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Home My WebLink About200-156STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS A 14 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ 44A pBdBgp,- tdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: WHIPSTOCK Q 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 200-156 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-21404-02-00 7. Property Designation (Lease Number): 8. Well Name and Number. KRU 1R -01B ADL 25640 ADL 25635 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field/Kuparukl River Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,611 feel Plugs measured 3756 feet true vertical 6,682 feet Junk measured None feet Effective Depth measured 3,688 feet Packer measured 3,557 feet true vertical 3,386 feet true vertical 3,294 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 feet 16 121' MD 121' TVD SURFACE 4,344 feet 95/81, 4,381' MD 3,868' TVD PRODUCTION 6,465 feet 7 6,500' MD 5,331' TVD Perforation depth: Measured depth: 3688-3706 feet All Perfs Plugged Off True Vertical depth: 3386-3398 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 3,628' MD 3,344' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - PACKER BAKER FP 3,557' MD 3,294' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 3688-3706 Treatment descriptions including volumes used and final pressure: Pumped 10 bbls 15.8ppg cement, squeezed 7bbls 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments (required per 20 MC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development 21 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSPE] 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: 319.041 Authorized Name: James OhOn Contact Name: William Long er contact Email: William.R.Long@cop.com Authorized Title: Staff CTD Engineer 19 Authorized Signature: Date Contact Phone: (907) 2634372 �y��1 : (/ V7-1- 9/9 f 9 RBDMS Form 10-404 Revised 4/2017 // o% /q AUG 15 2019 Submit Original Only 1R-101 SET WHIPSTOCK DTTM JOBTYP SUMMARYOPS START 6/19/19 ANNCOMM PERFORATE 7" CASING WITH 18'3-3/8" POWERFLOW HMX 6 SPF GUN. REQUESTED INTERVAL: 3688'- 3706'. GUN FIRED WITH GOOD INDICATION AT SURFACE. UNABLE TO FIND GR WEST SAK D @ 3655'. CONOCO ENGINEER IN TOWN USED BOTTOM COLLAR AT 3707' TO PUT LOG ON DEPTH. PERFORM SBHP SURVEY FOR 30 MIN. PRESSURE HELD AT 1334 PSI. MAX TEMP 74 DEGF 6/20/19 ANNCOMM SET TOP OF WHIPSTOCK AT 3688' IN 7" CASING. WHIPSTOCK ORIENTED ON HIGH SIDE (4 deg LOHS). 6/26/19 ANNCOMM RIH WITH CEMENTING BHA, TAG TOP OF WHIPSTOCK @ 3690' RKB, TRY TO DO INJECTION TEST, COULD NOT HOLD A STEADY INJECTION RATE WITHOUT GOING OVER INJECTION PRESSURE. BATCHED UP 15.8 PPG CEMENT, PUMPED 5 BBLS FW, 10BBLS 15.8 CMT, FOLLOWED WITH 15 BBLS FW AND 25 BBLS POWERVIS, SQUEEZED 7 BBLS INTO PERFS, DROP 5/8" BALL, CLEANED OUT DOWN TO 3685' RKB, CHASED CONTAMINATED CEMENT OOH SLOWING FOR ALL JEWELRY. WELL READY FOR SLICKLINE. 6/30/19 ANNCOMM SET 4.5" SLIP STOP CATCHER @ 3552' RKB; PULLED DMY @ 3504' RKB & SET OV. IN PROGRESS. 6/30/19 DRILLING Hook up to sows, pull sub & pits off well, move & stage rig on edge of 1 C -Pad, drop SIDETRACK stairs & landings, safe out areas around rig 7/1/19 DRILLING Pick reel off rig, laydown mast & perform inspections, wire brush well for Tubo -Scope SIDETRACK inspection, swap to 2-5/8" gripper blocks, change out pillow blocks bushing & spindles, removed stack, painted welds post Tuboscope inspection, picked & loaded 2-5/8" reel on rig, raised the mast post inspection 7/1/19 ANNCOMM PULLED DMY @ 2537' RKB & SET GLV; PULLED CATCHER @ 3552' RKB. JOB COMPLETE. 1R-101 Final CTD Schematic 18 on uctor 85# H-40 shoe a 7" Pedorelione end =one M76-339T Surface 36# J-65 slava at 4381' MD, 3868' TVD 3-12" Preductlon Tbo Jet Cul at 4715' MD Praducti 26# J5 window cut W 6479' MO (2000) T' CBL of 9-9-65 shored top of cement at BOW. Performed small squeeze atter milling window 1999. Top of 312" cement -T/90 Na CBL of 2-6-00 3-12" Production Liner 3# L-80 6243'-10915' XP liner -top packer Buckled liner 6470' MD Parted liner at 7213'? r '2" 12.6# LA0 HYD 503 0 3626' nm KBG-2 GLVs Q 2537', 3504' er FP Preduction Packer @ 3570' Nipple 0 3575'(3.813- ID) Updated: 164ul-2019 (WRL) Cameo KBMM-2 mandrels 812632', 3988', 5015', 5710', a 6175' OS nipple x16221' (ID= 2.913") BakerZXP packer at 6243' 3-1/2" Packer 8 screen al ]204' (2018) CTD Completion (2006) 2-3/8" linertop a16026' MD Whipstock at 6053' MD iR-101 11,871'MD: TD � 3678 -1 /2" x T' Thw-Tubing Mipslock -7/8" 6.5# LA0 Wedge 533 (0.125" Slots) 9879' MD, Sal OH OCLL w/ Dissolvable Bullnose 4051' MD: 2-71T xo 3-12" 3-12" 9.20 LA0 Wedge 511 (Solid) MDV MD: Seal Bore Deployment Sleeve Cameo KBMM-2 mandrels 812632', 3988', 5015', 5710', a 6175' OS nipple x16221' (ID= 2.913") BakerZXP packer at 6243' 3-1/2" Packer 8 screen al ]204' (2018) CTD Completion (2006) 2-3/8" linertop a16026' MD Whipstock at 6053' MD KUP PROD WELLNAME IR -01B WELLBORE 1R-01 COtlOCO✓1illipx Well Attributes Max Angle 8 MD TD 1'''' FIeIG Name W¢IIWre names Wellbore Status IV)) Mutant qcl in I.KB) AUas"LlrlC. NIIPARIIK RIVFR UNIT SnnJOJlanann P011ft �[nn ucinn 1RL1. wlYlma 103asz AN Casing Strings vw6d We-airsonwl CasngDeec""n Door) ID(In) T.N(MBl set Dean ("a' GOOepm (NUL.. widen ll -_dodo. TopmreY CONDUCTOR 16 15.06 380 1210 1210 62.50 H40 Welded ...__._......_.. ........................................................................ HANGER', 33.E-_ Casing Oesalimse OO ort in (in) Tapmose SN Deptin MB) SN Depth (read WtlLer(I Gratle Tap Tineas SURFACE 9518 8.76 37.0 4,WS 3,8675 36.00 J-55 Buttess Casing OescNptlan OO on 10(i.) Top ME) SO done(1KB) SSI Oepm (NOL.. WN.en(L,. Grade Top TBruE PRODUCTION POST 7 6.06 35.0 6,500.0 5,330.6 26.00 J-55 BTC SJT A Cables Determine Do (in) ID tial Top(kRB) SO Depth impel Set Degk TRID) Md_bp g... Grate Top island 6118"OPEN HOLE 6118 6.00 11,8495 12,170.5 Caslnp Deearlgbn Do (in) lo(in) Too WO) S.Ne MB) Bed Depth MD)... wtlLen O._ Gmae Top Thread WINDOW BIT 6 3.00 8,053.0 8,058.0 6,487.5 cgYOumOS IGG12m Casing Deacnption Do on to (m) TOP Rohl sM Depen WB) set Depa Door.. wllLen p._ Gmble Top Thread 3"OPEN HOLE 3 2.90 12,170.5 12,611.0 G46LIFT.Zedut Tubing Strings Tubing Description joined Us... 1. (r)TOpI KR)Set Depth ( set oepm (ND) (...Ture Grape TOPCOn nectlOr TUBING 3112 2.99 47150 6,2854 5.175.7 9.30 L-80 EUE8CM0D GASUFT a.5W.1 Completion Details Top (Not Coin Incl rvominai loop..) (MBI ('l lam Des com lD(m) i 6,M.51 5,129.0 4405 NIPPLE JUAMUU DS NIPPLE 2,812 PACKER, Sears 6,259.1 I 5,1568 4397 JISIEAL ASSY BAKER SEAL ASSEMBLY WILDCAT( COLUR 3.000 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etC.) NIPPIE:45Pv3 Top(tI TcPlncl Top(.B) (MB) (•l Des Com Run Das 10 (in) 3,590.0 3,3172 45.77 rmR1T.P Baker KS Packer asserably 3 70' KB pacer, 7/192019 2.370 ow TnPPawr,xseo.o Packer WILL stinger (OA_ EAT) 4.5' GS to pull packer. Lyerhq; 3.6]0.0 Assembly slang into PTSA. 3,80 0 3,3242 IS.JB Utter lop Northern Solution with seals sl9 mto RtoD )(192019 2310 seal bore. (Seals kak) 6'.10' DAL. 4.5' GS to pull. wmauNE GUIDE. 36213 7' ce WREUNE G: a,mxo.a 3,6060 3,3284 45. Liner Top CTO Liner top from 101 lateral, 2.99'seal bore. ]/142019 2.900 3GD6nn.arlti CTD urvER LATERAL 101 Vl0 cMr aqz: a6mw.]ca.o 3, .0 3,385.5 4590 WHIPSTOCK BH Delta Retrlevabie Whipstock, merge OAL18' 6202019 . w.marocK; seen° .RIME PLUG PE.M ENENS .0 y 3,7540 3,431.4 4602 EPLU PERMENENT Weatheofted Bi bo CHIP 10,IH10m dierential. g y 10,000p 4212019 umr lop'. Sado y( c.m.Inaw.em: aee5o.e 4,7150 4,D94.5 47.57 JET CUT Jet Cm 4RQ019 9000 6.4700 5,308.9 4171 LIN alipers Ows "Liner is severely eu ed bassoon W11]20 2680 ER 64]6-6]188 RKB; Min ID= 2.689M1rougM1 Ibis section 10123/1] -SL was able IO met 2.75' Gauge Ring borough buckled Liner area between 64)6-6]86' BOB to lag )254'RKB SURFACE: 370a,3805� 7.WO 5,80.3.4 43.16 SAND SCREEN NORTHERN N SC PROD A K R, YU018 9000 JET OUR, 4cS0 FLOW THROUGH KNUCKLE, QUADCO PREPACK SCREEN. OAL 12, MAX OD 2.5'. ),213,0 5,850.0 43.14 PA CLINE SL LIB oblamed 'half-moon' impression Indicating pamd 10/62 1 -0-000 G rUET;s.a154 R 3.5'Line, ,0530 6,483.6 3903 WHIPSTOCK FLO-THRUPMIPSTOCKBLI-01 4130/2008 cemem GRueem,'s.aPq.a 80950 6,516.3 3893 B FLO-THRU WHIPSTOCK BL1P01 4(28(2008 I WHIPSTOCK GPeSUPT;S.71S0 8.1440 6,554.4 38.83 1 FISH FISH'GS'Linerrunning mml, 5.3long lost 1/52001 1152001 Perforations & slots GAS uiT', 6. Pae som NIPPLE; 6.22a1i lop(..) B1mlkKel Ton(ND) mKB) BImpTVol (.B) Lmong are Dam Den n (shoran 1 Type Com T,6880 3,7060 3385.5 3,39.0 6179019 6.0 CMT SOZ PERF GUNi POWERFLOW HMX 6 SPF 8,185.0 10,201.0 6.566.4 A-, BL1- 4292 OB 32.0 SLOTS toned Alpe- 5' M. 01 @ 4 circumferengal adjacent rows, 3" centers sEALAssv;525911 staggered 18deg. 3'non- slotted ends 8,7330 9,019.0 4/302008 32.0 SLOTS 61Ode0 pipe- 5" 01BL1 @ 4 Circumferential adjacent rows, 3" centers UNERA1524Z&IM s.o staggered 18 deg, 3 non - PRODUCTION POST &TA: slotted ends osoe,wou aVCKLEOLlN ER6,go.O 9,1450 9,2400 R- 4 /30(2008 32.0 SLOTS SIDES pipe- . 016L1 @ 4 cimumferen dial adjacent rmss, 3" cement GAND SCREEN; 7,1%4.0 PARTED L I N E R, 72130 staggered 18 deg. 3' non - slotted ends 10,165.5 11,816.6 A-, Aut, 1R- 101181 32.0 SLOTS Blonsopipe- . 01B @ 4 circumferential atljacent rows, 3' centers staggered 18 deg, 3' non- Ends WHIPSTOCK e.OSTO � WINWHI STOCK SMO Carrlent esyu"2 sq u"2 Rmo Top f1Yo Br,r(rvo) Top IhKBI at IXKBI NNBI (..I Des Btan Das Com 5,61]0 8.000.0 4,709.3 6.4425 .mem M rse-U BMcNi.O150�� Squee2e 3,685.0 3,688.0 3,383.4 3385.5 Pullon 019 S pp9 cement squeezed into su cepipe OmCasingCemem NUK.1M0�! ;41312019 pelts in production string 3,885.0 3,9660 3,3834 ,5785 a act: Casing 419 squeeze7bbls ppgcementintosu acepla om Cement the producgon mring wbe pens shat O it. Mandrel Inserts at sLMi B,TJ3.oe,o190 s,luob m.._ on N TOp(MB) Top (ND) (MB) Molle Males OD pn) Sery NNe TyPe Iahh Typa Pon SW (H) RnONnstare'.e.1ssG1o2oea�- 5, 154 4,2975 CAMC 8MM- 1 GAS LIFT GLV BKS 0.15fi tROR;.Lois 5222008 Belo 2 T• CIBP score: 1. 1.111,mnB - _ - 4 5,718. 4,779.0 CAMC - 1GAS LIFT GLV BK -5 1.500 1,297.0 5r1212011 Belo 6 UT WEN HOLE B. 11,641.5 _ 30VEN HOLE IL 1¢110521NAS 2 I wJ" CIBP 128110 KUP PROD WELLNAME 1R -01B WELLBORE 1R-01 ConocoPhillips �— A'asICa,Inc MaMI CAEUI', NIPPLE RRIOGE PLUG FERMI NENT 37540 Hier hp: S. C—.S Sareeu: 38e50.y SURFACE. 3T."3E05� JETCUT;4,7150� G SUFT:50154� Cman Swee»: 58+TDM(B� GAELIFT:S,T80— BUCIQEO L I N E R, 84N05CR. PARTED L I N E wMPBTOCK B.Mfi O wwDOW M1.1, AM .,..o P81 wwPSTOCR: RM O ---- k� .EM: B.1N0 SLOTS; am ",Moo SLOTS; 8,14a ",,M 0. SLOTS; a. ISE C.10 SM 0. SLOTS: 10. I fi5S1181 B8 S 1 V OPEN MOLE 8: I1,EAS,S. 1ros S OPEN NOLE 8:121fi.S 1$,8110 - ConoaoPhillips Alaska, IND. KUP PROD WELLNAME 1R -01B RIVER UNIT W0. WELLBORE 1R -01B 'A.C,. 1.Co L:aB2AM Last Tag Veru Ppo led„ell Anwblbn Oepth DOG) EM Drab WellEore Lane III By _....................................................................... Last Tag: 5fi1)0 14 ......9 1 1R -01B III Last Rev Reason ,ANGER; W0 Annnmlmn End Dab WellOare La:, MW By Rev Reason: Jet CN Tubing 402019 1R-018 I lamaj Casing,%rings - ca6in4 DnwiPBPn DD OK ID ImI TPP InaBI seo.gnlnKBl set Depth lrvq... wuLen p._Gnde rop rnreaa LINERaBLDTTED- 2SIB 200 10,036.3 11,8495 4.43 L40 EXTENSION OF LINER 1 r A CONDUCTOR; 360.121 o Liner Details minel lD rop lrcKBl Top lrv011nRe1 Top Incl 9 Ilem Oes com (in) GAS LIFT: 2.sn.4 10.036.3 FISH NECK 3.5" GS FISHING NECK 1.995 11,8166 0 -RING BAKER O-RING 1000 Grafi UFT', 5634, Notes: General & Safety End Dadd I Ad..- 12/2611999 NOTE: SIDETRACK 10fl9R000 NOTE: SIDETRACK B ..E %.a— 5132008 NOTE: CTD SIDETRACKS IR-01BL181R-Dt BL -01 SI232008 NOTE: DMV @ 3998 MAYBE PERMANENTLY INSTALLED NIPPLE; 3.5]52 5/15/21119 NOTE: VIEW SCHEMAI CdAIaska SChama11C1D.O ops TCP PecMr.56W0 WIRELINE GUIDE: 3,628.] Cemem Byueem: 1. SGRE ONE LINER LATERAL iM CM III .a CMT SOZ, ] W W,MO WHIPSTOCK SIGNS BRIDGE PLUG PERMENENi O Lev.TOP:5 Geneve, BRvxza: 5865.0 . KKB SURFACE:. Loo 8— JET CUT. 4..7150 ms LET, 50154 Geneve SRIRAI 0Pot6 GAS LIFT: 5,1180— GAS LIFT: 8,1746 NIPPLE; AMM SEAL ASSY; A25A1 BUCKED L I N E R. RM .0 LINER N S M&10,9150 PRODUCTION M. SR/F as 08.SAO LINER BLI-01', 6,025614238 .0 I LINER B SLOTTED EXTENSKIOF UNERq tORaaa-l" as asl IR-IDI,ag3 I9Io:T.s1AM KUP PROD WELLNAME 1R-018 WELLBORE 1R-101 Last Tag'. 