .70 NIPPLE Nipple, Halliburton, 2813'Xprofile, 2813 ""(MILLED OUTTO 2 87'I^"""' anauFT;6.061.1 7.1 9T5 5,%.7 34. B POOR BOY Nomaedingov Wm 3 OVERSHOT Ons urr; 8ss61 TUM,I "!M -S, Me... I13IM) TUBING -9001984 412 2.99 (efler 21118 RWO) TW(MsS 7,161.9 -owtn(a.,M ],348.6 eplM1 (rVD11 61116.9 Yfllp'rtl 9.3D 8101. 755 TepCmmedm FLdS Completion Details GAS UFT; 494 04 TOP MOMI Ta1VOM p) ToopI�IWI Ilam OmSWIM 7,181.0 5,981.7 34.% RIASTRIN S -9 TRWGS( Lem IDM) 7,318.9 8,096.0 A. LOCATOR OTIS $TRAI HT BLOT IACAT R 3000 LOCATE aeras6860.8 aeE : 7,320.1 ,097.0 M. PAC ER OTIS WD PERMANENT PACKER -000 24.0 6,100.2 .99 MI 0ISMLL UT BON 4.350 PeR; 8.689 PALKEN: 8,8025 ,- 1 I 6, 13.5 3.84 NIPPLE OTIS 2,81 MS POLISHED SORE NIPPLE w/ 2.75- NO GO 2.813 ),345.9 8,116.4 33Vb bTI-S SH OTSU,FIMD TTL'] 'dudn9 P,0F On 4470 3?2/2008 nIPPLE; 7,p(4.e Perforations & Slots SMt TW nVD) amITva) Orae repeMe) 6110 tXaal IaKel 108.1 unlrod2ane px. IsIro1M ryW Cdn 7,1 .0 ],244.0 5,9 .1 6,033.9 CA, 11-07 ID121/1882 12.p (PERF 5" Venn U.B --7, 7,184. 44. 5,9 .1 6,033.9 C4, IF - 1/1984 12. RPERF TDA;90degph POOR aOV R,1Vsie ], .0 6.W7T UNITS. 'F417IV21 IT ,1F-0]1 2 12.0 PE 3 Venn O. .7,255.0 J, 6, .0 6,04].2 UNIT B, iF-07 9/1119% 2.0 RPERF 5'DA;%de9 ph -7M-C ).268.0 6, 6,0 A UNIT B,7F 012111982 12.0 IPERF SVann uns FRAC csagD; 7,te1.d (PERF: T,1Mg-7 W O RPERF; 710La7,a1AD aL60TRINO6, 7,101.0 ],2680 7282.0 600-8-9-M-49/1/1 .UNTB,iF 7 984 1 RPERF 5"DA; 80 de9 ph ].393.0 >,405.0 6,15.7.5 6,16].49 F-07 1M1/1% -12.0 TPER-F 5'VaMguns ]393. 7405. ,15-.5 6,167.4 A-4, 1F-07 Wt 006 6.0 RPERF 2.5"HSD HJ SOX, de9. RPERF:7=0. 7,=0 IPERF'gas'0'J'ao'ol- IPERF:>.ZB0.0.J,�1.0 RFERF.7,zfie.a7.a,.di�_ ph --f4-60 ],420.0 fi, 79.9 6, 201.6 Ai, iF-0] 1021/1982 12.0 IPERF 5'Vann9uns J,4 3.0 ],7,58.0 6,201.5 fi,211.8 M4, IF -07 1M 11982 2.0 FM 5' Vann Buna Fres Summary PROWCTION: 1.801.6 Manan ft,,W Da,nad116) Pronpntln Formaryon 6M W.TOR 7a189 PAOKER.7=1 a,i 1 8490.4 TW DeNM1(KKB) BM(OKa) UW FluMByWm yalCWn(Mp yd Slurryl6M 9232000 7,184.0 7,244.0 ffid0ab PrOPWx O-iiM Puu,-nnFWmU.(1b) 102712008 MLn 7821.0 GW2 BYB Deb TWmW-( -) SWISE6) LNklOR-Sy-, yol Ckan(bdl Vd51w 1 101712006 7,3930 7,458.0 rv16M Mandrel inserts at W NIPFUE 7.w.t H TWOW, `7,M is h TW(M®1 WES Men, M. ODlin) sxv TyW TypoWnpeb11 2,6 2 ,521. SLB MMG 112 GASL1, GLV 7,KlJMO18V47.7 WM 3.'93.8 LBMM 11 GASLIFT LV R 1 184526.8 SLB MMG 111 GAS LIFT GLV K 18 5,115.1 B G U T GLV 0.1RPERF7]OYvOIPERP: 7,pw.a7 uO 5,5115 LB GA LIFT LV RK 0188 2270 112 18 FSACAB a78.80 TG 6,904.4 5,> 5. BLB LIFT 0 RK 01 8 0.0112 201.PERF; 7ITn0> (PERF?..0-7AY.0 01 ],301fi 1.6 OTIS PROD DMV EK - K 0.000 0.0 2 006 Notes: Generel & Safety .. -MWblmn EM Om I 9/1011984 NOTE WO PR.O 132156 WELL LOG TRANSMITTAL 4905769461 To: Alaska Oil and Gas Conservation Comm. August 6, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 AUG 13 2019 AOGCC RE: Multi Finger Caliper, Cement Retainer, Gamma Ray, and String Shot Records: 1 F-07 Run Date: 6/13/2019, 07/02/2019, and 07/11/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1F-07 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20830-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: W/ -/ // off Signed: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Gary Eller Wells Advisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F-07 Permit to Drill Number: 182-156 Sundry Number: 319-284 Dear Mr. Eller: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Ww .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, `� %� leri ielowski Commissioner DATED this I2 day of June, 2019. RBDMS! '" JUN 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUN 05 2p? P75p�Qe�It- 19 AOGVC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Reddll ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: PACKER REMOVAL 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development 17 - Stratigraphic ❑ Service ❑ 182-156 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20830-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 F-07 - Will planned perforations require a spacing exception? Yes ❑ No Q 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25662 • I 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): 8,060' 6,717' 7357 6128 2339psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 45' 16" 80' 51858' Surface 2,225' 10314 2,259' 6,090' Production 8,013' 7" 8,045' 1,836' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7184.7458 598446212 3.5 J-55 7,346' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - PACKER, BAKER, 4782 FHL MD= 6983 TVD= 5618 PACKER - OTIS WD PERMANENT PACKER MD= 7320 TVD= 6097 SSSV - NONE N/A 12. Attachments: Proposal Summary El Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ DevelopmentEl ' Service ❑ 14. Estimated Date for WI.ThLbli 15. Well Status after proposed work: Commencing Operations: OIL EI 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. Authorizetl Name: Gary Eller Contact Name: Gary Eller Authorized Tide: Wells Advisor Contact Email: J.Gary.Eller@cop.com Contact Phone: (907) 263-4172 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commissions that a representative may witness Sundry Number: I ^ /_/II Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS(�JUN 13 2019 Post Initial Injection MIT Req'd? Yes ❑ No rf Spacing Exception Required? Yes ❑ No Subsequent Form Required: � APPROVED BY 7 } COMMISSIONER THE COMMISSION Date: W141-1 Approved by:nLffillu _ 1 IOtil IWR I ¢dlaltFt Lm kat Submit Form and Form 10-403 Revised 4/2017 Approved appl 1 a O 1 the date of approval. ,�� Attachments in Duplicate KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 COYWC0p11mP$ Well Attributes MaxAngle&MD TD Fee Name Welborc APIINYI WNIMrt SttlYs ndrl ink.) OCI BIm IOKe AlaBka,inc. KUPARUK RIVER UNIT 500292083000 PROD 4.83 5700.00 8.0600 Comment NR61ppm1 Ogle MM+tkn EW OYe KBGNIp Rip Release Dale SSBV: NONE 40 911012016 last WO: 81172018 40.59 IW21/1982 IFm,I.I.E%acne Last Tag v.nl[M.tnemata PCli.OI AnnMYpn OepMd%Xnl EM Dale 1 Wenhw. IxlMm ay Last Tag: R Kb (ter. 6701 Rai Hole) ],520.0112012019 1F-0] z.., MN Last Rev Reason Anode EM 13h I Wellbre non Motley Rev Reason: Updated Tag Depth 1120/LlN 1F -0J zembaej Casing Strings C. Desc,ipnnn DDlint ID lin) Top'"s sn Oeplh hlKB) Set DPih RVB- WIM, IL.. GrMe Top rpexl CONDUCTOR 16 1535 35.0 00.0 80.0 65.00 H40 WELDED Caine Desription ODlin) IDllnl Tap IIIKB) Set DePla IlIKR1 TW4Len IL, Gratle Tnp TMevl 1--parr-O... SURFACE 10 Y4 8.95 34.2 2258.] 2.189.0 45.50 K-55 BUTT OONOUc.0e;.,.. CalnpD-pan Oo lin/ IDllnl TopinKt,ouewroina) Set Oepui,-... MNLenpI-nae Tap TMutl PRODUCTION ] 6.28 32.1 8,045.0 6,]04.5 26.00 K-55 BTC Tubing SWngs Tubing Desnigbn Shirq Ma... lO In Tov RIK0 fief DepiM1 IR_a--Ih"O)I-.011116X) Orale Top6onneetian suREACE 34.72sse.7- TUBING-2018RW0 3112 2.99 28.4 7162.3 5,966.2 9.30 L-80 EUE Hrtl Motl Completion Details Tep(ND) T.PIMI Nnminzl roplxKel ONLal 0) ft.. par cnm IDON GAS LIFT; ZM.2 28.4 28.4 0.13 HANGER Tubing Hanger, FMC rCIA-ENS 1086' O.D.WI3.5'CIWH.BPVG 2992 GAS LIFT; as%s 6,960.8 5.8007 35.67 LOCATOR Locator Stilt Baker, GBH -22 (began Of locator spaCM out 3) 2.940 6.961.8 5.801.5 35.66 SBE Seal Analnby, Baker, 80 (total length =11.]6') 3.000 6,969.8 5,808.0 35.56 PER POP, Baker, 80-40 2.980 near LET. e.1 a 6982.5 6818.3 3541 PACKER Packed Baker, 4782 FHL (60K shear release) 2.940 7,066.8 5.087.4 34.70 NIPPLE Nipple, HallibuRan, 2.a10•X India, 2.813 "'•'(MIIJ.ED OUT TO 2.07')"--"" GAS LET: a%n 7,154.5 5,959.7 34.19 POOR BOY Nan-aealilgownhot 3750 OVERSHOT TYMnp Duc111YM BYIIq Ma.,. 10(Inl Tap IKILBI -OepM IIL. SaI OepIn RV.)I... WI IDIIt) one. Top Connection TUBING-RW01984 4V2 2.99 ],161.9 ).346.6 6,1189 9.30 J-55 FL45 Cas uFT:6a%.I Eoen 2018 RWO) Completion Details -P ("i Top Ind Nominal Top INKS) Intoe) r) Ipm par Co. IDnnl nes DET6a04.4 7,181,0 5.981.7 34.06 81ASTRINGS 31 -AST RINGS (4) 2.992 7318.9 6096.0 34.00 LOCATOR OTIS STRAIGHT SLOT LOCATOR 3.000 ,320.1 6,097. 34.00 PACKER OTIS WD PERMANENT PACKER 4.000 mura OBE:6.L%1.a.L. 7324.0 6.100.2 33.99 MILL OTIS MILL OUT EXTENSION 4.350 PeR: 6,fi9.e 7,3d0.1 8.113.5 33.94 NIPPLE OT15281"%NS POLISHED BORE NIPPLE .12.75' NO GO 2.813 PACKEe6'9az5 7,345.9 6,110.4 33.93 SOS OTIS SHEAR OUT SUB, ELMD TTL @7333 during PPROT on 4.470 Y2212008 Perroratlons & Slots MPPLE, 79N_e BIKK C nit TopINO) ..(,a) (aholarli ednlnMel Mal unkM IDne Wp 1 Can To7.18 RFTgO ).184.0 7.244.0 SEPIA 6.033.9 C -4.1F-0] 10/2111982 120 IPERF 5'Venn Guns .0 6.03 ],184.0 7244.0 6984.1 61133.9 C4. 1F-07 91111964 12.0 RPERF ST DA 90 deg ph 7, 600 7.2 UNIT B. IF47 1012111982 12.0 (PERF 5"Vann Guns Eo6a coy ovERSH9D55.0 INS9 7.2600 6. _76-97.2 UNIT B. IF -0) &111981 120 RPERF 5'DA; 90 deg Oh 7268.0 7.2820 6.063.0 6.065.4 UNIT B. IF -07 1012111982 12A IPERF 5 -Vann Guns ERAOCaANp7.INa .268. ].82.0 6,063.0 8.0854 UNIT B, IF -07 W111981 12.0 WERE 5' DA: 90 deg ph IPmP,,]INo-7Ja4a RPERF,716IN ],Na.O g na 7,393.0 ].405.0 6,15].5 6,16].4 A -0,1F-07 10121/1982 2.0 IPERF 'Varna aUe.71.07teL0 ],393.0 ],405.0 6,15].5 616].4 Ai, 1F-07 10110OKIN 6.0 RPERF 25•HSD HJ REX, 60 deg. RPERF;],29atrlr LO ,PERE 7, 6Lt7%aoL Dh ),4200 11446.0 6,1]9.9 6,201.6A{1F-0] 10/21/1982 12.01PERF 5 -Vann Ouns IPERF 7.269.67.MO RPERF', I.Vi 1]E20� ],453.0 1.4588 6,201.5 6.211.6 A-0, 1F-0] 10rz111982 12.0 (PERF 5 -Vann gMs Frac Summary PRODUCTION;]y)18 Shct Cavi Plopgnl 13-19netl II01Plcpgnl In Folmprri 9/2]12000 Ser Dah Top Depth lllKel Btm IXKB) Unit W Fluty System Vo1C4un1k69 VoI01urry1600 sv# 1 9123rz000 7,1840 1,244.0 LOCATOR, 7)19.9 PACKER1.734.1 Start bale Prgpam Oesignetl (In)Propgntln Formalkn gb) 10/211X006 Step SGr Dale Top Oepm IXKB)BM PIKE) tank 0 Flail System Volcker lba9 VeIONrry(hM .111ax.p 1 10127/2006 1,393.0 7458.0 Mandrel Inserts SI NIPPLE 7.340.1 m TOP IND) v.Ne LNeh Pa19be TRORun N Top Mal @KBI Make MMeI OD(in) Sery Type Type (in) Iq4 Run Dale Co.- -? 2.672.2 2,527.1 SI -B MMG 112 GAS LIFT GLV RK 0.188 1,265.0 1130/2018 a; 9 2 4,3365 3]93.6 SLB MMG 11rz GAS LIFT GLV RK 0.188 1,251.0 11130/2018 3 5261.8 4526.8 SLB MMG 1112 GAS LIFT GLV RK 0.188 1,242.0 1112912018 6.067.7 5,115. SLB G 777 GAS LIFT GLV RK 0.180 1.235.0 129/2018 PERF. 7.=p-7.345.0 aPERE.7..o-74%0 MMG 1112 GAS LIFT GLV RK 0.100 1,2270 11292018 FAAOA 140.7. Me 4-- fi 6,904.4 57560 818 MMG 1112 GAS LIFT OV RK 0.108 D.0 11128/2018 IPERF:].4M.0-].618.0 J 71301.6 6,081.6 OTIS OVAL❑ 1 PROD OMY EK DAO) 0.0 91262006 IPERF; ],49.6].4580 I I I Notes: General & Safety Ene Oah Anmlzlbn 9/01/1984 NOTE: WO PR .... RO.;-f-DIE.- KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 ConocoPhillips Alaska. Inc. 1F4I7, 1r 19 saxes AM Nates: General& Safety venwxn.mna aR'++9 End ozle Annolalon W10/2.16 NOTE: View SOFMm IicW/ Alaska Scnematic0.0 GNCVCTGR, 35 G20.0 SVRFACE:L?;7x.]— . LIFT. ;M] CJS LIFT, 4.3365— .3365WSLIFT. . LIFT.63619 UFT;6OO7 GAS LIFT 6.585.1 GA6 LIFT; 6.m A L.TOR:656ee SBE ', 6961 B PR: 6.x9.5 PACKER ',695i.5 NIPPLE:1.I5 POOR BOY G RSIpT ],15 1 FRACF O', 7154.0 IPERF.7,1M.67M n✓ RPERF.71..7: 0.0 BIASTRING6:7151.0 RIPERF: 7,.,5..03.0O PERF:73TW� (PERF:>fl6],ffi0 RF: 7.3.67ffi0� Paaoucr10x:7mI,6 L n 1 � S G �� a) Sr ✓ r3 S v 3 J�+ cusp t LOOPTOR:7315.9 PACKER;7.320.1 uM1ld� VY/ ; y MILL2w.0 L] r 1 IOV NIPPLE: 7.i N.1 SOS: ] )0.5.9 IPERF: 7.3N.6>.e05.0 RPFAF;7393,6].4050 , FMC MSANO; 7$10 IPERF. T,e M. 7.ex0 PR000CTION;]].1JLM60 KRU 1 F-07: Use Abrasive Cutting Tools to Remove Packer Pre- Workover Summary of Operations: KRU well 1 F-07 (PTD 182-156) is a well that was worked over in 2018 to set it up as a CTD sidetrack candidate by removing carbide blast rings from across the Kuparuk C -sand. That workover was unsuccessful in recovering the blast rings, so a second workover sundry (319- 250) has been approved to once again attempt to remove those blast rings. Prior to that workover, however, ConocoPhillips intends to employ a through -tubing technique that we hope will remove the lowermost production packer in well 1 F-07. If successful, it would allow the packer remnants and the blast rings above it to fall into the rathole inside the 7" casing, eliminating the need for a workover. If the technique is unsuccessful, we will proceed with the workover that was approved via sundry 319-250 to finish preparation for CTD sidetrack. Procedure Outline: Remove Existing WD Packer at 7320' MD with Through -Tubing Tools 1. Slickline: Drift/gauge run. Tag fill. 2. E -line: Tie in with GR/CCL. Set 3" CIBP at -7323` KB in the very bottom of the seals that are stung into the WD packer. 3. CTU: a. PU Halliburton jetting -style abrasion tool & Haley -style anchor. Abrasion tool should be configured to make a single horizontal cut. Tag CIBP for depth control. b. PU to remove slack plus -2'. Start circulating clean fluids to set Haley anchor and gauge returns. Start pumping 100 mesh sand as per Halliburton procedure. Objective is to cut off the end of the seal assembly and cut as much of the WD packer body as possible c. Switch to clean fluids when cut is deemed sufficient and POH d. PU Hipp Tripper and RIH. Tag CIBP. e. Start circulating and hammering on the CIBP. The idea is to see if we're able to move the cut-off section of seals down into the MOE. If seals do move, continue hammering to see if we can pull the lower mandrel enough to release the lower slips of the WD packer. 4. E -line: a. PU caliper. Tie in with GR/CCL, log from CIBP up for±100'. b. Shut down long enough to assess the caliper data. Note: Possible off -ramp if we've not had any success moving the seals or if our cut isn't where we intended. 5. CTU: a. PU Halliburton abrasion tool (no anchor). Abrasion tool should be configured to cut three holes 120° apart. Tag CIBP for depth control. Page 1 of 2 June 3, 2019 b. Start pumping 100 mesh sand while slowly POOH as per Halliburton procedure — the objective is to make 3 vertical cuts in the WD packer body. c. Switch to clean fluids when cut is deemed sufficient and POH. 6. E -line: Tie in with CCL. Set 3" CIBP at 7312' KB in the 10.11' pup that is immediately above the WD packer. 7. CTU: a. PU Hipp Tripper and RIH. Tag CIBP. b. Start circulating, see if we're able to move the blast joints by hammering on this CIBP. If we do get movement, continue hammering to see how much progress we can make. Note: If the assembly begins to move, the tubing stub & poboy overshot at 7155' will separate so that it could be difficult to get back inside the tubing stub. Therefore, if it does start to move then chase the assembly to bottom as best you're able before POOH. 8. E -line: PU caliper with extended arms for 7" casing. Tie in with GR/CCL, log from tag depth. Note: If the assembly has moved downhole, the tag depth could be the 3'/z" tubing stub that was originally at 7155', or it's possible that the caliper will enter into the stub. Page 2 of 2 June 3, 2019 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Dusty Ward Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F-07 Permit to Drill Number: 182-156 Sundry Number: 319-250 Dear Mr. Ward: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W W W.aogcc.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner Ma DATED this2 2 day of May, 2019. RBDMS±' MAY 2 31019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Type of Request Abe d ❑ MECEI ED MAY 15 2019 In on Plug Perforenona' Fracture Stimulate LJ Repair Well Ld ° Neiwn❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CTD Setup 3 . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhilli s Alaska Inc. Exploratory ❑ Development p 182-156 ddr 3. Aess: Smatigraphic ❑ Service E] 6. API Number: 1. O. Box 100360, Anchorage, Alaska 99510 50-029-20830-00 -GU 7. If perforating: U. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A lG Will planned perforations require a spacing exception? Yes ❑ No O KRU 1 F-07 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25652 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 8,060' 6,717' - 73571vrf rte ms 6128 2339psU2995psi95psi ✓ NONE NONE Casing Length Size MD ND Burst Collapse Conductor 45' 16" 80' 5,858' Surface 2,225' 103/4 2,259' 6,090' Production 8,013' 7" 8,045' 1,836' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 71847458 5984-6212 3.5 x 4. 5 L30/J- 55 7,346• Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): PACKER- PACKER, BAKER, 4782 FHL MD= 6983 ND=5818 PACKER - OTIS WD PERMANENT PACKER MD= 7320 ND= 6097 SSSV - NONE N/A 12. Attachments: Proposal Summary 0 Wellbore schematic El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Developments Service ❑ 14. Estimated Date for 6/20/2019 15. Well Status after proposed work: Commencing Operations: OIL O WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Ward Contact Name: Dusty Ward Authorized Title: Sr. Wells Engineer r fContact Email: Dusty.Ward@cop.com Authorized Signature: v✓ Date: J — 14-6101c( Contact Phone: (907) 265-6531 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 250 Plug Integrity ❑ BOP Test Lei Mechanical Integrity Test ❑ Location Clearance ❑ - Other: Q�p f�� f Z 5500 4-nrsv/ar pl-<V�nf�✓ } fa .25 r 5 Post Initial Injection MIT Req'd? Yes ❑ No RBDMS MAY 2 3 2019 Spacing Exception Required? Yes ❑ No GR/ Subsequent Form Required: 1Q — gD 4' APPROVED BY q Approved byko� COMMISSIONER THE COMMISSION Date: pofz- 5/z /// y Q CGt�yt�t o,,.. w-•ws neNsea a/zov r -,m no Approved application is valid for 12 months from the date of approval.�_/ `9 Attachm Duplicate --1c.1y 1F-07 Proposed RWO Completion 16" 65# H-40 shoe @ 80' RKB 10-3/4" 45# K-55 shoe @ 2259' RKB KOP @ -7190' MD KOP @ -7210' MD C -sand perfs 7184'- 7244' RKB B -sand 7255' - 7282' RKB 43)zrMD A -sand perfs 7393' - 7458' RKB 7" 26# K-55 shoe @ 8045' RKB PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ TBD Baker 3-1/2" PBR xxxx' RKB (3" ID) Baker FHL Packer @ xxxx' RKB (4" ID) 3-%" X landing nipple at xxxx' RKB (2.813" min ID) Tandem Wedges Perf Pup 3-1/2" Non -sealing Overshot REMAINING COMPLETION LEFT IN HOLE OTIS WD Permanend Packer @ 7312' RKB (4" ID) OTIS MOE @ 7316' RKB (4.35" ID) OTIS XNS nipple @ 7332' RKB (2.813" ID) OTIS SOS @ 7338' RKB ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 10 May, 2019 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1F-07 (PTD# 182-156). Well 1F-07 was drilled and completed in October of 1982 by Doyon 9 as a Kuparuk A/C sand producing well. The A -sand and C -sands were stimulated with acid treatment in April of 1983. In September of 1984, the A -sand was fracked and a well workover pulled the completion and then did a cement squeeze between the A and C sands. There was perforating and re -perforating throughout the 1990s and 2000s. In October 2006, a C sand patch was set at 7202.5' RKB to aid a Frac, which occurred later that year. The patch was attempted to be pulled in May 2007, in order to aid cleanout run abilities. CT got on the patch and tried to remove it, but sheared off part of the TTS pulling tool. Patch suspected to be damaged and couldn't be pulled. Well was flowing at time, so patch was determined to be left. Unable to re -latch path, so suspect fishing neck is split. Well has often passed MITs and TIFLs. There was a failed TIFL in November 2017, but replacement of the RM -OV of the GLM at 6965' RKB provided a passing test. The well became a CTD candidate and the blast rings joints from 7179' RKB to 7287' RKB need to be removed for KOP. A workover was attempted in 2018, but only got completion removed to the top of the blast rings before needing to release the rig. Another workover is to be attempted to remove the blast rings and have the well's completion swapped and set up for CTD. If you have any questions or require any further information, please contact me at 265-6531. Sincerely, Dusty Ward Senior Wells Engineer CPAI Drilling and Wells SF -07 RWO Procedure Kuparuk Producer CTD Setup PTD #182-156 Remaining Pre -Rig Work I. T-PPPOT and T -POT tests. 2. SBHP. 3. Open lowest GLM in upper completion. 4. CMIT-IA to 2500 psig. 5. Chem cut the tubing nominally at -7299' RKB in the middle of the 4' pup below the blast ring joints. 6. Install BPV and prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU on 1F-07. Pull BPV if need to circulate. 2. Record shut-in pre ssu`res on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30 -minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing, Packers, and Blast Ring Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2" tubing down to first packer (^'6970' RKB). 6. Pull first packer with 3-1/2" tubing down to non -sealing overshot (`7155'). 7. Washover tubing section blast rings to clean up. 8. Overshot tubing stub and pull blast ring section down to pre -rig cut (7299'), then pull to surface. Cleanout Run 9. Perform a Cleanout run if necessary based on tubing condition. Install in 3-%" Tubing with tandem wedge for CTD Set Up 10. MU 3 Y" completion with non -sealing overshot, tandem wedges, and packer. RIH and correlate completion so Kick Off Joints are at correct depth. 11. Once on depth, set packer and space out as needed. 12. Pressure test tubing to 3000 psi for 5 minutes. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. 16. NO BOPE. NU tree. 17. Pull BPV, freeze protect well, and set BPV if necessary. 18. RDMO. Page 1 of 1 jjjj1W KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 C.Of10Ci wen nnnoute5 Max Angle&MD TD NaSKa InC Fleltl Name We11Mre MI,T WNIb°rcslates MII'1 MDIes) AcfB n(has KUPARUK RIVER UNIT 50029208)000 PROD .8J 5,)00.00 6000.0 C°mmem H36 (ppml SSSV'. NONE 40 Oab Mnotatl°n EM OaIe KBGMIN qg gaMx Dtle 001002016 test WO'. 