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185-178
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SEP j SE 20,9 �,- r% ll,-� 1. Operations Abandon ❑ Plug Pertorations ❑ Fracture Stimulate ❑ Pull Tubing ❑ ONoianons murdowii „.I❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Whipstock D 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service p 185-178 3. Address: P. 0. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-029-21407-00-00 7. Property Designation (Lease Number): B. Well Name and Number: ADL 25635 K RU IR -04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field/West Sak Pool 11. Present Well Condition Summary: Total Depth measured 8,440 feet Plugs measured N/A feet true vertical 6,864 feet Junk measured N/A feet Effective Depth measured 3,711 feet Packer measured 6062, 738q 3374, 7706 feet true vertical 3,503 feet true vertical 5127, 6064, 3245, 6303 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 16 115' MD 115' TVD SURFACE 4,261 feet 95/81, 4,298' MD 3927' TVD PRODUCTION 8,392 feet 7 8,427' MD 6853' TVD SCAB LINER 328 feet 4 1/2 " 3,686' MD 3484' TVD Perforation depth: Measured depth: PLUGGED feet True Vertical depth: PLUGGED feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 8,047' MD 6,559' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- BAKER FP LINER TOP PKF 3,374' MD 3,245' 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 Gar _Mc` Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments (required per 20 MG 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development ❑ Servic❑' Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ EI 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: 319-328 Authorized Name: James Ohlinger contact Name: Shane Germann Authorized Title: Staff CTD Engineer Contact Email: Shane.Germann@cop.com Contact Phone: (907) 263-4597 Authorized Signature. �e+C 1SS t Date: \ Form 10-404 Revised 4/2017 I(/�%�, In/3 ly 313DMSSF° 19 2019 Submit Original Only 1 R-104 Plug Perforations, Perforate New Pool Re -Enter Susp Well, Pull Tubing Set Whipstock DTTMSTPJOBTYP SUMMARYOPS 5/21/19 RECOMPLETION MIRU. Rig accepted at 1300 hours. Take on 9.0 ppg Sea water in pits. Pull BPV. Displace diesel out of well to 9.0 ppg Sea Water. Nipple down production tree. Nipple BOP. 5/22/19 RECOMPLETION Perform in between well BOP maintenance. Pressure test BOP. Pull tubing hanger. 5/23/19 RECOMPLETION 5/23/19 DRILLING 5/24/19 5/24/19 5/25/19 5/26/19 5/27/19 SUPPORT - CAPITAL RECOMPLETION DRILLING SUPPORT - CAPITAL CBU. POOH LD 3 1/2" tubing. MIRU eline set CIBP, ND BOP, back off nuts on Tubing head to allow growth. MIRU Eline. Attempt to drift w/ 5.93" Gauge ring and hang up in tree. Run in with 5.74" SL Centralizer and tag top of tubing stub at 4506'. Log GR/CCL to confirm correlation for plug passes. Set first CIBP at 3710' to avoid collar. CCL to Mid 4 bolt tubing head and allow casing to grow. Wait on PESI Hydratight personnel. NU BOP and build 40 stands of 3-1/2" drill pipe. ND BOP. RU Hydratight and allow 7" casing to grow. Stretch 7" casing with 7" spear. Land casing NU new tubing head, BOP. (7ES RIG JOB) DRIFT 7" CSG TO IRON PLUG @ 3587' RKB w/ 5.735" CENT & 5.97" DRILL BIT. COMPLETE RECOMPLETION Slick line gauge ring run. Perforate well on DP. RIH w/ wash tool. RECOMPLETION Cement. WOC. RECOMPLETION WOC, drill out. 5/28/19 RECOMPLETION Drill out Cement PT. 5/29/19 RECOMPLETION Continue to displace well to clean brine. POOH. Lay down BHA. Perform USIT log. Run 4-1/2" liner. Cement the same. POOH laying down pipe in singles. 5/29/19 DRILLING **RIG JOB ON NABORS 7ES*** LOG USIT AND CBL. JOB COMPLETE. SUPPORT - CAPITAL 5/30/19 RECOMPLETION Continue laying down drill pipe. Run 4-1/2" completion string. 5/31/19 RECOMPLETION Finish Running 4-1/2" 12.6# L-80 503 completion String. Land tubing hanger. NU tree and freeze protect. 6/30/19 DRILLING (PRE -CTD) : TREE VALVE DDT PASSED ON SV, SSV & MV, TREE VALVE PPT SUPPORT- PASSED ON SV, SSV & MV. CAPITAL 7/20/19 DRILLING DRIFT w/ 3" BAILER TO TOP OF CEMENT @ 3579'RKB. DRIFT w/ 17'x3 5/8" SUPPORT- DUMMY WHIPSTOCK TO 3575'RKB. SET 3.81" X -LOCK & FLOW THROUGH CAPITAL SUB @ 3549'RKB. VERIFY LOCK FULLY SET w/ X CHECK SET. IN PROGRESS. 7/21/19 DRILLING SET CATCHER ON X -LOCK @ 3549'RKB. PULL DMY & SET GLV @ 2491'RKB. SUPPORT- PULL SOV @ 3309'RKB. MULTIPLE ATTEMPTS TO SET OV @ SAME. UNABLE CAPITAL TO FULLY NO-GO VALVE IN POCKET. IN PROGRESS. 7/22/19 DRILLING PULL OV, BRUSH POCKET & RE -SET OV @ 3308'RKB. IDENTIFY LEAK IN GLM SUPPORT- @ 2491'SLM. PULL & RE -SET GLV @ SAME. MIT -T TO 2500PSI *PASS*. PULL CAPITAL CATCHER @ 3549'RKB. READY FOR E -LINE TO SET WHIPSTOCK, IN PROGRESS. 7/24/19 DRILLING SET NORTHERN SOLUTIONS 4.5" INNER WEDGE ON TOP OF X -LOCK. SUPPORT- WHIPSTOCK ORIENTED 4 DEG ROHS ON X -LOCK AT 3549'. TOP OF CAPITAL WHIPSTOCK AT 3533.3'. PIP TAGS INSTALLED AT 3540.3'. LOGGED GAMMA RAY / CCL PASS FROM TAG DEPTH TO 2400'. JOB COMPLETE. .111", KUP INJ WELLNAME 7R-04 WELLBORE 1R-04 Conocor't fillips 1 " Well Attributes Max Angle 8 MD rD Alaska,Inc. 030 aPuude wndean.staus Icy°l mo lnxa) .Blum. USDPARIIK RIVFFi UNIT �cnlece vno III.. �V.,.. F 'DacatianowU:315n AM Last Tag wlypb Vertisl xlvmacpent, ......_................. HANGER.33.0...__........ ......_....... Last Tag: SLM Annoandon Cepin nx(BI Fntl Oah Wel Move Ws[Matl By 6,12111 ]/52014 I 1R-04 ",.hkf ...................... ................. .-- ................ ... .............. Last Rev Reason AnnotationEnd Rev Reason: Indallednew GLD Dam wennore vatmad By 9/10/2019 1R-04 jhansen8 'Casing Strings corvoucmR, ae.onso Caere Description CONDUCTOR OD pat m (In) 16 1506 Top ST 6) DepthsetKa set Depth m0 WULen U... G2aa Too Th tend 38.0 115.0 d 1150 ) 65.00 Hop WELDED INJECTION', 3499.7 Path, Dus=npibn SURFACE Do (in) IO (in) 95/8 8.92 Top MKB) SIT Depth MKB) Sat Depth (10) WULen II... Grade Top Tnhead 37.0 4,2915 3,92].1 36.00 J-55 BTC 1wSOT10N; steel NIPPLE,3ddG2 Casln00esch, on an (in) 10 (in) 7 628 Top IN(B) Set Depth lrMB) Set Depth (I va,.. WULenI Gntle Tap Th deadPRODUCTION 35.0 8,426.5 8853.1 28.00 155 BTC Cash, Des=ripebn On (in) ID (in) Top MILED 50Depth (ftke) Set Japan( ga,... woten g... crave TOP Tnreea qb SCAB LINER e dond 512 4.95 6,057.0 7,400.0 6,078.7 15.50 L-80 5-112 Hyd LOCATOR: 3354., 511 Liner Details - SFU ASW 3,.B Top mKB) roPV`Fd(hK ES roP Incl C) Item Orsom1na11D Co.am in) 6,081.8 5,12].4 41.39 PACKER CHP LINER TOP PACKER 4,940 ],380.4 6,064.4 43.60 PACKER 3D LINERHANGER PACKER 4950 �` snburv', 33onfun. y Conant sau=em;83E80eKa _ CMT 602: 3,3Efl03,559,0 ? y Caning Ms=rlp4an SCAB LINER 00 (in) IF( 0 (in) 4112 4.Op Top IKKB) $at Dep.. 11-1 SN Oe to 3,351.8 3686.0 3,464.3 DYD1 11 fi0n (1... Gentle Top Thread 80 BTCM Liner Details Top 3,35 Top(( DUMB) Top Incl P) Item Des Co. eems'lO (in) 3,3528 3,232.8 3820 PBR Scab Liner PER 5250 xa6K 3,52s.o 3,3]31 3,245.2 38,06 PACKER Liner Top Packer Baker FP 4-112"x]" VT P IBTb 3.810 WHmsTDCKa..a 3,4p3.9 3,269.1 3789 7 N I P WPLE X Nipple HES 3.813.5fi3 BKP 3958 x-Lo<xp.5ae.o 3,504.0 3,347.4 3961 WEDGE ASSY Wedge Assy Northern Solutions 4.000 Tutting Strings Tubing Des[ripron OLD TUBING LEFT IN HOLE senna Ma._min) 312 2.99 Top lttKBl 4,500.2 Srt Dep I, IS ],)04.0 T---1 Depth(TVI S F. 6,301.4 Wl nand 9.30 Grade L-80 TIP Connection IBTM scAe urvER:3.3s2as,eeeo Completion Details FISH; 3,7080 v6anuxexr exmGE PLUG; Da.2 Top(N0d Top (IIKB) (tlKed ],MKS) 6,291.6 iop Incl (') Ihm aes !2.11211OCATOR Can BAKER LOCATOR Nominal Grind 3000 7,6935 6,293.6 42.10 SEALASSY BAK R8040S LgSSEMBLV STB INTO A PACKER ER 390p SUHFACE; 3]D ..... 5 JET CUT, 4sm0 Tubina 0esanpllon STACKER, Srnng Ma... ID (in) 3112 2.99 11 D KB) as Depth (fir.. 3 7,6926 ],]91.0 60 0epM ,3663 RVD)I MIND) do L3o 1pconnechon Completion Details Top IRKS ToP D" (gold "Panto 1 0191,91 Top Incl I°) han Des 42.11 IFBR Co. BAKER 8040 PER Nominal ID (an) 3.020 7,706.0 6,302.8 4201 PACKER BAKER FHL PACKER 2.930 ce.a's"11.14darae " scA3 UNERAane and:Sgice ],]48.9 6,334.8 4T72 NIPPLE CAMCO DS NIPPLE NO GO pglp 1 aou.0 CFMENTREDBNER', 7,6100 7,789.7 6,365.3 4145 SEALASSY BAKER 8040 SEAL ASSEMBLY 3.000 Cemem PIM:7,1W.OXHB a Tubing Deeniption TUBING ORIGINAL Shlna Ma... IDun) 4 2.99 iop(RKB) Set Depth (11.. 8th Depth (NO)L.. Wt(IMp 7,]902 8,04]5 Sat Dep 93 Gude Top Connedlon GAS LIFT: Test Completion Details - LouToa; 7Tw1z T (TVD) TopeLKB) SMED Drainer I•) Ile. Des Com rvominel ID Bir) 7,8015 6,3]4.1 41.38 PBR BAKER PBR 300g sEALASGY, Tests PER ; 76R2.e ],8152 6,3844 41.39 PACKER BgKER FHL PgCKER 3.000 PPp ER.7mao 7,8913 6,4415 4143 BLAST RINGS (2)BIAST RINGS 2992 7,985,1 6,512.1 40.86 NIPPLE AVA PORTED NIPPLE 2750 NmPLe, 774es 8,022.6 6,540.4 4011 LOCATOR BAKER LOCATOR SUB 2,406 8,0244 6,541.8 40]0 PACKER BAKER FBA PACKER 2347 SEAL ASSY. 37097 8,039.2 6,553.0 40591 -NIPPLE CAMCO'D'NIPPLE 2.250 PACKEH;7et52 8,046.8 6,5588 40.53 SOS CASCO SHEAROUT SUB 2441 Other In Hole (Wireline retrievable plugs, valves, pumps, Rah, etc.) Top (WS Top 1n=1 TUBING PERFORATION; To25o PATCH ; Zew.o 1w6cnON,tesse Top(WES MKB) 3,5230 3,361.] (°) Des 39.96 X - Lock Co. Set 3.81'X -Lock w/flow thru sub. l9"GAL Run Oate ID (in) 8192019 0.000 3,533.3 3,369.6 40.15 WHIPSTOCK Set Ng, am Dlutions Inner Wedge on to oX- 9 P Lock @3549'. 2 Pip tags installed T below rop of whipstock. Top of whipstock at 3533.3. GAL 15.71'. 712412019 1.000 3,549.0 3,3816 40.45 X -Lock Set3a1"Xlock wl0ow thru sub. l8"GAL 712112019 0.000 IPERF;7,B92o7.a3zn� 3,708.0 3,5005 42.3] FISH Dtllled up IBP andpushadrobOROm a top IB at 3709 WWO19 SLEEVE -c: 39664 ,Hp"E, Tsse, T,709.2 3,501.4 42.39 PERM N BRIDGE PLUG Wft CIBP 512312019 L C.F: :g"' al PACKER; e,oza4 4,500.0 4,0]0.5 46.28 JETCUT Jet Cut Tb CCL 44866' 91 ) 4242019 2.992 NIPPLE, Ba3g2 ],610.0 6,231.9 42.73 C MENT RETAINER Set 3.5" Cement Retainer. 2.75"x I46'Iong. 4212019 0.000 sos:got,a 7,825.0 6,91.8 41.39TUBING PERFORATION MH-EGFX2-U T -MP ' 'Loaded) Thing Punch SPD 32&2019 2.982 �' ],8400 8,403.0 41.40 PATCH HES RCP patch, length 27.46, isolating station M9 GLM 522000 1.310 marepa"8c.9n40� 1,9851 6,512.1 40.86 SLEEVE -C BPI ISO Sleeve Bet4/12000 4/12000 2.310 esH;4uso 8,1360 6,62fi9 39.8] FISH R Valve Left Paceen, Hole 6122/1995 IPERF;a.Ns D$18B0� PRODUCTION', 35.00.4265 ConocoPhillips Alaska, Inc. CMT INJECTION; NIPPLE; .- K BU0.FgCE: 3l OJ.IDl B� SEAL g55V; POR; PACKER; TARING PERFOF SLEEVE-; NIPPLE', LOCATOR: PgCKE R: IPERF: 8.118OS,i N O� PRODUCTION, KUP INJ WELLNAME 1R-04 WELLBORE 1R-04 Dab, KUP INJ WELLNAME 1R-04 WELLBORE 1R-104 li-onocornnnpS Fta,"a.aRIVE MaxAngle TD Alaska Irm.�Ill FIeN NeTe 5an,p2 APWWI Wall N) clic) Mo mKB) pcI BIm IXKBI 4.08 4,269.48 10,885.0 r::mt:a Comment HRS 1ppm) peb pnnopEon Entl pah ---GM To Rigso-Dao LAST WO: 3869 911 W1985 1R-tw. a+Mzmetp3l s, AM Last Tag vcNalsawT.&Lcw+p a��Ann°tatl°n pnnotNion BapWlftK M wellWre Laae Moa avASTTAG1R-104 lennalt........................................................... Last Rev Reason te Reason. Liner Top Packer, Set DVs W¢IIWrt Last Mad avRev 1R-104 'FrajCasing StringscasbDescripnon ODlinl m(in) TOP IrtxBI sem lrvDl... waLen 11 cIdu Top Th,eaaCTD-Liner 2316 244 34]33 10fi 6.50 L-80 H533Liner Details Top(IKe) 3,4733 Top lNp)(ONE) 3,323.4 Top Incl f) 39.OJ Ihm Or,Nominul1. SBR eel Bore m Deployment sleeve warn 6' seal bore ) 2.990 r;.:.R Recepucle) sup -nal 3,825.3 3,453.7 88,43 CRO VER REDUCING Cross over3-i2"-2-718" 2.391 8,664.2 JAM, 9260 I D9PITY—M—EWOH SLEEVE Permanent,CLL 2.3]5 INJECTION: 2.437 Tubing Strings Tubing Descapli°n a1nnB Ma... UPPER 4.92fi COMPLETION Ip Iln) 3.9fi Top (nKa) 33.0 Sat DepIM1Set 3,364.4 pep(n lNp)1... 3,2329 WI (IbXlf 12.75 Gratla L-00 Top C°nnectlon HVD 503 Completion Details Ixsacnal ox;a,se Top (XKa) To1pnK(ryp) rop incl Nominal 1 fl nem Des Co. ID lin) 33.0 330 0.00 HANGER Hanger FMC no IV 11"x4112"CUE BXP+XO pup EUEx563 3.958 NIPPLE; s,33s.z 3,333.3 3,213.5 38.42 NIPPLE %Nipple 3.813HVD 563381GX]169 3.813 3,354.1 3,229.8 38.23 LOCATOR Tieback locator 3.980 3,354.8 3,2304 38.23 SEALASSV Tieback Seals 1805'spacetl Bu11.59 feet) 3.980 LOCATOR) 3. 4.1 Other In to (Wireline retrievable plugs, valves, pumps, fish, etc,) ToplNp) Top Incl .E ,OsV;3359.a Top fftKB) (XKB) 3,473.0 3,323.2 (1) 39.07 Co. —NJN— RETRIEVABLE Co. Baker 45 Fla- uartl Pa erL-8 wl NONhem Dlutipns PT SA. OAL10'Md%OD2.J0" Run Dar, 8232019 ID(ln) 2.310 LINER TOP PACKER 3,506.0 3,3502 40.01 WHIPSTOCK et NorNem olNipns Inner Wetlge on topo X -Loc @35231 2 Pip uBs inslalletl T below wp of whipstock. Top of whipsbck a13506', 0" (high sitle) prienlagon, OAL 8/10/2019 1.000 Perforations & Slots _ PRODUCTION sPsa ;3a9.93,aa6. RO; S.p9,G]9,6 �' `81 1J Top FINE) I mKB) Toplrvp) I1Kii atm lrvDl mKB) LInM HZone Top,) perm bnabm Type COm 3,398.0 3,558.0 3?64.4 3,385.8 51252019 12.0 CMT SQZ 5118"1 spfxzg RDX BH TCP pert guns Cements QUeeZBe SURFACE; 3>pi,zBi.e _ NON RETRIEYgaLE LINER Y('.: TOP PACKER:'J7sR cemem sw—', 3399.pnne CMT sox; 33ss.w,.a 'c Yj _.rSY Top(WE) alm("R) T°p(NDI mKB ) or" O) (RKa ) Dei --Rpate Lom 3,398.0 3,556.0 3,264.4 3,385.8 SQUEEZE EMEN 51262019 34 bbls of 15.6 ppg pumpea ^� Mandrel Inserts t N Top(Ran) TopIN D) Valve ta4M1 Poalze STRO Run M-) Mahe Motlel Op lin) Sery TyPo TYPo (In) :pig 0.un 0ek Lam 1'. WHEsTOCK35OLO ..0 Lilac R373.D Ina .1 -ac ° rv> � t�e81— 1 ' 2,488.7 2,478.7 Cam-- KBMG 5984 GAS LIFT GLV BK 0.188 1,524.0 9/1012019 3,306.6 3 192 Cam.D IRrawo, 1 5.984 rJAb LIFT 10V jBK 1 01881 00 91102019 Notes: General & Safety E 2 Top,pnnobaon ,� 9/182019 NOTE View Schematic w/Alaska ScrNvT.,o,oO I 1 111 LTD-bhvr,34Y].310.,Ra. PTD /BS—/ -7S/ Loepp, Victoria T (CED) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Thursday, July 18, 2019 12:39 PM To: Loepp, Victoria T (CED) Cc: Eller, J Gary Subject: RE: [EXTERNAL)KRU 1 R-04(PTD 185-178) Perf Interval Cement Evaluation Attachments: Job Log - 1 R-04.pdf, 1 R-04 CBL-VDL 29-May-2019.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, I have attached the CBL and Archer job log for your reference. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 KVIe.Hampton@cop.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, July 16, 2019 11:03 AM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Eller, J Gary <1.Gary.Eller@conocophillips.com> Subject: [EXTERNAL]KRU 1R-04(PTD 185-178) Perf Interval Cement Evaluation Kyle, Could you please resend the Archer log and CBL referred to in the email you sent below(5/29/19 3:11 PM). I can't seem to locate it. Thank, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victona.Loegp(&alaska qov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loeop@alaska aov From: Hampton, Kyle <Kyle Hampton@conocophillips.com> Sent: Wednesday, May 29, 2019 11:08 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Eller, J Gary <J.Gary Eller@conocophillips.com>; Regg, James B (CED) <iim.regg@alaska.gov>; Regg, James B (CED) <iim.regg@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden conocophillips.com> Subject: RE: [EXTERNAL]RE: 111-04 Perf Interval Cement Evaluation Victoria, Our perforations were from 3,398' RKB to 3,548' RKB. The interval was shifted away from the 7" casing collars, —20' relative to the sundry depths provided. Based on the CBL, we interpret good coverage from 3,398' RKB to 3,556' RKB. We have good cement coverage above and across the perforated interval. I attached an email Gary sent about this depth correction. While pressure testing the 7" casing across the perfs, we were leaking at 3 psi/min, leaking from inside the 7" casing (most likely at the base of the perf interval) to the 7" x 9-5/8" annulus. While testing, we did not observe any pressure at surface on the OA; we passed an MIT -OA prior to rigging up, but we have not performed a new test since. We do not plan to change our cement job because we believe we have sufficient cement coverage from the perf cement job. Both 113-26 and 1R-04 and being converted into CTD injector wells; they should be under the same considerations. CTD is planning an uncemented liner. I attached an email Gary sent about this well previously. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle.Hampton@cop.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.Rov> Sent: Wednesday, May 29, 2019 4:19 PM To: Hampton, Kyle <KVie Hampton@conocophillips.com> Cc: Eller, J Gary <1.Gary.Eller@conocophillips.com>; Regg, James B (CED) <lim.regg@alaska.gov>; Regg, James B (CED) <iim.regg@alaska.gov>; Senden, R. Tyler <R Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]RE: 111-04 Perf Interval Cement Evaluation Kyle, Gary, There appears to be no cement above the top perforation — about 14' of perfs above the cement. The pressure loss of 3 psi/min is much lower than 113-26. What leak rate does this correspond to? I am concerned that the open perfs are above the top of cement. Is there any indication of OA pressure? Any changes in your planned liner cement job? 113-26 is a producer and this well is an injector so the situation is different. How will this well be completed? Victoria From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Wednesday, May 29, 2019 3:11 PM To: Loepp, Victoria T (CED) <victoria.loepo@alaska.gov>; Regg, James B (CED) <iim.regg@alaska.gov> Cc: Senden, R. Tyler <R Tvler Senden@conocophillips.com>; Eller, J Gary <J Gary Eller@conocophillips.com>; Hayes, James C <James.C.Hayes@conocophillips.com>; NSK RWO CoMan<NSKRWOCoMan@conocophillips.com> Subject: 111-04 Perf Interval Cement Evaluation Victoria, We are preparing to run and cement the 4-1/2" liner on 111-20 (PTD 185-178). We have drilled out the cement, passing a 14.2 ppg EMW test 50' above the perforated interval but leaking at 3 psi/min on a 14.2ppg EMW test after drilling out the perforated interval. We believe we have a properly cemented annulus based on the CBL and wash/cement job conditions. The results are very similar to SR -26, so we are planning to proceed forward with running the liner and cementing it in place. Do you need any other information from us before proceeding? I have attached the Archer log and CBL. Please let me know if you have any questions. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle. Hampton@cop.com rAciqui8itionVersion ell 2018 8.2.104493.3100 7Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include Parallel Data Run 4 Log[5]:Up Up 3258.89 ft 3703.43 ft 29 -May -2019 11:16:30 AM 29 -May -2019 11:31:38 AM ON 16.50 ft No All depths are referenced to toolstring zero • • Company:ConocoPhillips (Alaska), Inc. WellAR-04 Description: CBL_VDL Format: Log( Sonic CBL with VDL) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 29 -May -201911:47:40 � BIEP - Bond Index Event Pips DSLT-H TIME -1900 - Time Marked every 60.00 (s) Stuck Tool CBL Amplitude (CBL) DSLT-H Indicator, Total (STIT) 0 mV 50 0 ft 50 CBL Amplitude (CBL) DSLT-H Gamma Ray (ECGR_EDTC) EDTC-B Cable 0 mV 10 0 gAPI 150 Tension Good Bond (GOBO) Min Amplitude Max (TENS) Transit Time for CBL - - - - ' 0 mV 10 (TT) DSLT-H 10000 0 ' • .. , ; Variable Density Log (VDL) DSLT-H 400 us 200 Ibf ; ; ; ,GoodBond from CBL to GOBO•; ; : ; ; 200 us 1200 3220 3230 3240 3250 3260 3270 3280 ' 33003310 - — -� 1 9 t j i o- . ---- - - .. FJ73290 41 m 3� 3540 3550 3560 3570 3580 3590 3600 ' 3610 3620 3630 3640 3650 3660 3670 3680 3690 3700 Gamma Ray (ECGR_EDTC) EDTC-B Stuck Tod CBL Amplitude (CBL) DSLT-H 0 gAPI 150 Indicator, 0 mV 50 Total (STIT) Transit Time for CBL (TT) DSLT-H 0 It 50 CBL Amplitude (CBL) DSLT-H 400 us 200 0 mV 10 Cable Tension Good Bond (GOBO) (TENS) 0 mV 10 10000bf 0 - - ,Goo Bond from CBL to GOBO-.•; I TIME_1900 - Time Marked every 60.00 (s) '(i Min Amplitude Variable Density Log (VDL) DSLT-H 200 us BIEP - Bond Index Event Pips DSLT-H CBL_VDL Format: Log( Sonic CBL with VDL ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth 311:47:40 Date: Run 4: Parameters Parameter Description Tod Value Unit AMSG Auxiliary Minimum Sliding Gate DSLT-H 126 us BARI(ISSBAR) Barite Mud Presence Flag Borehole No BHS Borehole Status (Open or Cased Hole) Borehole Cased SS Bit Size WLSESSION 12.25 in CBLG CBL Gate Width DSLT-H 69 us CBLO Casing Bottom (Logger) WLSESSION 8427 8 CBRA CBL LQC Reference Amplitude in Free Pipe DSLT-H 62 mV COEN Cement Density EDTC-B 2 g1cm3 CMTV(U-USR_CEMT) Cement Type USIT-E Regular Cement DETE Delta -T Detection DSLT-H E1 DFD Drilling Fluid Density Borehole 9 lbMgal GCSE DOWN_PASS Generalized Caliper Selection for WL Log Down Passes Borehole BS(RT) GCSE_UP PASS Generalized Caliper Selection for WL Log Up Passes Borehole BS(RT) GOSO CURR Good Bond in Arbitrary Cement DSLT-H 2.87 mV [MAR Image Rotation USIT-E OS MAHTR Manual High Threshold Reference for first arrival detection DSLT-H 120 MATT_CURR Maximum Attenuation in Arbitrary Cement DSLT-H 11.82 dB/It MCI Minimum Cemented Interval for Isolation DSLT-H 14.81 8 MNHTR Minimum High Threshold Reference for first amval detection DSLT-H 100 MSA Minimum Sonic Amplitude DSLT-H 1.33 mV MSA_CURR Minimum Sonic Amplitude in Arbitrary Cement DSLT-H 1.33 mV NMSG Near Minimum Sliding Gate DSLT-H 257 us SGAD Sliding Gate Status DSLT-H OS SGDT Sliding Gate Delta -T DSLT-FI 47 usftl U-USR'_DFSZ Drilling Fluid Specific Acoustic Impedance USIT-E 0 Mreyl USI FVEL SEL USI Fluid Velocity Selection USIT-E Automatic USI ZMUD SEL USI Mud Impedance Selection USIT-E Theoretical Run 4: Parameters Parameter Description Tod Value Unit MODE DSLT Acquisition Mode DSLT-H CBL RATE DSLT Firing Rate DSLT-H 15 Hz DTFS DSLT Telemetry France Size DSLT-H 536 MAX_LOG SPEED Toolstdng Maximum Logging Speed WLSESSION 5000 tt/h SON Selectable Acquisition Gain DSLT-H x1 ULOG Logging Objective USIT-E MEASUREMENT UPAT USR Emission Pattern USIT-E Pattern 375 KHz UWKM USIT Working Mode USIT-E Uncompressed 1G deg at 6.0 in K17.05.2019 I 0800 I riranoon Leccese and Krzysztof Roicki check in Anchorage airport for a flight to Kunaruk 11.30Reached KOC Camp In Kuparuk. Meet with Sean Helton /Ql�neri r�4..�J__u _ 16:00 18.05.2019 1 16:00 10:00 11:00 Visit rig Nabors 7ES. Talk to company man. Rig currently on well iR-20 and RIH WBCU. Next operation: RIH completion. niroo Visit location. Current ops: RIH Had issues RIH Comnlatinn he* 0 ink basket and gauge ring. had to POnH has 21.05.2019 1 15:00 Come to location. Rig has moved over well 1R-04. Current ops: killing the well before settingBPV and N/D X mas tree. 22.05.2019 12:00 Visit location. Current ops: testing BOP. Discussed the job with COmDanv man 23.05.2019 1 11:40 I Visit location. Talk to co -man — issues with 5.875" gauge ring passing through the wellhParl Mz„ n --A. ..,n Visit location. Talk to company man —set 2xCIBP on a -line while 24.05.2019 10:30 waiting for personnel to come fix the wellhead. CIBP @ 3710ft & 3587ft. Current ops: M/Up stands for TCP while waiting to 18:00 Got a call from company man to move tool to the rig overnight due to limited trurkinn Move Barricade Tool assembly and NC38 swivel to location and place in 25.05.2019 6:30 Pipe barn. Talked to company man — wellhead fixed, gauge run with 5.99" performed without any issues. Current ops: comoanv man fn r.0 ..P/U TCP guns. Asked ..........�__ Start POOH 17:40 1 3572ft. with guns. Tagged top CIBP 15ft higher than expected @ cu: ru I UUH with TCP nl.n,. All shots fired and confirmed. P/U Barricade assembly to rig floor, inspect swab cups and tool — 21:20 everything good. RIH assembly below rotary, set in slips and install dnn rnllmr 21:45I M/up x -over onto the NC38 swivel and M/U on the bottom of first stand. Matra i�r, nn Fi,— o___:__ DATE TIME EVENT DESCRIPTION 6:50 Stop circuatlin — 15 175strokes total. Practice run for Pump&Pull to adjust Pulling speed and pumping rig 7:40 and prepare the crew for the operation. Will pull 35ft/min and pump 2.5BPM 44 SPM Finish practice run. Position tool @3547.82ft (bit depth). Circulating 7:50 ort @3539.43ft Oft above bottom perforation). 8:10 Pressure test lines from cement unit to manifold. 8:15 Start mixinq 35bbls of 15.8 G-class cement. 8:30 Start pumping cement 4BPM and 220psi. Line up valves for Pump&Pull. RIH to 3551ft (circulating port at bottom 8:40 erforation and start pulling 35ft/min and pumping 2.5BPM 44s m . Connection. Close TIW and close annular. Pumped 119strokes — 8:43 6.9bbls calculated 114strokes — 6.6bbls Resume P&P. Reach top perf with 223 strokes total pumped - 12.8bbls 8:48 tanned 11.4bbls . Pull Barricade Assembly 5ft into casing and pressure up to shear solid 8:50 seat. 8:53 Sheared solid seat @bbls 8:58 Pum &Pull in casing 60ft/min and 30spm 1.7BPM . Stop pumps at 312strokes — 18bbls (planned 16.5bbls) at 3307ft 9:00 tanned TOC 3223ft and pull through cement. 9:10 Pull 5stands + 1 single 50 min then circulate. 9:32 POH 5 stands to 2668ft. Start circulating 1OBPM. Receive cement/contaminated cement on 9:46 shakers from 1270 to—1500strokes—13bbis 10:10 Pumped 2500strokes. Stop circulation. Tool OOH. Inspect — a lot of metal debris on the tool (jammed in the 12:00 cups), upper lower cup deformed with a big chunk of metal jammed in it. Cement residue showing signs of cement dehydration already. 12:30 L/D tool and prepare for backload. 16:00 Got a ticket and LFP signed by company man. Brandon and Krzysztof leaving Kuparuk to Anchorage and will stay in 27.05.2019 8:00 town standby for next well 1G-03. I ablc I �Na.hin;; durx m+aI iI, dila Time Flow Rate (bpm/spm) Pressure (psi) TrippingPerforation Speed (ft/min) (ft) Bit Depth (ft) Notes 1:25 AM 10/172 1490 1 0 3392 1:28 AM 10/172 1418 1 2 3394 1:30 AM 10/172 1422 1 4 3396 1:34 AM 10/172 1415 1 6 3398 1:37 AM 10/172 1411 1 8 3400 1:41 AM 1.5/26 1412 1 10 3402 Pump 1.5BPM 1.5/26 1 12 3404 10.5-13ft 1:45 AM 10/172 1385 1 14 3406 1:47 AM 10/172 1396 1 16 3408 1:49 AM 10/172 1400 1 18 3410 1:51 AM 10/172 1395 1 20 3412 1:54 AM 10/172 1396 1 22 3414 1:56 AM 10/172 1395 1 24 3416 1:59 AM 10/172 1396 1 26 3418 2:01 AM 10/172 1395 1 28 3420 2:03 AM 10/172 1397 1 30 3422 1.5/26 1 32 3424 Pump 1.5BPM 2:09 AM 1.5/26 1390 1 34 3426 32-34ft 2:11 AM 10/172 1391 1 36 3428 2:14 AM 10/172 1398 1 38 3430 2:17 AM 10/172 1394 1 40 3432 2:19 AM 10/172 1397 1 42 3434 2:21 AM 10/172 1402 1 44 3436 2:24 AM 10/172 1402 1 46 3438 2:27 AM 10/172 1401 1 48 3440 2:29 AM 10/172 1447 1 50 3442 2:32 AM 10/172 1389 1 52 3444 1.5/26 1 54 3446 Pump 1.5BPM 2:36 AM 1.5/26 1390 1 56 3448 53-56ft 2:38 AM 10/172 1393 1 58 3450 2:40 AM 10/172 1397 1 60 3452 2:42 AM 10/172 1397 1 62 3454 2:50 AM 10/172 1399 1 64 3456 2:52 AM 10/172 1398 1 66 3458 3:24 AM 10/172 1442 1 68 3460 3:26 AM 10/172 1440 1 70 3462 3:28 AM 10/172 1447 1 72 3464 3:30 AM 1.5/26 1447 1 74 3466 Pump 1.5BPM 1.5/26 1 76 3468 74-77ft 3:32 AM 10/172 1446 1 78 3470 3:34 AM 10/172 1460 1 80 3472 3:37 AM 10/172 1460 1 82 3474 3:40 AM 10/172 1468 1 84 3476 3:43 AM 10/172 1467 1 86 3478 3:46 AM 10/172 1477 1 88 3480 3:48 AM 10/172 1485 1 90 3482 3:50 AM 10/172 1450 1 92 3484 3:53 AM 10/172 1458 1 94 3486 1.5/26 1 96 3488 Pump 1.5BPM 3:57 AM 1.5/26 1410 1 98 3490 95,5-98,Sft 4:00 AM 10/172 1425 1 100 3492 4:02 AM 10/172 1426 1 102 3494 4:04 AM 10/172 1425 1 104 3496 4:06 AM 10/172 1424 1 106 3498 4:08 AM 10/172 1424 1 108 3500 4:10 AM 10/172 1425 1 110 3502 4:12 AM 10/172 1422 1 112 3504 4:14 AM 10/172 1421 1 114 3506 4:16 AM 10/172 1422 1 116 3508 4:18 AM 1.5/26 38 1 118 3510 Pump 1.5BPM 4:20 AM 1.5/26 1416 1 120 3512 117-119ft 4:22 AM 10/172 1420 1 122 3514 4:24 AM 10/172 1419 1 124 3516 4:26 AM 10/172 1418 1 126 3518 4:28 AM 10/172 1418 1 128 3520 4:30 AM 10/172 1420 1 130 3522 4:34 AM 10/172 1419 1 132 3524 4:36 AM 10/172 1410 1 134 3526 4:38 AM 10/172 1418 1 136 3528 1.5/26 50 1 138 3530 Pump 1.5BPM 1.5/26 1 140 3532 138-141ft 4:46 AM 10/172 1431 1 142 3534 4:48 AM 10/172 1433 1 144 3536 4:50 AM 10/172 1428 1 146 3538 4:52 AM 10/172 1430 1 148 3540 4:54 AM 10/172 1427 1 150 3542 4:56 AM 10/172 1425 1 152 3544 4:58 AM 10/172 1425 1 154 3546 4:59 AM 10/172 1428 1 156 3548 5701 AM 10/172 1425 1 158 3550 5:02 AM 4/69 300 1 160 3552 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1R-04 Permit to Drill Number: 185-178 Sundry Number: 319-328 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. oogcc.a I oska.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, Jessie L. Chmielowski Commissioner DATED this I II day of July, 2019. RBDMS410JUL 12 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 JUL 0 9 201199 Pr -f 7/11 AOGCI C�f 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate p Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: —Whipstock—El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 185-178 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-21407-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?r N/A KRU 1R-04 Will planned perforations require a spacing exception? Yes ❑ No ❑� ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25635 r Kuparuk River Field, West Salk 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): 8440' 6864' 3711' 3503' 1180 n/a Ma Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 115' 115' Surface 4260' 9-5/8" 4298' 3927' Production 8392' 7" 8427' 6853' Liner 328' 4-1/2" 3358'-3686' 3233'-3484' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3398'-3558', 7892'-8188' (all 3264'-3388', 6442'-6667'( plugged) plugged) 4 .1/2" L-80 3367' Packers and SSSV Type: WFT Permanent Bridge Plug Packers and SSSV MD (fl) and TVD (ft): 3709' MD / 3501' TVD Baker FP 4-1/2" x 7" packer 3374' MD / 3245' TVD 12. Attachments: Proposal Summary Q Wellbore schematic Q 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: 7/10/2019 OIL ❑ WINJ 0 WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Shane Germann Authorized Title: Staff CTD Engineer Contact Email: Shane.Germann c0 .Com Contact Phone: 263-4597 /s� Authorized Signature. Date: f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3�q-328 Plug Integrity ❑ BOP Test r�,/ Mechanical Integrity Test ❑ g y ❑ Location Clearance 7 /� f Other: 1Z a p i -e -d t 7r d 5-I% `5 15 I /1-y1 1-7 vl a ✓ 00 r2- 1, -el h, F( P-- /Post PostInitial Injection MIT Req'd? Yes ❑ No 9, ■m� �,yy�,%/��L 1 q 2019 L Spacing Exception Required? Yes ❑ No Subsequent Form Required: �d /hOQ R �D. I APPROVED BY Approved by: �2 COMMISSIONER THE COMMISSION Date: 4111 hei d UKIUINAL Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 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 applications for sundry and permit to drill one lateral out of the KRU 1 R-04 (PTD# 185-178) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin on July 22nd, 2019. The objective will be to drill one lateral 1 R-104 targeting the West Sak B -sand. Attached to the permit to drill application are the following documents: - Permit to Drill Application Form (10-401) for 1 R-104 - Detailed Summary of Operations - Directional Plan for 1R-104 - Current wellbore schematic - Proposed CTD schematic Attached to the sundry application are the following documents: - Sundry Application Form (10-403) for 1 R-04 - Summary of Operations - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sincerely, t' a Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 1 R-04 (PTD #185-178) CTD Summary for Sundry Summary of Operations: KRU well 1 R-04 is an injector that was recently worked over to be set up for CTD operations. During the workover, 4-1/2" tubing was installed with tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge at a planned kickoff point of 3534' MD within the tandem wedge. CDR3-AC will use the inner wedge to mill a window in the 4-1/2", 7", and 9-5/8" casing strings. The 1R-104 lateral will exit through the casing at 3534' MD and TD at 11,500' MD. It will be completed with 2-7/8" slotted liner from TD up the end of the build and 3-1/2" solid liner from the end of the build to inside the parent wellbore. Pre -CTD Work 1. RU E -Line: Drift, set inner wedge at 3534' MD 2. Prep site for Nabors CDR3-AC rig. �J ' 1• Rig Work 1. MIRU Nabors CDR3-AC rig using 2-5/8" coil tubing. NU 7-1/16" BOPE, test. 2. 1 R-104 Lateral (West Sak B -sand - South) e. Mill 3.80" window at 3534' MD b. Drill 4-1/4" bi-center lateral to TD of 11,500' MD c. Run 2-7/8" slotted liner and 3-1/2" solid liner with deployment sleeve from TD to 3524' MD Nd ^ 3. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Ria Work 4. Return well to production. 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VMRn 11...MM ToPTRxe 6tR 400 3,3578 3686A 3484.3 11.60 LA0 BTCM Liner Dotalla Cemenl4RevR. 3.1B9.ORRB CMr 80L i 3W.645Y.0 TOP RKBI Top MD)(RKB ToomlNllO 1 PmGl14 ttem pea Co.C (In) 3.3518 3232.8 PBR R 5.250 33)3.] 32452 38.06 PACKER Packer BakerW 4-117xr VrpxlBTI, 3.810 8®b Doa43 .. 3,403. 3.269.1 3].89 NIPPLE %Nipple HES3.813.583Bw 3958 35044 3,34)4 3961 WEDGEASSY Wedge A y NonbBrn Solutions 4,000 3523.3 3.362.D 39.9) NIPPLE XNipple 4.1Z x 3813' STCMBFP -4aW 3,530.4 3,36)6 00.10 WEDGE ASSY NbnDem SnWuons41)2-Wedge ese, 4.000 3,5494 3,381.9 4065 NIPPLE Mppk4-12"x3.813"BTC11ol 4,000 B BLINER, 43Sl4g.gg40 35924 3,414] 41 COLLAR LanBin9 CWler }DIM♦12'BTC It cem) 4.00p PI$H:%7NO Tubing Strings PEPAUNFMaR98EPl.lx3; 3]043 Tubing Do<r101Ion UPPER COMPLETION - W...®m) 4925 Tpp111K8) 396 0.0 Sel Dean IR.8tl 3,3670 Cepin(ND) I...m1YM) 3,2400 12.75 CiRM b80 Tap COmxNm HYD503 Completion Details WMFACE', 37, M,S�� JEr CDr, 4.5N.0 TOP IND) Tap Incl xominal c- ID(In) Top IRKB) nine) I')Z�� 0.0 0 000 nger MC Genrylt'xa trt'EUE BXPaXO pap EUEx563 3.95826913 2A812 19.90LM DanKOIn xt-KBG2DVSB1p20836-1I 500)31946 3,990 38.64MCnm 4 rz'x1'KBG3 SOV 12oWpsr lA-aT)Sard2p83a 3.6803,3359 CwIwaPy:TtaoRM(B WS UFT Leat] 03.3576 S g 32155M- Mpple3S13-HYD563381GX1169cFMEMRETARalt1480 3621 back 101ala n,ggp 3.2324 36.20back Seals (8.05'sDacetl vM 1.59leetj 3980 Tubing Dn .M.n 301ep Auld) 1) TOp IN HOLE ING LEFT 31R 299 4,5002 INDOLE RKB) get Oepb lR. ]]04.0 9eL Depn (TVD) j- 6.301.4 m(PoRI 9.b DnM LA0 Tap Cannegbn IBTM Completion Details .TOR, 1.. sELLI8Bv, 16p3s FER;1p#e PACNER'LTmO HIND) Top lnKEl Inrce) Top mcl 1'I nem Dea com xominil Ip Onl .691.2 .291.8 BA 42.1 .LOCATOR KERL CATOR 3.61X) 1,6935 6.293.6 42.10 SEALASSY BAKER 80.40 SEAL ASSEMBLY STABS INTO StA KER PACKER 3000 NIPRE'LTi&4 Tubing Dasc,iptlon STACKER PACKER BONIp Ya... l01kQ TapIn6O) Sea Deue(k.I oaD p,TvD)I... m OW Wa4e 3112 2.99 ],692.6 ),)91.0 6,3fiB.3 960 LM Topcoonnum EUEBN Completion Details sFgLAB8r:1TN.T PBR; Is" 1 PAbRR: T,815z - Top true Top DIKE) Ke) R TCP Inm 1•) Co.MmCorn xoml l I)Im) ],892. 