1R401 ilennan ._........................_....._.........._........._............___...... Last Rev Reason ConOcOPhi'Iips Anion End Dale wellnon Well Attributes IUNGER. 32fi— REV R EASON. C ID West yak B Lateral 8112/2019 1R-101 Max Angle 8 MD TO .41a51ta. Im. Fieltl Name KIIPARIIK RIVFRI.NIT We11W,e APYUYn 50f1999161IdlIM1 Wel--Am- ORlltt net(') MDF%N91 nV sn no ACI BIm^kKBI non asl IR-IDI,ag3 I9Io:T.s1AM Last Tag va'M1sl xnw,ahl tv11 APP.mdan Dac4h AKB) End Dah .1amn Less Mae By Last Tag'. 1R401 ilennan ._........................_....._.........._........._............___...... Last Rev Reason Anion End Dale wellnon Leer Mod By IUNGER. 32fi— REV R EASON. C ID West yak B Lateral 8112/2019 1R-101 jennalt Casing Strings Czrma Dese,lpemn op (n) mpnl Top (flNB) Se l DaRm lrtKel sat DapN lrvol... w'JLen n... G,aee roP rnreae LINER LATERAL 101 2 )/8 2.44 3,606.0 11! 6.50 L-60 H533 CTD Liner Details Nomma ID Top ME) FAA fW H11Ke) Top Incl l•I Item pea cum lnl 3,61)6.0 3,3284 45.79 SBR deployment Seel with 6' sealbore 2.990 3,612.0 3,3]26 45.80 CROSSOVER CASE over 3-12"x3-112",Pm Pin 2890 4,051A 3,481.0 91.12 CRO - cress over}12"-2-AB• 2.391 REDUCING 6,882.5 3,495.9 Q07 UML 57MENT OH Permanemp LL 2.375 SLEEVE 9,8)9) 3,472.3 91 70 DEPLOYMENT OH Permanent WILL 2.3]5 07 ae.., SLEEVE Tubing Strings TYe1ne Ddd.rlPH., skma MB_. ID TUBING- 4112 1n) 396 iopinKal 326 set Depen pl- 3.628.0 set Depin (ND) I-. 13 3'13 wl pMtl G,aae 12.60 L-80 Top Con n ecnon HYD 503 GASUFT:Id'3T.4 PRODUCTION Completion Details ioPlrvDIma mol xommzl iaP lnnet Inns) r) lhm Des corn IDpn) 32.6 326 0.00 HANGER Tulnng banger 4.500 3,556.9 3,294.1 45.74 PACKER Pa&er Baker FP @ 357W 3820 3,95.3 3,3069 45.]6 NIPPLE Nipple GXSelecvve 3.813'(PTe38136K)169,SN:215 )-01) J.9S8 OAS UFT; 3,:A4.1 ],626.] 3,34.8 45.82 WIRELINE WLE 3.940 GUIDE Mandrel Inserts ni N Top (M(e) Tap(TVD) MK3) MAP, Modal Op (1n) 9eP, Valve Lain I POR Slee TRO RYn TyPo on). IWg Run Dai Com PACnE3.3.ESa.a 1 2,53]4 2,5126 C8mm KBG-2 1 GAS LIFT GLV BK 0.188 1,50]0 )l1 /2019 2 3,5041 3,25)2 Camcp KBU-2 I 1 JLJAb LIFT JOY SKU -3 0313 6/302019 Notes: General & Safety End Dah An Ed - 8/12]2019 NOTE. VIEW SCHEMATIC w/AAN,a ScdemaliclUU NIPPIE: 3.57e.i --Tap Fack ., SE0.0 16w'vad 3.90a0 WIRELINE GUIDE: 3,a36.7 ne, Tup: 3A a cem.n,s — 3, F95.0 Mrs cem.m SRP—,: 3sas0 mla PR0DUCTIDNP0ST&ta 3E EI%Edlo ,6 SURFACE: 37p{,39o.5 V� LINER IATERAL 101 CTD: pTD ,�cc-lb �- Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Friday, June 14, 2019 9:40 AM To: Long, William R Subject: RE: KRU 1 R-01 (200-156) Sundry Perf and Squeeze Interval (319-041) William, The change outlined below is approved. Please include this approval with your copy of the approved sundry. 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. LoepoCdalaska.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 Loepp@alaska.aov From: Long, William R <WiIlia m.R.Long@conocophillips.com> Sent: Friday, June 14, 2019 8:56 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Eller, J Gary <J.Gary.Eller@conocophillips.com>; Starck, Kai <Kai.Starck@conocophillips.com> Subject: KRU 1R-01(200-158) Sundry Perf and Squeeze Interval (319-041) Victoria, We are preparing to do the pre -CTD work on KRU 1R-01 prior to CTD operation into the West Salk formation. This operation was previously approved in Sundry #319-041. We would like to reduce the planned 7" perforation interval for squeezing to 20' and the cement volume to 10 bbls. (3690'— 3710' MD) After closer review of the operation we have concerns with the cement gravity swapping with the larger perforation interval originally proposed. Please let me know if any further documentation of this minor revision is required. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372 (office) STATE OF ALASKA At ASKA nil ANTI nAc rnk1CM011Ar1nk1 nne MAY 2 2 gnsa VVIVIY ��"' PL TIONREPORT AN ..,1 WELL ❑ Other ❑ L COMPLETIO❑N OR RECOAbanMnpended ❑ 1a. WellStatu 1 b. Weil Class 20AAC 25.105 20AAc 25 110 Development ❑� Exploratory❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Sus ., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Abend.: 9 4/29/2019 200-156/319-041 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 10/13/2000 50-029-21404-02-00 4a. Location of Well (Governmental Section): Surface: 153' FNL, 5140' FEL, Sec 20, T12N, R10E, UM Top of Productive Interval: 8. Date TD Reached: 10/17/2000 16. Well Name and Number: KRU 1R-018 9. Ref Elevations: KB:79, 1 17. Field / Pool(s): 1104' FNL, 2277' FEL, Sec 20, T12N R10E, UM Total Depth: 602' FNL, 3240' FEL, Sec 29, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 539830 y- 5991050 HT~' Zone- 4 TPI: x- 542701 y- 5990116 Zone- 4 Total Depth: x- 541780 y- 5985332 Zone- 4 GL: 3p, ¢ BF: Kuparuk River FieldlKuparuk River Oil Pool 10. Plug Back Depth MD/TVD:Air, 18. 8146/6,W 31Y 3vs3 11. Total Depth MD D: 19. 12611/6683 Property Designation: AK� ADL 25640 .�O[ 2 s-6 3s DNR Approv Number: ALK 2571 12. SSSV Depth MV lVD. 20. N/A Thickness of Permafrost MD/TVD: 1900/1900 5. Directional or Inclination Survey: Yes ❑ (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 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 WT. PER SETTING DEPTH MD SETTING DEPTH TVD CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16 62.5 H-40 38 115 38 115 24 1280sx CS _11 95/8 36 J-55 37 4380 37 13867 121/4 11250sx PFE III, 420sx PFC 7 26 J-55 35 6479 35 5315 81/2 65sx Class G 31/2 9.3 L-80 6243 10915 5145 6698 6 1/8 475sx Class G 23/8 4.43 L-80 10036 11850 6702 6669 3 Uncemented Liner 24. Open to production or injection? Yes ❑ No 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ALL PERFORATIONS PLUGGED OFFe' Q �4N CJ �1.k,1 DATE Zo( SIZE DEPTH SET (MD) PACKER SET (MDITVD) 41/2 3628 3557/3294 6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No El Per 20 AAC 25.283 (i)(2) attach electronic and printed information D VEXED C2 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A SUSPENDED Date of Test: Hours Tested: Production for Oil-Bbl:Gas-MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate O&Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 6�'f/ / y CONTINUED ON PAGE 2ubIA RBDMS ✓MAY 2 8 2019mit ORIGINL only/,, �,,,,�3, AlT 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, 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 Surtace Surface Permafrost - Base 1900 1900 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 - Formation at total de the I 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, paleontoloo calrproduction rwell test results. r 20 AAC 25 070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. ry .� Authorized Name: T Senden Contact Name: Dust Ward 494, AuthorizedT Workover Su ervisor Contact Email: dust co .ward .com Authorized Contact Phone: 265-6531 Signature: Date: 2' lI INSTRUCTIONS General: This form the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10 07 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 1 a: 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. RATIONS PLL 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 ConocAP'hillips Alaska, Inc, 1R.oy svrzmal2s'.13 vM Casing Strings Veaktl Whenepe (acyeq Lasing Dencri ion GO pal Ip HO Top MKS) Set Depth MIKE) Set Depth nVD)... WIILen R1 G,ads Top Thread CONDUCTOR 16 1506 38.0 121.0 121.0 62.50 H -0O Welded .................................e6G'u.'s'"'""""""""""'""""""" HMIGER:3P.8 Casing pezcnption Go (in) ID lint To'XIEQ SNpepIM1 111KB1 Se[OepM IN01._WVLen (L.. GraEe Top Thread SURFACE 9Big 836 37.0 4,380.5 3,66)5 36.00 755 euness Casing Oescriptlon 00 (in) IO lin) Top IXKB, SM Depth"Mill 9H Depth (rVD)... WVLen IL.. Gntle Top iM1natl PRODUCTION POST ] 6.06 35.0 6,5110.0 5,330.6 2fi.00 J55 BTC C'SITq Ce¢Ing Desctlptlon OD pct) Ip lint Top(XNBI Set OepM IXKBI Set Dep th IND)... Walla 11... GraEe Top "Meed 6111 OPEN HOLE B 61M 8.00 11,8495 12,1]0.5 Casing Descriptlon Do(in) ID (in) Top IKKB) SM DIRAIN mol) SM pepth(Nq... W11Len 11... Gntle Tep TM1reatl WINDOW BLI-01 6 3CD 8,053.0 8,0580 6,48].5 CONDUCTOR; 39.P1P 0 awls FMltl-semn gdNP Casing Description Oplln) IOlin) Top (XKB) Sel paplM1 IXKB) Sel pepm lrvDl... wuten p._Gntla Top TM1reatl LINERA 3112 299 6,2428 10,915.0 9.30 L -BD EUEBrtl Sap'n"I o;.16 Liner Details GAB LIFT, 263]0 Nominal In Tap MKS) rapINOHXKB) Tap Incl l•1 Item Des Lom pal 6,242.6 5,144.9 44.01 PACKER BAKER ZXP LINER TOP PACKER 4.375 GASUFT, a6w.1 6,2564 5,154.8 43.98 HANGER BAKER HMC LINER HANGER 4.375 6,2639 5,1598 43.96 1 PBR BAKER80-4DPBR 4.050 PACNER:3.5A8 6,30].3 5,191.5 43.8] OVERSHOT BAKER OVERSHOT W HIGH PRESSURE PAC 3.500 OFF NIPPLE, S.5i6.2 Le OPEN HOLEn 3"OPEN HOLEB ODlinl 3 Ip llnl 2.90 TaP("a) 12,170.5 SO Depth IXKB) 12,611.0 Set peptM1 (Npl... WVLen (1... Grace Tap TM11e� Cesing DescripM1an LINER B SLOTTED- EXTENSION OF LINER Op (in) 2 N ID gn) 2.00 Top I1MB) 10,036.3 Sel DepN IXKBI 11,849.5 Set DeptnlrvDl... wuLea 4.43 p... Gntle Top L-80 FL4S TM1reatl WIRELINE GUIDE: Saint A animplas Pa,mecan Liner Details 3,7<jG,U Nominal lD Top IXKa) Too (ILL (XKa) Top Incl l°) Mm psi Co. (n) 1 UCI FISH NECK 13.5' OS FISHING NECK 1.985 11,8168 O-RING BAKER O-RING 1.000 suRFACE3Taa.3w.5- Tubing Strings JETCUEQ150 Tnhma pese(ipxon shwa Ma._m1n1 TUBING- 4112 PRODUCTION TOP 3.96 -00 IXKpI BM 3,628.0 De pm IX..3M Depth (ND)L..Wl0om1 3,343] Gnae 12.60 L-80 sop can necllon HYD 503 GasuFTa,015.4 Completion Details CemuRSoaaam; S,eP.OXKB Tap IND) Topind Nominal Top MKS) IXKB) CI Item Des com ID lip 32.6 32.5 ON HANGER Tubinghanger 4.500 GASLIF7;57m0 3,5569 3,29.1 4574 PACKER Packer Baker FP @ 3570 3820 3,575.3 31306.9 45.76 NIPPLE Nipple GX Selective 3.STY PT#3813GI SN;2153b01) 3.968 Gas LIFT; 6,1748 3,6253 3,342.8 45.62 WIFUFUNE WLEG 3.940 GUIDE NIPPLE, 622o.e Tuhmg Description Shing Ma... ID lin) Top (flKa) Se[ DepIM1 IX.. Sel CeptM1 IND)1... WI(IbW) Gratle Top Lonnmlion TUBING 3112 2.99 4,]159 6,285.4 5,1]5.] 9.30 L-80 EUEBrdMOD Completion Details Top(Np) ToP Incl Nominal lop lfll(B) (ttKR) 1°) Ihm pa. Com Ip (in) 6,220.5 5,129.0 44.05 NIPPLE CAMCO DS NIPPLE 2,812 SEUAsav;ase.1 6,259.1 5,156.8 43.9] SEAL ASBY BAKER SEAL ASSEMBLY WILOCATOR COL LAR 3905 1 Other In Hole (Wireline. retrievable plugs, valves, pumps, fish, etc.) lop RISC) Topincl r" PRopucn. Poe; srtK V~so Top mol Imre) D Des I om Ran pate ID (in) 32.5 32.5 0.04 BPV 4232019 s5.o3seo.o aVLKLEp LI1NER: 6.OR.0 L' 3,754.0 3A31A 48.02 Bddge PQI1118nQn1 lug- Weatherford Big boy Clef lO,OOppsi tlifkronfial. 