8/1712018 40.59 102111902 tFd ], 1WO0185:1e9aM I Last Tag Vemcal-1-s.(adki Mentation I 0RIS(11KER I En4Date I Militia. I Wt Mal as IUNCER: a a Last Tag: 7524 SLM 11IZ8I2010 1F-0] JM1ansen8 Last Rev Reason MnoWbn EMDRS WeYborc tas[Mctl BY Rev REasom Post CTD Install Ni OLD 11/282018 1F-07 JM1ansen8 Casing Strings caclna Deaaiptun ODlnl lo(to) rop lrcNel see 0epm (nKel set Oeptb flVDl... woven ll...Onee roprnreae CONDUCTOR 16 15.25 35.0 80.0 80.0 65.00 H40 WELDED mNDucrpa: a.omp Cammom aiptm ODlinl ID llnl Tap OtKB) SN OepS ItIKB) Set Ceps (1V01- WOLen 11... Ggtle Top TM1rea4 SURFACE 1014 I'D 34.2 2,258.) 2,189.0 45.50 K-55 BUIT Cmirq pvcrlptl°n O.(Inl I011nl Top IRKBI SH Daps"RM sM"i"rVO)... Wplen ll...OMe Toplhrem PRODUCTION ) 6.28 32.1 8,045.0 6.)04.5 26.00 N55 BTC Tubing Strings SURFACE: x.a2asa.7- Ti pescrigi°n sting Ma... l01in1 T°P IfIKB) fief DeptM1 le., bel Cepm /TVD L.. Wlllblll "a" TopLMnmlbn TUBING -2018 RWO 31/2 299 28.4 ),162.3 5,966.2 g.30 L -BO EUE Brtl Motl Completion Details DASUFr;2=2 lbplNominal ("a,BI IeKB)rvpl Nomi I'1 Item Oe. cum IB(inl 26,4 26.4 0.13 HANGER Tubing Hanger. FMC TCiA{NS 10.86"D.D.0013.5"CIW H-BPVG 2.992 WSUW;asaR 6,950.8 5,800.735.67LOCATOR Locator Sue, Baker ,GBH-22(bollom of bcratu.aud O03) 2.940 6,961.0 5,801.5 1 35.665BE Seal Assembly, Baker, 8040(total length, 11.761 3.000 61969.8 5,800.0 .56 PBR PBR, Baker, 8 2g Das UFT gai 6,982.5 5.818.3 35.41 PACKER Packer, Baker, 4)132 PHIL (UK shear releaki 2.940 7,066.8 5,887.4 34.70 NIPPLE Nipple. HallibuMn, 2.813'X profile. 2813 '""'(MILLED OIfT TO 2.8]') -••'•- GAS LIPT, sa 7,154.5 5.959.7 )4.19 POOR BOY Noo-uah g Over7.]50 O ERSHOT DAR usT 6Sa.t TubinY Oeacriplun fihiy M.1011nl Top TUBING-RW01984 412 299 ),1619 (after 2018 RW0) lRllBl sat pepM (R.. ],3d6.fi Sa(DepS fJV011-WIIIB4q 6.118.9 9.30 Grate J-55 Top CDnnctbn FL45 COmpletion Details tus LIFT; saoa.4 T°p (TVDt T°°md Nomiw Top("") =a) r) Item Dee Com IDlinl 7,181,0 5,981.] 34.06 BLABT RINGS BIASTRINGS I) 2,992 7,318.9 fi,096.0 34.0 LOCA OR OTIS STRAIGHT SLOT LOCATOR 3.0x) m ],)20.1 6.097.0 34.00 PACK R O IS WE PERMANENT PACKER 4.000 saER..ski� ),324.0 fi.100.2 33.99 MILL OTOS MILL OUT IXTENSION 4,35p Pak: e,959.e PAOKER:sa925 ),340.1 6, 11 3.5 33.94 NIPPLE OTI5281"XNS POLISHED BORE NIPPLEw/2.]5'NO GO 2813 7,345.9 7118.4 33.93 505 OT SHEAR OUT SUB, ELMD TTL�]333' Curing PPROFon 4470 3122/2008 ka"PLE.'assi Perforations& Slots swe Dona T.,,MS TOp�D) arm nv0l tclats/rt 1 a- (MLS) IM(BI WB) UnkM 1pie I Oah ) Type Gm 7.184.0 7,244.D 5,984.1 6,033.9 C4, 1F-0 1021/1982 120 /PERF 5"Vann Guns 7.184.0 7,244.0 5,984.1 6,033.9 Cd, 1F-07 9/1/1984 12.0 RPERF SDA; 90 deg ph POOR eov lrvEAs�s 112 7,260.0 6,04).0 .001 UNITS, IF -07 W211102 12.0 IP 5"Vann Guns 7, 7,260.6 6,043,0 6.0i UNIT B, IF -0) 11980 12.0 RPERr 5"DA; Wdeg ph 7,288.0 7,282.0 6,053.8 6,065.4 UNIT S. IF -0) 102111982 12.0 (PERF 5'Vann Guns FRACC@ NolrutlR IPERF; r1aa.0.T,2M0 7,268.0 ),262. 6,053.8 6,0654 UNIT B, iF-07 9111198/ 12.0 R ERF SDA; W degph RPERF,rIBLOcTSINO 91ASTawss2Stp RPERF,, ]y5p),2E0.0 IPERF, 12s30.),2 O IPERF: 72SA2R RPERF;raR.p7,�.pL 7,393.0 ],005.0 6.15).5 5167.4 A4, 1F-07 10211982 12. IPERF 9 vannguns 7,393.0 J, 5.0 6,15).5 6,16].4 A4, IF -07 101101200fi TO RPERF Zip HSO HJ RDX, 60 deg. ph 7,420.0 7.d4fi.0 6.1]9.9 a,201.6A4, 11-07 1021/1982 12.0 IPERF 5"Vann guns ]456.0 6.207.5 Bat USA4, 1F -0J 102111902 1201PERF 15' Vann guns 7e u Sun Frac Summary PRODUCTION; 7301a -um P..I Deslan^tl 1161 ProwassunF°rmalbn(WI 9/212000 LOCATOR; rates Slap Sbrt Oeh icp Ceps MS, Ban M, co.okiluMSYslem VW CIwn(bbD VOI3lurryrybp 1 9123rz0o0 ),104.0 7,244.0 frecop.7=1 Sbrt Dale limppnt Desipntl(IC) Pr°ppanl In Formalbn l0) N27/2006 1r024n StpY stat Dak T°pbiMKBI BCn MKS) LiNbFIUMSYskm Vale Vq Slunylbb6 1 10/27IM06 7.393.0 7458.0 Mandrel Inserts 31 °tl NIPPLE; 734co1 SDS:r 92 T°PnVD) Wh'e lake ORun N To°(nKBI ( gig527 Make MO O11112 Sery Type W.6Run Dat.6122 4)(,-) 252).1 SLB MMG 1 tl2 GAS LIT GLV RK 265.0 13002018 4,336.5 3.]93.6 SLBMMG 112 GAS LIFT GLV RK 251.0111302018 3 5.261.8 4.526.0 SLB MMG 112 GASLFT GLV RK '2.0 111292010 4 6.6).) 5, 15.1 SLB MMG 12 LIFT GLV RK . 08 1,235.0 11292018 RPERF; r]&a.0.].4Mp IPmF:rA3.0.>.ap6a 5 .596.1 1.5 SLB MMG 112 GAS T GLV RK 0.188 1,22]A 12002018 FgAc asax0: Z3T.p IPERF;'ked NSO 6 6,904.6 SJ55.0 SLB MMG 1112 GAS LIFT OV WK- 0.188 D.0 11282018 IPERF 7AGi.74S0 ],301.6 6,081.6 OTOS OVALD t PR00 OMY BK 0000 0.0 926121106 Notes: Ita Safety E' Dah Mwblion 9/1011984 NOTE WO "heakTIDN:8 llaul KUP PROD WELLNAME V-07 WELLBORE 1F-07 tonocc Phillips Alaska, Inc. 1F471MOO186:14UM Notes: General&Safety venrxsN.mak lxwll EM Ozh Mnolatan NOTE: Vew Sch... U. wl Alaska SNemalic9.0 NViAER: M49/10/2010 CONDUCTOR, MO ,o SURFACE: H33.2d.7� G48 LIFT; Z, .- GAS uFT. a,3E5 crs un', s.M� 6 W6 LIFT 6 W].] G96 LIFi:6$6.1 GGS LIFT; 8.90f.0 LC(ATO R; fi.BO].B 86E ',6,961.6 PBfl; 8Sfi8.8 PACKEfl: 8,6925 NIPPLE', TM.B MOR BOY OY SHOP. ].1N.6 FRAC F6ANO: 11.0 MRF. 7j& ?..2MA RPERF; 7,IM.07,,N O a.. .1..: 7,W.0 , RPERF; 7,84.1.]60.0 IPERF, 7,8B 7,M o IFERF', 1,M8.].M20 Rp.,, ],M8.7. PROD .., ].3018 LOOATOR', 7..31" .KM 7,310,1 MILL', ]]MO NIPPLE', 73tl1 606', 73. .9 RPERF; 7,H3.0.7.ROfi.B 'PERF : 7`0—,,Yfi0 F-0.6AN0; 2393.0 IPERF;, _-7616.0 IPERF', 7,W.0.)L8.0 PROOUCTION,6 14A 0� 77' -7 13 5/8" 5000# WP HYDRIC, TYPE "GK" 13 5/8" 5000' WP LATCHED TOP BY 13 5/8" FLANGED BOTTOM ANNULAR BOP 54 1/2" LENGTH 13-5/8" 50001 FLANGED HYDRIC DOUBLE GATE PREVENTOF 58 1/8" LENGTH 3" 50001 HCR VALVE 2° KILL LINE 900{L GATE VALVE - HYDRIL 13-5 8" 5k PSI HYDRAULIC RAr /SNGLE GAT! FLANGED CONNECTION 36 LENGTH Loepp, Victoria T (CED) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Tuesday, May 21, 2019 12:01 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1 F-07(PTD 182-156, Sundry 319-250) WO for CTD set up Attachments: BOP Schematic -Nabors 7ES.png Victoria, Thanks for your reply. The MPSP is 2339 psig. - The MPSP is derived from a BHP of 2995 psig at 6163' TVD at 0.1 psig/ft tvd gas column (1/20/2019); apologies for the confusion. Does that clarify things? That's why I was planning on 2500 psig for MPSP, sound appropriate to you? The work will be performed on Nabors 7ES. Attached is the BOP schematic. Please let me know if you need anything else. Thanks! Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, May 21, 2019 8:45 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]KRU 1F-07(PTD 182-156, Sundry 319-250) WO for CTD set up Dusty, Two MPSPs are listed: 2339 psi and 2995 psi. Please explain the difference. Would like to see a 3000 psi or 3500 psi BOP test pressure. What rig will perform this work over? Please provide BOP stack schematic and ram size/configuration. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 V icto ria. LoeppCcD a laska. oov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). If may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it fo you, contact Victoria Loepp at (907)793-1247 or Victoric.Loeoo@alaska aov 1,000,000 t 100,000 c O CL LL 10,000 V O a+ v C m _ c7 O o 1,000 v l7 v LL L u O Z 7 u 100 C C m 0 O L F 10 1 Jan -1980 CONOCOPHILLIPS ALASKA, INC., KUPARUK RIV UNIT 1F-07 (182-156) KUPARUK RIVER, KUPARUK RIV OIL Monthly Production Rates 1,000,000 O 1,000 m O 100 d m 13 m Z 0 10 3 s 1 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 Produced Gas (MCFM) GOR Produced Water (BOPM) Produced 0.1 (BOPM) SPREADSH EET_1821560_KRU_1F-07_Pr0d-1 nject_Curves_W ell_Oil_V120_20190516.xlsx 5/16/2019 Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: Y AOGCC \ ATTN: Natural Resources Technician II e Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 ---y Anchorage, AK 99501 .. 1 TRANSMIITAl DATE b TRANSMITTAL N19Febi 03 WELL NAME 1R-26 3M-26 1R•01B 1R-04 API N 50.029.22193-00 50-029-22431-00 50.029-21404.02 50-029-21407-00 ORDERSERVICE DWUJ-00077 DWUJ-00078 DWUJ-00079 6WUJ-00080 FIELD DESCRIPTION KARUK R UPIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL DELIVERABLE r • EMIT Caliper EMIT EMIT r, FINALFIELD FINAL FIELD FINAL FIELD FINAL FIELD r, • r Prints 2 -Feb -19 4 -Feb -19 5 -Feb -19 6 -Feb -19 r 1 1 1 1 1F-07 50-029.20830.00 E9KH-00003 KUPARUK RIVER WL PPROF FINAL FIELD 9 -Feb -19 1 1B -15A 1R-17 50.029-22465-01 50-029-22212.00 EA77-00001 EA77.00006 KUPARUK RIVER KUPARUK RIVER WL WL PPROF IPROF FINAL FIELD FINAL FIELD 12 -Feb -19 13 -Feb -19 1 1 7 ------'--"" j ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X ` package have been verified to match the media noted above. am Signature Date specific content of the CDs and/or hardcopy prints may or may not have been.verified for correctness or quality level at this return via courier or sign/scan and email a col o Schlumberger and CPAI. point. 'TSPrmtCenter(2slb com Tom.OsterkamoC)conocoohillios com SLB Auditor J lA Sch I u m be rge r -Private WELL LOG TRANSMITTAL PROACTIVE DIAgNOSTIC SERVICES, INC. To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 ndsanchoraae@memorvloa com 21 -Jan -19 1F-07 CD RECEIVE® FEB 0 1 2019 AOGCC 50-029-20830-00 Date : OdO ZO PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEGDMEMORYLOG COM WEBSITE: WNNV.MEMORYLOG.COM 182156 30319 D'.Nchives'ale,iaa mploteFllaaAT:mplaksVDishiDutioa Gansm,ttalSheetsVCo..c Plo ,, 'fmn,wiLd... L 0, ifilo 18156 30319 Memory Multi -Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1F-07 Log Date: January 21, 2019 Field: Kuparuk Log No.: 14366 State: Alaska Run No.: 2 API No. 50-029-20830-00 Pipe Description: 3.5 inch 9.3 Ib. L-80 ELIE 8rd Mod Top Log Interval: Surface Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of the XNS Nipple at 7,340.1 feet (Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate significant wall penetration in blast joint 222 at 7,197 feet. Nominal ID/OD is assumed with the calculation of the wall penetration because of the ID/OD for the blast joints are not listed in the tubing tally, resulting in 100% wall penetration. Apparent mechanical damage are recorded from 7,179 feet to 7,181 feet, with a 25% cross-sectional wall loss recorded in the same area at 7,180 feet. A 3-D log plot of the caliper recordings across the interval from 7,120 feet to the end of the log is included in this report. No significant I.D. restrictions are recorded throughout the tubing logged. This is the second time a PDS caliper has been run in this well and the first time the 3.5 inch tubing has been logged since RWO in 2018. MAXIMUM RECORDED WALL PENETRATIONS: Hole in Blast Joint Apparent Mechanical Damage 100 222 7,197 Ft. (MD) 67 221.4 7,180 Ft. (MD) No other significant wall penetrations (> 17%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Apparent Mechanical Damage 25 221.4 7,180 Ft. (MD) No other significant areas of cross-sectional wall loss (> 10%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. C. Goerdt HY. Yang E. Zemba ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (231) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAna ysiS@)Memorvlog com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (14.5' - 7,342.9') Well: 1 F-07 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: January 21, 2019 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 15 25 780 50 � 1,559 75 2,342 GLM 1 Z 100 c 0 3,148 150 175 200 W E 125 3,925 �- c GLM 2 s a D 4,732 GLM 3 5,538 GLM 4 6,350 GLM 5 GLM 6 GLM 7 7,268 226.3 7,341 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 226.3 � Z c 0 150 175 200 J 4's PDS Report Overview Body Region Analysis Well: 1 F-07 Survey Date: January 21, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 Analyst: HY, Yang Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 f L-80 2.992 in. 15 ft. 7 343 ft. Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Number of laints damaged (total = 3) 0 1 1 0 1 Damage Profile (%wall) Penetration body Metal loss body 0 50 100 GLM 1 (5:30) GLM 2 (9:00) GLM 3 (12:00) GLM 4 (12:00) GLM 5 (12:00) GLM 6 (9:30) GLM 7 (2:30) Bottom of Survey = 226.3 PDS Report Joint Tabulation Sheet ii S- Wel: 1 F-07 Survey Date: January 21, 2019 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 15 ft. 7,343 ft. Joint No. It. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Min. Damage Profile Loss I.D. Comments (% wall) % (in.) 0 50 100 5 0 002 7 1 2.96 1.1 46 0 0.03 13 1 2.96 P 1.2 56 0 0.02 8 1 2.94 Pu 2 64 0 0. 2 7 1 2.96 95 0 0.02 7 1 2.96 4 127 0 0.02 6 1 2.95 5 158 0 0.01 5 1 .95 189 0 .01 7 220 0 0.02 7 1 2.95 250 0 0.02 1 6 9 282 0 0.02 7 1 2.96 10 313 0 0.02 7 1 2.96 11 344 0 0.02 7 1299 12 376 0 0.02 6 1 2.96 13 407 0.02 7 6 1 438 0 0.02 7 1 2.96 1 15 469 0 0.02 7 1 2.96 1 500 0.02 8 1 17 0 2 7 2.9 18 561 0 0.02 7 1 2.95 1 593 0 .02 6 1 2 .96 20 0 7 1 2.95 21 65610(0)00000 02 8 1 2.93 22 687 2 7 1 2.97 23 7 2.95 24 750 02 6 1 2.94 25 780 02 8 1 2.96 26 810 02 6 1 2.96 27 84202 7 5 28 74 7 29 905 02 7 1 2.96 0 937 02 7 1 1 235 31 968 02 7 1 2.96 32 100002 6 1 2.96 33 103702 6 1 .94 34 706302 8 2.96 35 109402 8 1 2.96 36 11232 7 1 2.95 7 115401 5 1 2A3 38 1186 2.97 39 1217 0 .94 4 1248 0 299 41 1280 0 2.95 4 1311 2.96 43 1342 0.04 2.96 44 0 2.96 45 40 2.96 46 1436 0 2.94 47 6 02 .94 48 14913 1 0 1 0.02 1 6 1 1 2.95 Penetration Body Metal Loss Body Page 1 ji-�s PDS Report Joint Tabulation Sheet Well: 1F-07 Survey Date: January 21, 2019 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 15 ft. 7,343 ft. Joint No. JL Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Min. Damage Profile Loss I.D. Comments (% wall) % (in.) 0 50 100 49 1529 0 0.027 1 2.95 50 1559 0 0.02 6 1 51 1590 0 0.02 7 1 2.96 2 1621 0 0.02 8 1 2.95 53 1652 0 0.01 5 1 2.96 54 1683 0 0.02 7 1 2.96 55 1714 0 0.02 6 1 29 56 1746 1 0 0.03 10 1 2.95 57 1777 0 0.02 7 1 2.96 58 1809 0 0.02 7 1 295 59 1840 0 0.02 7 1 2.96 60 72 0 0.02 8 1 2.95 61 1903 0 0.03 12 1 2.95 62 1934 0 0.02 6 1 2.95 63 1966 0 0.02 7 1 2.96 64 1997 0 0.02 6 1 2.94 65 2028 0 0.01 5 1 2.96 66 20 8 0 0.02 7 1 2.96 67 2089 .02 7 1 2.94 68 2120 0 0.02 7 1 2.96 69 2152 0.02 6 1 .96 70 2183 0 9 1 .95 71 2215 0 0.01 5 1 2.94 72 224 0.02 8 2.95 73 2278 0 6 1 4 74 2309 0 0.02 7 1 2.95 75 2342 0 0.02 6 1 2.95 76 2373 0 0.02 8 1 2.95 77 2405 0 0.02 6 1 2.96 78 2436 0 0.02 8 1 2.94 79 2466 0 1 0.03 10 1 2.95 80 2497 0 0.02 7 1 2.94 81 2528 0 0.01 5 1 2.94 82 1 2559 0 0.02 6 1 2.93 3 2591 0 0.03 11 1 2.95 84 2622 0 0.01 4 1 2.93 84.1 2654 0 0.03 12 2 2.96 Pu 84.2 2663 0 0 0 0 2.90 GLM 1 fLATCH @ :3 84.3 2672 0 0.03 11 2 2.98 Pu 85 2682 0 0.02 6 1 2.97 86 2714 0 0.02 6 1 2.97 87 2745 0 0.02 7 1 2.97 88 2776 0 0.03 1 10 1 1 2.94 0 0.02 7 1 1 1 294 1 0 0.02 7 2 2.95 6 1 7 P932932 0 1 1 0 0 0.02 8 Penetration Body Metal Loss Body Page 2 ji-�s PDS Report Joint Tabulation Sheet Well: 1 F-07 Survey Date: January 21, 2019 Field: Kuparuk Analyst: HY. Yang Company: ConocoPhillips Alaska, Inc. Pipe Descrip Don 3.5 in. 9.3 ppf L-80 Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 15 ft. 7,343 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. Damage Profile I.D. Comments (% wall) (in.) 0 50 100 96 3024 0 0.02 8 1 2.95 7 3055 0 0.03 10 1 2.96 98 3086 0 0.01 4 1 2.97 9 311 7 0 0.02 6 1 2.96 100 3148 0 0.03 11 i 2.95 101 3180 1 0 0.02 6 J 1 2.96 102 3211 0 0.01 5 1 1 2.96 103 3240 0 0.02 6 1 1 2.97 104 3271 0 0.01 5 1 1 2.97 105 3302 0 0.01 4 1 2.96 106 3333 0 0.02 7 1 2.95 107 3365 0 0.01 5 1 2.96 108 3396 0 0.02 6 1 2,95 109 3427 0 0.02 7 1 2.96 110 3459 1 0 0.02 6 1 1 2.95 111 3490 0 0.02 6 1 2.94 112 3522 0 1 0.02 7 1 2.95 113 3551 0 0.02 9 1 1 2.95 114 3589 0 0.02 7 1 2.96 115 3620 0 0.01 5 1 2.96 116 3652 0 0.01 4 1 2.96 117 3682 0 0.03 10 1 2.97 118 3714 0 0.02 6 1 2.97 119 3745 0 0.02 6 1 2.96 0 3775 0 0.01 5 1 2.97 121 3806 0 0.02 6 1 2.97 122 3834 0 0.02 7 1 2.96 123 3862 0 0.02 6 1 2.94 124 3893 0 1 5 1 2.95 125 3925 0 0.02 7 2.93 126 3957 0 0.01 4 1 2.97 127 3987 0 0. 6 1 2.95 128 4018 0 0.02 7 1 2.96 129 4048 0 0.01 5 2 2.95 130 4079 0 . 2 6 1 2.95 131 4110 0 0.01 5 2.96 132 4140 0 0.02 6 1 2.94 133 4172 0 1 0.01 4 1 2.95 134 4203 0 0.01 5 1 2.96 135 4235 0 0.01 5 1 2.96 136 4266 0 0.01 5 1 2.95 137 4298 0 0.02 6 1 2.95 137.1 4330 0 0.03 11 2 2.99 Pu 137.2 4339 0 0 0 0 2.91 GI -M 2 LATCH @ 9:0 137.3 4348 0 0.03 12 2 2.98 Pu 1 0 0.01 5 1 2.95 139 4389 -0 00 7 1 194 140 44200 0.02 6 1 2.95 1 0 0.01 5 1 2.96 142 A4133 0 1 0.02 7 1 296 Penetration Body Metal Loss Body Page 3 ii S- Well: Field: Company: 1 F-07 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: January 21, 2019 Analyst: HY. Yang Pipe Description 3.5 in. 9.3 ppf L-80 Tubing Nom. ID 2.992 in. Body Wall Top Depth Bottom Depth 0.254 in. 15 ft. 7,343 ft. Joint Jt. Depth Pen. No. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 143 4 0 .02 6 2-94. 1 4545 0 2 6 1 2.9 145 4576 0 0.03 11 t 2.96 14 4608 0 0.02 6 i 2.9 147 46 9 0 6 1 .96 148 4670 0 0.01 5 1 2.93 14 4700 0 .02 6 1 2.9 150 47 0 5 1 2.95 151 4763 0 0.02 6 1 2.96 152M4980n . 6 1 .96 15302 6 1 2.96 1541 5 1 2.95 55.01 5 i 94 156 01 5 1 2.93 15701 5 1 .95 158 01 5 2. 6 159 02 7 1 2.96 00 6 b 1 5074 0 0.01 4 299 162 51050 0.02 6 2 2.95 136 0 0.02 6 1 2,95 164 5167 0 .02 1 2. 165 5196 0 0.02 6 1 2.96 1 2 0 0.02 1 2 166.1 5260 0 3 2 2.97 P --- u 166.2 166.2 5270 0 0 0 0 2.93 GLM 3 LATCH 72:00 166. 5278 0 .03 1 2 2. Pu 167 5289 0 0.02 6 1 2.93 8 5 1 0 0.02 6 1 .94 1 5349 0 0.02 1 2. 6 170 5381 0 0.01 5 1 2.96 7 541 0 0.01 5 172 5444 0 0.02 2.9 173 5475 0 0.02 7 1 2.95 550 0 0.02 7 5 175 5535 0 .01 5 1 2.9 176 5569 0 0.01 5 2 2.95 7 559 0 0.01 5 2.95 178 5630 0 0.01 2. 179 5661 0 0.01 5 1 2.95 5 0 0.02 6 1 .95 181 1 5729 1 0 0.02 2. 5 182 1 5758 1 0 0.02 7 1 2.96 18 5790 0 0. i 2 .96 184 5821 0 0.02 7 1 2.95 185 5852 0 2 7 1 2.9 7 6 502 Q 0.02 6 1 2.94 787 5912 0 0.02 7 1 2.95 188 943 0 Q02 7 1 2.9 189 740 Q,02 6 1 2.95 Penetration Body Metal Loss Body Page 4 *-4s Well: 1 F-07 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: January 21, 2019 Analyst: HY. Yang Pipe Description 3.5 in. 9.3 ppf L-80 Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 15 ft. 7,343 ft. Joint Jt. Depth No. (Ft) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss °% Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 190 6006 0 R02 6 1.96 191 038 0.02 7 1 6 191.1 6070 0.04 0.03 13 2 2.97 Pu 191.2 6081 0 0 0 0 2.92 G LLA 4 (LATCH@ 12: 91.3 6090 0 0.03 13 1 2 97 Pu 192 6101 0 0.02 6 1 2.96 193 6132 0.02 6 6 94 3 0 0.02 6 1 296 1 195 6194 0 0.02 6 2 2.94 96 6225 0 0.02 7 1 2.9 197 1 6256 0 1 0.02 6 1 2.96 198 870.02 8 1 2. 199 631 0 0.03 11 1 2.96 200 6350 0 0.02 9 1 2.94 01 6 0 .02 1 2.9 202 6413 0 002 6 i 2.93 203 6444 0 0.02 7 1 2.94 4 6475 00.01 1 2.9 20 6506 0 9 1 1 2.95 206 6537 0 0.02 9 1 2.95 207 6568 0 1 0 OZ2_ 1 2.95 207.1 6600 0 1 0.03 96 P 207.2 6609 0 0 0 0 2.89 GLM 5 LATCH @ 12:00 207.3 6619 1 0.04 3 13 1 2.94 208 1 6630 0 0.02 8 2 5 2096660 0 0.02 7 1 2.93 210 6691 0 0.Q2 6 1 2.94 211 6720 0 0.02 6 1 2.94 6 751 0 0.02 1 2.9 213 1 6782 1 0 7 1 .96 2142.56813 0 0.02 7 1 2.95 6844 0 1 0.02 1 2.94 216 1 6875 1 0 1 0.02 6 1 .95 216.1 6908 1 0 1 0.03 11 2 2.95 Pu 216,2 6917 110 0 ) 0 2.91 GLM 6 ATCH :30 216.3 1 6926 1 0 1 0 M 13 1 2 1 2.96 217 6938 0 0.02 8 1 2.95 7 6971 1 2 2.93 Pu 217.2 1 6977 1 0 I n0 0 2.98 BAKER -22 ATOR B 217.3 6979 0 0 0 1 0 1 2.97 BAKER 80-40 SEAL ASSEMBLY 217.4 6990 0 2. BAKE 0-40 P 7.5 1 6995 0 0 0 0 2.91 RAkFR A7R2 FH 0K SHFAR REF SPA(-I<Fl 217.6 7002 0 0.02 9 0 2.95 Pu 7 00.02 6 1 2. 219 7037 0 0.02 8 1 2.95 219.1 1 7068 0 0.0 10 5 P 0 0 0 0 HA URT NTT 219.3 7079 0 0.02 9 2 2.97 Pu 220 89 8 1 .94 1 80 0.04 17 3 95 A r nt S w Me apical ma e. Penetration Body Metal Loss Body Page 5 ii S, Well: Field: Company: 1F-07 Kuparuk ConocoPhilips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: January 21, 2019 Analyst: HY. Yang PipeDescripfion 3.5 in. 9.3 ppf L-80 Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 15 ft. Bottom Depth 7,343 ft. Joint Jt. Depth Pen. No. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 221.1 7147 0 0.03 11 Pu 21.2 7158 004 0.02 8 1 2.96 PUD 221.3 7165 0 1 0 0 0 2.97 NON -SEALING OVERSHOT 221.4 66 0.17 C7 2.9 1 Pu Aimment Mechanical Damage. 22 7184 0 0. 0 1 0 10 2.97 1 HAW in BI st I,i,t 223 7215 0 0.02 7 2 2.94 Blast oint 7 0 0.02 3 2.96 st oin 7268 0 7 2 .93 Mao oint 7297 g225.3 0 0.02 7 1 2.95 Pu 7301 0 0 0 0 .90 G 7 LA @ 2:30 7307 0 0.02 8 1 2.95 Pu 7315 0 0 0 0 2.98 CRISS -O 2 5 7316 0 0 0 .96 OT TRAIT T LO TOR 225.6 7318 0 0 0 0 2.97 OTIS WD ..... ENF PACKER 225.7 7321 0 0 0 0 .99 C SS -OV 225.8 7322 0 0 0 I 0 OTIQ KAIIL OI IT CVT.11� 225.9 7330 0 0 0 0 2.99 CROSS-OVER 7331 0 0. 6 1 6 Pu 226. 340 0 0 2.7 OTIS 81"XN LISHE ORE N W 2. 