6,292.9 42.11 PBR BAK ISOiO PBR 3.020 NBIND FERFDRATXX{ ).>(K.09 6.302.81% HLPADKER PACKER RF7425,0- 2.9M 6 ,148..331 .8 ) 162.01 4.]1 NIPPLE MCO DS NIPPLE NO GO 2.812 PATCH: 7.M4o INIECMN: T,B•v3.a - ].'69.1 1.1 41.45 6EALA65Y BAKER8040SEALASSEMSLY 3000 TWInpDeORGIN TUBING ORIGINAL Sbbg Ya... 2IM1 TW RKa) 8,0475 ln.. SN DepIM1 INp)1 "vJtllbRn Woes q 299 ],]902 8,001.5 6.5593 Top CmuxcMn Completion Details IFERF;188267eYa�� TopIN01 Top RKB) InKB) Top I ('1 Mm Dea Com Nominal ID nn) I.Pi 03)4.1 41.38 MR BAKER MR 0000 s UMV4.1165, IWLE 1ees., _ ) 15.2 SSW 41.39 PACKER RFHLPACKER 3. LCCATOR:9.OB3.8 ].891.3 6,441.5 41.43 BLAST RINGSM T RINGS 2, PACKER: a.maw ],885.1 6.512.1 40,96 NIPPLE TED NIPPLE 2J60.022.6 ,64 4 1 LOCA R TOR SUB 20068. 44 6,541, d0.m PACKER B-1 PAC R 234) 8,039. 6.553.0 9059 NIPPLE 'D'NIPPLE 2.250 8,0168 6.558.8 053 SOSSHEAROIIT We 2.441 Otter In Role (WI ellne retrievable plus, pumps, fish, eto.)TopIND) rcp IntlTOPRKB) InKB) ('1 DeaCom Run Wle ID nn) 34.0 330 0 BPV lxe uaNelmtYleB an 5910600 spurs3,]08.0 3. .5 4.31 FISH '•CISo WaneC lO bpnpnalop ClBP 5/2312019 P200.CTIOx; 38.644ID.5 Conoco`Phillips ` KUP [NJ WELLNAME 1R-04 WELLBORE 1R_04 PlasKa. mc. ,a.w. nlnrzms,zlD'w PM Other In Hole (Wireline reMevaDle plugs, valves, para ps, fish, etc.) Vwlul3tMniFlk OtluM1 TOPIrvD) roP Incl 7, 3./x61 InKel fl p0 cora am pm ID lint 3]09.2 3,SOtA 42.39 PERMANENT 4V8 IW 5232019 BRIDGE FLAG X R:a0""- BW,vD - -__................ .___. 4,500.0 8 JET CUT Jet Cut Tug (CCL 648fi.IT) 4]242019 2. 2 7,610.0 M CEMENT t 3.5• Cement Raba 2.75•x1.4&Ib M, 4]21/1019 0.000 RETNNER No -H80 16.Ml.8 J,8250 TUBING MH M Fx241PCT-MP05' 13 LpatleG) TubIN uM- 32&2019 2.992OONpx3TOR PERFORATION SPD7,840.0 0 PATCH HES RCP pakR 1¢,1916 Z].46'. is MN M649G59Y1000 1310 ].985.1 %SLEEVEC BPIIS sleere6ea4N200p 4]112000 2310 Iw;s.lm.x 8.136.0 8] FISH PO Valle LeR Pie25 in Hole N22/1995 NIPRf; J,135.8 Perforations & Slots LauTpx; a,asv.> sna 6FALA5.91'; 6364 TIRK61 TM 01.1"In ToB)) 1M( M(MR p) ....d Z... paN 6Ma I6MW1 / ora =IM- 3, .0 3,558.03,M41,388.4 5]252019 12.0 CMi BOZ /8'12apOx RDx TCPpMfipuns 7,892.0 ],9320 6,4420 6.4721 G1, 1R4 10]28]1985 1201PERF F Expentlable HJ 11; 120 In ph amem 8eu33m.3]99oPHB wrspx a3e6.w sM.9 8,116.0 ,131.0 6,611.6 6,625.4 A4, IR iN2811985 12.0 IPERf 4•HJ II Csp Gun:8J tle9 pa 8,146.0 8,188.0 6,8348 6.66].0 AJ, 1R4H 102M1985 0,0 (PERF /' HJ II CW Gun: di, ph sm Jnx 3.3rs.D nim Cement Squeezes P IRKBI 60n IRK6 TopINDI 6XnINp1 taIflK61 pnK.) pea BMXOm Com 1 ],1/2.0 5,891.1 6.2M CEMENTPLUG 4121/2019 ].100.0 8,127.0 Sz605 6,620.0 CEMENiPWG 412112019 3.398.0 3,558.0 3,264.4 3.388.4 CEMENT 5262019 34 bbbofl ePM Pumpel SCUEEZE 66PB LIXEP; a, y5i,63.1m.0 Mandrel Inserts Flax:lamo M aY PEAMWENF&i6]GE PWO: a.M.x 9uRFAOE: rz08,9T5� JETCIJT' 410°0 I l an TaP I]VDIV�NB M Top 10K61 (Me)Make Ma4el OOIM) 9ery INca pw181Le TR`RYn Tyq Typo 6n) (pap I R,m WM C. CKBMG 5.984 INJ DMY 1. Y 019 30 1 ,9.2 3,194.6!c -!Z: KBMG 5.984 -41 INJ SOV 1.000 56ID(2019 Notes: Gem & Safety I Bna men Ann4Mwn 3'112000 NOTE: F08nG posgble l¢eka�]858 WLM8]84Y YVLM IPATC ED 5120001 316]2008 NOTE: •'YIARNING�Akx test preasureon lq 19000 tlue to Srmb Liner pKR�]3B0' 2]2/2015 NOTE: Scab ener-max GiRerem4l preasurel psi ;a 6]25]2019 INOTE: View Scbemauc w/Kaska Bctrernenct00 um,M P,µ ],uzonxa aGnuXFn:aO!]0],4w0 � cellaxr.rAlxBa: ].610a Cemex Fly: ],IDpD Mie y f' pP.s uFT: ]av 3fi —T ],6911 PPA ]fiPx 9 PMnER; ],rm,° HIPRE; l.]W 9 9ELL ASSY; ] ]W I P9a: ].6113 PAGFER: 7.8111 T91X0 PERFGV.TO.: T.. PATCH. 7.M.O IXIEfiIK)X; IFENF;7,M.O7,9g.0� BtEEVEL', ).9M.1 NPPIE: >.BBS1 .IX TOR: 0.09.8 PAGER: 1.M44 NIPPIE;1Aae2 aps: go4e.4 IFERF: 8,11808.3340 Y! FISH', 61A0 RERF; &,14808.1960 PROCVC]Ipµ 1e08,IM5 1R-104 Proposed CTD Schematic 5/e" uh 36# J-55 s at 4298' MI 3927' ND 9ENWA WELL LOG TRANSMITTAL #90565136 To: Alaska Oil and Gas Conservation Comm. June 26, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 RECOVIED Anchorage, Alaska 99501 AN 2 7 2019 RE: Jet Cutter Record: 1R-04 Run Date: 4/24/2019 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 1R-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21407-00 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: �T��% Signed: PTD Loepp, Victoria T (CED) From: Hampton, Kyle <Kyle.Hampton@conocophilIips.com> Sent: Thursday, May 30, 2019 4:47 AM To: Loepp, Victoria T (CED) Cc: Eller, J Gary; Regg, James B (CED); Senden, R. Tyler Subject: Re: [EXTERNAL]KRU 1 R-04 Perf Interval Cement Evaluation Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria. We're glad to answer any more questions. Thanks Kyle Senior Wells Engineer Cell 832-421-1506 Sent from myiPhone On May 30, 2019, at 4:26 AM, Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> wrote: Kyle, Approval is granted to proceed with running/cementing the liner. Thanx, Victoria Sent from myiPhone On May 29, 2019, at 11:08 PM, Hampton, Kyle <Kyle.Hampton @conocophillips.com> wrote: Victoria, Our perforations were from 3,398' RKB to 3,548' RKB. The interval was shifted away from the 7" casing collars, -20' relative to the sundry depths provided. Based on the CBL, we interpret good coverage from 3,398' RKB to 3,556' RKB. We have good cement coverage above and across the perforated interval. I attached an email Gary sent about this depth correction. While pressure testing the 7" casing across the perfs, we were leaking at 3 psi/min, leaking from inside the 7" casing (most likely at the base of the perf interval) to the 7" x 9-5/8" annulus. While testing, we did not observe any pressure at surface on the OA; we passed an MIT -OA prior to rigging up, but we have not performed a new test since. We do not plan to change our cement job because we believe we have sufficient cement coverage from the perf cement job. Both 111-26 and IR -04 and being converted into CTD injector wells; they should be under the same considerations. CTD is planning an uncemented liner. I attached an email Gary sent about this well previously. Thanks, Kyle Hampton Senior Wells Engineer ) Office. 907-263-4627 1 Cell. 832-421-1506 ) Kyle. Hampton[1a cop.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Sent: Wednesday, May 29, 2019 4:19 PM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Eller, J Gary <J.Garv.Eller@conocophillips.com>; Regg, James B (CED) <jim.reaa@alaska.eov>; Regg, James B (CED) <Jm.regg@alaska.eov>; Senden, R. Tyler <R.Tyler.Senden pconocophillips.com> Subject: (EXTERNAL)RE: 111-04 Perf Interval Cement Evaluation Kyle, Gary, There appears to be no cement above the top perforation — about 14' of perfs above the cement. The pressure loss of 3 psi/min is much lower than 113-26. What leak rate does this correspond to? I am concerned that the open perfs are above the top of cement. Is there any indication of OA pressure? Any changes in your planned liner cement job? 111-26 is a producer and this well is an injector so the situation is different. How will this well be completed? Victoria From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Wednesday, May 29, 2019 3:11 PM To: Loepp, Victoria T (CED) <yictoria.loepp@alaska.aov>; Regg, James B (CED) <iim.reee@a laska.aov> Cc: Senden, R. Tyler<R.Tvler.Senden@conocophillips.com>; Eller, l Gary <J.Garv.EIler@conocophill ips.com>; Hayes, James C <James.C.Haves@conocophillips.com>; NSK RWO CoMan <NSKRWOCoMan@conocophillips.com> Subject: 1R-04 Perf Interval Cement Evaluation Victoria, We are preparing to run and cement the 4-1/2" liner on 1R-20 (PTD 185-178). We have drilled out the cement, passing a 14.2 ppg EMW test 50' above the perforated interval but leaking at 3 psi/min on a 14.2ppg EMW test after drilling out the perforated interval. We believe we have a properly cemented annulus based on the CBL and wash/cement job conditions. The results are very similar to 111-26, so we are planning to proceed forward with running the liner and cementing it in place. Do you need any other information from us before proceeding? I have attached the Archer log and CBL. Please let me know if you have any questions. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 Kyle. Hampton@cop.com <mime -attachment> <mime -attachment> PTD /5S-/�15 Loepp, Victoria T (CED) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Wednesday, May 29, 2019 11:08 PM To: Loepp, Victoria T (CED) Cc: Eller, J Gary; Regg, James B (CED); Regg, James B (CED); Senden, R. Tyler Subject: RE: [EXTERNAL]RE: 1 R-04 Perf Interval Cement Evaluation Attachments: RE: [EXTERNAL]KRU 1 R-26(PTD 191-092, Sundry 318-538) Plan Forward ; FW: [EXTERNAL]KRU 1R-04 (PTD 185-178, Sundry 319-102) ;KRU 1G-03 (PTD 182-149, Sundry 318-536) Workover Revisions Approved Follow Up Flag: Follow up Flag Status: Flagged Victoria, Our perforations were from 3,398' RKB to 3,548' RKB. The interval was shifted away from the 7" casing collars, ^20' relative to the sundry depths provided. Based on the CBL, we interpret good coverage from 3,398' RKB to 3,556' RKB. We have good cement coverage above and across the perforated interval. 1 attached an email Gary sent about this depth correction. While pressure testing the 7" casing across the perfs, we were leaking at 3 psi/min, leaking from inside the 7" casing (most likely at the base of the perf interval) to the 7" x 9-5/8" annulus. While testing, we did not observe any pressure at surface on the OA; we passed an MIT -OA prior to rigging up, but we have not performed a new test since. We do not plan to change our cement job because we believe we have sufficient cement coverage from the perf cement job. Both 113-26 and 111-04 and being converted into CTD injector wells; they should be under the same considerations. CTD is planning an uncemented liner. I attached an email Gary sent about this well previously. Thanks, Kyle Hampton Senior Wells Engineer ( Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle. Hampton@cop.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, May 29, 2019 4:19 PM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Eller,1 Gary <J.Gary.Eller@conocophillips.com>; Regg, James B (CED) <jim.regg@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]RE: 1R-04 Perf Interval Cement Evaluation Kyle, Gary, There appears to be no cement above the top perforation — about 14' of perfs above the cement. The pressure loss of 3 psi/min is much lower than 111-26. What leak rate does this correspond to? I am concerned that the open perfs are above the top of cement. Is there any indication of OA pressure? Any changes in your planned liner cement job? 1R-26 is a producer and this well is an injector so the situation is different. How will this well be completed? Victoria From: Hampton, Kyle <Kvle.Hampton@conocophillips.com> Sent: Wednesday, May 29, 2019 3:11 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov>; Regg, James B (CED) <jim.regg@alaska.aov> Cc: Sender, R. Tyler <R.Tyler.Senden@conocophillips.com>; Eller, J Gary <J.Gary.Eller@conocophillips.com>; Hayes, James C <James.C.Haves@conocophillips com>; NSK RWO CoMan<NSKRWOCoMan@conocophillips.com> Subject: 1R-04 Perf Interval Cement Evaluation Victoria, We are preparing to run and cement the 4-1/2" liner on 1R-20 (PTD 185-178). We have drilled out the cement, passing a 14.2 ppg EMW test 50' above the perforated interval but leaking at 3 psi/min on a 14.2ppg EMW test after drilling out the perforated interval. We believe we have a properly cemented annulus based on the CBL and wash/cement job conditions. The results are very similar to 1R-26, so we are planning to proceed forward with running the liner and cementing it in place. Do you need any other information from us before proceeding? I have attached the Archer log and CBL. Please let me know if you have any questions. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle.Hampton@cop.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION m , Cn y' i1.uu CC-�tis' !as". MAY 2 3 2019 WELL COMPLETION OR RECOMPL TION REPORT AN 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned MSuspended [] 1b. Well Class: 20MG 25.105 11X�V 20AAC 25.110 Development ❑ Exploratory E]GINJ [_1WINJ ❑ WAGE] WDSPL ❑ No. of Completions: Service E] . Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Com Su ., or Abend.: /24/2019 14. Permit to Drill Number/ Sundry: . 185-178/319-092 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 911111985 15. API Number: 50-029-21407-00-00 4a. Location of Well (Governmental Section): Surface: 334' FNL, 137' FWL, Sec 20, T12N, R10E, UM Top of Productive Interval: 1463' FSL, 1265' FWL, Sec 20, T12N, R10E, UM Total Depth: 1094' FSL, 1406', FWL, Sec 20, T12N, R10E, UM S. Date TO Reached: 911711985 16. Well Name and Number: KRU 1R-04 9. Ref Elevations: KB:82 GL: BF: 17. Field / Pool(s): Kuparuk River FieldlKupamk River Oil Pool 10. Plug Back Depth MD/TVD: 7207/5939 18. Property Designation: ADL 25635 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 539829 y- 5990870 Zone- 4 - TPI: x- 540988 y-5987394 Zone- 4 Total Depth: x- 541132 y- 5987025 Zone- 4 11. Total Depth MD/TVD: • 8440/6863 • 19. DNR Approval Number: ALK 2568 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1600/1600 5. Directional or Inclination Survey: Yes ❑ (attached) No Fy] Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: NIA 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD AMOUNT WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 38 115 38 115 24 250sx CS II 95/8 36 J-55 37 4297 37 3927 121/4 1190sx PFE, 425sx PFC 7 26 J-55 35 8426 35 6853 81/2 300sx Class G, 250sx PFC 51/2 15.5 L-80 6057 7400 5124 6079 uncemented scab liner 24. Open to production or injection? Yes ❑ No E] If Yes, list each interval open (MDRVD of Top and Bottom; Perforation Size and Number; Date Perfd): (1 PERFORATIONS PLUGGED SUS ,'''yam_ 7892-7932 r'emktr" ��1�1�� 8146-8134 D TE N"` 8146-8168 - 7.1 l V _IED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/f VD) 3 1/2 8047 7815/6384, 7706/6303, 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): ABANDONED Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casinq Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 V`I'A / 0 / a 3 / l 9 COzNTIN�(DD 0i9 . Submit OR,I�GxINI�A9L only MAY 2 42019 /1 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 2 If Yes, list formations and intervals cored (MD7TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1600 1600 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI - N/A N/A Formation at total depth: N/A 31. List of Attachments: Daily Operations Summary, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological r r n orwell test resub,r 20 AAC 25.070 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Ty Senden Contact Name: Gary Eller Authorized e. WorkoverSu ervisor Contact Email: Ga .Eller co .cem Authorized Contact Phone: 263-4172 Signature: Nqk 5 Date: INMUCTIONS General: This form an a required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-4 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 11a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas/ Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1 R-04 PLUG FOR RE -DRILL DTTMSTAFJOBTYP SUMMARYOPS 3/28/19 PUMPING FREEZE PROTECT TBG WITH 2OBBLS DSL & FL WITH 26BBLS TRACKING METH, FROM MANIFOLD ONLY 3/28/19 DRILLING T TUBING PUNCH AT 7825' SUPPORT- GOOD INDICATION THAT GUN FIRED. CAPITAL LRS INJECTED DIESEL WITH THE FOLLOWING RESULTS: 5 BBLS PUMPED, 1.3 BPM RATE AT 1450 PSI 10 BBLS PUMPED, 1.5 BPM AT 1800 PSI 20 BBLS PUMPED, 1.75 BPM AT 2000 PSI 3/30/19 DRILLING FREEZE PROTECT TBG & MIT -IA TO 2500 PSI **PASSED** SUPPORT- PUMPED 20 BBLS OF DIESEL DOWN TBG FOR FREEZE CAPITAL PROTECT. PUMPED A TOTAL OF 4.2 BBLS OF DIESEL DOWN IA TO ACHIEVE MIT -IA TESTING PRESSURE 2500 PSI, 1ST 15 MIN IA LOST 100 PSI, 2ND 15 MIN IA LOST 45 PSI, MIT -IA TO 2500 PSI PASSED. BLED BACKAPPROX 1.8 BBLS. JOB COMPLETE 4/1/19 DRILLING DRIFT W/ 2.79" x 4' AVA CATCHER TO SET @ 7749' RKB; SUPPORT- PULLED DMY @ 7642' RKB; PULLED CATCHER @ 7749' RKB. CAPITAL HANDOVER TO LRS TO PUMP 105 BBLS DIESEL DWN IA TO FORMATION. READY FOR COIL 4/21/19 DRILLING RAN IN W / CEMENT RETAINER GOT TO SETTING DEPTH SUPPORT- PUMPED 1/2" BALL AND NEVER SEATED PUMP A SECOND 4/24/19 DRILLING TAG CEMENT @7207' RKB RECOVER GOOD SAMPLE OF SUPPORT- CEMENT STATE WITNESSED (GUY COOK), MIT TBG 2000 PSI 5/20/19 RECOMPLETION MIRU 5/21/19 RECOMPLETION MIRU. Rig accepted at 1300 hours. Take on 9.0 ppg Sea water in pits. Pull BPV. Displace diesel out of well to 9.0 ppg Sea Water. Nipple down production tree. Nipple BOP. 5/22/19 RECOMPLETION Perform in between well BOP maintenance. Pressure test BOP. Pull tubing hanger. Pull 3 1/2" completion string and lay down the same. ConocoPhillips Alaska, 9K. KUP ]NJ WELLNAME 1R-04 [NJ WELLBORE 1R-04 1RM, porage IYne;16PM W INtage Last Tag .i acnsupt.' ous, End Dad: WeIIWre AnnUA-W�w Last and By _........................._........................................._................. L86ITa9:SLM 014 1R-04 hipshk( H.WGER:3s.. Last Rev Reason •.._..........•••••••••.......................••••........... .. End D.k wenbara Last mae 6v Rev Reason: Cul Try 2019 1R-04 bWUMi JAY Casing Strings 7C0NWCTCR;WgA150 caamg Description O;7W at.,.shrv0)._wtlLen(I._ Gram Top ThreadCONDUCTOR 1S0 65.00 H40 WELDED Casing Descrupee Do (in) to (in) Top (I Set Depth (flKB) 9N Cepth (NO)... WIMnp... Gratle Top TM1rend SURFACE 958 892 37.0 4,29].5 3,92].1 36.00 3-55 BTC Casing Descriptlon Frohn) IDpn) Top (XKB) SM DepIM1 (M1KB) Set DeptM1 jND)... WtlLen (L.. Gratle Top TM1Kad PRODUCTION 7 6.28 35.0 8,428.5 6,853.1 260D J-55 BTC NPPLE; wIo Casing Descdptlab Do (in) IO (in) iop (XKB) Set DeptM1 (flN3) 9N DepN (ND)... WIILen ll._Gratle Top TMead SCAB LINER 512 4.95 6,05)0 ],400.0 QCrS7 15.50 L -0o 5-12 Hyb 511 Liner Detains suRPACE; 3]o4,n]s- ammm lD Top lnkB) roplrvD)IXIIe) Top lnal ('1 Item Daz Com (in) 6,051.8 5,12)4 47.39 PACKER CHP LINER TOP PACKER 4.W ,.Cut'a,.L - ],3804 16,06,141 4360 PACKER 13D LINER HANGER PACKER 4,959 Tubing Strings Toting Description Blnng Ma... 10 (I n) Top (WE) setDeptM1(fl.. Bet Dep(M1 ffva L..WI(IbM) Gratle Tape-recrlan TUBING WO et.. 299 33.9 ],]040 8,3016 9.30 L-80 "BTM _ Completion Details Tap(ND) Top Incl NomineI Top WINMe) p) Ipm Des Bom m(in) 33.0 33.0 0.08 IRMINGER FMC GEN III TUBING HANGER 3.500 501.0 030 NIPPLE CAMCODS NIPPLE 2.875 4 ,291.8 42.12 LOCATOR BAKER LOCATOR 3.000 cenemPXp; Tt4za xKB SCASUNEen,O5T_b�4Do.o ,293.6 42.10 SEAL ASSY BAKE SEALA EMBLYS AB INT S A KER 3.000 PACKER =Sbing C.P.7J0emo Mua; ],I.D.mce String Ma... 1D(in) Top (IIKB) Set Oegn lR. Bet Degn IND)(... Wlpbnt) Gratle ioCoxtancomm ER 3112 2.99 ],692.Details Gas LIST. >,6I17 ss TOPIrvD)Top mm i rap (race) eWB) 1°1 nem oea cora NomID pnn)m ],6826 6,292.9 42.11 PER BAKER 8040 PER 3.020 ],)06.0 6,3028 42.01 PACKER BAKER FHL PACKER 2.930 LOCATOR: 7.6813 7,748,91 6,334,81 41.]2 1NIPPLE CAMCO US NIPPLE NO GO 2.812 SEALAsW7,9905 PBR; ],�6 PACKER;],IIB.. 7)89.] 6,365.3 4145 SEAL ASSY BA KER 8040 SEALASSEMBLY 3.000 Tubing Description Bhln9 Me_.IDpn) TOP(XKB) setDOhM.sel Depth(ND)(...Wt(FMI Grade Tap Connectlon TUBINGOri-inel 4 2.99 ],]902 8,04]5 6,559.3 Completion Details NIPPLE. 77,48 9. r.P(WD) I Topmcl Nominal Gom ID (in) Tap WE)grafi MMBAKER ],801.5 8,3]4.1 41.38 PERBAKER PER 3.000 6,384.4 41.39 BAKER FHL PACKER 3.000 ],8913 6,441 5 41.43 (2)SIirST RINGS 2992 SEALASSY,7,M7 ],965.1 6,512.1 40.96 AVA PORTED NIPPLE 2350 8,022.6 6,5404 49.]1 SAKE. LOCATOR SUB 2.406 Pat;;w1s 8,024.4 6,5418 40.70 BAKER FB -1 PACKER 2.34]PACKER;]6tB1 8,039.2 6553.0 40.59 CAMCC D'NIPPLE 2.250 $046.8 6,558.8 40.53 CAMCO SHEAROUT SUB 2441 r,blrg va,aadon; ],eu.p Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) ToplrvDl Topli PATCH 781 INJECTl.:].633e p Di (-.lee) PI Des Co. Run Dale Dbing 4,5000 4070.5 46.28 Jet Cut Jet Cut Tbg"CCL 44866) 4242010 2.992 7610.0 8,231.9 42.73 Cemeln Set 35" Cement Retainer. 2.75"x1,46'1.-.-. 4212019 OA00 Retainer ],825.0 6,391.8 41.39 Tubing' MH -EDF 2-U T -MPD 'Loatletl) Tubing Punch- 31282019 2.992 Perforation SPD ),840.0 6403.0 41.40 PATCH HES RCP patch, length 2745', isolating station p9 GLM 5014000 1.310 (PERF; ],BB1.0.],9320- ],985.1 6,512.1 4096 SLEEVE -C BPI ISO sleeve net 4/112000 4,112000 2.310 6LEEVEL: ]9R5.t NIPPLE. 1985.1 8,136.0 fi,526.9 3987 FISH PO Valve Leh Pieces In Hole fi12211995 Perforations 8 Slots LOtionas 9.os.9 Top (M(6) Btm (lYl(Sj Top(ND) We)tTIKB) Btn(ND) Llnketl IDne ooh an., Dens (sboWt ) Type Cour PACKER: a.WA4 NIPPLE: eget ],8920 ],9320 8,442.0 6,4]2.1 C-1,18-04 1028"1985 12.0 "PERF5" Expenbable HJ II; 1ZU SDs:6046.9 Ee9 pM1 8,116.0 8,134.0 6,611.6 8,6254 74, UPI 1W2&1985 12.0 (PERE 4" HJ II Csg Gun; 90 deg ph 6 $188.0 6,634.6 6,667.0 TT 1R-04 1028,1985 4.0 "PERF 4- HJ II Cis,Gun; M beg ph Cementant Squeezes (PERF, 6,11668.134.0 Top(ND) Btm(rvD) PISH; e.laso Top (flKB) Btm(ftKB) (NRB) (ttRB) pas Siad pah Com 7,1420 ],642.0 5,891.1 6,255.5 Cement Pluq 421I201B ],1000 8,1220 5,880.5 6,620.0 Cement Plug 4212019 Mandrel Inserts (PERF; 0.148D8,1fti SL i N 1 Tod V"D) To,argon Mahe Model 00(10) Sam Valve Tyce Lahb Pod Siu TYPo (int TqO Run "Psi) Run Dale Com ],6413 8,255.3 CAMCO -2- 9 1 GAS LIFT OPEN INT 4112019 PRODUCTION: 35.b6,4]65 ►' ,iV.lp%,KUP INJ WELLNAME 1R-04 WELLBORE 1R-04 Lonocornnups AleSka,lnc 1am, smrzola lzw:l6 PM Mandrel Inserts VerpcaleMenetic (.m.p at B ..................... ........................................... HANGER', M0 """"""""""""""-"""""""'------ - ------ on N Top IXKR) Toa(IVOI (XKBt Make Mwlel 00 (In I aery VBhre Type Lalc11 type PDXSIu (lnl TRORun (Peq Run Oale Com ],853.8 6,413.4 MERLA TMPD 1 INJ PA BK 0.000 0.0 10211895 H Notes: General & Safety Ene pam AnnoWtI n 112000 NOTE: FDuntl possible leaks @ ]858' WLM 8 ]842' WLM (PATCHED 5 ] 2000) 31612006 NOTE:^NJARNING'^Max testpressure on lA 1900tt bue...I, Liner PMH@]380' CONDUCTOR', 380.1150 10/142010 NOTE View SEhemafic wl Alaska SchematiE90 &2015 NOTE: Scab linermax Eifierential pressure 1900 psi NIPPLE; PH SURFACE, aT .2P7s_� Cement PNp; T,id 6CAa LINEfl: B4OST0.T,dW 0 I= 0 Cement PeBvwr 76100 C-1PMN; T,1.URKII GAA LIFT: ].OH T LOCATOR],681] NEAL ASSY. 7,M PBR;7,6R].6 PACKER ],AAO NIPPLE', 7,]d68 6EALASSY:T.]BBT Per. 7M1111 PACKER; 7,818.2 Tudna PeN tm,],8250 PATCH: TWO INJECTION, 7.aO. I PERF: ],MU-?,MO2 6LEEVEC;],8851 NIPPLE;1,..1 LOCATOR; &622.8 PACKER: E.M NIPPLE: B,.2 606; B4OWB y l IPERF', 81160.8,131.0 5 FISH:8,1380 IPERF:8.1d808, WCC PROOUCTION;30.Mg 5 Loepp, Victoria T (CED) From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Thursday, May 16, 2019 9:11 AM To: Hampton, Kyle; Hayes, James C Subject: FW: [EXTERNAL]KRU 1 R-04 (PTD 185-178, Sundry 319-102) ;KRU 1G-03 (PTD 182-149, Sundry 318-536) Workover Revisions Approved From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, May 16, 2019 9:05 AM To: Eller, J Gary <J.Gary.Eller@conocophillips.com> Subject: [EXTERNAL]KRU 1R-04 (PTD 185-178, Sundry 319-102) ;KRU 113-03 (PTD 182-149, Sundry 318-536) Workover Revisions Approved Gary, Approval is granted as written below. Please update the approved sundry with this new approval. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(Wa laska. aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Vicloria.Loepo@alaska.aov From; Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Tuesday, May 14, 2019 8:52 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.sov> Cc: Hayes, James C <James.C.Haves@conocophillips.com>; Hampton, Kyle <Kyle.Hampton@conocophillips.com>; Ohlinger, James J <James.J.OhlinPer@conocophillips.com> Subject: Revision for Workover Sundries for KRU 1R-04 (319-102) and KRU 1G-03 (318-536) Victoria — I'd like to get your approval on some minor changes in the approved workover sundries for KRU 1 R-04 (PTD 185-178, sundry 319-102) and KRU 1G-03 (PTD 182-149, sundry 318-536). In both wells, ConocoPhillips wants to make minor corrections to the depths of the squeeze perfs and the location of wedges for future CTD exit points. In both wells, we've moved the CTD kickoff points uphole to avoid placing a window in a casing collar, and the squeeze perfs are likewise being moved uphole by the same amount. Approved Squeeze Perfs New Squeeze Perfs Comment IR -04- 3418'-3578' MD by same amount) 1G-03: 3675'-3835' MD same amount) 3398'-3558' MD Moved 20' uphole (lower CTD exit point moved 3669'-3829' MD Moved 6' uphole (lower CTD exit point moved by Attached are updated operational summaries for both wells, with revisions shown in red font. Please let me know if you need any other information to help facilitate this request. << File: 1G-03 Ops Summary for Sundry - update 5-14-19.pdf >> << File: 111-04 Ops Summary for Sundry - update 5-13- 19. pdf >> J. Gary Eller Wells Advisor ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 Loepp, Victoria T (CED) From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent Friday, May 3, 2019 1:40 PM To: Loepp, Victoria T (CED) Cc: Senden, R. Tyler; Hampton, Kyle; Long, William R Subject: RE: [EXTERNAL]KRU 1R-26(PTD 191-092, Sundry 318-538) Plan Forward Victoria - CTD plans to run an uncemented 2-7/8" slotted liner but will have blank liner placed from above the window to the pay in the West Sak 'B' Sand. They plan to install liner -top packers on the two producers to protect against formation failure at the window during production, but nothing on the injectors. I don't know of any way to specifically evaluate the squeeze perfs with a cemented 4-1/2" liner in the way. A CBL in the 4- 1/2" wouldn't tell me about the squeeze perfs per se but I could get info on the liner cement job which is protecting the squeeze perfs. But any remedial work would require perforating that 4-1/2" liner, so it would have to look pretty bad to justify the risk of creating a new leak point. Only other log I can think of would be an oxygen activation log once the well is on injection — look for up -flow from the CTD window. But that's so unlikely in 1 R-26 especially given that we have competent, cemented surface casing external to these squeeze perfs. We took great pains to design a perforating charge that would penetrate the 7" but not the 9-5/8" surface casing even though the 7" is highly de -centralized, and we were successful in our test shots in accomplishing that. I think monitoring OA pressure is our best long-term gauge of whether we're getting any leakage into the OA. I hope that helps! -Gary Eller From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, May 2, 2019 8:59 AM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]KRU IR-26(PTD 191-092, Sundry 318-538) Plan Forward Kyle, Thanx for the additional information. The plan forward outlined below is approved. Is there any way to evaluate the cement in the squeeze perfs post liner cement? The CTD WSak completion will be an uncemented slotted liner with a LTP? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoo(oi7alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or Victoria.Loeoo@alaska gov From: Hampton, Kyle <Kyle.Ham gtonCcDconocophillips com> Sent: Wednesday, May 1, 2019 4:57 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Regg, James B (DOA) <Iim.reggCdalaska.gov>; Senden, R. <J.Gary.EllerPconocophillips com> Subject: RE: [EXTERNAL]RE: 1R-26 CBL Update Victoria Tyler <R.Tvler.SendenCcDconocophillips com>; Eller, J Gary We're preparing to run and cement the 4'/x" liner in place in well 111-26 (PTD 191-092). Our pressure testing indicates there is some leakoff into the squeeze perfs that will be dealt with during the liner cementing operation. Below are some pertinent details. • Calculations suggest the leak is roughly 0.2 gpm (i.e. 35 psi decline every 5 minutes) at 14.2 ppg equivalent mud weight (which exceeds our maximum anticipated injection pressure during injection operation). • We are not certain where in the perforated interval that it is leaking, but a test packer has confirmed that it's definitely within the squeeze interval. The most likely leak point is at the base of the perfs (4478' MD) given the signature of the CBL at that depth and that there is a path for leakoff via the shoe of the 9%" surface casing. • We conducted a passing MIT -OA to 1575 psi yesterday. There has been no indication of communication to the OA pressure gauge at surface • We believe the 4'/:" liner cement job will remediate any leakage in these squeeze perfs, and in fact that is one of the reasons it was included in the completion design. We've consulted with our cementing SME in Houston, and he thinks it is the best plan forward to address whatever channel or pathway that exists in the squeeze. He believes this should address the pressure leak and create a sufficient seal, better than another squeeze operation. • We're tentatively planning to increase the cement volume in our liner cement job, and we'll place the cement while holding some back -pressure to help force the cement to plug whatever channel exists. • Overall, we believe that the squeeze cementing operation went as well as it possibly could have, given that we have uncentralized 7" casing inside of 9%" casing. We met today with the Archer representatives who were on- site during the squeeze cementing operation. They attested that the pert -wash phase of the operations went very smoothly, and that there was not substantial material that had to be removed from behind the 7" casing, as we expected. The cementing phase likewise went quite well, and the bond log clearly indicates the positive results of the squeeze behind the 7" casing. I have attached the job details that Archer provided us with from the wash phase and the cementing phase of the squeeze. These include: • Screen shots from the Nabors 7ES RigWatch system during the pert -wash phase of operations. Typically the pert -wash data provides the best indicator of cement success because it shows how well the Barricade tool did at removing debris from behind the casing. In this case, the circulating pressures were very consistent throughout the entire wash and there was little debris across the shakers. We have learned that we need to come up with a better way of capturing the circulating pressure data on Nabors 7ES — a series of screen shots is not the most effective method available to us, but it's all that we have right at this moment. Schlumberger cementing record • Archer job log Please let us know if we can answer any more questions. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 ) Cell. 832-421-1506 1 Kvle.Hampton@cop.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, May 1, 2019 10:56 AM To: Hampton, Kyle <Kyle. Hamptonc@conocophillips.com> Cc: Regg, James B (DOA) <iim.regg@alaska.gov> Subject: [EXTERNAL]RE: 1R-26 CBL Update Kyle, Thank you for the CBL results, interpretation and reference schematic. Approval is granted to proceed with running the 4-1/2" liner. Please forward the second CBL interpretation when it becomes available as well as the cement job info. 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 ictoria. LoepDA alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@alaska.gov From: Hampton, Kyle <KVIe.Hampton@conocophillips.com> Sent: Wednesday, May 1, 2019 10:35 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Senden, James B (DOA) <[im.regg@alaska.aov> Subject: 1R-26 CBL Update Victoria, R. Tyler <R.Tyler.Senden@conocophillips.com>; Regg, I have attached the post -cement CBL pdf ( 1R-26 CBL _2 30APR19), the pre-perf CBL (1R-26 71N CBL 26APR19), and a couple slide explanation. We are currently waiting to hear back from our Cementing SME for a second interpretation on the CBL, but we feel that it shows cement isolation across the perf interval. The first slide shows the CBL interpretation. The second slide shows a schematic view of the well to provide context with formations and CTD exit points. We are currently gathering all of the information for the cement job and will be sending that over this afternoon. Pending your response, we will be ready to run the 4-1/2" liner this evening and cementing it in place tomorrow morning. Please let us know if you'd like to discuss. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle Ham oton@coo com PTD Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, May 16, 2019 9:05 AM To: Eller, J Gary Subject: KRU 1R-04 (PTD 185-178, Sundry 319-102) ;KRU 1G-03 (PTD 182-149, Sundry 318-536) Workover Revisions Approved Gary, Approval is granted as written below. Please update the approved sundry with this new approval. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 71h Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp r2 alaska. gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or victoria Loepp,d ala ska.00v From: Eller, J Gary <1.Gary.Eller@conocophillips.com> Sent: Tuesday, May 14, 2019 8:52 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Hayes, James C<James.C.Hayes @conocophillips.com>; Hampton, Kyle <Kyle.Hampton@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: Revision for Workover Sundries for KRU 1R-04 (319-102) and KRU 1G-03 (318-536) Victoria — I'd like to get your approval on some minor changes in the approved workover sundries for KRU 1 R-04 (PTD 185-178, sundry 319-102) and KRU 1G-03 (PTD 182-149, sundry 318-536). In both wells, ConocoPhillips wants to make minor corrections to the depths of the squeeze perfs and the location of wedges for future CTD exit points. In both wells, we've moved the CTD kickoff points uphole to avoid placing a window in a casing collar, and the squeeze perfs are likewise being moved uphole by the same amount. Approved Squeeze Parts New Squeeze Perfs Comment • 1 R-04: 3418'-3578' MD 3398'-3558' MD Moved 20' uphole (lower CTD exit point moved by same amount) 1G-03: 3675'-3835' MD 3669'-3829' MD Moved 6' uphole (lower CTD exit point moved by same amount) Attached are updated operational summaries for both wells, with revisions shown in red font. Please let me know if you need any other information to help facilitate this request. << File: 1G-03 Ops Summary for Sundry - update 5-14-19.pdf >> << File: 1R-04 Ops Summary for Sundry - update 5-13- 19. pdf >> KRU 1 R-04: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1 R-04 (PTD 185-178) is a Kuparuk injector equipped with 3'/z" tubing and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1 R-04 so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of 1 R-04; a CTD permit to drill (10-401) will be submitted in the near future for 1 R-04. The Kuparuk sand formation pressure in 1 R-04 is 2952 psi at 7618' MD, 6238' TVD, as measured on 2/22/08. For the plugging operations the maximum potential surface pressure is 2328 psi assuming a gas gradient of 0.1 psi/ft. The workover operations shall be conducted after the Kuparuk sands have been plugged. The expected pressure in the West Sak formation is 1557 psi at 3385' TVD (i.e. 0.46 psi/ft gradient, which is original formation pressure). The maximum potential West Sak formation pressure assumes an 0.8 psi/ft gradient, which equates to a maximum potential surface pressure of 2369 psi assuming a gas gradient of 0.1 psi/ft. • Recommended BOP Test Pressure during Kuparuk Sand plugging ops = 3000 psi • Recommended BOP Test Pressure during West Sak workover ops = 3000 psi Kuparuk Sand Plugging Operations 1. RU Slickline: a. MIT -IA to 2500 psi b. Drift tubing down to the tubing patch at 7840' KB. Tag fill at 8127' KB. 2. RU E -line: a. Tie in with CCL to tubing tally of 3/6/08. b. Punch holes in the 3'/s" tubing at —7900' KB, adjacent to the C -sand perfs. c. Pump down the tubing to confirm injection into the perfs d. Punch holes in the 3'h" tubing at —7665' KB, above the upper production packer. Perf in the lower half of the full joint immediately above the packer to leave room for the cement retainer in the same joint. e. Bullhead 105 bbl diesel down IA to confirm that the tubing punches are clear to the perfs. Diesel will serve as an IA freeze protect fluid after cementing. i. 105 bbl = 4000' in the 7" x 3'/z" annulus f. Set 3'/" cement retainer at —7645' KB, below the GLM at 7628' KB but above the tubing punches. 3. RU Service Coil and cementing unit: a. RU to take returns off the IA and the tubing b. RIH with CT. Sting into cement retainer at 7645' KB and establish injection into A and C -sand perfs with seawater. Monitor IA pressure to establish a baseline injection pressure. c. Prepare to pump 15.8 ppg class G cement. Page 1 of 3 i. This procedure calls for pumping a minimum of 27 bbl of cement to plug the 1 R-04 Kuparuk Sands completion, but we will blend cement on the fly in the event more cement is needed. d. Pump 15.8 ppg cement through the retainer into the A and C -sand perfs. Monitor pressure on IA continuously while pumping cement into the perfs. i. A minimum of 11 bbl of cement is expected just to fill the tubulars, but the intention is to pump sufficient cement to see at least a 300 psi increase in IA pressure. e. Once IA pressure has built to 300+ psi over baseline injection pressure, open up the IA to allow cement to enter the IA. Maintain 1:1 returns on the IA. Circulate a minimum of 11 bbl of 15.8 ppg cement into the IA, which is sufficient to place a 500' plug of cement in the IA. i. 500' of 15.8 ppg cement will add -160 psi hydrostatic pressure over diesel at the 1 R-04 inclination of ±450 . f. Sting out of the cement retainer and shut-in returns on the IA. Begin taking returns on the tubing. Lay in 5 bbl (minimum) of cement inside the 3.5" tubing, which is sufficient for a 500' plug of cement. g. Continue to POH while switching over to PowerVis to contaminate any leftover cement. Remain at 200' above calculated top of cement in the tubing until PowerVis turns the corner, and then POH while cleaning up any residual cement. 4. Slickline: a. After cement has had minimum of 24 hours to cure, RIH with slickline bailer. Tag top of cement. Pressure test cement plug to 2000 psi via tubing and IA separately. Provide 24-hour notice for the AOGCC to witness this operation. 5. E -line: a. RIH with jet cutter for 3'Y2", 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the tubing mid -joint at ±4500' KB (i.e. -1000' deeper than the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation Note: Well 1 R -04's intended service following CTD sidetrack is as a water -only injection well into the West Sak formation. The CTD KOP is tentatively planned at 35:34KB 31,93 T , v Li. 1. MIRU workover rig onto 1R-04. NU BOPE, test. 2. Pull old 3'/" tubing down to the cut at ±4500' KB 3. MIRU a -line a. (optional) Run CBL from -4400' to surface to evaluate cement behind the 7" casing. Tie into the Schlumberger EMIT log run in Jan/Feb 2019. b. Set Cl BP for 7", 26# casing at ±3700' MD as a base for cement. C. S _� a second 7 CiBP at 35£ig' ME RD a -line. 4. PU and TIH with ±160' of TCP guns (gun OD and shot density TBD). Tag CIBP to correlate depth for squeeze perfs MD (i.e. top of the N mudstone to mid West Sak D -sand). Page 2 of 3 5. Circulate hole full of t9.0 ppg brine to overbalance anticipated formation pressure 6. Fire TCP guns. 7. Circulate bottoms up, confirming adequate overbalance to formation pressure. Adjust brine weight as needed. 8. TOH, laying down spent TCP guns. 9. PU and TIH with cup -style perf wash & cementing tool 10. Use cup -style wash tool to wash squeeze perfs removing old mud, cuttings, and debris from between the 7" casing and the original 8'/z' borehole. 11. Prepare to pump 15.8 ppg class G cement. Use cup -style placement tool to ensure that cement is circulated through the perfs. a. Calculated annular volume between the 7" and the 8'/2' borehole is only 3.7 bbl for the 160' perforated interval, but be prepared to pump -23 bbl of cement (i.e. at least 2x the 8'/�" hole volume) to adequately squeeze this interval. 12. Pick up out of cement, circulate clean. 13. TOH, lay down cement squeeze assembly. 14. WOC as needed 15. PU drilling BHA with 6%" mill tooth bit. Drill out cement down plus the upper CIBP down to the lover CIBP at 3700' MD. Pressure test squeeze perfs to 14.2 ppg EMW (i.e. 0.74 psi/ft, or 920 psi at surface with 9.0 ppg brine in the hole). 16. MIRU a -line a. Run CBL across the squeeze interval to evaluate quality of the cement squeeze. 17. PU t330' of 4Y2", 12.6 ppf, L-80 liner on Liner will include two outer wedge assemblies spaced out for CTD exits at MD and MD. TIH, space out 4'/�' liner, putting the outer wedges on depth and the S3 liner -top packer within 200' MD of the deepest exit point (i.e. no shallower than 3.34' MD). 18. Set liner hanger. Cement 4'/:° liner in place with 15.8 ppg Class G cement. Set 33 packer, and pressure test IA. Circulate clean and TOH. 19. PU with 4'/i' completion and TIH. Sting seals into sealbore and space out. Circulate hole over to corrosion inhibited brine. Land tubing in tubing hanger. MIT -IA. Set BPV. 20. ND BOPE, NU 4-1/16" tree. RDMO. Page 3 of 3 THE STATE °fALAS- A GOVERNOR MIKE DUNLEAVY Ty Senden Wells Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1R-04 Permit to Drill Number: 185-178 Sundry Number: 319-102 Dear Mr. Senden: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner S DATED this _ day of May, 2019. RBDMS.�wMAY 0 2 2019 STATE OF ALASKA MAR L' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCO 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑r Other Stimulate ❑r�' v Pull Tubing ❑r Change Approved Program ElPlug for Reddll ElPerforate New Pool ❑v • Re-enter Susp Well L' 1 4� Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ 185-178 3. Address: Stratigraphic p Service ❑� 6. API Number: , PO Box 100360, Anchorage AK 99510 50-029-21407-00—D0 q/ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 4068 KRU 1R-04 Will planned perforations require a spacing exception? Yes ❑ No ❑V 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25635 Kuparuk River Field, West Sak Pool E aawJPa4l ✓ 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): 8440' 6864' 8127' 6620' 2328 n/a n/a Casing Length Size MD ND Burst Collapse Structural Conductor 115' 16" 115' 115' Surface 4298' 9-5/8"" 4298' 3927' Intermediate Production 8427' 7" 8427' 6853' Liner 1 1343' 1 5-1/2" 1 6061'-7400' 5127'-6079' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7892'-8188' MD (gross) 6442'-6667' (gross) 3-1/2", 9.31 L-80 7704' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): FHLB 7706'& 7815' MD, 6303'& 6384' tvd Baker FHL pkr (two) & FB-1 pkr, Baker CPH & 3D scab liner pkrs FB-1 at 8024' MD/6542' tvd, CPH at 6062'MD/5127' tvd, 3D at 7380' MD/6064' tvd 12. Attachments: Proposal Summary V Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/15/2019 OIL ❑ WINJ`��� WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Ty Senden Contact Name: Kyle Hampton Authorized Title: Wells Supervisor Contact Email: k le.ham ton a Conoco hilli s.com Authorized Signature: Date: 27 h Contact Phone: 907-263-4627 COMMISSIO14 USE ONLY Conditions of approval: Notify CItission ,sso that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test u Mechanical Integrity Test ❑ Location Clearance Other: Vanancc 9rs.-�tc�y-o SIoAAc 25.030 (d)C3 - l30P >=Bi- fo 3000 Ps- 9. t=5�-109a I, I'NrS a en otr i•Ibn: CPRI mv5irvfdc m I$Yf}k7,7V1ar ProVe*rl d-rI- fr 5Yo{ KVP4rvk well$ M tr,rAoRoFa Wes+ S.k InJ6 C+er tvftt,:5ur fQ cc e5in9 ,S Lro6 Se><Ab4vY Post Initial Injection MIT Req'tl? Yes No ,�/' the W<Sr 541:/Un rev 11 F1r,Oti ma rhahiurl !`VrF< rr� ❑ LJ fn fn mairw i et•,J"- gre55vre,. -thf, 1 Spacing Exception Required? Yes ❑ No EK Subsequent Foon Required: /0,10 ;7- /'' Sf be p(-nvi',4e whrn ri- v�5+rd by the A-oc,e� undwhcn o.4 �r<ssv ra develops. APPROVED BY Approved b) COMMISSIONER THE COMMISSION Date:/L•^/� ///7 I (/ Vrl 41rl,y l o R� Approved P L�G/II �@.pG �bra@J�L�"ark�r'aPprA✓s O ZO Submit Form and V orm 1 0 evised 4/2017 A roved a plica I 1 1 [ r m h i. MAY 2 c mems in Duplicate .���� $4x'.8.31311 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 20, 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 Applications (10-403s) to plug for re -drill the KRU 1 R-04 V/ (PTD# 185-178) and to perform workover operations to set the well up for CTD sidetrack in the West Sak formation. The plugging of the existing KRU 1 R-04 completion in the Kuparuk Sands is in accordance with the requirements of 20 AAC 25.112(c)(1). Following plugging, workover operations will prepare 1 R-04 for CTD sidetrack into the West Sak formation. Included in this workover summary is ConocoPhillips plans for achieving cement isolation behind the uncemented T' casing adjacent to the West Sak formation. Later, a Permit to Drill (10-401) application will be submitted for the planned West Sak lateral to be drilled with Nabors CDR3-AC in a mid -2019. Attached to the plugging application are the following documents: - 10-403 Sundry Application for KRU 1R-04 - Operations Summary in support of the 10-403 Sundry Application - Current well bore schematic - Proposed plugging schematic of the Kuparuk sands completion Attached to the workover application are the following documents: - 10-403 Sundry Application for KRU 1 R-04 - Operations Summary in support of the 10-403 Sundry Application - Current well bore schematic - Proposed post-workover schematic - Map of well penetrations in the West Sak formation within a quarter -mile of 1 R-04 - Mechanical review of West Sak penetrations within a quarter -mile of 1 R-04 If you have any questions or require additional information, please contact me at 907-263-4172. Sincerely, J. Gary Eller ConcoPtiigips Alaska)\` Wells Advisor KRU IR -04 Workover Setup for West Salt Injection Quarter -Mile Review Surface Top of D- Sur/ace Surface Surface Well Well Top of D -sand Casing Set Surface Casing Cement Arctic Pack PTD API Classification Well Well Status Pool (MD) Sand Oil Pool Casing Set Casing Set Casing Set Across West Operations Summary Cement Ops Mechanical Integrity Name (TVD) Depth (MD) Depth (TVD) Across Ugnu7 Sak? 93/8"'. 12M 1x(439 ball o1 PP E 123 ppg OA: 33 bbl Last 55 bbl WRMAL WELL lead a ISO sa Of obl 10 1 15.6 pog PF Chas. Ekse. 9/5/115. 33 bbl= TI FL passed 7/9/13 1RU13 2061% 500292110402 Predi LOU 3,694 3,383 4.381 3,BM TRUE I TRUE I FUll returns entire lob. Grf 3]9 Is (98 bbl) ]110'In6gannax,55bb1 CM ria oUrul rdpassMS/17)08 meMmsudare. NorecaProaOon. Fn= =]851'. MIT U1 Io I&Mpar passed 10/21/18 12.5onEMW. OA: 42 bel sent. 55 IN .0..L.F 95/e': 11505[(103 bell of 11-112.3 PW tll[SA, 9/16/85. 42 bel- MITJA[o also psi passed J/28/16 l0. -03n .1 SDOH2U0601 Injector sleeping 3,36) 3,3fi] 3.889 3699 NUE TRUE lead 1340v FS8 hall of 15.6 Pars PF-Ctall. Full returns esti re job, sheep Re(10 ball U14 In We annuli. 55 bel MR -0A to 1806 psi based]/28/16 marttosurlMe. FFT=12.5PKEMW. =1951'. IN: 42 W1 West 55 bbl WAIVEREP WELL be sub liner rating 9S/8":I. a(41]bbl) 112 323p06 deal, 9/18/85. 42 ab1= MIT IA to 3020 yl passed S/14/15 SRM 185-178 5002921407-11 Winner Inpat" 3490-3559' 3336'4389' 4,298 3,928 TRUE TRUE lead 1425 W 171 WII of T54 PFC tail, 1414' in re, annW'y 55 bbl MITM 0 I84 psi Passed 10/21/18 (no st (no al FLg repress entire led, circ 333l ON) owrface. Flr=12.5pp8EMW. '1851' OA: 43A b61 sort, X5 bbl NOUWgLWELL 9-5/8'n 1230 as(431 bel) of PF E 12.3pcg ping distant. 5/15/85. ]46b1= PFI passed 5/16/36 Of Of 1g5070 50-0292133006 PrWUWa proded, 3164 3.381 altar 3,7111 TRUE TRUE head 1425 V(716bU of ISO Ppb PFC 1393' In ca, annuli, 54.5 Mn -0A to IBM pJ passed 7/10/11 Good redrrsenOrepb, Wement[Osurfa[¢ WI=18N' FIT= 12.5 P, EMW. 1O -3W -:Moo Wof PF -E 136 III lead 1240A:42WCm49Gbbl WAIVEREDWELLIAVM ..a, WhoeM. sll of Ise plot III.11. he Well as diesel, 6/15/115. 42 bel= TI F L passed VIV17 ]0.0) 185-0Tt SP029-2.2. Producer Ensure., 31.16 3,Nfi 2,873 Z. muddle d led Ugnu IM.F carfare Top lob with W as FIT =132 ppg 855' In cap annuli, W WI= MIT M W III psi passed 2/9/17 EMW. 1853' CMITAA W 254 or paregard 1/24/13 Was: 29.6 Wl carat 55 bbl aORMALWELL 93/8':.605 x(40) bell of PFE 12.3 pp, the%I, TUNAS. MAJOR! M U -1A 0 MOD 01 Passed 5/tap5 30-08 ]1150)3 50029-2IM-00 InW hear IWaning 3.106 3,342 aall 3,817 TRUE TRUE I eae 1420¢ nO bbl) of Ise pp PK tag. - 936'. Wsg annuli. 55 Off vall to 18030 passed 7/5/09 G. reluma entire A,, 196 bbl cemMit. surfare. III =I2.S ppg EMW. 1851' 95/8". 11SOM(404661)of PFEt2.3ppg OR 42 bhp Cmt 56 bel WAIWR..ELUI . 1.15 185152 5602421387LO We, LT51 3,357 3.357 3,BIM 3,1faY TRUE TRUE lead 13105(52 MI) of 156 M PFC has diesel, WMAIS. 42bel= 1414' In M amull, 56 bbl MIT IN, to 200)0 passed S/2J/17 al to 3306 of passed 5/2]/1] Full returns entire lob, care so ass 1120 ball corearalt To forlace. IFF -. S pq E.W. IMS 9.Ar: Iles .(as..11 of PFE 122 ppg N—tand NORMALWnI In 16 185353 —5-13-- Produser 3.Spfi 3,371 ..OB1 3,812 TRUE TRUE Wad 1306 M(W bbl) of 15.7 FOR PF{ tall MIASo MIT) psi fo IBM psi Passed ed 3ag/1 MOTOR ,sulci qq GWd,ard. entire led, 50 bel cemenl to sIII FIT' 12.5 ppg EMW. 0 LTISI WS D 0Top West Sak Pick in 1R-04 ConoeoPh i I I i ps • Other West Sak Picks Alaska (� 1R-04 Top WS Ouartermile Buffer R-04 Well track Well 1 R-04 Top West Sak Pick — Active Well and Quartermile Buffer _-- Suspended well --- P&A Well with Nearby WellsN CPAI Lease West Sak Picks 0 0.1 0.2 2/28/2019 1 A off======== Miles wmI- t rs,nra1,a, qr .. rlANI .1 . ._.rm .,KA G�ciiz e, � ei a.oerh ,maim I.u,__ pD1-.b eIe. Ga e'1 1R nG rip W ,-a ft,. iT, ihbufiHn 8' SOH vhoe$g 15'MD JES shoe at 4299' D. e'A D 1R-04 Present Well Condition P care saM ]892'-]832' MO min $115-B 131' MD santl $145-8169' MD J 5 since ® a42r MO 1R-04 Workover Setup 4%" completion In preparatlonfor CfD sidetrack 9EMP 3554' MO 3-MWO. 49-Mq Inc WeaSakformation (top "3200' WO) 41835PWC squeeze perfs: 3418'- 3578' ]8' KB (360') Following squeeze, drill out & log, run 4.5",12.6 '.. ppf, L-80 liner cemented in place with UP packer @ '33W'KS. Shoe of linerat -3690, KB. ]" CIBP at '"3700' KB KRU 1 R-04: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1 R-04 (PTD 185-178) is a Kuparuk injector equipped with 3'/2° tubing and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1 R-04 so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of 1 R-04; a CTD permit to drill (10-401) will be submitted in the near future for 1 R-04. The Kuparuk sand formation pressure in 1 R-04 is 2952 psi at 7618' MD, 6238' TVD, as measured on 2/22/08. For the plugging operations the maximum potential surface pressure is 2328 psi assuming a gas gradient of 0.1 psi/ft. The workover operations shall be conducted after the Kuparuk sands have been plugged. The expected pressure in the West Sak formation is 1557 psi at 3385' TVD (i.e. 0.46 psi/ft gradient, which is original formation pressure). The maximum potential West Sak formation pressure assumes an 0.8 psi/ft gradient, which equates to a maximum potential surface pressure of 2369 psi assuming a gas gradient of 0.1 psi/ft. • Recommended BOP Test Pressure during Kuparuk Sand plugging ops = 3000 psi • Recommended BOP Test Pressure during West Sak workover ops = 3000 psi Page 1 of 3 2/20/2019 1. RUlickline: a. MIT -IA to 2500 psi b.\bbl'esel tubing down to the tubing patch at 7840' KB. Tag fill at -8127' KB. 2. RU E -1 a. with CCL to tubing tally of 3/6/08. k(� b. h oles in the 3'/2° tubing at -7900' KB, adjacent to the C -sand perfs. �� c. p do n the tubing to confirm injection into the perfs 2 Q d. h hole in the 3'/2° tubing at -7665' KB, above the upper production Pert the lower half the full immediately the to 5�, er. i of joint above packer Jr e room fort a cement retainer in the same joint. 7j e. ead 105 bbl 'esel down IA to confirm that the tubing punches are clear e parts. Diesel ill serve as an IA freeze protect fluid after cementing. i. 105 bbl = 400 'n the 7" x 3'/2' annulus f. '/2° cement retainer t --7645' KB, below the GLM at 7628' KB but above ubing punches.3. RU SeCoil and cementing unit:a. o take returns off the IA an the tubing b. with CT. Sting into cement r iner at 7645' KB and establish injection into A and C -sand perfs with seawater. Monitor IA pressure to establish a baseline injection pressure. c. Prepare to pump 15.8 ppg class G cement. Page 1 of 3 2/20/2019 i. This procedure calls for pumping a minimum of 27 bbl of cement to 'lyg the 1 R-04 Kuparuk Sands completion, but we will blend cement on the fly in the event more cement is needed. d. Pump 15.8 1pg cement through the retainer into the A and C -sand perfs. Monitor press re on IA continuously while pumping cement into the perfs. i. A minimum of 11 bbl of cement is expected just to fill the tubulars, but the intentioR is to pump sufficient cement to see at least a 300 psi increase in I pressure. e. Once IA pressure ha built to 300+ psi over baseline injection pressure, open up the IA to allow cem6,nt to enter the IA. Maintain 1:1 returns on the IA. Circulate a minimum of 1 bbl of 15.8 ppg cement into the IA, which is sufficient to place a 500' lug of cement in the IA. i. 500' of 15.8 ppg cement will add -160 psi hydrostatic pressure over diesel at the 1 R-04 inclination of ±450 . f. Sting out of the cement retaine and shut-in returns on the IA. Begin taking returns on the tubing. Lay in 5 b(minimum) of cement inside the 3.5" tubing, which is sufficient for a 500 lug of cement. g. Continue to POH while switching ov leftover cement. Remain at 200' ab until PowerVis turns the corner, and cement. to PowerVis to contaminate any � c�alculated top of cement in the tubing eR POH while cleaning up any residual 4. Slickline: a. After cement has had minimum of 24 hours cure, RIH with slickline bailer. Tag top of cement. Pressure test cement plu to 2000 psi via tubing and IA separately. Provide 24-hour notice for the AO CC to witness this operation. 5. E -line: a. RIH with jet cutter for 3'/i', 9.3 ppf, J-55 tubing. ie in with CCL. Jet cut the tubing mid -joint at±4500' KB (i.e. -1000' deeper han the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation Note: Well 1 R -04's intended service following CTD sidetrack is as a water -only injection well into the West Sak formation. The CTD KOP is tentatively planned at 3554' KB, 3385' TVD. 1. MIRU workover rip onto 1R-04. Nu BOPE, test. 2. Pull old 3%" tubing down to the cut at ±4500' KB 3. MIRU a -line a. (optional) Run CBL from -4400' to surface to evaluate cement behind the 7" casing. Tie into the Schlumberger EMIT log run in Jan/Feb 2019. b. Set CIBP for 7", 26# casing at ±3700' MD as abase for cement. RD a -line. 4. PU and TIH with ±160' of TCP guns (gun OD and shot density TBD). Tag CIBP to correlate depth for squeeze perfs 3418'-3578' MD (i.e. top of the N mudstone to mid West Sak D -sand). 5. Circulate hole full of±9.0 ppg brine to overbalance anticipated formation pressure Page 2 of 3 2/20/2019 6. Fire TCP guns. 7. Circulate bottoms up, confirming adequate overbalance to formation pressure. Adjust brine weight as needed. 8. TOH, laying down spent TCP guns. 9. PU and TIH with cup -style perf wash & cementing tool 10. Use cup -style wash tool to wash squeeze perfs 3418'-3578', removing old mud, cuttings, and debris from between the 7" casing and the original 8'/:" borehole. 11. Prepare to pump 15.8 ppg class G cement. Use cup -style placement tool to ensure that cement is circulated through the perfs. a. Calculated annular volume between the 7" and the 8'/" borehole is only 3.7 bbl for the 160' perforated interval, but be prepared to pump —23 bbl of cement (i.e. at least 2x the 8'/2" hole volume) to adequately squeeze this interval. 12. Pick up out of cement, circulate clean. 13. TOH, lay down cement squeeze assembly. 14. WOC as needed 15. PU drilling BHA with 6%" mill tooth bit. Drill out cement down to bridge plug at 3700' MD. Pressure test squeeze perfs to 14.2 ppg EMW (i.e. 0.74 psi/ft, or 920 psi at surface with 9.0 ppg brine in the hole). 16. MIRU e -line a. Run CBL across the squeeze interval to evaluate quality of the cement squeeze. 17. PU ±330' of 4'/:", 12.6 ppf, L-80 liner on ZXP liner hanger/packer. Liner will include two outer wedge assemblies spaced out for CTD exits at 3554' MD and 3524' MD. TIH, space out 4'/2" liner, putting the outer wedges on depth and the ZXP liner -top packer within 200' MD of the deepest exit point (i.e. no shallower than 3354' MD). 18. Set liner hanger. Cement 4'/2" liner in place with 15.8 ppg Class G cement. Set ZXP packer, and pressure test IA. Circulate clean and TOH. 19. PU with 4'/1" completion and TIH. Sting seals into sealbore and space out. Circulate hole over to corrosion inhibited brine. Land tubing in tubing hanger. MIT -IA. Set BPV. 20. ND BOPE, NU 4-1/16" tree. RDMO. Page 3 of 3 2/20/2019 KUP INJ 1 R-04 CofiocoPhlllIpS AlasKd.IrIC TD Well Attributes MaC) MD( ) weuGam u1N FiaW Nam. wellMra statue nn rl MD mice) MBIm InNB) 5 0 0 2 9214 0]00 KUPARUK RIVER UNIT ,NJ46.82 5200.00 8,440.0 Cwnmen[ (Pw) 104heNanr+l SSSV: NIPPLE EM WYe LasI WO: 3/812008 NBlnJ lnl fllO Release 38.69 911811985 IRoa. arzrzou x:5707 PM en¢au mala ncWa m �-- dWk Last Tag: SLM 8,1270 452916 LzsIMM Y F1100Me Rev ReasM:NOTE UPDATE IeM1allf 2CL2015 _..... HPNGER, 339 _.. 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MI -ea .., -a TOP mad CashraDaNchl,%dan OD(ln) 511 SCAB LINER 51/2 4.950 6057.0 7.400.0 6.078.7 15.50 LAD 5-1/2 Hyd Liner Details N minm ID PoP(RKS) Ta` -R` -B) T"Wi) K' Des Com (In1 6.061.8 5,12]4 4739 PACKER CHPLMERTOPPACKER 4940 ?3804 I 30 LINER HANGER PACKER 4.950 Tubing Strings peal BWOloe 12.9SN oen]04.0BM 63013 1Y191) .30GrMe IBoTP MTUBING s3112n2992iconnedlan Completion Details Nominal ID Tap NMS) Top( ep Nee, 1 Tap Incl(' hearDes- Lom (In) 32.9 32.9 0.09 HANGER FMCG N (TUBING HANGER 3.500 01.0 501.0 0.30 NIPPLE CAMCO SNIPPLE 2.075 76912 629 b 62.12 LOCATOR BAKER LOCATOR 3.000 7,683.5 6,293.6 62.10 TEAL ASSY BAKER 8040 SEAL ASSEMBLY STABS IN TO 3.000 STALKER PACKER r. -WI semnom .. Top LIMBI sN DepM NL. Bet D)1-Vnl GrWe oP nna[Ilon STACKER PACKER 318 n2,%2 7,692.6 7,79L0 6.366.3 9.30 LA0 IDLESrtl Completion Details Namkal lB Tap TNB) Top IND)NKBI Tap Ind l-) I Ifem As Lwn LIN ).692.6 6,292.9 42.11 PBR BAKERBII40PSR 3.020 7,706.0 6,302.8 42.01 PACKER BAKER FHL PACKER 2.930 6334.8 41.M NIPPLE CAMEO DS NIPPLE NO GO 2.812 )] 9J 6.16.3 41.45 SFALASBy BAKER 8n40 SEAL ASSEMBLY 3.0001 mg Iglan Nna Me... IO Pn) oP lneBl x(tt. sato (... Yn NLLTII GIW. Top Lan..kah TUBING Original 4 2.992 ?7902 6,047.5 6,559.3 Completion Details Nammal lD TnPmKB) TWMD)(WB1 Twlnclr) lkm Dee Lam Nm 7,801.5 6,374.1 41.38 PER BAKER PER 3.000 7,815.2 6384.4 41.39 PACKER BAKER FHL PACKER 3.000 7891.3 6,441.5 41.43 BLASTRINGS (2)BVST RINGS 2.992 .985.1 6512.1 40.96 NIPPLE AVA PORTED NIPPLE 2.50 0.022.6 6,5404 40.]1 LOCATOR BAKER LOCATOR SUB 27M 8,0244 6,541.8 4D.)0 PACKER BAKER REA PACKER 2347 8,039.2 65530 4059 NIPPLE CAMCOVNIPPLE 2250 8046.6 6.558.8 40.53 SOS GAMCO SHEAROUT SUB 2441 Other In Hole (Wireline retrievable plugs, valvas, pumps, fish, etc.) Tap(Na) Tap ln[I Lom RYn Oata ID lin) iep IRNB) (Ml8) fl ).840,0 6403.0 4140 PATCH ES RCP patch bn8M 2)AS', 6olalin8 ak0an 119 $012000 1.310 GLM ],985.1 6,5121 40.96 SLEEVE -C BPI ISO sleeve sat 4112000 4118000 2.310 8,1360 6,6269 19.8]FISH PO VeNa Lel Pieceain Hole fi22/1995 Perforations & Slots TaP InK O) Bbn IHNB T mK.L 1n6.4 6Im (rvD) (LMB) Zane DeM sxx B ne bxetzn Tra 0m1 7,892.0 7,932.0 6442.0 648.1 Gt, iR-00. 102811985 12.0 IPER' 5-Expentlable HJ 11: 120 tlep ph 8,flfi.0 8,134.0 6,611.6 6,625.4 A-0, 1R-04 1028/1985 120 WERE 4 -HJ II Call Gun: Wtlep pM1 8,146.0 8,188.0 6,634.6 6.fifi7.0 A-3.18-04 10/2811985 4.0 IPERF T HJ II Cs9 Gun; 98 tlep ph Mandrel Inserts 3[ I onTop(N01 N Top1aNB) (INLB) Melee Male/ ODNN Ban' VeNe Tee rkpa Pon Atre TflO Run II n) (paD Run OXe Com 7.645.7 6255.3 CAMEO KBG-2- 1 9 GA5ULI DM INT 0.000 0.0 32Y2008 2 7,853.8 6413.4 MERLA TMPG 1 IW PATC H BK BDW 0.011012311995 Notes: General & Safety End Dake AmL.. 112000 NOTE: Found possible leaks @785WVL-M&)842' WLM(PATCHED 572000) 1612008 NOTE: -"WARNING'^Max test Pressure on IA 19ON dUe m Swb Liner PKR @ 7380 10I1412ptp NOTE View Schematic w/ Aleek,I SchervI 228015 NOTE Scabliner-max d-Belend-1Prea9Ym1Bm pat MEMORANDUM TO: Jim Regg --? S P.I. Supervisor V (( I FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 24, 2019 SUBJECT: Well Bore Plug & Abandonment KRU 1 R-04 Conoco/Phillips Alaska PTD 1851780; Sundry 319-092 Section: 20 - Township: 12N Range: 10E Drilling Rig: NA Rig Elevation: NA Total Depth: 8188 ft MD Operator Rep: Bryce Worthington Suspend: Casing/Tubing Data (depths are MD): Conductor: 16" - O.D. Shoe@ Surface: 95/8" - 0. D. Shoe@ Intermediate: Feet 0. D. Shoe@ Production: T' 0. D. Shoe@ Liner: 5.5" 0. D. Shoe@ Tubing: 3.5" 0. D, Tail@ Plugging Data: Test Data Meridian: Lease No.: ADL0025635 P&A: X - Tvpe Pluo Founded on Casing Removal: 115 Feet Csg Cut@ Feet 4298 Feet Csg Cut@ Feet 20 Feet Csg Cut@ Feet 8427 Feet Csg Cut@ Feet 7400 Feet Csg Cut@ Feet 7704 Feet Tbg Cut@ Feet Tvpe Pluo Founded on Denth Btm De th (Tnnl MW Above Verified Open Hole Retainer - 7641 ft MD 7207 ft MD " 15.8 Wireline tag 20 20 Initial 15 min 3n min ec . ice o,.....if Tubing 2280 2185 2150 " IA 955 960 960 P ✓ OA 20 20 20 Initial 1S min 'An min A9 ...i., o......i. Tubing 710 715 715 IA 2260 - 2130 2060 P OA 20 20 20 Remarks: The MIT -T passed with no issues. The MIT -IA failed the first attempt with a slightly over 10% total loss over a 30 minute test period. The second MITIA attempt was a pass (included above). The first tag of cement gathered a good solid sample of cement. The second tag, after the MIT -T, came in at the same footage as the first - 7170 ft WL. There was a 37 -foot correction for wireline to get it back to drilling rig rkb measurements. Attachments: none 11 rev. 11-28-18 2019-0424_Plug Verification_KRU_1R-04_gc Loepp, Victoria T (DOA) From: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Sent: Tuesday, April 23, 2019 5:56 PM To: Loepp, Victoria T (DOA); Eller, J Gary Subject: RE: [EXTERNAL]KRU 1 R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Follow Up Flag: Follow up Flag Status: Flagged Victoria, Sorry for finally following up on your email. Our plan to handle these West Sak water injection wells is no different that every other well. Obviously we'll monitor the OA pressures, as required by law, but we'll also put notes into our Annular Communication database and our fieldwide SCADA system maintained by Operations staff. These notes will act as "rules" within our WellTracker software package and notify the Well Integrity Supervisors and the Drill Site Operator if/when a high OA pressure exists and what may be the likely cause. I personally don't foresee these West Sak injectors causing any problem at all but do feel that our normal everyday monitoring, tracking and notification system is more than adequate to alert us if there should be a problem, just as it does for regular Kuparuk wells. Please let me know if this satisfies your concern, otherwise, I'd be more than happy to sit down and discuss at your convenience. Thanks, Ty Senden Director, Integrity, Interventions, Well Testing and Workovers Conocophillips Alaska, Inc. ATO -1396 907-265-1544(o) 907-982-3996(C) r.tyler.senden@cop.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, April 18, 2019 8:27 AM To: Eller, J Gary <J.Gary.Eller@conocophillips.com> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Gary, Received the information you sent, thank you. Only concern is the monitoring of the OA pressures in the Kuparuk wells with surface casing set above the West Sak. While I understand these are monitored daily, I'm concerned that they may not be flagged in your system as having this configuration such that the mechanical integrity people will not identify the source of the pressure if the OA pressures increase. There are a number of Kuparuk wells with surface casing above the West Sak that have been identified. I've copied Ty Senden as he may be able to address this. Thanx, Victoria Loepp Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, April 18, 2019 2:08 PM To: Eller, J Gary; Senden, R. Tyler; Driscoll, Michael D Subject: OA Monitoring in Kuparuk wells with Surface Casing set above W Sak Gary, Ty, The following highlighted comments are what you have provided concerning OA monitoring in Kuparuk wells with surface casing set above the West Sak. These wells are in the AOR of West Sak injectors. They have no cement above the hydrocarbon bearing West Sak. They do not meet regulations for cement above HC bearing zones. For a variance(equally effective), we need more assurance that these wells are specifically identified/flagged with their unique configuration and evaluated if elevated OA pressures are encountered. There are other Kuparuk wells with this configuration that the AOGCC has asked to be monitored for OA anomalies. I'm not sure if CPAI has these wells specifically identified and monitored as was required in several WSak PTDs. That being said, what you have provided below is not adequate and additional assurance from the mechanical integrity group is needed. We can have a meeting or a description/proposal can be emailed sooner. Any additional monitoring requirements will also be applied to 1G-06 and 1G-16. "Similarly, in that approved sundry application there were no incremental monitoring plans for offsets 1G-06 and 1G-16." "For 1 R-04 and other similar West Sak injection wells, ConocoPhillips will continue to routinely monitor well annuli pressures in offset Kuparuk wellbores. In particular, the occurrence of elevated OA pressures in any of these wells would lead to evaluation followed by action to address the underlying issue. " Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loepp(ovlalaska 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). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria LoeOPAaias a. oy From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Thursday, April 18, 2019 12:44 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conoco phi Ili ps.com>; Driscoll, Michael D <Michael.D.DriscolI@conocophiIlips. com> Subject: RE: [E) TERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Victoria — I'd like to bring Ty Senden and Mike Driscoll over to meet with you to discuss this with you face-to-face. We've been trading emails on this for 4 weeks without much headway, and we're rapidly approaching the proposed start date for this 1 R-04 workover. Would you be available Wednesday (4/24) morning, say at 8:30 a.m. or so? -Gary Eller From: Loepp, Victoria T (DOA) <victoria loepp@alaska.gov> Sent: Thursday, April 18, 2019 8:27 AM To: Eller, J Gary <J Gary.Eller@conocophillips.com> Cc: Senden, R. Tyler <R Tyler Senden@conocophillips.com> Subject: [EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Gary, Received the information you sent, thank you. Only concern is the monitoring of the OA pressures in the Kuparuk wells with surface casing set above the West Sak. While I understand these are monitored daily, I'm concerned that they may not be flagged in your system as having this configuration such that the mechanical integrity people will not identify the source of the pressure if the OA pressures increase. There are a number of Kuparuk wells with surface casing above the West Sak that have been identified. I've copied Ty Senden as he may be able to address this. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loepp(a),alaska.00v, CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeipip@ola5ka.gov From: Eller, J Gary <J Gary Eller@conocophillips.com> Sent: Thursday, April 18, 2019 7:55 AM To: Loepp, Victoria T (DOA) <victoria loepp@alaska.Rov> Cc: Hampton, Kyle <Kyle Hampton@conocophillips.com> Subject: RE: [EXTERNAL]KRU IR-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Victoria — I'm just back from Hawaii today. Can you tell me if this workover sundry for KRU 1 R-04 has been approved? I assume you received the updated '/<-mile map? -Gary From: Loepp, Victoria T (DOA) <yictoria.loepp@alaska.gov> Sent: Friday, April 5, 2019 5:55 PM To: Eller, J Gary <J Gary Eller conocophillips.com> Subject: Re: [EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Thx, have a great time in Hawaii! Sent from my iPhone On Apr 5, 2019, at 3:47 PM, Eller, J Gary <J Garv.Eller@conocophillips.com> wrote: Victoria — I had hoped to have both of these ready for you today but we're not quite there. Attached is the 1G-06 schematic which includes Ugnu and West Sak formation tops. I was unable to get file access yet to the 7" CBL of 1/31/83 so I can't tell you where the cement top is, but the cement top is certainly well below the West Sak formation. The 1G/1 R spider map at the West Sak horizon will be sent to you by Lee McAuliffe early next week. Please be aware that the directional plans on the map are probably not the final directional plans that we'll submit with our CTD drilling permits, so the areas will change slightly. -Gary From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Thursday, April 4, 2019 3:15 PM To: Eller, J Gary <J.Gary Eller@conocophillips.com> Cc: Hampton, Kyle <Kyle Hampton@conocophillips.com>; McAuliffe, Lee 1 <Lee J McAuIiffe@conocoPhil Iips.com> Subject: RE: (EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Could you please provide a spider map of the current West Sak wells(and proposed new West Sak wells) in the DS -1G and DS -1R area. Also, a WBS for 1G-06. Thanx, Victoria From: Eller, J Gary <J Gary Eller conocophillips.com> Sent: Thursday, April 4, 2019 3:06 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Cc: Hampton, Kyle <Kyle Hampton @conocophillips com>; McAuliffe, Lee J <Lee J McAuliffe@conocophillips.com> Subject: RE: (EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Victoria — I've had the opportunity to discuss the issue of crossflow with a few peers. Reservoir management practices for West Sak aim to maintain voidage replacement only and seek to avoid over- pressuring the reservoir. Empirical evidence shows that over -pressuring the West Sak formation can damage the waterflood pattern by short-circuiting injection to offset producers through the friable West Sak formation. This management practice keeps the average reservoir pressure of the West Sak close to original pressure during production. So although the flow path for West Sak to Ugnu exists through some offset Kuparuk penetrations like 1 R-07, the pressure differential will be minimal and significant crossflow is not expected. Additionally the in-situ viscosity of the Ugnu is high enough to restrict flow within the Ugnu reservoir itself, minimizing risk of crossflow, to the Ugnu reservoir. For 1 R-04 and other similar West Sak injection wells, ConocoPhillips will continue to routinely monitor well annuli pressures in offset Kuparuk wellbores. In particular, the occurrence of elevated OA pressures in any of these wells would lead to evaluation followed by action to address the underlying issue. I'm in the office tomorrow (4/5/19) but then out on vacation for most of the next 2 weeks. So please use 'REPLY ALL' if you write back with other questions so that Kyle and Lee can respond promptly. Thanks. -Gary From: Loepp, Victoria T (DOA) <victoria loepp@alaska.gov> Sent: Thursday, March 28, 2019 9:57 AM To: Eller, J Gary <J Gary Eller@conocophillips.com> Subject: [EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Gary, Please discuss the issue of crossflow from the West Sak into the Ugnu in % mile wells where the surface casing is above both the West Sak and Ugnu. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria LoeppOalaska.gov 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 recipieni(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793- 1247 or Victoria Laepo@alaska.aov From: Eller, J Gary <J Gary Eller@conocophillips.com> Sent: Tuesday, March 26, 2019 9:41 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Hampton, Kyle <Kyle Hampton@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Victoria — I'll get working on that 1 R-07 schematic, but the short answer is that we're planning no incremental monitoring at 1 R-07 since 1 R-04 has been permitted as a water -only injector. AIO 2C provides for incremental monitoring of offsets to VRWAG injectors but there's no specific monitoring required for offsets to water -only injectors. The situation between 1 R-04 and 1 R-07 is mechanically similar to that between proposed water -only injector 1G-03 (182-149) and 1G-06 (182-220) and 1G-16 (183-155). Both 1G-06 and 1G-16 are within %-mile of the proposed 1 G-03 and neither have surface casing set across the West Sak. But in 1 G -03's workover sundry application (318-536), we demonstrated that the remedial cementing plan will adequately prepare that well for water -only injection into the West Sak. Similarly, in that approved sundry application there were no incremental monitoring plans for offsets 1G-06 and 1G-16. I hope that helps clarify. Please let me know if you'd like to discuss further. -Gary From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, March 19, 2019 9:27 AM To: Hampton, Kyle <Kyle Hampton @conocophillips.com>; Eller, J Gary <1 Gary.Eller@conocophillips.com> Subject: [EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Walkover: CTD Set up for WSak Kyle, Gary, Please provide a WBS for KRU 111-07 showing cementing and zones. What are plans for KRU 111-07 given West Sak is below the SC shoe, KRU 1R-04 will be injecting and KRU 1R-07 is within the Y4 mile AOR. Tha nx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loeppraflalaska goy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793- 1247 or Victoria Loeoo@o1aska aov From: Hampton, Kyle <Kyle Hampton@conocophillips.com> Sent: Tuesday, March 19, 2019 9:00 AM To: Loepp, Victoria T (DOA) <victoria loepp@alaska.9ov> Subject: RE: [EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Victoria, We are planning to use Nabors 7ES for this work (schematic attached). Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 [ Kvle Hampton@coq com From: Loepp, Victoria T (DOA) <victoria loepp@alaska.gov> Sent: Friday, March 15, 2019 10:03 AM To: Hampton, Kyle <Kyle Hampton@conocophillips com> Subject: [EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Kyle, What rig is planned? Please provide BOP/Choke manifold drawings. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loem)( alaska.aov CONFIDENTIALITY NOTICE., This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact victoria Loepp at (907)793- 1247 or victoria Loeoo@alaska aov <1G-06 Offset schematic.pd5 6 w r ConocoPhillips Alaska West Salk CTD Wells with Injector 1/4 -mile Buffers and West Salk Intervals Marked All Other Wells -� ii j 1Q,; ns 0 1 N �ve*11G,. stt0 u2 0.4� 0.6 0.8 Miles / ppd/ OW West Bak Picks Aare vas OW West Sak Picks Suspended / WS CTD Injector Plugged and Abandoned WS CTD Producer WS CDT Injector -114 We Buffer of WS Interval / CPAI Leese ConocoPhillips Alaska West Sak CTD Wells with Injector 1/4 -mile Buffers and West Sak Intervals Marked All Other Wells 4/8/2019 5r§ WD D N � r� 'il srz0 0.2 0.4� 0.6 0.8 Miles OWWest Sak Picks Active / D 0 OW West is Picks $U6Fellded - WS CTD Injector Plugged and Abandoned WS CTD Producer WS CDT Injector -114 Mile Buffer of WS Interval CPAI Lease 1G-06 Kuparuk Sand Injector 16" Conductor 65# H40 shoe @ 80' MD 10-3/4" Surface 45.5# J-55 shoe at 2248' MD, 2060' SSTVD Cemented to surface Arctic Pack Cement in OA: 41 bbl, est. 844' column but displacement volume unknown (1/30/83) Top of Ugnu C -sand 2944' MD, 2594' SSTVD Top of West Sak D -sand 4007' MD, 3253' SSTVD Top of 7" cement via CBL of 1- 31-83 7" Production 26# J-55 shoe @ 9235' MD, 6692' TVD 16" Conductor 65# H-40 shoe @ 80' MD 10-3/4" Surface 45.5# J-55 shoe at 2248' MD, 2060' SSTVD Cemented to surface 7" Production 26# J-55 shoe @ 9235' MD, 6692' TVD 1G-06 Kuparuk Sand Injector tic Pack Cement in OA: bbl, est. 844' column but Placement volume :nown (1/30/83) M nu C -sand ,2584'SSTVD A Sak D -sand 3253' SSND Top of 7" cement —,IXXIt' via CBL of 1- 31-83 IR -07 Kuparuk Sand Producer nm.me� I 11a MD ' �\ �- Arctm vack Cement in OA. 62 bbi, ert. 1653'3738' MD (6/15/85) Top of Ugo C- 2713' MD, 2591' SSWD Topof Westyak D- nd 3/16'MD, 3262'55WD Top of 7" cement "5750' Wa CBL of 6- &85 .155 ante @ 71W D,fD18'TVD IR -07 Kuparuk Sand Producer 1 4' Top of UBnu C -sand 2871' .D2 , AD 22TVD 2743' MD, 2591' SSND ICernwhadm su II I I I Top of West Sak D -sand 3416' MD, 3262' SSND Top of 7" cement —575V via CBL of 6- 8-85 J566koe � 71W D, 8918' ND 6nea@ tfiaVl \ 1;;�� Arctic Cement in DA. pack \ � 42bbl, bbl,est. 1853'-2]18'MD (6 1 4' Top of UBnu C -sand 2871' .D2 , AD 22TVD 2743' MD, 2591' SSND ICernwhadm su II I I I Top of West Sak D -sand 3416' MD, 3262' SSND Top of 7" cement —575V via CBL of 6- 8-85 J566koe � 71W D, 8918' ND NABORS ALASKA RIG 7ES BOP STACK CONFIGURATION 13 5/8" 50001 WP HYDRIL, TYPE GK" 13 5/8" 50001 WP LATCHED TOP BY 13 5/8" FLANGED BOTTOM ANNULAR BOP 54 1/2" LENGTH 13-5/8" 50001 FLANGED HYDRIL DOUBLE GATE PREVENTOR 58 1/8" LENGTH 3" 50001 HCR VALVE 2" KILL LINE 7001 GATE VALVE - HYDRIL 13-5 8" 5k PSI HYDRAULIC RA SINGLE GATE FLANGEQ, CONNECTION 36 LENGTH NABORS ALASKA RIG 7ES BOP STACK CONFIGURATION 13 5/8" 50001 WP HYDRIL, 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 HYDRIL DOUBLE GATE PREVENTOR 58 1/8" LENGTH J" 50001 HCR VALVE 2" KILL LINE 700' GATE VALVE - HYDRIL 13-5 8" 5k P51 HYDRAULIC RA SINGLE GATE FLANGE., CONNECTION 36 LENGTH Loepp, Victoria T (DOA) From: Hampton, Kyle <Kyle.Hampton @conocophiIIips.com> Sent: Tuesday, March 19, 2019 9:00 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 1 R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Attachments: 7ES BOP Config.pdf Follow Up Flag: Follow up Flag Status: Completed Victoria, We are planning to use Nabors 7ES for this work (schematic attached). Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle.Hampton@cop.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, March 15, 2019 10:03 AM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Subject: [EXTERNAL]KRU 1R-04(PTD 185-178, Sundry 319-102) Workover: CTD Set up for WSak Kyle, What rig is planned? Please provide BOP/Choke manifold drawings. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeop(rDalaska.go CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victona.Loeoo@alaskagov Boyer, David L (DOA) From: Roby, David S (DOA) Sent: Thursday, February 28, 2019 3:29 PM To: Hampton, Kyle Cc: Loepp, Victoria T (DOA); Boyer, David L (DOA); Wallace, Chris D (DOA) Subject: RE: [EXTERNAL]Sundry application for KRU 1 R-04 (PTD 185-176) Thanks Kyle, This answers all my concerns. Regards, Dave Roby 907-793-1232 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 Dave Roby at 907- 793-1232 or dave.robvC@alaska.¢ov. From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Thursday, February 28, 2019 3:20 PM To: Roby, David S (DOA) <dave.roby@alaska.gov> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Boyer, David L (DOA) <david.boyer2@alaska.gov>; Wallace, Chris D (DOA) <chris.waIlace @alaska.gov> Subject: RE: [EXTERNAL]Sundry application for KRU 113-04 (PTD 185-176) David, 1) We are working on a 5 well pilot program of converting Kuparuk wells that do not have a significant reservoir impact (redundancy, shut-in, etc.) for a West Sak CTD development program. 2) Once 1R-04 is converted, we will be able to use 111-03 to accommodate the rate needed to fully support this area. 111-03 is so close to 1R-04 (^800' away) and in the same horizon that we don't feel there will be an issue. When we model the change in injection from 1R-04 to 1R-03, our sweep efficiency actually increases due to the new sweep pattern. 3) We still need to maintain injection in the unit, but we feel we'll be able to benefit from changing the sweep pattern of the area. Let me know if you need anything else. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 ) Kyle. Hampton@cop.com From: Roby, David S (DOA) <dave.robv@alaska.gov> Sent: Wednesday, February 27, 2019 3:04 PM To: Hampton, Kyle <KVIe.Hampton@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.Ioepp@alaska.gov>; Boyer, David L (DOA) <david. bover2@alaska.eov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: (EXTERNAL]Sundry application for KRU 111-04 (PTD 185-176) Kyle, In reviewing the subject sundry application I have a couple of questions for you. 1) The KRU 1R-04 well is in active water injector, putting away 2-4 MBWPD, what is the reason for converting this well from a Kuparuk injector to a West Sak development well? 2) Is there another Kuparuk injector that will make up for the loss of injection support from this well when it is converted? 3) Is injection support in this portion of the pool no longer needed? Thanks in advance. Regards, David Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 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 forth e 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 Dave Roby at 907- 793-1232 or dave.robv@alaska.eov. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Kyle Hampton Senior Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-04 Permit to Drill Number: 185-178 Sundry Number: 319-092 Dear Mr. Hampton: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaslka.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, 4)/�� Daniel T. Seamount, Jr. Commissioner / DATED this -57 day of March, 2019. RBDMSL-* MAK 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED wES 2 6 2019 ; OGCC 1. Type of Request: Abandon ❑ Plug Perforations [71 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[] Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program[] Plug for Redrill 121 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Conocoichillips Alaska Inc Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑. 185-178 - 3. Address: 6. API Number: - PO Box 100360, Anchorage AK 99510 50-029-21407-00 — 00 g 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1 R-04 Will planned perforations require a spacing exception? tJA Yes ❑ No ❑ 9. Property Designation (Lease Number):10. zmA Field/Pool(s): , ADL 25635 Ku aruk River Field, Kuparuk River Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (fl): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8440' 6864' 8127' 6620' 2328 n/a n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 115' 115' Surface 4298' 9-5/8"" 4298' 3927' Intermediate Production 8427' 7" 8427' 6853' Liner 1343' 5-1/2"6061'-7400' 5127-6079' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7892'-8188' MD (gross) 6442-6667' (gross) 3-1/2", 9.3 plat L-80 7704' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (fl): FHLB 7706'& 7815' MD, 6303'& 6384'tvd Baker FHL pkr (two) & FB -1 pkr, Baker CPH & 3D scab liner pkrs FB -1 at 8024' MD/6542'tvd, CPH at 6062'MD/5127' tvd, 3D at 7380' MD/6064'tvd 12. Attachments: Proposal Summary ❑� Wellbore schematic E] 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service [21 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/1/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Kyle Hampton Contact Name: Kyle Hampton Authorized Title: Senior Wells Engineer Contact Email: k le.ham ton Conoco hill) s.com Authorized Signature: Dater yDl d. l Contact Phone: 907-263-4627 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / (, Plug Integrity ISi BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / Post Initial Injection MIT Req'd? Yes ❑ No le t3 Spacing Exception Required? Yes No d Subsequent Form Required: � a' —r �L'.r-'- 6 7 MR 0 5 20 ❑ JIBDMS APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date V7L 3/7/79 cr4\V Form 10-403 Revised 4/2017 n" 7 M Approved application !s©ld Qf72pI h+e of approval. Submit Form and ahments in Duplicate ,6SC 7�41"el CO. A$- Z,'z-1'llq ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 20, 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 Applications (10403s) to plug for re -drill the KRU 1 R-04 (PTD# 185-178) and to perform workover operations to set the well up for CTD sidetrack in the West Sak formation. The plugging of the existing KRU 1 R-04 completion in the Kuparuk Sands is in accordance with the requirements of 20 AAC 25.112(c)(1). Following plugging, workover operations will prepare 1 R-04 for CTD sidetrack into the West Sak formation. Included in this workover summary is ConocoPhillips plans for achieving cement isolation behind the uncemented T' casing adjacent to the West Sak formation. Later, a Permit to Drill (10-401) application will be submitted for the planned West Sak lateral to be drilled with Nabors CDR3-AC in mid -2019. Attached to the plugging application are the following documents: 10-403 Sundry Application for KRU 1 R-04 Op erations Summa in support p Summary of the 10-403 Sundry Application SP - Current well bore schematic h - Proposed plugging schematic of the Kuparuk sands completion Attached to the workover application are the following documents: 10-403 Sundry Application for KRU 1 R-04 t Operations Summary in support of the 10-403 Sundry Application hUC - Current well bore schematic h - Proposed post-workover schematic Map of well penetrations in the West Sak formation within a quarter -mile of 1 R-04 - Mechanical review of West Sak penetrations within a quarter -mile of 1 R-04 If you have any questions or require additional information, please contact me at 907-263-4172. J. Gar Eller ConocoPQl ips Alaska Wells Advisor KUP INJ 1 R-04 LOIIOCOFaAaskap,. aaska, nil Well Attributes Merz Angle TD AB Well2we PPUU IeM wme INJ' slalu: nnl4 MOlnl<B) Acl etm lnl84 5002921dW00 KUPARUK RIVER UNIT INJ 46.82 5,200.00 8440.0 Comment X IWmI pan, SSSV: NIPPLE notalcn EnG on. KB un. (fl) Pig Ratusa ate CalIWO: 3182008 3669 9/1811985 1 ii. 9LiDIs 12 azm Pm XVIGER; 72.9 LONDOCT.3.461130 HIPPIE WIO sVREACE; J].OA.D]5 SCAB LINER: BOTS 07#7.0 GM UFT; 7.6417 LOCATOR:T®u sEMAss1:7,8935 PaR iB9l.B PACKER:],nil RIPPLEIT7 ii SEALASSY;77s9.7 PER ],MI.S PATMER: LBIs2 PATCH : 7440.0 INIECTION:],B5}B IPERP; 7,Bp2,6]Ri20- 7. .uB.:]9d5.1 LOCATOR: SAME PACKER; B4O2<a NIPPUSS=2 SDs: e.aas.e IPERF:e,116"1340� RSH, a1Bsp (PERF: B,1M.64189.0 PRODUCTOKs,"'OB.3 Mn BellI En.. million 1 ...y EnEOaie Last Tag- SLIM 8.12].0 71512014 Rev Reason: NOTE UPDATE lehetlf 222015 Casing Strings CONDDescnglon 00 (Int ID llq oP In Bl 9H Pere lnMBl 9%I DepthjIYDI... pi -en I.- Grafi Top Tn,Wll CONDUCTOR 16 15062 30.0 115.0 1150 65.00 H40 WELDED .Im me OD (in) ID lin mPnrBl set Dean lm e' set p 4�. wulnn ll... Grace Tap Thread SURFACE 998 0.921 3).0 4297.5 3.92).1 3fi.00 JAS BTC enp mvlq n ME., ID In op M-K'g 8etDeph lnKB)Set 1n.;'11 -en 0... Ge Top Th PRODUCTION 7 6.276 35.0 6426.5 6853.1GinniererJ 26.00 J-55 BTC anp Denenolumn OD9n ID (in) P,) PUKSQ See DepM MIK.)Sat 1... WtlLen 9... Gray Top Tnlatl SCAB LINER 5112 4.950 6,05).0 ).4170.0 6,078.7 15.50 LA0 5-1/2 Hyd 11 Liner Details TIP LK_BlTop(NOIInKBI Topinall'1 Ibm Ms Com wmina110 6.0618 5,12]4 4].39 PgCKER CHP LINER IOP PACKER 4940 ].300.6 6.064.4 43.60 PACKER 3D LINER HANGER PACKER 4.950 Tubing Strings Tuhinp Dnmlglm spina ... lD (in)TIP MKS) tDepin .. sal Depth CND)(-. wlpbTtl Grafi rovCln.- TUBING WO 312 2.992 32.9 7.7040 63013 9.30 LA0 IBTM Completion Details Top XKBI Trip ENDO BI TopincIP1 Ibm Dea Com w1in1110 32.9 32.9 0.09 HANGER FMC GEN III NeING HANGER 3.500 501.0 SOIA 0.30 NIPPLE CAMOO DS NIPPLE 2.875 71691.2 6,291.8 42.12 LOCATOR BAKER LOCATOR 3.000 7,693.5 6,293.6 42.10 SEALASSY BAKER 8040 SEAL ASSEMBLY STABS INTO 3,000 STALKER PACKER I., DtlEdptian Nn9 Ma.. IOlinl TOPP`M) eqh (rt. 9N Oegn (NO11� � Wi(1 1 apcurnesa- STACKER PgLKER 312 2.992 7,592.6 ),791.0 6.366.3 9.30 LAOe EUESrd Completion Details hei ID TIP mKDI TIp INDI1nKa) TophicuP) ItemD-DCom ImI 7,692.6 6,2929 43.11 PBR BAKER 8040 PBR 3,020 )706.0 6.302.8 42.01 PACKER BAKER FHL PACKER 2,930 7763.9 6.334.8 41.72 NIPPLE CAMCO DS NIPPLE NO GO 2,812 7,789.7 6,3653 4.45 SEALABBY BAKER 8040 SEAL ASSEMBLY 3.000 Tub np B`- Shin, w... Tuh-1 ap f Degn (n. set Degn IrvDI1... 1 cmde op nnection TUBING Od9inal 6 2.992 ),790.2 8,06].5 6559.3 Completion Details wau-, IO Tnp(a I TOP(NO)(fil Twinali% IMn Des Cum lin) ),001.5 6.374.1 41.30 PER BAKER PER 3.000 7,815.2 6,384.4 41.39 PACKER BAKER FHL PACKER 3.000 7,891.3 6,4415 41.43 BLAST RINGS (2)BIAS RINGS 2,992 7,985.1 6,512.1 40.98I PLE AVA PORTED NIPPLE 2.750 8.022.6 6,5404 40.1 LOCATOR BAKER LOCATOR SUB 2.406 8,024.4 6,5419 40.70 PACKER BAKER FB -1 PACKER 2M7 8,039.2 6,553.0 40.59 NIPPLE CAMCO'D'NIPPLE 2.250 6046.8 6557-7051505 505 CAMCO SHEAROUT SUB 2,441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tur RVIO Topline, Top(nKBI Hi,E) 1°) Be. Gen Run Dule IDan) 7.840.0 6.403.0 41.40 PA OH HESRCPpaWn,len91h2).45'.uWahnD leaf n#9 01]2000 1.310 GLM )985.1 6512.1 40.96 BLEEVEL SPIISOslmvesn4/12000 .112000 2.310 8,136.0 6,6269 39.87 FISH ROVeNe LBBPKIces in Hole 921/1995 Perforations & Slots Tap incl In. mKe) T�B' 1 BiMK IO Inns Dab snot Dens (shenel 0 Type Cwn 7,892.0 7,9320 6,442.0 6,4n.1 C -1,11R-01 192811985 120 PERF 5- aMpicabM HJ 11; 120 deg ph 8.116.0 8.116.0 8.1M.0 6.611.6 6.625.4 A4, 1RA4 1028/1985 22.0 (PERF 4' HJ II CSD Gun: 90 deg Ph 8,146.0 81188.0 6,63B.6 6,667.0 A -3,1R -M 102&1985 4.01PERF 4' HJ II Cs9 Gun; 90 deD ph Mandrel inserts St a H Top(ND) Vater Top InKB) IBNBI wYe MWN With) Sery Type Iatth Type Po115¢e TRORun lin, (Poll Run Delo Co. ],641.] 6,255.) CAMCO KBG-2- 1 GAS LIFT JR., 9 INT 0.000 0.0 32320118 2 7.853.8 6pt34 MERCA TMPD 1 1 INJ PATO H BK 0.000 I 0.0 1012311995 Notes: General & Safety End wle Mnga1IM 31112-65-0 NOTE: FOund possible hesens @ 7858' WLM B]84T WED (PATCHED 572000) 3162008 NOTE:"'WARhIsh.-Wia lest Pressure on lA IWO# due to Scab Liner PKR 5107380' 19142010 NOTE.View Schematic w/ Alaska Schurnel.9.0 T22UT, NOTE. Scab liner- max dilferentiel pressure 1900 Psi cc law H0 shoe 15'MD Surtace 3BCJL5 oboe it 6280' MD, 382]']VD 1 Scab i5b%L-00, 005]'-]I MD veckem Map& eonun EIiPS Fsentl ]BBY-]BBT MD antl0081116-0101'MD 68'-0180'MD P N MThoe @012]' MD 1R-04 Present Well Condition 1R-04 Proposed P&A DP 0550 MD. ;SND, tlEp inc m pupi atljemnib no parts Igen mandrel or lb8 Wncp a top Poona I"releinerselepon," 2p.h �bullbeatletl tbru nor inro all upon porta 'not circulatecl up IA 'aR on top of releimr in 3 mg tingwtabove TODat bMD KRU 1 R-04: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1 R-04 (PTD 185-178) is a Kuparuk injector equipped with 3'/" tubing and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1 R-04 so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of 1 R-04; a CTD permit to drill (10-401) will be submitted in the near future for 1R-04. The Kuparuk sand formation pressure in 1 R-04 is 2952 psi at 7618' MD, 6238' TVD, as measured on 2/22/08. For the plugging operations the maximum potential surface pressure is 2328 psi assuming a gas gradient of 0.1 psi/ft. The workover operations shall be conducted after the Kuparuk sands have been plugged. The expected pressure in the West Sak formation is 1557 psi at 3385' TVD (i.e. 0.46 psi/ft gradient, which is original formation pressure). The maximum potential West Sak formation pressure assumes an 0.8 psi/ft gradient, which equates to a maximum potential surface pressure of 2369 psi assuming a gas gradient of 0.1 psi/ft. • Recommended BOP Test Pressure during Kuparuk Sand plugging ops = 3000 psi • Recommended BOP Test Pressure during West Sak workover ops = 3000 psi Kuparuk Sand Plugging Operations 1. RU Slickline: a. MIT -IA to 2500 psi b. Drift tubing down to the tubing patch at 7840' KB. Tag fill at -8127' KB. 2. RU E -line: a. Tie in with CCL to tubing tally of 3/6/08. b. Punch holes in the 3'Y2" tubing at -7900' KB, adjacent to the C -sand perfs. c. Pump down the tubing to confirm injection into the perfs d. Punch holes in the 3%" tubing at -7665' KB, above the upper production packer. Perf in the lower half of the full joint immediately above the packer to leave room for the cement retainer in the same joint. e. Bullhead 105 bbl diesel down IA to confirm that the tubing punches are clear to the perfs. Diesel will serve as an IA freeze protect fluid after cementing. i. 105 bbl = 4000' in the 7" x 3%" annulus f. Set 3'/" cement retainer at -7645' KB, below the GLM at 7628' KB but above the tubing punches. 3. RU Service Coil and cementing unit: a. RU to take returns off the IA and the tubing b. RIH with CT. Sting into cement retainer at 7645' KB and establish injection into A and C -sand perfs with seawater. Monitor IA pressure to establish a baseline injection pressure. c. Prepare to pump 15.8 ppg class G cement. Page 1 of 3 2/20/2019 i. This procedure calls for pumping a minimum of 27 bbl of cement to plug the 1 R-04 Kuparuk Sands completion, but we will blend cement on the fly in the event more cement is needed. d. Pump 15.8 ppg cement through the retainer into the A and C -sand perfs. Monitor pressure on IA continuously while pumping cement into the perfs. i. A minimum of 11 bbl of cement is expected just to fill the tubulars, but the intention is to pump sufficient cement to see at least a 300 psi increase in IA pressure. e. Once IA pressure has built to 300+ psi over baseline injection pressure, open up the IA to allow cement to enter the IA. Maintain 1:1 returns on the IA. Circulate a minimum of 11 bbl of 15.8 ppg cement into the IA, which is sufficient to place a 500' plug of cement in the IA. i. 500' of 15.8 ppg cement will add -160 psi hydrostatic pressure over diesel at the 1R-04 inclination of ±450. f. Sting out of the cement retainer and shut-in returns on the IA. Begin taking returns on the tubing. Lay in 5 bbl (minimum) of cement inside the 3.5" tubing, which is sufficient for a 500' plug of cement. g. Continue to POH while switching over to PowerVis to contaminate any leftover cement. Remain at 200' above calculated top of cement in the tubing until PowerVis turns the corner, and then POH while cleaning up any residual cement. 4. Slickline: a. After cement has had minimum of 24 hours to cure, RIH with slickline bailer. Tag top of cement. Pressure test cement plug to 2000-1pspswd IA \yl� separately. Provide Z4 -hour notice for the AOGCC to witness this operation. ` ^M' C 5. E -line: ,J a. RIH with jet cutter for 3Yi', 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the tubing mid -joint at ±4500' KB (i.e. -1000' deeper than the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig Workover Operations to Set Up CTD Sidetrack into the West Sak Formation Note: Well 1 R -04's intended service following CTD sidetrack is as a water -only injection well into the West Sak formation. The CTD KOP is tentatively planned at 3554' KB, 3385' TVD. 5� 1. MIRU workover rig onto 1 R-04. NU BOPE, test. 2. Pull old 3'/" tubing down to the cut at ±4500' KB 3. MIRU a -line a. (optional) Run CBL from —4400' to surface to evaluate cement behind the 7" casing. Tie into the Schlumberger EMIT log run in Jan/Feb 2019. b. Set CIBP for T', 26# casing at ±3700' MD as abase for cement. RD a -line. 4. PU and TIH with ±160' of TCP guns (gun OD and shot density TBD). Tag CIBP to correlate depth for squeeze perfs 3418'-3578' MD (i.e. top of the N mudstone to mid West Sak D -sand). 5. Circulate hole full of ±9.0 ppg brine to overbalance anticipated formation pressure Page 2 of 3 2/20/2019 6. Fire TCP guns. 7. Circulate bottoms up, confirming adequate overbalance to formation pressure. Adjust brine weight as needed. 8. TOH, laying down spent TCP guns. 9. PU and TIH with cup -style perf wash & cementing tool 10. Use cup -style wash tool to wash squeeze perfs 3418'-3578', removing old mud, cuttings, and debris from between the 7" casing and the original 8'/z' borehole. 11. Prepare to pump 15.8 ppg class G cement. Use cup -style placement tool to ensure that cement is circulated through the perfs. a. Calculated annular volume between the T' and the 8'/z" borehole is only 3.7 bbl for the 160' perforated interval, but be prepared to pump -23 bbl of cement (i.e. at least 2x the 8%' hole volume) to adequately squeeze this interval. 12. Pick up out of cement, circulate clean. 13. TOH, lay down cement squeeze assembly. 14. WOC as needed 15. PU drilling BHA with 6%" mill tooth bit. Drill out cement down to bridge plug at 3700' MD. Pressure test squeeze perfs to 14.2 ppg EMW (i.e. 0.74 psi/ft, or 920 psi at surface with 9.0 ppg brine in the hole). 16. MIRU a -line a. Run CBL across the squeeze interval to evaluate quality of the cement squeeze. 17. PU ±330' of 4%", 12.6 ppf, L-80 liner on ZXP liner hanger/packer. Liner will include two outer wedge assemblies spaced out for CTD exits at 3554' MD and 3524' MD. TIH, space out 4'/" liner, putting the outer wedges on depth and the ZXP liner -top packer within 200' MD of the deepest exit point (i.e. no shallower than 3354' MD). 18. Set liner hanger. Cement 4'/z" liner in place with 15.8 ppg Class G cement. Set ZXP packer, and pressure test IA. Circulate clean and TOH. 19. PU with 4'/z" completion and TIH. Sting seals into sealbore and space out. Circulate hole over to corrosion inhibited brine. Land tubing in tubing hanger. MIT -IA. Set BPV. 20. ND BOPE, NU 4-1/16" tree. RDMO. Page 3 of 3 2/20/2019 Roby, David S (DOA) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Thursday, February 28, 2019 3:20 PM To: Roby, David S (DOA) Cc: Loepp, Victoria T (DOA); Boyer, David L (DOA); Wallace, Chris D (DOA) Subject: RE: [EXTERNAL]Sundry application for KRU 1R-04 (PTD 185-176) David, 1) We are working on a 5 well pilot program of converting Kuparuk wells that do not have a significant reservoir impact (redundancy, shut-in, etc.) for a West Salk CTD development program. 2) Once 1R-04 is converted, we will be able to use 1R-03 to accommodate the rate needed to fully support this area. 111-03 is so close to 111-04 (^'800' away) and in the same horizon that we don't feel there will be an issue. When we model the change in injection from 1R-04 to 111-03, our sweep efficiency actually increases due to the new sweep pattern. 3) We still need to maintain injection in the unit, but we feel we'll be able to benefit from changing the sweep pattern of the area. Let me know if you need anything else. Thanks, Kyle Hampton Senior Wells Engineer ) Office. 907-263-4627 ) Cell. 832-421-1506 ) KVIe.Hampton@cop.com From: Roby, David S (DOA) <dave.roby@alaska.gov> Sent: Wednesday, February 27, 2019 3:04 PM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Boyer, David L (DOA) <david.boyer2@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: [EXTERNAL]Sundry application for KRU 1R-04 (PTD 185-176) Kyle, In reviewing the subject sundry application I have a couple of questions for you. 1) The KRU 1R-04 well is in active water injector, putting away 2-4 MBWPD, what is the reason for converting this well from a Kuparuk injector to a West Salk development well? 2) Is there another Kuparuk injector that will makeup for the loss of injection support from this well when it is converted? 3) Is injection support in this portion of the pool no longer needed? Thanks in advance. Regards, David Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: 4J AOGCC v ATTN: Natural Resources Technician II r% Alaska Oil & Gas Conservation Commision . 333 W. 7th Ave, Suite 100 "'titr Anchorage, AK 99501 18 b1 IU' 30388 WELL NAME 1R-26 3M•26 API # 50-029.22193-00 50-029-22431-00 50-029.21404.02 ORDERSERVICE # DWUJ-00077 DWUJ-00078 DWUJ-00079 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL LE DESCRIPTION -EMIT Caliper EMIT DATA TYPE FINAL FIELD FINAL FIELD!4M-Feb-191R-01B FINAL FIELD1R-04 DATELOGGED Prints 21 CD's 50-029-2.1407-00 DWUJ-00080 KUPARUK RIVER WL EMI7 FINAL FIELD1F-07 50-029-20830-00 E9KH-00003 KUPARUK RIVER WL PPROF FINAL FIELD1 1B -15A 50-029-22465-01 EA77-00001 KUPARUK RIVER WL PPROF FINAL FIELD 12 -Feb -19 1 111-17 50.029-22212.00 EA77-00006 KUPARUK RIVER WL IPROF FINAL FIELD 13 -Feb -19 1 7 Print Names Signatu Please return via courier or sign/scan and email a cod Date Schlumberger and CPA]. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,May 20,2015 P.I.Supervisor ( ��/I S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-04 FROM: Bob Noble KUPARUK RIV UNIT 1R-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ��— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IR-04 API Well Number 50-029-21407-00-00 Inspector Name: Bob Noble Permit Number: 185-178-0 Inspection Date: 5/14/2015 Insp Num: mitRCN150516100635 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1R-04 Type Inj W"TVD 6303 Tubing 2175 - 2175 2175, 2175 PTD 1851780 Type Test SPT Test psi 1576 IA 750 3020 - 2880 - 2820 - Interval 4YRTST P/F P " OA 442 675- 665 670 - Notes: SCppllE JUL 1 l 2115 Wednesday,May 20,2015 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~L ~',-~-- J-7~' Well History File Identifier Organization {done) JJ~Two-Sided RESCAN [] Color items: [] Grayscale items: Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No, [] Other, No/Type · [OTAL PAGES: ~ ~J' NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL~R~LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: D Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl PAGES: & ~'~ (at the time of scanning) SCANNED BY.' BEVERLY BREN VINCEN~ARIA LOWELL RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; /SI General Notes or Comments about this file:,,/~:)/~" ~ /O Quality Checked (done) PAGES: ~ ? Rev1 NOTScanned.wl~ STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Q Repair well Q Plug Perforations Ci Stimulate Q Other © Starting head Alter Casing Pull Tubing Perforate New Pool Waiver weld A 9 Q 9 Q Q Time Extension Q Change Approved Program Q Operat. Shutdown Q Perforate Q Re -enter Suspended Well Q 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. _ Development r Exploratory Q •185 -178 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Q Service r ..50- 029 - 21407 -00.00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025635 t 1R -04 9. Field/Pool(s): ie Kuparuk River fiver Field / Kuparuk River Oil Pool,. 