4222019 4,715.0 4,094.5 47.57 1JET CUT Jet Cut 422019 0.000 SANDSCREENl 72UO PARTED L I N E B. 1.2130 6,470.0 5,308.9 43.75 BUCKLED ER L I Naliper shows 3 5' Liner Is severely Buckled b6w Pn 6476-6786'RK6; Min ID= 268' through this section 31122O08 2.680 1023/1] -SL was able To drift 235" Gauge Ring through Tackled Liner area between 84]6- 6786' RKB to tag 7254' RKB 7,2040 5,843.4 43AS RANO SCREEN NORTHERN SOLUTION PRODUC I NPACKER, 3IW2016 0900 WHIPSTOCK aos3.o FLOW THROUGH KNUCKLE, OUADCO PRE -PACK WINDoW aunl: 60a.D� SCREEN. DAL 12', MAX OD 2.5". aosap 7,213.0 5,850.0 43.14 PARTE R LINE S LI obtalrand al -moon' impression intlicetin 3.5' Liner 9 panetl 11A62013 0.000 PBI WHIPSTOGK e,m60-------- 1� 8,053.0 6,483.6 39.03 WHIPSTOCK FLO-THRU WHIPSTOCK BIT 01 4202008 FISH', e,f. d 8,095.0 6,511 38.93 WHIPSTOCK B LU -1 WHIPSTOCK BLIPBI 4282008 sea 8,144.0 6,554.4 3883 FISH FISH GS Liner running bp; 53' long last llw AuI 1IW2D01 Perforations & Slots J fI snot smTC."Es 9.mo0 TapmKIU abnmKB) Top ITI (MKS) atm (Ti MKS) Linka2ne pale Den. IsM1olaXt ) Npe core sLms; e,lasae,zaoo 3 L smrs; e,lasa-1a2mo � B.1B5.0 10,201.0 6,586.4 A -,1R BLt- 3 42912008 320'MIS Sloned pipe -0.2"x2." @ 4 circumferential adjacent rows, 3"centers staggered 18 tleg.3'rom, slotted ends B,J33.0 9,019.0 A4. Aa, 1R- 4/302008 32.0 SLOTS Tioled pipe -07217=5 01B -1 @ 4 circumferential adjacent rows, 3'centers staggerer) 18 do,, 3' non- sloned ends UNERaaQ42,6w.816o i smrs; lalaasnl,alaeLl LINPRaBmNER". EXTENSION OFLINERge5 maa,11.84 9,1450 9,240.0 A,I,g5,1 mBL1 - 4!302008 32D SLOTS ISIDINCI pipe - .125'#. ' @4dreumkrontial adjacent rows, 3' centers ma sect l8 de ger g,3'non- sl0netl ends e 1re�opaN HOLE e; n.aae.s 5- ,1]06 3' OPEN HOLE 6: 1Sen II 2,8110 diLlIftilI KUP PROD WELLNAME 111-01B WELLBORE 1R-01 CarocoPhillips AlaSw, Inc eom em SSSV: NIPPLE iR-01, O1'V1N1O1YII:19 PM Perforations & Slots veRwl waameee(aakm) snot Dan Top (Ta.) Eft. 2 alad 6 IsnoM .......... .......... B ......................................... i.5 INrvGER, 92.B Top IXKB) BIm IXKB) IIIKB) gon) Linked Zone Oete ) TYT',.Com 10,165.5 11,816.6 A4, - 1011812000 32.0 SLOTS o4 x25" O1B 01B cicoumfenoodal ad 4 circumferential adjacent sggred 18 deg, Tcon- dotedentls Cement Squeezes roplrvD) .;aIrvD) CONDUCTOR; 9A6121O M..m rale-saawkxlea a: Top IXKB) Bim IXKB) IXKB) (XXB) Des Smrl Date Com 5,611.0 8,0011.0 4,]89.3 5442.5 emenl 4/312019 310{7150,.1O Squeeze Gout LIFT: me24 Mandrel Inserts 81 ad GAS LIR, 3,DF1 N Top IXKB) To(flKB D) Make Madel DD6n) Sery Type T,� Po'91u Tind ("I) Run Co. CO. 1 2,537.4 2,512.6 Camco KBG-2 412312019 2 3,504.1 3,2572 Camco KBG-2 412NN19 PACKER; a,ssee 3 5,0154 4,297.5 CAMCO KBMM- 1 GASLIFT GLV BK -5 0.156 1,270.0 5/2212008 Belo 2 vi NIPPLE, 35F.1CIBP -MM- 4 5,718.0 4)]90 CAMCO WB 1 GASLIFT GLV BKS 1.500 1,297.0 5222008 Belo 2 wT' CIBP WIRELINEGumE; 382.7 5 6,1747 5,096.2 CAMCO MMM 112 GASLIFT OPEN Open N912019 Belo areea Pluo-Pwmmam: 37%O w]" CIBP .Lt..: 9104.08 E JET CUT. 4.7150 (DE Arr. 5,0154 Cm2 MR, E.N7.. B GASUFT:'7WJ) G95 LIFT: 0.1748 NIPPLE;g.dE SFnLASsv emi PRODUCTION POST SRA: W Cd.yl].O BUCKLE. L I N E R; B,.. SANDSCREEN, 724.0 PARTED LIN E R', 72130 WIHWHIPSTOCK89,0 W W BL1 L1', BKve. BCS9O PBt WHIPSTOL1l B,L95O��.a ain. t,LkC�a �I SLOTS:8]39.08.O1R0------ SLOrc elM.0.8,2. 9LOT9', 8, a.c-R.1 O = UNERK4242!5-l0E5O t SLOTS: 10. LINERBSLOTED- EXTENSION EXTENSION OF LINER A', tO,Coal,MEE 818' OPEN HOLE B. T.W5- rz.1ros 3 OPEN HOLE 8: 12,170Y 1?on o ConocoPhillips KUP PROD WELLNAME 1R -01B UNIT WELLBORE 1 R-01 B 1Rdifi, b22/3o191223'.56 PM Last Tag VeNcal ( e,0 pnnotr[lonI pepth(I I End Dale .11l.fe Last Moe By ........................................................................................... Last Tag:I 5,61].0 141bOU19 1R-010 famaj Last Rev Reason pnnofa[ion End oxte Wetmore List Mue 9y Rev Reason Jet Cut Tubing 4012019 1R -01B famaj LINER Bu41', e, NO 610 Me 0-J Notes: General & Safety End oem Aneofelion 1212611999 NOTE. SIDETRACK 10/192000 NOTE. SIDETRACK B 5/3)2008 NOTE. CID SIDETRACKS 1R-01BL1 & 1R-01BL-01 5/23/2008 NOTE .OMY@ 3998 MAY BE PERMANENTLYINSTALLED 511512019 NOTE: VIEW SCHEMATIC w/Alaska SCM1ema[ic10.0 KUP PROD WELLNAME 1R -01B WELLBORE 1R -01B ConocoPhillips Ataska. Im. LINER Bl.l�l � SLME�10,� O -J Operations Summary (with Timelog Depths) 1R-01 Fi& Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time Entlrme our (m) Phase Op Code Adivlly Code Time P-T-X Operation Stan Depth (ftK8) End Depth n1K13) 4/18/2019 4/19/2019 4.00 DEMOB MOVE RURD P Remove hoses, U tube tubing and IA. 20:00 00:00 Remove secondary annulus valve and install flange and gauges. Clean pits, blow down fluids. Load trucks with equipment for next pad. 4/19/2019 4/19/2019 11.50 DEMOB MOVE DMOB P Continue Rigging down on 2K-26 00:00 11:30 location. 4/19/2019 4/20/2019 12.50 DEMOB MOVE MOB P Mobilize office to 1R-01. Mud pits, 11:30 00:00 electric shop, and mechanic shop mobilized at 11:30. Rig substructure mobilized to 1R-01 at 16:30. Continue mobilizing misc equipment to 1R-01. 4/20/2019 4/20/2019 20.00 MIRU MOVE MOB P Move sub. Lay herculite, spot tree 00:00 20:00 and BOP adapters behind well, spot sub base over well. Lay herculite and spot pits, cuttings box. Raise derrick, burm the containments. Set up tiger tanks, hard line. **Rig accept at 20:00** 4/20/2019 4/20/2019 2.00 MIRU WELCTL RURD P Take on 9.8ppg NaCl brine. RU and 20:00 22:00 test cellar hardline to tiger tank. 0 psi on tubing, 400psi on IA, 650psi on OA. 4/20/2019 4/20/2019 0.50 MIRU WELCTL OWFF P Bleed IA off to tiger tank, observe 22:00 22:30 10min, no flow. Drain tree, check for pressure above BPV, no. 4/20/2019 4/20/2019 0.50 MIRU WHDBOP PRTS P RU to IA, pressure test BPV to 22:30 23:00 1000psi for 5min, test good. 4/20/2019 4/21/2019 1.00 MIRU WHDBOP NUND P ND tree. 23:00 00:00 4/21/2019 4/21/2019 2.00 MIRU WHDBOP NUND P ND tree, inspect hanger and install 00:00 02:00 test plug. 4/21/2019 4/21/2019 5.00 MIRU WHDBOP NUND P NU BOPE. Install adapter flange, 02:00 07:00 - DSA, BOP stack and torque all bolts. Cut and install riser, turnbuckles and secure BOP Stack. 4/21/2019 4/21/2019 1.00 MIRU WHDBOP OWFF P Bleed off PSI from IAand verifyno 07:00 0800 flow. 4/21/2019 4/21/2019 1.50 MIRU WHDBOP KURD P PU test tools, prep XO's for 3.5" and 08:00 09:30 4.5" test joints. Fill surface lines and stack. Grease surface equipment. 4/21/2019 4/21/2019 0.50 MIRU WHDBOP SVRG P Pressure test BOP and associated 09:30 10:00 equipment. While pressure testing choke manifold observed valves leaking. Grease and service valves. At approximately 0930 observed IBOP leaking and change out IBOP, lower top drive valve leaking. 4/21/2019 4/21/2019 10.00 MIRU WHOBOP BOPE P Change IBOP and lower top drive 10:00 20:00 valve. Resume BOPE test 13:30. Test BOPE 250psi low/3000psi high 3 1/2" and 4 1/2" test joints. 4/21/2019 4/21/2019 1.00 MIRU WHDBOP RGRP T Complete final ROPE tests with 4 1/2" 20:00 21:00 test joint, accumulator test. 4/21/2019 4/21/2019 0.50 MIRU WHDBOP BOPE P Clean and clear floor 21:00 21:30 Page 1/3 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 1 R-01 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Tune Dw (hr) Phase Op Code Activity Code T me P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 4/21/2019 4/21/2019 2.00 MIRU WHDBOP MPSP P Open rams and found diesel 21:30 23:30 bypassing the BPV and test plug. Observe well, Pump stack out to verify fluid is not coming from rig, Diesel still bypassing. Ru to pull, Pull blanking plug, no change. Dry rod in stinger to open poppet, no change. Stay stabbed on with poppet open, observe well for 20min, slowed and stopped rolling. POOH, PU BPV retrieval tool, pull BPV. Well dead. 4/21/2019 4/22/2019 0.50 MIRU WELCTL CIRC P Close blind rams, pump 200bb 99.8# 23:30 00:00 NaCl down tubing taking returns to tiger tank, 6bpm, 700psi ICP. 4/22/2019 4/22/2019 0.50 MIRU WELCTL CIRC P Continue circulating 200bb1 9.8NaCl 00:00 00:30 brine, Final circ pressure 1100psi. 4/22/2019 4/22/2019 0.50 MIRU WELCTL OWFF P Monitor well 30mm RU to pull tubing. 00:30 01:00 4/22/2019 4/22/2019 1.00 COMPZN RPCOMP PULL P Run landing joint, back out LDS. Pull 01:00 02:00 hanger to floor 65k string wt. No signs of fluid erosion on hanger. Lay out hanger. Pull 3 1/2" EUE tubing. 4/22/2019 4/22/2019 6.50 COMPZN RPCOMP PULL P POOH with 3 1/2" 9.3# L-80 EUE 02:00 08:30 8RDM completion string and lay out the same. POOH from 4715' to 950'. Hole taking proper displacement. 4/22/2019 4/22/2019 2.50 COMPZN RPCOMP OWFF P While POOH with completion string, 08:30 11:00 well began to U-tube diesel. Make up TIW, low torque valves and cement line. Allow well to U -Tube taking returns to cutting box. Filling backside with 9.8 ppg brine. Approximately 8 bbls of diesel U -tubed from well. Monitor well for 10 mins no flow observed, well back in balance. Prep 4 112" tubing handling equipment, load cart with wire line tools. Spot wire line unit. 4/22/2019 4/22/2019 0.50 COMPZN RPCOMP SVRG P Perform full rig service. Grease 11:00 11:30 crown, blocks, top drive and drawworks. 4/22/2019 4/22/2019 0.50 COMPZN RPCOMP PULL P Continue pulling 3 1/2" completion 11:30 12:00 string out of hole. POOH from 950' to surface (2 GLM's, 147 full joints, 1 cut joint). 4/22/2019 4/22/2019 5.00 COMPZN RPCOMP FLOG P PJSM with dg crew and a -line crew. 12:00 17:00 Rig up wire line unit. RIH with junk basket gauge ring, CCL and Gama ray to 4650' WLD. Unable to correlate on first run. Perform second correlation run. Able to correlate and get on depth via gamma ray signature from previous logs. POOH with tools. Make up Weatherford running tool and 7" Big Boy CIBP (101k psi differential rating). RIH and get on depth. CCL depth 3742.36', CCL offset 13.64', 7" CIBP mid element set at 3756'. Observed approximately 320 ftlbs of line tension lost. Positive indication plug set. POOH with E -line. Page 213 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) f 1 R-01 Rig: NABORS 7ES Job: RECOMPLETION Time Log StartTme End Tune Dur (hn Phew Op Code A[linty code Time P-T-X Operation Start Depth MKB) End Depth ME) 4/22/2019 4/22/2019 3.50 COMPZN RPCOMP RURD P Rig down Pollard E-line. 17:00 20:30 RU to run 4-1/2" completion, clean clear floor until Xnipple, landing joint and crossover arrived. Bleed OA f/ 740psi to 500psi. 4/22/2019 4/23/2019 3.50 COMPZN RPCOMP PUTB P PU and RIH 4-1/2" HYD 503/563 20:30 00:00 completion. MUT4600ft1b. 4/23/2019 4/23/2019 5.00 COMPZN RPCOMP PUTB P PU 4 1/2" completion as penally. 00:00 05:00 RIH, space out, pick up hanger and land at 3628' EOT Ran in three LDS, unable to operate fourth, changed out LDS. 4/23/2019 4/23/2019 0.50 COMPZN WHDBOP MPSP P Set BPV, pressure test down IAto 05:00 05:30 1 1000psi, good test. 4/23/2019 4/23/2019 0.50 COMPZN WHDBOP WASH P Wash the BOP stack, drain. 05:30 06:00 4/23/2019 4/23/2019 6.50 COMPZN WHDBOP BOPE P In between well BOPE maintenance. 06:00 12:30 N/D BOP 4/23/2019 4/23/2019 1.50 COMPZN WHDBOP FUND P NU tubing adapter. Test void 250psi 12:30 14:00 5min 5000psi 10min. Good test. 4/23/2019 4/23/2019 1.00 COMPZN WHDBOP NUND P NU tree 14:00 15:00 4/23/2019 4/23/2019 0.50 COMPZN WHDBOP MPSP P Pull BPV set tree test plug. 15:00 15:30 4/23/2019 4/23/2019 0.50 COMPZN WHDBOP PRTS P Pressure test tree 5000psi 5min. 15:30 16:00 Good test. Pull test plug. 4123/2019 0.50 COMPZN WHDBOP MPSP P Set ISA BPV. test 1000psi 5min via 14/23/2019 16:00 16:30 IA, test good. "Rig Released at 16:30hm** Page 313 ReportPrinted: 513/2019 Winston, Hugh E (CED) From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Tuesday, May 28, 2019 10:41 AM To: Winston, Hugh E (CED) Cc: Haggerty -Sherrod, Ann (Northland Staffing Services); Ward, Dusty K; Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1 R-01 B Well Completion Report Hugh — Boxes 9 and 11 should be identical for both reports (see corrected info below). Box 10 is correct for the 10-407 dated 5/15/19 but is incorrect for the one dated 5/22/19 (see correction below). • Box 9: KB = 79.9' • Box 10: 3756' MD, 3433' TVD (only for the 10-407 dated 5/22/19) • Box 11: 12,611' MD, 6682' TVD Are you able to make those corrections by hand, or do we need to resubmit? I apologize again for the confusion, and please let me know if I can be of further help. -Gary Eller From: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Sent: Thursday, May 23, 2019 3:14 PM To: Eller, J Gary <J.Gary.Eller@conocophillips.com> Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Haggerty -Sherrod @contractor.conocophillips.com>; Ward, Dusty K <Dusty.Ward@conocophillips.com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 1R-0113 Well Completion Report Hi Gary, Ok I've got it cleared up. We did need two 10-407's 6. However can you still please verify the which numbers are correct for boxes 9, 10, and 11? Thank you Huey From: Eller, J Gary<J.Garv.Eller@conocophillips.com> Sent: Thursday, May 23, 2019 12:35 PM To: Winston, Hugh E (CED) <huah.winston(a�alaska.