226.3 7341 0 1 0.01 1 2 1 0 1 2.96 1 PUP Penetration Body Metal Loss Body Page 6 (k;�s Well: Field: Company: Country: 11rIn Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 in. 9.3 ppf L80 PDS Report Cross Sections Survey Date: January 21, 2019 Tool Type: UW MFC 24 No. 218527 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 222 at depth 7,197.020 ft. Tool speed = 57 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 90% Tool deviation = 27° Finger = 19 Penetration = 0.300 in. ii4�s Well: 1F-07 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 3.5 in. 9.3 ppf LSO PDS Report Cross Sections Survey Date: January 21, 2019 Tool Type: UW MFC 24 No. 218527 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 221.4 at depth 7,180.410 ft. Tool speed = 53 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 76% Tool deviation = 27° Finger = 9 Penetration = 0.170 in. Apparent Mechanical Damage 0.17 in. = 67% Wall Penetration HIGH SIDE = UP PDS Report Cross Sections Well: 1 F-07 Survey Date: January 21, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Cross Section for Joint 221.4 at depth 7,180.350 ft. Tool speed = 53 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area= 75% Tool deviation = 27° Finger = 7 Penetration = 0.164 in. Apparent Mechanical Damage 25% Cross -Sectional Wall Loss HIGH SIDE= UP KUP PROD WELLNAME 1F-07 WELLBORE 1F-07 LOnoeoPhinips even Aur(pmes Max Angle &MD jTb Am3l,i I1, Me N"'. WNlbon"WWI WNMorassetua nal l°I Mo1RKB) >al BfmlRl(BI KUPpRUK RIVER❑NIT 500292D6i000 Pg00 83 5j03.D0 60600 Comment HYS IppM SSSV:NONE 40 Dna Lee, Bna Bah KBira llq Pog RMa-DW 9/102016 Lest WO: 0/1]2018 40.59 10/21H982 1F07,12ilMI851451 M1 Last Tag Is", los'-shic tocol) Annotation 1111(BI bMDW WYlhere LBat Mea ..... .... Iwi�E9.ze4""- Ian Tag: 75M SW 11282018 "-07 hansen8 Last Net, Reason ....San bnaDffi Wreaker, Lart Mpa Ras REaS., Post CTD lnsfall New GLO 1128/2010 iF-D7 Jhansene Casing Strings Casing assort tion 00 IIn1 10A rola lnlcel sN Baphe gMe) sRDW ITI'CL-W'kL,n p.. w.ae Top Tlrma CONDUCTOR 10 15.25 35.0 800 80.0 8500 H40 WELDED co6DucroR;uosO.o CUA-Bmaaptlm OB IS,SA IB lint TeplMal SnOgMIRXBi Sel Dept." u.'...fMBLen Vi..Waae Top Tkrana SURFACE 103/4 9.95 342 2,258,7 2, Imo 45,50 K-55 BUTT Cning Bmcaptlan OD pal I911n1 Tap IRRBI SN BepM 1., Sar Ogtk(rwM.P ll.. DrWe IT.,n,. PRODUCTION ] 628 32.1 8,0450 8,70¢.5 2600 KSS BTC Tubing SMngs -" o 9UPFM'£, 3a a'.259T- €- Tubing 0ascription eking Me... ID lint Top IRKS) So Depin lR. sn Oapm (fwl k.. Wl "'a Oreo, Tap C -.01- .01 n TUBING 2018 RW0 31/2 299 284 7,162.3 5,986.2 930 6 BO EUE Brtl Marl COrnplegan Details GPS UR.]ID22 Tapnw) Tap Fol Top uIK6 IRI(B Nominal (°) Ihm pea Cam IB lana 284 284 013 HANGER Turing Hanger, FMC TCIA-ENS 1080' 0.0. WA,a-GIW H-BPVG 2992 GPS UFT.4a3as 8,9608 5,800.] 75.87 LOCATOR Locator Sub,Baker, GBH -22 (bdbm Di locator spaced out 3) 2.940 8,9018 5,801.5 35.86 SBE Seal Meambly, Baker, 80AG(total length s11.76) 3.0M 6,969.8 5,8080 35.56 PSR PBR, Bakar."40 290 Gres uFT, s2eta 8,982.5 5,8183 35.41 PACKER Prend, Baker, 4782 PHL(WK sheer release) 2.940 7.066.8 5,8874 34.]0 NIPPLE Nipple fthbur1og281TXprollle, 2913 (MILLED OUTTO 2.87')"'°"" 1w UFT, esdir 7,1545 5859.7 3449 POOR BOY Non-seal'mgovebbcd 3750 OVERSHOT oAs uFT.5.5s3.1 Turner, Beaarrtem par LIgoo , ad Pia Top TUBING RW019U 412 2.99 7,161.9 (alter 2018 RWO) (me, I S%Derr pr ],346.6 SM DepIb MB10 61189 Wt(aurta 8.30 Oraae Y% Tep eonnectlon FL4S Completion Details Ons uFT.6.un.a ToprtwI Thp FaI Nomxel Top ea (RKe I'a Rem Bm Cam IB lana 71181.0 519817 3408 BL45T RINGS BLAST RINGS (4j 2992 7,318.9 6,0913.0 34.00 LOCATOR OTIS STRAI OHT BLOT LOCATOR 30W L 0 uTOR.t aRo9 7,3201 BOOTS 34.00 PACKER OTIS WD PERMANENT PACKER 4000 seE laBFta 7,324.0 6,103.2 3398 MILL OTIS MILL OUT EXTENSION 4350 PeR, a.gmg PncxER; e,aee5 7,3401 6,1135 33.94 NIPPLE OTIS 281° XNS ROUGHED BORE NIPPLEw/276NOGO 2813 7,3459 6,1184 33.93 BOB OTI2S SHEAR OUT SUB. ELMduring PPROF on 4470 DTTLID]0 2 008 rv.PRE;;0aa8 Perforations IS Slots Shot Bm TOP IRRB Bml T°p ITwl Skn(Tw' (In. IRI( IRK,) al Lt. San. Dale I a corn 7,184.0 7,244.0 5,984.18,am CA, 1F,07 1021/1982 12.01PERF 5' Vann Guns 7,1840 ].244.0 5,984.1 aOna CA, 1F-07 Si 12.0 RPERF 5- DA; 90 Reg ph Poon Dor Ov6asHOL I,aas ],255.0 ],2600 , 3.0 8,0422 UNIT B. IF -07 121/1982 f2O IPERF 5 -Vann Guns 7,255.0 7,2600 6, 043.0 8,047.2 UNITS IF -07 07 9/1/1984 12.0 RPERF 5 -DA; 90 deg ph 7,2680 7282.0 6,053.8 6065A UNIT B, IF -07 102111982 12.0 (PERE 5' Vann Guns Fpuc osw+D. U¢ng IPERF, r,,8n 6] 2x4 0 ],268.0 7,282,1) 6,0538 6,065.4 UNIT B, 1F07 9/111984 12.0 RPERF 5' DA, 90 de b 9 P RPERF, 7151 6) 2440 BLASTRINGSip81.0 1 ],3930 7-0.50 6,1575 6,167A A 4, 1F-07 1021/1982 12.01PERF 5 -Van. guns RPERF.12556T,]W 0 PERF, T M1.14gma PERP. 7.2 2W 0-T 2rI2$2 a RPERFI #aeDR5Y0� 73930 74050 6,1575 6,16IA A-, 41F-0> 10I1012008 6.0 RPERF 12.5- HI HJ RDX, 50 deg, ph 7,4200 7,446.0 6,178.8 6,201.8 A-9.iF-07 1021/1882 120 (PERF 5'Venn gum ],453.0 7,458.0 8,207.5 8,211.8 A-4, 1F-07 1021/1982 12,0 IPERF 5°Venn guns Frac Summary pROBUCTKH. 130,8 92/32000 FrapPWDWIgma lab) Fmppanl In Famnllop llrl L0.ln', r,51e.9 Slga SF,R Bab Top oRtk lRl(BI SW 111X81 LMN Ia But Syalrn VOI Clean lbbe Vol Elurrylbrl) 1 9232000 7,1840 ],2¢40 .:n",],3A.1 1Sued>rz PmPpant omlgnaa(bl paapPanlln Finard.rbl m1u.1?240 5di Stenon. Tap Dephe heard ardent inap, ILI flea )/atm VOlcrmn(bbi VPISIu 1 102]2006 ],393.0 7,458.0 1 ny(ebO Mandrel Inserts Sl m Ni,tas 13+01 H Tap (TPI Vass Lmtelak pSU TRO Rnn Top(RKB (RKB) Make MI OBpna a. Type TSp. pre (psi) Ron am$ Com 2,672.2 2.527.1 SLB 1,11,40 112 GAB UFT GLV RK 0,188 1,285.0 11/3021118 2 4,336.5 3793.13 SLB MMG 112 GAS LIFT GLV RK 0,188 1,251,0 111302018 3 5,281.8 4,5288 SLB MMG 112 GAS IJFT GLV RK 0.188 1,2420 11292018 4 6,0377 5,115,1 SLB 0--G112 GAS LIFT GLV RK 0.188 1,2350 11/292010 RPERF 7,3a3M174fRA REDF,73aa x14[50 5 6596.1 5,5115 SLB MMG 11/2 GAB UFT GLV RK 0.188 1,227.0 1129,'2018 Fels h2ANC, 73030 GERF,i1}n p].iv60 6 6,904.4 5,755.0 SLB WAG 112 GASUFT OV RK 0.188 0.0 1128/2018 1FERF. 7.153114ce o 7 7,301,6 BOSIS OTIS OVALO 1 PROD DMV BK OOW 00 926,2006 Notes: General & Safety Enda.. Nm..... 9/10119" NOTE WO PRVDUCTION, 521-80450� KUP PROD WELLNAME 1F-07 WELLBORE 1F_07 ConocoPhillips .A,;k., ui 6- 1 1 F711 I1b72 s Notes: General & Safety VerXro sL!IemeCa lttyel) EnE Oah Mn,4t— ..,,, 8902010 NOTE'. Vbw SO—alicw/Alaska Sch—flc0.0 IWJGEk:231 LONDUCiOR, 356800 SVRFALE', 30.2�3350i� 6Ai LIFT', 26722 GA�LIFi,+:3a5 GAS LIFi:5,38f B OAS LIFT:6,e6] i 6M' LIFT:09981 OAS LIFT 6,504 LO Gi0R,89608 SBE 6AE1.6 PBR, 6,BE98 PACKER, 8,5E35 NIPPLE, );0586 POOR 90V OVERENOT 1,WS FRAC CSNJD, l,16<0 PERF', I,1&6 ]M0 RBLRTP1N, N<0 BLPSi RINGS; 1,181-0 RPMF: i 211 ",3.0 N ERF: i 2S. p7,2W.0 VERF,)2W 0.]3630 RPERF]2666T 1120 PROMCfpN, 7.6GI8 LOCAic R1311-0— PACMEIR 1120.1 .ILL', 13A0.0 NwPLE]d+01 LOS.F n RPEAF, 1.653.0-)105 0 IPERF,i393 CLTA 0 FR p D. 7,3534 PERF,?+2a o-7.16 )PERF: r,assnv,l W PROD VRION 1321a,01S0 � Py OFTJ{�, • , ,,��y7,, s THE STIR Alaska Oil and Oas p Conservati®n C®mmissi n 5 - ALAsKA. 333 West Seventh Ave ue k GOVERNOR BILL WALKER Anchorage, Alaska 99501- 572 tip `rh Main: 907.279.1433 piw ALAS" Fax: 907.276. 1542 www.aogcc.alaska.gov Dusty Ward sCANNIT JUN 2 1 met Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F-07 Permit to Drill Number: 182-156 Sundry Number: 318-247 Dear Mr. Ward: 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 le) day of June, 2018. ReDM JUN 2 0 2018 • • LEI STATE OF ALASKA JUN 1 €118 ALASKA OIL AND GAS CONSERVATION COMMISSION O 0 -S G f' N j /e APPLICATION FOR SUNDRY APPROVALS AG 20 AAC 25.280 1.Type of Request Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 • Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 ' Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other: New Rig on Kuparuk Fi@Id0 ✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development 0 • 182-156 ' 3.Address. Stratigraphic ❑ Service 0 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-20830-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1F-07 • Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25652 • 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): 8,060' ' 6,717' • 7357 6128 2069psi None 7585 Casing Length Size MD TVD Burst Collaps@ Conductor 45' 16" 80' 80' Surface 2,225' 103/4 2,259' 2,189' Production 8,013' 7" 8,045' 6,704' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7184-7458 MD 5984-6212 TVD 3.500" J-55 7,338' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-OTIS RH RETRIEVABLE PACKER(HYD SET) MD=7031 TVD=5858 PACKER-OTIS WD PERMANENT PACKER MD=7312 TVD=6090 SAFETY VLV-OTIS QLS SAFETY VALVE w/X NIPPLE PROFILE ON TOP MD=1855 TVD=1836 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0I 14.Estimated Date for 6/25/2018 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL 0 Suspended P 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned p 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Dusty Ward Dusty Ward — Authorized Name: Contact Name: Authorized Title: Sr.Wells Engineer Contact Email: Dusty.Ward@cop.com Contact Phone: (907)265-6531 Authorized Signature: P:44,;— 47;er,`i Date: b - 13- oO 1g COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n I,,e;3 , itil Plug Integrity 0 BOP Test l ' Mechanical Integrity Test 0 Location Clearance 0 Other f ..- 5-60 ) f RBDMS.!1 JUN 2 0 2018 Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes ❑ No L5Q Subsequent Form Required: / 0 --`1 C``I APPROVED BY Approved by: `I COMMISSIONER THE COMMISSION Date: Co t i 16116 1 okh / ‘18,/8 O R I G I N C- Submit Form and (oA v Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachm is in Duplicate • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 11 June,2018 Commissioner State of Alaska �y3 ! i Alaska Oil&Gas Conservation Commission �,,) A 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1F-07(PTD# 182-156). Well 1F-07 was drilled and completed in October of 1982 by Doyon 9 as a Kuparuk A/C sand producing well. The A-sand and C-sands were stimulated with acid treatment in April of 1983.In September of 1984,the A-sand was fracked and a well workover pulled the completion and then did a cement squeeze between the A and C sands.There was perforating and re-perforating throughout the 1990s and 2000s. In October 2006,a C sand patch was set at 7202.5' RKB to aid a Frac,which occurred later that year.The patch was attempted to be pulled in May 2007,in order to aid cleanout run abilities.CT got on the patch and tried to remove it, but sheared off part of the TTS pulling tool.Patch suspected to be damaged and couldn't be pulled.Well was flowing at time,so patch was determined to be left.Unable to re-latch path,so suspect fishing neck is split. Well has often passed MITs and TIFLs.There was a failed TIFL in November 2017,but replacement of the RM-OV of the GLM at 6965' RKB provided a passing test.Total open flow of the well is calculated at 556 BLPD. The well became a CTD candidate and the blast rings joints from 7173' RKB to 7281'RKB need to be removed for KOP.The well will have the tubing completion swapped and set up for CTD. If you have any questions or require any further information,please contact me at 265-6531. Sincerely, Dusty Ward Senior Wells Engineer CPAI Drilling and Wells • • 1F-07 Proposed RWO Completion 16"65# H-40 shoe @80' MD PROPOSED COMPLETION 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-1/2"Camco MMG gas lift mandrels @ TBD M Baker 3-1/2"PBR xxxx'MD(3"ID) 10-3/4"45# K-55 shoe Baker FHL Packer @ xxxx'MD(4"ID) @ 2259' MD ( 1 y-, 3-'/z"X landing nipple at xxxx' MD(2.813"min ID)IP v (k ZTandem Wedges Perf Pup 3-1/2"Non-sealing Overshoe = REMAINING COMPLETION LEFT IN HOLE OTIS WD Permanend Packer @ 7312'MD(4"ID) KOP @ 7190' MD OTIS MOE @ 7316' MD(4.35"ID) OTIS XNS nipple @ 7332'MD(2.813" ID) OTIS SOS @ 7338'MD KOP @7210' MD Fr—L— C-sand perfs 7184' -7244' MD B-sand 7255' -7282' MD A-sand perfs 7393' -7458' MD ISI 7"26# K-55 shoe @ — 8045' MD 1F-07 RWO Procedure • Kuparuk Producer CTD Setup PTD#182-156 Remaining Pre-Rig Work 1. Chem cut the tubing nominally at^'7157' RKB in the middle of the first above the blast ring joints that start at ^'7173'RKB. 2. Chem cut the tubing nominally at"'6995'RKB in the middle of the first above the SBR that starts at^'7005'RKB. 3. Install BPV. 4. ND SSV and Swab valve within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU on 1F-07.Kill well by circulating KWF long way around. 2. Record shut-in pressures on the T&TC.-If there is pressure,bleed off IA and/or tubing pressure and complete 30-minute NFT.Verify well is dead. 3. Set BPV,ND Tree,NU BOPE and test to 250/2,500 psi.Test annular 250/2,500 psi. Retrieve Tubing,Packers,and Blast Ring Tubing Section 4. Pull BPV,MU landing joint and BOLDS. 5. Pull 3-1/2"tubing down to pre-rig to first packer(7031'RKB). 6. Pull first packer with 3-1/2"tubing down to pre-rig cut(^'7165'). 7. Washover tubing section blast rings to clean up. 8. Overshot blast ring section and mechanically cut below blast ring section(7293'),then pull to surface. Clean out hole and set 7"Bridge Plug 9. Perform a Cleanout run if necessary based on tubing condition. Install in 344"Tubing with tandem wedge for CTD Set Up 10. MU 3 W'completion with non-sealing overshot,tandem wedges,and packer. RIH and correlate completion so Kick Off Joints are at correct depth.Confirm overshot has engaged tubing stub. 11. Drop ball and rod and set packer w/completion. 12. Pressure test tubing to 3000 psi for 5 minutes. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP,NU Tree 14. Confirm pressure tests,then shear out SOV with pressure differential. 15. Install BPV. 16. ND BOPE.NU dry hole tree. 17. Freeze protect well. 18. RDMO. Page 1 of 1 • 1F-07 RWO Procedure • Kuparuk Producer CTD Setup PTD#182-156 f Remaining Pre-Rig Work t3 . 1. Chem cut the tubing nominally at 7157' RKB in the middle of e first above the blast ring joints that start at 7173'RKB. 2. Chem cut the tubing nominally at 6995'RKB in the middl: of the first above the SBR that starts at^'7005' RKB. 3. Install BPV. 4. ND SSV and Swab valve within 48 hrs of rig arrival. Rig Work MIRU • 1. MIRU on 1F-07. 2. Record shut-in pressures on the T&IA. If t -re is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT.Verify well is dead. K.0 Kms/ 3. Set BPV, ND Tree, NU BOPE and test to 2.1/2,500 psi.Test annular 250/2,500 psi. Retrieve Tubing, Packers,and Blast Ri : Tubing Section 4. Pull BPV, MU landing joint and BOLD . 5. Pull 3-1/2"tubing down to pre-rig 'o first packer(7031'RKB). 6. Pull first packer with 3-1/2"tubi : down to pre-rig cut(-7165'). 7. Washover tubing section blast r gs to clean up. 8. Overshot blast ring section an. mechanically cut below blast ring section(7293'),then pull to surface. Clean out hole and set 7"Bri•ge Plug 9. Perform a Cleanout run if ,ecessary based on tubing condition. Install in 3-'34"Tubing wit tandem wedge for CTD Set Up 10. MU 3'/:"completion th non-sealing overshot,tandem wedges,and packer. RIH and correlate completion so Kick Off Joints are at •rrect depth.Confirm overshot has engaged tubing stub. 11. ro and rod an set packer w/completion. 12. Pressure test tubin: to 3000 psi for 5 minutes. 13. Pressure test inner .nnulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 14. Confirm pressur: tests,then shear out SOV with pressure differential. 15. Install BPV. 16. ND BOPE.NU d hole tree. 17. Freeze protect well. 18. RDMO. Page 1of1 4, -� KUP PROD • 1F-07 ConocoPhillips Well Attributes Max Angle&MD TD )Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) -Act Btm(ftKB) ji,mp, 500292083000 KUPARUK RIVER UNIT PROD 44.83 5,700.00 8,060.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1F-07,12/420172'.044:27 PM SSSV:TRDP 40 9/10/2016 Last WO: 9/10/1984 40.59 10/21/1982 VeNcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,396.0 8/10/2017 Rev Reason:TAG&GLV C/O(#6&#7) pproven 12/4/2017 HANGER;22.3- Casing Strings ] Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WELen(I...Grade Top Thread CONDUCTOR 16 15.250 35.0 80.0 80.0 65.00 H-40 WELDED 5111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread II SURFACE 103/4 9.950 34.2 2,258.7 2,189.0 45.50 K-55 BUTT • as-A-A-CONDUCTOR;35.0- .,�W ,�,.,. Strings D IDI Top(ftKB) SettDepth(ft.. Depth(TVp)ND tl Wt/Len Gr Grade Top Thread Casing P (in) (in) Top(ftKB) Depth(ftKB) P ( I PRODUCTION 7 6.276 32 1 8,045 0 6,704.5 26.00 K-55 BTC Tub 800 I Tubing Description StringMa...IDGrade Top Connection TUBING 31/2 2.992 22.3 7,338.4 6,112.2 9.30 J-55 BTC IPC Completion Details SAFETY VLV;1,855.1WI Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inol(') Item Des Corn lin) 22.3- 22.3 0.10 HANGER FMC GEN II HANGER 3.500 GAS LIFT:1.933.3---1,--Ir41,855.1 1,836.1 23.46 SAFETY VLV OTIS QLS SAFETY VALVE w/X NIPPLE PROFILE ON 2.813 TOP 7,005.4 5,837.0 35.16 SBR OTIS SBR w/X NIPPLE PROFILE 2.813 7,030.9 5,857.9 34.97 PACKER OTIS RH PACKER(HYD SET) 4.000 2.992 7,172.9 5,974.9 34.10 BLAST RINGS BLAST RINGSRETRIEVABLE(4) SURFACE;34.2-2,258.7 W i i 7,310.8 6,089.2 34.02 LOCATOR OTIS STRAIGHT SLOT LOCATOR 3.000 GAS LIFT;3,145.2. 7,312.0 6,090.2 34.02 PACKER OTIS WD PERMANENT PACKER 4.000 7,315.9 6,093.4 34.01 MILL OTIS MILL OUT EXTENSION 4.350 GAS LIFT;4,326.6 i 7,331.9 6,106.8 33.96 NIPPLE OTIS 2.81"XNS POLISHED BORE NIPPLE w/2.75"NO 2.813 GO GAS LIFT;5,466.0 1E 7,337.8 6,111.6 33.95 SOS OTIS SHEAR OUT SUB,ELMD TTL©7333'during 4.470 PPROF on 3/22/2008 GAS LIFT;6,277.1-f Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) ("I Des Com Run Date ID lin) 7,182.0 5,982.5 34.06 PATCH '10/13/2006-SET TTS LOWER PACKER ELEMENT 10/15/2006 1.625 GAS LIFT;6,965.2 jr, OF A PATCH AT 7202.5'BASED ON SWS LDL. PACKER MID ELEMENT SET DEPTH:7202.5' 10/15/2006-SET UPPER TTS PKR&SPACER ASS'Y(OAL:25.08',MIN ID:1.625")©7182'SLM. SBR;7,005.4-3A1NOTE:PACKER HAD AN ALUMINUM PINNED FOR 3600 PSI DIFFERENTIAL. PACKER;7,0309 PRODUCTION;7,067.6 7.585.0' 6,318.2' 32.88 FISH Vann Gun Downhole 9/10/1984 Perforations&Slots PRODUCTION;7,136.0 Shot Dens Iy/ Top(ND) Btm(ND) (shots# - /� Top(, (,K (ftKB) Bun B) (ftKB) (ftKB) Zone Date t) Type Com 7,184.0 7,244.0 5,984.1 6,033.9 C-4,1 F-07 9/1/1984 12.0 RPERF 5"DA;90 deg ph ��.��All(ERF;7f840-7244u 44/t.' GMMM///"` 7,184.0 7,244.0 5,984.1 6,033.9 C-4,1F-07 10/21/1982 12.0 IPERF 5"Vann Guns PATCH;7,182.0 7,255.0 7,260.0 6,043.0 6,047.2 UNIT B,IF-07 9/1/1984 12.0 RPERF 5"DA;90 deg ph , . , . . `+ ERF;7,184.0.7, 4.0 AC C-SAND;7,18184.0 . 7,255.0 7,260.0 6,043.0 6,047.2 UNIT B,1F-07 10/21/1982 12.0 IPERF 5"Vann Guns RPERF;77:256.0--772260.601__ (PERF; 250 , 7,268.0 7,282.0 6,053.8 6,065.4 UNIT B,1F-07 9/1/1984 12.0'RPERF 5"DA;90 deg ph RPERF;7,268.67,282.0 IPERF;7,266.0-7,282.0 C 7,268.0 7,282.0 6,053.8 6,065.4 UNIT B,IF-07 10/21/1982 12.0 IPERF 5"Vann Guns I. 7,393.0 7,405.0 6,157.5 6,167.4 A-4,1F-07 10/10/2006 6.0 RPERF 2.5"HSD HJ RDX,60 PRODUCTION;7,293.4 i. J deg.ph 7,393.0 7,405.0 6,157.5 6,167.4 A-4,1F-07 10/21/1982 12.0 IPERF 5"Vann guns LOCATOR;7,310.8 7,420.0 7,446.0 6,179.9 6,201.6 A-4,1F-07 10/21/1982 12.0 IPERF 5"Vann guns PACKER;7,312.0 7,453.0 7,458.0 6,207.5 6,211.6 A-4,1F-07 10/21/1982 12.0 IPERF 5"Vann guns MILL;7,315.9 fr' Stimulations&Treatments Proppant Designed(lb) Proppant In Formation(Ib) Date 9/23/2000 NIPPLE;7,331.9 Stimulations&Treatments Vol Clean Pump Stg# Top(ftKB) Btm 1560) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 506;7,337.8 dr7b 1 7,184.0 7,244.0 9/23/2000 Proppant Designed(Ib) Proppant In Formation(lb) Date 10/27/2006 Stimulations&Treatments Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date Stjm/Treat Fluid (bbl) Vol Slurry(bbl) IPERF;7,3930-7,405.0- : 1 7,393.0 7,458.0 10/27/2006 RPERF;7,393.0-7,405.0 Mandrel Inserts FRAC A-SAND;7,3930 II St IPERF;7,420.0-7,446.0 , ati on Top(ND) Valve Latch Port Size TRO Run (PERF;7,453.0-7,458.0 IIN Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1� 1,933.3 1,907.1 OTIS OVAL D' 1'- GAS LIFT 'GLV BK 0.156 1,311.0 12/2/2013 2 3,145.2 2,895.3 OTIS 'OVAL D 1'GAS LIFT GLV BK - 0.156 1,298.0 12/2/2013 FISH;7,585.0 1111P3 4,326.6 3,785.9 OTIS OVAL 0' 1'- GAS LIFT GLV BK 0.188 1,323.0 12/2/2013 • 4 5,466.0 4,683.6 OTIS OVAL D' 1'- GAS LIFT -GLV BK ' 0.188 1,310.0 12/2/2013 PRODUCTION;32.1-8,045.0 KUP PROD • 1F-07 ConocoPhiilips fel;{.shit,k,„ 1 F-07,12/4/2017 2.04:29 PM Vertical schematic(actual) HANGER,22.3 Si':.L""rO Mandrel Inserts at 1 Y� ° Top(ND) Valve Latch Port Size TRO Run t� N Top(11KB) (RKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Coo,.. .., .., paa, 6,277.) 5,269.2 OTIS OVAL D 1 GAS LIFT GLV BK 0.188 1,295.0 12/2/2013 untl6 6,965.2 5,804.3 OTIS HP1 1/2 GAS LIFT OV RM 0.188 0.0 11/25/2017 ✓✓\CONDUCTOR;35.0-80.0' ' 1111 7 7,067.6 5,888.0 OTIS OVAL D 1 PROD DPHF BEK 0.313 0.0 11/26/2017 CV SAFETY VLV;1,855.1 p 8 7,136.0 5,944.4 OTIS 'OVAL D 1 PROD DMY BK 0.000 0.0 9/24/2006 9 7,293.4 6,074.9 OTIS 'OVAL D 1 PROD DMY BK 0.000 0.0 9/26/2006 GAS LIFT;1933.3 Notes:General&Safety End Date Annotation 9/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;34,2-2,258.7- GAS LIFT;3,145.2 I GAS LIFT;4,326.6 GAS LIFT;5,466.0 : • GAS LIFT;6,277.1 GAS LIFT;6,9652 SBR;7,005.4 PACKER;7,030.9 :.. PRODUCTION;7,067.6 PRODUCTION;7,138.0 . PATCH;7,182 0 I � RPERF;7,184.0-7,2440 r I IPERF;7,184.0-7,244.0 FRAC C-SAND;7,184.0 R PERF;7,255 0-7,260.0, IPERF;7,255.0-7,260.0 RPERF;7,268.0-7,282.0 IPERF;7,268.0.7,282.0 t. la PRODUCTION;7,293.4 • TOR;7,310.8 r, ti PACKER;7.312.0 Y J I. c e_ MILL;7,315.9 � •; NIPPLE;7,331.9 SOS;7,337.8 .: 111 IPERF;7,393.0-7,405.0, . RPERF;7,393.0-7,405.0 FRAC A-SAND,7,393.0 ; IPERF;7,420 0-7,446.0 IPERF;7,453.0-7,456.0 I FISH,7,585 0 PRODUCTION;32.1-8,045.0- - • • • xi cn z - / D $ — — - 1 c V _ _ c co C ..=O O Q• C Z 2 - - — C © •Z PI t0 m SCO2 j'm 3 Vii w O2 oP� g1� pix xD0 y w g,)7< m 09 m I lb.'.'4, 9g N N E N N N 6 3 OO x w »T m y n— 2 I X�3 R am m v 9 ii an , GaN �mmp)o3ac o3 p mm n v IIm<. n < r - << 1®O® 4OOOOO= x c a �' m m C OOO OOOO ism o*o d * * mc O^O ® Oo` O® - ® ,— II INI i Ciat 1 1 II t 1 1 0 1 1 = D 11 1D I.0 zni° o o ... ..... 3� } 8 m , 6 m D ' a m m lh 6 W5,-)r a:`Ng.= m LT I' - � <• '5°..