10. Present Well Condition Summary: e) E 1 Total Depth measured 8440 feet Plugs (measured),fa Ao n e true vertical 6864 feet Junk (measured) k,, ; &kr Effective Depth measured 0 feet Packer (measured) 7706, 7815, 6 f30i4 true vertical 0 feet (true vertucal) 6303, 6384, 6403, 6542 Casing Length Size MD ND Burst Collapse CONDUCTOR 77 16 115 115 0 0 SURFACE 4260 12 4297 3927 0 0 SCAB LINER 1343 6.07 7400 6079 0 0 PRODUCTION 8392 7 8427 6853 0 0 Perforation depth: Measured depth: 7892'- 7932', 8116'- 8134', 8146'- 8188' ' JUN: 'l I I viola)JU True Vertical Depth: 6442'- 6472', 6612'- 6626', 6635-6667' ' Tubing (size, grade, MD, and ND) 2.875, J -55, 8047 MD, 6559 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER FHL PACKER'. 7706 M ■ and 6303 TVD PACKER - BAKER FHL PACKER @ 7815 MD and 6384 ND PATCH - HES RCP PATCH, LENGTH 27.45', ISOLATING STATION #9 GLM @ 7840 MD and 6403 ND PACKER - BAKER FB -1 PACKER @ 8024 MD and 6542 ND NIPPLE - CAMCO DS NIPPLE @ 501 MD and 501 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory Q Development Q Service J2 Stratigraphic Q X 15. Well Status after work: Oil Q Gas Q VVDSPL Q Daily Report of Well Operations GSTOR Q WIND Q WAG Rij GINJ Q SUSP Q SPLUG Q 16. 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 NA Contact MJ Loveland /Perry -r` in Printed Name MJ Lo I d / . e Well Integrity Project Supervisor Signature Phone: 659 -7043 Date 6 -7 -11 Form 0-40" Rev 10/2010 RBDMS JUN 0 9 201�a 44;7: li Submit Original Only 1R-04 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/15/11 TAG 2.81" NIPPLE @ 7747' RKB WIH 2.83" GAUGERING.SET 2.81" CSA -2 PLUG @ 7747' RKB.BLEED TBG TO NO FLOW,BLEED GAS FROM IA AND OA. 06/04/11 Pre heat and weld thread leak between casing head and casing mandrel hanger (Braden head). 06/06/11 MITOA - (Passed), Post BH Weld. Initial T /I /0= si 0/12/0. OA FL AS. Pressured up OA to 1820 psi with .5 bbls of diesel. Start MITOA, T /I /O= 0/14/1820 15 min T /1 /0= 0/14/1765 30 min T /l /O= 0/14/1749 Final T /I /0= si 0/12/0 * w a ' t ' r a '".� "".:° $:+F, w w „• • 3a .* - � � ma y« °' - -r .. . ' -1 1 „ ' ** Vt. y ,_ -t ,-. -, A. ,..„,...„.. „....,„„ gib.,- � .... � -'� , "` �+ . "' ,�w ,[, .,�' : '.+ti' ' ;yµ •r a `nom- s % ay� � f fa � a u. � ` -. „ `te � ..�, ^� � +►� � ? � � , A ,•�` r�` , �--'- ..,+s}` x,44 Cn' y . r _ L_____,.......___ 7 „.........,,...., ..........c.„____...., i ,., .. , „..,,, ,.......,N............:„......,..............,.... ...................„ „„ rn,,„,..._______ ......„3., .,.... .......c.,,, ,. . _ ...., ... ,....._ .. :,,,_„.411)Itiziacti,, lt, ,, ,.. - . . , .. , - . = - r „,....,,,,,,,,,„.. - , = , ,, .. ,-,4o - . . , - - _ , .. .., "` r`'4- ' " -'`„ . . ©ConocoPhillips Alaska, nc This photo is copyright by ConocoPhillips Alaska, Inc. and cannot be released or - published t written consent withou o�f express ConocoPhillips Alaska .,, of 0 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, May 25, 2011 Jim p ()' 5(�Ill P.I. Supervisor l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R - 04 FROM: Chuck Scheve KUPARUK RIV UNIT 1R - 04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry iP NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1R -04 API Well Number: 50- 029 - 21407 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCS110522083525 Permit Number: 185 -178 -0 Inspection Date: 5/21/2011 Rel Insp Num: Pac e Depth r De th Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1 R -04 Well I T Type Inj. r N 1 TVD F ' IA loo 1 zlso ' r 2125 2110 - , f 1851780' I p.T.D TypeTest sPT Test pst 1575 OA 0 1 40 1 40 40 4YRTST , P Tubing 0 0 1 0 0 Interval P/F g L Notes: ! ANN.F.J1W AY 6201, Wednesday, May 25, 2011 Page 1 of 1 ~ COI'10 ~ ~ ~ coPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`~ Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ SEP 0 2 2009 ~~?~~k~ ~~~ ~ ~~~ ~ons..~o 'ssion AfiG~10F~ ~, ~~~ ~ ~~~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23`d 2009, and the corrosion inhibitor/sealant was pumped August 27th, 28;~ and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~" G~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor _', ~ _:, ~ ~~ V~ ~~'r4`_ ~ <~;~ a~ ~,; `~ .,.~ ~ S ? ... H _ ._ , u. ~.. _. , .- + k.. . . ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/29/09 1 R PAD Weli Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft al 1 R-01 B 50029214040200 . 2001560 13'7" 2.0 26" 8/15/2009 5.1 8/27/2009 1R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8l28f2009 1R-03A 50029214060100 2000270 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" S/15/2009 5.1 8/28/2005 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-O6 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1 R-07 50029213320000 1850720 44' S.00 24" 8/15/2009 4 8/28/2009 1R-08 50029213330000 1850730 8' 1.00 21" 8/15/2009 13.7 8/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009 1 R-10 50029213510000 1850960 32' 5.40 22" 8/15/2009 3.4 8/28/2009 1 R-11 50029213520000 1850970 47' 6.00 38" 8/15/2009 13.9 8l28/2009 1 R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8/15/2009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1 R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009 1R-18 50029221880000 1910870 9'4" 1.20 21" 8/15/2009 3.7 8/28/2009 1 R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" 8/15/2009 11.3 8/29/2009 1 R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 8/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8/15/2009 5.1 8/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23l2009 13.9 8/28/2009 1 R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1 R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1R-35 50029230500000 2012700 18" N/A 18" N/A 5.3 8/29/2009 1 R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009 1VIEM012A1~DLTIVI • To: Jim Regg ~' ,.,/ P.I. Supervisor ~C ~~' ~// FROM: Bob Noble ( j Petroleum Inspector State ®f Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 30, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-04 KUPARUK RIV UNIT IR-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: r~ P.I. Suprv ~ Comm Well Name: KUPARUK RN UNIT 1R-04 Insp Num: mitRCN080730085950 Rel Insp Num: API Well Number 50-029-21407-00-00 Permit Number: 185-i78-0 ~ Inspector Name• Bob Noble Inspection Date: 7/27/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IR-oa Type Inj. ~ TVD 6303 IA soo 1710 16so 1670 ~ p.T ~ 1as17so ~TypeTest ~ SPT , Test psi 1s7s.~s pA so 10o so vo ~ Interval irvITAL P/F P ~ Tubing z77s i z77s z77s z~7s ~ NOteS: Waiver on well stating Scab packer, do not exceed 1500 psi on IA. VVf W~i~Y~l~ ~~'4 v $'{ i`~VV Wednesday, July 30, 2008 Page 1 of 1 • STATE OF ALASKA r a~ a9... -~, ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA~~; - ,; „. 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ gtfser Alter Casing ~ Pull Tubing Q -Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 185-178 / 3. Address: Stratigraphic ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21407-00 7. KB Elevation (tt): 9. Well Name and Number: RKB 82' • 1 R-04 8. Property Designation: 10. Field/Pool(s): ADL 25635 ' Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8440' feet true vertical 6864' ~ feet Plugs (measured) 7815' Effective Depth measured 8138' feet Junk (measured) 8136' true vertical 6627 feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 4215' 9-5/8" 4297 3927 PRODUCTION 8345' 7" 8427' 6853' SCAB LINER 1343' S-1/2" 7400' 6079' ~ ~1~~ ~J ~.i , ~Ut~ a~>v,~: r Perforation depth: Measured depth: , 7892'-7932', 8116'-8134', 8146'-8188' true vertical depth: 6442'-6472', 6612'-6625', 6635'-6667' i'd~~ Tubing (size, grade, and measured depth) 3.5" x 2-7/8", L-80 / J-55, 7992' / 8047 MD. ~'CJ~ ~ ©~~~ Packers & SSSV (type & measured depth) Scab liner, scab liner hanger, 2 Baker'FHL', Baker'FB-1' packers @ 6062', 7380', 7706', 7815', 8024' Camco'DS' nipple C~ 501' 12. Stimulation or cement squeeze summary: ..~- ~°,¢S~ Pa~1~~~-s ~~ ~~ ` Intervals treated (measured) not applicable ~ `~,~,~ p~- J ~ ~ji ~ SC~~p Treatment descriptions including volumes used and final pressure: ~'t~r 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ' Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG Q GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-058 contact Howard Gober @ 263-4220 Printed Name Howard ober Title Wells Group Engineer ~~ , Signature Phone 263-4220 Date ~~Z~~ ~'CL j Pre Sharon Alls Drake 63- 61 ~ ~~/.fit Form 10-404 Rev~s~~i 0 ~ t~0~ ~ ~ ~ ~ _ ~ F~ ~U~ ~ ~ 200 Submit Original O~~ 7 8 t • --....•- C'onocaPhllp~ Alaska, inc. 1 R-o4 __ _ ~- T API: 50029214070D Well T e: INJ An le TS: 41 de 7823 TUBING ~ ~ SSSV Type: NIPPLE Orig 9/18/1985 Angle @ TD: 38 deg @8440 (a7ao1, OD:3 500 Com letion: . , ID:2ss2) ~, Annular Fluid: Last W/O: 3/8/2008 Rev Reason: WORKOVER >, i Reference Lo Ref Lo Date: Last U ate: 3/28/2008 ~ Last Ta : 8138' SLM TD: 8440 ftK6 ` Last Tag Date: 2/15/2008 Max Hole Angle: 49 deg Cgs 5200 Casin Strin -ALL STRINGS _ -- _ - -- Descri ion Size 7o Bottom TVD VJt Grade Thread CONDUCTOR 16.000 0 115 115 65.00 H-40 ~_;, SURF CASING 9.625 0 4297 3927 36.00 J-55 PROD CASING 7.000 0 8427 6853 26.00 J-55 SCAB LINER 5.500 6057 7400 6079 15.50 DRILL5 r I ubing String -TUBING T PBR (7693-7694, OD:5.010) SEAL (77so-7so1, OD:4.500) PLUG (7815-7816, OD:3.000) TUBING (7801-7992, OD:3.500, ID:2.992) PATCH (7840.7858, OD:2.750) Pert (7892-7932) SLEEVE-C (7985-7986, OD:2.750) PKR (8024-8025, OD:6.156) NIP (8039-8040, OD:2.875) Perf (8116-8134) 2.875 __ _f _ 7992 I 8047 I 6559. I 6:50 I J-55 I EUE 8RD ~ Perforatirans Summary Interval TVD Zone Status Ft SPF Date T Comment 7892 - 7932 6442 -6472 C-1 40 12 10/28/1985 IPERF 5" Expendable HJ I I; 120 de h 8116 - 8134 6612 - 6625 A-4 18 12 10/28/1985 IPERF 4" HJ II Cs Gun• 90 d h 8146 - 8188 6635 - 6667 A-3 42 4 10128/1985 IPERF 4" HJ II Csg Gun: 90 deg ph --- .Gas Lift M_andrelsNalves _ _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 7642 6256 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 3/23/2008 2 78.54 6414 Mena Qiher lu s e ui .:, etc TMPD MY/PATC 1 A BK Q000_ _ _ 0 ' 10/23/199 .J -COMPLETION De h TVD T e Descri tion ID 42 42 HANGER FMC GEN III TUBING HANGER 2.992 501 501 NIP CAMCO'DS' NIPPLE 2.875 6062 5127 PACKER SCAB LINER CHP LINER TOP PACKER 4.940 6073 5135 NIP SCAB LINER CROSSOVER NIPPLE NEW VAM X HYD 511 4.850 7790 6366 SEAL BAKER SEAL ASSEMBLY 80 7801' 7801 6374 PBR Baker 7815 6384 PLUG WRP set 2!19/2008 7815 6384 PKR Baker'FHL' 7840 6403 PATCH HES RCP atch len th 27.45' 7985 6512 SLEEVE-C BPI ISO sleeve set 4/1/2000 7985 6512 NIP Set 2.75" BPI SLV 4/1/00. ~- 2.930 2.812 w/8' PUP, INSERTED INTO OLD PBR @ 3.000 station #9 GLM - ~ 8048 16560 I TTL I I 2.441 I _ --- - Fish - FISH Depth Description Comment I 8136 PO Valve ~ Left Pieces in Hole E ----.. , _ _. _ (General Notes _ _ __ _ _ __ - - ---- _ _ _ Date Note 3/1/2000 NOTE: Found ossible leaks 7858' WLM & 7842' WLM 4/2/2000 NOTE: Drifted tubin w/23.5" X 2.79 dumm atch to 7910' WLM. 4/10/2000 NOTE: Drifted tubin w/27' x 2.473" dumm atch to 7900' 3/6/2008 NOTE: ***WARNING***Max test ressure on IA 1900# due to Scab Liner PKR 7380' • KRU 1 R-04 Perf (6146-8188) ConoCOPhillips Time Log & Summary Wetlv7ewr Web ReyoriPng Report Well Name: 1 R-04 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/28/2008 2:30:00 AM Rig Release: 3/7/2008 3:00:00 PM Time Logs __ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 2/28/2008 24 hrSummarv Move from 1 R-36 to 1 R-04. Accept Rig @ 2:30 am 2/28/08. 01:00 02:30 1.50 0 0 MIRU RPCOM RURD P MIRU on 1R-4. 02:30 03:30 1.00 0 0 MIRU WELCTI KLWL P PJSM, Lubricate out BPV; Record pressures tbg 150, tbg X 7 = 500 psi. Acre t Ri 02:30 2/28/08. 03:30 04:30 1.00 0 0 MIRU WELCTL OTHR P RU kill lines for well kill. 04:30 12:00 7.50 0 0 MIRU RPCOM PULD P Load pipe shed with 3-1/2 DP workstring, while wait on delivery tiger tank. Test kill lines, take on brine to its. 12:00 15:00 3.00 0 0 COMPZ WELCTL KLWL P Note 350 psi on OA. Attempt bleed dn. Press drop to 300 psi while taking 30 bbls diesel to tiger tank. Shut in, press stable at 300 psi.Total bleed time 30 min on 1/4" choke. PJSM, commence kill well. 150 psi on tbg, 500 psi on 3-1/2 X 7 ann. Pump do tbg, return to annulus. Total 300 bbl 4 bpm at ICP 200, FCP 650 si. 15:00 16:00 1.00 0 0 COMPZ WELCTL OTHR P Slowdown and rig down all hose and kill manifold. 16:00 17:00 1.00 0 0 COMPZ WELCTI OWFF P Attempt to het BPV. Note aas buildu .Bleed tubingand IA, allow ~~~ as mi ration. 17:00 18:00 1.00 0 0 COMPZ WELCTI OWFF P Monitor well for flow. Well static. No ain /loss Burin kill. 18:00 19:30 1.50 0 0 COMPZ WELCTL OTHR P Rigging up to set BPV. Set BPV. 19:30 22:00 2.50 0 0 COMPZ RPCOM NUND P PJSM, ND tree and adaptor. Set blankin lu . 22:00 00:00 2.00 0 0 COMPZ RPCOM NUND P PJSM, NU BOPE. 2/29/2008 Circuited 9.6 ppg brine. ND tree and NU BOPE. 00:00 04:00 4.00 0 0 COMPZ WELCTI NUND P NU BOPE 04:00 10:00 6.00 0 0 COMPZ WELCTL BOPE P PJSM, test BOPE, all related components 250 / 2500 psi. Perform time /volume /press test on accumulator system. All tests successful. Witness by Mr Bob Noble AOGCC. 10:00 11:00 1.00 0 0 COMPZ WELCTL OTHR P RU /pull BPV. Flow check. Well static. l~~ge 1 esf 6 _ Time Logs _ _ _ _ _ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment _ 11:00 12:30 1.50 0 0 COMPZ RPCOM PULD P PJSM, RU /null tba to floor. Multiple attempts staging up to 155 K (35K block weight). Cont sharp oscillations with brake. Seal assv freed. Pull to floor. Flow check. 12:30 15:30 3.00 0 0 COMPZ RPCOM CIRC P Reverse circulate top PBR, scale and sludge to shaker with btms up. Cont circ shaker clean. No gain / loss. 15:30 16:30 1.00 0 0 COMPZ RPCOM PULD P Remove tbg hgr /control line. MU to s ooler. 16:30 00:00 7.50 0 0 COMPZ RPCOM PULD P PJSM, POOH lavin do 3-1/2 tbg. Jts very tight, necessitating use of rig tongs to break connections. Recovered all 32 control line bands. 3/01 /2008 Tested BOPE. POOH with 3-1/2" completion. 00:00 06:00 6.00 2,614 0 COMPZ RPCOM PULD P POOH laying down 3-1/2 completion. 06:00 06:30 0.50 0 0 COMPZ RPCOM PULD P R/U pull wear ring. 06:30 07:00 0.50 0 0 COMPZ RPCOM RURD P RU floor for 3-1/2 DP. 07:00 10:30 3.50 0 379 COMPZ RPCOM PULD P PJSM, MU BHA #1, cleanout assy, pkr /string mills, flow check, RIH same. 10:30 16:30 6.00 379 7,784 COMPZ RPCOM TRIP P Follow BHA with 3-1/2 DP to tag at 7784 ft. 16:30 19:00 2.50 7,784 7,797 COMPZ RPCOM CIRC P Circ while rotate string 1!4 turn to drop in PBR, 56PM at 920 psi. Circ do to to at 7797 ft. Cont rev circ 5 bpm at 960 psi. Sand returns at btms up, cleaning up after addtnl 100 bbls. Cont circ shaker clean. 19:00 23:30 4.50 7,797 0 COMPZ RPCOM TRIP P PJSM, flow check, POOH for E-line. La down cleanout BHA. 23:30 00:00 0.50 0 0 COMPZ RPCOM OTHR P Drain stack, cleantools and floor, re are to RU a-line. 3/02/2008 RIH with cleanout BHA on 3-1/2" worksring down to the PBR. Re-circ well until clean returns. POOH and re are for E-Line. 00:00 01:00 1.00 0 0 COMPZ EVALWE PULD P PU Schlumberger UCI logging tools. 01:00 03:00 2.00 0 0 COMPZ EVALWE ELOG P RIH to 7750' ELM. POOH to orientate tool. RIH to 7750' ELM. Test OA to 1800 psi /15 min while logging. 5 bbls to test. Bleed 5 bbls. ICP "0" psi. Press at 90 psi after bleed. Recover diesel turning to gas at end of bleed. Shut in, WO orders as how to roceed on OA. 03:00 14:00 11.00 0 0 COMPZ EVALWE ELOG P Logging up from 7750' ELM wit ,~I l0 425 fdh . Prelim_observation shows hole in 7" csg at 6610 ft WLM. Cont log UCI to surface. Download data. Transmit to CPAI Anch. 14:00 15:00 1.00 0 0 COMPZ EVALWE RURD P RD Eline, clear floor, release unit. Page 2 caf fi ~, Time Logs Date From To Dur 5 De th E. De th Ph Code Subcod T Comment 15:00 18:00 3.00 0 0 COMPZ RPCOM PULD P Load shed with 3-1/2 comp tbg. Prep / stra same. 18:00 19:30 1.50 0 0 COMPZ RPCOM PULD P PU and assemble stack packer BHA (seal assembly, DS nipple w/RHC plug, FHL packer and PBR, test acker 19:30 00:00 4.50 0 7,490 COMPZ RPCOM TRIP P RIH with FHL packer and test acker. 3/03/2008 Ran UCI log in 7" casing. PU and assemble stack packer BHA, RIH. 00:00 01:00 1.00 7,490 7,490 COMPZ RIGMNT SVRG P PJSM, slip and cut drilling line. 01:00 02:00 1.00 7,490 7,490 COMPZ RIGMNT SVRG P Service top drive and drawworks. 02:00 03:00 1.00 7,490 7,801 COMPZ RPCOM TRIP P Continue to RIH with FHL packer and test acker. 03:00 04:00 1.00 7,801 7,680 COMPZ RPCOM RCST P No- o seal assembly on top of old BR. Up weight 125K# down weight 95K#. Set FHL packer with 1 ft space out. Pull out of new PBR with 1330 psi on the tubing and 15K# over ull. _ 04:00 08:00 4.00 7,680 6,430 COMPZ RPCOM DHEQ P POOH and set test acker and test below acker to 2500 psi. Pulled 1 stand after each good test. Test passed @ 6881', 6782' and 6686'. Test failed below acker and u th IA 6591'. I asse~,~ 6430,, ** Casing between 6686' to 6430' did not test.** 08:00 11:30 3.50 6,430 365 COMPZ RPCOM TRIP P POOH with test packer and 3-1/2" work strin . 11:30 12:00 0.50 356 0 COMPZ RPCOM PULD P LD Test Pkr, flow check. 12:00 14:30 2.50 0 0 COMPZ RPCOM PULD P PJSM, Load 3-1/2 comp equip to i e shed. 14:30 16:30 2.00 0 0 COMPZ RPCOM OTHR P PJSM, rack /tally 3-1/2 comp tbg. 16:30 20:00 3.50 0 1,342 COMPZ CASING RUNL P PJSM, MU lower 5-1/2 liner ar / PKR /mule shoe assy. RIH same. Flow check, follow with 31 jts 5-1/2, 15.50 #, L80 cs . 20:00 00:00 4.00 1,342 5,311 COMPZ CASING RUNL P RIH with 5-1/2" liner asse 3-1/2" work strin . 3/04/2008 RU and RIH with 5-1/2" scab liner to cover leaks in the 7" casing between 6686' and 6430' to 7,400'. Unable to set 3D liner hanger packer. POOH with 5-1/2" scab liner. Inspect "3D" Liner hanger packer, packer to have failed and Re lace. Rerun 5-1/2" scab liner to 4,047'. 00:00 02:45 2.75 5,311 7,400 COMPZ CASING RUNL P RIH with 1323' of 5-1/2' assembl to 7400" 02:45 04:30 1.75 7,400 7,400 COMPZ CASING RPTH P Attempted to set 3D hanger at 7400', unable to set. Tried setting while rotating, jarring, pumping, RIH at higher speed and trying to set across a 60' interval to catch acollar - co, u, l~ not et 3D han er to take wei ht. €~age 3 of 6 ~~ Time Logs Date From To Dur S. De th E. De th Ph e Code Subcode T Comment 04:30 10:00 5.50 7,400 0 COMPZ CASING PUTS P POOH with 3-1/2" work strin_p and , 5-1/2" scab liner assembly. After inspection, found that the control in 'J' slot tamed underneath the cage not allowing slips to ride up and set. (Note: pin on 'J' slot 3/16" shorter than second 3D packer assembly sent out 10:00 17:00 7.00 0 0 COMPZ CASING WOEQ T Ordered out new "3D" Liner Hanger/ Packer from Baker. Fifteen ft xover pup galded when backed out. Waited on xover u from machine sho , 17:00 19:30 2.50 0 1,337 COMPZ CASING PUTB P PU and Rih w/ 5 1/2 Scab liner ass . 19:30 00:00 4.50 1,337 4,047 COMPZ CASING RUNL P Rih w/Scab liner on DP From 1,337' to 4,047' 3/05/2008 Continue to Rih w/ 5.5" Scab liner to 7,400'. Set 3D liner hanger packer and test. Release from and Set "CPH" Liner to acker and test. Pooh la in down DP. Be in to Rih w/ 3 1/2 Com letion to 4,429.0' 00:00 04:30 4.50 4,047 7,403 COMPZ CASING RUNL P Continue to Rih w/ 5.5 Scab liner ass f/ 4,047 to 7,400' 04:30 05:30 1.00 COMPZ CASING GIRC P Pump 20 bbl 9.6 ppg brine w/ 1% by volume CRW 132 followed by 72 bbls 9.6 brine 05:30 06:00 0.50 7,403 COMPZ CASING OTHR P Set 3D Liner hanger @ 7,403.0' ?. Attempt to pressure test, was circ around packer. Pressure up on IA to 500 psi and felt cone slide up. Pressure up to 500 psi on DP and increase to 1,000 psi. Held for 15 minutes w/ no pressure loss. Release from i r acker and set 6 071..0' 06:00 07:00 1.00 6,071 5,921 COMPZ CASING DHEQ P Pooh w/ to 5,921.0' and Close annular. P essure test annulus ~.._,.,- _,a,.ti._.._.. 1,900 psi for 15 minutes. Held w! no ._..N..._.._ ......__. ~._`.._ ressure loss. 07:00 15:30 8.50 5,921 0 COMPZ RPCOM TRIP P Pooh laying down DP f/ 5,921.0' to 0'. LD runni tool. 15:30 16:00 0.50 0 COMPZ RPCOM PULD P Pull wear ring 16:00 00:00 8.00 0 4,429 COMPZ RPCOM RURD P R/U to run 31/2" tom letion to ~~~~~~~~~~~ 4 429.0' 3/06/2008 Continue to Rih w/ 3 1/2 Completion f/ 4,429.0' to 7,196.0'. P/U and MU Baker 7" Retrievamatic storm pkr and Rih to 50' and set. Release off and pressure test to 500 psi for 15 minutes. Blow down stack and lines. ND BOPE. Test flange break to 250/2500 psi. Pull test plug and retrieve storm pkr. Continue to Rih w/ completion to 7,705'. Space out. Circ corrosion inhibited brine. Land hanger and RILDS. Pressure test tbg to 2,500 psi and bleed to 1.,750 psi, hold and pressure test IA to 1,900 psi for 30 minutes and shear out SOV. Monitor well 00:00 02:30 2.50 4,429 7,196 COMPZ RPCOM PULD P Continue to Rih from 4,429.0' to 7,196.0' PU 31 /2 9.3# L-80 I BT-M tb F'ar~s 4 of B • __ Time Logs Date From To Dur S. De th E De th Phase Code Subcode T Comment 02:30 05:00 2.50 7,196 7,246 COMPZ RPCOM HOSO P PU and MU Baker 7" Retrievamatic pkr. Rih to 50' and set. Land w/ 35k of tbg wt below. Release off and pooh w/ setting tool. Close blind rams and pressure test to 500 psi fob 15 minutes -good solid test. Bleed off and blow down stack and lines. Open OA 120 psi and bleed off to ti er tank. 05:00 10:00 5.00 COMPZ RPCOM NUND P ND BOPE and tbg spool. 7" casing rew a roximately 1-1/2" to 2". RU Wach's Cut Off Tool. Cut 1-1/2" off 7 26# casm 10:00 12:00 2.00 COMPZ RPCOM OTHR P Install new 7" casing packoff. NU new tubing head. PT casing packoff to 250/3000 si. 12:00 16:00 4.00 COMPZ WELCTI ROPE P NU BOP. Set test lu . PT BOP to 250/2500 si. 16:00 16:30 0.50 7,246 7,196 COMPZ RPCOM PACK P Pull test plug. PU retrieving tool. Retrieved Baker 7" Retrievamatic acker and broke down. 16:30 17:30 1.00 7,196 7,675 COMPZ RPCOM PULD P PU and MU 2.875"'DS' Nipple and continued RIH with completion f/ 7,196' to 7,675' 17:30 18:00 0.50 7,675 7,705 COMPZ RPCOM CIRC P M/U Circ equipment and circ @ .5 bpm @ 60 psi and tag no go @ 7,693' (Top of PBR) w/ bottom of seals 7,705' ad'. RKB 18:00 19:30 1.50 COMPZ RPCOM HOSO P PJSM, Space out, MU circ e ui ment, MU Han er 19:30 21:30 2.00 COMPZ RPCOM CIRC P Pump 10 bbls 8.5 ppg brine followed by 240 bbls 8.5 ppg brine w/ 1 % by volume CRW-132 Corrsion inhibitor, followed by 10 bbls 8.5 ppg brine. ICP 240 si FCP 250 si 21:30 22:00 0.50 COMPZ RPCOM OTHR P Circ @ .5 bpm @ 60 psi seen seals engage w/ pressure increase to 120 psi. Bleed off pressure. Slide seals in 10' and Land hanger. 83k up wt -. ~_. 80k do wt RILDS 22:00 00:00 2.00 COMPZ RPCOM DHEQ P RU Circ lines and pressure test lines to 2,500 psi. Pressure up tbg to 2,500 psi for 15 minutes and chart. - good test. bleed down to 1,750 psi. Pressure up on IA to 1,900 psi for 30 minutes and chart. -good test. Bleed pressure off tbg and shear out SOV 7,642'. Monitor well. 3/07/2008 Pull landing jt and set BPV. ND BOPE and NU Tree. Test tree and packoff to 250/5000 psi. Good test. Release Ri 15:00 hrs 3-7-08. 00:00 00:30 0.50 COMPZ RPCOM OTHR P Pull landing jt. Set BPV. 00:30 04:30 4.00 COMPZ RPCOM NUND P ND BOPE I~ag~ 5 of & Time Logs Date From To Dur S De th E. De th Ph se Code Subcode T Comment 04:30 07:30 3.00 COMPZ RPCOM NUND P NU 3-1/8" 5M tree with proper orientation (consulted with DSO). Pull BPV, set test plug. Pressure test tree to 250/5000 psi. Test packoff to 250/5000 psi. Pull test lu . 07:30 11:00 3.50 COMPZ RPCOM FRZP P RU LRS for freeze protect. Pumped 86 bbls diesel down annulus taking returns to kill tank. Hook up jumper hose from the IA to tubing and allowed diesel toe ualize. 11:00 12:00 1.00 COMPZ MOVE RURD P Set BPV. RDMO. Clean cellar and area of pad used. Released rig @ 15:00 3-07-2008. Page S of S 1 R-04 Well Events Summary DATE SUMMARY 3/22/08 PULL BALL & ROD @ 7720' SLM, (7752' RKB) JOB ONGOING. 3/23/08 REPLACE SOV W/ DV @ 7628' RKB. MITIA TO 1900 psi PASS. PULL 2.81" RHC PLUG BODY @ 7752' RKB. BAIL FILL FROM TOP OF 2.27" CATCHER @ 7780' SLM. JOB ONGOING. 3/24/08 BAIL FILL OFF 2.27" CATCHER TO 7780' SLM, IN PROGRESS. 3/25/08 BAILED FILL ON 2.27" CATCHER TO 7782' SLM. GUAGED TBG TO 2.79". IN PROGRESS. 3/26/08 ATTEMPTED BAIL DEBRIS @ 7782' SLM & PULL CATCHER. NO SUCCESS. IN PROGRESS. 3/27/08 ATTEMPTED BAIL HARD-PACKED INJECTION RESIDUE @ 7782' SLM. MINIMAL RECOVERY. JOB SUSPENDED. 5/11/08 MAKE BAILER RUNS TO RECOVER 1/2 GALLON HARD PACKED SANDS FROM 7786' SLM.IN PROGRESS. 5/12/08 ATTEMPT TO BAIL HARD PACKED SAND TO CATCHER SUB ON WRP.VERY LITTLE HARD SAND RECOVERED. IN PROGRESS. 5/13/08 BAILED HARD SANDS FROM 7782' SLM TO 7794' SLM.PULLED 2.27" CATCHER FROM 7794' SLM.IN PROGRESS 5/14/08 BAILED OFF WRP @ 7801' SLM.ATTEMPT TO EQUILIZE.IN PROGRESS 5/15/08 BAILED SANDS LEFT 3 1/2" WRP PULLING TOOL @ 7790' SLM 5/16/08 PULLED 3 1/2" WRP FROM 7790' SLM.JOB COMPLETE ~`EO~...i ~..r.~' Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, May 20, 2008 12:55 PM ~ ~ ~1~~,~®~ To: 'NSK Problem Well Supv' Subject: RE: KRU 1 R-04 (PTD# 185-178) Return To Injection Can't remember if we responded to your request about placing KRU 1 R-04 back on injection. Your request is approved. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 ~~11NE® MAY ~ ~. 200 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Sunday, May 04, 2008 12:50 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPFi Prod Engr; CPF1 DS Lead Techs; Fleckenstein, Robert J (DOA) Subject: KRU iR-04 (PTD# 185-178) Return To Injection «1 R-04 Well Schematic.pdf» «MIT KRU 1 R-04 03-23-08.x1s» Jim/Tom, Kuparuk WAG Injector 1 R-04 (PTD# 185-178) has been shut in since May 12, 2007 due to a failed MITIA. A rig workover to eliminate the production casing leak by installing a scab liner was completed on 03/07/08. The well subsequently passed an MITIA. A copy of the update we schematic and the results of the test are attached. CPAI requests permission to return the 1 R-04 to injection service and Normal status. We will schedule aState- ~ witnessed MITIA once the well conditions are stabilized. If the future well performance indicates lack of integrity, appropriate action will be taken. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhitlips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 5/20/2008 STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. ~j~~~~ FIELD /UNIT /PAD: Kuparuk /KRU / 1 R-04 ~ ~~ DATE: 03!23/08 OPERATOR REP: Hanks - HES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 1R-04 Type Inj. W TVD 6,306' Tubing 1,100 1,150 1,150 1,150 Interval O P.T.D. 1851780 Type test P Test psi 1577 Casing 800 1,900 1,900 1,900 P/F P Notes: Post workover non-witnessed MITIA OA 50 50 50 50 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 1R-04 03-23-08.x1s ~'' KRU 1 R-04 °~~ Cvncr~~phllips A~lats~~-, inc. 1 R-04- _ AF'I: 5UULyl14UluU Well T e: ~ INJ An le TS: 41 de 7823 TuBIN~ ---- SSSV Type: NIPPLE Orig 9118!1985 Angle @ TD: 38 deg @ 8440 (o-7ao1, Com letion: ID:2.992) ~~' ~ Annular Fluid: Last W/O: 3/8/2008 Rev Reason: WORKOVER Reference Lo Ref Lo Date: Last U date: 3/28/2008 Last Ta : 8138' SLM TD: 8440 ftK6 Last Tag„Date: 2/15/2008 Max Hole An le: 49 de 5200 ,Casin String -.ALL STRINGS Descrl lion Size "ro Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 65.00 H-40 :~, SURF CASING 9.625 0 4297 3927 36.00 J-55 PROD CASING 7.000 0 8427 6853 26.00 J-55 SCAB LINER 5.500 6057 7400 6079 15.50 .DRILLS Tubing Stri~~ TUBING ' Size To Bottom TVD Wt Grade Thread 3.500 0 7801 6374 9.30 L-80 IBTM 3.500 7801 7992 6517 9.30 J-55 EUE 8RD 2-875_ 7992 8047 6F59 6.50 J-55 FIIF RRD Perforations Summary PBR- 7ss3-76sa Interval TVD Zone Status Ft SPF Date T e Comment , ( OD:5.010) 7892 - 7932 6442 - 6472 C-1 40 12 10/28/1985 IPERF 5" Expendable HJ II; 120 ----- de h 8116 - 8134 6612 - 6625 A-4 18 12 10/28/1985 IPERF 4" HJ 11 Cs Gun; 90 de h 8146_ 8188. 6635 - 6667 A-"t - - __ 42 4 1012R/1985 IPERF 4" HJ II Cso Gun: 90 deq ph ,. Gas Lift Mandrels/Valves -- - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Fort TRO Date Run Viv Cmnt ~~ 1 7642 6256 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 3!23/2008 2 7854 6414 Merla TMPD MY/PATC i0 BK 0.000 0 10/23/199 - -- - --- Other plugs equip., etc.) -COMPLETION ______ De th TVD T e Descrl lion ID 42 42 HANGER FMC GEN III TUBING HANGER 2.992 seA~ ------ - 501 501 NIP CAMCO'DS' NIPPLE 2.875 (77so-7so1, 500) OD:4 6062 5127 PACKER SCAB LINER CHP LINER TOP PACKER 4.940 . 6073 5135 NIP SCAB LINER CROSSOVER NIPPLE NEW VAM X HYD 511 4.850 7380 6064 PACKER SCAB LINER HANGER PACKER 4.950 PLUG ----- 7693 6293 PBR BAKER 80-40 PBR 3.020 (7a15-7a16, OD:3 000) 7694 6294 SEAL BAKER 80-40 SEAL ASSEMBLY 3.000 . 7706 6303 PACKER BAKER'FHL'PACKER 2.930 TUBING ---------- 7801-7992 7749 6335 NIP CAMCO 'DS' NIPPLE 2.812 ( , oD:3.5o0, 7790 6366 SEAL BAKER SEAL ASSEMBLY 80-40 w/8' PUP, INSERTED INTO OLD PBR @ 3.000 iD:2.ss2) 7801' PATCH ---- 7801 6374 PBR Baker 3.000 (7aao-7s5s, 7815 6384 PLUG WRP set 2/19/2008 0.000 oD:z.75o) 7815 6384 PKR Baker'FHL' 3.000 7840 6403 PATCH HES RCP atch, len th 27.45', isolatin station #9 GLM -set 5/7/2000 1.310 7985 6512 SLEEVE-C BPI ISO sleeve set 4/1/2000 2.310 7985 6512 NIP Set 2.75" BPI SLV 4/1/00. 2.750 _._ 8024 6542 PKR Baker'FB-1' 4.000 Pert -- - 8039 6553 NIP Camco'D' Ni le NO GO. 2.250 paszas3z) -- 8047 6559 SOS Camco 2.441 ---- -- -- -- ------ 8048 6560 TTL 2.441 -- __ .. - _ _ _ Flsh -FISH _ De th Descrl lion :omment - - 8136 PO Valve Left Pier. ~ ~~~ Hc~l!~ _ __ _ s~eeve-c ---- ~ General Ngtes psa5-79as, ~~~_ Date Note oD:2.750) ) 3/1/2000 NOTE: Found ossible leaks 7858' WLM & 7842' WLM 4/2/2000 NOTE: Drifted tubin w/23.5" X 2.79 dumm atch to 7910' WLM. PKR --- -~---- (8024-8025 4/10/2000 NOTE: Drifted tubin w/2T x 2.473" dumm atch to 7900' , OD:6.156) 3/6/2008 NOTE: ***WARNING***Max test ressure on IA 1900# due to Scab Liner PKR 7380' ~ NIP ------ ','~ (8039-8040, ', OD:2.875) __ _ I I Perf -~-- - ~ b - ~ I --. (8116-8134) __, - Perf ~ (8146-8188) ---- ---- . Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 1` ( - Log Description ' ~'~~ ~~~~ 03/12/08 NO. 4624 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1A-12 11964583 LDL U`~. (°° @~- 02/28/08 1 1 E-1128 SAND LATERAL 11978443 _ MEM INJECTION PROFILE 03/03/08 1 1 R-04 11964585 USIT ~ • - 03/02/08 1 2L-330 11837544 OH EDIT (SONIC SCANNER) ~}- ~ 11/27/07 1 1 31-01 11994626 LDL 03/06/08 1 2N-327 11994628 PRODUCTION PROFILE ~~--. 03/08/08 1 1Y-28 11994629 PRODUCTION PROFILE 03/10/08 1 3S-OSC 40016310 OH MWD EDIT VISION SERVICE '~ cj 01/17!08 1 1 ~ J Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ € ~ ~€ ~~ ~ ~~~- CO1~TS~RQ~ ATIO CO ~ Ip1S~T Howard Gober Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 R-04 Sundry Number: 308-058 ~~~~ ~ FEB ~ ~t 20~f Dear Mr. Gober: `$~~ leg Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair r~ DATED this ~ day of February, 2008 • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Encl. • • ~ o CanocoPh~llips Alaska P.O: BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 18, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: FEB 2 0 ~4:~; ~8ska Oil & Ga;a o,~~ _ ~,f,,.:~. ,~sz ~' Anchorago ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 R-04 (PTD# 185-178). Injecting well 1 R-04 has been shut-in since May of 2007 when an MIT of the inner annulus failed. A TecWel leak detect log run on 8/5/07 determined that the leak was at 6618'. The leak rate was approximately 0.7 bpm at 2350 psi. The purpose of the proposed workover is to pull the existing 3-1/2" J-55 tubing string, repair the casing leak with a casing patch or a scab liner, and run a new 3-1/2" L-80 tubing string. Attached is a proposed schematic along with a general workover procedure: If you have any questions or require any further information, please contact me at 263-4220 Sincerely, ~' owar B. Go er Wells Engineer CPAI Drilling and Wells DUPLICATE • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION R~C~~ ~/ ~D Fie 2 o zoos APPLICATION FOR SUNDRY APPROVALAIaska Oil & Gas Cons. Commission 20 AAC 25.2ao Anchorage 1. Type of Request:- Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^/ Repair well 0 Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^~ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 185-1.78 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-21407-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ^~ 1 R-04 9. Property Designation: 10. KB Elevation (ft): 11.. Field/Pool(s): ADL 25635 RKB 82' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8440' 6864' 8164' 8136' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' SURF CASING 4215' 9-5/8" 4297' 3927' PROD CASING 8345' 7" 8427 6853' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7892'-7932', 8116'-8134', 8146'-8188' 6442'-6472', 6612'-6625', 6635'-6667' 3.5" x 2-7/8" J-55 7992' x 8047' Packers and SSSV Type: Packers and SSSV MD (ft) pkr-- BAKER'FHL' ; BAKER'FB-1' pkr= 7815' ; 8024' Baker'FVL' SSSV= 1802' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ .Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat March 1, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG 0 GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. thereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name HOWard. Ober Title: Wells Group Engineer Signature Phone 265-6958 Date Z ~j ~ Commission Use Only umber: Sund Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ^ BOP Test Mechanical Integrity Test ~ Location Clearance ^ Other: ~_~~~ r ~~ ~~ ~ - . ~ 7 ~~_ ~'~.~ !d ~ 20~U Subsequent Form Required: ~rh~ V ~' ~ ~~ APPROVED BY Approved by: OMMISSIONER THE COMMISSION -7 Date: ~ L--2-- Form 10-403 Revis~d 0~200~ 1 ~ t~ ~ E ~ ~ ~ ~ Submit in Duplicate • Sundry RWO Procedure . 1R-04 Kuparuk Injector Repair Casing Leak PTD# 185-178 Procedure Outline 1. Obtain SBHP @ 8152' MD. 2. Set WRP @ 7820' MD. 3. Obtain SBHP for casing leak. 4. 'Set BPV. 5. MIRU Nordic #3. 6. Kill well. ND tree, NU and test BOP. NU 11", 5M BOPE for 3.5" tubing. Pressure test BOPE including annular to 250/2500 psi. Maximum anticipated surface pressure is 700 psi based on six month SI wellhead pressures obtained 2/14/08 as follows: 7/I/O 450/650/380 psi. 7. Pull 3-1/2" tubing and lay it down. Run scraper and string mill on 3-1/2" workstring. Run stinger on bottom of scraper and cleanout 80-40 PBR while on bottom. Reverse circulate hole clean. 8. Run seal assembly, FHL packer, and PBR. Run test packer above PBR. Circulate corrosion inhibited brine. Sting into existing PBR & set FHL packer. 9. Shear new PBR. Pull up hole and isolate casing leak with test packer. POOH w/ test packer. 10. If warranted by PT results, RU E-Line. Run UCI log in 7" casing from PBR to surface. 11. If leak can be isolated with 40' patch, continue with next step. If not, go to Step #15. 12. Run 40' Baker ExPatch and seal off casing hole. PT csg 2500 psi. 13. ND BOP and tubing head. Change out 7" casing packoffs. NU tubing head & BOP. Pressure test packoff and body test BOP. 14. Lay down 3.5" workstring. Go to Step #18. 15. If leak is too long for ExPatch, run 5-1/2" flush joint scab liner. PT csg 2500 psi. 16. ND BOP and tubing head. Change out 7" casing packoffs. NU tubing head & BOP. Pressure test packoff and body test BOP. 17. Lay down 3.5" workstring. 18. Run new 3-1/2" completion. 19. Spot corrosion inhibited seawater. Sting into PBR. Space out and land completion. 20. Pressure test tubing and IA. 21. ND BOP, NU and test tree. 22. Freeze protect well 23. RDMO workover rig. 24. Pull WRP. Pull SOV and run DV. • ~'~~~~ " ~ ~Car~~carPlli~s A[~~ka~, ~~~ • KRU 1 R-04 1 R-04 API: 500292140700 Well T e: INJ An le TS: 41 de 7823 sssv (isoz-,so3, T L- --'~ SSSV Type: Locked out Orig Com letion: 9/18/1985 Angle @ TD: 38 deg @ 8440 oD:3.5o0> ~ ~ Annular Fluid: Last W/O: Rev Reason:. TAG FILL, Drift Patch w/1.25" tool strin Reference Lo Ref Log Date: Last Update: 2/15/08 Last Ta 8168 TD: 8440 ftKB r Last Tag Date: 2/15/08 Max Hole An le: 49 deg @ 5200 - - ~ -- Casin Strin -ALL STRINGS ---- ._ Descri lion Size To Bottom TVD Wt Grade Thread '' ~ ~ • CONDUCTOR 16.000 0 115 115 65.00 H-40 I ~ SURF CASING 9.625 0 4297 3927 36.00 J-55 PROD CASING 7.000 0 8427 6853 26.00 J-55 ~ Tubin` Strin :.TUBING __ ___ __ _ Size To Bottom TVD Wt Grade Thread 3.500 0 7992 6517 9.30 J-55 EUE 8RD -a: ~ ~ 2.875 7992 8047 6559 6.50 J-55 EUE 8RD -- Perforations Summa _ Interval __ TVD Zone Status Ft SPF Date T e Comment ~ ~ 7892 - 7932 6442 - 6472 C-1 40 12 0/28/198 IPERF 5" Expendable HJ II; 120 de h ~ - - 8116 - 8134 6612 - 6625 A-4 18 12 0/28/198 IPERF 4" HJ II Csg Gun; 90 de h . ~ rr t 8146 - 8188 6635 - 6667 A-3 42 4 0/28!198 IPERF 4" HJ II Csg Gun; 90 deg ph .Gas Lift Mandrels/Valyes ~,' St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt ~~ ~; 1 2277 2275 Merla TMPD DMY 1.0 BK 0.000 0 /141199 2 3729 3516 Merla TMPD DMY 1.0 BK 0.000 0 /14/199 3 5159 4520 Merla TMPD DMY 1.0 BK 0.000 0 /14/199 PBR (7801-7802 4 5784 4938 Merla TMPD DMY 1.0 BK 0.000 0 /141199 , OD:3.500) 5 6286 5279 Merla TMPD DMY .1.0 BK -0.000 0 /261199 6 6784 5632 Merla TMPD DMY 1.0 BK 0.000 0 /26/199 PKR 7 7254 5973 Merla TMPD DMY 1.0 BK 0.000 0 /26!199 (7815-7816, - ~ 8 7753 6338 Merla TPDX DMY 1.5. RM 0.000 0 4/112000 OD:8.156) ~ g 7854 6414 Merla TMPD Y/PAT 1.0 BK 0.000 0 0/2_3/199 -- TuBwc - :Other lu s e ui .etc. -JEWELRY (o-7992, De th ND T e Descri lion _ ID OD:3.500, ID:2.992) 1802 1802 SSSV Baker-'FVL' Locked Out 6/8195 2.812 7801 6374 PBR Baker 3.000 PATCH (7 - 7$15 6384 PKR Baker'FHL' - - 3.000 0o z i5oj _ ~ ~ 7840 6403 PATCH HES RCP patch, tenth 27.45', isolating station #9 GLM -set 5/7/2000 1.310 Pert - 7985 6512 NIP Set 2.75" BPI SLV 4/1/00.. 2.750 (7s9z-7s3z) - 8024 6542 PKR Baker'FB-1' 4.000 - - 8039 6553 NIP Camco'D' Ni le NO GO. 2.250 s~Eeve-c 8047 6559 SOS Camco 2.441 psa5asss' OD:2.750) ~ `~ 8048 6560 TTL 2.441 I __ - Other lu s, equip. etc. -SLEEVE _ - De th TVD~ Type Description _ID PKR (8024-8025 1 7985 6512 'SLEEVE-C~ BPI ISO sleeve set 4/1/2000 2.310 , oDS.iss) Fish -FISH _ De th Descri lion _ __ _ Comment NIP 8136 PO Valve Left Pieces in Hole (ao3s~oao, _ GeneraFNotes OD:2,875) Date NOIe TUBING 3/1/2000 Found ossible leaks 7858' WLM & 7842' WLM; Ref: WSR 3/1/2000 pssz$oa7, 4/2/2000 Drifted tubin w/23.5" X 2:79 dumm atch to 7910' WLM. OD:2.875, ID:2 441) - - 110/200 Drifted tubin w/2T x 2.473" dumm atch to7900' , Pert -• (8116-8134) ~:. ,; • • Well: 1 R-04 API: 500292140700 ~t~1'100+E3P~'11~5 Field: Kuparuk PTD: 185-178 2008 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3%' BTC BPV: 3" FMC ISA Model: FMC Gen 3 CONDUCTOR 16", 65 ppf, H-40 SURFACE CASING 9-5/8", 36 ppf, J-55 e PRODUCTION CASING 7", 26 ppf, J-55 TUBING 3%", 9.3 ppf, L-80, IBT Mod, 0' - 7801' (new this workover) 3-1/2", 9.3 ppf, J-55, EUE-8rd Mod, 7815' 7801' - 7992' (existing) 2-7/8", 6.5 ppf, J-55, EUE-8rd Mod, 7992' - 8047' (existing) _ NEW COMPLETION A: Landing Nipple: 2.875" DS profile 500' M D B: Expandable Casing Patch or 5-1/2" scab liner. Repair type depends on pressure testing results. Leak detect log determined leak depth to be 6618'. C: Gas Lift Mandrel: No. MD TVD TYPE 1 -7700 6298 1" KBG2-9 D: PBR and stack packer @ 7735' MD E: Nipple: 3%2" with 2.813" DS profile F: Injection Mandrel Patched with HES RCP patch on 5/7/00 ~ G: AVA Nipple G 8024' H: NoGo Nipple: 2.25" D profile NIPPLE H 2-7/8" Camco 2.25" 'D' Nipple @ I: Existing completion from PBR at 8039' RKB -~~.• •• •• PERFS 7892' - 7932' 12 spf Last Tag: 2/15/08. 8116' - 8134', 12 spf Tag Depth: 8,168' RKB 8146' - 8188', 4 spf Fill: 20' above btm perf TD: 8,440' RKB Last Updated: 18-Feb-08 Updated by: HBG . . MElVIORANDUM State of Alaska ~Iaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor --¡-:://)i . "/4/:"1 ('-"'?1 - - 't ~ DATE: Fnday, May 11,2007 FROM: Bob Noble Petroleum Inspector SlJBJECT: '\lechanlcal Integnty Tests CONOCOPHILUPS ALASKA fNC IR-04 KUPARUK RlV UNIT lR-04 Src: Inspector s~\1't \C6 NON-CONFIDENTIAL Reviewed By: P.I. Suprv .j~Ç- Comm Permit Number: 185-178-0 Inspector Name: Bob Noble Inspection Date: 5/9/2007 Well Name: KUPARUK RIV UNIT IR-04 Insp Num: mitRCN070510203521 ReI Insp N urn: API Well Number: 50-029-21407-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~~:I~i~~~·!W~~~'l_øM~~_~~~-L~~,~~l~w~I~I~~~ P.T.Di 1851780 iTypeTe~~~2j~estI?~~~~_.LYA 1_ 700_~___~0 ----'--_.700 ___---=()()_~~ ____~___n____ Interval 4YRTST P/F F ~/ Tubing j 1900 . 1900 1900 1900, Notes: ~,'c'fJN'SRGs per.fìì¡ì'IN/¿;~. ~1¡ÌlO7;-~~--~----------'-- UJ QQ..l S cL f¿\j 4.M ¡-h¿'YIcb ß,t?l¿þwbhc<; SCANNED JUN 0 6 2007 Friday, May 11, 2007 Page I of I lR pad MITs 5-9-07 . Tom, Jim, & Bob, 144.l I R-ö 4- prrs~ i '3'>'-17'6 Attached are Injector MITs for lR pad witnessed by Bob Noble on 5-9-07. All MITs passed except for lR-04 & lR-09. Both wells have been added to the failed MIT report for May. 90 day TIO plots and schematics for both wells are attached. Diagnostics are planned this morning for both wells to test the tbg packoffs and measure the leak rates. There is a chance that leak is in the packoff off and tightening the packoff may result in a passing MIT. lR-09 has been SI since last fall waiting for flowline repair. lR-04 is on water injection. I'll send an update on thepiâil forward for these wells after today's testing/repair attempt is complete. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com sCANNED MAY 1 6 2007 «MIT KRU lR 05-09-07.xls» «lR-04 90 day TIO plot 5-10-07.gif» «lR-04.pdf» «lR-09 90 day TIO plot 5-10-07.gif» «lR-09.pdf» Content-Description: MIT KRU IR 05-09-07.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 MIT KRU lR Content-Description: IR-04 90 day no plot lR-04 90 day TIO plot 5-10-07.gif Content-Type: image/gif Content-Encoding: base64 Content-Description: IR-04.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: lR-09 90 day no plot lR-09 90 day TIO plot 5-10-07.gif Content-Type: image/gif Content-Encoding: base64 0-07. gif 10f2 5/11/2007 1 :48 PM lR pad MITs 5-9-07 . . Content-Description: IR-09.pdf lR-09.pdf Content-Type: application/octet-stream Content-Encoding: base64 20f2 5/11/2007 1:48 PM 1 R-Q4 90 no ofi 5/1 SSSV (1802-1803, 00:3.500) PBR (7801-7802, 00:3.500) PKR (7815-7816, 006.156) TUBING (0-7992, 00:3.500, 10:2.992) PATCH (7840-7858, 00:2.750) Perf (7892-7932) SLEEVE-C (7985-7966, 00:2.750) PKR (8024-8025, 00:6.156) NIP (8039-8040, 00:2.875) TUBING (7992-8047, 00:2.875, 10:2.441) Perf (8116-8134) - 'mm -- - ----- - 7985 6512 NIP 8024 6542 PKR 8039 6553 NIP 8047 6559 SOS 8048 6560 TTL otñertñmíJl'I~:¡(~1~1:::låtê; Depth TVD Type Description 7985 6512 SLEEVE-C BPI ISO sleeve set 4/1/2000 1It1li111A:llt'Is'IîI'FI¡1 ¡¡ Depth I DescriPtion 8136 PO Valve IJSm1Iìí:tì!øtes11 Date Note 3/1/2000 Found oossible leaks @ 7858' WLM & 7842' WLM; Ref: WSR 3/1/2000 4/2/2000 Drifted tubinQ w/23.5" X 2.79 dummy patch to 7910' WLM. /10/200< Drifted tubinq w/27' x 2.473" dummy patch to 7900' . API: 500292140700 SSSV Type: Locked out Annular Fluid: Reference Loq: Last Taa: 8164 Last Tag 7/7/2006 Date: Description CONDUCTOR SURF CASING PROD CASING iÎll!ilñli~Jriiiiti:i:plt1iiI!lIIfIJ:JS . Size Top 3.500 0 2.875 7992 l!!ø:ifóíilíllilSl::$ mlñâll1 Interval TVD 7892 - 7932 6442 - 6472 8116 - 8134 6612 - 6625 8146 - 8188 6635 - 6667 11!SSS St MD TVD Man Mfr 1 2277 2275 Merla 2 3729 3516 Merla 3 5159 4520 Merla 4 5784 4938 Merla 5 6286 5279 Merla 6 6784 5632 Merla 7 7254 5973 Merla 8 7753 6338 Merla 9 7854 6414 Merla Depth TVD Tvpe 1802 1802 SSSV 7801 6374 PBR 7815 6384 PKR 7840 6403 PATCH - - ---- - - ------ - .m.... . KRU 1 R -04 Well Type: INJ Orig 9/18/1985 Completion: Last W/O: Angle @ TS: 41 deq (ã) 7823 Angle @ TO: 38 deg @ 8440 Ref Log Date: Rev Reason: TAG FILL, Drift Patch w/1.25" tool strinQ Last Update: 7/8/2006 TO: 8440 ftKB Max Hole 49 deg @ 5200 Anqle: Size Top Bottom TVD Wt Grade Thread 16.000 0 115 115 65.00 H-40 9.625 0 4297 3927 36.00 J-55 7.000 0 8427 6853 26.00 J-55 :'«<n I Bottom TVD I Wt I Grade I Thread I I 7992 6517 I 9.30 I J-55 I EUE8RD I 8047 6559 I 6.50 I J-55 I EUE 8RD ¡) Zone Status Ft SPF Date Type Comment C-1 40 12 0/28/198 ¡PERF 5" Expendable HJ II; 120 deq oh A-4 18 12 0/28/198 IPERF 4" HJ II Csg Gun; 90 deg ph A-3 42 4 0/28/198 IPERF 4" HJ II Csg Gun; 90 deg ph )FF:i:iF "" Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt TMPD DMY 1.0 BK 0.000 0 /14/199 TMPD DMY 1.0 BK 0.000 0 /14/199 TMPD DMY 1,0 BK 0.000 0 /14/199 TMPD DMY 1.0 BK 0.000 0 /14/199 TMPD DMY 1.0 BK 0.000 0 /26/199 TMPD DMY 1.0 BK 0.000 0 /26/199 TMPD DMY 1.0 BK 0.000 0 /26/199 TPDX DMY 1.5 RM 0.000 0 4/1/2000 TMPD MY/PATC 1.0 BK 0.000 0 0/23/199 Description Baker 'FVL' (Locked Out 6/8/95) Baker Baker 'FHL' HES RCP patch, lenth 27.45', isolating station #9 GLM - set 5/7/2000 Set 2.75" BPI SLY 4/1/00. Baker 'FB-1' Cameo '0' Nipple NO GO. Camco ID 2.812 3.000 3.000 1.310 2.750 4.000 2.250 2.441 2.441 I ID 2.310 Comment Left Pieces in Hole . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/1 R 05/09/07 Greenwod-Rogers 1 Ives/ Bates Bob Noble c;\n\ö'1 i~ ar1 Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us -7 Packer Depth Pretest Initial 15 Min. 30 Min. We1l11R-03A I Type Ini. I W TVD I 6,403' Tubing 2240 2240 2240 2240 IntervaJ 4 p.T.D.1200021 0 I Type test I P Test psil 1601 Casing 770 1650 1650 1650 p/FI P Notes: OA 800 830 830 830 We1l11R-04 I Type Inj.1 W TVD I 6,384' Tubing 1900 1900 1900 1900 Interval 1 4 p.T.D,11851780 I Typetesd P Test psil 1596 Casing 825 2500 2060 2010 p/FI F Notes: OA 700 700 700 700 Well11 R-06 1 Type Inj. I N TVD I 6,266' Tubing 1190 1190 1190 1190 Interval I 4 P.T.D.11850710 1 Type test P Test psil 1567 Casing 530 1950 1910 1900 P/F P Notes: Silang term since 5/7/07 for flowline repair OA 20 20 20 20 We1l11R-08 I Type Inj. 1 W TVD I 6,380' Tubing 2075 2075 2075 2075 Interval I 4 P.T.D.!1850730 I Type test I P Test psi I 1595 Casing 1100 2600 2600 2600 p/FI P Notes: OA 750 810 810 810 Well11R-09 I Type Inj. I N TVD I 6,309' Tubing 1100 1100 1100 1100 Interval 4 P.T.D.11850950 I Type test I P Test psi! 1577 Casing 1210 1970 1870 1780 P/F F Notes: Silang term since 9/26/06 for flowline repair OA 0 0 0 0 Well11R-10 1 Type Inj. I N TVD I 6,257' Tubing 1300 1300 1300 1300 I ntervall 4 P.T.D 11850960 I Type test I P Test psil 1564 Casing 860 2075 2060 2055 p/FI P Notes: Silang term since 9/26/06 for flowline repair OA 220 220 220 220 Weill 1 R-13 I Type Inj.1 W TVD I 6,420' Tubing 2150 2150 2150 2150 Interval 4 p.T.D.11851500 I Type test I P Test psi! 1605 Casing 1060 1650 1620 1620 P/FI P Notes: Bled OA to 500 psi for start of test. OA 1000 500 500 500 Well 1R-15 Type Inj.1 W TVD I 6,317' Tubing 1750 1750 1750 1750 IntervaJ 4 p.T.D.11851520 I Type test I P Test psil 1579 Casing 1280 2500 2450 2440 P/FI P Notes: OA 650 650 650 650 Well 1R-17 I Type Inj.1 G TVD I 6,462' Tubing 3400 3400 3400 3400 I ntervall 4 P.T.D.11911140 I Type test I P Test psi 1616 Casing 1470 2500 2440 2420 P/FI P Notes: OA 760 760 760 760 Well11R-18 I Type Inj. N TVD 3,182' Tubing 660 660 660 660 Interval 4 p.T.D.11910870 I Type test I P Test psil 1500 Casing 40 1500 1500 1500 P/FI P Notes: IA&OA are common due to circulation string. OA 40 1500 1500 1500 Class" disposal well. Iniection SI during test. MIT Report Form BFL 9/1/05 MIT KRU 1R 05-09-07-1.xls Well 1R-19A I Type Inj. W I TVD I 6,548' Tubinç¡ 1950 1950.50 1950 Interval I 4 P.T,D.11910850 I Type test P Test pSi 1637 Casina 750 2590 2590 2590 P/F P Notes: OA 450 610 610 610 Weill 1 R-23 I Type Inj.1 W TVD I 6,713' Tubina 2100 2100 2100 2100 Interval 4 P.T.D.11911010 I Type test I P I Test psil 1678 Casinç¡ 1030 2650 2580 2560 P/FI P Notes: OA 360 500 500 500 Well11 R-26 I Type Inj.1 W I TVD I 6,535' Tubina 2150 2150 2150 2150 Interval 4 p.T.D.11910920 I Type test I P I Test psi 1634 Casinç¡ 1360 2650 2650 2650 P/FI P Notes: OA 690 690 690 690 We1l11R-32 I Type Inj.1 W I TVD I 6,253' Tubina 2075 2075 2075 2075 Interval 4 P.T.D.11941460 I Type testl P Test psi 1563 Casing 660 2610 2590 2580 P/FI P Notes: OA 380 610 610 610 Well 1R-33 I Type Inj.1 W I TVD I 6,596' Tubing 1900 1900 1900 1900 Interval 4 p.T.D.11941560 I Type testl P I Test psi 1649 Casing 680 2800 2780 2780 P/F P Notes: OA 0 225 225 225 . D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 1 R 05-09-07 -1.xls MEMORANDUM TO: THRU: FROM' State of Alaska Alaska Oil and Gas Conservation Commission Commissioner SUBJECT: Mechanical Integrity Tests P.I. Supervisor~0[ii ConocoPhillipsl R Pad Alaska Inc. 1R-04, 1R-13, 1R-32, 1R-33 Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I w~,,I ~-o~ i~,~,~i.i ~ i ~.V.D. I~ I~,.~ I~o I ~o I~o I ~o I,~,erv~,l ~ I P.T.D.( 1851780 ITypetesq P I Testpsil 1596 I Casingl 1150I 2500I 2420I 2410I P/F I P I Notes: Test fluid: 2.2 bbls diesel. I Packer Depth Pretest Initial 15 Min. 30 Min. I P.T.D.I 1851500ITypetestI P I Testpsil 1605 ICasingI 1125I 3000I 2970I 2940I P/F I P Notes: Test fluid' 2.5 bbls diesel. Held press, test extra 15 min. Tubing =2350 psi / Casing =2920 psi final. Packer Depth Pretest Initial 15 Min. 30 Min. w,,,I.,,~-~ I Typelnj. I sI T.V.D. I~ I-,-,,,~,,-,~1 ~,o I ~,o I~o I ~,o I,nt~,-vq 4 P.T.D.I 1941460 Type testI P I Testpsil 1563 I Casingl 1350I 3040I 3020I 3020I P/F I P Notes: Test fluid: 3.3 bbls diesel. Packer Depth Pretest Initial 15 Min. 30 Min. iw~,,I1R-33 ,nj.I S I T.V.D.I 6596 I Tubingl ~o I~o I~o I~o I,nte~a,I 4 P.T.D.I 1941560 IType Type testI P I Testpsil 1649 ICasingI 225 I 31501 31251 31251 P/F I PI INotes: Test fluid: 8 bbls diesel. " Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S - SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details May 31, 2003: I traveled to ConocoPhillips Alaska's Inc.'s (CPAI) Kuparuk River Field injection wells 1R-04, 1R-13, 1R- 32 and 1R-33, to witness 4 year MIT's. Nina Woods was the CPAI representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with all four wells meeting the criteria for successful MIT's. The pressure test on well 1R-13 was extended an extra 15 minutes to further demonstrate a non-l/near trend toward stabilization. I inspected four well houses and one exception was noted; the swab valve on well 1R-04 was leaking f~om the balance chamber and was repaired while I was on the pad. Summary: I witnessed successful MIT's on CPAI's injection wells 1R-04, 1R-13, 1R-32 and 1R-33 in the Kupamk River Field. Four well house inspections, one exception. M.I.T.'s performed: _4 Number of Failures: 0 Attachments: Wellbore schematics (4) · . ....,a~'~'.;;,~ Total Time dudng tests: 5 cc.'. MIT report form 5/12/00 L.G. ~CA~NE~:, JUL {) ? 2[ID3 2003-0531_MIT_KRU_lR-33_jj.xIs 6/19/2003 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ¢ (1802-1803, 0D:3.500) PBR (7801-7802, 0D:3.500) PKR (7815-7816, 0D:6.156) PATCH (7~4~7858, 0D:2.750) SLEEVE-C (7985-7986, 0D:2.750) KRU 1R-04 1R-04' ', · . APl:15002 92140700 SSSV Type:I Locked out I Annular Fluid:I Reference Log:I Last Tag:lB229 Last Tag Date:~3/l/2000 casing S~g"~,ALL STRINGS Description CONDUCTOR SURF CASING PROD CASING Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: Size Top 16.000 0 9.625 0 I 7.000 0 INJ 9/18/1985 3440 ftKB 49deg(~5200 Angle @ TS:141 deg@ 7823 Angle @ TD:I38 deg @ 8440 I Rev Reason:I Sleeve update by Last Update:J6/9/2002 Boffom TVD 115 115 4297 3927 8427 6853 Wt Grade 165.OOl H-~O I 36.00 I J-55 I 26.°°1 J-55 Thread Tubing Strin9 - TUBING ' ,': ': · Size I Top I Bo"om I TVD I wt IGradeI Thread 3.500 I 0 I 7992 I 6517 I 9.30 I J-55 I EUE8RD 2.875 I 7992 I 8047 I 6559 I 6.50 I J-55 I EUEeRD ~ ~ :fid ~ti i~ §ils ~'~ ~ ~i~:i;i !:ii;; :i ':'. ~ :' !: ii i:i ?~: :i: i ;: ,! i!! .!~; ~:i :.i i:!i:~!:ii'.; i i:i :~;i (i: i~ ~.!i! ! !:i !! ~.~i i '.:~: :: :: :::i i i~ i i~i! il i:iiii ~,: i! ':i :, :: !:! i ill il i! !.; ! !i :! i:.ii; i: ]; i: !! ! :: i:i ~.i:. i!~ i i !~ ! i! i.; :: i;;~ ~.i i ~,'i~: i! ~ :i :i !! i:: :i ::· ::ii;;! ~. ;i !: i~ ii Interval I TVD I Zone I Status IFt ISPFI Date ! Type I Comment 7892- 7932 I 6442-6472 I C-1 I I 40 I 12 110/28/1984 IPERF 15'' Expendable HJ II; deg ph 8116'8134 I6612'6625 I A4 I ] 18 r 12 110/28/198511PERFI4"HJIICsgGun;O0degph 8146-8188 I 6635-6667 I A-3 I 1421 4 r10/28/1985~ IPERFI4"HJIICsgGun;90degph I Gas Lift Mandrels/Valves . · · ' . ' · 1 I 22771 22751 Mer 2 137291 35161 Mar 3 I 5159l 45201 Met 4 I 57s41 49381Met 5 162861 5279J Mer 6 I 67841 56321 Mer 7 172541 59731 Met 8 I775~1 63381 Met 9 I 78541 64141 Met Other {plugs, equip;r etc.I Depth I TVDI Type 180211802 I sssv 7801 16374 I PER 7815 16384 I PKR 7840 16403 I PATCH 7985 16512 I NIP 8024 16542 I PKR 8039 16553 I NIP 8047 16559 J sos 8o48 1656o I TTL Depth lTVD I Type' 7985 I 6512 I SLEEVE-C "I Man I v Mfr I VTypeI V OD I LatchI Port I TRO I Date I V,v · Type Run a I TMPD I I DMY 11.0 I BK 10.0001 0 17/14/1990l ~a ITMPD I I DaYI 1.o IBEi0.0001 0 17/14/19901 ,a I TMPD I I DMY 11.0 I BK 10.0001 0 17/14/1990I a I TMPD I I DMY 11.0 I BE 10'0001 0 18/26/1990l a I TMPD I I DMY 11.0 I BE 10'0001 0 18/26/19901 ,a I TMPD I I DMY 11.0 I EK 10'0001 0 18/26/19901 ~a I TPDX I / DMY /1.5 IRa I0.0001 0 /4/4/2000/ Iai TMPD I ])MY/PATCI~ 1.0 I BK 10,0001 0 ]10/23/1995I - JEWELRY . · Description ID I Baker'FVL' (Locked Out 6/8/95) 2.812 , ?.ker ___ 3.000 ~aKer 'l-I-IL' 3.000 !HES RCP patch, lenth 27.45', isolating station #9 GLM - set 5/7/2000 1.370 ISet 2.75" BPI SLV 4/1/00. 2.750 Baker 'F,B-I' 4.000 iCamco D' Nipple NO GO. 2.250 ;Camco 2.441 2,441 Description I ID BPI lSD sleeve set 4/1/2000 I 2.310 Fish- FISH · PO Valve Note Description Comment Left Pieces in Hole leaks @ 7858' WLM & 7842' WLM; Reft WSR 3/1/2000 Drifted tubing w/23.5" X 2.79 dummy patch to 7910' WLM. Drifted tubin x 2.473" dummy patch to 7900' PKR (8O24-8025, 0D:6.156) NIF 0D:2.875) Per[ (8116-8134) PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 1R,13. SSSV ~ (1824-1825, 0B:2.875) NIF (7822-7823, OD:2.875) SBP, (7861-7862, OD:2.875) PKR (7880-7881, 0D:6,156) PERF (8O3O-8O40, 0D:2.875) KRU 1R-13 Size 2.875 0 Perfo'rati~fi~ Sd~ APl: 500292138500 ' ' Well Type: INJ I Angle ~ TS:145 de¢l ~'7969 I Angle @ TD: J44 deg @ 8570 TRDP Odg Completion: 7/29/85 Annular Fluid: Last W/O: 11/10/88 Rev Reason: tTag fill Reference J Ref Log Date: Last Update:13/7/01 51 deg @ 6700 ~:ALL'STRINGS=: ! '.ii. i:': ::". ;:~:? ~: ":~,:i:~:~ii'!~::; :.:! : ': :.. - ion Bottom TVD Wt Grade'Thread SURFACE 0 3945 3835 36.00 PRODUCTION 0 8561 6904 J 26.00 J-55 CONDUCTOR 0 115 115 I 62.50 H-40 Bottom I TVD Wt Grade Thread 8124 ~ 6591 6.50 I J-55 EUE 8RD AB MOD Interval TVD Zone Status Ft SPF Date Type Comment 8030-8050 6525-6539 IC-1,UNITBI I 20 I 12 I 10/17/85 IPERF 5" HJ II Csg Gun;120 deg. phasing 8210 - 8266 6652 o 6692 A-4,A-3 56 4 10/17/85 IPERF 4" HJ II Csg Gun; 90 deg. I {phasing 8290 - 8300 6709 - 6716 A-2 10 I 4 10/17/85 IPERF 14" HJ II Csg Gun; 90 deg. I I I phasing 8330- 8340 6737- 6744 A-2 I 10 I 4 I 10/17/85 IPERF 4" HJ II Csg Gun; 90 deg. I I I I I I I phasing VIv Cmnt Gas Lift Mandrels/Valves BLAST JOINTS PERFORATED · 0 11110/88 0 11110/88 Description ID PERF Blast Joints Perforated ~ 4 SPF on 7/19/87 2.441 PERF Blast Joints Perforated ~ 2 SPF on 2/1/87 2.441 -JEWELRY ' ' · SSSV Camco q'RDP-1A-SSA' Description ID 2,312 NIP Otis 'X' 2.313 SBR Camco 'OEJ' 2.297 PKR Camco 'HRP-1-SP' 2.340 PKR Baker 'DB' 3.250 NIP Camco 'D' Nipple NO GO SOS Camco 2.250 2.441 TTL 2.441 PKR (8096-8097, 0D:6,156) NIF (8116.8117, OD:2.875) TUBING (0-8124, 0D:2,875, ID:2.441) Ped (8210-8266) Ferf (8290-8300) Per/ (8330-8340) NIP (532-533, OD:3.906) TUBING (O-10547, OD:3.500, ID:2.992) mdrel/Durnmy Valve 1 (1O436-1O437, 0D:6.018) NIP (10482-10483, 0D:3.500) PROD, CASING (0-10709, OD:7.000, Wt26.00) LOCATOR (1O516-10517, 0D:3.500) LINER (lO510-11470, OD:5,000, Wt18.00) MULESHOE (10546-10547, (11197-11237) (11259-11288) Conoc0PhilliPs AlaSka, Inc. KRU 1R-32 AP~:15oo2922523oo ' Well'TYPei INJ I Angle @ Ts:J42 deg @ 10969 SSSV Type:il NIPPLE Completion: J Orig J 12/17/1994 j Angle @ TD:J 41 deg @ 11470 Annular Fluid:J Last W/O:J j Rev Reason:JTAG FILL Reference LoB:I J RefLog Date:J Last Update:J5/23/2003 Last TaB:J 11330 J TD:J11470 ftKB I Last Tag Date:J5/16/2003 J Max Hole AnBle:J61 deB (~ 8818 Casing'strin~:~'ALL STRINGS -:. ~: :::::::~::.~. :.i; .:: ':~!:.::'.!: ~. :.~:!:~:! ;:; :!'i::':i: :' :.~.:: Description Size Top BoSom I TVD I wt I Grade 1Thread CONDUCTOR 16.000 0 121 I 121 162.581 H-~0 I SUR. CASING 9.625 0 6423 I 4073 14o.ool L-soI PROD. CASING 7.000 0 10709 I 6391 126.001 L-SO I LINER 5.000 1o51o 11470 I 11470 I 18.00 L-S01 ;!~.T:U B IN G :.:;~ ::i;;::i:~ :: !i i~.::: ii: !ii:~;i!:: ~ ~'::~ :ii ii ::!: ';::i:! ::.:!,:;: ~;!::::'~! ;i:i! :i;i~:~:: :.;:~;::. ! :!:~ ::i i; !~ii~ i !:i.; 7;:;~i !!i!i; :!:ii:i~: i: il i: ;;: i.;;;i~.~: !::: :.i;:. ;:i;i:: 0 10547 6274 ABM-DUE Interval TVD Comment 11197- 11237 6749-6777 2 1/8" Enerjet; 180deg. phasing; Oriented (+/-) 90 11259-11288 6792-6812 2 1/8" Enerjet; 180 deg. phasing; Oriented (+/-) 90 Gas Lift Mandrels/Valves · StI MD J TVD I Man I Man I V Mfr I V Type I V OD I'atchl Por~ I TROI Date I Vlv J J JMfrlType j J I I J J J"unlCmr" 1 10436 6196 Camco MIVIVI DMY 1.5. RK 0.000 0 6/29/1996 Other (plugs, equip,~ etc.)- JEWELRY . .. Depth ITVDI Type ] Description ID 532 I 531 I NIP ]Camco'DS' Landin9 Nipple 2.812 10482 I 6228 I NIP lOfts 'XN' Landing Nipple 2,750 10516 J6252 J LOCATOR JBaker 3.000 10546 J 6273 JMULESHOEJBaker (half-muleshoe) 4.000 NIP (480-481, 0D:3,500) TUBING (O-15O96, 0D:3.5O0, ID:2,992) ~ndml/Dummy Valve 1 (2069-2070, 0D:6,018) SLEEVE-C (14972.14973, 0D:3,5O0) PKR (15O18-15O19, OD:6,156) SOS OD:3.500) Tn_ (15O96-15O97, 0D:3.5O0) Pe# (15132-15165) (15186-15212) Conoc0Phillips Alaska, Inc~ .. KRU 1R-33 SSSV Type:I Nipple Annular Fluid:I Reference Log:I Last Tag:115294 Last Tag Date:J2/24/2003 ' W;il Type:IINJ I Angle@ TS:148 deg @Ii 14912 Orig 112/30/1994 Angle @ TD:[47 deg @ 15530 Completion:I Last W/O:I Rev Reas0n:lT, ag Fill Ref Log Date:I Last Update:J3/11/2003 TD:115520 ftKB Max Hole Angle:~74 deg @ 4571 Description Size I Top leo.om I TVD I Wt IOradel Thread CONDUCTOR 16.000 I 0 I 121 I 121 I 62.50 I H-4C)I ' SUR. CASING 9.625 I o I 7669 I 4081 140.001 L-so I PROD. CASING 7.000 I 0 I 15062 I 6626 126.001 L-80 I LINER . 5.00o I 15062 I 1552o I 15520 118001 L'8~I Size I ,,Top I Bottom I WO I Wt I Grade I Thread 3.5oo 0 15096 6649 I 9.3o I L-80 I EUE8RABM Inter~a~' I WO "'1 Zone I StatuslFt IS~'FI Date I Type I Commen! 15132-151651 6673-6696I A-3 I 1331~ 13/28/~9951 PERFla3/8"HSDTBGCONV; I I I I I I I 1180deg. ph;Orient165deg. ' I I I I I I I iccw F/High Side 15186-152121 6710-6728 I A-2 I I 26 I ~ 13/28/19951 IPERF 133/8" HSDTBGCONV; I I I I I I I 1180deg. ph; Orientl65 deg, I I I I I I I iccw F/High Side VIv Cmnt Other: (plugs, equip, etc.) - JEWELRY · , ' Depth lTVDI Type I Description ID 480 I 480 I NIP lCamco'DS'Landing Nipple NO GO 2.812 14972 I 6565 I SLEEVE-C lBaker ~CMU' Sliding wi Camco 'D' Profile 2.750 15o18 1 6596 I PKR Ieaker'FB-l' 3.OOO 1509416647 I SOS IxsAR Schlumberger 2.992 15096 I 6649 I TTL 13.5" Tubing 2.992 Depth I Description I Comment 15302 1128' Spent Tbg Perf Guns in IPerf°n3/28/95 (SWS3318" HSD) I Rathole STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 334' FNL, 137' FWL, Sec. 20, T12N, R10E, UM At top of productive interval 1463' FSL, 1265' FWL, Sec. 20, T12N, R10E, UM At effective depth At total depth 1094' FSL, 1406' FWL, Sec. 20, T12N, R10E, UM Perforate _ Other _X 5. Type of Well: Development _ Explorato~___ Stratigraphic__ Servi~__X (asp's 539828, 5990872) (asp's 540985, 5987396) (asp's 541130, 5987028) 6. Datum elevation (DF or KB feet) RKB 82 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 R-04i 9. Permit number / approval number 185-178 10. APl number 50-029-21407 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 4215' PROD CASING 8345' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 8440 feet Plugs (measured) 6864 feet 8229 feet Junk (measured) 6699 feet Size Cemented 16" 250 Sx CS II 9-5/8" 1190 Sx PFE, 425 PFC 7" 300 Sx G, 250 Sx PFC Tagged Fill (3/1/00) @ 8229' MD. Measured Depth 115' 4297' 8427' True verflcalDepth 115' 3927' 6853' RECEIVED 7892 - 7932'; 8116 - 8134'; 8146 - 8188' 6442 - 6472'; 6612 - 6625'; 6635 - 6667' FEB 1 6 ; 001 Alaska 0il & Gas Cons. Commission Anchorage 3-1/2', 9.3#, J-55, Tubing @ 7992' MD; 2-7/8", 6.5#, J-55, Tubing @ 8047' MD. Baker 'FHL' Packer @ 7815' MD; Baker 'FB-I' Packer @ 8024' MD. Baker 'FVL' (Locked Out 6/8/95) @ 1802' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) . (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OihBbl Shut In Representative Daily Avera.qe Production or Injection Data Gas-Md Water-Bbl 2OO0 Casing Pressure Tubing Pressure - 2800 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X .16. Status of well classification as: Oil __ Gas __ Suspended Service ~.(WAG)~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Prepared by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · ORIGINAL 1 R-04i DESCRIPTION OF WORK COMPLETED TUBING PATCH INSTALLATION OVER GLM LEAK 3/6/00: Performed a Leak Detection Log. Found a leak in tubing at 7838' MD at GLM #9. 5/7/00: RIH & set a Halliburton Tubing Patch over GLM leak at 7838' MD. Top element of patch at 7829' MD. Placed well on water injection & obtained a valid injection rate. RECEIVED FEB Alaska 0il & Gas Cons. Commission Anchorage 1R-04 Flowback Subject: 1R-04 Flowbaek Date: Mon, 17 May 1999 13:02:56 -0900 From: "Beck&Zuspan" <N1052~mail.aai.arco.com> To: blair wondzell@admin.state.ak.us Dear Blair, Per our discussion this morning 5/17/99, ARCO Alaska, Inc. was granted verbal approval for temporary production from injection well 1R-04. Well 1R-04 was classified as an injector on the Form 10-407 Completion Report, and has been on injection service since start-up. We plan to do a sidetrack completion on adjacent well 1R-01 in mid-September. Well 1R-04 has been shut-in for approximately six weeks in an effort to reduce the bottom hole pressure in the drilling area, prior to beginning the rig work on 1R-01. The bottom hole pressure has been measured every two weeks, and has not declined any appreciable amount. Therefore, we plan to flow the well for approximately 4 months in an effort to reduce the bottom hole pressure around 1R-01. 1R-04 will be produced through the flowline of adjacent shut-in producer 1R-27. Once the rig is off of well 1R-01 (or likely sometime before), 1R-04 will be returned to injection service. If you have any questions or comments concerning our activities, please e-mail back or give me a call at 276-1215 x7285. Sincerely, Mike Beck Wells/CPF-1 Engineering Tech Kuparuk 1 of 1 5/17/99 4:05 PM To: well Name I.o~ Run i)alc Kuparuk Kuparuk Euparuk KulDaruk Kupan~k Ktlpal uk iiiver iinit iR-iA River Unit IA-Il River Unit 1I.-10 ]liver Unit 11.-14 River Unil 1I.--17 Rive, Unit 1I.-22 Kuparuk River Unit IR 04 ~°r-/~ Kuparuk River Unit 1¥'-I0 ~j)'j - ~/ Kuparuk River Unit 1 Y--t2 ~fl --~d Kupatuk River Unit 1Y-IS ~~ 3 Kuparuk Kuparuk K u pal u k Kuparuk Kuparuk ik U [larll K Kupamk Kuparuk. Kuparuk Kuparuk lliver Unit 214-08 River Unit 2C-02 Rive, Unit 2C-04 River Unit 2C 05 River Unil 2C-06 itiver Unit 2V-i0 River Unit 2V--13 River Unit 30-.12 River Unit 311-02 River Unit 30-20 Water How [.og (Ti)T--P) Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile in t.~: on l-'rOllle Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Survey Injection Profile Survey Injection Profile Production l.og Production Log Injection Profile Injection Profile Survey Injection Profile 07.IA N 1991 10-1-91 03 NOVEMBERI991 4 NOVEMBER 1991 4 NOVEMBER 1991 11-06-1991 6/30/91 12-13---1991 1 I-I9-9i 11--17-1991 12.--2.-91 12~27--1991 26 DEC 1991 10-27--1991 1 II25191 11-16-1991 R-.IIJNF.-1991 31-JULY--1991 11 NOV 1991 10/119/91 11~29-1991 l!cceived by: ~~'~"~ Dated: Copy sent to .sender: Yes ,// No ~ RECEIVED MAR 2 6 1992 Alaska 0Il & Gas Cons. Commission Anchorage STATE OF ALASKA ~ OIL AND GAS ~SERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate __ Plugging Perforate _ Repair well O t h e r X feet Tubing Pressure 145 2300 Service Date I ~,-- ~7- ~ ~ SUBMIT IN DUPLICATE 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 334' FNL, 137' FNL, Sec. 20, T12N, R10E, UM At top of productive interval 1463' FSL, 1265' FWL, Sec. 20, T12N, R10E, UM At effective depth 1152' FSL, 1388' FWL, Sec. 20, T12N, R10E, UM At total depth 1094' FSL, 1406' FWL, Sec. 20, T12N~ R10E, UM 12. Present well condition summary Total Depth: measured 8570' feet true vertical 6. Datum elevation (DF or KB) 82' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-04 9. Permit number/ Approval # 85-178 / 90-452 10. APl number ~;0-029-21 407-00 Plugs (measured) 6965' feet 11. Field/Pool Kuparuk River Field Kuparuk River Pool Effective depth: measured 8453' feet Junk (measured) true vertical 6874' feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Cemented Measured depth True vertical depth 115' 16" 250SXCSII 4297' 9 5/8" 1190 Sx PF"E" & 425 Sx PF"C" 842 7' 7" 300 Sx Class G & 250 Sx PF"C" 13. Perforation depth: measured 7892'-7932', 8116'-8134', 8146'-81 88' true vertical 6442'-6472, 6612'-6626, 6635'-6667' Tubing (size, grade, and measured depth 3 1/2" J-55 9.3 #/FT @ 8031' MD-RKB Packers and SSSV (type and measured depth) Baker FHL @ 7799, Baker FB-1 @ 8008, Baker FVL SSSV ~ 1786 Stimulation or cement squeeze summary MD-RKB TVD-RKB Intervals treated (measured) CONVERSION TO WATER INJECTOR 14. Treatment description includin~l volumes used and final pressure Re_oresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 600 780 6000 1200 Subsequent to operation -0- -0- 5800 800 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X Oil _ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ Title Form 10-404 Rev 09/12/90 ARCO Alaska, Inc. Post Office ,_..,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 8, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1 R-04 Conversion June, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA A,_ ,SKA OIL AND GAS CONSERVATION COMiv. SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _~X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 334' FNL, 137' FEL, Sec. 20, T12N, R10E, UM At top of productive interval 1365' FNL, 1400' FEL, Sec. 20, T12N, R10E, UM At effective depth 1435' FNL, 1140' FEL, Sec.20, T12N, R10E, UM At total depth 1451' FNL, 1066' FEL, Sec. 20, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 8570 true vertical 6 8 91 ' Effective depth: measured 8 4 5 3' true vertical 6797' Casing Length Size Structural Conductor 1 I 5' 1 6" feet Plugs (measured) feet None feet Junk (measured) feet None Cemented 250 Sx CS II 6. Datum elevation (DF or KB) RKB 84 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1R-04 9. Permit number 8,5-178 10. APl number 5o-029-21 407 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' Surface Intermediate Production Liner Perforation depth: 4380 9 5/8" 8535' 7" 1200 Sx PF"E" III & 4380' 420 Sx PF"C" 250 Sx Class G 8 5 3 5' 200 Sx PF"C" measured 8072'-81 03', 81 99'-8245', 8289'-8300' true vertical 6498'-6523', 6597'-6634', 6668'-6678' Tubing (size, grade, and measured depth 3 1/2" J-55, 9.3 #/ft @ 8150' Packers and SSSV (type and measured depth) Baker FHL @ 7974', Baker DB @ 8126', Baker FVL SSSV @ 1799' 3867' 6864' RECEIVE i JUH 1 $ ]99i) Oil &, Gas Cons. CommissiOn '~ ~nch0rag~ 13. Attachments Description summary of proposal _ Detailed operation program _ Propose conversion from oil producer to water and gas injector. 