¢ov> Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haaaerty She rrod@contractor. conocophilli ps.com>; Ward, Dusty K <Dustv.Ward(&conocophillips com>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 111-016 Well Completion Report Hugh — I'm copying Victoria Loepp (AOGCC) to make sure she's part of the conversation; the way the sundries were written has been confusing for us as well. There were two sundries issued at the same time for KRU 1 R-01: the first (319-042) was for the plugging of the old Kuparuk Sand completion, and the second (319-041) for the workover to set it up as a West Sak producer. That's why ConocoPhillips submitted two 10-407's. The workover 10-407 reflects the present well condition. Does that make sense? -Gary From: Winston, Hugh E (CED) <hueh.winstonPalaska.zov> Sent: Thursday, May 23, 2019 11:58 AM To: Eller, J Gary<J.Gary.EllerPconocophillips.com>; Ward, Dusty K <Dusty.Ward(caconocoohillips.com> STATE OF ALASKA ALASKA CII ANTI (.AS2 CnNSFRVATInni rnnnnniecinr,i MAY 16 2919 WELL COMPLETION OR RECOMPL TION REPORT AN 1a. Well Status: OilA j as❑ SPLUG ❑ Other ❑ AbandonedSuspended 21b. 5-141 20MC 25.105 � 20AAC 25.110 GINJ ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: -46. Well Class: Development ❑� Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. Date Comp., Sus ., or Aband.: 4/20/2019 14. Permit to Drill Number / Sundry: 200-156/319-042 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 10/13/2000 50-029-21404-02-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 153' FNL, 5140' FEL, Sec 20, T12N, R10E, UM 10/17/2000 KRU 1R -01B Top of Productive Interval: 9. Ref Elevations: KB:79.9 17. Field / Pool(s): 1104' FNL, 2277' FEL, Sec 20, T12N, RI OE, UM GL: 36.7 BF: -MD/TVD Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth : 18. Property Designation: 602' FNL, 3240' FEL, Sec 29, T12N, R10E, UM 5617/4709 ADL 25635, ADL 25640 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 539830 y- 5991050 Zone- 4 11. Total Depth MD/TVD: 12611/E8k3 "b3 ROV 19. DNR Approval Number: ALK 2571 TPI: x- 542701 y- 5990116 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 641780 y- 5985332 Zone- 4 N/A 1900/1900 5. Directional or Inclination Survey: Yes ❑ (attached) No ❑r 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 NIA (tt MSL) N/A 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 CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT GRADE TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 38 115 38 1115 2 4 260 sx CS 11 9 5/8 36 J- 55 37 4380 37 13867 1121/4 1250 sx FIFE III, 420sx PFC 7 26 J- 55 35 6479 35 15315 181/2 65 sx Class G 31/2 9.3 J- 55 6243 10915 5145 16698 151/8 475 sx Class G 2318 4.4 L-80 10036 11850 6702 16669 13 uncemented pre -drilled liner 24. Open to production or injection? Yes ❑ No 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): n ALL PERFS PLUGGED OFF ✓ vAr SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 6285 6243/5145 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE N W ho/ 11 Was hydraulic fracturing used during completion? Yes ❑ No E] Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED 5617-8000 ✓ 28bbls 15.8 ppg Class G 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Press. Casinq Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): Form 10-407 Revised 5/2017 VTL 6/¢// 9 CONTINUED ON PAGE 2 /�/��yBDMSMAY 1 7101SuJmiyOR<jIGINIAL only^1 28. CORE DATA Conventional Corals): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, 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 Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1900 1900 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 - Top of Kuparuk D 7 682 6365 Top of Kuparuk A3 8370 6650 TD 12611 6683 Formation at total de the 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, paleontolooicalr r II test results. perg C2 .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 Title: Wells Su ervisor Contact Email: J.Ga co .Eller .com Authorized Contact Phone: 263-4172 Signature: C Date: :/ INSTRUCTIONS General: This fo d the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each -407 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 1a: 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 IR -0113 PLUGG FOR RE -DRILL Field Name: KUPARUK RIVER UNIT Start Date Job Type Last 24hr Sum MIRU on 111-01, take on fluids, rig accept at 20:00hrs. Bleed IA, PT BPV. 4/20/2019 RECOMPLETION ND tree. 4/19/2019 RECOMPLETION Continue RD off 2K-26. Mobilize Office, mud pits, and substructure. 4/18/2019 RECOMPLETION RD off 2K-26 PUMPING TRACKING 4/8/2019 ONLY PUMPED 20 BBLS OF 60/40 METH DOWN F/L DRILLING SUPPORT- RAN 2.5" JET CUTTER. CUT DEPTH= 4,715'. JET CUTTER FIRED WITH GOOD 4/7/2019 CAPITAL INDICATION. JOB COMPLETE. STATE WITNESS TAG TOC W/ 2" BAILER @ 5617' RKB; MITT TO 2000 PSI DRILLING (PASS); CMIT IA X TBG (DUE TO LGLV'S IN WELL) TO 2000 PSI (PASS); RE- SUPPORT- TAGGED CEMENT W/ 2.75" GAUGE RING @ 5617' RKB. JOB COMPLETE & 4/5/2019 CAPITAL READY FOR E -LINE. MIRU CT UNIT. INSTALL CEMENT RETAINER BHA IN RISER. PT. CIRCULATE TUBING & IA TO DIESEL 220 BBLS @ 3 BBLS/MIN. RIH WITH CEMENT RETAINER TO 6,140' CTMD. POOH TO 6,125' CTMD (OPEN GLM @ 6,175' RKB). PUMP 1/2" OD BALL AND SET CEMENT RETAINER. RETAINER SET BUT FAILED TO TEST. CONSULT ENG. STAFF. RIG UP SLB CEMENT PUMP. DRILLING PT. PUMP 28 BBLS OF 15.8 PPG CLASS G CEMENT INTO COILED TUBING. SUPPORT- PLACE 9 BBLS IN LINER AND 14 BBLS IN IA. UNSTING FROM CEMENT 4/3/2019 CAPITAL RETAINER. LAY IN 5 BBLS OF CEMENT IN 3.5" TUBING. POOH. WASH TO DRILLING V SUPPORT- PULLED PLUG BODY @ 6221' RKB. JOB COMPLETE & READY FOR CTU 3/10/2019 CAPITAL (ONCE PROCEDURE IS CONFIRMED W/ ENGR.) SET CATCHER/PULLING TOOL ASSEMBLY ON PLUG @ 6221' RKB; PULLED DRILLING OV @ 6175' RKB; CIRC OUT TBG X IA W/ 217 BBLS OF DIESEL; CMIT TXIA SUPPORT- TO 2500 PSI (PASS); PULLED CATCHER & EQ PRONG @ 6221' RKB; 3/9/2019 CAPITAL ATTEMPT TO PULL PLUG BODY AT SAME. IN PROGRESS. PERFORM INJECTIVITY TEST W/ SEAWATER UP TO 1 BPM @ 2000 PSI, AFTER 45 BBLS AWAY TBG STARTED PRESSURING UP & CUT RATE BACK DRILLING TO .4 BPM TO PUMP IN 20 BBLS OF DIESEL FP; TAG FILL @ 7123' RKB SUPPORT- (RECOVERED SAMPLE); BRUSH n' FLUSH DS -NIPPLE @ 6221' RKB & SET 3/8/2019 CAPITAL 2.81" CA -2 PLUG @ SAME. OBTAIN GOOD TBG TEST TO 2500 PSI. IN ConocoPhillips Alaska b1c. KUP PROD WELLNAME 111-016 RIVER UNIT NIPPLE WELLBORE 1 R-01 B L.'rese.1.7110sitill Last Tag V. achiscall Annomron Depth aft,el 1 End Data I wenbone tmlMW By _._. eenrer-peck Pmion-Vi s ... ........................................... as Ki 328 Last Tag; Dol /L loi.u,9 iNi famaj Last Rev Reason Announce I End Date Wellbore test MW By Rev Reason: Jet Cut Tubing 402..9 I iR-01B lourrou Casing Strings Cu es Description OD (in) in and Tap but set Deem IXKB) see Depth lrvDl... wuLm a... Gae Top rxreae CONDUCTOR 16 15.06 38.0 1210 1210 62.50 H70 Welded CONDUCTOR; adeno Casing DeunptionOD(in) to (in) Top RKTs Set Depto IXKBI Set Di EIVD)... ped -op (l._ Grace Top Txrcae SURFACE 9518 8.76 37.0 4,380.5 3,86].5 35.00 J-55 BuTdess Cps UFT MANDREL z ast4 Casing DesmpNon OD pnl ID (in) Top ISSUE) Set D.P. b B) Sed DapN IND1... MLen NL.. Grade Top Threat PRODUCTION Post SIT 7 8.06 350 6,SW.0 2600 J-55 BTC q Casing Descrlptlon 17 Nn) ID lin) Top (HKB) Set Depm (ryKB) set Depth (rv01... wuLen It.. Gntle Tap Txrud 6118"OPEN HOLE 61/8 6.00 11,849.5 12,170.5 cos LIFT M4NOREc asw.l Gersco rgetue OO(In) IDlln) Top(XKBI Set DePOMB) Set Depth IND)... Wi p... Grace Toplereae WINDOW BI -1-01 6 3.00 8,053.0 8,058.0 Casing Description ODIMI ID lin) iop lrD(BI Set Depth IXKB) SN Depth MD) WtA.en p... G,aee Top Threat LINER 312 2.98 8,242.6 10,915.0 9.30 L-80 EUE8rd peckescal Liner Details Top lnrce) I Top frvDl (XrcB) I rap lore l°1 Ilam Co. ominauo Com (in) 6,242.6 5,144.9 1 44... IPACKER I BAKER ZXP LINER TOP PACKER 1 4.375 6,256.4 5,154.8 4398 1 HANGER IBAKER HMC LINERHANGER 4.375 - 4WeRPe p 3,aM] : drum PWDPa 6,2630 5,159.6 43.98 PAR BAKER 8040 PBR 4.000 6,3...3 OVERSHOT B ROVERSHOT wIHI HPRESSU EPAGK 3500 OFF 0 mean[ Casing OPEN 3"OPEN HOLE B OD(inl ID (in) 3 2.90 Top IXKB) Set 12,170.5 12,611 Depm IXKBI 0 tlLm p... Guea Top TMestl suaPAce,aw3m.6- casing Descdption LINER BSIOned- Extension of Liner A OD In) ID Lee 2318 2.00 TopfnR81 Sa 10,038.3 11,849.5 �IUADIRNIIUVD)... Depm ltdKB) set Depm lrvOl... wui.en P... Greae Top I'll3 L-80 FL4S Threes 1.1 Cd: 4115.° Liner Details OPSUFT;50I5.4 Top MKB)Top (N been) Top led rl Mm Cas Co. Nominal lO 10,036.3 FISH NECK 3.5"GS FISHING NECK 1.995 c.m.Ptsq,Neze:561].DnKe 11,816.5 OANG BAKER O-RING 1.000 ONE upT', Snfl0 Tubing Strings Tubing 0escreeop Shing Ma...IDDn1 TopmKBl IS Dept'dL.Set Depth IN D1 L.. Vedined Grade Top CoonaaGon Tubing-Pmtlucti0n 41/2 3.96 -04 3,6280 3,343.7 12.80 L,30 HYD 503 Completion Details GAS UFT', EINIa Top IND) Top incl Nominal Top Mike) (be.) I°) @m Des Co. ID(n) NIPPLE', III 32.6 32.5 0.04 lHainger Tubing hanger 4,500 3,556.9 3,294.1 45.74 1Packer Packer Baker FP @ 3570' 3.820 3,575.3 3,306.8 45.78 Nipple - X Nipple GX Selective 3.813" (PT#3813GX7169, SN: 21537-01) 3.958 3,6257 3,342.84582 Wireline Guice WLEG 3.940 sEAL Assv: e.gsad Tubing Description sMng Me._ID(in) Top(MKER sd Depen (A. sed Depth LORD)(... Vllpam) Jere ee Top Con action TUBING 312 2.88 4,715.0 6,285.4 5,1]57 930 L-80 EUE8rdMOD Completion Details Top (TV) Top Incl Nominal Top L..."RKB) r) Item Das Co. IO pn) 6,220.5 5,129.0 44.05 NIPPLE CAMCO DS NIPPLE 2812 PRODUEION Pmt SITA:55.0 ..gene 6,2501 5,156.8 1 43.97 SEAL ASSY BAKER SEAL ASSEMBLYw/LOCATOR COLIAR 3.000 BUCNILEDu N E K:0sure0 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(NO) Top In., Top mute) IXKB) r) Los Com Ron Data m(in) sPNO scREEw, gesso PaHTED u N E R; 7 cu D 32.5 325 0.04 Barrier - Back Pressure Valve 4/232019 3,754.0 3,431.4 46.02 BXdge lug- Wasi berlord Big boy CIBP 10,00opsi differential. 4222019 Permanent 9,0E K Seas 0 a LINER IN WHIPSTOCK wwpsiocK Baa.O I� wwpow euuc dp53 a- a,oseo 4,715.0 4,094.5 4757 Jet Cut Jet CUT 417/2019 0.000 Bp]00 BUCKLED IN ER aliper shows .5°Lin I=S2varely BuckledbeN+een fi476-6785'RKB; Min 10 =2.68"thr0u8h this section 3I1220p8 2.680 Pat WHIPSI sive 0� 10123117 - SL was able IN drift 2.75° Gauge Ring through b uckletl Liner area beMreen 6478- 6786' RKB to tag uceedKB FISH:8 nki0 7,204.0 SAND SCREEN NORTHERN SOLUPRODUCTION PACKER ' A KER, M018 0.000 FLOW THROUGH KNUCKLE, QUADCO PRE -PACK SCREEN. OAL 12, MAX OD 25". 7,213.0 PgRTEDL NE9L R LIB Dbmined'ha-moonimpressionindicatingpeGe 35"Liner 776=13 0.000 8,053.0 WHIPSTO K FIUCI UWHIPSTOCK BLI-01 41302008 $0950 PBt WHIPSTOCK FLO-THRU WHIPSTOCK BIT PBI 412812006 8,144.0 FISH FISH' GS' Liner running 153' long 10971/52001 1/52001 Perforations & Slots shoe Top(ryKB) Btm IXKB) Tap enol IXKB) B. TND/ IXKBI Linked Zane Data Dens Lsx, Type Can 10,165.5 11,81fi8 A.3,A 01B ,1R- TUMIUM00 32.0 SLOTS Sloned pipe -0.125"x2.5" @ 4 circumferential LINER A; fi,x4gs10915O StoRs; 10,165 &1 adjacent rows, 3" centers staggered 18 beg. 3' non- smtted Ends Cement Squeezes Top LrvDl Ban D) uNERasuam-Exlmervmd UPwN 1pWa311,90.45 e ba.OPEN HOLE B: n.Mgs Top LIMBI Bbn IXKB) IXKB) Ur one IN B) Sad Oah Cam 5617.0 8,0000 4,7093 Came Squeem 41312019 105 S' OPEN HOLES; 1 2.170& iiva],6110 "' CanocoPhillips KUP PROD WELLNAME 1R -01B WELLBORE 1R -01B 1 �' ^' QIa5112,IK. 18.16 sn..1111... Mandrel Inserts vaNcal schematic meN.0 3L 01 ...... MI F&Fk Prxum Valve; ._-.....___.. ........................... 335 HanSer; ais on N Top IryKB 1 Tep liVDl fltl(BI Make Model O011nl 8ery Valve Type lalcM1 Typk Port Slze TRO Run 9n1 Ipa) Run Oeh Sam 2,537.4 2,5126 Camco KBG-2 G232019 2 3,504.1 3,2572 Camco KBG-2 412312019 3 5,015.4 4297.5 CAMCO K MM- 1 GAS LIFT GLV BK -5 0.156 1,270.0 5/22/2008 Belo 2 w7„ CIBP 0 5,718.0 6,7790 CAMCO K -MM 1 GAS LIFT GLV BK -5 1.500 1,297.0 5122/2008 Belo CONOVCTOP; 3A61210 2 w 7 - Clap Goa NFi MPNOREL 2.EW4 5 6,174) 5,096.2 CAMCO MMM 11/2 GAS LIFT OPEN Open 3/9/2019 Belo W 7.. CIBP Notes: General & Safety OAS LIFT MANDREL 3, SW.1 Fptl 08k AnnoWfion 122701999 NOTE: SIOETRACKA 11019/2000 NOTE'. SIDETRACK Peck.: a,wa.3 53/2008 NOTE; CTD SIDETRACKS IR-01BL181R-01BL-01 51232008 NOTE. DMV@ 3998 MAY BE PERMANENTLY INSTALLED 10/62010 NOTE: VIEW SCHEMATIC w/Alaske Schematic9.0 NRrAne GI 369.7 FoNPNm-PI 3.7540 S SURFACE: ST... 5- b CK 4,7150 GAS LIR; 5OIS4 ...Spleen,5,E170RKB GLS LIFT; 571811 GAS URl 13,114. NIPPLE: 5220. BFALASSV;6,2:8.1 PROWCTION..IA;.. 