„_r?, a) 4 9 E4P " m OOO'3'. Li • i_ R`W g 23 II■ ■ AC'2 .1,"2-, WN a %m m A-,x p a= N a m i gnw m0s mum m ;' �s N A 1ummum mummom D 11 a_r �� 'O� 000 quo E. SNgR a ill �a m ° 92 = Fm o ° g A 'No .0 3O OO OO Ono o s^3 �d mN -0 O�O GOO.. .,. • • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday,June 18, 2018 9:47 AM To: 'Ward, Dusty K' Cc: Loepp,Victoria T(DOA);Coberly,Jonathan Subject: RE: [EXTERNALJ1F-07 RWO using AA111 Dusty, Thanks for the clarifications....AA111 won't need a another rig inspection as this will be second well. I will use your updated procedure in the sundry application. I also assume you will be circulating brine around before you chemical cut the tubing too. (oil and chemical cuts don't mix !!) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservati n Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From:Ward, Dusty K[mailto:Dusty.Ward@conocophillips.com] Sent: Monday,June 18, 2018 7:30 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>;Coberly,Jonathan<Jonathan.Coberly@conocophillips.com> Subject:RE: [EXTERNAL]1F-07 RWO using AA111 Guy, Thanks for the e-mail and list of questions.That's helpful to have a list to respond to. - Negative on this being AAO-111's first well with us,we're using it on 31-01 first. - Answers to your questions in red below. Question: If you've recently inspected the rig before 1F-07 for our program,will you also need to inspect it at 1F-07?(ISI know we need you present on both for BOP test from my understanding, but I was curious if the rig would need it agaiht if we just moved wells.)Thanks for clarifying. And noted on the fact that your inspectors are busy. Let me know if you need anything else Guy. Good day. Dusty Ward Senior Wells Engineer Office:907-265-6531 Cell:503-476-2519 From:Schwartz,Guy L(DOA)<guy.schwartzPalaska.gov> Sent: Friday,June 15, 2018 1:42 PM To:Ward, Dusty K<Dusty.Ward(Wconocophillips.com> 1 Cc:Loepp,Victoria T(DOA)<vicS.loepp@alaska.gov> • Subject: [EXTERNAL]1F-07 RWO using AA111 Dusty, I see you are submitting a sundry for the RWO on 1F-07. Is this the first well for the AA111 rig? A couple of comments: 1) When was last time the IA was tested? May want to do a casing test(CMIT) before pulling completion. Recently: CMIT T x IA of 2500 psi on 5/30/2018, passed. 2) Need to circulate KWF around before pulling the completion. I don't see that in your procedure. 10-4. Have it in the elan and I undated summary(attached) 3) AOGCC inspectors will need to see the BOPE test and do rig inspection. Will not waive the BOPE/rig inspection so you may have to wait for an available inspector. Also, Need a vendor schematic of the BOPE stack and choke manifold. attached). We're using the short stack in the drawing w/double gate and annular. Choke manifold is described in there. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). 2 � r 0 s I H > r T a xp a S v O > L v O �r� { v L ° o LL O E ; Q��<10 N co Y o v o ca O O iZ @ Q x U O_ O' a: J w r r r r r n r *' � o c l7 L N U L Q) ZT �"' L -0 O to 7 0 0 0 Q Q Q `� L v1 V1 F- N O N U) Ls- CO CO C T` Q N U �O C� O u O C L F- +7+ aJ +.' as O U f0 v 'p U 7 7 0 Cl 0 7 7 C L O p L W J J J J J J J C O } W W W W W W W N N .0 U `+' F- LL LL LL LL LL W LL +- a) a) aJ -0 Q L > L a) uto r Q Q Q Q Q Q Q Q1 O L O 0) 0 Z Z Z Z Z Z Z a, L a) v pp ! 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O O M M Cl M E _ _ N N N N N N N N N = n .M o) o) o) C) C) C) C o a R O N N N N N N Q1 • O O O O O O CO u 0 O O O O O O O ++ 4' C O rintl 00 !) 0 0 C in to tN N7 a "O 0 C epri I- cn m . u C • U cur TE a) 00 Q a3 w x w -p co (ID ,O ■� F^ ,ry Q N n n O Q W W ac. C .Y -C QI = Z ++ 00 fY) Z N Oi >7 r ,- �_ C a) aJ aJ A c:cv) cL0 r J Q y N = _ E C mom a Q O N w N N N v) Z (1) 0 0 t L r 2� a C v E E O '� a i0 Qks, H a Ll H FO- Imac. ect Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J-- ~ C:~- ~- ~-~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] .Diskettes, No. [] Maps: :[] .C~ayscale~ items: [] Other, No/Type [] Other items scannable by ~ Poor Quality Originals: large scanner OVERSIZED (Non-Scannable) [] Other: n Logs of various kinds NOTES: [] Other BY: ~BIN VINCENT SHERYL MARIA WINDY Project Proofing Scanning Preparation Production Scanning Stage f PAGE COUNT FROM SCANNED FILE: =/--~ OUNT SCANNING PREPARATION: YES A NO MATCHES NUMBER IN IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~YEs NO BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS EPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAY$CALE OR COLOR IMAGES) ReScanned (individual page [special at~e,tion] .~ca~ming cr~mple~ed) RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: /SI Quality Checked 12/10/02Rev3NOTScanned.wpcl • ConocoPhillips P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 18, 2008 ~~ ~ ~ ~ ~' =~' Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ ~_ ~ ° i ~ ~i BAR ~ 2009 ;:~~a~G ~s Ca~~s. CQf ~j' "~'~: 93/6 ~?C~lOI~~C r-~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRII). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 13th, 2009. The corrosion inhibitor/sealant was pumped March 4th, 11 ~` & 16th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Pen, ~~.,,.~. f~a-~s~ ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/16/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-01A 205-029 7" N/A 7" N/A 1.7 3/16/2009 1 F-02 182-211 SF N/A SF N/A 2.90 3/4/2009 1F-03A 196-096 SF N/A SF N/A 2.20 3/4/2009 1 F-04 182-172 20" N/A 20" N/A 5.20 3/4/2009 1F-05 182-132 SF N/A SF N/A 1.60 3/4/2009 1F-06 182-145 SF N/A SF N/A 2.10 3/4/2009 1F-07 182-156 SF N/A SF N/A 2.40 3/4/2009 1 F-08 182-162 SF N/A SF N/A 2.20 3/4/2009 1F-10 183-105 20" NA 20" NA 1.70 3/11/2009 1F-12 183-136 54' 7.50 5'6" 2/13/2009 18.70 3/11/2009 1F-13 183-144 SF NA 6" NA 1.30 3/11/2009 1F-16A 201-209 SF NA 22" NA 1.70 3/11/2009 ~~;~-- - ~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Welt Job # ~~.~ ~~~ ~ ZQ~ Log Description NO. 4650 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 r/,, Field: Kuparuk ~ ~,{j Jv ~~ Date BL Color CD 04/08/08 1A-19 12031469 LEE TOOL PROD PROFILE 03/21/08 1 1F-07 1203f470 PROD PROFILE r'~ 03/22/08 1 3A-09 11980648 PROD PROFILE f ~-~9 03/22/08 1 2A-22 11970645 MULTI-FINGER CALIPER 03/20/08 1 1 F-15 11970659 INJECTION PROFILE 04/02/08 1 1 C-11 11994642 LDL 04/03/08 1 iG-09 11996613 INJECTION PROFILE V = 04/05/08 1 iJ-159 11994646 GLS (o.- 04/06/08 1 2W-15 11996615 PRODUCTION PROFILE -a 04/07/08 1 1 L-08 11996616 PRODUC710N PROFILE L 04/08/08 1 Please sign and return one copy of this transmittal to Beth ai the above address or fax to (907) 561-8317. Thank you. • • r r1> 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 115' . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Repair Well 0 Pull Tubing 0 Operat. ShutdownD o Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Other o o 182-156/ 6. API Number: 50-029-20830-00 ' Exploratory Service 9. Well Name and Number: 1 F-07 8. Property Designation: ADL 25652; ALK 2578 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: measured 8060' " feet true vertical 6717' feet measured 7357' feet true vertical 6128' feet Length Size MD 80' 16" 80' 2144' 10-314" 2259' 7923' 7" 8038' Plugs (measured) Junk (measured) 7585' TVD Burst Collapse 80' 2189' 6699' ;¡) (" Measured depth: 7184'-7244',7255'-7260',7268'-7282', 7393'-7405', 7420'-7446', 7453'-7458' true vertical depth: 5984'-6034',6043'-6047',6054'-6065', 6157'-6167', 6180'-6202', 6208'-6212' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7338' MD. Packers & SSSV (type & measured depth) pkr= OTIS 'RH' RETR.; OTIS 'WD' PERM. pkr= 7039'; 7320' Otis 'aLS' SSSV= 1863' 12. Stimulation or cement squeeze summary: 7393'-7458' Intervals treated (measured) 182823# 16/20 carbo in formation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 218 420 251 153 Subsequent to operation 366 . 850 481 157 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 . Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0' GasD WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Title Phone: 265-6958 Wells Group Engineer Date I k IL( - 0(; Pared b Sharon All Dr ke 263-4612 ORIGINAL þ1lL. ¡..:Þ II- Is ~ /Z..b· iginalOnly ! ( (rJi(c¡; ./"p' . 1 F-07 Well Events Summary . DATE Summary 9/5/06 TAGGED FILL @ 7483' RKB, 25' OF RAT HOLE, SET 2.81" XN PLUG W/ DUAL PANEX GAUGES @ 7332' RKB 9/9/06 MEASURE C-SAND SBHPS OF 2138 PSI (154 DEG F) @ 7214' RKB & 2131 PSI (152 DEG F) @ 7000' RKB. PULLED XN LOCK WITH DUAL PANEX GAUGES @ 7332' RKB. A SAND SBHP = 2566 PSI (158 DEG F). JOB COMPLETE. 9/18/06 DRIFT & TAG BOTTOM @ 7493' RKB, PULL CV FROM 7302' RKB. JOB IN PROGRESS. 9/19/06 SET DV @ 7302' RKB, UNSUCCESSFUL IN PULLING CV @ 7144' RKB DUE TO JUNK AROUND VALVE, VALVE POSSIBLE OUT OF POCKET @ 5474' RKB. JOB IN PROGRESS. 9/20/06 SET DV @ 3153' RKB, BRUSHED TBG & MANDRELS LOOKING FOR MISSING VALVES, IN PROGRESS 9/21/06 SET 1" DV @ 5474' RKB, ATTEMPT TO PULL CV W/ TRASH @ 7144' RKB, IN PROGRESS 9/22/06 ATTEMPT TO PULL CV W/ TRASH ON TOP @ 7144' RKB, IN PROGRESS 9/23/06 SET CAT SV @ 7332' RKB, ATTEMPT TO PULL CV @ 7144' RKB. IN PROGRESS 9/24/06 FOUND EMPTY POCKET @ 7144' RKB ONCE DEBRIS WAS REMOVED, SET DMY VALVE, FAILED PT. PULLED VALVE @ 7076' RKB. IN PROGRESS 9/25/06 SET DV @ 7076' RKB, TESTED TBG W/ D&D HOLE FINDER BELOW MANDREL @ 7144' RKB HELD 1000#, PULLED & RERAN CAT SV, TBG FAILED PT, IN PROGRESS 9/26/06 REPLACED DV @ 7302' RKB, FOUND LEAK BELOW MANDRELL @ 7144' RKB W/ D&D HOLE FINDER @ 7159' WLM 9/27/06 LEAK DETECTION LOG. LEAK FOUND AT 7196' -IN MIDDLE OF SECOND BLAST JOINT BELOW PRODUCTION MANDREL #8. WELL LEFT SHUT IN. 10/6/06 DRIFT TUBING TO 7334' RKB W/20' X 2.75" DUMMY PATCH. PULLED HEAVY (900#) WHILE POOH WITH PATCH BUT NO PROBLEMS RIH. IN PROGRESS 10/7/06 PULL 2.81" CAT-SV @ 7332' RKB, BRUSHED TUBING FROM 7150'-7250' RKB, RAN PDS CALIPER FROM TUBING TAIL @ 7338' RKB TO SURFACE 10/10/06 PERFORATED 7393' - 7405'. GUN DETAILS: 2.5" HYPERJET, RDX, 6 SPF, 60 DEG PHASING, 13.1" PENE, 0.43" EH. TAGGED TD AT 7483'. WELL LEFT SHUT IN. 10/13/06 SET TTS LOWER PACKER ELEMENT OF A PATCH AT 7202.5' BASED ON SWS LDL. PACKER MID ELEMENT SET DEPTH: 7202.5' NOTE: PACKER HAD AN ALUMINUM PINNED FOR 3600 PSI DIFFERENTIAL. DID NOT TAG TD. WELL LEFT SHUT IN. 10/15/06 SET UPPER TTS PKR & SPACER ASS'Y (OAL: 25.08', MIN ID: 1.625") @ 7182' SLM. TESTED 2500 PSI, GOOD. BEAT SHEAR DISC OUT OF LOWER PKR. IN PROGRESS. 10/16/06 SET 2.81" XX PLUG @ 7013' RKB, PULLED 1.5" OV @ 6979' RKB. CIRC. TBG & CSG TO DSL. SET 1.5" DV @ 6979' RKB. IN PROGRESS. 10/17/06 REPLACED 1.5" DV @ 6979' RKB. MITT & MITIA 3500 PSI, PASSED. PULLED 2.81" XX PLUG @ 7013' RKB. 10/25/06 SAT DOWN IN TREE @ -3' SLM, RUN LIB, SHOWS PICTURE OF 1/4" LIP. JOB IN PROGRESS 10/26/06 TROUBLE SHOOT OBSTRUCTION IN TREE, SSV NOT FULLY OPEN, SET 3.5" QLS FRAC SLEEVE ACROSS SSSV @ 1863' RKB. JOB COMPLETE . 1 F-07 Well Events Summary . 10/27/06 PUMP FRAC. W/ 50# XL GEL PAD AND 40# XL GEL SAND STAGES. RATES RANGED FROM 20 BPM TO 9 BPM. ACTIVATOR RANGED FROM 5/1000 TO 3.5/1000, FLUSH W/10 BBLS WF-20 AND 50 DIESEL, FINAL PUMPING PRESSURE 3760 PSI, ISIP= 2339 PSI PUMPED A TOTAL OF 182823# 16/20 10/28/06 PULLED 31/2" QLS FRAC SLEEVE FROM TRDP @ 1863' RKB. TAGGED @ 7357' RKB (EST. 101' ABOVE BOTTOM PERFS). PULLED 1.5" DV FROM STA# 6 @ 6979' RKB AND REPLACED W/ 1.5" OV (3/16" PORT, RM LATCH). IN PROGRESS. 10/29/06 PULLED 1" DV FROM STA# 5 (6285' RKB) AND REPLACED W/ 1" GLV (3/16" PORT, 1329# TRO, BK LATCH). PULLED 1" DV FROM ST A# 4 (5474' RKB) AND REPLACED W/ 1" GLV (3/16" PORT, 1343# TRO, BK LATCH). PULLED 1" DV FROM STA# 3 (4335' RKB) AND REPLACED W/ 1" GLV (3/ 11/11/06 TAGGED @ 7399' RKB, EST. 59' FILL. ~ SSSV (186;}'1864. 00:3.500) SBR (701;}'7014. 00:3.500) PKR (7039-7040, 00:6.156) (7149-7151) . ConocoPhillips Alaska, Inc. 1F.Q7 ¡ I ~ ~ Perf ~ (7255-7260) ~ - = = Perf ~ - (7268-7282) ~ - ~ - PKR (7320-7321, 00:6.156) (7330-7332) (7366-7368) Perf (7393-7405) (757H574) I ~ ~ I DescriDtion CONDUCTOR SURFACE PRODUCTION Tubina Strina - TUBING Size I Top I Bottom 3.500 0 7338 Perforations Summary Interval TVD 7184 - 7244 5984 - 6034 7255 - 7260 6043 - 6047 7268 - 7282 6054 - 6065 7393 - 7405 6157 - 6167 7420 - 7446 6180 - 6202 7453 - 7458 6208 - 6212 Stimulations & Treatments Interval Date 7573 - 7574 10/13/1982 7330 - 7332 10/15/1982 7149 - 7151 10/16/1982 7366 - 7368 9/6/1984 7184 - 7244 9/23/2000 FRAC C-SAND API: 500292083000 SSSV Tvpe: TRDP Annular Fluid: Reference Loa: Last Taa: 7357' RKB Last Tac:¡ Date: 10/28/2006 7393 - 7458 . KRU 1 F-07 Well Tvpe: PROD Oria Completion: 10/21/1982 Last W/O: 9/10/1984 ii, Anale@TS: 34dec:¡@7183 Anc:¡le @ TD: 33 dec:¡ @ 8060 Rev Reason: TAG, GLV C/O, PERF, FRAC, Set PATCH Last Update: 11/7/2006 Ref Loa Date: TD: 8060 ftKB Max Hole Anc:¡le: 45 dec:¡ @ 5700 Size 16.000 10.750 7.000 Grade Thread H-40 K-55 K-55 I Grade Thread J-55 BTC Tvpe Comment RPERF 5" DA- 90 dea oh RPERF 5" DA' 90 dea ph RPERF 5" DA; 90 dea ph RPERF 2.5" HSD HJ RDX, 60 dec:¡. ph IPERF 5" Vann c:¡uns IPERF 5" Vann auns Comment Used for 7" Primarv Cement Job TOD o o o TVD 80 2189 6699 Wt 65.00 45.50 26.00 I Bottom 80 2259 8038 I Wt 9.30 Zone C-4 UNITB UNITB A-5 A-4 A-4 TVD 6112 Status Ft SPF 60 24 5 24 14 24 12 18 26 12 5 12 Date 9/1/1984 9/1/1984 9/1/1984 10/10/2006 10/21/1982 10/21/1982 TVDe PUMPED C SAND FRAC. PLACED 85M# PROPPANT BEHIND PIPE, 16/20 AND 12/18, 8 PPA ON PERFS. FLUSHED TO COMPLETION. PLACED 106% OF DESIGN. FINAL PUMPING PRESSURE 3760 PSI, ISIP- 2339 PSI PUMPED A TOTAL OF 182823# 16/20 CARBO IN FORMATION (85% OF DESIGN) W/1200# LEFT IN WELL V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 10/27/2006 FRAC A-SAND Gas Lift MandrelslValves St MD TVD Man Man Type Mfr Otis Otis Otis Otis Otis Otis Oval D' Oval D' Oval D' Oval D' Oval D' 'H. P. Round' Production MandrelsNalves St MD TVD Man Man Type V Mfr Mfr 7 7076 5895 Otis Oval D' 8 7144 5951 Otis Oval D' 9 7302 6082 Otis Oval D' Other plugs equip, etc.) - COMPLETION Depth TVD Type 1863 1843 SSSV 7013 5843 SBR 7039 5865 PKR 7182 5983 PATCH I 1 2 3 4 5 6 1914 2901 3792 4689 5275 5816 1941 3153 4335 5474 6285 6979 7320 6097 7332 6107 7337 6111 7338 6112 Fish - FISH DeDth I 7585 I Vann Gun PKR NIP SOS TTL DescriDtion I ~ -¿ =j :::;". ..s.. I GLV 1.0 BK 0.156 1345 10/29/2006 GLV 1.0 BK 0.156 1332 10/29/2006 GLV 1.0 BK 0.188 1355 10/29/2006 GLV 1.0 BK 0.188 1343 10/29/2006 GLV 1.0 BK 0.188 1329 10/29/2006 OV 1.5 RM 0.188 0 10/28/2006 V Type VOD Latch Port TRO Date Run Vlv Cmnt DMY DMY DMY 0.000 0.000 0.000 9/25/2006 9/24/2006 9/26/2006 o o o 1.0 1.0 1.0 » Description Otis 'QLS' w/ 'X' Nipple Profile on Top Otis w/ 'X' Nioole Profile Otis 'RH' RETR. (Hvd. set 10/13/2006 - SET TTS LOWER PACKER ELEMENT OF A PATCH AT 7202.5' BASED ON SWS LDL. PACKER MID ELEMENT SET DEPTH: 7202.5' 10/15/2006 - SET UPPER TTS PKR & SPACER ASS'Y (OAL: 25.08', MIN ID: 1.625") @7182' SLM. NOTE: PACKER HAD AN ALUMINUM PINNED FOR 3600 PSI DIFFERENTIAL. Otis 'WD' PERM. Otis 2.81" 'XNS' POLISHED BORE Nipple w/2.75" NO GO Otis BK BK BK ID 2.813 2.813 4.000 1.625 4.000 2.750 2.992 2.992 I I Downhole Comment 10/13/06 Sc~_bepgep OGr :I. 6 :2006 l~~ Oil (;(Ni!P'i~1Wt "'> ~'I \Ø ...L ,;;'/Î" Üìk~i¡t:¡¡}.::1I1 U\i;?nJ;\.G\'!J;>,,â,,: Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth /fSé) - IS-~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Date Color CD Job# Log Description BL 1 J-127 11404957 PROD PROFILE WIDEFT 09/14/06 1 2W·10 11404958 INJECTION PROFILE 09/15/06 1 2W·14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20/06 1 2A-19A 11415618 PROD PROFILE W/DEFT 09/03/06 1 1E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 2T-39 11296724 PROD PROFILE W/DEFT 09/20/06 1 1 L-04 11415626 SBHP SURVEY 09/24/06 1 2V -04 11415628 INJECTION PROFILE 09/26/06 1 1A-17 11415622 PROD PROFILE W/DEFT 09/21/06 1 1 L-06 11415625 SBHP SURVEY 09/24/06 1 1F-07 11415629 LDL 09/27/06 1 2F-06 11434750 FLOWING BHP SURVEY 10/03/06 1 2A-17 11434751 PROD PROFILE W/DEFT 10/04/06 1 2P-447 11404966 INJECTION PROFILE 10/06/06 1 2V -08A 11216327 US IT 09/21/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 1 00 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Ca/iper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1 BL / EDE Disk 1 F - 07 Caliper Report 7 -Oct-06 1 ] 2] 3) 4] 5J 6] 7] oÇA~~fXJ <:' r}f,r\~ (~} £..L""-"'''; Signed : / (Î ;1 j/, '-_ )UA ('11 " i.... (ì/¡ I .ir L.]J/ì 'S T , vl 'º- / 1/ cd/\- i/l!¡_ OA , . -- Date : Print Name: r¡:t i1J d - í S- {o ILl ( 1- 3 PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE. AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL:'>'·:..: _ .u'-, 3: ;,-2~~,'::::_-';~',:, ,"'. :' __ .:- ,;;. :. --~ WEBSITE: :/:"~:. ._ - ~.-.!' '" ."' ~. ~ . ~-- D:'.OO _ PDSAJ\fC~2006\Z_ W ord\Dtstnbution\TransI!Úttal._ Sheets\Transrrut_ Ongmal.doc I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Oesc.: Pipe1 Use: ConocoPhi/llps Alaska, Inc. October 7, 2006 6117 1 3.5" 9.3 lb. J-55 BTC Tubing Well: 1F-07 Field: Kuparuk State: Alaska API No.: 50-029-20830-00 Top Log Intvl1.: Suñace Bot. Log Intvl1.: 7,338 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the bottom of the 3.5" Tubing @ 7,338' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing logged appears to be in good condition with respect to corrosive and mechanical damages. No significant wall penetrations, areas of cross-sectional wall loss, or 1.0. restrictions are recorded in the 3.5" tubing logged. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 16%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. I Field Engineer: D. Cain Analyst M. Tahtouh Witness: T. Senden I c·,-··-·"F····"····· "·.c ~ECE IVE 0 n..:)".','.·' i !CO' , gJ, Y!U'.;.(~ . 6.59-231.4 OCT 1 0 2006 I'ð"d -15"" **= 1t../{ 7-3 Alaska Oil & Gas Cons. commission Anchorage I I Well: Field, Company: Country, 1F-07 Kuparuk ConocoPhillips Alaska, Inc. USA I I Tubing: Nom.OD 3.5 ins Grade & Thread -55 BTC Weight 9.3 f I Penetration and Metall.oss (% wall) penetration body metal loss body I 250 200 150 100 50 0 o to 1 ')'0 10 to 20 to 40 to over 20% 40% 85% 85% I 1 to 10% I o o I I Damage Configuration ( body ) 10 I I o I isolated general line ring hole I poss pitting corrosion corrosion corrosíon ¡ble hole I o I I PDS Report Overview Body Region Analysis Survey Date: Tool Type, Tool Size: No. of Fingers, Anal st Nom.ID 2.992 ins October 7, 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) penetration body o o GLM 1 GLM2 GLM3 GLM4 GLM 5 GLM6 metal loss body 50 100 Bottom of Survey 232.8 Analysis Overview page 2 I I I I Pipe 1 3.5 in (13.1' - 7337.9') GLM2 3111 0 Q¡ ~ ..Q ....; E LL ::¡ c: z 3890 ...c:: ...... ...... c Q.. '0 () GLM3 ~ 0 4671 I I I I I I GLM 1 I I I I I GLM4 I GLM5 GLM6 I I I Bottom of Survey = 232.8 I I Correlation of Recorded Damage to Borehole Profile Well: Field: Company: Country: Survey Date: 1 F-07 Kuparuk ConocoPhillips Alaska, Inc. USA October 7, 2006 Approx. Tool Deviation Approx. Borehole Profile 17 768 1542 2340 5436 6218 7040 232.8 o 50 7338 100 Damage Profile (o,{, wall) / Tool Deviation (degrees) I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf j-55 BTC 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 F-O 7 Kuparuk ConocoPhillíps Alaska, Inc. USA October 7, 2006 joint Jt. Depth Pen. Pen.. ' ¡\I¡e od Min. Damage Profile No. (Ft.) Body 1.0. Comments (%wall) ( (Ins.) (Ins.) 0 50 100 .1 13 0.00 _2 1 2.98 PUP 1 17 il 0.03 .11 ;£ 2.92 1.1 49 0 0.01 ;; 2.94 PUP 2 56 JL 0.00 î 2.95 3 89 C 0,01 ( 2 2.97 II 4 120 0 0,02 ( 2 2.97 II' 5 151 0.02 9 1 2.93 6 183 0.03 J3 J 2.96 Shallow pitting. 7 215 ( 0.02 .5) £ 2.93 8 244 J 0.01 JL .J 2,97 9 274 º- 0.01 6 1 2.97 10 305 -º-- 0.01 4 2 2.96 11 337 (I 0.01 3 '¡ 2.94 12 367 (I OJ)l 4 (I 2.95 13 397 0 0.02 9 2 2.97 f'Ii 14 429 (I 0.01 .4 .1 2.95 15 461 0.ü1 6 .2 2.94 16 492 º- 0.01 1 2.96 17 522 (I 0.02 ¡ 2 2.93 I'" 18 554 0 0.01 f 1 2.95 fIE 19 585 0.01 2 2.94 20 616 I 0.01 5 1 2,94 pi 21 645 0.01 l~ 2.94 22 675 0.00 1 2.95 23 705 ( 0.01 1 2.95 24 736 º- 0.02 J 2 2.96 ;m 25 768 ( 0.03 ¡ 2 2.97 Ell 26 799 0.02 ¡ ¡ 2.96 Ell 27 829 0.02 ( 1 2.94 28 859 ( 0.01 4 I 2.95 29 891 J) OJ)] -¡ 2.95 30 922 J! 0.01 2. 2.93 31 953 J 0.00 I 2.95 32 984 .J 0.01 2 2.92 33 1013 (I 0.02 'I 2.94 34 1043 (I 0.ü1 3 2 2.92 35 1074 0 0.01 2 2 2.93 36 1105 .0 0.01 ~2 2.92 37 1136 Jl 0.01 I 2.93 38 1167 ill 0.01 JL 2.91 39 1199 Jl 0.01 2 2.95 40 1230 Jl 0.00 2 2.93 41 1260 0 0.01 ;; 2.95 42 1292 0 0.01 4 2 2.94 43 1324 0 0.01 .2 J 2.94 44 1355 J 0.01 .3 ¡ 2.95 45 1386 (I 0.03 12 2 2.94 46 1416 (I 0.ü1 2 I 2.93 47 1447 (I 0.ü1 3 1 2.94 48 1479 ( 0.01 3 2 2.91 Body Meta! Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall, NominaII.D.: 3.5 in 9.3 ppf )-55 BTC 0.254 in 0.254 in 2.992 in Well, Field: Company: Country: Survey Date: 1 F-O 7 Kuparuk ConocoPhillips Alaska, Inc. USA October 7, 2006 Joint Je Depth Pen. Pe1;- Ivlelal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (I (Ins.) (Ins.) 0 50 100 49 1511 n 0.01 ) ) 2.94 50 1542 n 0.00 ) ) 2.94 51 1573 h 0.01 ) ) 2.93 52 1604 I) 0.01 1 2.94 53 1635 n 0.01 ! 