14. Estimated date for commencing operation 115. Status of well classification as: , July. 1990 I Oil X Gas __ 16. If proposal was verbally approved Name of approver Date approved Service _Oil Producer 17. I her~jy %rtif~tha[ th~ f~o~oing is true and correct to the best of my knowledge. Signed~/~'~" ~ Title Senior Operations Engineer FOR COMMISSION USE ONLY BOP sketch Suspended _ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10- IAppro..,val No,, Approved b), the order Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LO.U. NIE ~, .~TH' Commissioner Approved Copy SUB~,II'T I~ TRIPLICATE .. - STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION _.,_,>.,. ,~' APPLICATION FOR SUNDRY APPROVALS_. ,\ . 1. Type of Request: Abandon_ Suspend_ Operation Shutdown_ Re-enter suspend~v~l ~_.'''~ Alter casing _ Repair well _ Plugging _ Time extension _ StimulaterS.- Change approved program Pull tubing Variance _ Perforate _ Other X~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X~ ARCO Alaska, Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 334' FNL, 137' FNL, Sec. 20, T12N, R10E, UM At top of productive interval 1463' FSL, 1265' FWL, Sec. 20, T12N, R10E, UM At effective depth 1152' FSL, 1388' FWL, Sec. 20, T12N, R10E, UM At total depth 1094' FSL, 1406' FWL, Sec. 20~ T12N, R10E, UM 12. Present well condition summary Total Depth: measured 8440' feet Plugs (measured) true vertical 6863' feet RKB 82 7. Unit or Property name Kuparuk River Unit 8. Well number 1 R-04 /~'~" 9. Permit number 85-72 10. APl number 5o-029-21407-00 11. Field/Pool Effective depth' measured 8339' feet Junk (measured) true vertical 6784' feet None Casing Length Size Cemented Structural Conductor 1 I 5' 1 6" 250 Sx CS II Surface 4297' 9 5/8" 1190 Sx PF"E" & Intermediate 425 Sx PF"C" Production 8427' 7" 300 Sx Class G & Liner 250 Sx PF"C" Measured depth 115' 4297' 8427' Perforation depth: measured 7892'-7932', 8116'-8134', 8146'-8188' true vertical 6442'-6472, 6612'-6626, 6635'-6667' Tubing (size, grade, and measured depth 3 1/2" J-55 9.3 #/FT @ 8031' MD-RKB Packers and SSSV (type and measured depth) Baker FHL @ 7799, Baker FB-1 @ 8008, Baker FVL SSSV @ 1786 MD-RKB TVD-RKB feet Kuparuk River Field Kuparuk River Oil Pool True vertical depth 115' 3927' 6853' 13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch _ ScaleSolv and sec Pump Schedule 14. 15. Status of well classification as: Oil ~ Gas __ Estimated date for commencing operation July 15, 1989 If proposal was verbally approved ~/2. O// ~ ?- Name of approver ~. ,.2/~ ,'//~ Date approved Service _Oil Producer 16. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /'~ ¢,~,'r.~ ,/~ ~,/?,,,~,~eu~~ Title FOR ~.,OMMISSlON USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance__ Mechanical Integrity Test__ Subsequent form require Suspended _ Approved b~' the order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH IApproval No. Approved .Copy Returned ?-¢,m _ Commissioner Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Well 1 R-04 Application for Sundry Approval June 26, 1989 It is proposed to pump a ScaleSolv folowed by a SOC job Well 1 R-04's A Sand. The SOC job is required to control deposition of barium scale in the tubulars and near wellbore area. No workover fluid will be used. No BOP is required. The expected bottom hole pressure of the A sand is 2500 psi. ,,,,/" 5/1/89 Procedure Well 1 R-04 Barium Treatment CC 230DS10RL 10. 11. 12. 13. 16. 17. 18. 1. MIRU slickline. 2. Pull Circ. valve at 7838 MD-RKB. Check for scale. Run dummy valve. 3, Pull AVA at 7969 MD-RKB, Run AVA 'BCP' with nitrile seals. Attach Amerada bombs to bottom of 'BCP' for A Sand PBU. 4. Rig down slickline. 5. MIRU pumping equipment for scale treatment. 6. Pump 70 bbls of diesel @ 2 BPM to wash tubing and displace crude, 7. Pump 5 bbls of xylene @ 2 BPM, 8. Displace xylene with 70 bbls of diesel @ 2 BPM. 9. Allow well to soak for 30 minutes. Inject 50 bbls of 75/25 water/ScaleSolv mixture (10 drums of ScaleSolv and 37 bbls of water) at 2 BPM, Stop pumping and rig down service company pump trucks. Allow fluid to gravity segregate in the wellbore for three hours. Displace ScaleSolv with 20 bbls of diesel. 14, Allow well to soak for 18 hours. Pump 20 bbls of diesel. 15. Allow well to soak for 18 hours. Pump 9 bbls of diesel. Return well to production. Allow well to clean up and obtain C Sand test, Perform SOC treatment and open A Sand to production. Procedure in following letter. 4/27/89 Page 2 Procedure 1R-04 SOC Treatment CC 230DS10RL , . . 1 . 10. 11. 12. 13. 14. 15. 16. 17. 18. MIRU pumping equipment. Service company should have on location: a. 110 bbls. 2% KCl water b. 620 gallons 7.5% HCl Note: this acid can be pre-mixed into the KCl water at the service company's facility and delivered to location. Mix the SOC pill per the following volumes and in the following order: a. 110 bbls 2% KCI water containing 620 gallons 7.5% HCl b. 6 drums SOC-2 c. 9 drums $-256 Circulate and monitor the SOC pill. The pH should be less than 2.5. If the pH is greater than 2.5, add additional SOC-2 liquid until pH is below 2.5. Add 9 drums CaCl 30% to the $OC mixture. Pump a pre-flush consisting of: 50 bbls diesel + 2 bbl SA-8660 (Chemlink chemical) Pump SOC pill at 2-4 bpm. Overdisplace using 235 bbls of injection* water (7.5 ft radial displacement). * (Other Drill Sites have used the drain system to divert water from an injectionwell into the producer being treated.) Displace water using 75 bbls diesel. Allow SOC pill to remain in formation for 24 hours. MIRU slickline. Pull AVA 'BCP' and Amerada bombs at 7969 MD-RKB. Run AVA commingling sleeve. Rig down slickline. Return well to production. ARCO Alaska, In, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 2, 1987 Transmittal #:6074 RETURN TO: ARCO Alaska, Inc. Attn: 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. 3M-17 3M-20 3M-21 3M-22 1R-1 1R-2 1R-4 1R-6 1R-8 1R-Ii 1R-13 1R-14 1R-16 Kuparuk Well Pressure Report (Otis) Kuparuk Well Pressure Report (Otis) Kuparuk Well Pressure Report (Otis) Kuparuk Well Pressure Report (Otis) Kuparuk Fluid Level Report Kuparuk Fluid Level Report' Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report (Camco) Kuparuk Fluid.Level Report Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report (Otis) Kuparuk %~11 Pressure Report (Otis) Kuparuk Fluid Level Report 9-13-87 Static 9-15-87 Static 9-17-87 9-16-87 Static 'A' Sand 8-22-87 8-22-87 8-23-87 Static 'C' Sand 8-23-87 'C' Sand 8-22-87 8-23-87 'C' Sand 8-22-87 8-21-87 Static 8-22-87 ReceiPt Acknowledged: DISTRIBUTION: E I y E,D AJaska Oil ~.a,.~ :Cops. Commission ~ch0rago D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AIlantlcRichfieldCompany ARCO Alaska, In/~''' Post Office pox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 22, 1987 Transmittal #: 6062 RETURN TO: ARCO Alaska, ~nc. Attn: 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. 3C-1 31-1 1R-4 1R-6 3C-14 31-5 3M-16 3M-18 3M-19 · PBU Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pressure Survey Static BHP Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pressure Survey 'A' Sand PBU Bottomhole Pressure Survey. Kuparuk Well Pressure Report(Otis) 8-20-87 8-15-87 8-27-87 8-20-87 8-21-87 8-16-87 Kuparuk Well Pressure Report(Otis) Static 'C' Sand Kuparuk Well Pressure Report (Otis) Static Kuparuk Well Pressure Report (Otis) . 50-029-21413 50-029-21407 50-029-21331 50-029-21425 9-7-87 9-14-87 9-14-87 Receipt Acknowledged: DISTRIBUTION: / ~x~'as'~ Oil & Gas Cons. " Anchorage .... Date: D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AllantlcRichlieldCompany ARCO Alaska, Inc. ";' Post Office I~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 25, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-4 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 1R-4. questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L180 Enclosure ~o~ap If you have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL []XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-178 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21407 4. Location of well at surface 9. Unit or Lease Name 334' FNL, 137' FWL, Sec.20, T12N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1463' FSL, 1265' FWL, Sec. 20, T12N, R10E, UM 1R-4 At Total Depth 11. Field and Pool 1094' FSL, 1406' FWL, Sec. 20, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk River 0il Pool 82' RKBI ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 09/11/85 09/1 7/85 09/1 8/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+ l-VD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 8440'MD, 6863'TVD 8339'MD, 6784 'TVD YES [~(X NO [] 1802 feet MDI 1600' (approx) 22. Type Electric or Other Logs Run D I L/GR/SP/SFL, FDC/CNL,Cal ,CET,GCT 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 115' 24" 250 sx CS II 9-5/8" 36.0# J-55 Surf 4297' 12-1/4" 1190 sx PF "E & 425 s~ PF "C" 7" 26.0# J-55 Surf 8427' 8-1/2" 300 sx Class "G" & 25£ sx PF "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) 8188' - 8146' w/4 spf 3-1/2" 8047' 7815' & 8024' 8116' - 8134' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8103' - 8072' w/12 spf DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR ~OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD e Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED FF..B 2 8 1986 Almtlm Oil & Gss Cons. Anchorage Form 10-407 * NOTE: Tubing was run & well perforated 10/28/85. DAM/WC18 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. -. GEOLOGIC MAFI.KEFIS -- FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7824~ 6390' N/A Base Kuparuk C 7934' 6473' Top Kuparuk A 8098' 6597' I Base Kuparuk A 8251' 6715' I I i I 31. LIS-I- OF ATTACHMENTS ~ell History (completion details) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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:, Attache~d ,sup_p..lemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. _ .- . Item 27' Method ~f Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jecti'on'; Gas I nject~i,o~, Shut-in, Other-explain. Item 28: If no cOre's taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Daily Well History-Final Report Inslru,-lions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel~3rt" 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 [ North Slope Borough Field ILease or Unit [uparuk River I ADL 25635 Auth. or W.O. no. [ Title AF~. 604542 [ Completion Nordic 1 AP1 50-029-21407 Operator ] A.R.Co. W.I. ARCO Alaska, Inc. [ 56.24% Spudded or W.O. begun [ Date Complete [ 10 / 27 / 85 Date and depth Complete record for each day reported as of 8:00 a.m. Accounting State COSt center code Alaska Well no, ].R-4 I otal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well our [Prior status if a W.O. 0515 hrs. 10/26/85 thru 10/28/85 10/29/85 7" @ 8427' . 8339' PBTD, 8047 TT, Prep Co lnd 3½" tbs 10.2 ppg NaCi' Accept ri~ @ 0515 hfs, 10/27/85. NU & tst BOPE. RU Schl, peri w/4" guns, '4 SPF f/8188'-8146' & 8116'-8134'. Perf w/5"guns, 12 SPF, f/8103'-8072'. Make 6" JB/gage ring run. RIH, set FB-1 pkr @ 8008' WLM. RD Schl. RIH w/3½" CA. 7" @ 8427' 8339' PBTD, 8047 TT, RR Diesel Land Cb~-Set pkr @ 7815'. Tst compl equip. ND BOPE. NU tree & tst. Displace to Diesel. Secure well. ER @ 1430 hfs, 10/28/85. ~t~~Moving to DS 3C-16. Old TD New TD Released rig Date 1430 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data REC IVF-D FEB 2 8 1966 Naska 0il ~;"6ti~ Cons. | ~n~hnraQ8 8339' PS'ED 10/28/85 Rotary Type completion (single, dual, etc.) Single Official reservoir name(a) Kuparuk Sands Well no. Dale Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day i Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Ellective date corrected i The above is correct Signature/JJ~,~ ~-----/~lJ-P~~ [ Date JTitlO For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office E ]00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 9, 1985 ' Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: · Attached in duplicate are subsequent following wells at the Kuparuk River Field. notices Well Action Date Performed 1B1 Frac 11/6/85 1E8 Frac 1 2 / 6 / 85 1E-1 9 Convers i on 1 0/1 7/85 1E-21 Conversion 8/1/85 1E.-23 Convers i on 1 0/23 ! 85 1G-2 Frac 12/6/85 1R1 Frac 11/5/85 1R2 Frac 11/5/85 1R4 Frac 11/6/85 1R6 Frac 11/6/85 1R1 3 Frac 11/1/85 1R1 4 Frac 11 /1/85 2D-5 Ac idi zed 6/1 8/85 2D-6 Ac id i zed 6/18/85 2V5 Convers i on 7/6 / 85 on the If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION $ JN_nRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL I~( OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 10036'0, ANCHORAGE, 4. Location of Well SURFACE LOCATI ON- 334 ' T12N, R10E, UM FNL, 5. Elevation in feet (indicate KB, DF, etc.) 84' 12. Perforate Stimulate Repair Well ALASKA 9951 0 137' FEL, SEC. 20, 7. Permit No. 85-178 Pull Tubing 8. APl Number 50- 029-21 407 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1R-4 I 6. Lease Designation and Serial No. (RKB) PAD 47' ADL 25635, ALK 2568 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) [] Alter Casing [] Perforations [] Altering Casing [] Abandon [] Stimulation ~ Abandonment [] Change Plans [] Repairs Made [] Other 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL [] 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). On November 6, 1985, the "A" sands of Kuparuk well 1R-4 were hydraulically fractured and propped to improve production. The treatment consisted of 215 BBLS of gelled diesel as pad and carrying fluid and 750# of 100 mesh and 9744" of 20/40 sand as proppant. 71 BDLS of gelled diesel was used as a flush. Prior to pumping, equipment and lines were tested to 7400 psi. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. f"~"k~' Cfi ~ ~i~:'~' ~'~ .... ~:.m: '.~."::~;~ . '.. ,~,:[ _. _~.,c~.~.~~ KUPARUK , .':0 Date 12 / 6 / 85 Signed ~"~ ~ Title OPERATi ON$ COOPED i NAI(Ji~ The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate RETURN TO: ARCO Alaska, Im Post Office uox 100360 Anchorage, Alaska 99510-0360 Telepho~]e 907 276 12:15 2~,CO A.[,ASK&~-: INC. KUPARUK OPERATIONS ENGINEERING _ RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE:il-19-85 TRANSMITTAL NO:5452 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/ SCHL/ CET'S/ ONE * OF ~ACH 1R-4 ~ 09-22-8.5 2A-16 ~ 09-05-85 2~.- 12 / U9-24-~5 3C-2~ 09-30-85 3J-2 ~ 09-19-85 RUN ~1 6755-8302 RUN %1 8643-9808 ~UN #1 7~00-9330 ~UN ~1 4750-7440 RUN %1 7647-9338 Rk'CEIPT ACKNOWLEDGED: DISTRIBUTION: BPA~ DRILLING*BL ~. PASHER B. CURRIER L. JOHNSTON EXXON C~EVBON ~IOBIL PHILLIPS OIL D & M NSK CLERK*~L J. RATHMELL DATE: STATE OF ALASKA*BL SOHIO /S~h UNION VAULT/ANO*FILMS ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfiel~lCompany ARCO Alaska, Incx-% Post Office =ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ._ RETURN TO: -',~ ~.-' --~,?-~ ~ .' .: -- TRANSMITTAL NO: 5422 ARCO* ALASKA, INC. KUPARUK_. OPERATIONS ENGIN~-'~-'RING RECOKDS CLERK ATO-1115B P.O. BOX 100360 ANChOKAGE, AK 99510 TRANSMITTED HERE54IT~ APE Th~ FOLLOWING ITEMS. PLF. A$~: ACKNOWLEDGE R~'.CEIPT AND RETURN ON~ SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/SCHL OPEN HOLE (ON~ * OF EACH) " DIL/SFL-GR ~' 5" DEN/NEU ?\'~2" DEN/NEU PORO \~5" D~:N/N~.'U KAW ' ~2"~ DEN/N~U ~W . CYBE~OOK 3A'3 ~5" DIL/SFL-G~ / ~5 DEN/NEU PORO ; ~2" D~N/NEU PORO ~5' D~N/NEU / ~2" DEN/NEU ~W ~X~,' CYB~OOK BHC SONIC-GR BHC SONIC-GR / 1R-4 DIL/SFL-GR ~ 2 DIL/SFL-GR /'~ ~% 5" DEN/NEU POR ~ ~2" DEN/NEU PORO ~" DEN/N~U ~W '2" DEN/NEU ~W ~ ~ CYBE~OOK 09-24-85 RUN #1 3966-8634 09-24-85 RUN #1 3966-8634 09-24-85 RUN #1 7850-8609 09-24-85 RUN #1 7850-8609 09-2~-~5 I{UN ~1 7~50-8609 09-24-85 I~UN #1 7850-8609 09-24-85 RUN #1 7850-8500 09-14-85 RUN #1 3890-8268 09-14-85 RUN #1 3890-~268 09-14-85 RUN ~1 3890-8242 09-14-85 t{UN ~1 3890-~242 09-14-85 t{UN #1 3890-8242 09-14-85 RUN #1 3890-8242 09-14-85 RUN ~1 7550-8219 09-15-85 i43N #1 3890-8270 09-15-85 RUN #1 3890-8270 09-17-85 RUN #1 4297-~336 09-17-85 RUN #1 4297-8336 09-17-85 ~UN #1 4297-8310 09-17-85 RUN #1 4297-8310 09-17-85 RUN #1 4297-8310 09-17-85 RUN #1 4297-8310 09-17-85 RUN #1 7600-8287 KECEIPT ACKNOWLEDGED: DIS%'KIBUTION: BPAE DkILLING*DL w. PASHER B. CURRIER L. JOHNSTON ~XXON CHEVRON MOBIL PHILLIPS OIL D & M*BL NSK CLEi<K*BL J. RATBI4ELL*BL / r,',,'.,-.,,'..-,, ,,~.%/ ) - D./,j~/~.~.u: / ~.~OV U ~, ~' .A~:k~ Oi~ ~ G~ Cons 6ommissior, STAT~ OF SOHIO /SE UNION VAULT/~O*FI~S ARCO Alaska. Inc. I$ a Subsidiary of AtlanticRichlieldCompan¥ ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 23, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-4 Dear Mr. Chatterton' Enclosed are the Well Completion Report and 1R-4. Tubing details will be submitted when completed. If you have any questions, please call me Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L27 Enclosures gyroscopic survey the well has been at 263-4944. for ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany U II I u I I1 Fl I. STATE OF ALASKA ---~ ALASKA~ . AND GAS CONSERVATION CC ~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDEDX{~] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-178 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21407 4. Location of well at surface 9. Unit or Lease Name 33/4' FNL, 137' FWL, Sec. 20, T12N, R10E, UM LOCATIONSi Kuparuk River Unit At Top Producing Interval VERiFiED i 10. Well Number 1/463' FSL, 1265' FWL, Sec. 20, T12N, RIOE, UM II~ 1R-/4 Surf. At Total Depth J 11. Field and Pool 109/4' FSL, 1406' FWL, Sec. 20, T12N, R10, UN B.H~_____~I Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Ku@aruk River 0i I Pool 82' RKBI ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 09/11/85 09/17/85 09/18/85I N/A feet MSLI N/A 17. Total-Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8/4/40'MD, 6863'TVD 8339'1vD, 678/4'TVD YES ~ NO []I N/A feet MD 1600' (approx) 22. 'Type Electric or Other Logs Run DI L/GR/SP/SFL, FDC/CNL,Cal ,CET,GCT 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 115' 24" 250 sx CS il 9-5/8" 36.0# J-55 Surf 4297' 12-1/4" 1190 sx PF "E & 425 sx PF "C" 7" 26.0# J-55 Surf 8427' 8-1/2" 300 sx Class "G" & 250 sx PF "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) None , N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I · Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHoKE SIZE 1GAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Alaska 0ii & Gas p, ........ ,._, · Form 10-407 Submit in duplicate Rev. 7-1-80 TEMP2/WC44 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7824' 6390' N/A Base Kuparuk C 7934' 6473' Top Kuparuk A 8098' 6597' Base Kuparuk A 8251' 6715' 31. LIST OF ATTACHMENTS' ~ ..... ~, ....... .,, ~.~ copies) t 32. I hereby certify that the foregoingI'strue and correct to the best of my knowledge Signed "~~ _)~~ Title Associate E.gineer Date //- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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. Item 28' If no cores taken, indicate "none". ~~~:~}.~or~t~:~ g ~ d: b . ~mmai ~:on ~ fo~ fo giving. Inclusive dates '~ly;. DiSt,~t : : ~ : :/:.~:~ :: :: ~ - I~.n~. pa.~ or borough ITM :: I Alaska AlaS~ :.:~:: ~.: : :~ ::: :: ~: ::: !: ::: North Slope Borough 5:: ' ILea~ or Unit lWell Field no. Kupa~k River :' I ~L 25635 I 1R-4 Au~. or W.O. no. llTltle "- ~ - ~g 604542 I Drill I Doyon 9 50-029-21407 Operator ]ARCO W.I, ARCO Alaska, Inc. 56.24% Spudded or W.O. begUnspudded IDate 9/11/85 ]Hour 1100 hrs. IPri°r ·tatus if a w'O' Date and depth as of 8:00 a.m; 9/12/85 9/13/85 9/14/85 thru 9/16/85 Complete record for each day reported 16" @ 115' 2415', (2300'), Navi Drl'g Wt. 9.5, PV 15, YP 15, PM 9.0· WL 8.8, Sol 9 Skid rig f/1R-3 to 1R-4, NU diverter, Accept. rig @ 1000 hfs, 9-11-85. PU BHA, Spud @ 1100 hfs, 9-11-85. Drl f/115'-2415'. 2064' o, · 2222' , 9.1 16" @ 115' 4310', (1895'), Short Trip Wt. 9.5, PV 16, YP 21, PM 9.5, WL 8.0, Sol 9 Navi drl f/2415'-3515', trip f/BHA. Drl f/3515'-4310'. CBU, short trip. 2536', 21.7°, S19.75E, 2523 TVD, 104 VS, S100, E28 2978', 29.5°, S10.75E, 2920 TVD, 297 VS, S286, ES0 3475', 39.0°, S15.75E, 3324 TVD, 584 VS, S566, El50 3641', 41.6°, S14.75E, 3451TVD, 692 VS, S669, E178 4280', 43.7°, Sll.75E, 3916 TVD, 1129 VS, S1096, E280 9-5/8" @ 4297' 7920', (3610'), NaVi-Drl'g Wt. 9.9, PV 16, YP 9, PM 9.5· WL 7.0, Sol lZ Fin short trip· C&C, POOM. RU & rn 104 ]ts, 9-5/8", 36#, J-55 BTC csg w/FC ~ 4212' FS @ 4297' Cmt w/l190 sx PF "E", followed by_425 sx P~ "C". CIP ~ 1815 hfs, 9/13/85. t~ MTdrl, NU &tst BOPE':: RIH, DO FC, cmt, FS + 10' new hole. Conduct formation tat'to 12.5 ppg EMW. POOH· PU Navi-Drl, drl & surv 8½" hole to 7920'. 4502'· 46.4°, S13.75E, 4073 TVD, 1285 VS, 1249S, 315E 5130'· 48.9°, S19.75E, 4500 TVD, 1745 VS, 1692S, 442E 5606'· 48.2°, S19.75E, 4816 TVD, 2099 VS, 20248, 564E 6392', 45.2°, 821.75E, 5352 TVD, 2674 VS, 25618, 772E 6767', 44.2°, S21.75E, 5619 TVD, 2937 VS, 2806S, 870E 7525', 43.0°, 823.75E, 6168 TVD, 3458 VS, 3288S, 1071E The above is correct Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Finsl Report" should be submitted also when ope~l~flons are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, repo.,'[ completion and representa.t.i.ve test data in blocks provided. The "Finsl Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District IICounty or Parish State I Alaska Alaska North Slope Borough Field Lease or Unit Well no. Kuparuk River ADL 25635 1R-4 Auth. or W.O. no. Title AFE 604542 Drill Doyon 9 API 50-029-21407 Operator IA.R.Co. W.I. rrotal nurnber of wells (active or inactive, on thisI ARCO Alaska, Inc. 56.24% Icost center prior to plugging and labandonment of this well Spudded or W.O. begUnspudded [Date 9/11/85 ]Hour i 100 hrs. IPrl°r status If a w'O' Date and depth Complete record for each day reported as of 8:00 a.m. Old TD Released rig 9/17/85 9/18/85 9/19/85 1700 hrs. Classifications (oil, gas, etc.} Oil Producing method Flowing 9-5/8" @ 4297' 8361', (441'), RU Schl Wt. 9.9, PV 14, YP 8, PH 9.0, WL 7.2, Sol 12 Navi-drl 7920'-8361'. Lost 1000 psi pmp press. POOH wet. Schl. 8060', 40.6°, S20.75E, 6567 TVD, 3814 VS, 3618S, 1206E RU 7" @ 8427' 8440', (79'), Rn'g csg Wt. 9.9, PV 14, YP 8, PH 9.0, WL 7.2, Sol 12 Log DIL/GR/SP/SFL f/8344'-4300', FDC/CNL f/8344'-7600' & 4600'-4300', CAL f/8344'-4300', RD SOS. RIH, drl 8361'-8440', short trip, POOH, LD DP. RU & begin rn'g 7", 26#, J-55 BTC csg. 7" @ 8427' 8440' TD, 8339' PBTD, RR 9.9 ppg NaC1/NaBr Rn & lnd 199 its, 7", 26#, J-55 BTC csg w/FS @ 8427' w/FC @ 8339'. Cmt w/300 sx C1 "G" w/6% FDP-344 & .3% HR-7. Displ w/brine. Bump plug. CIP @ 1235 hrs, 9/18/85. Tst csg to 3000 psi; OK. Set slips, cut csg, instl pack-off. NU tbg head & tamp tree. Tst pack-off to 3000 psi. RR @ 1700 hrs, 9/18/85. Move rig to DS 3F-1. Arctic Pak w/250 sx PF "C" followed by 55 bbls Arctic Pak , INew TD I PB Depth 8440' 8339' PBTD IDate J Kind of rig 9/18/85 Rotary I! Type completion (single, dual, etc.) Single Official rese~oir name(s) Kuparuk Sands Potential test data 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 is correct FOR W.S. CO~'~GDO?-! ~ For form preparation and_ distribution, Drilling Superintendent I I ~UB. SURFACE DIRECTIONAL SURVEY ~]UIDANCE ~]ONTINUOUS [~OOL Company Well Name ARCO ALASKA INCORPORATED 1R-4 (334'. FNL., [37' FWL, g20. T12M. RlOF.. ~TM _ Field/Location ,~~, NORTH SLO,,Pg, ALASKA Jol= Reference No. ~FACRE Oat_....~e 06-OCTOBER- 1985 Computed KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1R-4 KUPARUK NO~TH SLOPE,&LASKA SURVEY DATE: 22-SEPT-85 ENGINEER: H~LFACRE METHODS OF COMPUTATION TOOL LOC~TION: TANGENTIAL- ~VERAGED DEVIATION AND AZIMUTH , . INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. gIST. PROJECTED ONtO A TARGET AZIMUTH Of S~UTH 18 DEG ~ MIN EAST COMPUTATION ARCO ALASKA, iNC. 1R-4 KUPARUK NORTH SLOPE,ALASKA iNTERPGLATED VALUES TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MZN FOR 0.00 0,00 -82,00 0 0 100.00 100.00 18,00 ' 0 16 200.00 200.00 118,00 0 20 300.00 300.00 218.00 0 23 400.00 399.99 317.99 0 21 500.00 499.99 417.99 0 18 600.00 599.99 517.99 0 13 700.00 699.99 617.99 0 15 800.00 799.99 717.99 0 20 900.00 899.99 817.99 0 22 1000.00 99'9.98 917.98 0 21 1100.00 1099.98 1017.98 0 19 1200.00 1199.98 1117.98 0 18 1300.00 1299.98 1217,98 0 18 1400.00 1399.98 1317.98 0 23 1500.00 1499.97 1417.97 0 36 1600.00 1599.97 1517.97 0 32 1700.00 1699.96 1617.96 0 23 1800.00 1799.96 1717.96 0 34 1900.00 1899.96 1817.96 0 40 2000.00 1999.94 1917.94 2 0 2100.00 2099.71 2017.71 5 22 2200o00 2198.94 2116.94 8 35 2300,00 2297.32 2215.32 1Z 9 2400.00 2394.32 2312.32 15 56 2500.00 2489.33 2407.33 20 17 2600.00 2581.79 2499.79 24 24 2700.00 2671.61 2589.61 26 37 2800.00 2761.35 2579.35 25 43 2900.00 2851.32 2769.32 26 48 N 0 0 N 53 8 N 32 15 N 53 34 S 78 1 S 43 25 S 2 31 N 78 10 N 3'7 1 N 2 22 O~TE: 3-0CT-85 EVEN 100 mEET OF PAGE 3000.00 2939.24 2857.24 30 11 3100.00 3024.53 2942.53 32 29 3200.00 3107.62 3025.62 35 28 3300.00 3187.12 3105.12 38 43 3400.00 3265.40 3183.40 37 49 3500.00 3343.72 3261.72 39 32 3600.00 3419.63 3337.63 41 24 3700.00 3494.16 3412.16 42 16 3800.00 3567.33 3485.33 43 31 3900.00 3639.57 3557.57 43 56 DATE OF .SURVEY: 22-SEPT-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE MEASURED OEPTH VERTICAL DOGLEG RECTANGULAR SECTION SEVERITY NORTH/SOUTH FEET DEG/IO0 FEET 0,00 0.00 -0.12 0,32 -0,57 0.46 -1.03 0.41 -0.97 0.34 -0.55 0.31 -0.12 0.25 0.01 0.56 -0.43 0.25 -1.06 0.27 0.00 N 0.07 N 0.41 N 0.94 N 1.08 N 0.81 N 0.39 N 0.18 N 0.50 N 1.10 N -1.45 0.43 1.61 N -1.12 0.16 1.43 N -0.59 0.33 0.91 N -0.41 0.06 0.58 N -0.30 1.72 0.31 N 0.66 0.24 0.64 S 1.44 0.30 1.56 S 1.82 0.38 2.12 S 2.31 0.27 2.77 S 2.06 0.27 2.85 S N 72 15 E S 34 41 E S 28 37 W S 71 52 w S 16 36 W S 1Z 53 E S 46 48 W S 2 16 E S 75 38 w S 87 45 W S 10 17 W S 4 14 E S 14 9 E S 13 57 E S 21 42 E S 21 25 E S 17 38 E S 15 18 E S 14 37 E S 1~ 2 E S 11 21 2 S 13 11 E S 14 ZO E S 13 48 E S 15 22 E S 16 33 E S 15 39 E S 14 58 "- S 13 25 : S 13 21 E 2~86 3.64 4.01 9.04 3.04 10.49 21.11 3.15 22.55 38.96 3.93 39.54 63.17 4.22 62.24 94.21 4.26 91.10 132.21 4.81 126.92 176.12 0.74 169.10 220.18 1.09 211.72 263.73 2.90 254.04 311.13 3.46 362.98 2.90 418.47 4,28 478.96 1.57 541.02 1.05 503.14 3.17 668.20 1.54 734.79 1.25 ~02.78 0.54 871.70 0.41 COORDINATES EAST/WEST FEET 0,00 E 0,17 W 0,59 W 0,45 W 0,18 E 0,69 E O, 82 E 0,57 E 0.15 E 0.05 W HORIZ. DIST,' FEET~, ",0'. 00. ~,~ 0~'1'8. N 67 0.,;7i! N 55 1~'0'4, 'N 25 '1'06 N 40 0'91,'N 64 0.60 N 72 0.53 N 17 1.10 N 2 300.45 S 351.58 S 405.47 S 464.32 S 524.70 S 584.53 S 646.91 S 711.25 S 777.36 S 844.62 S DEPARTURE AZIMUTH DEG MIN 0 E 35 W 2 W 36 W 29 E 25 E 24 E 47 : 3 3 ~1 82.20 E 311,49 S 15 18 E 92,66 E 363,58 S 14 45 E 106,39 E 419,20 S 14 42 E 121.05 E 479.84 S 14 36 E 136,06 E 542,05 S 14 32 E 152.95 E 604.21 S 14 39 E 171.50 E 669.25 S 14 50 E 188.97 E 735.93 S 14 ~2 E 205.56 E 804.08 S 14 48 E 221.61 E 873.21 S 14 42 E 3,07 W 5,05 S 37 23 W 3,02 W 10.92 S 16 2 W 1,05 W 22.58 S 2 39 W 4.43 E 39.78 S 6 23 E 12.89 E 63.56 S 11 42 E 24.51 E 94.34 S 15 3 E 37.26 E 132.27 S 16 21 E 49.51 E 176.20 S 16 1° E 60.95 E 220.32 S 16 ~ 71.64 E 263.95 S 15 44 0,26 E 1,63 N 9 10 E 0,78 E 1,63 N 28 41 E 0.87 E 1,26 N 43 58 E 0.47 E 0.75 N 38 51 E 0.00 E 0.31 N 0 24 E 0.17 E 0.66 S 15 12 E 0.13 W 1.56 S 4 46 W 0.62 W 2.21 S 16 15 W 1.03 W 2,95 S 20 25 W 2,09 W 3.53 S 36 14 W COMPUTATION ARCO ALASKA, INC. 1R-4 KUPARUK NORTH SLOPE,ALASKA INTERPOLATEO VALUES FOR EVEN IO0 TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE VERTICAL DEVIATION AZIMUTH SECTION DEG MIN DEG MIN FEET 4000.00 3711.49 3629.49 4100.00 3783.42 3701.42 4200.00 3855.71 3773."71 4300.00 3928.11 3846.11 4400.00 4000.11 3918.11 4500.00 4069.63 3987.63 4600.00 4138.59 4056.59 4700.00 4207.19 4125.19 4800.00 4275.69 4193.69 4900.00 4344.25 4262.25 44 1 S 13 7 E 940.93 43 50 $ 13 1 E 1010.13 ,43 34 S 12 44 E 1075.94 43 32 S 12 22 E 1147.61 44 59 S 12 24 E 1216.64 46 1T S 12 51 E 1!88.19 46 36 $ 14 4 E 1360.35 46 46 S 15 37 E 1433.02 46 43 S 15 39 E 1505.81 46 48 S 15 37 E 1578.54 5000.00 4412.$9 4330.59 5100.00 4479.86 4397.86 5200,00 4545.78 4463.78 5300.00 4612.25 4530.25 5400.00 4679.36 4597.36 5500.00 4746.52 4664.52 5600.00 4813.40 ~731.40 5700.00 4880.18 4798.18 5800.00 4947.72 4S55.72 5900.00 5016.37 4934.37 47 6 S 15 49 E 1651.47 48 26 S 15 24 E 1725.44 48 49 S 19 21 E 1800.63 48 3 S 20 12 E 1875.30 47 46 S 20 6 5 1'949.38 47 56 S 19 57 E 2023.44 48 2 S 20 0 E 2097.73 48 9 S 20 1 E 2172.12 46 44 S 20 9 E 2245.82 46 44 S 20 '9 E 2318.49 6000.00 5084.70 5002.70 6100.00 5152.39 5070.39 6200.00 5219.46 5137.46 6300.00 5286.76 5204.76 6400.00 5356.66 5274.66 6500.00 5427.37 5345.37 6600.00 5498.76 5416.75 6700.00 5570.48 5488.48 6800.00 5642.32 5560.32 6900.00 5714.35 5632.35 47 0 S 20 7 E 2391.45 47 38 S 20 14 E 2465.01 47 56 S 20 22 E 2539.12 46 58 S 20 22 E 2613.02 45 5 S 21 11 5 2684.45 44 45 S 21 26 E 2755.04 44 15 S 21 38 E 2824.94 44 10 S 21 34 E 2894.49 43 55 S 21 38 E 2963.92 43 44 S 21 34 5 3033.16 7000.00 5786.80 5704.80 7100.00 5859.61 5777.61 7200.00 5932.79 5850.79 7300.00 6005.60 5923.60 7400.00 6077.80 5995.80 7500.00 6150.60 6068.60 7600.00 6223.24 61~1.84 7700.00 6297.67 6215.67 7800.00 5372.40 6290.40 7900.00 6447.41 6365.41 43 30 S 21 36 E 3101.94 43 5 S 21 39 E 3170.37 43 3 S 22 1 E 3238.38 43 37 S 23 1 E 3306.71 43 36 S 23 20 E 3375.61 43 6 S 23 9 E 3443.89 42 ~3 S 22 40 E 3511.73 42 3 S 22 14 5 3578.97 41 23 S 21 41 E 3645.27 41 26 S 21 32 E 3711.27 3-0CT-85 PAGE DATE OF SURVEY: 22-SEPT-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 82.00 ~T FEET OF M:ASURED DEPTH DOGLEG RECTANGULAR COORDINATES SEVERITY NORTH/SOUTH EAST/WEST DEG/IO0 FEET FEET 0.31 912.25 S 237.51 E 0.72 979.92 S 253.21 E 0.58 1047.27 S 268.63 E 0.96 1114.62 S 283.59 E 2.54 1182.42 S 298.33 E 0.49 1252.54 S 314.11 E 2.05 1323.05 S 330.65 E 0,17 1393.27 S 349,68 E 0.36 1463.44 S 369.31 E 0.14 1533.53 S 388.94 E HORIZ. DEPARTURE DIST. AZIMUTH FEET, DEG MIN 941 $ 14 35 E 10 $ 14 29 E 1081 !iS 14 23 E 1150', ~"S 14 16 E 12~9. S 14 9 E 129.~'33 S 14 4 E 1363'~.74 , S 14 1 E 1436,48S 14 5 ~ 1509.32 ,s 14 S ) 1582.08 S 14 13 ~ 1.19 1603.83 S 408.61 E 1.81 1674.57 S 430.28 E 1.23 1745.70 S 454.68 E 0.44 1815.94 S 480.12 E 0.30 1885.52 S 505.70 E 0.49 1955.14 S 531.06 E 0.35 2025.01 S 556.47 E 0.20 2094.94 S 581.95 E 0.55 2164.20 S 607.27 E 0.49 2232.45 S 632.33 E 1655.06 S 14 17 E 1728.96 S 14 24 E 1803.94 S 14 35 E 1878.34 S 14 48 E 1952.16 S 15 0 E 2025.98 S 15 11 E 2100,07 S 15 21 E 2174.27 S 15 31 E 2247.78 S 15 40 E 2320.29 S 15 48 E 0.76 2301.00 S 657.48 E 2393.09 0.52 2370.10 S 682.85 E 2466.51 0.34 2439.66 S 708.58 E 2540.48 3.28 2508.97 S 734.40 E 2614.25 0.24 2575.83 S 759.75 E 2685.54 0.51 2641.70 S 785.47 E 2756.00 0.36 2706.84 S 811.17 E 2825.77 0.48 2771.61 S 836.88 E 2895.20 0.31 2836.29 S 862.50 E 2964.53 0.77 2900.78 S 888.04 E 3033.66 0.29 2964.85 S 913.42 E 3102.37 0.22 3028.59 S 938.66 E 3170.72 1.04 3091.89 S 963.91 E 3238.66 1.36 3155.18 S 990.22 E 3306.92 1.24 3218.71 S 1017.b3 E 3375.75 0.50 3281.71 S 1044.69 E 3~43.98 0.53 3344.41 S 1071.21 E 3511.78 0.88 3406.74 S 1096.97 E 3579.00 0.36 3468.37 5 1121.82 E 3645.28 0.44 3529.84 S 1146.22 E 3711.28 S 15 56 E SI6 4 E S 16 11E S 16 18 E S 16 26 E S 16 33 E S 16 40 E S 16 48 : S 16 5~ ) S 17 1 -E S 17 7 E S 17 13 E S 17 18 E S 17 25 E S 17 32 E S 17 39 E S 17 45 E S 17 50 E S 17 55 E S 17 59 E ARCO ALASKA, INC. 1R-4 KUPARUK NORTH SLOPE,ALASKA C OM PUT ~T I ON DATE: 3-0CT-85 'INTERPOLATED VALU=S FOR 'EVEN 100 FEET OF TRUE SUB-S2A MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE VERTICAL DOGLEG DEVIATION AZIMUTH SECTION SEVERITY DEG MIN DEG M!N FEET DEG/iO0 40 53 S 21 1 E 3776.82 0.32 40 8 S 21 11 E 3841.85 1.23 39 24 S Z1 3 E 3905.55 0.82 38 29 S 20 27 E 3'968.12 0.00 38 29 S 20 27 E ~030,30 0.00 38 29 S 20 27 E 4055.17 0.00 8000.00 6522.85 6440.85 8100.00 6598.74 6516.74 8200.00 6675.75 6593.75 8300.00 5753.70 6571.70 3400.00 6831.98 6749.98 8440,00 6863,29 6781,29 PAGE ATE OF SURVEY: 22-SEPT-85 ELLY BUSHING ELEVATION: ENGINEER: HALFACRE MEASURED DEPTH RECTANGULAR NORTH/SOUTH FEET 3591.07 S 3651.83 S 3711.32 S 3769.94 S 3828.25 S 3851.57 S 3 $2,00 FY COORDINATES HORIZ. DEPARTURE EAST/WEST DIST. AZIMUTH FEET FEET DEG MIN 1169.87 E 3776.82 ', S 18 2 E 1193.30 E 3841,85 18 5 E 1216.30 E 390~ 55 ' $, 18 8 E 123~.39 E 396o~13 S 18 11 E 1260.14 E 4030,31 S, 18 13 E 1268.84 E 4055.19 .S 18 14 E ARCO ALASKA, INC. 1R-4 KUPARUK NORTH SLOPE,ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH 0.00 0.00 1000.00 999.98 2000.00 1999.94 3000.00 2939.24 4000.00 3711.49 5000.00 4412.59 6000.00 5084.70 7000.00 5786.80 8000.00 6522.85 8440.00 6863.29 COMPUTATION DATE: 3-0CT-85 INTERPOLATEO VALUES FOR EVEN 1000 FEET COURSE VERTICAL DOGL DEVIATION AZIMUTH SECTION SEVE DEG MIN DEG MIN FEET DEG/ SUB-SEA VERTICAL DEPTH 0 0 N 0 0 E 0.00 0 0 21 N 72 15 f -1.45 0 2 0 S 10 17 N 2.86 3 30 11 S '11 21 E 311.13 3 44 i . S 13 7 E 940.93 0 47 6 S 15 49 E 1651.47 1 47 0 S 20 7 E 2391.45 0 43 30 S 21 36 E 3101.94 0 40 53 S 21 1 5 3776.82 0 38 29 S 20 27 E ~055.17 0 -82.0~ 917.9 1917.94 285?.24 3629.49 4330.59 5002.70 5704.80 64~0.85 6781.29 DF MEASU EG RITY 100 .00 .43 .64 .46 .31 .19 .76 .29 .32 .00 RECTA NORTH FE 0 1 4 300 912 1603 2301 2964 3591 3851 PAGE 4 DATE DF SURVEY: 22-SEPT-85 KELLY BUSHING ELEVATION: 82.00 FT ENGINEER: HALFACRE RED DEPT NGULAR CD /SOUTH EA ET F .00 N · 61 N .01 S .45 S 8 .25 S 23 · 83 S 40 .00 S 65 .85 S 91 · 07 S 116 · 57 5 126 ORDINATES ST/WEST EET 0.00 E 0.26 E 3.07 W 2.20 E 7.51 E 8.61 E 7,48 3.42 9.87 8.84 HORIZ. DEPARTURE OI ST~ ,' .... AZIMUTH FEET :'~ :~<,DEG MIN COMPUTATION ARCO ALASKA, INC. 1R-4 KUPARUK NORTH SLOPE,ALASKA O,~TE: 3-0CT-$5 PAGE 5 DATE OF SURVEY: 2Z-SEPT-85 KELLY BUSHING ELEVATION: 82.00 ENGINEER: HALFACRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COUPS= VERTICAL OOGL DEVIATION AZIMUTH SECTION SEVE OEG MIN DEG MIN FEET DEG/ 0.00 0,00 -82,00 82.00 82,00 0,00 182,00 182,00 100,00 282,00 282,00 200,00 382,01 382,00 300'00 482,01 482,00 400.00 582,01 582,00 500,00 682.01 682.00 600.00 782.01 782.00 700.00 882,01 882,00 800,00 EG RECTANGULAR COORO PITY NORTH/SOUTH EAST/ 100 FEET FEET 0 0 N 0 0 F 0.00 0.00 0.00 N 0 13 N ,50 15 W -0.05 0.34 0.02 N 0 20 N 43 38 W -0,47 0,32 0,32 N 0 22 N 41 18 E -0.99 0.52 0.86 N 0 22 S 87 13 E -1,02 0.31 1.09 N 0 19 S 52 27 E -0.64 0.28 0.87 N 0 14 S 5 45 E -0.19 0.14 0.47 N 0 13 S 80 7 W 0.03 0.49 0,17 N 0 19 N 41 54 W -0.33 0.10 0,42 N 0 22 N 7 35 W -0.94 0.17 0.98 N 982,01 982,00 900,00 1082,02 1082,00 1000,00 1182,02 1182,00 1100,00 1282,02 1282,00 1200,00 1382,02 1382,00 1300,00 1482,03 1482,00 1400,00 1582,03 1582,00 1500,00 1682,03 1682,00 1600,00 1782,04 1782,00 1700,00 1882.04 1882,00 1800.00 0 21 N 57 55 E -1.44 0 20 S 44 27 E -1.21 0 18 S 11 50 W -0,86 0 18 S 67 41 W -0.41 0 20 S 48 46 W -0.36 0 35 S 14 6 E 0.48 0 33 S 43 22 W 1,36 0 22 S 16 57 W 1,72 0 32 S 72 27 W 2.32 0 39 S 89 1 W 2.12 0.61 1.57 N 0.40 1,51 N 0.60 0.99 N 0.20 0.61 N 0.56 0,40 N O. 07 0.46 S 0.28 1,44 S 1.49 2.01 S 0.30 2,72 S 0.11 2,84 S 1982,06 1982.00 1'900,00 2082,22 2082,00 2000,00 2182.87 2182,00 2100,00 2284,35 2282.00 2200,00 2387,21 2382,00 2300,00 2492,20 2482,00 2400.00 2600,23 2582,00 2500,00 2711,63 2682.00 2600.00 2822.91 2782,00 2700,00 2934.53 2882,00 2800,00 1 4 11 15 19 24 26 25 27 18 S 18 30 W 2.42 2.95 3.50 S 45 S 3 10 E 7.51 3,67 8.92 S 8 S 12 10 E 18,63 3,27 20,12 S 33 S 18 49 E 35.74 3,60 36,49, S 25 S 21 23 E 59.75 4.10 59.05 S 57 S 21 33 E 91,53 4.34 88.61 S 24 S 17 38 E 132.31 4.82 127.00 S 34 S 15 13 E 181.34 0.99 174.14 S 35 S 14 19 E 230,07 1,08 221.31 S 51 S 13 22 E 279.52 3,73 269.41 S 2,56 325,57 S 2,99 388,22 S 1,86 460,36 S 1,11 537.12 S 2,19 615.41 S 0,94 700,61 S 0.18 790.94 S 0.20 884.48 S 0.73 978.60 S 0.57 1071.65 S 3049.84 2982.00 2900.00 3168.79 3082.00 3000.00 3293.46 3182.00 3100.00 3421.02 3282,00 3200.00 3550.08 3382.00 3300.00 3683.59 3482.00 3400.00 3820.26 3582.00 3500.00 3958.97 3682.00 3600.00 4098.04 3782.00 3700.00 4236.26 3882.00 3800.00 31 30 34 22 38 35 37 56 40 37 42 6 43 36 44 4 43 51 43 35 S 11 13 E 335.53 S 14 32 E 400.59 S 13 49 E 474.90 S 15 30 E 553,90 S 16 45 E 535.42 S 15 2 r. 723,79 S 13 25 E 815,70 S 13 12 E 912.51 S 13 1 E 1008.78 S 12 32 E 1103.81 INATES HORIZ. WEST DIST. 0.00 E 0.10 W 0.52 W 0.54 W 0.07 E 0.6,2 E O. 82 E 0.65 E 0.22 E 0.04 W F E E T ' ,. . O::'a 0'0 ~ ,',, N :0:~ 10 'ii!' :N -02 1",09. 