8,5020 BUCKLED L I N E R; E.0 SANOSCREEN; 7,M N PARTED LIN E R; 7,2130 LINEROLI-098 6-10.2380 WHIPSTOCK;8,0530 ool. WBAAt ESEI 60150 P81 WHIPSTOCK; 8,035, 0-------- FISH, 3,144, 0�� LINER A; 5242 E1OSISOL SLOT.: 101BSS11816 a� LINERS SMWJ-E11D Fny Do. -g 10,OM3m,M8.5 ElSI OPEN HOLE 8, 1181E i _ 2,1705 S OPEN HOLE B; 12,170E 12.110 ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 U7411119a:75:7111:16]:14910120iP BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. �` 1 0 0 Attn: NSK-69 R�Ci 06 ,�p19 700 G Street ��++ Anchorage, Alaska 99501 0 1 0 1 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 lir Print Na ne Signaturea/ I/ L-�A Please return via e-mail a copy to both Alaska E -Line Services and Conoco Phillips Alaska: 15G 0� p-rD a 00 -15C, Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Monday, April 15, 2019 8:42 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 1R-01(PTD 200-156, Sundry 319-041) RWO Change Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for your response. Will do. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, April 12, 2019 2:10 PM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]KRU 1R-01(PTD 200-156, Sundry 319-041) RWO Change Dusty, Approval is granted for the requested changes to the sundry as outlined below. Please include a copy of this approval with the approved sundry. 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 Victoria. Loepp(Lialaska.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)793-1247 or Victoria. Loepp?alaskaopv From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Monday, April 8, 2019 3:20 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska�> Cc: Eller, l Gary <1.Gary.Eller@conocophillips.com>; Senden, R. Tyler <R.Tyler.SendenC9conocophillips.com> Subject: IR -01 Workover Steps being moved to Post -Rig Victoria, Hope this finds you well. On the RWO coming up on the 1R-01 producer (approved sundry attached), we'd plan to tweak our order of operations slightly and move: The corrosion inhibited fluid circulation step and The actual setting and testing of the packer step to Post -Rig operations. The following shows the above changes with strikethrough portions moved to red 'Post-Workover Operations...' steps: Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation Note: Well 1 R-01 B's intended service following CTD sidetrack is as a development oil well in the West Sak formation. The CTD KOP is tentatively planned at 3690' MD, 3387' TVD. 1. MIRU workover rig onto 1 R-01 B. NU BOPE, test. 2. Pull old 3'/2" tubing down to the cut at *4700' KB 3. MIRU a -line a. (optional) Run CBL from 4600' 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 *3720' MD as a base for cement. RD a -line. 4. PU 4'/", 12.6 ppf, L-80 completion and TIH. Completion will include hydraulic set packer and gas lift mandrels. Gomulate hole eveF te GOFF06POn 6nhobited bFiRe. Land tubing in tubing hanger aad Packer depth tentatively planned at ±3500' MD. MIT -4A Set BPV. 5. ND BOPE, NU 4-1/16" tree. RDMO workover rig. Post-Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation 1. Pull BPV 2. Circulate hole over to corrosion inhibited brine. 3. Pressure up tubing to set packer. Pressure test tubing. 4. Pressure Test IA. 5. MIRU a -line. Tie into Schlumberger EMIT log run in Jan/Feb 2019. Tag CIBP at 3720' MD. Perf for squeeze 3640'-3710' KB (70'). 6. Set 4'/" x 7" thru-tubing whipstock at 3690' MD with high -side orientation. RDMO a -line. 7. MIRU coiled tubing unit. Lay in 15.8 ppg class G cement from TOWS to 3580' and apply squeeze pressure. a. Calculated volume of 130' of 7" casing is only 5 bbl, but be prepared to pump at least 15 bbl of cement to adequately squeeze this interval. 8. Once target squeeze pressure is achieved, contaminate and circulate out green cement down to the TOWS at 3690' MD. Maintain overbalance the entire time. POH, trap sufficient surface pressure to maintain overbalance. RDMO, allowing time for cement to cure. a. The intention is for coiled tubing to leave cement nodes over the perfs. CTD will drill out any cement nodes inside the 7" casing when they go to perform their window exit at 3690' MD. Thanks for your time! Please let me know if you have any questions/comments or need anything else. PTO ;too -/s(, Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, April 12, 2019 2:10 PM To: Ward, Dusty K Subject: KRU 1 R-01 (PTD 200-156, Sundry 319-041) RWO Change Dusty, Approval is granted for the requested changes to the sundry as outlined below. Please include a copy of this approval with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCa)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 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: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Monday, April 8, 2019 3:20 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: 111-01 Workover Steps being moved to Post -Rig Victoria, Hope this finds you well. On the RWO coming up on the 1R-01 producer (approved sundry attached), we'd plan to tweak our order of operations slightly and move: - The corrosion inhibited fluid circulation step and - The actual setting and testing of the packer step to Post -Rig operations. The following shows the above changes with strikethrough portions moved to red 'Post-Workover Operations...' steps: 11 Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation Note: Well 1 R-01 B's intended service following CTD sidetrack is as a development oil well in the West Sak formation. The CTD KOP is tentatively planned at 3690' MD, 3387' TVD. 1. MIRU workover rig onto 1 R-01 B. NU BOPE, test. 2. Pull old 3'/" tubing down to the cut at ±4700' KB 3. MIRU a -line a. (optional) Run CBL from 4600' 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 ±3720' MD as abase for cement. RD a -line. 4. PU 4'/z", 12.6 ppf, L-80 completion and TIH. Completion will include hydraulic set packer and gas lift mandrels. . Land tubing in tubing hanger and pFessure up tubing to set paGke . Packer depth tentatively planned at ±3500' MD. MIT 'A. Set BPV. 5. ND BOPE, NU 4-1/16" tree. RDMO workover rig. Post-Workover Operations to Set Up for CTD Sidetrack into the West Salk Formation innansmair 2. Circulate hole over to corrosion inhibited brine. 3. Pressure up tubing to set packer. Pressure test tubing. 4. Pressure Test IA. 5. MIRU a -line. Tie into Schlumberger EMIT log run in Jan/Feb 2019. Tag CIBP at 3720' MD. Perf for squeeze 3640'-3710' KB (70'). 6. Set 4Yz' x 7" thru-tubing whipstock at 3690' MD with high -side orientation. RDMO a -line. 7. MIRU coiled tubing unit. Lay in 15.8 ppg class G cement from TOWS to 3580' and apply squeeze pressure. a. Calculated volume of 130' of 7" casing is only 5 bbl, but be prepared to pump at least 15 bbl of cement to adequately squeeze this interval. 8. Once target squeeze pressure is achieved, contaminate and circulate out green cement down to the TOWS at 3690' MD. Maintain overbalance the entire time. POH, trap sufficient surface pressure to maintain overbalance. RDMO, allowing time for cement to cure. a. The intention is for coiled tubing to leave cement nodes over the perfs. CTD will drill out any cement nodes inside the 7" casing when they go to perform their window exit at 3690' MD. Thanks for your time! Please let me know if you have any questions/comments or need anything else. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 MEMORANDUM TO: Jim Regg kTi `1/01 P.I. Supervisor ! / FROM: Matt Herrera Petroleum Inspector Section: 20 Township: Drilling Rig: n/a Rig Elevation: Operator Rep: Lease No.: ADL 25635 " Rory Ober Casing/Tubing Data (depths are MD): Conductor: 16" 0. D. Shoe@ Surface: 9 5/8" 0. D. Shoe@ Intermediate: Feet 0. D. Shoe@ Production: 7" 0. D. Shoe@ Liner: 31/2" 0. D. Shoe@ Tubing: 31/2" - 0. D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 5, 2019 SUBJECT: Reservoir Plug & Abandonment KRU IR -011B CPAI PTD 2001560; Sundry 316-042 12N Range: 10E Meridian: Umiat n/a Total Depth: 12611 It MD Lease No.: ADL 25635 " 6175 ft MD, Suspend: 15.8 P&A: X - 660 660 Casing Removal: 115 - Feet Csg Cut@ Feet 4380 Feet Csg Cut@ Feet Feet Csg Cut@ Feet 6479 Feet Csg Cut@ Feet 10915 - Feet Csg Cut@ Feet 6285 Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing Retainer 6175 ft MD, 5617 ft MD 15.8 Wireline tag 660 660 Initial 15 min 30 min 45 min Result Tubing 2070 1950. 1900 - IA 520 530 530 P OA 660 660 660 Initial 15 min 30 min 45 min Result Tubing 1970 - 1880 1840 - IA 2020 1915 - 1870 P OA 700 710 710 Remarks: Reservoir abandonment for redrill of 1R -01C per Sundry 319-042. Pollard #1 slickline unit used for plug tag. MITT and MITIA. Attachments: none " rev. 11-28-18 2019-0405_Plug_Verification_KRU_1 R-01 B_mh PrD-3vo-5-6 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, March 19, 2019 8:42 AM To: 'Eller, J Gary' Subject: KRU 1 R-01 B (PTD 200-156, Sundry 319-042) Plug for Redrill Revisions Gary, Please make the changes to the original procedure in red font for the plugging operations sundry and email tome. The revisions are fine. The changes will be approved once I receive the revised procedure. 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(o)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 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 LoepPLgL laskaaov From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Thursday, March 14, 2019 10:03 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: 1R -01B (200-156) Plugging Procedure Victoria — Greetings! I'd like to make a revision to the approved plugging procedure (sundry 319-042) for KRU 1 R-01 B (200-156). In the approved procedure, my intention was to pump 33 bbl of cement through a retainer at 6230' KB into 3%" cemented liner. Injectivity testing of 3/7/19 showed very poor injectivity into the existing perfs, possibly due to partial plugging of a permanently installed rock screen at 7204' KB. I have no confidence that I'm going to be able to pump 33 bbl of cement past this obstruction, and 33 bbl would be too large a volume of excess cement to manage if it locks up. I propose cutting the volume of cement below the retainer from 33 to 9 bbl, which is sufficient volume to fill 1000' of 3%:" liner. If the cement pressures out before placing the full 9 bbI below the retainer, then there is adequate room in the tubing and annulus above the liner -top packer to accommodate the excess cement without interfering with workover operations. So the plugging procedure would now call a total of 28 bbl of cement: 9 bbl below the retainer, 14 bbl in the IA (500'), and 5 bbl in the tubing (500'). This revised procedure will still meet the objectives of 20 AAC 25.112(c)(1), and of course the AOGCC would still receive 24-hour notice to tag and pressure test the cement plug after it has been placed. Please let me know if you'd like to discuss this further << File: 1R-01B.pdf >> Originated: Schlumberger PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: Y i� AOGCC •. "�411 ATTN: Natural Resources Technician II rJ Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 -*A& Anchorage, AK 99501 20 0 156 TRANSMITTAL DATE-. - TRANSMITTALN WELL NAME 1R-26 3M-26 1R-018 1R-04 1F-07 18-15A 1R-17 .. # 50-029-22193-00 50-029-22431.00 50.029-21404.02 50-029-21407-00 50-029-20830-00 50-029-22465-01 50-029-22212-00 ORDERSERVICE DWUJ•00077 DWUJ-00078 DWUJ-00079 DWUJ-00080 E9KH-00003 EA77-00001 EA77-00006 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER DELIVERABLE WL WL WL WL WL WL WL DESCRIPTION EMIT Caliper EMIT EMIT PPROF PPROF (PROF DATA TYPEColor FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD DATE LOGGED Prints 2 -Feb -19 4 -Feb -19 5 -Feb -19 6 -Feb -79 9- Feb -19 12 -Feb -19 13 -Feb -19 r 1 1 1 1 1 1 1 7 nt Name Signature return via courier or sign/scan and email a Date Schlumberger and CPAL Schlumberger -Private A Transmittal Receipt signature confirms that 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. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Ty Senden Workover Supervisor ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU IR-0IB Permit to Drill Number: 200-156 Sundry Number: 319-041 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 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 04 P�q-- - Cathy V Foerster Commissioner DATED this a day of February, 2019. RBDMSi FEB 112019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVE® a 1. Type of Request: Abandon ❑ Plug Perforations u F actture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ ✓ Suspend F, /P. - Perforate 1-i Ether Stimulate ❑ Pull Tubing ❑+ Change Approved Program ❑ r Plug for Redrill Perforate New Pool ✓ Re-enter Susp Well Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development El • Stratigraphic ❑ Service ❑ 200-156 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-21404-02 eat yt, 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1R -01B . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25635 R /j 2 lk7l /ZI> F, , Ku aruk River Field, Ku aruk River Pool ' 11.1 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12611 • 6683 4700 4084 2383 cement to 5700' MD cut tbg 4700' MD Casing Length Size MD TVD Burst Collapse Structural Conductor 115 16" 115 115 Surface 4380 9-5/8" 4380 3867 Intermediate 6479 7" 6479 5315 Production 4672 3-1/2" 10915 6698 Liner 1814 2-3/8" 11850 6669 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10165'-11817' MD (gross, sgz'd 6698'-6668' (gross, sqz'd) 3-1/2", 9.3 ppf L-80 6285 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker ZXP liner -top packer ZXP packer: 6243' MD, 5145' TVD 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/1/2019 OIL �� . WINJ ❑ WDSPL ❑ Suspended ys•y 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: Ty Senden Contact Name: Dusty Ward 0��A 4444 Authorized Title: Workover Supervisor Contact Email: dust .Ward Conoco hilli s.com Contact Phone: 907-265-6531 Authorized Signatur Dater COMMISION USE ONLY Conditions of approval: NotifyC ission,ssoo,tthhat a representative may witness Sundry Number: _` /V'' Plug Integrity F-1 BOP Test Ltij Mechanical Integrity Test El Location Clearance F-1 Other: QDP tfs f to 3000b/ fJnvavlar �rcve�fr-''AA Z5oZ) Ps1_7 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: (�. COMMISSIONER THE COMMISSION Date: 2— VT !iT I- /-i ii 9 BDMS�- 1p • .., „-_.:C .::. (y r.pproved applic i s i 2`lnt f m the date of a rovF�B t U IJ Submit Form and �� y'Y` � PP a /�j/�� Attachments in Duplicate V � LLL///7 _,::g z..F: <g ConoeoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 29, 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-01 B (PTD# 200-156) 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-01 B completion in the Kuparuk Sands is in accordance with the requirements of 20 AAC 25.112(c)(1). Following plugging, workover operations will prepare 1R -01B for CTD sidetrack into 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 1R-016 - 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-01 B - Operations Summary in support of the 10-403 Sundry Application - Current well bore schematic - Proposed post-workover schematic If you have any questions or require additional information, please contact me at 907-263-4172. Sincerely, JGar Eller Cor{pco fillips Alaska Qieyas ra//� c,P�l P�,rj "no(,^�wlf T4if well wos e rook a'"C�otei 1 Concur. a ('271"m a . iede rAet ro !etvc^ Trtev -I ilf j` YI �1 R �� P•� �Y MP/ Gf �o� �iN,d(/�o1 / KRU 1 R-01 B: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1 R-01 B (PTD 200-156) is a Kuparuk producer equipped with 3'/" tubing, 3'/" production liner, and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1 R-01 B so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of -- 1 R-01 B; a CTD permit to drill (10-401) will be submitted in the near future for 1 R-01 B. The Kuparuk sand formation pressure in 1 R-01 B is 3253 psi at 7150' MD, 5897' TVD, as measured on 10/23/17. For the plugging operations the maximum potential surface pressure is 2663 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 1558 psi at 3387' 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 2370 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 January 25, 2019 1. RU Slickline: a. MIT -IA to 2500 psi b. Pull 3'/�` packer and rock screen at 7204' KB 2. RU E-li1�'L. a. with CCL to tubing tally of 12/24/ b. p down the tubing. If fluids ar of freely going into the CTD lateral, ct Wells Engineer to disc plan forward. �d� N 0 q, c. h holes in the 3'/" tub' at 6248' KB, above the ZXP packer. Perf in wer half of the full int immediately above the packer to leave room for CN ement retainer i he same joint. d. ead 105 bbl iesel down IA to confirm that the tubing punches are clear perfs. Di sel will serve as an IA freeze protect fluid after cementing. i. 105 1= 4000' in the 7" x 3'/�" annuluse. '/2' ment retainer at 6230' KB, below the DS nipple at 6221' KB but e a tubing punches.3. RU Seoil and cementing unit:a. o take returns off the IA and the tubingb. ith CT. Sting into cement retainer at 6221' KB and establish injection into the A -sand CTD lateral 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 January 25, 2019 L This procedure calls for pumping a minimum of 52 bbl of cement to plug the 1 R-01 B 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 C -sand perfs. Monitor pressure on IA continuously whil/at10,0 ng cement i to the perfs. i. A minimum of 33 bbl of cexpecte ust to fill the tubulars down to the 2%" slotted lt 10,0 ' MD, butthe intention isto pump sufficient cement tleas 300 psi increase in IA pressure. e. Once IA pressure has built to 30er baseline injection pressure, open up the IA to allow cement to entMaintain 1:1 returns on the IA. Circulate a minimum of 14 bbl ofg cement into the IA, which is sufficient to place a 500' plug ofn the IA. i. 500' of 15.8 ppg cemepdwill add -160 psi hydrostatic pressure over N diesel at the 1 R-01 B . clination of ±450 . 1)l� f. Sting out of the cement re finer and shut-in returns on the IA. Begin taking returns on the tubing. L in 5 bbl (minimum) of cement inside the 3.5" /^ J a� tubing, which is suffici t for a 500' plug of cement. l ti g. Continue to POH w ' e switching over to PowerVis to contaminate any leftover cement . main at 200' above calculated top of cement in the tubing until PowerVis to s the corner, and then POH while cleaning up any residual cement. 4. Slickline: a. After came has had minimum of 24 hours to cure, RIH with slickline bailer. Tag top o cement. Pressure test cement plug to 2000 psi via tubing and IA separat y. Provide 24-hour notice for the AOGCC to witness this operation. 5. E -line: a. RI with jet cutter for 3%', 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the with/ ing mid -joint at ±4700' KB (i.e. -1000' deeper than the eventual CTD detrack depth). 6. Set BPV, prepare for workover rig Workover Operations to Set Up for CTD Sidetrack into the West Salk Formation Note: Well 1 R-01 B's intended service following CTD sidetrack is as a development oil well in the West Sak formation. The CTD KOP is tentatively planned at 3690' MD, 3387' L`J G1 TVD. V � /I S 1. MIRU workover rig onto 1 R-01 B. NU BOPE, test. 2. Pull old 3'/2" tubing down to the cut at ±4700' KB 3. MIRU a -line a. (optional) Run CBL from -4600' 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 ±3720' MD as a base for cement. RD a -line. 4. PU 4%", 12.6 ppf, L-80 completion and TIH. Completion will include hydraulic set packer and gas lift mandrels. Circulate hole over to corrosion inhibited brine. Land Page 2 of 3 January 25, 2019 tubing in tubing hanger and pressure up tubing to set packer. Packer depth tentatively planned at ±3500' MD. MIT -IA. Set BPV. 5. ND BOPE, NU 4-1/16" tree. RDMO workover rig. Post-Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation 1. Pull BPV 2. MIRU a -line. Tie into Schlumberger EMIT log run in Jan/Feb 2019. Tag CIBP at 3720' MD. Perf for squeeze 3640`-3710' KB (70'). 3. Set 4%' x 7" thru-tubing whipstock at 3690' MD with high -side orientation. RDMO e- line. 4. MIRU coiled tubing unit. Lay in 15.8 ppg class G cement from TOWS to -3580` and apply squeeze pressure. a. Calculated volume of 130' of 7" casing is only 5 bbl, but be prepared to pump at least 15 bbl of cement to adequately squeeze this interval. 5. Once target squeeze pressure is achieved, contaminate and circulate out green cement down to the TOWS at 3690' MD. Maintain overbalance the entire time. POH, trap sufficient surface pressure to maintain overbalance. RDMO, allowing time for cement to cure. a. The intention is for coiled tubing to leave cement nodes over the perfs. CTD will drill out any cement nodes inside the 7" casing when they go to perform their window exit at 3690' MD. Page 3 of 3 January 25, 2019 Ile a« Sg HJO aM1oe 21' MD IM sre-s d 3Be3.55 sne«oe D M43111-• MD, 3868' TV P d55 ind4w cut M 8476' MD (2000) T CBL of &985 showaalop of mentMeD6D, Pedormedsmall us. aver mnn9 window 1099). Pecker Top of 3.1/2" cement" 7790'via CBLof2-5-00 1R -01B Present Well Condition Arctic Pack cement is well above the West Salk formation 7" CBIS don't go shallow enough to see arctic pack cement. Bestguessis AP cement goes down to ±3000' MD (i.e, ±500' TVD above WSak) nipple a149T(2.8)5"ID) nipple at 6221' (ID =2 813] er 2)Ua packer M 820.1' Y Packer a screen at 7204' cTD Completion (2D() 8) -&9" Mertop a10028' MD pstos,M8053'1110 1R -01B Workover Setup CTD KOP MW MO, 3305' 68TV0, 46de7 nc West Sakformation (top "3200' TVD) RWO will set a 7" CIBP and run new 4X" completion. Post-RWO will pert, set (whipstock, and squeeze via U. Squeeze pelt 3640'-3710' KB KUP PROD 1R -01B ConocoPhillips AMRJI Well Attributes Maz Angle BN TD Ai2Sk3, inC. Lvtlleo tum 1mi d Name wNlEorestauz nd l°I MD IXKBI nn atm /12,6 500292140402 KUPARUK RIVER UNIT PROD 4]92 4.600.00 12.811.0 Comment MS/ppm) 0. ospo=n EM pab KBGM IX) flip RNmeOare SSSV; NIPPLE Last Vp' 122611999 38,78 B27/1985 r PO1e, 191N1093693 PM Last Tag enicalscfemeuc acus rvnrvcEF. 693 AnnaeGon DegnglKBl EM Des LLL Mod By Last Tag: RK wasable to drift 2]5' Gauge Rng to Tag ],254.0 10/231201) ppmven Laat Rev Reason Annotation End Doh Last Mod By Rev Reason: Bel Sand Screen 3/92018 lama, Cuing Strings Cxing Mscnptmn mPn1 mllnl Top (nKal set Mpm lmaBl sat Depth DVD'... wuLen O... Grade Tap rnread CONDUCTOR 16 15060 38.0 121.0 121.11 62.50 K40 WNded Casing Vwriplbn Moo) ID(in) Top IXKa) SeL MPI6IMLB) Set DVId.. WULen B... Grwte Top In. CONDUCTORaeaf2v0 SURFACE 9516 4,380.5 3,887.5 moo 55 Bull.. "Ont Casing DesoriPtlon 7D IID Top (nKB) Moet,"(me 311 ", `TVDL.. ME - Toils Top Tnrmd PRODUCTION Post ST ] 8.059 35.0 6,500.0 26.00155 BTC A wp"Eaasf Cuirq Cesc p[bn p0 fin) I Dnl Top IRNBI Set pepM OIXB) Bet Cepth (NOL.. WNLen g-. Gretle Tap Tnr� 6118' OPEN HOLE B 5118 fi.000 11 819.5 12,170.5 Casino Demlptbn OD lin/ lin) TePMKB) 9&IMptlf (nKBI BH Deem ()VDI„-WgLen IL.. Grade Top lnrml G/S LIFi; 2b324 WINDOW BL101 8 J.000 8,0530 8,058.0 Caming Deacrgr ion OD gp /Donn Tep(KKB)set lTvpl... Wtl rTDresd Top LINERA 3112 2992 6.242.6 109150 9,30 9,30 L 80 80 EUEB tl Liner Details GfS LIFT; 3.980 Top IXKB) Tap RVIS)YOUED I Top lrlcl l°I I rare LMCom Nominal f0 in) 6,242. 5. 1" 91 44.01 PACKER IBAKER 57-LIEER TOP PACKER 1 4.375 8,2584 5,1540 43.98 HANGER BAKER HMC LINEN HANGER 1 4.375 8.263.0 5,159.8 43.96 1 PER BAKER 80-40 PER 4,000 6,307.3 OVERSHOT BAKER OVERSHOT w/HIGH PRESSURE PACK 3.500 OFF 1 SURFACE;3]Dy3W5- Caere DemelplonOplln) IDOn) 1gent") ""a"'Rl(01 Depm(ivvj MI -ant Jo aP Tnwtl 3- OPEN HOLES 3 2900 12.1]0.5 128110 G43UFT;50154 Ca9q-.ptbn LINER B Slotted - CO pn) 2318 IOlinl 1.995 TaP In1LBl 10.03fi3 sat Myth IRKS) 11,819.5 SN Oeptb I.' -I... --n11... 4.43 Grade L-80 TOPTIIr®d FI -4S Eodenai0n pf LinNA Liner Detalm OI%LIFT: S)18L ominal lD Top XHBI TopINp1MKB) TBPIM I°) Ilam Des Com (inl 10,036.3 FISH NECK 3.5"GS FISHING NECK 1.995 11.816.6 O RING BAKER O�RING 1.000 Tubing Strings GASUFT;6.11LA TudnB Description S1nng Ma... 1p pn) i0p LNKB) SH Deprn lR.. 5e1 MVln (TLU)l., Wt(10/X) Grade Tap ConnMlon TUBING 31/2 2.992 29.3 6,285.4 5,175 ] 9.30 L80 EUE8NMOD Completion Details NIPPLSS.i206 To, M) I Toplxl Nomlrul TopmKB) (NNS) M pari Cam m(in) 293 29.3 0.04 1 HANGER FMC GEN IV TUBING HANGER .500 4931693.1 008 NIPPLE CACO DS NIPPLE 2.-5 M 8,220.5 5.129.0 k05 NIPPLE CAMCO DS NIPPLE 2.812 52591 ,1513.8 1 43.97 SEAL ASSY BAKER MTASSEMBLYw/LOCATOR COLLAR LouI am May. NE I'll OSaer In Hole (Wireline retrievable plugs, valves, Pumila, fish, etc) Top (ND) Top Incl Tap(..) ("Ke) 0 pas Com Run Dare mMl 6,470.0 SUCKLEDL IN Caliper share. 