2.95 54 1664 () 0.01 ;> 2.91 55 1694 I,) 0.01 I 2.94 56 1725 I) 0.01 4 2.93 57 1756 0.01 5 ;; 2.91 58 1788 0.01 2 2.90 59 1818 iT 0.00 ) 2.94 59.1 1849 n 0.00 I 2.93 PUP 59.2 1852 n 0 n I 2.81 SSSV 60 1866 I) 0.00 2.92 61 1898 I) 0.03 10 ¡ 2.89 61.1 1929 I,) 0 I I) N/A GLM 1 (latch @ 9:00\ , 62 1937 I,) 0.01 ;; 2.92 63 1967 I) 0.01 2.93 64 1999 n 0.01 ) 2.92 65 2029 n 0.01 4 2.92 66 2061 I 0.01 It 2.94 67 2092 n 0.01 2.88 68 2123 () 0.01 2.92 69 2154 0 0.01 2.93 70 2184 n 0.01 2.90 71 2215 () 0.01 5 2.93 72 2246 n 0.01 2.94 73 2277 I) 0.01 2.94 74 2309 I 0.01 2.94 75 2340 ( 0.01 ;; 2.94 76 2369 0.00 ;; 2.93 77 2399 0.01 ;; 2.94 78 2431 0.01 2.92 79 2459 iT 0.01 2.94 80 2491 iT 0.01 2.94 81 2522 n 0.01 4 2.93 82 2553 n 0.01 2.93 83 2584 0.01 2.95 84 2615 0.01 ;; 2.92 85 2645 0.01 ;; 2.92 86 2676 0.01 2 2.92 87 2707 I) 0.01 4 2 2.94 88 2737 I) 0.01 I 2.93 89 2768 n 0.01 ¿ ;; 2.93 90 2799 I) 0.01 I I 2.92 91 2830 () 0.00 ;; 2.94 92 2861 n 0.01 ) 2.93 93 2892 Íì 0.01 5- 2 2.93 94 2923 () 0.02 i) 2 2.93 95 2955 0 0.01 ¡ ;; 2.94 Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf J-55 BTC 0.254 in 0.254 in 2.992 in Well: Field: Company, Country: Survey Date: 1 F-07 Kuparuk ConocoPhillips Alaska, Inc. USA October 7, 2006 Joint Jt Depth Pc' ( Pen. Pen. \'\clal Min. Damage Profile No. (Ft.) Body /.D. Comments (%wall) ) (Ins.) (Ins.) 0 50 100 96 2987 0 0.01 2.90 97 3018 0 0.01 2.94 98 3050 0 0.01 ¿ 2.93 99 3080 0 0.01 2.94 100 3111 () 0.02 C) 2, 2.95 100.1 3142 0.01 ·1 J 2.97 PUP 100.2 3144 0 ( 0 NLA GlM 2Í-latch @ 11 :00) 101 3152 0.01 2 2.92 102 3182 I 0.01 ., 2.94 , 103 3213 ) 0.01 2 2.92 104 3244 0 0,01 2 2.95 105 3275 0 0.01 2.93 106 3303 _0 0.01 _2 2,91 107 3334 JL 0.01 6 2.92 108 3365 0 0.01 4 2.94 109 3396 0 0.01 2 2.94 110 3427 0 0.03 2.89 111 3458 0 0.01 2.92 112 3488 J) 0.01 .J 2.92 113 3519 _v 0.01 A 2- 2.94 114 3550 0 0.01 3 2.91 115 3581 0 0.01 2.91 116 3612 0 0.02 2,90 117 3643 0 0.01 2.94 118 3675 IJ 0.01 2.93 119 3706 ..0 0.01 2 2.89 120 3737 0.00 2 2.91 121 3768 ( 0.01 -.1.. 2.91 122 3799 ( 0.01 2.86 ì 123 3831 J 0.02 2.94 IIIÆ 124 3861 0 0.01 ( 2.94 125 3890 0 0.03 10 2 2.94 126 3922 0 (Wl j 2.93 127 3952 0.00 2 2 2.91 128 3984 JL 0.01 2 2.90 129 4015 J2 0.01 2.94 130 4046 0 0.01 2.94 131 4077 0 0.01 2.92 132 4108 0 0.01 2.93 133 4139 0 0.01 2 2.92 134 4171 Jl 0.01 J2 2.89 135 4202 IL 0.01 J 2 2.91 136 4234 0 0.00 2.94 137 4264 0 0.01 2.91 138 4294 0 0.01 2.93 138.1 4325 01 0 I N/A GlM 3 (latch @ 2:00) 139 4332 J) 0.01 2.89 140 4362 _lI 0.00 2.94 141 4393 0 0.03 10 2.93 11I1 142 4424 0 0.01 2 ) 2.88 Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe, Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf J-55 BTC 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 F-07 Kuparuk ConocoPhìllips Alaska, Ine. USA October 7, 2006 Joint Jt. Depth Pen Pen. !\lelal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) ) (Ins.) (Ins.) 0 50 100 143 4456 0 0.01 2 2.89 144 4486 0 0.01 ) 2 2.93 145 4518 0 0.03 2 I 2.92 Shallow QittinQ. 146 4548 0 0.01 2 2.92 147 4579 () 0.02 B 2 2.92 148 4609 () 0.01 2 2.93 149 4640 () 0.02 2 2.89 150 4671 () 0.01 2 2.90 151 4702 0 0.01 2 2.92 152 4733 () 0.02 } 3 2.87 153 4765 0 0.01 4 2 2,90 154 4793 0.01 2.93 155 4824 0.01 2.94 156 4856 0.01 2.91 157 4886 1 0.03 12 2.93 158 4919 0 om 4 2.93 159 4949 0 0.03 II 2 2.89 160 4980 ( 0.01 4 2 2.94 161 5009 0 om ) 2 2.89 162 5041 0 0.01 t; 2 2.92 163 5072 0 0.01 2 2.93 164 5103 ( 0.03 10 2 2.91 165 5135 0 0,01 2.92 166 5164 0 0.02 2.90 167 5194 0 0.02 2.92 168 5225 0 0.01 4 2.93 169 5255 0 0.01 2.91 170 5285 0 OJ)l I 2.91 171 5314 U 0.01 2 2.94 172 5345 0 0.01 3 2.90 173 5375 0 0.01 I 2.89 174 5406 ( 0.01 2 2.87 ! 175 5436 () 0.02 2.89 175.1 5467 0 0 N/A GlM 4 (latch @ 6:001 176 5476 0.03 .¡ ^j 2.89 177 5505 0.02 9 2.91 178 5536 I om 12 2 2.89 179 5566 0 0.01 3 0 2.89 180 5596 0 0.ü2 9 ) 2.90 181 5629 0 0.01 2 I 2.93 182 5659 0 0.04 1 ¿) 0 2.91 Shallow nittimz. 111'1 183 5691 0 0.01 0 2.90 184 5722 0 0.01 2 2.93 185 5753 U 0.01 2 2.91 186 5784 0 0.02 ( ( 2.92 187 5815 0 0.02 2 2.90 188 5847 0 0.ü2 2.90 189 5877 0 0.01 5 2.91 II 190 5909 0 0.03 12 ( 2.88 II 191 5939 0 0.02 9 2.90 Body Metal Loss Body Page 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION S EIT Pipe: Body Wall: Upset Wall, Nominal 1.0.: 3.5 in 9.3 ppf J-55 BTC 0.254 in 0.254 in 2.992 in Well: Field: Company, Country: Survey Date: 1 F-O 7 Kuparuk ConocoPhillips Alaska, Ine. USA October 7, 2006 Joint Jt. Depth p¿, Pen. Pen. I '\if,tal Min. Damage Profile No. (Ft.) I Body I 1.0. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 192 5970 0 0.01 4 2.92 . 193 6001 0 om 5 I 2.90 194 6032 0.02 '! 2.89 11%1 195 6064 j 0.02 (( ) 2.90 Lt. Dcr>osits. 196 6094 0.01 I 2.91 197 6125 0.03 10 2 2.88 110 198 6155 om '( I 2.93 199 6186 0 0.02 '! 0 2.88 200 6218 0 0.02 6 I 2.93 201 6246 0 0.01 . 2.90 I 202 6278 (1 0.02 3 2.87 r 202.1 6309 JJ 0 0 N.LA GlM 5iLatch @ 2:0m 203 6316 º- 0.04 I 2.90 Shallow Ditting. '" 204 6348 º- 0.02 I 2.92 205 6382 0 0.03 J 4 2.87 206 6408 0 0.02 ¡ 2.92 207 6439 0 0.01 ;2 2- 2.89 208 6469 0 0.02 î 2.93 209 6499 (} 0,01 2 2.92 210 6530 J) 0.01 I 2.92 211 6564 0 0.01 2 2.92 212 6594 Jl 0.01 2 2.94 213 6625 0.01 2.92 214 6657 0.01 3 2.92 215 6689 I 0.01 ( 2.92 216 6719 0.00 2.90 217 6751 0.03 ~2 2.90 218 6782 0.01 2.88 219 6813 I 0,02 q 2 2.91 220 6842 0 0.03 12 3 2.89 221 6873 0 0.01 I 2.87 222 6905 0.01 3 2.90 223 6934 0.03 Q 2.90 223.1 6966 0 N.LA GlM 6jlatch @ 9:00) 223.2 6975 0.01 2.92 PUP 224 6977 0 0.02 2 2.88 !" 224.1 7008 ( 0 0 2.81 X Nipple 224.2 7009 ( 0 0 0 N/A SBR 224.3 7034 ( 0 J) 4.00 RH PACKER 225 7040 ( 0.02 9 ¿ 2,90 225.1 7071 J 0 J1 NLA Production Mandrel 7 (Latch @ 3:001 226 7077 J. 0.00 2.89 227 7109 J 0.02 9 2.91 I'" 227.1 7139 Jl 0 0 0 N.LA Production Mandrel 8 (Latch @ 10:00) 228 7148 0 0.01 4 I 2.90 Blast It. 229 7175 0.02 9 2.95 Blast jt. 230 7205 L 0.00 2.93 BlasUt. 231 7235 ) 0.01 2.95 Blastjt. 232 7265 0.01 2.91 Blast It. 232.1 7295 0 0.02 ( 2 2.85 PUP Lt. Deposits. Body Meta! Loss Body Page 5 I I Pipe: Body Wall: Upset Wall: NominaIID.: I I Joint Jt. Depth No. (Ft.) 232.2 7299 232.3 7308 232.4 7317 232.5 7328 232.6 7335 232.7 7337 232.8 7338 I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf J-55 BTe 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 1 F-07 Kuparuk ConocoPhiilips Alaska, Ine. USA October 7, 2006 Comments Production Mandrel 9 PUP WD PACKER PUP XNS Ni Ie PUP END OF LOG Page 6 Damage Profile (%wall) o 50 100 Body Metal Loss Body I I I SSSV (1863-1864, 00:3.500) I I I I I SBR (7013-7014, 00'3"500) I PKR (7039-7040, 00,6" 156) I I (7149-7151) I I Perf ~ (7184-7244) Perf (7255-7260) -- Perf = (7268-7282) -- I I I PKR (7320-7321, 00'6.156) (7330-7332) I TUBING (0-7338, 00:3.500, 102992) (7366-7368) I Perf (7393-7405) I Perf (7420-7446) Perf (7453-7458) I (7573-7574) I I I -- - -- - -". - -- - = - - I '- :;:: -= -- 11 F.01 API: 500292083000 SSSV Tvoe: TRDP Annular Fluid: KRU 1 F-07 Well Ty"e: PROD Oria Camoletian: 10121/1982 LastWIO, 9/1011984 Anale ill) TS: 34 daa ill) 7183 Analeill)TD:33d~iII)8060 Rav Reason, Tag Fill, GL In I Droarass Last UDdate: 912312006 1 1941 1914 Otis Oval D' 2 3153 2901 Otis Oval D' 3 4335 3792 Otis Oval D' 4 5474 4689 Otis Oval D' 5 6285 5275 Otis Oval 0' 6 6979 5816 Otis 'H. P. Round' ~ND Man Mfr Man Type V Mfr V Type V OD latch 7 I 70761 5895 Otis Oval D' 8 71441 5951 Otis Oval 0' ~~:.)~ DeDth TVD Tyoe Descriotioo 1863 1843 SSSV Otis 'QLS' wI 'X' NiDDle Profile on TaD 7013 5843 SElR Otis w/'X' NiDDle Profile 7039 5865 PKR Otis 'RH' RETR. Hyd. set 7320 6097 PKR Otis 'WD' PERM. .7332 6107 NIP Otis 'XNS' Nioole NO GO 6111 SOS Otis 6112 TTI Depth I Description I 7585 Vann Gun Downhole Reference Loa: Ie g La;t :a¡¡: , 7493' RKB , DescriotÎon CONDUCTOR ~,-' ~ ' "'" S...., 7184 - 7244 5984 - 6034 7255 - 7260 6043 - 6047 7268 - 7282 6054 - 6065 7393 - 7405 6157 - 6167 ~1~~~~ interval Date 7573 - 7574 10/1311982 7330 - 7332 10/15/1982 7149 - 7151 10/16/1982 7366 - 7368 9/6/1984 ~IFRAC ~Man Type VMfr Max Size 16.000 10.750 .000 lone C-4 UNIT B UNITB A-5 A-4 A-4 Type I - "- I Ref Loc Date: TD: 8060 flKB ¡ da¡;¡ iI1J 5700 Too Bottom ND Wt Grade Thread 0 80 80 65.00 H-40 0 2259 2189 45.50 K-55 0 8038 6699 26"00 K-55 I ND I wt I Grade I Thread I 6112 9.30 I J-55 I BTC Ft SPF I Date Type Comment 60 24 I 9/111984 RPERF 5" Dk 90 de¡¡ Dh 5 24 1_9/1/1984 RPERF 5" Dk 90 daa ph 14 24 RPERF 5" DA' 90 daa on 12 12 5" Vann cuns 26 12 5" Vann cuns 5 12 Comment Used for 7" PrimarY Cement Job V Type VOD latch Port TRO Data VI v Run Cmnt 0.000 0 5/15/2001 0.000 0 912012006 0.000 0 9/19/2000 0.000 0 9/21/2006 0.000 0 9/19/2000 0.188 0 10/2112000 DMY DMY DMY DMY DMY OV 1.0 1.0 1.0 1.0 1.0 1.5 BK BK BK BK BK RM Port DMY CV DMY 0,000 0.000 0"000 TRO Date Run o I 1/412005 g~ Vlv Cmnt 1.0 1.0 1.0 BK BK ElK ID 2.813 2.813 4.000 4.000 2.750 2.992 2.992 Comment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: - 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 115 feet 3, Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 1331' FNL, 27' FWL, Sec. 20, T11 N, R10E, UM (asp's 540007, 5958198) 1F-07 At top of productive interval 9. Permit number / approval number 1895' FNL, 1842' FEL, Sec. 20, T11 N, R10E, UM (asp's 543421, 5957654) 182-156 At effective depth 10. APl number 50-029-20830 At total depth 11. Field / Pool 2036' FNL, 1383' FEL, Sec. 20, T11 N, R10E, UM (asp's 543881, 5957515) Kuparuk Oil Pool 12, Present well condition summary Total depth: measured 8060 feet Plugs (measured) Tagged Fill (10/14/00) @ 7412' MD. true vertical 6717 feet Effective depth: measured 7412 feet Junk (measured) true vertical 6173 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 295 Sx AS II 80' 80' SURF CASING 2144' 10-3/4" 1000 Sx Fondu, & 250 2259' 2189' Sx PFC PROD CASING 7923' 7" 450 Sx G & 250 Sx PFC 8038' 6699' Perforation depth: measured 7184 - 7244'; 7255 - 7260'; 7268 - 7282'; 7393 - 7405'; 7420 - 7446'; 7453 - 7458' true vertical 5984 - 6034'; 6043 - 6047'; 6054 - 6065'; 6157 - 6167'; 6180 - 6202'; 6208 - 6212' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55, Tubing @ 7338' MD. Packers &SSSV (type& measured depth) Otis'RH' Retr Packer (Hyd set)@ 7039' MD; Otis'WD' Perm Pac~eer~2~l~.~u. Otis 'QLS' w/'X' Nipple Profile on top @ 1863' MD. 13. Stimulation or cement squeeze summary F' Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. CommissJol3 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 305 306 117 164 Subsequent to operation 844 748 521 172 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __X Gas __ Suspended m Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~~L--- ~~.~ Title: Prepared by John Peirce 265-6471~..~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICA~~~~ '1F-07 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 9/18/00: RIH & tagged PBTD at 7486' MD. 9/21/00: MIRU & PT equipment. Pumped Gelled Sand Slurry containing 2750 lbs of 20/40 mesh sand, to place an isolation sand plug across the lower 'A' sand perforation intervals located at: 7393 - 74O5' MD 7420 - 7446' MD 7453 - 7458' MD 9/22/00: RIH & tagged top of sand plug at 7364' MD. 9/23/00: MIRU & PT equipment. Pumped a 'C' Sand Hydraulic Fracture Treatment using 16/20 & 12/18 mesh proppant, through the open perforation intervals located above the sand plug at: 7184-7244' MD 7255-7260' MD 7268- 7282' MD Pumped Breakdown: a) 250 bbls 20# Linear Gel @ 28 bpm, followed by b) Shutdown. ISIP @ 2156. Resumed pumping Scour Stage: c) 100 bbls Pad, followed by d) 50 bbls Crosslinked Gel w/lppa proppant, followed by e) 96 bbls Flush @ 15 bpm, followed by f) Shutdown. ISIP @ 2102. Resumed pumping Data Frac: g) 100 bbls 50# Crosslinked Gel, followed by h) 63 bbls Flush, followed by i) Shutdown. ISIP @ 2365. Resumed pumping Frac Treatment: RECE/t,,ED FEB Alaska 0il & Gas Cons. Anchorage C°rn~ission j) 230 bbls Crosslinked Pad, followed by k) Crosslinked Slurry stages w/proppant ramped up in stages from I to 10 ppa, followed by I) 230 bbls Flush, followed by m) Shutdown. Placed a total of 85,300 lbs of proppant into the formation. RD. 9/26/00: Performed a CT proppant / sand plug fill cleanout to 7360' MD. RECEIVED 10/14/00: RIH & tagged fill at 7412' MD. Returned the well to production w/gas lift & obtained a valid well test. FEB 1 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging , Perforate _ Repair well Pull tubing Other 2. Name of Operator AR(;;O Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory ... Stratigraphic _ Service _ 4. Location of well at surface 1331' FNL, 27' FWL, Sec. 20, T11N, R10E, UM At top of productive interval 1895' FNL, 1842' FEL, Sec. 20, T11N, R10E, UM At effective depth 1995' FNL, 1440' FEL, Sec. 20, T11N, R10E, UM At total depth 2036' FNL, 1383' FEL, Sec. 20~.T11N, RI.0E~ UM 12. Present well condition summary Total Depth: measured 8 0 6 0' feet true vertical 6717' feet Plugs (measured) None 6. Datum elevation (DF or KB) RKB 115 7. Unit or Property name Kuparuk River Unit foot 8. Well number 1F-7 9. Permit number/approval number #82-156 10. APl number 50-029-20830 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 9 4 2' feet true vertical 6617' feet Junk (measured) Vann Gunn @ 7583' MD Casing Length Structural Conductor 80' Surface 2 2 5 9' Production 8 0 3 8' Liner Perforation depth: measured 7184'-7244', 7255'-7260', true vertical 5983'-6033', 6043'-6047', Measured depth True vertical depth 80' MD 80' TVD 2259' MD 2188' TVD 8038' MD 6698' TVD Size Cemented 16" 295SXAS II 10/3/4" 1000 Sx Fondu & 7" 450 Sx Class "G" & 250 Sx Permafrost C 7268'-7782', 7393'-7405', 7420'-7446', 7453'-7458' MD 6053'-6065', 6157'-6167', 61 80'-6200', 6206-6211' TVD Tubing (size, grade, and measured depth) 3 1/2" J-55 tbg w/tail @ 7327' MD Packers and SSSV (type and measured depth) Otis WD pkr ~ 7312'; Otis pkr ~ 7028'; Otis QL.S SSSV.~ 1852' MD 13. Stimulation or cement squeeze summary Refracture 'A' Sand RECEIVED 14. 'JAN 1 4 1991 Intervals treated (measured) ~~'~ 'A' sand from 7393' to 7458' MD RKB Treatment description including volumes used and final pressure . '" Refracture 'A' sand with 80M lbs. 12/18 Carbolite proppant and gelled water~ FWHTP=5400 psi . Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation , Subsequent to operation 700 400 0 900 190 1900 1300 0 1400 190 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X, Gas Suspended Service 17. I herqtl~ certify..[that the foregoing is true and correct to the best of my knowledge. Signed Ir ,h~..%,-.x.:),.... __¥,, , Title Sr. Operations Engineer Form 10-404 Rev 06/15/88 Date 1/7/90 SUBMIT IN DUPLICATE ' ~RCO, Alaska, Inc,~'~ Subsidiary o Atlantic Richfield Company WELL SERVICE REPORT WELL CONTRACTOR REMARKS IPBDT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME ~o ,-,-, pL ....+ ~. · IDAYS I DATE CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ,, REMARKS CONTINUED: ¢:::)~, w', p ¢ cL. DESC RI PTION DAILY ACCU M. TOTAL cAMCo OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL ' HALLIBURTON ' ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFE TOTAL FIELD ESTIMATE I 1. Type of Request: 2. Name of Operator STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION /7 · REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown .. Stimulate ~( . Plugging Perforate _ ~ Pull tubing Alter casing Repair well Pull tubing Other__ ~ ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1331' FNL, 27' FWL, Sec. 20, T11N, R10E, UM At top of productive interval 1895' FNL, 1842' FEL, Sec. 20, Tll At effective depth 1995' FNL, 1440' FEL, Sec. 20, Tll At total depth 2036' FNL, 1383' FEL, Sec. 20, Tll Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 12. N, R10E, UM N, R10E, UM N, R10E, UM 6. Datum elevation (DF or KB) RKB 115 7. Unit or Property name Kuparuk River Unit 8 0 6 0' feet 6 71 7' feet Casing Length Structural Conductor 80' Surface 2 2 5 9' Intermediate Production 8 0 3 8' Liner Perforation depth: measured 7184'-7244', 7255'-7260', true vertical 5983'-6033', 6043'-6047', 8. Well number 1F-7 9. Permit number/approval number #82-156/8-1 80 10. APl number so-029-20830 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None feet Junk (measured) Vann Gunn @ 7583' MD 7942' feet 6 61 7' feet Measured depth True vertical depth Size 80' MD 80' TVD 2259' MD 2188' TVD Cemented 1 6" 295 Sx AS II 10/3/4" 1000 Sx Fondu & 250 Sx Permafrost C 7" 450 Sx Class "G" & 250 Sx Permafrost C 8038' MD 6698' TVD 7268'-7782', 7393'-7405', 7420'-7446', 7453'-7458' MD 6053'-6065', 6157'-6167', 6180'-6200', 6206-6211' TVD Tubing (size, grade, and measured depth) 3 1/2" J-55 tbg w/tail @ 7327' MD Packers and SSSV (type and measured depth) Otis WD pkr @ 7312'; Otis pkr @ 7028'; Otis QLS SSSV ~ 1852' MD.~. r 13. Stimulation or cement squeeze summary Refer to Well Service Report Intervals treated (measured) Refer to Well Service Report Treatment description including volumes used and final pressure Refer to Well Service Report Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 700 500 0 1250 150 Subsequent to operation 850 600 0 1300 160 16. Status of well classification as: 14. Oil X Gas Suspended Service Date 9/1 8/88 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and cor~ct to the best of my knowledge. Signed ~ ~ ~f~ ,~,~,~~~'~ ~ Title Sr. Operations Engineer Form 10-404 R~; 06/15/88 WELL ARCO Alaska, Subsidiary of Atlantic Richfield Compa( /f -7 WELL SERVICE REPORT £s ~. d.~, s ~ /P q 7 y/. / 2, 155f - /y49 - /gpo- /7.~ - / CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, In~_~~ Sul:~si~lia~ of Atlantic Richfield Company WELL IF'- ? J ,ON]'F~CTOR .o REMARKS WELL SERVICE REPORT [:::] BLOCK IF BACK CHECK THIS J // _ ,, SUMMARY CONTINUED ON w..,,_ 1"'~ ,1-':!''''''~, .,,-I-v' -.~~,(-n' ' ARCO Alaska, Inc~'~ Subsidiary of Atlantic Ricl~fielcl Comoany WELL 'ONTRACTOR REMARKS IAz% .~ PP~x ;:PBDT 1F'IELD'- DISTRICT. STATE 1OPERATION AT REPORT TIME WELL SERVICE REPORT ID^Y/S _ l~] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W"thIr IT'mp' I Chtll FI'"t ! Vl'ibllity IWInd V'l'Report 'For, --F mil. ARCO Alaska, Inc. Date: August 12, 1988 Transmittal #: 7257 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. 3 ! - 1 2 Kuparuk Well Pressure Report 6 - 1 5 - 8 8 Amerada 1 G-04 Kuparuk Well Pressure Report 7- 1 6 - 8 8 Amerada 2T-06 Post Frac Job Report 7-1 8-88 AIIo Frac A-10 3Q-15 Kuparuk Stimulation Summary 8-07-88 #230DS36QL 3J-10 kuparuk Stimulaiton Summary 8-08-88 #230DS36JL 2V-11 Kuparuk Stimulation Summary 8-03-88 #230DS28VL I R - 1 5 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Tubing I F - 07 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing 2 D - 1 3 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil STATE OF ALASKA ?'" ALAS,.., OIL AND GAS CONSERVATION COMI,,,,6SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address ... PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 1331' FNL, 27' FWL, Sec 20 T11N RIOE UM At top of procluctive interval ' ~ ' ~ 1895' FNL, 1842' FEL, Sec.20, T11N, R10E, UM At effective depth 1995' FNL, 1440' FEL, Sec.20, T11N, R10E, UM At total depth 2036' FNL, 1383' FEL. Sec.20: T11N: RIOE. UN 11. Present well condition summary Total depth: measured 8060' MD feet true vertical 6717' TVD feet 5. Datum elevation (DF or KB) RKB 115 feet 6. Unit or Property name Kuparuk River Unit 7. Well number 1F-7 8. Permit number Permit #82-156 9. APl number 50-- 029-20830 10. Pool ~uparuk River Oil Pool Plugs (measured)None Effective depth: measured 7942' MD feet true vertical feet 6617' TVD Casing xxx~o~l~xxxx Conductor Surface XXX;IC~R~n~Rte Production xxxk-Jae xxxx Perforation depth: Junk (measured)vann Gunn @ 7583' MD Length Size Cemented Measured depth True Vertical depth 80' 16" 295 SX ASII 80' MD 80' TVD 10-3/4" 1000 SX FONDU & 2259' MD 2188' TVD 250 SX PERMAFROST C 2259' 8038' 7" 450 SX Class G 8038' MD 6698' & 250 SX PERMAFROST C measured 7184'-7244', 7255'-7260', 7268'-7282', 7393'-7405' MD 7420' -7446', 7453' -7458' MD truevertica15983,_6033, 6043'-6047' 6053'-6065' 6157'-6167' TVD 6180'-6200', 6206'-6211' TVD TVD Tubing (size, grade and measured depth) 3½" J-55 tbg w/tail @ 7327' MD Packers and SSSV (type and measured depth) OTIS WD peg @ 7.~12'. {3TTR nun @ 7078'; OT_~S QLS SSSV ~ 1852' MD 12.Attachments DescriPtiOn s~um~rnary of proposal [] Detailed operations program [] Pump 5380 qallons MUSOL Diesel/Acid Stimulation 13. Estimated date for commencing operation March, 1988 BOP sketch [] R .Lt:t cu 14. If proposal was verbally approved Work Beported on Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge S,,ned Sr. Operations Engineer Commission Use Only approval [] Plug integrity [] BOP Test [] Location clear~anq, eJ Approval Conditions of Notify commission so representative may witness J No. Approved by 0RI6INAL SI~NED BY ·-,,'"" C. SMITH Form 10-403 Rev 12-1-85 R urned <9 ~ -?~ - ~oby order of Corffmissinn~x-- the commission Date 0.~ '"/~.~'"- ~:~ ~ ~_~.~ Submit in triplicate Well 1F-07 General Description Well 1F-07 is currently a combined A and C Sand oil producer. Proposed downhole stimulation work will reduce near wellbore damage to increase well productivity. Both the A and C Sands will be treated separately by isolating the A Sand with a blanking plug or running dummy valves across the C Sands. The downhole work will be performed with a Slickline unit. A 5000 psi Slickline BOP and lubricator will be used during all stages of wireline downhole work. The proposed musol diesel work will utilize a pump truck and surface lines to displace musol diesel across the A and C Sand perforations. The sudace lines will be pressure tested to 4000 psi against the 5000 psi tree valves. Should the results of the musol diesel treatments not show desired rate increases, then the subject sands will be stimulated by either acid(C Sands) or re-frac(A Sands). Static bottomhole pressures from a wellhead pressure and fluid level indicate BHP of 2800 psig in the A Sand and 3000 psig in the C Sand. 1. MIRU Slickline. Pressure test lubricator, 2. Isolate A Sands with blanking plug in tubing below the C Sands. 3. RDMO Slickline. 4. MIRU pump truck and transports. Pressure test equipment. 5. Pump 1896 gallons musol diesel and displace with 65 barrels diesel. Surface injection pressure should remain below 3500 psi. 6. Allow to soak for I hour. 7. RDMO pump truck and transports. 8. MIRU Siickline. Pressure test lubricator. 