1-07 O · 9,4 '0, 6:7' 0.48 0.98 DEPARTURE AZIMUTH DEG MIN 0 76 ?'N 57 N 32 N 3 N 35 N 60 N 74 ,N 27 N 2 0 E 28 W 56 W 0 W 32 E 9 E 22 E 53 : 12 0.16 E 0.72 E 0.91 E 0.56 E 0.06 E 0.13 E 0.01 W 0.62 W O. 86 W 1.88 W 2.94 W 3.12 W 1.62 W 3.39 E 11.64 E 23.52 E 37.29 E 50.89 E 63.43 E 75.44 E 87,10 E 101,93 E 120,07 E 139,52 E 162,35 E 186,11 E 208.81 E 231.01 E 252.90 E 274.09 E 1.57 N 5 43 E 1.67 N 25 23 E 1.35 N 42 24 E 0.83 N 42 17 E 0.40 N 8 55 E 0.48 S 15 38 E 1.44 S 0 19 W 2,10 S 17 8 W 2.86 S 17 34 W 3.41 S 33 26 W 4.57 9.45 20.19 36.65 60.19 91.58 132.36 181.42 230.22 279.77 337.02 401.38 475.76 554.94 536.47 724.91 818.04 914.15 1010.75 1106.14 S 40 1 W S 19 16 W S 4 35 W S 5 18 E S 11 8 E S 14 51E S 16 21 E S 16 17 E S 15 5~' S 15 38 E S 14 58 E S 14 42 E S 14 37 E' S 14 33 E S 14 46 E S 14 52 E S 14 47 E S 14 38 E S 14 29 E S 14 20 E FT ARCO 6LASKA, iNC. 1R-4 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 3-0CT-85 INTERPOLATEO VALUES FOR EVEN 100 TRUE SUB-S~A MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 4374.54 3982.00 3900.00 4517.89 4082.00 4000'00 4563.24 4182.00 4100.00 4809.21 4282.00 4200.00 4955.18 4382.00 4300.00 5103.23 4482.00 4400.00 5254.66 4582.00 4500.00 5403.93 4682.00 4600.00 5553.02 4782.00 4700.00 5702.73 4882.00 4800.00 5849.90 4982.00 4900.00 5996.04 5082.00 5000.00 6144.06 5182.00 5100.00 6292.98 5282.00 5200.00 6435.91 5382.00 5300.00 6576.60 5482.00 5400.00 6716.06 5582.00 5500.00 6855.13 5682.00 5600.00 6993.38 5782.00 5700.00 7130.65 5882.00 5800.00 COURSE VERTICAL DEVIATION AZIMUTH SECTION DEG MIN DEG MIN FEET 4/, 22 S 12 46 17 S 12 46 42 S 15 46 42 S 15 46 52 S 15 48 27 S 18 48 14 S 19 47 46 S 20 48 2 S 20 48 9 S 20 15 E 1198.83 55 E 1301.06 27 E 1406.27 40 E 1512.51 35 E 1618.75 27 E 1727.86 59 E 1841.55 6 E 1952.29 0 ~ 2062.81 1 E 2174.15 9 E 2282.05 7 E 2388.56 18 E 2497.61 23 E 2607.86 18 E 2709.84 35 E 2808.64 35 E 2905.66 35 E 3002.12 36 E 3097.39 39 E 3191.26 46 37 S 20 46 58 S 20 47 51 S 20 47 9 S 20 45 5 S 21 44 19 S 21 44 11 S 21 43 57 S 21 43 31 S 21 42 59 S 21 43 17 S 22 43 32 S 23 42 53 S 22 42 11 S 22 41 22 S Z1 40 57 S 21 40 23 S 21 39 22 S 21 38 29 S 20 38 2g S 20 45 E 3284~43 19 ~ 3379.60 57 E 3473.05 20 E 3564.83 39 ~ 3653.71 1 E 3741.53 7 f 3827.69 1 E 3910.68 27 E 3990.60 27 5 W055.17 7267.49 5982.00 5900.00 7405.80 6082.00 6000.00 7542.93 6182.00 6100.00 7678.86 6282.00 6200.00 7812.80 6382..00 5300.00 7945.99 6482.00 6400.00 8078.06 6582.00 6500.00 8208.09 6682.00 6600.00 8336.15 6782.00 6700.00 8440.00 6~63.Z9 5781.29 PAGE DATE OF SURVEY: 22-SEPT-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE FEET OF SUB-SEA DOGLEG RECTAN SEVERITY NORTH/ DEG/IO0 FEE 2.39 1164. 0.57 1265. 0.74 1367. 0.29 1469. 0.25 1572. 1.67 1676. 0.76 1784. 0.32 1888. 0.26 1992, 0.19 2096. 0.71 2198. 0.61 2298. 0.25 2400. 2.58 2504. 0.39 2599. 0.44 2691. 0.45 2782. 0.51 2871. 0.13 2960. 0.52 3048. DEPTH GULAR COORO SOUTH EAST/ T FEET INATES HORIZ, WEST DIST. 93 S 294.51 E 14 S 317.00 E 48 S 342.48 E 89 S 371.12 E 29 S 399.78 E 86 S 431.06 E 24 S 468.49 E 25 S 506.70 E 17 S 544.52 E 85 S 582.64 E 23 S 619.76 E 28 S 656.49 E 70 S 694.16 E 13 S 732.61 E 54 S 768.98 E 65 S 805.15 E 02 S 840.99 E 86 S 876.61 E 61 S 911.74 E 04 S 946.38 E 1.00 3134. 1.38 3222. 0.52 3308. 0.54 3393. 0.23 3476. 1.23 3558. 1.07 3638. 0.91 3716. 0.00 3791. 0.00 3851. 58 S 981.52 E 39 S 1019.22 E 64 S 1056.16 E 62 S 1091.59 E 23 S 1124.94 E 07 S 1157.25 E 60 S 1188.17 E 12 S 1218.15 E 02 S 1246.25 E 57 S 1268.84 E 82.00 FT FEET lZO1-5~,~,.~,,:i',S 14 11 1304.2i~i":?~S 14 4 E 14 3 E 1516:',:,0Z' ,,,S 14 10 E 173~'38':,i" S2 14 24 E 1844'i7 . S 14 42 E 1955.0'6 S 15 1 ' 2065.25 , S 15 17 ) 2176.29 S 15 31 E 2283.93 S 15 44 E 2390.20 S 15 56 E 2499.05 S 16 7 E 2609.10 S 16 18 E 2710.89 S 16 28 E 2809.50 S 16 39 E 2906.35 S 16 49 E 3002.67 S 16 58 E 3097.82 S 17 6 E 3191.58 S 17 14 E DEPARTURE AZIMUTH DEG MIN 3284.66 S 17 23 E 3379.73 S 1T 33 E 3473.12 S 17 42 E 3564.86 S 17 49 E 3653.72 S 17 55 E 3741.54 S 18 i E 3827.69 S 18 5 E 3910.68 S 18 8 - 3990.61 S 18 11 . 4055.19 S 18 14 E ARCO ALASKA, INC. iR-4 KUPARUK NORTH SLOPE,ALASKA MARKER TOP BASE TOP BASE PBTD TD KUPARUK C KUPARUK C KUPARUK A KUPARUK A COHPUT~TZON DAT~: 3-0CT-~5 INTERPOL.&TED VALUES FOR CHOSEN HORIZONS ORIGIN= MEASURED DEPTH TVD BELOW K5 FROM KB 334' FNL, SUB-SEA 7824.00 6390.41 6308.41 7934.00 6472.95 5390.95 ~098.00 6597.22 6515.22 8251.00 6715-34 6633.34 8339.00 5784.23 6702.23 8440.00 6863.29 6781.29 PAGE DATE OF SURVEY: 22-SEPT-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 82.00 137 ' FWL RE~T NOR SURFACE LOCATION AT SEC 20 TJ2N RiOE, ANGULAr' 'IINATES T H/S OUT:Hi:i; ',T/WEST 3550.73 S 1:t:54.41 E 3650.62 S 1192.83 E 3741.3T S ,~.227.73 E 3792.68 S 1,246.87 E 3851.57 S: 1268.84 E FT UM ARCO ALASKA9 INC. 1R-4 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP ~UPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH MEASURED DEPTH ~ELOw KS 7824.00 7934.00 8098.00 8339,00 8440.00 3-~CT-85 SUMMARY FROM ORIGIN: TVD KB 6390.41 6472.95 6597.22 5715.34 6784.23 6263.29 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN PAGE 8 DATE OF SURVEY: 22-SEPT-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 82.00 FT SU 334' FNL, 137' FWL, S RECTA SUB-SEA NORT 6,308.41 348 6390.95 355 6515.22 355 6633.34 374 6702.23 379 6781.29 385 RFACE LOCATION AT EC 2~0~ T"12N' RIOE UM NGUL,~,~ C,O:.ORDINATE~; H/SOUTH ';E~ST/WEST 3.11 S 1127.67 E 0.73 S 1154.41 E 0.62 S 1192.83 E 1.37 S 1227.73 E 2.68 S 1246.87 E 1.57 IS 1268.8~ E ) 8440.00 5863.29 6731.29 4055.19 S 18 14 E ,, SCHLUMBEROER D I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 1R-4 F ! ELD KuPARuK COUNTRY USA RUN ONE DATE LOOOED 22-SEPT-8S REFERENCE. 000070848 I~I~fH 9000 WELL NAME: ~R-4 SURFACE LOCATION: 334' FNL, 137' FWL, S20, T12N, R10E, UM · HORIZONTAL PROJECTION SCALE ~- 1/I000 IN/FT ~ooo 1ooo -2000 -4000 BOOTH -SO00 -~ooo NEST :':' ..... l:'''; ;.: ~ ' : ~.~i~..:~-.~::.~:~:.~.~:~:~:~+~:~:~.~...~.~: ........ :-~---:---:--~ ............ ..;_.2_ ,...i.......~..~._+L..i...2 ~ ..... I...2...i...i_.L...~........i.._., ....... t.......i .......... .L..~...i ......... ; :'? ~ ~ : ~ : : i ' : ~ ; ~ ' 1--.;--; .... '. L..: .... : ...... : I ...... : ...... :": ....... ' ..... :' I .... 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J-'+'--~-'?'? ........... +-'f'-'~'-':-:"-~-~--':'--:---~-":-'-t-'!'--~---:---:-'!'--'-'"!".!-'?--!---: ~:~.~.~i::~!~!~::~::.~:~r.:~!::::~:::::::~:::::~::::::::::::::::::::::::::::::::::!:::::~:::::::::::::::::::::::~:~::::!:::::::::::::~::::.::::~:::::::.:~.:::: ::::::::: -zooo - ,ooo o ,ooo 2000 3000 4000 sooo EAST 1341. WELL NAME: 1R- 4 SURFACE LOCATION: -L~O00 -~000 0 0 · . .... ,:.i..h: ........ i-.-r-i---i-.-i---i--.!.i.-.i :.,~i::i: ~:~.~;:~- :,~':~. :: :::: . · "*'"!-'?"c"~'"~'"*'";'",'" ::::: 334' FNL, 137' FWL, S20, T12N, R10E, UM VERTICAL PROJECTION 1000 2000 3000 4000 5000 : ~-.;-..;'! :.Z: :I~:. * I "'T'-7-~-T-I : : : ~ - ........ ?~?~ i I : . . : . . : : : ..... . . . . · . . ..... ..... i-..i..;! .......... * .... ..... . : : ~ : : : : ........ : : ; : . : ~ ; : ......... .... . i ~ - . : !-! ! ~ : !1 : : i : ! : ~ -? ~-'t i~ +.:'i ...... It~I . "7"?"'7-T'"F"F"7"T'-:-" : ; ? ~ I i ; *, '-'. ...... '-. ................... .- ..... ;...:. ....... 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". .... - ' ................................. ~ ........ . ....... ~ ...................................... ~ ............ z .................................. . . : . , . : : . . ' - ............. : ......... ~.-: ....... 7-;---: ....... ~ ~ .............. : ...... ; ........... l ....... ' . ..... ; _..:._ ; ..... · ..: ............ ,-..i ................. t...:--..: :.;?:'":'"7-~"~ ...;.:.,xi;:z:::;xxx...:"~.:::iz;.:;...ziiX:zxx..c::..;,. PROJECTION ON VERTICAL PLANE 161. - 941. S6~EB IN VERTIC~ ~PTHS HORIZ SCRLE = i/1000 IN/FT Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: /~,' ~-/(k~-~:~_~ Date Required Date Received Remarks CompletiOn Report . Core Description Drill Stem Test Reports Production Test Reports Digitized Data . ARCO Alasi(a, inc.~''''~ Post Office. ,-~,x 100360 Anchorage, Alaska 99510-0360 Teiepi3one 907 276 1215 October 14, 1985 Mr. C. V. Chatterton Con~n,i ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are the September monthly reports for the following wells' 3A-2 3C-3 3J-4 WSP-6I (workover) L3-5 9-29 3A-3 3C-16 3J-5 L1-2 4-21 11-8 3A-4 3F-1 3J-6 L1-14 (workover) 4-30 11-9 3C-I 3F-2 1R-3 L2-13 4-32 11-11 3C-2 3J-3 1R-4 L2-26 9-24 15-7 16-17 If you have any questions, please call me at 263-4944. Si ncerely, Gruber Associate Engineer JG/tw GRUll/L62 Enclosures ARCO ~._,aska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA " ALASKA C.._ AND GAS CONSERVATION CO,..,~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-178 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 5o- 029-21407 4. Location of Well at surface 334' FNL, 137' FWL, Sec.20, T12N, RIOE, UM (approx) 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB 6. Lease Designation and Serial No. ADL 25635 ALK 2568 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1R-4 11. Field and Pool Kupa ruk Ri ver Fi el d Kuparuk River Oil Pool For the Month of. September ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1100 hrs, 9/11/85. Drilled 12-1/4" hole to 4310'. Ran, cmtd, & tstd 9-5/8" csg. Drilled 8-1/2" hole to 8361'. Ran logs. Continued drlg 8-1/2" hole to 8440'TD (9/17/85). Ran, cmtd, & tstd 7" csg. PBTD = 8339'. Secured well & ER ~ 1700 hrs, 9/18/85. 13. Casing or liner r~n and quantities of cement, results of pressur9 tests 16", 62.5#/ft, H-40 weld conductor set ~ 115'. Cmtd w/250 sx Cold Set II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 4297'. Cmtd w/1190 sx PF "E" & 425 sx PF "~'. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8427'. Cmtd w/300 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/8344' - 4300' FDC/CNL f/8344' - 7600' & 4600' - 4300' Cal f/8344' - 4300' 6. DST data, perforating data, shows of H2S, miscellaneous data None ~!aska Oil & Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Reporti~n 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 DRH/MR28 Submit in duplicate ARCO Alaska, inc. Posl Otlice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 9/26/85 Transmittal No: 5321 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 995i0 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape and Verification Listing: -~-~lR-3j ~70811 9/10/85 '~lR-4~' #70823 9/17/85 ~3A-2~ .#70808 9/7/85 -~3A-3 #70814 9/14/85 ~3C-3f #70807 9/6/85 ~3J-3" #70812 9/9/85 Receipt Acknowledged: B. Currier BPAE Chevron DISTRIBUTION Drilling W, Pasher Geolog~L,Johnston Exxon /-'-"--- f~ <,,,,, State o . Sohio Mobil Phillips Oil Union D & M NSK Drill Clerk J, Rathmell K. Tulin/Vault MEMORANOUM TO: THRU: FROM: State of Alaska ALAS¥~ O%L AND GAS CONSERVATION COivR~ISSION ¢. V. rton Cha±r~a~fi ./ ~-.;: / FILE NO: Lonnie C. Smith Cozmnis s ioner TELEPHONE NO: Bobby D. Foster?=p~ SUBJECT: Petroleum inspector September 16, 1985 D.BDF.82 BOPE Test ARCO- 1R-4 Permit No. 85-178 Kuparuk River Field Friday,, September 13, 1985: was completed at 11:15 tR~{. there were no failures. The BOPE Test began at 10:15 PM and As the attached BOPE Test Report shows, In summary, I witnessed the BOPE Test on ARCO's 1R-4. Attachment 02-00IA(Rev. 10/79) O&G #4 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Location: Sec. ~ TJ~/R./~ M ~ ~/~Casing Set @ ~~ ft. Drilling Contractor ~zP~-~9~ Rig # ~- Representative~~ Location,-General ~~ Well Sig~ ACC~ATOR'SYST~ General Housekeepin~g~ Rig ~~ Reserve Pit ~(~/~. Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Test Pressure Annular Preventer . / · ~of) Choke Line Valves H.c.R. valve Kill Line Valves Check Valve ---- Test Results: Failures O Full Charge Pressure~~ psig PreSsure After Closure/~Zp psig Pump incr. clos. pres. 200 psig ~ minSq/sec. Full Charge Pressure Attained: ~ min/~--sec. Controls: Master ?~ ~ Remote ~~ Blinds switch cover ~~ Kelly and Floor Safety Valves Upper Kelly / Lower Kell~ / Ball Type / Inside BOP / Test Pressure Test Pressure Test Pressure Test Pressure Choke Manifold, ~.~ Test Pressure No. Valves / ~ No. flanges ~ ~-- Adjustable Chokes ~ HYdrauically operated choke Test Time ! hrs. Repair or Replacement of failed equipment to be made within Commission office notified. days and Inspector/ Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor July 26, 1985 Mr. J. B. Kew in Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 1R-4 ARCO Alaska,~ Inc. Permit No. 85-178 Sur. Loc. 334'FNL, 137'FWL, Sec. 20, T12N, R10E, UM. Btmhole Loc. 1008'FSL, 1422'F~U.~, Sec. 20, T12N, R10E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing opera~ionS you may be contacted by a representative of the Department oz Environmental Conservation. Mr. Jeffrey B. Kewz~ Kuparuk River Unit 1R-4 -2- July 26, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. .Where a diverter system is required, please also notify this office 24 hours prior to commencing 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 witness present. Ver~_ truly y~o~.rs, C. V. ChattertOn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. Mr. Doug L. Lowery ARCO Alaska, Inc. ~ · Post Office Bo~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 16, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 1R-4 Dear Mr. Chatterton' Enclosed o are' An application for Permit to Drill Kuparuk 1R-4, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot o A diagram and description system o A diagram and description We estimate spudding this well any questions, please call me at of the surface hole diverter of the BOP equipment on September 14, 1985. 263-4970. Sincerely, J. B. Kew in Area Drilling Engineer If you have JBK/HRE/tw PD/L135 Enclosures RECEIVED J u L 2 2 Alaska Oil & i~as Cons. Oommissiorf ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA --' ALASKA O,- AND GAS CONSERVATION COI~,,¢ilSSION PERMIT TO DRILL 20 AAC 25.005 SINGLE ZONE MULTIPLE ZONE la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 334' FNL, 137' FWL, Sec.20, T12N, R10E, UM At top of proposed producing interval 1455' FSL, 1276' FWL, Sec.20, T12N, R10E, UM At total depth 1008' FSL, 1422' FWL, Sec.20, T12N, R10E, UM 5. ElevationRKB 84 ' in, feetpAD (indicateb~7, KB, DF etc.) 6. Lease designation and serial no. ADL 25635 ALK 2568 9. Unit or lease name Kuparuk River Unit 10. Well number 1R-4 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 1R-3 well 60' ~ surface feet 16. Proposed depth (MD & TVD) 8497' MD, 6855' TVD 18. Approximate spud date 09/14/85 14. Distance to nearest property or lease line miles 1008' @ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 45 o I (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1950 feet. 21 psig@__80oF Surface psig@ 6388 ft. TD (TVD) SIZE Hole Casing 24" 16" il 2-1/4''I 9-5/8" - 8-1/2" '7" Weight 62.5# 36.0# 26.0# 22. Describe proposed program: CASING AND LINER IGrade I Couplingl Length H-40 / Weld l SETTING DEPTH MD TOP TVD 80' 35' I 35' I 4244' 35' I 35' I 34' I 34' MD BOTTOM TVD , 4279'I 3884' I 8497'1 6855' I I QUANTITY OF CEMENT (include stage data) + 200 cf 1190 sx PF "E" & 425 sx PF "C" 270 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8497' MD (6855' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2838 psi Pressure calculations are based on virgin reservoir ' pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented.annuli through the permafrost interval. 1R-4 will be 60' away from 1R-3 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby certify that the foregoing/~s true and correct to the best of my knowledge SIGNED ./~~~ ~~'/} )~ ~:¢/~ TITLE Area Drilling Engineer The space bel6w for Commission use ~/- V / CONDITIONS OF APPROVAL Samples required [[]YES [~O Permit number APPROVED BY Fnrm 10401 {HRE) PD/PD135 Mud log required []YES ~J~O Approval date ~ 0.Q,7 / 235 / ~5 Directional Survey required (gLTEs []NO IAPl number s0- o't.~- z.~ Yo7 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE July 26, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 1R-4 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. c'O°ra9o t'°t~rolSSlo# ZOO0- . i I 1000 ' 2000 3000 ....... VERTICAL ~--eTION 4000 $ooo RECEIVED J !J L 2 '.':~ ~'~,::::~ .3.'zi & O-~s Cons. Commissiori . Hl:~I_Z:Clt~t,z~d_~. ? EOJE C Ti ON ............ SC/d.E ! I#, = 1000 FEET I R, 14ELL NO ~ 4: IH~-OPOSED ........KUPARUK-i -- --F [ [.L_D_,~' NORT~H_! SLOPE, ......... ALASKA EASTHAN t4H :[PSTOCK, ~t'1¢. ~ 000 _ D ] 000 2000 ' OOp SURFACE: LI)CATI 01t~ 334' FNL, SEC. 20, T1214. RIOE . . "S" TS .... DEC ..... 4 "ilfftN" E 3~I 4' (TO T~;~ET) ,. 2,00 4.00. _500. 600 _ ~00 7o'o ~0 ., ' .... ~ · - ' ~i ARCO ~ N,¢ ~ " : "~{ !:I:..! ' ~:',"i~./"!':~:'.~-.''''~ >; '?~ :~ '-; ~,~..,~,~.,~...~..~,..~ ~~~e~e i~. , , , , ; ~~ ~ ~[~T.~ ~I~ST~, inc. ...... ; ............. ~ .............. i ............. ~ .......... ~~ ....... , ................................... ~ ~ ~:/;:-~:':::.; ;'.. ~~to~ , NOT[, .......... ~. .,. ~727 $005 5173~' IIII i KUPARUK R I VER UNIT 20" DIVERTER SCHEMATIC 8 DE SCR I PT I ON i. 16' CO~XJCTOR. 2. TA~I(O STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LO¥1ER QUICK-C~CT ASSY. 5. TAI~O UPPER QUI CK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/I0' OUTLETS. 7. I0' HCR BALL VALVES W/lO' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF AFI~kA. AR PREVENTER. 8. 20" 2000 PSI A~UI.~ 6 MAI NTENANCE & OPERAT I ON. I. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE At~ULAR PREVENTER AF~) BLOW A I R THROUGH DI VERTER L I hl[$ EVERY 12 HOURS. CLOSE AI~NULAR PREVENTER IN THE EVENT THAT AN I~FLUX OF ~LL~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, MAI~ALLY OVERRIDE ANO CLOSE APPROPRIATE VALVE TO ACHIEVE DO~J~I~II~D DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES. Comm~s,~i~ < < ,m ' ] 6 [ h > > DIAGRAM #1 13-5/8" .50QO PSI RSRRA B(;~ ~TACK I. 16' - 2000 PSI TAI~(CO STARTING ~ 2. I1' - 3000 PSI ~ING 3. II' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRILLING SPCOL W/Q-ICKE KILL LIt~_S 6. 13-5/8' - 5000 PSI ~E RAM W/PIPE ~ ON TOP° ?. 13-5/8' - 5000 PSI AtOLl_AR ACQJVlJL, ATOR CAPACITY TEST I. CHECK Abl:) FILL AC~TDR RESERVOIR TO PR~ LEVEL WITH HYDRAULIC FLUID. 2. A~ THAT AC~TOR P~S,.~ IS 3000 PSI WITH 1500 PSI DC~T~ OF l~ R~OULATDR. 3. ~VE TI~o TFEN CLOSE: ALL UNITS SIIvIJLT~~Y AAD RECCRO THE TIE ~ PRE_$_qURE RE~W~INING AFTER 4. RECCRD ON NADC R~PORT, Tt-[ ACCEPTABLE LOME~ LIMIT IS 45 St[CCI~ CLO~ING TIME ~ 1200 PSI REMAINING 5 4 2 13. CEiVED 13-5/8" BOP STACK TEST I. FILL BCP STAC~ AI~ CHOKE MANIFOLD WITH ARCTIC DIESEl.. 2. O-ECX THAT ALL LOI~ ~ ~ IN ~EI_LHEAD ARE FUU_Y RETRACTED. SEAT TEST PLUG IN ~i. LJ-EAD WITH ~IN~ JT ~ RUN IN LO0<I)O/~ SCREWS. 3. CLOSE ANdJt. AR ~cVF-NTER ~ MANJAL KILL AN:) CHCKE LIE VALVES ADJACENT TO B~P STA(~,, ALL OTHER 4. PRESSURE UP TO 250 PSI ~ H~LD FCR I0 MIN. IN- CREASE PRE~ TO 3000 PSI AAD HCLD FCR I0 MIN. E~_F'~r) PRE~ TO 0 PSI. S. ~ ~ PREVENTER AhD MANUAL KILL AN2 CHCKE LI~E VALVES. CLOSE TOP PIPE RAMS AN] HCR VALVES ON KILL AhD CHOKE LI~ES. 6. TEST TO 2~0 PSI A~D 3000 PSI AS IN STEP 4. ?. CONTINUE TESTING ALL VALVES, LI~ES, AN] CHCKES WITH A 250 PSI L(~N AhD 3000 PSI HIGH. TEST AS IN STEP 4. DO NDT p~BlJR~ TEST ANY CHOKE TH~TY~sON_ NOT A FULL 9-OSINQ pOSITIVE SEAL CHOKE. F~I~N TEST CHCKE5 THAT DO NOT FULLY CLO~E. 8. OPEN TOP P~PE RA~S A~D CLOS~ BOTTC~ PIPE ~S. TEST BOTTC~ PIPE RAMS TO 2~0 PSI AhD 3000 PSI. 9. ~ BOTTC~ PIPE RA~S, eACX OUT RU~ING JT AN] PULL OUT OF HOLE. I0. CLOSE BLIND RAMS AN:) TEST TO 250 PSI AAD 3000 PSI: II .. (:PEN BLIN] RAMS AhD RETRIEVE TEST PLUG. MAKE SURE · MANIFOLD Arid LI~ES ARE FULL OF NGN-FREEZING' FLUID.-'SET ALL VALVES IN DRILLING POSITION. 12. TEST STAb/]PIPE VALVES, KELLY, KELLY CO(~S, DRILL PIPE SAFETY VALVE° AhD INSIDE BOP TO 250 PSI AN2 3~00 PSI. REO2RO TEST I~FDRMATION ON BLC~/OUT PREVENTER TEST FORM, SIGN, AhD ~ TO DRILLING SUPERVISDR. PERFDRM CCt,~:~ETE BOPE TEST AFTER NIPPLING UP AN] ~_EKI. Y THEREAFTER FUNCTIONALLY OPERATE BCPE DAILY. ' Alaska 0il & ~as Cons. COmmissio. Anchora,~,, 510084001 REV. 2 MAY 15, 19~5 ARCO Alaska, Inc' Post Office =ux 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 1R Pad Wells 1-16 . Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber . Associate Engineer JG/tw GRU6/L115 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany WELL I Y- 5,99t,050.09 Let. : 70°23'11.370'' x = 539,829.76 Long.= 149o40'33.808" ~ SEC. 20 -- I54'FNL, 139'FWL N 0 R T H I. WELL 2 Y= 5,990,990.16 Lei. = 70°23'10.7el" x = 5:59,829.82 Long. = 149°40'$$.816" '~ SEC. 20-- 214'FNL, 138'FWL WELL 3 ~= 5,990,930.24 Lat = 70°23'i0.192'' ~ ~ X = 539,829.78 Long. = 149040'33.826" SEC. 20 -- 274'FNL~ 138'FWL ,~ ~ WELL 4 Y= 5,990,870.26 Lot. = 70023'09.602'' ~m2 ) )3~ ~ X= 539,829.77 Long. = 149°~'33.836" ~)m ~4~,)/ SEC. 20-- 334' FNL, 137' FWL ~ ,c ,,~ WELL 5 Y= 5,990,870.21 Lot. = 70°2~'09.620" s : ~s~ X= 539,469.75 Long.= 149°~'44.377" ' ~ i SEC. 19- 352'FNL, 223'FEL I, WELL 6 Y= 5,990,930.21 Let. = 70°23'10.210'' ~ ~ x= 539~469.74 Long. = 149°~'44.368'' ~. ~ SEC. 19 -- 272' FNL~ 222'FEL WELL 7 ~= 5,990,990.23 L~I..= 70°Z3'10.800" X = 539,~9.76 Long. = 149°~'~.358" SEC. 19 ~ 212' FNL~ 222'FEL '- S~9'S~0 WELL 8 Y= 5,991,050.20 Lat. = 70°23'11.390" m X= 539,469.7~ Long. = 149°40'~.350" ~ .~ SEC. 19 -- 152' FNL, 221'FEL ~¢, ~ ,~ ' WELL 9 Y= 5,991,600.16 L~t. = 149040'44.259"70°23'16'8~" ~7 m a~ X: 559~ ~9.91 Long.: , SEC. 18 -- 398' FSL~ 216'FEL ~, WELL 10 y=5,991,660, ll L~t.= 70°23'17.389" x = 5~9~469.82 Long. = 149°40'~.253" SEC. 18- 458' FSL,216'FEL , ~ ~ WELL i ! ~= 5,991,720.17 L~t. = 70°2~'17.980" , X = 539,~9.81 Long. = 149°~'44.244" ' , ~,' SEC. I8 -- 518'FSL, 2IS'FEL =mmWELL 12 v= 5,99m,780.16 ~t. = 7~25'18.570" x = 539~469.78 Long. = 149°40'44.2~5" SEC. 18 -- 578'FSL~215'FEL DRILL SITE t R ,"=~oo' WELL 13 v= 5,99~,780.~s L~t. = 70°2~'~e.55m" , X = 539,829.73 Long. = 149°40'33.695'' AS-BUILT CONDUCTORL~ATi0NSSEC. 17 -- 576'ESL, 145'F~ WITHIN SECTIONS 17,18,19B20~TI2N,RIOE,U.M. WELL 14 Y=5,991,720. m3 Lot. = 70°23'17.961" X = 559,829.71 Long.= 149°40'~3.705'' NOTE: SEC.17 -- 516' FSL, 145'FWL COORDINATES ARE ALASKA STATE PLANE~ ZO,E ~.WELL ~5Y = 5,991,660.19 Lat. = 70023'17.371" SECTION LINE DISTANCES ARE TRUE. X= 539~829.71 Long. = 149°40'35.715'' HORIZONTAL 6 VE~ICAL POSITIONS PER L.H.D. SURVEYORS~ SEC. 17 -- 456'FSL, 144'FWL DOCUMENT NO. 129:NI9+69 NI7+25 WELL 16 Y=5,991,600.20 Let. = 70°23'16.781'' E 9+56 a E 15+25 X = 539~829.77 Long.= 1~9°40'33.722'' EL.50.39 EL.38.75 SEC. 17-- 396' FSL~ 144'FWL RV[YOR: I HEREBY CERTIFY THAT I AM PROPERLY :~ ........ VlImADIIV - ~l ~e~eee · eee~ele~ee · ~ DATE MAY 9~9a51 · ~ % F ROBERT 8E~ ~ ~ ~ CHECK LIST FOR NEW WELL PERMITS Company Lease & ~ell No. , ITE~ APPROVE DATE (1) Fee (2) Loc ' (3) Admin (~thru 12) . _ 10. (10 andF2) ' 12. (13 thru '21~ (22 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. '23. 24. 25. 26. 27. YES NO __ 3. Is well located proper distance from property line .,............. 5. Is sufficient undedicated acreage available in this pool ......... 6. Is well to be deviated and is wellbore plat included ............. ?. Is operator the only affected party .............................. 8. Can permit be approved before ten-day wait ....................... Does operator have bond in force Is a conservation order needed e®eeeee®.e.eeeeleeeeeeeee®eeeee®eeeeee Is administrative approval needed Is the lease number appropriate Is conductor string provided ........................................ ~-ff 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 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 wellbore separation proposed ............................ Is a diverter system required eeeeeeeeeeeeeeeeeeeeeee..eee®®e.eeeeeee Are necessary diagrams of diverter and BOP equipment attached ........ Does BOPE have sufficient pressure rating - Test to ~,~'~ psig .. Does the choke manifold comply w/AP1RP-53 (Feb.78) .................. Is the presence of H2S gas probable eeleeeeeeee~leee.eeeeeee.eeeeeeee Additional requirements eeeeeeeeeeeeeeeeeeeeeeeeeeeeee.eeeeeeeeeeeeee REMARKS O ~O Additional Remarks: fl/b Geology: Engipeering: JAL.~--~_ rev: 03/13/85 6.011 INITIAL CEO. UNIT' ON/OFF POOL CLASS STATUS AREA NO. SHORE ~ ,, Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LVP t~lt~,WOP VE~IFiCAmlON [,IS'rI~IG PAGE 1 ** TIPK HEADWR SERV?CF NAME DA~E :~5/09/24 ORIGIN TAPE Naif :0893 CONTIN[~ATION # :Ol PREVIOUS TaPF : CO~MFNTS :T,IRRARY TAPE ** FILM MEADFR ** FILE NAMF :MDTT .001 SERVICF NAME VERS!O~ ~ ~ATE ~ ~AXI~ll" LENGTH : 1024 FISE TYPB : DR~VTOUS FIbF ** INFPR~A~ION RECORDS ** ~NFM COWTMNTS CN : WN : ~R-4 FN : KUPA~U~ RANG: !,0~ ?OWN: SECT: ?0 COUN: ** COMMEWTS ** UNTT TYPE CATE SIZE CODE 000 000 0i6 065 000 000 004 06 5 000 000 008 065 000 000 004 065 000 000 004 000 000 002 065 000 000 0i2 065 000 000 006 065 000 000 004 065 UNiT TYPE CATE SIZE CODE 000 000 OOi 065 [,VP ~lO.WO? VEPlFICATinN LTS~ING PAGE ALASKA COMPUTING C~NTER COMPANY = ATLANTIC ~ICHFI~LD CONPANY WELL = 1~-4 FIELD = KIIPARU~ COUNTY = N~RTH SLOPE 50ROUCH STAT~ = ALASKA JOR ~U~BFR AT ,ACC: 7fl823 RU~ #1, DA?E LnG~ED: 17-SEP-85 LDP: M. OGDE~ CASING = q.b~5" @ 4~97.0' - BlT SIZE = ~.5" TO 8361.0' TYPE F[~U~D = P~LYM~R DEWS~TY = 9 9 LB/G R, = 4.450 ~ 47,0 DF VISCOSITY = 3~.~ ~ RMF - 4.910 , 63.0 Dr PH = 9~0 e~C = ~..460 ¢ 5~0 D~ F~tIID 1,0~$ : ?,~ C] R~ AT BHT = 1,560 ~ 1 , D~ ~ATRIX SANDSTONE ***** THIS D~TA ~{AS NOT BE~N D~PTH SHIFTED - OVER£,,AY$ FIELD PRINTS **~ LVP OIO,~!OP V~:~I~'ICATInN blSTI~l{; PAGE ******************************************************************************* · , , * * * * , * , * * * , * · SCHbUMRE~GMR L~G$ INCb!~DED ~TH TH~5 M~GNETIC TAPE~ * , · ~UAb ]MDI}CTION SPHER%C~LL¥ FDC!~$ED hOG (DIb) * , D~TA AVAILABbM{ 8336,0' TO 4~7,0' * · FORMATIO~ DENSITY COMPENSATED LOC (FDN) * · COMPENSATED NEUTRON · D~TA ~¥~I[,AgbE~ 4600,0' TO 4297,0' * , * ENTRY RhmC~S T¥~E SIZE ~EPR COD~ ENTRY 2 1 66 0 4 ! 66 l 8 4 ?~ 60 9 4 65 ,lin 16 1 66 l 0 1 66 0 DATUM SPECIFICATION gLOCKS MNEM SERVICE S~RVlCE tI~T APl AP! APl ~P! FILE SIZE SPb REPR pROCESS LVP OlO,H02 VILRiP'ICATION [,IS?lNG .PAGE 4 bOG TYPE FT O0 O00 OH~ O0 220 OH~ O0 ~20 OH~ O0 120 ~V O0 aAPI O0 310 ~A~I O0 310 ~N oO ~80 G/C3 00 350 C/C3 O0 356 O0 42o O0 ~00 PU ~0 ~PS O0 330 CPS O0 330 CLASS MOD NO, O0 0 0 d 1 O1 0 0 4 46 O 0 4 1 44 0 0 4 1 O1 0 0 4 1 01 0 0 4 O1 0 0 4 1 01 0 0 4 O2 0 o 4 1 01 0 0 4 1 O1 0 0 4 1 O0 0 0 4 1 O0 0 0 4, 1 31 0 0 4 1 30 0 0 4 CODE 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 (O It.) 000000000~ T 0000 00000000000000 00000000000000 00000000000000 00000000000000 898ooooooooo0o ooooooooooo oooooooooooooo oooooooooooooo 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 Sp RHOB ~PRI DEPT SP OF. 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O0 -999.2500 1 89~6 -g99' .999 '2500 .2500 -999,2500 3.0i98 -999.2500 -999.2500 -999.2500 ~,.02~7 -999.2500 '999,2500 '999,2500 1.8809 -999,2500 -999,2500 -999.2500 ~,1838 '099,!500 -999, 500 '999. 500 -999, ~0000 -99'9, 500 1'.~.376 '999, 500 -99'9 2500 -ggg:2500 . '2.3752 999, O0 -099.~g00 IbM CALI RNRA CALI RNRA, CALl RNRA CALI RNRA RNRA RN~A CAbI CALX RNRA CALl' RNRA ALI RNRA ,7159 4.2520 ,3328 ,1135 ,8691 4,0164 2,3674 '999,2500 '999,2500 , 500 -999,2500 3, ~74 -999,~ O0 ~999'2 O0 -999, -999,~500 -999, O0 -99q,, 500 ,99~'2659 2,3108 '9g:9,~500 -999, -999,~500 2,4553 :999,2500 999,2500 t, VP 01~.~0~ VER1FICATIDN LISTING PAGE 6 ~PHI -99q.9500 NCN5 DE~? 6600.~000 SFLU Sp -24.7451 CR ~HOB -~90,2500 DRHO ~P~I -.9q,~500 ~YCNb O£PT 6500 ~000 SFt. U SP '25:57~2 GR RHOB -q99.~500 DRHO NPHI -q99.2500 NCML OEPT 6400.0000 SFt. U Sp -28.~076 O~ RHOB -999.~500 DRHO NPHI ~g99.~500 NCN5 DEPT 6100.0000 SFLU Sp 20 72~5 OR RHOB -~99'~500 DRNO DEP? 6100,0000 SFbU SP ~25,.~545 ~R ~HOB -~99. 500 D~HO DEPT 6000 0000 SFLU SP ~'21i4951 ~R ~HOB ~999 ~500 DR,O NPHI 999 ~500 wC~b DEPT 5900,0000 SFLU RHOB -999,~500 DRHO Np~! -999.2500 ~CNI~ DEDT 5BO0.O000 ~FbU SP -20,8557 GR ~MOB -999,~500 DRHO WP~I -999.~500 NCNb nE~,? $~.oo oooo SFt,,U -q99.2500 WCNb -q99.~500 ?.8167 TLD 2.3713 YI.,M 2,~n4n6 106.2148 GR -q99.2500 CALl ..999, -999.2500 t4R/tT -999.2500 RNRA -999,2500 .q9g.25nO ~'CNb -g99.2500 . -999, O0 2148 OR =99 2500 CA -999* 2500 NR~T -q99 . 2500 RN~A =999. 2500 -99q~2500 FCNb -999,2500 ~,92~0 IbD . ~,80)0 Ib~ 2,85t8 i15,$273 ~R 999.~500 CALl -999,2500 -999,2500 ~]RAT -999,~500 RNRA -999,2500 -099.2500 PCNL -999.~500 101,7148 GR -999,250 CALl ..999. · 2500 RNRA -999, -999 2500 NR~T -999, -q99.2500 FCML -q99.~500 2 ~$'~I ThP ~,9905 IbM 3,0354 ]04' GR -99 ..2500 CALl: -999,2500 -~'99 2500 NR~T -999,2500 RNRA -999,2500 -999:2500 FCN5 ~999.2500 ],1457 YbD {,1189 IbM .~,~.,~,,~, ~. .,,,.~oo c~ .~,..,soo .2500 NRAT -999'2500 RNRA -999,2500 -999,.2500 PCNb -999,2500 .°'° 999,2500 NRAT -999.2500 RNRA ~ 3245 lbo 93,3186 IbM 3.3167 -999 2500 NRIT -99 ,2500 RNRA -'999, 5 0 -q99 2500 FCML -99 ,2500 ].2209 YI.,O ) 2268 Ib~ $, 50 -q9q .~5.00 NRAT -999 500 RNRA -999, -qg~: 500 ~CNL ,999,~500 3.0061Yb~ ~,0569Ib~' .!'0569 97..15~3 ~, .~ .~oo c~ .~ .~,$oo ..~.~ o ..~ -~:.~oo ...~ .~ .~oo -099.~500 FCNb -g9q.~500 9~.~773 ~R -99 .2500 CAL! .999.~500 QHOB -Ogq,2500 nR~O NpHI -q9q,~.500 ~.tC~)L SP -22i1514 ~R RHOB -ggg 2500 ~RHO NPHI -999 2500 NC~b DEPT 5300.0000 SFI.U SP -29 0264 GR RHnB -q99:~'500 DRNO ~P~I -999,2500 .CNL sp RHOB -990 ~500 q'PNI -999:2500 DEPT 5000,0000 SF~JU SP '23,7764 GR WHOB -999,~500 DRNO NPNI -999.~500 NCNb 8PDEPT 4~g,0000.. 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RNRA CALl RNRA ~NRA -999,2500 2,8596 -999,2500 -999,2500 2,9260 -999,2500 -999,2500 '99 , 500 '999,2500 2 I131 -999:500 '999,2500 77 -999:2500 ,99~'5510 2,6545 -999,2500 '99'9,~500 3,,0608 2999.2500 999,2~00 -999, -999, 2,7698 1~,6973 3,9553 LVm 010,HO'~ VERIFICATlO~v LISTING PAGE 8 Sp -20.7b07 GR RHO6 2.3127 DRHO 4pH! 4q,g199 NC~'6 8a,4023 CR -~,O06B NRAT DEPT 4400,0000 SFLU 3.5042 SP -27.'3232 ~R 67 OBqB RHOB 2.30~B DRHU -0~00~4 NRAT ~PHI 41.~109 NCNL 2020,6875 FCNL DEPT 4300.0000 SFLU SP -44.g25B ~R RHOB ~.19~5 ~RHO NpH! 40.t367 NC~II, 5.7195 Tbn 77.02~3 GR 0,0034 NRAT l~4a.6B'.15 rCN6 OEPT 4.~90 no00 ~FLU 2000.6875 SP 34' ObOB GR 5.~ ~R RHnB 2 !506 DR"O .:(4242 ~ 3774 NRAT gPUI 51 .4160 NCNL 1403..6875 FC~L ** FI6F, TRAILER ** ~'ILE NANE JEDTT ,001 SEDV,I'CR NAME : DATE : MAXI~L,I~ [,ENGT}i : 1024 NE~T FTL~ NAME ; EOF ** TAPF TR,AILER ** SEDVIC~: NA~E :EDIT DATE :~5/0~/~4 ORIG~N :0000 TAPE NAiF t0823 CONTINUATION NEXT T~PF NA~E AE~V'ICE ~A,~E :EDIT DATE 1B5/09/74 ORIGIN : REEb NA~E :~492~3 CO~TINIIATI'ON # ~EXT R~g[, NA~E ~ COMMENTS :Y,IBRARY TAPE EOF EOF B4. 4023 CA[,I 3 N 3.7B?¢ IbM 67.OggB CALI ].49~4 RNRA 525,8125 4.1179 IbM 7~,0273 ~AI,! 3.5334 RNRA 461.1406 B '7363 IbM 51!8242 CAI,.[ 9866 ~NRA 31 ,8906 1~,i270 3,5608 9,7207 3,8440 5.4382 11.4160 ,0007 2000,6875 8,9473 4,4B~