3.5- Liner is sewrety BOWed Disburser 3/11/2008 2680 ER BQB-Singer RIM, Min tD= 2,689hmugh this sergon 1 012311 -SL was ableto drift 2]S Gauge Ring through buckled Liner area between 64]6-6]86' RKB to tag 725,4 ROD PRODUCTION Post STA; 360 sSUO.o BUCKLED L I N E N: S.ATOO ].2fb.0 SAHOBCREEN NORTHERN SOLUTION SC PRODIXTICIN FACKER. FLOW THROUGH KNUCKLE, OUAD00 PREPACK FN2018 E.. SCREEN. OAL 12'. MAX OD 2.5. 7,213.0 PARTEDL I NE SL LIB obtained ha&moonImpression indiMngpaned 1082013 7000 R 3,5' Liner SAND ECREEµ],2w.0 8,053.0 WHIPSTOCK FL0.THRU WHIPSTOCK EILt-01 40012008 PARTED L I N E N. 22aD �y 8,095.0 Pal FLU-MRU WHIPSTOCK BL1 P81 M213I2DD8 WHIPSTOCK 8,144.0 FISH FISH GS' Linermnning Idol; 5.3'long lost l/52001 1/52001 LINER BU-OI;SD25.KI0 dee 6 Perforatlona & SIOt$ WXIPSTOCKaW30 WINOOW BLt Ohrood 6 B.OEB.OTop(NO) PBI WNMOCKSdgdd�+ Top( -GN BMIXKBI NIKE) BWMD) (Iran Mone Date so. pens IshoKM ) TV. Com 10,1855 11,8168 M3, A-4, 1R- 101182000 32.0 SLOTS 01B 4 nmumlerendal adjacent FI.:B,1410� JSIodedRPe-OA25'K25F@ NOW . 3'Cenlemalaggemd 18 deg, 3' non-sloaed ends Mandrel Inserts is, aK an N Tap 11rB) TaP(ND) doing MeM vYve Loch Pon Slee Ric Run Mods CU(In) dery Type TI" (Inn (.1) Run Dere non 1 2.632./ 259]9 CAMCO KBIWIgLIGLV BK -5 0.125 1252.0 5232008 2 2 3.998.0 3600. GPMCO KBM -0 Y BK -5 0000 DO 1225/189 2 3KBMM-LV BK5 015fi 1,200 2i/20082d 5]180 4]]90 CAMCO KBMM�LV BK5 1500 1,290 52220DO a1a R10.91G0 SLOTS; fdMMM 2 V RI( 0.150 00 5/222008 Notes: General & Safety 6th Dae annotation LINER BSMxd-Evemien of 12126/1999 NOTE SIDETRACK GmrA10008.311,549,6 10/19/2000 61fiPOPENHOLEp;tf,&9Ui-- NOTE. SIDETRACKS 121T0.5��- 3OPEN ROLE 12.170 1 138110 -- ConocrPPhillips Auska.!rc KUP PROD 1R -01B iR01 B, 34'V1893fiM AN HANGER 39.3 Notes: General & Safety Ene Dote Annotation 5/3/2008 NOTE: OTD SIDETRACKS IR-O1BL181RA18L01 coxDUcio fl:39Plma 5232008 NOTE: OMY a 3998 WY BE PERWNENTLY INSTALLED 10/82010 NOTE. VIEW SCHEMATIC wA.Rka SOheln"O0 NIPPLE: 493.1 GM LIF1:2.63R.< GAS LIFE; 3 WB.O SURFPCE:3)P93B3S— GAELFT,54154 GASUF(;511B0 GIS UFr; a,vae SFPLASSY', 63591 PRODUCTIONPNIF?A350 8,W 0 BUGxLEDLINER.RMLO SAND SGflEEN;)3H0 PARTEDLINER:72130 r� U LINER BLWH1TOOK OW30 wxWSTOCK 00la— WINOtlN ELt-01.SL530� S,OSSO PBI WNIPSTOGK a.0550—� Rel: e,uaa—� LINERA:62a2 0.8150 MOTS: IO, 189.P11,a1fiA� LINER B6MIW-ENnunol Wr A; 1O,01 61TOPENNOlEB.E0:11paR5 96- 12,1]05` 3' OPFN XOLF B;121 TOS -- 128110 1R-018 Present Well Condition (generic) "o Nae a pX'MD West Sak formatlol (top -33W TVD) r Arctic Pack cement is well above the West Sak formation 7" CBIS don't go shallow enough to see arctic pack cement. gest guess is AP cement goes down to±3000' MO (I.e.±S00' TVD above WSak) .Maraudaee Mi ahae® aeoo'TV[) "A" shoe Is below the base of the West Sak Fn to 12.5 tog No CBL across 9-5/8" 7" cement extends above the Kuparuk sands which will be abandoned. CBIS in a11. 111-016 (producer) Rost-RWO Condition 4K" gas Ilft completion In preparation for CTO sidetrack Kuparuk intervals. P&A'd 19-RWO block iueeca of 7"a 9%" mulus in the vicinity the CM KOP IR -010 (producer) West Sak CTD pilot (2019) Cf0 completion: 2K" slotted Ilner In 4.25" ID hole f CTD Window "it (2 -string) eatt near the top of the WSak sands. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Ty Senden Wells Supervisor ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-0113 Permit to Drill Number: 200-156 Sundry Number: 319-042 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 �.aogcc.a losko. 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,• / /"-, --- Cathy P. Foerster Commissioners DATED this e day of February, 2019. ABDMS�-- Ftb 1 12919 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® JAN 3 0 20119 ®nr � 1. Type of Request: Abandon ❑ Plug Perforations ✓❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑✓ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑✓ . Stratigraphic Service El 200-156 ' 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-21404-02 —cr> 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1R -01B Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ,��J.� ADL 25635 jibL- 254 /L> ! T' �-i% Ku aruk River Field, Kuparuk River 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): 12611 6683 7213 5955 2663 n/a n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 115 16" 115 115 Surface 4380 9-5/8" 4380 3867 Intermediate 6479 7" 6479 5315 Production 4672 3-1/2" 10915 6698 Liner 1814 2-3/8" 11850 6669 Perforation Depth MD (ft): Pertorat1cm Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,165'-11,817' MD (gross) 6698'-6668' (gross) 3-1/2", 9.3 ppf L-80 6285 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker ZXP liner -top packer ZXP packer: 6243' MD, 5145' TVD 12. Attachments: Proposal Summary ✓ Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 2/15/2019 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Ty Senden Contact Name: Dusty Ward Authorized Title: Wells Supervisor Contact Email: dust .ward conoco hllli S.com Contact Phone: 907-265-6531 Authorized Signature: Date: ltjo corAmissilbN USE ONLY Conditions of approval: Notify C ission so that a representative may witness Sundry Number: , Plug Integrity BOP Test ❑ Mechanical Integrity Test u Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No L� Spacing Exception Required? Yes No Subsequent Form Required: ❑ /J9 IlLp APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: RBDMSJL FFR I tole- z131-1141 Submit Form Form 10403 Revised 4/2017 Approved applicati"% dF and YYRhe date of approval. Attachments' Duplicate FC "! �/ i 2 qty ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 29, 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-01 B (PTD# 200-156) and to perform workover operations to set the well up for CTD sidetrack in the West Sak formation. The plugging of the existing KRU IR -01B completion in the Kuparuk Sands is in accordance with the requirements of 20 AAC 25.112(c)(1). Following plugging, workover operations will prepare IR -01B for CTD sidetrack into 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-01 B - 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: - 10403 Sundry Application for KRU 1R -01B - Operations Summary in support of the 10-403 Sundry Application - Current well bore schematic - Proposed post-workover schematic If you have any questions or require additional information, please contact me at 907-263-4172. Sin rely, J. Gary Eller ConocoRhillips Alask�' Wells Ad�isor t co Cu . rh i�(le 'ell feC -r 1cl,&il-c'S f well /p C%f 4�pf Al p (at ted CIV 4 n d eeej l o S'drixcic 70 6P (,-e fir, KRU 1 R-01 B: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1 R-01 B (PTD 200-156) is a Kuparuk producer equipped with 3'/" tubing, 3'/" production liner, and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1 R-01 B so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of 1 R-01 B; a CTD permit to drill (10-401) will be submitted in the near future for 1 R-01 B. The Kuparuk sand formation pressure in 1 R-01 B is 3253 psi at 7150' MD, 5897' TVD, as measured on 10/23/17. For the plugging operations the maximum potential surface pressure is 2663 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 1558 psi at 3387' 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 2370 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 Ptuaainn Operations 1. RU Slickline: a. MIT -IA to 2500 psi b. Pull 3'/2" packer and rock screen at 7204' KB 2. RU E -line: a. Tie in with CCL to tubing tally of 12/24/99. b. Pump down the tubing. If fluids are not freely going into the CTD lateral, contact Wells Engineer to discuss plan forward. c. Punch holes in the 3'/z" tubing at —6248' KB, above the ZXP 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. d. 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 e. Set 3%" cement retainer at 6230' KB, below the DS nipple at 6221' 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 6221' KB and establish injection into the A -sand CTD lateral 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 January 25, 2019 gVvo J This procedure calls for pumping a minimum of 52 bbl of cement to plug the 1 R-01 B 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 C -sand perfs. Monitor pressure on IA continuously while pumping cement into the perfs. i. A minimum of 33 bbl of cement is expected just to fill the tubulars down to the 2%" slotted liner top at 10,036' MD, 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 14 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-01 B 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 31/:", 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the tubing mid -joint at ±4700' KB (i.e. -1000' deeper than the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig �rkover Operations to Set Up for CTD Sidetrack into the West Sak Formation Note: Well 1 R-01 B's intended service following CTD sidetrack is as a development oil well in the West Sak formation. The CTD KOP is tentatively planned at 3690' MD, 3387' TVD. 1. MIRU workover rig onto 1R -01B. NU BOPE, test. 2. Pull old 31/" tubing down to the cut at ±4700' KB 3. MIRU a -line a. (optional) Run CBL from -4600' 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 ±3720' MD as abase for cement. RD a -line. 4. PU 41/2", 12.6 ppf, L-80 completion and TIH. Completion will include hydraulic set packer and gas lift mandrels. Circulate hole over to corrosion inhibited brine. Land Page 2 of 3 January 25, 2019 tubing in tubing hanger and pressure up tubing to set packer. Packer depth tentatively planned at i3500' MD. MIT -IA. Set BPV. 5. ND BOPE, NU 4-1/16" tree. RDMO workover rig. Post-Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation 1. Pull BPV 2. MIRU a -line. Tie into Schlumberger EMIT log run in Jan/Feb 2019. Tag CIBP at 3720' MD. Perf for squeeze 3640'-3710' KB (70'). 3. Set 4'/i' x 7" thru-tubing whipstock at 3690' MD with high -side orientation. RDMO e - line. 4. MIRU coiled tubing unit. Lay in 15.8 ppg class G cement from TOWS to -3580' and apply squeeze pressure. a. Calculated volume of 130' of 7" casing is only 5 bbl, but be prepared to pump at least 15 bbl of cement to adequately squeeze this interval. 5. Once target squeeze pressure is achieved, contaminate and circulate out green cement down to the TOWS at 3690' MD. Maintain overbalance the entire time. POH, trap sufficient surface pressure to maintain overbalance. RDMO, allowing time for cement to cure. a. The intention is for coiled tubing to leave cement nodes over the perfs. CTD will drill out any cement nodes inside the 7" casing when they go to perform their window exit at 3690' MD. Page 3 of 3 January 25, 2019 KUP PROD 1R -01B Conommillips AaSka,!n6. 1fl-016. 39'V108RD6 PM HPNGER'. i93 Notes: General 8 Safety EM MroWlon "Z.. NOTE. CTD SIDETRACKS 1ROt BLt B1R018L-0t SI2J2L00 NOTE'. DMY U.19% MAY SE PERMANENTLY INSTALLED CONDULTORI39.0.f]1D 101612010 NOTE'. VIEW SCHEMATIC wINaska Schematic9.0 NIPPLE... .111725.21 OP$ LIFT: J.9�.0 6URFACE;3] W,3W.5- GASLIFT:S,m59 GMLIR;57180 GfS LIFT; 8,1]<B NIVPLE 6.II08 fiFN A83Y:6.TA.1 f PRODUCTIONPo"t WF;]5D ry r bYAO BUCKED LI N E R:Ba]DO V SNIDE REEN;]3W 0 v RTEDLINER;]$130 b LINER BLI 01: B W 0 TMKE. W MLI-CIi km, WINDOW BL1At; 8,05J6 eD580 RE, WXNSTOLX: 8.096 D � FIfi4; 8.1MD� LINER A 8302110$150 &LOTS: 10.1 C5.111,815fi� LINER BEbIYE-EffimbnM LwO.1184a5 B td'OPMEN HNOTEM B: 8;111,8085 - 121I05` '.:.: S OVEN xOLE B',13,1]OS , 12811D ••DOMYtIor 5e HID shoe 121' MD 9-sre•Surfan 36e J55e at 4361' M0, 3868'ND uc ion 26e J-55 dove cul a16477 MD (2000) T• CBL ol9-B85 sllovstl rop of ..am.1%080'. Per(omled Bme11 equaeze after rrilfin9 window (1999). ner6470'MD ler at 7213'7 Top of 3-1/2" cement-7790'via CBL of 2-"0 1R -01B Present Well Condition Arctic Pack cement is well above the west Sak formation 7" CBIS don't go shallow enough to see arctic pack cement. Bestguessts AP cement goes dawn to ±3000' MD (i.e. 3500' ND above WSak) pM 049T (2.075' 10) t KBMM-2 mandrels at 2632', 5015', ST1C, & 6175' pie at 6221' (ID= 2.8131 Z Ppeter at 6243• Packer & screen at 7204' CTD Campp.6on (200&) 2-3/8•• finer top at 8028'file nhipsrock at 8053' MO 1R -01B Proposed P&A CTD KOP 3690' MD, 9305'SSND.464.9 inc (1) Ti, M recover TT packer& screen at 7204'7?1 (2) Open mandrel or its punon slow, 2%P pack., (3) CM retain.rzet above top eg punch (4) Cml luliheatletl thm retain., into CTD completion (5) Cent cko ilaled up IA above Z Ppacker (6) Core on tap of retainer in 3- il2"149 (7) TubiN cul above roc at -4710' MID Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, October 31, 2018 11:23 AM To: Eller, J Gary Subject: RE: Sundry Application for KRU 1G-03 Gary, We need the two separate sundries as you outlined below: First sundry to plug 1G-03 Kuparuk and the second sundry to Ferxarm-and perform a workover. _�k r vi PTP Fbr CTD "I'5 °t l,::- 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. LoeooCdalaska.