9. Pull blanking plug and then pull C Sand circulating valves and run dummy valves. 10.RDMO Slickline. 11.MIRU pump truck and transports. Pressure test equipment. 12.Pump 3484 gallons musol diesel and displace with 63 barrels diesel. Surface injection pressure should remain below 3500 psi. 13. Allow to soak for 1 hour. 14.RDMO pump truck and transports. ARCO Alaska Inc. is a subsldia~/of Atlantic Richfield Cornpany AR3B-6001-A Attachment Page g · Drill Site 1H Well No. ~1H-3 ~'lH-4 .,~,f. ~lH-7 ~1H-8 Log Date 8/16/82 8113/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E Drill Site 1G Wel 1 No. %G-~ ~'~1G-3 ~1G-4 ' X, aG-5 %1G-8 L..Og Date 9/7/82 ' 9/25/82~ 9128/82 12/8/84~ 10/13/82 11/12/82 3/12/83 1/22/83 Dri 11 Si te Wel 1 No. Log Date 1F' IF-1 1F-2 '"'1F-3 '"1F-4 %1F-5 ",,1F-6 "~1F-7 2119/83 213183 1/31/83 5129/83 10/25/82 10128182' 11/1g/82x~ ~ 5/7/83~9 ~ ~1~' FEB 2 1 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska. in,'~'h POSl Olfice i~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: TkAL~$blITTAL NU }<L'£ U t11~ TO: AHCL) ALA:3Ka, INC. KUPARUK UPEkATIOI~S ENGINEerING R]ZCORD5 CLERK ATO- 111513 P.O. bOX 100360 ANCI~OkAGIJ, ~K 99510 11EREWITA~ ~kHU TIiU FOLLOWING ITt2~IS. PLEASE RETUi~ ON~ SIGNLD COPY OF THIS TRANSMITTAL. EVENTS RE DATA 4/27/85 ]{]3 DATA 3/ 8/85 1F-4 PRESSURE 1F-7 PRESSURE 1F-5 PRLSSUKIJ IF-7 i1.'-3 1E-11 EH-11 DATA 1/22/85 DATA 1/22/85 DATA 1/21/85 DATA - 4/21/85 DATA 4/21/85 DATA 4/21/85 DATA- A bAND P~3U 3/ 8/85 DATA- FALLOFF C bAND 5/ 7/85 DATA' 4/27/85 DATA - A SAND PBU 3/ ~/B5 - PBS CO[,1CINED 1/30/~5 5234A ACKNOWLI~DGiJ CEIPT ACKNO~LEDGLD: DR ILLING L. JOIINSTL)N i,iOi31 L" Nbk (JLEIiK LXXON PHILLIPS OIL ~ J. kATtlMELL/, STATE O£" kLASKAx. SOI{IO ~ UNION ~- K. TULIN/VAULT ARCO Alaska, Inc. Post Office Bdx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I) A T lie · 0 "5 .... '1.5 .-.- 85 '¥ F:: A N S Iq I 'f' T A L l'.~ (3 ·..,'::' t o" ,., ~- A'T' T N: F' E7 C 0 R I) S C I... Iii: F: K A '1" O -" 1 t t '.5 I::',[1, BOX i00360 A N C I"10 R A C E, *'.%. I( 9 9'.5 i O 'f' F;: A N S' i"t :17 T T Iii: D H IZ I:;: E t,J ]7 T H A 1:;: Ii!: 'T I'1 Iii: F' O 1... 1... [:J W ]: i',~ (; F;,' IE [2 E I F' T ¢, N I) I:;: I::' T [J 1:;: N · (] N 157. .? :[ [.~ N Iii: I3, [:] (] 1::' Y (] F :l:'i'E:H.'.i', F: I...IEA,'.i'I'] At]l< NOWI...liiil)61E T H I ;.? 'f' I:;: A N S I't :1: T T A I.., W.? 1::: / S E (~ U E: i"~ C li'~ (3 I::' li!: V E N'f' S 2(]--. 1 4 ;..!(:; .... t 4 F;: U N L. Y N EX ,? F;; Ii: C (:)I:;11) E I:;:,!.~' I:;: Ii;: ]' IR :1: E V li-~ 1... Y N Iii: ,'!? I:;: l!i: C. (] I:;: ):) li~. F;: :g' I... Y i",{ ['~ ."¢ I::: I:;; I:": ,'.~' 3' L.I I:;: I:!: I{',' (21 i'J l{; S '"' F:' ,S B H I::' ' C ' ~','-'-i N ]0 'C' .YAND,5.' ONI_Y I::'I{':U ' C ' ,~AND I::'I-'.",U T A (~. F:' ]; L.. L/',S' Ii4 t'1 f':' 'TAG F"IT. LL.,/SBHF:' ' A' ,S'AN)},S' ~';' I'.": H F' .5; B 1"1F:' F:' A L. L (3 F:' F:' '1' E 5:'i" F:' ;.5-L I... [) F: F"' 'f' E,:-;'T' .? I~': I"I F:' 17_' / I._ I N Ii"' ,.'5.? F' I N / '1" C L. ,? U F;: VIE Y I... Eil A I< l.) E ]' I:"I C T I 0 N "C ' ,?? A N I) 04 .... 2 !5 .... .:::,'"".5 04-2t .... 85 I'-" )?: U F:' E: t.) I':.: U N 'f' (1. I:;.: (;~ U Iii; 'f' t..I I:i: i'.! / ,-r', ?'i E F;: A I) A,57 F:' Ii': t.J -I::' L.I I... 1.. T [)I:;~ (] t.J Ei; "f' t.J F;: N / A 7i Iii: F;: A l) A B. [1 t-"i I-) ,.,v j:;; I..J i",} ')" ()I"'< (:~ t.J Ii" T U I:~: N / A H Ii'.-. IR A D A ,'.'7 F:' I') tJ .... I::' t.J i... t_ T O I:;~ (;! U I']; "J' U I:;: N ,/ *' .... , A '"'1 A -Art :: I'.,mI, ~.., z. D --- ''~ I:,: U N 'F O F;: 6) U Ii'.'. T U '^:.-'. I) .... t O I:;: t.J i'-I -I" O I:;: {~ LI lie 'l' U 1:;: iq / ¢;', H 2 l>'- t 0 F' I-7: U--- F' U I.. L. T 0 I:;.: (.:'~ t.J Ii!: 'r t.J F,: i'-,{ / · · ..... , -~ "}. ¢-, ,-"h d I::. I',, ~'-, l.. A I:J 0 H I'}: 2 F: '"' ,'5 F:' I':4 t.J ,:.'"' ,ct .... ,.,c:' F' I{: t.J ~...I ..... d F' Bt.J 2 F' '-'- t t I::' i-;: t.j 2 F:' '--' t t F' ][i~ t..I "~ r' .... 1 ~:' I)t.J ,.) .. ,._ (.,- '--' 1 F:' ii',' U 2 (I,; '-' ~ F:' B 2 (;. ---p, F:' B U O'T I S [) F I ,'.';' C A iq (3 C A hi C [:; A i'i C, C A i"l C (] A i't C 0 C A i't C (3 [) T :[ 5.' C; :::': i'"i C (.': A H C i] ]' I ,~' 0'~"I ,:? C A i'i C O C A i'5 C 0 : BAI< El:;: I'?' A I( IZ F;: / 7' 0 Ii: (i,~ U 1![ ]'U I:;: N [)'l" I S !;: ('.': l< E I:;: / T [)I:;: (~ t.J lie '1" LJ 1:;: N B A l< E: I:;: [-: A I:: E: I:;,'/"1" O F;: (;~ LJ I"" l].[j l:~ N (]'f' :[ S C; A i'l C (] .-.--"-"'7. ,. - C A }"1 C (:} ~ 5-4- (.'; A ?"1C (3 OT T ..'5;' /,:;,. .... .,,, ;,. I) R T liil: ............................ '×' S T 1'4 T r....' {:.IF ~,~.,5; (] I-1 ]I (3 3(. t.j N ]I (] N I( ,, ]' U L. I N / V A U L. T ARCO Alaska, Inc,f''''' Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 D A TIE ' 0 5 -- 1.., "=' .... o"~ ':7 TF;:AN.S'ifilTTAI_ N0 ' 5t 84 1:;: EF.'T' U R N 'T' 0 ' T I:;: A i'j..%' i~i I T 'I' lie I) R E'" C El I r:' T A N I) I:;:[il l" U R N Ii.". C OI::'Y I.. 5'lii:T 74 '76 747 6 8~300 8~300 84 ~ '5 · ;' ~-.. ,:~ 8 <;>, ~-..'" 8 8. 6 1 ':":- ..) .b '70 7 5 ; 0'? 5 73~ 2 .. 6701 670 i 01:: EACH.) I) Iii: F:' l" I"1 l' 0 0 I... "" 1~' t 72'2 i $0''~ t ':i t '') i '7..'~ 4 tvt:? 20 ,::52 12'.~29 i 508 i ..~ 0,3 t t .~'0 t 1:507 t '~ ;:~ t t:5t t tst7 / ?D : I~ A,. ~.: ~m~..~-~L ~/ BI::'AE-x- r;,l:~ I 1..i._ I NG W. I::'A.gHIER ' '"-~',- -~Sa;~':~:~:~,O: .ALACK A.x. B. CLJF(F:IER~ L. JOHNSTON EXXON SOHIO.x- 5as Cons. ~o~,~m:sstor, (:I..IE:VRON-x- NOB]:I_.~. i::'HII..LIF'S Oll...x. LJi'(]:ON~,:. Anc,qorage D & N~(- NSI( CLEI:;:I( J i~ATI..INEL. L..)~ I( 'T'UI..I~/,ALJI..T Alaska, Inc. Post Office x 360 Anchorage, ~,,aska 99510 Telephone 907 277 Transmittal No: 5019 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 an r~nsmitted herewith are the following items. Please acknowledge receipt return one signed copy of this transmittal. ~BU SURVEYS . Otis 1B-3 1/24/8 .... 1E-2 1/24/85 lA-4 1/20/85 2G-7 1/23/85 2V-SA 1/24/85 2Z-4 1/19/85 2Z-6 1/19/85 · SEQUENCE OF EVENTS - 2B-lO 1/21/85 PBU SUR~EYS Lynes ., . .j.×z /,~_7b/1/21/85 " #1511 /1~-8 //1/21/85 " #1508 .- /cat Receipt Acknowledged: 1/21/85 "PBU" 1/21/85 "PBU" 1/21/85 "PBU" Q ~ /~" q i ~ '7 '" 1/21/85 "PBU" Date: .' B. Currier Drilling . BPAE Geology Chevron Mobil DISTRIBUTION W. Pasher ~ G. Phillips Phillips Oil State of AK Sohio Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc. Post Office f'-'"\ 360 Anchorage,, Ska 99510 Telephone 907 ;;77 5637 RETURN TO: ARco ALASKA, INC. ATTN: Records Cler~ ATO-1115B P.O. Box 100360. Anchorage, AK 99510 Date Transmittal No: 4 9~'-~ - - - Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CAMCO- .BHP RERORT~/.~U : ,-?.ORQUE 'TURN PBU & TEMP SURVEYS ~/%F-7 12/02, 03/84 ~'4 12/12, 13/84 Gauge ~/64009 v/1G-4 12/10,11/84 /lB-3 11/26/84 / /~G-2 12108/84 ~E-8 12/12,13/84 ~lA-.6 10/21,22/84 / ~/lC-9 10/12,14/s4 /i~-~ ~0/~0,~/s~ w/iE-3 10/15/84 /2B-4 10/19/84 / 2s-3 101191s4 i ~ 1E-2 10/15/84 /cat Receipt Acknowledged: DISTRIBUTION JAN 30 RECEIVED .JAN 2 ~ --' 1985 Dat'q~k= Of; & c~as Cons. tort]mission Anchorage B. Currier Dzill~ng W. Pasher State of AK BPAE Geology' G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ope. J. Rathmell Well Files ARCO Alaska, Inc. is ~ subsidiary of AttanticRichlieldCompany ARCO Alaska, Inc. Post Office/P,~x 360 Anchorage, ,~ska 99510 Telephone 907 277 5637 Date: 1/07/85 Transmittal No: 4942 RETURN-TO:-, ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B /Box 100360 orage, AK 99510 · ed herewith are the following items. &,'and return One signed copy of this transmittal. 1F-7 ~'"--t2/02, 03/84 Please acknowledge receipt ~T.ORQUE .'TURN PBU 1F-4 ~ ...... 12/12, &. TEMP SURVEYS 13/84 Gauge ~'/64009 1G-4 ~-- 12/10,11/84 'lB-3 ~'? 11/26/84 1G-2/~ 12/08/84 1E-8/ 12/12,13/84 lA-6 ? 10/21,22/84 ~ . 1C-9./" 10/!2,14/84 -. lB-11 ..... 10/10,12/84 . 1E-3 · 10/15/84 2B-4~ 10/19/84 2B-3 / 10/19/84 1E-2"~ 10/15/84 /cat Receipt Acknowledged: B. Currier Drilling DISTRIBUTION Date: A/aska 0il & Gas Cons. Commission Anchorage W. Pasher State of AK BPAE Geology: G. Phillips Sohio Chevron Mobil Phill'ips Oil Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc, is a subsidiary o! Atlar~ticRichfieldCcmpany ARCO Alaska,. Post Office Box 100360 /~nchor~ge, /~.13~!<3 F:.?.-5'! Telephone 907 276 1215 October 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field' Well Action Date Performed 1 F-4 Fracture 9 / 1 8 / 84 ~:~.1;:~_,-. ~7 ~'~ Fracture 9/21/84 1L-1 Fracture 10/23 / 84 1L-8 Fracture 10/16/84 1Y-2 Fracture 10/9/84 1Y-2 Acidi ze 1 0/22/84 1Y-3 Fracture 10/7/84 1Y-5 Fracture 10/4/84 1Y-1 4 Fracture 1 O/6/8q 2C-4 Perforate 1 0/1 6/84 If you have any questions, please call M. ike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) me at 263-4253. RECEIVED 0C1'2 91.984 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA "'-'x ALASKA OIL AND GAS CONSERVATION bOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 1331' FNL, 27' FWL, SEC. 20, T11N, R10E, UM OTHER [] BOTTOM HOLE LOCATION' 2036' FNL, 1383' FEL, SEC. 20, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 11 5 ' (RKB) I 7. Permit No. 82-156 8. APl Number 50- 029-20830 9. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1F-7 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL 12. NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Stimulate [] Abandon [] Repair Well [] Change Plans [] Pull Tubing [] Other [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) ADL 25652, ALK 2578 pOOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data SUBSEQUENT REPORT OF: (Submit in Duplicate) Perforations [] Altering Casing Stimulation ~ Abandonment Repairs Made [] Other Pulling Tubing [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On September 21, 1984, the "A" sands of Kuparuk well 1F-7 were hydraulically fractured and propped to improve production. The treatment consisted of 298 BBLS of gelled diesel as pad, carrying fluid, and flush and 15,540 LBS of 12/20 sand as proppant. Prior to pumping, equipment and lines sand was tagged with R.~.A. tracer performance. were tested to 6000 psi. The to aid determination of job RECEIVED OCT 2 9 ]984 Alaska 0~1 & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATI ONS COORDINATOR The space below for Commission use 10/29/84 Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ' = A~CO Alaska, t./''~, Post Offic,?Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 24, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1F-7 Dear Mr. Chatterton- Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU2/L52 Enclosure If RECEIVED OCT 2 6 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~' STATE OF ALASKA ALAS;OIL AND GAS CONSERVATION iMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOCI 1. Status of Well Classification of Service Well OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE []. ... . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-156 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20830 4. Location of well at surface 9. Unit or Lease Name 1331' FNL, 27' FWL, Sec.20, T11N, RIOE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number' 1895' FNL, 1842' FEL, Sec.20, T11N, R10E, UN 1F-7 At Total Depth 11. Field and P°ol 2036' FNL, 1383' FEL, Sec.20, T11N, R10E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i I Pool 115' RKBJ ADL 25652 ALK 2578 12. Date Spuddedl 0/02/82 13. Date T.D. Reached10/11/82 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °fish°re I 16' N°' °f C°mpleti°ns '10/21/82 N/A feet MSL 1 '171 Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness o'~ Permafrost 8060'MD,6716'TVD 7942'MD,6617'TVD YES [] NO [] 1863 feet MDI 1450' (approx) 22. Type Electric or Other' Logs Run D IL/SFL/FDC/CNL/GR/SP/Cal, BHCS/GR, RFT, CCL/Gyro, CBL/VDL/GR, CBL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD ,, sETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80'P.L. 24" 295 sx AS II 10-3/4" 45.5# K-55 Surf 2259' 13-1/2" 1000 sx Fondu & 250 sx Permafrost C 7" 26~0# K-55 Surf 8038' 8-1/2" 450 sx Class G & 250 s; Permafrost C .... 24. Perforations open to Production (MD+TVD of Top arid Bottom and 25. TUBING RECORD interval, size and number) SIZE 'DEPTH SET (MD) PACKER sET (MD) 7184' -7244' 3-1/2" 7338' 7312' & 7039' 7255' - 7260' I 7268' - 7282' w/12 spf 26. ACID, FRACTURE, CEMENT SQUEEzE, ETC, 7393' - 7405' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7420, - 7446, -. 7573' - 7575' 250 sx Class Gr 7453' - 7458' 7330' - 7332' 100 sx Class 7149' - 7151' 100 sx Class 6 7366' - 7368' Z00 sx Class C , ,, 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etC.) I , Date of'Test Hours Tested pRoDucTION FOR OI L-BBL GAS-MCF WATER-B'BL CHOKE SIZE I GAS~OIL RATIO iTEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OI L-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (c°rr) Press. 24-HOUR RATE 28. COP E DATA ,, Brief desCription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED 2 Alaska 0il & Gas Cons. Commission 4,nch0ra,ge Form 10-407 GRU2/WC01 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 Upper Sand 7184' 5984' N/A Base Upper Sand 7242' 6032' Top Lower Sand 7376' 6143' Base Lower Sand 7512' 6256' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ('" ' "'" Title Area Drilling Engr. Date /0 ",/- I 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 i.n 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Form 10-407 ' Well Hiltory - Initial Report'- Dally well le ipudded or workover Ol~,ii;one ere stinted. Incluelve detee only. Diatri~t Alaska Field Kuparuk River Auth. or W.O. no. AFE 204552 - 103918 WWS #1 North Slope Borough Dr Unit ADL #25652 Title Recompletion Operator ARCO Alaska, Inc. Spudded or W.O. begun AP1 50-029'20830 l~tate Alaska IWell no. 1F-7 W/O ARCO W.I. · 56 24% IPrlor stature ti a W.O. Workover [Hour 8/31/84 0130 Hrs. Date and depth as of 8:00 a.m. 8/31/84 Complete record for each day reported 9/01/84 thru 9/04/84 9/05/84 9/06/84 The above,,~ cor(~ 7" @ 8038' 7942' PBTD, Displ well w/brine Accept rig @ 0130 hrs, 8/31/84. Pull BPV. Kill well by displ'g tbg w/40 bbl calc carbonate pill, followed w/25 bbls 8.6 ppg brine. Displ ann w/8.6 ppg brine. 7" @ 8038' 7942' PBTD, 7582' Top of Vann gun, Fsh'g Circ brine thru GLM @ 6370'. Set BPV. ND tree, NU &tst BOPE. Circ 8.8 ppg brine, well dead. Pull tbg & LD. RIH w/pkr retrv'g assy, unable to wsh to latch assy, POOH. PU mill tooth shoe, TIH to TOF, wsh 7012'-7031', CBU, POOH. RIH w/short catch OS, latch fsh @ 6999', pkr moved up hole 8', jar pkr dn 5', stuck, CBU, POOH. TIH w/OS, latch fsh @ 6995', jar on fsh. RU string shot, TIH 20' below pkr, fire shot, BO fsh, POOH, rec'd partial fsh. TIH w/OS dressed to catch 4-3/4" OD to 6973', latch onto fsh, fire string shot, POOH, rec'd slick stick. WO spear. 7" @ 8038' 7942' PBTD, 7582' Top of Vann gun, POOH w/milling assy PU spear dressed to catch 4" ID weld straps on 2-3/8" conn, RIH to TOF @ 7016', spear fsh, POH, LD spear, J-slot body, retrv'g ti & XO to pkr. TIH to top of pkr @ 7021', mill over pkr, POOH. 7" @ 8038' 7942' PBTD, 7582' Top of Vann gun, POH w/R-3 pkr PU. 3-1/8" spear, spear into pkr, jar, POH w/RH pkr & tailpipe assy. PU R-3 pkr, RIH, set pkr @ 7500', tst DP & pkr to 3000 psi; OK. POH to 7330', set pkr. Est breakdn rate @ 2800 psi/4.4 BPM, pmp 25 bbls, §or ret's. RIH to 7500', retst pkr & DP to 3000 psi; OK. POR to 7350', set pkr, pmp @ 2200 psi/2.7 BPM; §ood ret's. -POH to 7140', tst csg .to 3000 psi; OK. POH · .. w/R-3 pkr, prep to sqz.'. RECEIVED Oc:T2 E, Alaska Oil & Gas Co;~s. Commissior., ITitle For form oreDaratlon and dlstributl~,' ..... l~ 10/02/84 Drilling Superintendent ARCO Oil and Gas Company g~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. Date and depth as of 8:00 a.m. District ICountyorParish IState Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL #25652 Complete ~cord for each day while drilling or workover in progress 9/07/84 7" @ 8038' 7942' PBTD, 7582' Top of Vann gun, WOC RU Schl, tst lub to 1500 psi. RIH w/BP, set @ 7380'. RIH w/4" perf gun, perf 7366'-7368' @ 4 SPF (accum fluid loss = 292 bbls). RIH w/EZSV cmt retnr, set @ 7290', RD Schl. RIH w/stinger, sting into retnr @ 7290', M&P 200 sx C1 "G" cmt. Displ w/8 bbls NaC1 @ 1BPM. Cmt @ perfs @ 2300 hrs, 9/6/84. Sqz cmt thru perfs w/final press of 2250 psi @ 1/2 BPM, POH to 7164', rev out 9 bbls cmt, POH, WOC. 9/08/84 3½" @ 7338' thru 7338' Tbg Tail, 7582' Top of Vann gun, Prep to set pkr 9/10/84 PU EconoMill/DD, RIH, tag cmt @ 7127'. Drl firm cmt to 7142', drl hard cmt 7190'-7278', drl CR f/7278'-7281', hard cmt f/7281'- 7334' (void f/7334'-7369'). Drl BP f/7369'-7371'. RIH, tag fsh @ 7567', POH. RIH w/6-1/8" bit & 2 csg scrprs to 7567', rev circ. Displ well w/cln brine, POH. RU DA, tst lub to 1000 psi. RIH w/perf gun, perf 7268'-7282', 7255'-7260', 7234'-7244', 7224'-7234', 7214'-7224', 7204'-7214', 7194'-7204' 7184'-7194' @ 12 SPF (accum fluid loss = 312 bbls). RIH w/JB & gage ring to 7511' WLM, POH. RIH w/WD WL set pkr, set @ 7312' WLM, POH. RU & rn 222 jts, 3½", 9.3#, BTC IPC tbg, space out & lnd tbg. The above/ti Cor~c~ SignaturtJ ,-~V ~i,C~~ IDate Fo r ,tormJ~'p~ep~& d~ t, o~ ~' see Procedures Manual Section 10, Drilling, Pages 86 and 87 Alaska IWell no. 1F-7 W/O 10/02/84JTM .F- CE I vED - u~ COll~. Commission " ,,,rage ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are-suspended-for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ~County or Parish Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. JTitle I AFE 204552 - 103918 wws #1 Operator ARCO Alaska, Inc. Spudded or W,O. begun Workover Date and depth as of 8:00 a.m. 9/11/84 Accounting cost center code State Alaska North Slope Borough Well no. ADL #25652 1F-7 W/O Recompletion API 50-029-20830 IA.R.Co. W.I. rrotal number of wells (active or inactive) on thisI Icost center prior to plugging and 56.24% Jabandonment of this well IOate IHour ] Prior status if a W,O. 8/31/84 J 0130 Hrs. Complete record for each day reported 3½" @ 7338' 7338' Tbg Tail, 7582' Top of Vann gun, RR Crude w/30 bbls diesel cap Set pkr, ND BOPE, NU &tst tree to 250/3000 psi. Disp1 well lw/30 bbl diesel, followed w/crude. Open SSSV, set BPV. RR @ 1600 hrs, 9/10/84. Classifications (0il, gas, etc.) .. Oil -.. - Old TD J New TD J PB Depth I I 8060 ' Released rig Date ~Kind of rig 1600 Hrs. 9/10/84. I Type completion (single, dual etc.) . , . · . Single Produc.ing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7 9 5 2 ' p~ii ~ (ib'5 CC,,:~. Cor~lnJssi.on Rotary Anchoraffe Well no. ;Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above i~c°rrlII-L Signature IDate J'rit,e .,-,i..,. ' ," ,,or, J ~ ~ ~_C~ ~ 10/02/84 Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, ARCO Alaska, t~-''~ Post Offk,,~ c3ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1F-7 Dear Mr. Chatterton- Enclosed is Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Si ncerely, If J. Gruber Associate Engineer JG/tw GRU2/L32 Enclosures OCT 2 5 ]11184 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~" ALASKA OIL AND GAS CONSERVATION L, OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 1331' FNL, 28' FWL, Sec.20, T11N, RIOE, UM 7. Permit No. 82-156 8. APl Number 50-- 029-20830 9. Unit or Lease Name t(uparuk River' Ilni~ 10. Well Number 1F-7 11, Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool RKB 115' I ADL 25652 ALI( ?.C,7R [ 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans F-J Repairs Made (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 0130 hrs, 08/31/84. Killed well. Pulled tubing. LD hanger, packer, and tailpipe assembly. Set R-3 packer ~ 7500'; tstd DP & packer to 3000 psi - ok. POH to 7330'; set pkr. Established breakdown of "A" Sand ~ 2700 psi ~ 1.1 BPM. RIH to 7500'; retested pkr & DP to 3000 psi - ok. POH to 7350'; set pkr; pumped ~ 2200 psi (2.7 PBM) w/good returns f/30% - 40%. POH to 7140'; tstd csg to 3000 psi - ok. Tstd lubricator to 1500 psi - ok. Set bridge plug ~ 7380'. Perf'd 7366' - 7368' w/4 spf. Set EZSV cmt retainer 7290'. Pumped and squeezed 200 sx Class G cmt. Drld cmt, cement retainer and more cmt to 7334'. Drld bridge plug. Tstd lubricator to 1000 psi - ok. Perf'd the following intervals w/12 spf: Set WD wireline pkr ~ 7312'WLM. well w/diesel and Kuparuk crude. 7268' - 7282' ~ J~E i-'-' ;~,' T'~} 7255' - 7260' ,- ?,~ i ~,' ii' L2 7234' - 7244' 7214' - 7234' 0CT'2 5 ]98 . 7194' - 7214' Alaska 0il & 6~S Co:is. 6;,r,,~m,!ssion 7184' - 7194' Anchorsg3 NU tree & tstd to ~000 psi - ok. Disp Set BPV. Secured well & released ~ig ~ 1600 hfs, 09/10/84. Ran 3-1/2" completion assy. ND BOPE. Opened SSSV. 14. I hereby cer/t~ that the foregoing is true and correct t° the best of my knowledge. Signed _ Title Area Drilling Engineer The space ~/~v f~r~Cf~ issi;n us; COnditions/of Apprck~l, if any: Approved by_ By Order of COMMISSIONER the Commission Date __ Submit "Intentions" in Triplicate Form 10-403 GRU1/SN66 and "Subsequent Reports" in Duplicate Rev_ 7-1-80 ARCO Alaska,z-~'/-~ F :.,: ? Of~., c box.360 Ar, oho:age. Alaska 99510 ~etephone 907 277 5637 Date: 9/04/84 Transmittal No: 4712 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ra, nsmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PRESSURE ANALYSIS/PBU SURVEYS & 1E-12~ PBU "BOMB" 8/17/84 1E-15t .... S'~i~%~"-~HP 8/05/84 1F-2~' SlBH? 6/04/84 iF-3~' ~.~ 4/3O/84 1F-4 / SIBHP 6/04/84 1F-5 -" .(]~Bp,~> 5/08/84 iF-6- SZB~P 6/05/84 iF-? ~ SZ~ 12/i9/83 iF-7~' SI~ 6/05/84 1F-7 ....SlBHP 4/30/84 1F-9-~'. GAS LIFT SURVEY 4/29/84 1F-9~'' ,'PBU/DRAWDO~ SAND 12/26/83 iF-10 .... ~..,'[P~U/DRAWDOWN~' 12/20/83 1F-10''~ DRAW-DOWN 12/21/83 1F-11-. cP'B~? 12/23/83 iF- 11 .... C~/~-~X~-~~3 / 15 / 84 1F-11--' -PB-OTDRAWDO~*~ 12/24/83 3/09/84 7/03/84 3/10/84 3/09/84 5/03/84 1/26/84 5/04/84 SEQUENCE OF EVENTS 1F-16~/ 1F-16 ' /cat B. Adams D&M DISTRIBUTION LOGS & PBU_"A" SAND ~/04/84 , , ..... o. CO;IIITIIS:. · . , W,V. Pasher C.R. Smith F.G. Baker P. Baxter BPAE Drilling Geology Mobil G. Phillips stare'of Alaska Phillips Oil Sohio J.J. Rathmell Union R & D Well Files Chevron ~SK Operations /---% ARCO Alaska,~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 8, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are notices of intention to fracture Kuparuk Field wells: - 1F-2, 1F-4, 1F-6, 1F-7 the following If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL! kmc Attachment (In Triplicate) RECEIVED AUG 0 9 Alaska Oil & Gas Cons. CommJsr~b~ Anchorage · ,r~r,n ~,t~ol,= I.,- ;= = ~,,hcidi:~rv ~! AtlantJcRichfieldCompany ~--,,. STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator 3. Address · ANCHORAGE, ALASKA 4. Location of Well SURFACE' LOCATION: 1331' FNL, 27' T11N· R10E, UM 99510 FWL, SEC. 20, BOTTOM HOLE LOCATION: 2036' FNL, 1383' FEL, SEC. 20, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 115' (RKB) ADL 25652, ALK 12. 7. Permit No. 8. ApSl') _ 1 i~uMb~r~ SO- 029-20830 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 1F-7 11. Field and Pool KUPARUK RIVER F I ELD KUPARUK RIVER O I L 2.578 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of startinffany proposed work, for Abandonment see 20 AAC 25.105-170). it is proposed that the "A" sand in Kuparuk well 1F-7 be hydraulically fractured and propped to improve production. The treatment uses gelled water as. the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Radioactive tagging of the .proppant and pre-post frac logs are included in the treatment program. · Fluid- Gelled Water 238 BBLS Proppant. 12/20 Sand 18,100 LBS RECEIVED ANTICIPATED START DATE: September 4, 1984 AUG 0 Alaska Oil & Gas Cons. Commission Subsequent Work Reported Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ...... Title KU PARUK Date The space below for Commission use ' ' OPENAT IONS COL)RD I NATOR 8/8/84 Conditions of APproval, if any: BY LOttt~lt C. $9i1Ii Approved by. COMMISSIONER Approved Copy P, eiurr~d , ...... By OrOer of the Commission . Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Ataska, %~/''~'" -00360 ARCO post Ott%c" u'ox · Anchorage' Ataska 99510-0360 1. etephone 907 276 1215 23, 19B4 tqr. C. ~' chatterton commi s si oner , ate of /klaska St . ~ & GaS Conservation ~kl asKa u-- -' CommissiOn 3001 porcupine Drive ~nchOrage, ~K' 99501 SUBJECT' 1~'7 to Dear Bt. chattertOn: ' . ~e subject well We propose is a Sunar~ ~ot~ce for.t completion' Encl°sealF_7 to a s~ngle select, ye , convert 's work on June 17, 19B4 your . +~ start th~ .... ~iated. If you h~ve · e we exP~,:~will be questlon~' ~1 sin~el Y, ~ 11 ing Engi neet jBK/JG'tw Eric! osureS P c[IVED MAY 2 ARCO A%aska, thc, is a subSidiarY ot At%anticRichtieldC°mpanY STATE OF ALASKA ~ ALAS~"OIL AND GAS CONSERVATION' )MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-156 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20830 9. Unit or Lease Name Kuparuk River Unit OTHER [] 4. Location of Well Surface: 1331' FNL, 27' FWL, Sec.20, T11N, R10E, UH TD: 2036' FNL, 1.383' FEL, Sec. 20, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 115' 12. I 6. Lease Designation and Serial No. ADL 25652 ALK 2578 10. Well Number 1F-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~;- Other ~. Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1F-7 to a single selective completion. The procedure will be as follows: 1. The well will be killed with brine. Weight to be determined after running pressure bomb. 2. The current completion assembly will be pulled. 3. A retrievable packer will be run to verify zone isolation between A and C sand. 4. The well will then be completed as a single selective. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be-left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: June 17, 1984 Subsequent Work Beporte~l RECEIVED 011 & ~; Co,s. Commiss/o~l AnCot;ge 14. I hereb~et~jtify that the foregoing is true and correct to the best of my knowledge. Area Drilling Engineer ?/ Signed Title Conditions of AP~g~fal. if any: Date Approved by ORIGINAL ,~IQN£B BY LOt~IE C. SMITH COMMISSIONER Approved Copy By Order of the Commission Form 10403 GRU7/SN30 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission · 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are subsequent reports of stimulations performed on the following Kuparuk River Unit Wells: 1E-20 1E-21 1E-22 1E-23 1E-24 1E-26 ~F?.7~. 1F-8 1G-4 1Y-14 If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Duplicate) cc: W. Crandall/T. Best R. Ruedrich R. May ARCO Alaska. Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator ARCO ALASKA~ INC, 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 1331' TllN, R10E, UM FNL, 27' FWL, SEC. 20, BOTTOM HOLE LOCATION' SEC. 20, T11N, 5. Elevation in feet (indicate KB, DF, etc.) 115 ' (RKB) 12. 2036' FNL, 1383' FEL, 7. Permit No. 82-156 8. APl Number 50- 029-20830 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-7 11. Field and Pool R10E, UM KUPARUK RIVER FIELD I 6. Le.seDesignationandSeria~No. KUPARUK RIVER OIL ADL 25652~ ALK 2578 POOh CheckAppropriateB°xTolndicateNatureofNotice, Report, orOtherData NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate} (Submit in Duplicate} Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation X [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state ail pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On April 26, 1983, Kuparuk River Unit Well 1F-7 was stimulated with 14.1% HC1 through coiled tubing. All surface lines and BOP's were pressure tested to 4000 psig. Maximum CTU pressure was 1150 psig. Diesel was used to displace the acid. Nitrogen was injected via the coiled tubing and circulated intermittently with diesel to aid in cleanup. Following the cleanup period, the well was switched to the CPF. TOTAL AHOUNT USED' Acid 114 BBLS Nitrogen 784 GALS Diesel 85 BBLS 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ..... Title KUPARUK The space below for Commission use 0 P E RAT I ON S COORDINATOR Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions'' in Triplicate and "Subsequent Reports" in Duplicate KUPARUrK ENSINEERlb~ 7RAt"'~,A ! Tf'AL TO: William VanAlen ~4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the roi lowing- PLEASE KOTE: BL- BLUELINE, S- SEPIA, F - FILM, T - TAPE, RECE ! PT/~]"~x~]WI_ _FI]G~: PLEASE RETURN RECE ! PT TO: KUPARUK RIVER UNIT ., SEQUENCE DF EVENTS ARI::D REP: //'C' ~ EVENT DPERATIDN: 7-= y.y, ( °,~' Alaska. Oil & Gas. Conk,, Anchorage F-~IL: :?4 .P. UfJ 19~ ._ --r~oo- BLT [lB,,- 7,[.8 32. !5 08.Ztl._q 2143,50 (~8:47:08 2142,12 O,00 08:48:002!38,67 -3.45 [IB:qg:00 2135,42 %20 08:50:002133,15 -8.91 08:51:002131.~B -lO.E,~ 08:52:002t30.20 -11.~ 08:53:00212~.82 -13.~ 0B:54:002127.93 -1~.1B 08:55:002127.a~ -1~.E8 08:%:00 2125,17 -t6.~ 08:57:00212~.30 08:58:002122.3~ -I9.81 08:59:002121 ,EB 09:00:002120.9~ -21.19 fiB:01:00 2120.7~ ~2! 09:~:00 2'120A~ -21.~ 09:0~:00'~ ~ ~ ,.l~0.jq -21 09:0~:00 ~120.~q -21.D~ o. ,~ '-"~% ~' -21.~ ~.~,[,j:L~I ~,¢_~ .~j 09:0G:002120.05 -22.07 ~:l~:00 ~119.85 -22.27 0~:lfl:0fl ~ ~ ~ [19:11:00 ~11B.75' -~.37 ~9:13:002119.35 -~.75 ~:1~:00 2119.55 -22A7 09:15:002119.75 -~.~7 09:15:0~2119.55 -~.57 10:~0:00~76~,80 ~7,~8 10:~:00 2~69,71 6~,~ ~0:~5:00226~,92 ~,~l 10:~:00 2268,53 ~.~0 10:~:00 2~87,8~ ~5,~1 ~0:~:00 2767,~ ~%,~ 10:50:002F62,5~ 10:52:0027~7A~ ~S,~ 10E~:00 2767,05 ~,~ 10:55:0027B7,15 10:%:00 2766,75 ~,~ liME .01~q .0311 .0478 33.60 .0811 :~.80 ,11~q 33.80 ,1311 ~.B0 .1~78 ~3,GO 33. '~ .1811 ,192B ~,~0 ,21~ .~11 .~.~0 .2G~ ,~11 .31~ ~,GO ..~¢,1 ~.~0 .ql~q .q311 ~.~l .qq18 ,~8 1,~1i 159.90 1,9~78 1~.90 1.9811 1~.90 1,~?B 1~.~ 2,01~ !~,90 2,0311 1~,~I 2,0~ -1~,~ ' 2,1~11 2.097~ 2,11~ !~,90 2.1311 1~.~ --1!,% .... PRE%- DLT ~'~'-"" ,,~_o,~ DLT TIME !0~57'~0 10:3~ :."10 10: '5~: 11:00:00 11:01 !1:01:3~ - li':Lr2:uU ._il :09'./I7 0,00 11:10:00. ~,BB 11:11 11:12:00 11:13:3!) !1:1~:0[I 11:1 .., 20 !1:1D 11:17'.00 11:!8:80 11:19:~0 !1:~I:8(I 11:21 :.90 11'.~:00 11 11:2a:N0 11:2~ 1! :27 11 11:~:00 11:30:00 11:3!:00 11 :~:O0 11:~:80 11 11:~:00 11:~:.00 !.1 '11 11: ~0 '~ P76~.75 ~24.~ "' 2165.5[; 82~.~ 2,181115B,90 ..... ,,~ ?~ ~ , ,~ ~ , /~.% B2 1,43 ~,IBTB1:,8.90 ..... 27~.~E 62a.~ ~,21~ 158.90 ..... 2~5~.B5 6~/I.73 22311 1~8.~ ..... 27~.7F 82~.~ 2.2475158.81) T .... -21~.12 2,37751~.1n I ....... zIBO.~ 2,3Bll1~3.70 ..... 26~.88 ~80,% 2,39781~3,71) ..... ~a.37 Z~Bl.~ 2Alqq 1~3.7J 26Z] ,57 q81. ~5 2. ~311 1 q3,70 ..... ~$73.77 ~81.~ 2.~7B 1~3.70 ..... 2~q.26 ~82,14 2.~6~q1~.70 ..... 2523,87 q81.7~ 2.~Bll1~3,70 ..... 262q.36 q82.2q 2,q97B1~.70 ..... ~2q.06 ~81.~ 2.51qqlq3.70 ..... ~2q.35 q82.2q 2.~11 1~Q.70 ..... ~.B7 qB1.Ta 2.~7B 1~2.70 ..... 28~,96 ~81.8q 2.55qq1~.70 ..... ~,67 qB1.55 2.5Bll143,70 ..... ~q.16 qB2,0q 2.5978lq3.70 ..... ~q.06 qBl.~ 2.61~4lq2.70 ..... ~.7~ q81.6q 2.63111~,10 ..... ~3.77 ~Bl.~ 2.64781~3.70 ..... 282q.26 q82.1q 2,66q~1~./0 [~q.16 ~B2,0q 2.68111~3.70 ..'" ~.., ~.77 qB1.6q 2,G9781~.70 ~.~7 qBl.~ 2.71q~1~.70 ..... ~q,16 q82,0~ 2,73111~,/0 ..... ~,57 ~81.q5 2.747B1~.70 ..... ~.G7 q81,~ 2.76q41~.70 ..... ~q.0B q81,~ 2.7Blllq3.70 ..... ~3,7/ q81,~ 2,79181~.70 ..... ~.77 qBl,~ 2.B1~ lq3,70 ..... ~.87 ~1.1~ 2,~11 1~,70 ..... ~.37 qBl.~ 2.B47Blq3,70 ..... , ,, f'r}~ ,, . 0.00 1~3./0 .... E 0.00 ; 0,00 ALASKA To: OIL AND GAS CONSERVATION COMMISSION Re: .lAY S. HA¥¥O#D, ~;OVERNOR 3001 ,PORCUPINE DR/VE.ANCHORA GE, ALASKA ,99501 are the following: Quantity DescriPtion of Item Please acknowledge receipt by signing and returning one copy of this letter. ~S_igned: ' Dated ALASKA OIL Yours very truly, & GAS CONSERVATION COMMISSION KUP~No. UK -Elx~ 1 NEERI hVo TO: WilliamVanAlen ~: D.' W. Bose/Staelby J. Matthews Transmitted herewith are the following' ~ALASKA, ATIlt' SHELBY J. M'NI-H-t~'~ - ATO/1115-B P. O. BOX 100360 AND-IC)R,~E, AK. 99510 ARCO Alaska, Inc. ~ Post Office B,._. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 25, 1983 Chat Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat: Attached are notices of our Wells iF--7 and 1Y-14 with have any questions, please Commission intent to stimulate Kuparuk Unit acid via coiled tubing. If you call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kjc Attachment (In Triplicate) xc: W. L. Crandall/M. D. Schall R. A. Ruedrich - ANO 332 H. C. Vickers - AFA 326 - Kuparuk, North Slope ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~'" ALASKA uIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-156 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 so- 029-20830 4. Location of Well SURFACE LOCATION' 1331' FNL, 27' FNL, SEC. 20, T11N, R10E, UN BOTTOM HOLE LOCATION' 2036' FNL, 1383' FEL, SEC. 2'0, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 115' (RKB) I ADL 25652~ ALK 2578 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-7 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to acidize Kuparuk River Unit Well 1F-7 through coiled tubing to improve the well's productivity. The initial production test on this well indicated a high skin factor and a corresponding low flow efficiency. Other Kuparuk wells with similar characteristics have shown marked improvements following acid treatments. The treatment will consist of 4,788 gals of 12% HC1 with mud and silt remover additives. The coiled tubing unit BOP's will be pressure tested to 4000 psig. The end of the coiled tubing will be positioned initially just below the lowermost perforations and then pulled up across the perforations as the acid is pumped. Pump pressure will be limited to 4000 psig and the tubing pressure will be limited to 1500 p$ig. Following the acid treatment, nitrogen will be injected through the coiled tubing and aid the cleanup. During cleanup the well will be produced to tanks on location. Following the cleanup the well will be produced to CPF1. Expected start date' 4/26/83 . 14' I here~Z;h~°reg,~~d c°~t~''"e best °f mY kn°wledge' 2519,3 KU PARU KON~Ia~;R~ Signed C~,~~ ~ I ~ ~~ Tit,e OPERAT~ ~n~-, Date The space below for Commission use Conditions of Approval, if any: Approved Copy Returned AY [OflHIE C. SMITII By Order of Approved. by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Will/am VanAlen Transmitted herewith are the following: Pr.VASE NOTE: BL - B .I/3E~, S -'SEPIA, F - F~,. T - TAPE, PC - PHOltX2OPY IF-' 7 ~,. o. ~x ANCHORAGE, AK. ,99510 ARCO Alaska, Inc. Post Office [~'"~360 Anchorage, ~laska 99510 Telephone 907 277 5637 December 9, 1982 Mr. C. V. Chatterton Commissioner State'of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are monthly reports for November on these drill sites' 1-22 13-6 1-23 13-11 1-24 13-13 6-24 13-14 7-15 1C-9GI 7-16 1C-IOGI 12-19 1E-24 12-20 1E-25 WSW-6 WSW-7 WSW-8 Also enclosed are well completion reports for' 1-21 6-23 13-15 18-10 1F-7 1G-4 WSW-4 WSW-5 WS. 24 The survey for'2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including a subsequent Sundry Report for WS 24. Since the information on the WS 24 well is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV:·JG'sm Attachments GRU1/L3 ARCO Alaska. Inc. is a subsidiary of AllanticRichfleldCompany STATE OF ALASKA AND GAS CONSERVATION., MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILX[~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-156 , - 3. Address 8. APl NUmber P. O. Box 360, Anchorage, AK 99510 50- 029-20830 , , 4. Location of well at surface 9. Unit or Lease Name 1331' FNL, 27' FWL, Sec. 20, T11N, R10E, UNi~i- Kuparuk River Unit At TOp Producing Interval 1895' FNL, 1842' FEL, See. 20, T11N, R10E, UN/ VERIFIED ~ 10. Well NumberlF_7 At Total Depth Surf.~ 11. Field and Pool 2036' FNL, 1383' FEL, Sec. 20, T11N, R10E, UM B.H..~- Kuparuk River Field -- 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial ~Jo.' Kuparuk River 0i 1 Pool 115' RKBI ADL 25652, ALK 2578 ,, 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ! 15. Water Depth, if offsh°~e 16. No. of Completions 10/02/82 10/11/82 10/21/82I N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(ME)+TvD) 19. DirectionalSurvey ] 20. Depth where SSSV set I 21. Thickness of Permafrost 8060'MD,6716'TVD 7942'MD,6617'TVD YES ~ NO [] 1895' feet MD 1450' (approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/GR/SP/Cal, BHCS/GR, RFT, CCL/Gyro, CBL/VDL/GR, CBL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD cASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80'P.L. 24" 295 sx AS II 10,3/4" 45.5# - K-55 Surf 2259' 13-1/2" 1000 sx Fondu & 250" Perma ~rost C 7" 26.0# K-55 Surf 8038' 8-1/2" 450 sx Class G '& 250 sx ~ermafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7184 ' -7244 ' 3-1/2" 7107 ' 7031 ' 7255 ' -7260' 7268'-7282' w/12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7393 ' -7405' ' ' . DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 742'0'-7446' 7573'-7575' 250 sx Class G 7453'-7458' 7330'-7332' 100 sx Class G 7149'-7151' 100 sx Class G 27. N/A PRODUCTION TEST Date First ProdUction Meth6d of Operation (FloWing, gas lift, etc.) - , Date of Test' Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 'WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED , OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-APl (cor'r) Press. 24,HOUR RATE I~ , 28. CORE DATA Brief description OfNone lithology, porosity, fractures, apparent dips and: . presence of oil, gas or water. Submit core ch~s~'~ ,,! ! ~la~ D£C1 5 1982 Form 10-407 Submit in duplicate Rev. 7-1-80 GRU2/WC23 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 Upper Sand 7184' 5984' N/A Base Upper Sand 7242' 6032' Top Lower Sand 7376' 6143' Base Lower Sand 7512' 6256' . 31. LIST OF ATTACHMENTS Drilling History~ Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~_J~_~2 ~~, !..~__.~~ TitleSr' Dri''ing Eng'neerDate ~''~j/~u~-' , , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. : Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. 1F-7 DRILLING HISTORY il. & diverter. Spudded well. @ 1800 hrs, 10/02/82. Drld 13-1/2" hole to 2275'. Ran 57 its 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2259'. Cmtd 10-3/4" csg w/lO00 sx Fondu & 250 sx Permafrost C. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 Psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, FS & 10' new form. Tstd form. to I2.5 ppg EMW - ok. Drld 8-1/2" hole to 7741'. Ran DIL/SFL/FDC/CNL/GR/SP/Cal f/7721'-2259' and BHCS/GR f/7721'-2259'. Ran RFT (sample @ 7436'). Cont drlg 8-1/2" hole to 8060' TD (10/11/82). Ran 7" 26#/ft, K,55, BTC csg w/shoe @ 8038'; worked down to 8+ from landing hanger. Attempted to reciprocate csg free- max. pull 250,000 lbs. Broke circ.; partial returns. Worked pipe & attempted to circ;, zero returns' Cont. working pipe.. Tstd floats - ok. Perf'd the following interval for cir.' 7573'-7575' (8 shots). Pumped 16.5 bbls mud; no fluid loss. TIH w/EZ drl ret & set @ 7573'. Tstd 7" csg & retainer to 2000 psi - ok. TOH & ND BOPE. Set 7" slips & hang csg w/lO0,O00# below slips. Cut 7" csg & LD landing jr, hgr & csg stub. Instld primary & secondary packoffs; tstd packoff to 3000 psi - ok.. RIH & tagged ret @ 7573'; pumped 250 sx Class G cmt. Hesitate sqz 3 times - final sqz pressure 2550 psi. .T. OH.-' Ran CCL/Gyro. Ran CBL/VDL/GR f/6100'-7563'. CBL showed poor bond f/7563'-7100'. (Arctic packed 7" x 10-3/4" ann w/300 bbls H20, 250 sx Permafrost C & 99 bbls Arctic Pack.). Ran CBL #2 f/7563'-7000'; poor bond. RIH & perf'd 7330'-7332' w/4 spf. RIH w/7" EZ drill & set @ 7300'. Pumped 100 sx Class G cmt. Perf'd 7149'-7151' w/4 spf. RIH w/7" EZ drill & set @ 7080'. Sting into retainer & pumped 100 sx Class G cmt. . Tstd perfs (7149'-7151') - ok. Drld cmt f/7282'-7345'; tstd perfs (7330'-7332' & 7149'-7151') - ok. Washed f/7395'-7563'. Drld cmt f/7563'-7585'. Tstd sqz'd perfs . (7573'-7575' 7330'-7332' & 7149'-7151') to 2000 psi - ok Drld cmt to 7942' PBTD Tstd 7" csg & perfs to 2000 psi - ok. Disp well to NaC1/NaBr. Ran CBL/GR/CCL; good bond @ sqz'd intervals. Ran 3-1/2" completion assy w/tail @ 7107' & pkr @ 7031'. Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel Set pkr. Dropped perf bar & perf'd 7184'-7244' 7255'-7260' 7268'-7282' 7393'-7405' 7420'-7446' 7453'-7458' w/12 spf Flowed well to tst tanks Closed SSSV @ 18.95'. Secured well & released rig @ 1000 hrs, 10/21/82. i £C£1V£D DEC 1 1982 Oil &~as, Cans. Co~ission ~nc]]orage JG'llm 11/08/82 DEPTH · UPA~UK' ,dEASUR BOJE C~t 8 N'~i Suggested form to be inserted in each "Active-' well folder to check for timely compliance with our regulations. · - 'Operator,-We~/1 N~ima and Number Reports and Materials to be received by: Date f Requi,red Date Received Remarks · Ccmpletion Report Yes' /~,'-J ~-- ~ ~. ~,~. _ . Well History Yes / ~ --/.~~ " ~. /'~ -.~ Samples _~- ,, , , ,, ,,. Core Chips ,,,~(~::f. ~~. - _ , · ' ,,, · Core. Description ' ~/~/z~/~'~ ' Registered Survey Plat ~ _ . , , , ,,, , .! Inclination Survey /~/~ Directional Survey Y~. ~-- ~; /-~ --,/ ~'-- ~~/ ~~ Z..'.i '~"~ Drill Stem Test Reports Z,///~::~/~e' ~ Prod~C~n Test Reports ,7~ Logs Run. Yes Digitized Data ~ ARCO Alaska, Inc.._.~. Post Offic~/ ix 360 .Ar~=horage, ,~raska 99510 Telephone 907 277 5637 November 12, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil. & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUbject' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for October on these drill sites' 1-21 18-7 1-22 18-10 6-23 1E-26 6-24 1E-27 7-15 1F-7 13-14 1F-8 13-1.5 1G-4 WSW-4 WSW-5 WSW-6 Also enclosed are well co.mpletion reports for: 1-20 1G-2 6-22 1G-3 13-16 WSW-3 1E-30 The survey for 2-22 needs to be reran; a completion report for this well will be. submitted when an approved survey is received. We alSo are including subsequent Sundry Reports for 1-20 and 13-16. P. A. VanDusen District Drilling Engineer PAV'JGOI:ltc Attachments RECEIVED NOV 1 8 1982 Alaska Oil & Gas Cons, ARCO Alaska, Inc. is a subsidiary of AllanticRichhetdCompany .- J STATE OF ALASKA ALASKA~-"L AND GAS CONSERVATION CC.jiMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling welIxI~x Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-156 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20830 4. Location of Well atsurface 1331 ' FNL, 27' FWL, Sec. 20, T11N, R10E, UN 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1F-7 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 11c;' RKB 6. Lease Designation and Serial No. ADL 25652 ALK 2578 For the Month of. 0ctober ,1982 Kuparuk River Oil Pool 12.Depthatend~fm~nth~f~~tagedri~~ed~fishingj~bs~directi~na~dri~~ingpr~b~ems~spuddate~remarks Spudded well ~ 1800 hrs, 10/02/82. Drld 13-1/2" hole to 2275'; ran, cmtd & tstd 10-3/4" csg. Drld 8-1/2" hole to 7741'; ran logs; cont drlg to 8060'. Ran 7" csg; worked down to ±8' from landing hgr. 5et EZ drill, 7" slips & hung csg below slips, Cut 7" csg & LD landing jr. Tagged ret & squeezed cmt. Ran logs; poor bond; squeezed cmt. Ran CBL-good bond. Ran 3-1/2" comp], assy. Perf'd well. Secured well & released rig ~ 1000 hrs, 10/21/82· SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 16" 62 5#/ft, U-40, weld conductor set ~ 80' PL Cmtd w/295 sx AS II · · · · lO-3/4",45.5#/ft,K-55,BTC csg w/shoe ~ 2259'.Cmtd w/lO00 sx Fondu & 250 sx Permafrost C. 7" 26 O#/ft, K-55, BTC csg w/shoe @ 8038' See Drlg History for cmtg details. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/FDC/CNL/GR/SP/Cal BHCS/GR f/7721'-2259' EFT (sample ~ 7436') CCL/Gyro CBL/VDL/GR f/6100'-7563' f/7721'-2259' CBL f/7563'-7000' CBL/GR/CCL 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Senior Drilling Engineer TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 G R U 2 / M R 20 Submit in duplicate 1F-7 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1800 hrs, 10/02/82. Drld 13-1/2" hole to 2275'. Ran 57 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2259'. Cmtd 10-3/4" csg w/lO00 sx Fondu & 250 sx Permafrost C. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, FS & 10' new form. Tstd form. to 12.5' ppg EMW - ok. Drld 8-1/2" hole to 7741'. Ran DIL/SFL/FDC/CNL/GR/SP/Cal f/7721'-2259' and BHCS/GR f/7721'-2259'. Ran RFT (sample @ 7436'). Cont drlg 8-1/2" hole to 8060' TD (10/11/82). Ran 7" 26#/ft, K-55, BTC csg w/shoe @ 8038'; worked down to 8~ from landing hanger. Attempted to reciprocate csg free - max. pull 250,000 lbs. Broke circ.; partial returns. Worked pipe & attempted to circ; zero returns. Cont. working pipe. Tstd floats - ok. Perf'd the following interval for cir.- 7573'-7575' (8 shots). Pumped !6.5 bbls mud; no fluid loss. TIH w/EZ drl ret & set @ 7573'. Tstd 7" csg & retainer to 2000 psi - ok. TOH & ND BOPE. Set 7" slips & hang csg w/lO0,O00# below slips. Cut 7" csg & LD landing jt, hgr & csg stub. Instld primary & secondary packoffs; tstd packoff to 3000 psi - ok. RIH & tagged ret @ 7573'; pumped 250 sx Class G cmt. Hesitate sqz 3 times - final sqz pressure 2550 psi. ~OH.~ Ran CCL/Gyro. Ran CBL/VDL/GR f/6100'-7563'. CBL showed poor bond f/7563'-7100'. (Arctic packed 7" x 10-3/4" ann w/300 .bbls H20, 250 sx Permafrost C & 99 bbls Arctic Pack.). Ran CBL #2 f/7563'-7000'; poor bond. "RIH & perf'd 7330'-7332' w/4 spf. RIH w/7" EZ drill & set @ 7300'. Pumped 100 sx Class G cmt. Perf'd 7149'-7151' w/4 spf. RIH w/7" EZ drill & set @ 7080'. Sting into retainer & pumped 100 sx Class G cmt. Tstd perfs (7149'-7151') - ok. Drld cmt f/7282'-7345'; tstd perfs (7330'-7332' & 7149'-7151') - ok. Washed f/7395'-7563' Drld cmt f/7563'-7585'. Tstd sqz'd perfs · (7573'-7575', 7330'-7332' & 7149'-7151') to 2000 psi - ok. Drld cmt to 7942' PBTD. Tstd 7" csg & perfs to 2000 psi - ok. Disp well to NaC1/NaBr. Ran CBL/GR/CCL; good bond @ sqz'd intervals. Ran 3-1/2" completion assy w/tail @ 7107' & pkr @ 7031'. Tstd · tbg hanger & packoff to 3000. psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Set pkr. Dropped perf bar & perf'd 7184'-7244', 7255'-7260', 7268'-7282' 7393'-7405' 7420'-7446' 7453'-7458' w/12 spf. Flowed well to tst tanks Closed SSSV @ 1895'. Secured well & released rig @ 1000 hrs, 10/21/82. JG:llm 11/08/82 Oil & Gas Co~s. oommis~ion Anchorage William VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: ?LFASE · Alaska Oil & Gas Cons, COmmission' Anchorage PT.VASE RE-'II3RN. RDCEIPT ARCO ALASKA, INC. ATIN: IDRTR. L. JOHNSON - AFA/311 P. O... BOX 360 ANCHORAGE, AK. 99510 ~s~~ # 17e0 TO:~ William VanAlen D. W. Bose/Lorie L. Johnson TranSmitted herewith are the following: PLFASE NOTE: ~F- FILM, T- TAPE, PC - PHOTCCOPY PLVASE RETURN PdDCEIPT TO: RECEIVED ~o ~m~s~, ~c. ~0¥ 0 ~) 11t82 ATIN: LORIE L. JOHNSON - AFA,~,m P. O. BOX 360 mu~r,- Oil & Gas Con~. ~mmissioTI · Anchorage. ANCHORAGE, AK. 99510 TO:' William VanAlen Transmitted herewith are the following: D. W. Bose/Lorie L. Johnson PLFASE NOTE: BL- BLUELINE, S - SEPIA, F - FIL~, PC - PH~PY A'I'Z'N: ZDR.ZE 'r,. JOI-I~$ON - AFA/311Alaska 0il & Gas Corers. 2. O..BO× 360 Anchorage .~0~, ~. 99510 TO: William VanAlen D. W. Bose/Lorie L. Johnson smitted herewith are the follc~ing: PT.WASE NOTE: ~ ~~'¢~ F- FILM, T- TAPE, PC - PHOTCCOPY ATI'N: LORIE L. JOHNSON P. 0.. BOX. 360 ANCHORAGE, AK. 99510 ,-,., MEMORANDUM Stale of Alaska TO: C. y~ ~~rto~ DATE: October 11, 1982 Chai~'~-~ LEPHONE NO: SUBJECT: Thru: Lonnie C. Smith Co~missione r FROM: Ben LeNorman petroleum Inspector Witness BOPE Test on ARCO's Kuparuk 1F-7 Sec. 20, T11N, R10E, UN .,,Kupar_uk River Dnit Sun~Y~_ __0~_.to~r 3,_ !9.8_2 - I departed my home at 6: 00 a.m. for a 6z25 a.m. showup and 7:25 a.m. departure via Alaska Airlines flight %55 for Deadhorse. Accompanied by Harold Hedlund, I arrived in Deadhorse at 9:05 a.m. Weather: +22"F, light snow, light wind. BOPE tests on DS 6-23 completed, the subject of a separate report. october 4. 1982 - Standing by on Kuparuk 1F-7. _T~esda¥, October .5,_ !982 - BOPE tests on ARCO's Kuparuk ~F-7 began at 7:50 a.m. and were completed at 9:30 a.m. BOPE inspection report is attached. BOPE tests on Sohio's A-28 completed, the subject of a separate report. Wednesday, 0~.qtober 6, 1982 - BOPE tests on ARCO's DS 1-21 -C0mpie-t~-, 't~' "~ubj~ct~'Of 'a separate report. I departed Deadhorse via Alaska Airlines flight #66 at 9:45 a.m. arriving in Anchorage at 11=25 a.m. and at my home at 11~ 55 a.m. In summa~-f, I' witnessed success BOPE test on ARCO's Kuparuk 1F-7. O&G #4 4/8~ ,- 3TATE OF ALASKA ALASKA OIL & GAS ODNSERVATION CCMMISSION B .O. P .E. Inspection Report .Inspector Operator. Representative- Well ,, /~~~9. ~t~_ __/~'- ~ ~tion: Sec ~ ~ T !/~R I~E M U~ ~il ling ~n~a~or ~ F~ ~ Rig ~ '~ Permit # ~-~- t~ /6~, asing Set @ .~~, ft. Representative Location, Genera] Wel 1 Sign_ C~neral Housekeeping Reserve pit ACCUMUIATOR SYSTEM Ful 1 Charge Pres sure ~o~ ~ psig Pressure After Closure ,/-~~' psig Pump incr. clos. pres, 200 psig Full/~j_O~~~sure At~ta_ined: . _ ~ _, ' ~ .z~ ~g:)~.Z~ . N2 .~_ _~j-~ ps Controls: Master BOPE Stack Annular Preventer Pipe Rams Blind Rams, Choke Line Valves H,C,R. Valve Kill Line Valves Check Valve Test Results: Failures~ Test Pressure min ~O sec. min~ sec. Remote 4Q~ Blinds switch cover Kelly and Floor Safety Valves · Test Pressure ~$~g~ Test Pressure__ ~$~ Test Pressure ~$ _~%/~ Test Pressure Test Pressure Upper Kelly Lower Kelly · ~all Type Ins ide BOP Choke Manifold ~. valves__ _. /~ ~ No. flanges ~D Adjustable Chokes / Hydrauical ly· operated choke TeSt Time.' /~ hrs. Repair or. Replacement of failed equipmmnt to be made within . days and Inspector/Ccrmnission office notified, Distribution orig. - AO&(I2C cc - Operator cc - Supervisor Inspectoz~ t"l J ~ '8 I"-- I Hi L/N-F. = ~o° I-T' 4'~ .~o~_-t" go~.: {49°4o' ~5. ~'T" L~-T. ~ -/o° ~'T'"A~ .'-p~o I" L~,'T.=. ...[~o I'F' ,4. T. $ ~'7B" Lot, jR.-. l,~ ~ go ',~.~,1~/ " L ~"F. =. Tc::P ~-'r'4/.,,. 4 ~ ~" L~-E. =- "To° LA,"F. = "i'c5° ~9~8. t~.~ L,N,"F.= -To°F1'' ~'4 ooo$ .ZG' LoNIF,.T.; 14'5~4o' $3,.'To4" .: · ARCO Alaska, Inc. Kuparuk Project North Slope Drilli.ng drawn by Mr. Jeffrey I~, Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O, Box 360 Anchorage, Alaska 99510 Euparuk River Unit 1F-? ARCO Alaska, Inc. Permtt No. flur. Loc. 1331'I~. 28'F~, Sec. Btm~ole Loc. 1689'1~L, 1211'FEL, Sec. 20, TIlN, R10E, U~. Dear Mr. Kewtn: Enclosed is the approved application for permit to drill the above re ferenoed we I 1. Well samples and a ~ud log are not required. A continuous directional survey is rectuired as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized Icg information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys, ~ny rivers in Alaska and their drainage systems have been classified as important for the spawnin~ or migration of a~adromous fish, Oporations in these areas are subject to A~ 16.05.$?0 and th~ regulations promulgated thereunder (Title 5, Alaska Administrative Code), Prior to commenctn~ operations you Fflay be contacted by the Babitat Coordtnator*s Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Artiele? and the regulations promulgated thereunder (Title 15, Alaska Ad~inlstrative Code, Chapter 70) and by the Federal ~ater Pollution Control Act, as amended. Prior to eo~ncinc operations you may be contacted by a representative of the Department of ~nvironmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to eon~nein~ installation of the blowout pr~vention equip~ent so. that a representative of the Commission ~ay be present to witness testin~ of the equipn~nt before the Mr, Jeffrey B, K~tn Euapruk River Unit 1F-? September 15~ 1982 surface casing shoe is drilled. ¥~here a diverter system is required, please also notify this office 24 hours prior to c~enoing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. Very~.~ truly Cha i ~n o f ~ 02D~a O~ Alaska Oil and Gas Conse=vatton C~ission o sure .Department of Fish & Game, Habitat Section w/o encl. Department of Envtromnental Conservation w/o encl. CVC:be ARCO Alaska, Inc. /'%' Post Office B~,~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 3, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kuparuk 1F-7 Dear Mr. Chatterton' Enclosed are- An application for Permit to Drill Kuparuk 1F-7, along with a $100 application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. A diagram and description of the surface hole diverter system. A diagram and description of the BOP equipment. Since we expect to spud this well on September 22, 1982 your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Sr.. Dril ling 'Engineer JBK'JG'ltc ECE!VED Alaska 0il & Gas Cons. Anchorage Attachments ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ."~"~ ALASKA ~L AND GAS CONSERVATION CO,viMISSION PERMIT TO DRILL 20 AAC 25.OO5 DRILL ~ ' REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OILX]] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZON EX[] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchoraqe, Alaska 99510 4. Location of well at surface ' EIO 1 . i982 1331'FNL, 28'FWL, Sec. 20, TllN, RIOE, UM 4!aSkaOil~aSOoas' At top of proposed producing interval Target: 1650'FNL, 1650'FEL, Sec. 20, T11N, RiOE, At total depth 1689'FNL, 1211'FEL, Sec. 20, 5. Elevation in feet (indicate KB, DF etc.) 74.4'GL, 79.4'Pad, ll5'RKB '11N, RIOE, UM 6. Lease designation and serial no. ADL 25652 ALK 2578 9. Unit or lease name Kuparuk River Unit 10. Well number . .1F-7 >-~f~Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Co. Type Statewide Suretyand/or number8088_26_27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1211' @ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8053'MD, 6603'TVD fe~t 2480 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1200feet. MAXIMUM HOLE ANGLE42' oI (see 20 AAC 25.035 (c) (2) 21 SIZE Hole 24" 1R~" I Casing Weight 16" 10-3/4' ,1 65# 45~5# 26~ Proposed Casing, CASING AND LINER Grade CouplingI Length _1(_-55 2217' K-55 ;T; 8020' _iner and Cementing Program SETTING DEPTH MD TOP TVD 36' I 36' - - i 3~'! 35' I I 33' I 33 I I Amount $500,000 15. Distance to nearest drilling or completed F-6 we~ 120'+ @ Surface feet 18. Approximate spud date I 9/22/82 MD BOTTOM TVD !!5' 1!5' 2252'! 2200' I 8053'1, 6603' I I 2707 psig@~ Surface ~psig@ 5950ft. TD (TVD) QUANTITY OF CEMENT (include stage data) 300 C: f: + llOOsx ext. nerm. ! 250sx Perm C lO00sx Class G 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field development well to approximately 8053~MD~ (6603~TVD) A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-~/4" surface pipe. It will be tested upon instal lation and weekly thereafter. Test pressure will be ~000 psig (1800 psi for annular). Expected maximum surfac, pressure will be 2707 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressur~ calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will b~ logged. The well will be completed with ~-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left i uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparu formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon comple- tion of the job. 1F-7 will be 120' from 1F-6 at surface. Their courses are divergent from there. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED L~. ~J/~ '~. ~(~~ TITLE Sr. Drilling Engineer The space beloyor'- '"---~"' "--" ~~'~r~mKon uSe ~'' - '" Samples required []YES [~0 Permit number APPROVED BY Form 10~401 CONDITIONS OF APPROVAL Mud Icg required EYES ~-NO DATE SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE ~e~t~mb~-~' 15; 1.qR~~'''' by order of the Commission Submit in triplicate Directional Survey required APl number [~ES []NO 50-O Z-~ Surface D~ve ~.r Si/stem , -®. O. . 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. lO" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cal ly upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. -20" ~bell ,nipple. 16" Conductor Maintenance & Operation ~ 1. UpOn initial installation close annular ! preventer and verify that ball valves ! have opened properly. ' · i 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. t 3~ Close annul ar preventer in the event that gas or flui'd flow to surface is 'detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under any circum'stances:' --" ) 7 ( ) . ) ) ( 13-5/8" 5000 PSI RSRRA BOP sTACK PiPE 16" Bradenhead 16" 2000 PSI x l lO" 3000 PSI tub 10" 3000 PSI x 1 adapter spool 13-5/8" 5000 PSI 13-5/8" 5000 PSI and kill lines _. o 13-5/8" 5000 PSI pipe rams. 13-5/8" 5000 PSI. blind rams 13-5/8" 5000 PSI annular ... · . 0" 3000 PSI casing head ing head .. 3-5/8" 5000 PSI pipe rams · dr: 11 i ng spool w/choke ACC~IULATOR CAPACITY TEST : · k CHECK AND FILL ACCUHULATOR RESERVOIR '[0 PROPER LE~'E[ Wild HYDRAULIC FLUID: 2. ASSURE THAT ACCU{-iULATOR PRESSURE IS 3000 PSI WITH. 1500 PSI DE~dlaTREA}t OF THE REGULATOR. 3. OBSERVE TINE THEN CLOSE ALL UNITS SI}O~II. TAME- OUSLY A~iD RECORD l'rlE TIME AND PRESSUP. E REMAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT.' THE ACCEPTABLE LIYdER LIMIT IS 45 SECONDS CLOSING ~fIME AND 1200 PSI RB--v~I NI ~,~ PRESSURE. - . 13-5/8' BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH ARC'DC DIESEL. CHECK I~rIAT ALL HOLD D~dN SCREWS ARE FULLY RE- TRACTED. PREDETE~';INE DEPTH IHAT TEST PLUG WILL SEAT A)ID SEAT IN WELLHEAD. RUCl Ill LOCK I~gN SClLgtlS IN HEAD. CLOSE A~'(UI_AR PREVENTER AND CHOKES ~ BYPASS YALVES ON HANIFOLD. TEST ALL CONPONE~tTS TO 250 PSI AND HOLD FOR lO MINUTES. - INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. OPF4N /~;HULAR PREVE~TER ~ND CLOSE TOP ~ET OF PIPE RAP. S. INCREASE ·PRESSURE TO 3000 PSI AND HOLD FOR HII~JTES. CLOSE VALVES DIRECTLY UPSTRF_/V4 OF CHOICES. ' BLEED DG'~NSTRF_~t PRESSURE TO ZERO PSI TO TEST VALVES. TEST RB. IAINIRG UNTESTED M~IFOLD VALVES, IF ANY, WITH ,3,000 PSI UPSTRE2-¢4 OF VALVE A/;D ZERO PSI D(%d(STREAM. BLEED SYSTEM TO ZERO PSI. - ' . ' OPEN TOP SET OF PIPE RAI4S AND CLOSE BOTTO,~! SET OF PIPE R~S. Ir;CREASE PRESSURE TO 3000 PSI ;L~D HOLD FOR 10 HIRUiES.- BLEED TO ZERO PSI. OPEN BOTTOH SET OF PIPE RR4S. BACK OFF RUN- I(ING JOINT AND~' .PULL OUT OF HOLE. CLOSE BLIND I~.tS AND TEST TO 3000 PSI FOR 10 HIRUTES. BLEED TO ZERO PSI. OPEM BLIIID PJ~4S AND RECOVER TEST PLUG. I~KE SURE H~'~IFOLD AND LIliES ARE FULL OF ARCTIC -. DIESEL ?did ALL VALYES ARE SET 'IN DRILLIRG POSITI(~t. - : . TEST STA~IDPIPE VALVES TO 3000 PSI. ' TEST KELLY COCKS At~D II, SIDE BOP TO 3000 PSI .WITH .KOO:IEY P~-IP. . , - RECORD TEST INFO.~-IA.TION ON BLOWOUT PREVE;ITER TEST FORM SIGri Arid SEND TO DRILLI;;G SUPER- . VISOR... . . , . ' , ' ' ' PERFOR;-I COtIPLETE BOPE TEST OhCE A I,;E~ A:ID ' FUMCTIOr;ALLY OPERATE BOPE DAILY.' .'.. ~: ' ~ . .o CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (~2 thru 8) YES NO 1. Is the permit fee attached ......................................... 2. Is well to be located~in a defined pool ........ .I.,,~ 3.. Is well l°cated pr°per distance fr°m pr°perty li~'iiiiii!!!iiii}'i'ii~ ..... ' 4. Is well located proper distance from other wells .. · . 5. Is sufficient undedicated acreage available in this pool . 6. Is well to be deviated and is well bOre plat included.......~..... . ~. 7, Is operator the only affected party ................, ,'','','1''''''' 8, Can permit be approved before ten-day wait ,' ........ ''' '' ' '''''''. , , ~__ (9 thru 11) 10, 11, (4) ,casg ~ ~ (12 thru .20) (21 thru 24) 12,¸ 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a bond in force .................................. (~x_ Is a conservatiOn order needed ....................................... ? ~ Is administrative approval, needed ................................... ,z~~] Is conductor string provided Is'enough cement used to.circulate on conductor and surface ........ Will cement tie in surface and intermediate or production strings Will cement cover all known prOductive horizons ...... . ,~ Will surface casing protect fresh water zones ...~.~1.~1~,.~1~. Will all casing give adequate safety in collapse, tension and burst . Is this well to be kicked off from an existing wellbore .............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... ~-~ Is a diverter system required ....................................... ff~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~zZ~-ZP psig ,, ~ Does the choke manifold comply w/API RP-53 (Feb,78) .................. Additional requirements ............................................. REMARKS N~7- so~M~v77'fO Additional Remarks: (D Geology: Engigeering: WVA JKT J-- RAD ]-- JAL~ MTM ~ HJH ~ rev: 08/19/82 INITIAL GEO, UNIT ON./OFF pOoL CLASS STATUS AREA NO, SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No Special'effort has been made to chronologically organize this category of information. .o bVP OIO.HOI VERIFICATION b~STING PAGE I ** REEL HEADER SgRVICE NAME )SERVIC DATE 8~/10/13 ORIGI~ REEbNAME CONTXNUATION # ~0! PREVIOUS RB~b COMMENTS {SCHLUMBERGER WELL SERVICES FIELD TAPE ** TAPE, HEADER SERVICE NAME {$ERVIC DATE ORIGIN ~6567 TAPE NAME PREVIOUS TAPE COMMENTS {SCHLUMBERGER WELL SERVXCES FIE~D TAPE VER$ # ) ,001 5VP OiO,HOi VERIFICATION 5{STING PAGE 2 ** RECORD TYPE 047 ** RECORD TYPE 047 ** ** COMMENTS ** l' ~ $CHbU~B~RGER I AbASKA CONPUTING CENTER COMPANY "ATbANTIC RICHFIEbD COMPANY rlgbP = KUPARUK COUNTY s, NORTH SbOlaE BOROUGH STATE = AbASKA JOB NUMBER AT ACCI ,65671 5¥P OIO,H01 VERIFXCATZO~ 5ISTZNG PAGE DENSITY = 10,0 LB/G VISCOSIT~ = 43.0 $ PH B 10.0 FLUID bOSS = 5,6 C3 R~F m , 65,0 DF R~ AT BHT = , 152~0 DF MATRIX SANDSTONE ** DATA FORMAT RECORD ENTRY BhOCKS TYPE SIZE REPR CODE ENTRY 4 8 4 73 60 DATUM SPECIFICATION BLOCKS ~U bVP 010.H01 VERIFICATION blSTING PAGE 4 DT BH¢ U$1F 60 GR BHC GAPI 60 52 32 0 0 31. :{2 0 0 DEPT SP DRHO CAb! GR 7727 -22 -999 il -999 5000 SFL, U 3594 OR 2500 RHOB 5000 $P 2500 DEPT GR 7700 0000 8FLU RHOB tt 55'47 SP -999 2500 DEPT SP DRHO CAbI GR DEPT 7600 0000 srbu ll3 5 7500 2,8184 IL'M 9~93.4063 NPH! · ' ,2500 NCNb' "22,3594 GR 2,9668 MPH{ ,4063 ¢23,4824 I~CNL "23 ' 95,31, GR 9746 Ibl~ 6094: GR 3 t8'87 Ib~ 8 4 0 4 0 47il5 9 500 rCNb 43.4063 2,4316 lbD 43,6035 RNRA I .oooo · 4063 DT 1,5986 IL, D F'CNL, 105,6875 DT 2: ,80 I.L,D 1 68 1 2,4043 -999,2500 -999,2500 '999,,2500 2 3457 3 8287 218 8750 -999 2500 4923'9736 .5000 109,1875 3 0605 bVP 010,H01 VERIFICATION blSTING PAGE 5 617 DRHO 7000 0000 SFLU -15 1094 GR 0 0044 RHOB 10 0547 6P 187 1250 4,0977 ILM 219,5000 NPH! '2,3945 NCNL -15,1094 GR DEPT SP DRHO R 6900 0000 SFLU ,,,9 6406 OR -999 2500 RHOB 228 8'/ 3 4258 47 2168 RNRA 1899 0000 219 5000 DT DEPT 6800 0000 SFLU -999 O0 RNOB 6250 3,2793 4,~188 455, 500 110,0000 D£PT SIP, DRHO 6700 0000 SFLU .,,16 2,7051 IbM 2,2441 IbD 2,1152 174,3750 .PHI -999.2500 RNRA .,999,2500 -999,2500 NCNL -999,2500 FCNL -999,2500 -9,6406 GR 174,~750 DT 115,3750 ?$00 NPH! 999,2500 NCNL · '22,1250 GR i4 IbM ,,, 16: 3,1836 ILD 3,0313 -999 ~500 RNRA -999,2500 -999:~500 FCNL -999,2500 130,7500 DT 91,1875 3,4297 ILD ,5254 ° 999, FCNL 99~,2500 103,5625 DT 108,7500 O' GR D~PT 6600.~.C~.C~: 0000 SFLU .~:=,~i~j3 7227' IbM 9160 IbD 0000 SFLU D E: P T 6'4 '0"0' 3 311 bVP OIO,HO1 VERIFICATION LISTING PAGE DE:PT SP DRHO 61.00 0000 SFLU ,,18 4063 GR -999 2500 RHDB 9 6250 SP 166 2500 2 0625 '/6: 6250 NP H -999~2500 NCNL 't8,4063 GR DEPT DRHO 6000 0000 &FLU -30 87'50 GR .,999 2500 RHOB oo 4,9805 Ib~ ,8750 NPHI -~9;2500 NCNL -30,8750 GR DEPT 5900,0000 6FLU 2,61.52 SP GR 97; 6250 DEPT 5800,0000 SrbU 2 i586 'IbM CAbI ~R 90,1250 __4 GR 99~ 8340 .999~2500 RNRA ,2500 FCNL 176,6250 DT 3,9668 ILD -999,2500 RNRA -999"2500 FCNL 199,8750 DT 2 6035 IbD -999 2500 RNRA -999 2500 FCNL 99 2500 DT 2,8301 ILD "~99'2500 RNRA ' 99,2500 FCNL 86,5000 DT !I1 ILD 6914 -999,2500 108,0000 3 9766 ,,999 2500 -999 2500 109 5625 :9992:59~8 2500 999,2500 99.1875 2 8496 '999 2500 -999 2500 97 ~ 5625 2 1 100: DE;: >T GR bVP OlO.HO1 VERIFICATION blSTING PAGE DEPT SI:' DRHO DEPT Sp DRHO DEPT ..o 5200 0000 SFLU · ,31 8906 GR ,,.999 2500 RHOB 989 6484 &P 1a75 5100,0000 SFbU .'"34,9'06,2 GR 999.2500 RHOB 9~9.'6875 SP ,3750 5000 0000 SFbU ,,, ,4,8 DEPT 4900 ~RPHO .-34999 000 8FbU 2,4824 ILM 89,9375 NPH! -999,2500 NCNL -3~,8906 GR 2,3867 IbM 9~.tl750 WNPHI ,2500 CNb -34'.9062 GR 2 2.5234 -999,2500 RNRA 2,5898 -999,2500 -999,2500 FCNL 94,8750 DT 8828 IbM 2,8281 IbD NCNb -999, O0 FCNL 3438 GR 90,9375 DT 2,6406 IbM 062'5 N:PH! 2500 NCNL 6250' OR 2 3984 ILD ..,999 2500 RNRA 999 2500 FCNb 82 0625 DT DEPT 2 0762 ILD 4800 0000 SFLU 94000 D? 2 5234 -999:2500 -999,2500 106,5625 2,6719 '999.22~00 -999. O0 105,0000 2,8398 '999,2500 -999,2500 102,5625 '999, O0 -999, O0 105,5625 2,0664 · 2500 t::! :i ~ 562 5 GR. ',R DEP? bVP OtO,HO! VERIFICATION LISTING PAGE 8 DEFT 4300 SP DRHO -999 CALX 1½ GR 9 0000 SFbU 2 68?5 (;R 98: 2500 RHOB -999, 3594 SP -.41, 3125 7109 ILi~ 2,7773 ILD _2,8184 ~25 NPH! -999.250~ RNRA -999.2500 O0 NCNb -999,250 FCNL -999,2500 6875 OR 98,3125 DT 118,0000 DEFT 4200 SP ,,,47 DRHO -999 0000 SFLU 25 RHOB 2031 SP 0000 DEPT 4100 SP DRHO 0 CA{.,I 11 GR 100 0000 SFLU 2187 OR 0059 RHOB e{,72 SP 3750 DEPT 4000 SP DRHO 0 CAI,! 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