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 (9071793-1247 or victoria Loeop@alaska.aov From: Eller, J Gary <J.Gary.Elie r@conocophillips.com> Sent: Thursday, October 18, 2018 10:32 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: Sundry Application for KRU 1G-03 Victoria - Greetings! A few weeks back Ty Senden and myself discussed with you our plans for conducting a pilot program in 2019 whereby we would CTD sidetrack out of existing Kuparuk Sand wells into the West Sak formation. I'm preparing the first of those sundry applications for your review for well KRU 1G-03 (PTD #182-149), which covers both the plugging of the Kuparuk sand completion and the workover to set the well up for CTD sidetrack into the West Sak. My question is this: do you have a preference whether the plugging operations and workover operations are submitted via a single sundry application or via separate applications? It's really the same amount of work for me regardless, but if you have a preference on how you'd like to see them then that would be the more efficient way of submitting them. One factor that has a bearing on this is what we're going to name well 1 G-03 when we convert it to a West Sak injector. I propose that we rename the well as 1 G-103 according to our West Sak naming convention, and I recommend that we do so following plugging of the old Kuparuk completion but prior to the workover that sets the well up for CTD sidetrack. In other words, we would plug 1G-03 pre -rig but we would work over 1G-103 in prepiarafion foT sidetrack. There is precedent in this in GKA already: well 1 H -05A was renamed 1 H-105 (204-228) without changing the PTD number; this was done via sundry 305-005. If we follow this convention, then I think we'd have one sundry application to plug 1G-03 and a second sundry application to rename and perform a workover on 1 G-103. Thoughts? I'm a bit confused by these two sets of sundry applications. I received them separately, but they were submitted on the same day for the same well. The first set (319-042) appears to be identical to the second set (319-041) except for the "Type of Request" specifications at the top of the 403 forms. The operations proposed in both sets appear to be intended to plug the 111-0113 well for redrilling. Suggest voiding the applications numbered 319-041 Or am I missing something? Thanks, Steve D. 7-441 a l r40�4 Tiklf91v(eAfe' hT4 Ski, of it 1-4e e Thr Gie 6'nly ��cn/1!` dlot�y f ltP /C 11 aruk Stiff/,y�y. as'i U uric — C� fi.N�' a h of Go pul�P oho 4 f 165T 111de/ —0%X', K61' Pure Ir�tr hex g1(i?d 74, w4l, t; Oct Tafre'f no t q, 4 9 9P "k, 1"4r �,0.-eoosev S1urt Pq fe) �twteo roe *0 a0�ut,onf y 7 7 741�k TA,7 �,4,,t 1 P f l t -h -r �� is a ntw L1, 7-D �r—o��cf• Plv11"-,% kUKRU /cepa.-� , �l15, Thv1 B a �'lIY1 S � k rw Y') 'k -)q �� z I've t I FV C T n p C r W %e /hr PTD': w I 5}-a �� a-�eP, 1,u1-rzh t1�� wSa� is c/r�ltrc� t Vve !'1e+VVI C w)<< /Y1� J`�n Gl✓t5 wf rL c (i✓�5 t �a wC� -F, ll v w5 -Fro V1- t� z �l� r �<c rs a s r��yr5ttcl Plvk� vk wciI q ar✓l< wok � 1 ✓5 a- � P wo fo, STD thz w CTO PT -0 fat- V✓�wlC Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of"Suspended." Ste 1 Task Res onsible The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and t initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling The drilling engineers will serve as quality control for steps 1 and 2. Engineer (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and atch and one of the Stat Tech Geologists will check the "Well by Tanding" user query Geologistin =:ne RBDMS to ensure that all of the Pells have beenhandled properly. At this same time,eview the list of suspended wells for accuracy. CONOCOPHILLIPS ALASKA, INC., KUPARUK RIV UNIT 111-0113 (200-156) KUPARUK RIVER, KUPARUK RIV OIL Monthly Production Rates 1,000,000 s c 100,000 0 a 0. LL V y0 10,000 _ O 0 o m v L7 LL L V 1,000 3 V 100 10 ---- Jan-2000 Jan -2005 Jan -2010 Jan -2015 1,000,000 w v m 100,000 0 O v m 0 10,000 s 0 m m m 1,000 0 i d m eD m 100 0 0 S i 10 Jan -2020 SPR EADSH EET_prod-Inject_Curves_Well_V117_2001560_KRU_1R-01 B_20190204.xlsx 2/4/2019 :at 1 10 ---- Jan-2000 Jan -2005 Jan -2010 Jan -2015 1,000,000 w v m 100,000 0 O v m 0 10,000 s 0 m m m 1,000 0 i d m eD m 100 0 0 S i 10 Jan -2020 SPR EADSH EET_prod-Inject_Curves_Well_V117_2001560_KRU_1R-01 B_20190204.xlsx 2/4/2019 Lr~e Project Weli History File Co~Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. s~~l~- ~~ ~ .Well History File Identifier Organizing (c~al~~t ^ ~~(o-Sided III IIIIIIIIIII II III Rescan Needed ~~~ ~~~~~~~~~~ ~~~ ~~~ P~SCAN DIGITAL DATA OVERSIZED (Scannable) Color items: ^ Diskettes, No. ^ Maps: ^ Grayscale items: ^ Other, No/Type ^ Other items scannable. by large scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable} ^ Other: ^ Logs of various kinds NOTES: ^ Other BY: BEVERLY ROBIN VINCENT SHERYL MARIA INDY DATES~7~(.~d~~/S/ ~fV~ Project Proofing III IIIIIIIIIII II III BY: BEVERLY ROBIN VINCENT SHERY MARIA WINDY DATE`~~a.~~~~/S/ ~/ 4~ Scanning Preparation ~ x 30 = ~ ~ + 1 ~ = TOTAL PAGES BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; ~, / ~S/ ~~~~ 111 Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~~~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO B`(, BEVE LY ROBIN~/INCENT SHERYL MARIA WINDY DATEa~ ~ S/ wx Stage 2 IF NO IN STAGE 1, PAGES} DISCREPA S RE FOUND: ,r YE I/~NO BY, BEVERLY ROBIN VINCENT SHERYL MART WINDY DATA.-I`/~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON INDIVID PAGE BA515 ___ III DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) III II I I II I I III I ~ III ReScanned l3tTt/if/{f~€dr7~ J.).3E~f? {.~./7fiC7x~/z?PP@fFYdC3Ftf SC:?{Ft?fPi£J €. tTf#3(31£€£7t~/ III IIIIIIIIII III III RESCANNED BY. BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /S/ General Notes or Gamments about this file: Quality Checked (c3L~nc} III IIIIIIIIlIIII III 12/10/02Rev3NOTScanned.wpd n U COI'1 ~ . . ocoPh i I I ~ ps Alaska F.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: ~'~` . ~. ,._,. ' 1~~~` ~ aao- is~O ~~~ Q~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL~. 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 treatxnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, f~~ MJ Loveland C~ SEP 0 2 2009 ~Al~~~~ pil ~ f ~s Cons, .Co 'ssion An~hOr~ ConocoPhillips Well Integrity Projects Supervisor ~- ~ ~ ~ ~~ ~ ;= ~, '~G`?`~ rnr. ._. M ..... .. i P ..~e i... _x. ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (70-404) Kuparuk Field Date 8/29/09 1 R PAD Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 R-01 B 50029214040200 . 2001560 13'7" 2.0 26" S/15/2U09 5.1 8/27/2009 1 R-02 50029214050000 1851760 80' 7 3.30 23" 8/23/2009 4.7 8/28/2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-06 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 1 R-08 50029213330000 1850730 8' 1.00 21 " 8h 5/2009 13.7 S/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 1R-17 50029222120000 1911140 20" N/A 20" N!A 4.4 8/28/2009 1R-18 50029221880000 1910870 9'4" 1.20 21" S/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 S/29l2009 1 R-25 50029221530000 1910474 7'4" 1.50 26" 8/15/2009 5.1 8/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009 1R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009 1R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009 ~ ~ RECEIVED STATE OF ALASKA ~UN ~ ~ ~~~$ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOAI~ica Oil & Gas Cons. Commission 1. Operations Pertormed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Other ~~ ~~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development^ Exploratory ^ 200-156 3. Address: Strati ra hic g p ^ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21404-02 7. KB Elevation (ft): 9. Well Name andyVumber: 79' 9" ~'~ `` 1 R-01 B 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit ~ ~ , 5 ~' ~ ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: ~( j` Total Depth measured 12,611' feet true vertical 6,683' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 4380' 9-518" 4380' 3867' PROD. CASING 6479' 7" 6479' 5315' Perforation depth: Measured depth: 6685' - 6699', 8588' - 10350' true vertical depth: CC~~ ~ 61d JUN ~ ~ 208 Tubing (size, grade, and measured depth) 3 1/2", L-80, 6,285' Packers & SSSV (type & measured depth) Baker ZXP LT - 6,243' ~ - 4........... _... .f,....... _., ._.. ..... ~ . 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OiIO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Perry I / MJ Loveland P ' Name Pe I Title Well Integrity Projects Supervisor Signature Phone 659-7034 Date 5/27/2008 v Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only • 1 R-016 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/14/08 05/20/01 05/21 /08 Removed furmanite clamp and cleaned bradenhead with wire wheel.Drilled and tapped two 1/2" holes in conductor. TOC= 8'.Moved ground wire from top to lower ear of tanko cap. t 1 R-01 B T/I/O = 0/0/0. Nitrogen purged IA,OA @ 80 cfu,conductor @ 15 cfu in preparation for braden head weld.Removed tanko top; Applied cooper heat to preheat wellhead 450-500 F degrees .Seal welded Cad braden head with three pass weld while purging with nitrogen per normal braden head weld rocedure. Installed VR plug in IA and OA,normal up wellhead jewelry.MITOA-passed.T/I/0= 0/0/0, pressured up with diesel to 1800 psi.lntial T/I/0= 0/0/1800, 15 min T/I/0= 0/0/1740, 30min T/I/0=0/0/1720,b1ed down to 0/0/O.Final T/I/0= 0/0/0. ph~ito is cc~l~~-ri~ht b~' C'onc~cnPhillihs _alasla. and catul~~t be releasul or l,ithli~lie(i n-tih«ttt c'SS t~Y"lttc;ll Cc~11Nt;nt ut'Cc}ttt~c:c,l'hillihs .-11a{;a .,...- - • ~~LL L ?"~?~4 /1 ~~~/I/T l'~4 E Via= ProActive Diagnostic Services, Inc. To: ACC Chiristine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907j 245-8952 1) Depth Correlatiom 12-* MAr-08 1 R-01 B 2) a6v - r5~ ~ rlo/3a EDE 50-029-21404.02 \~ Signed Print Name: ~~,,~,s~3 /l ~i~~.s Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsaroc9aor~asCa~raism®ryloea.c~rra WEBSITE : ~nN.cre!~orylaca.~~m ~@~~' APR ~ 200 '} ~ ;3 C:\Documents and Settings\Owner\Desktop\Transmit_Conoco.doc ~d. • Y I~~L~ ~O T~~f V~IV// ~/r-11~ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907j 245.8952 1) Caliper Report 2) 12-Mar~08 1 R-01 B a~-l5b ~ ~~05 Signed Print Name: • 1 Report / ESE 50-029-2140402 -~ a1N 1 V 1.~.,',3 PROACTNE DIAGNOSTIC SERVICE8, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (807)245-8951 FAX: (907)245-88952 E-MAIL : 13tlsar~cl3orageCa~rsaernoryReg.cor*a WEBSITE : w+.+v~v.ataerraorvlog.c~na C:1Documents and Settings\Owner\DesktoplTransmit_Conoco.doc Memory Multi-Finger Caliper S Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1R-016 Log Date: March 12, 2008 Field: Kuparuk Log No.: 7695 State: Alaska Run No.: 1 API No.: 50-029-21404-02 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8md Top Log Intvl1.: Surtace Pipet Use: Tubing and Liner Bot. Log Intvl1.: 8,107 Ft. (MD) Inspection Type : Corrosive and Mechanical Inspection COMMENTS This log is tied into the 1R-01A - SLB Slim Cement Mapping Tool (Pup: 7,093) dated 8-Jan-2000. This log was run to assess the condition of the 3.5" tubing and liner logged with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing and liner logged are in good to fair condition with respect to corrosive penetrations, with a maximum wall penetration of 29% recorded in joint 195 (6,207'). The damage recorded appears mostly in the form of General Corrosion and Shallow Pitting. No significant cross-sectional wall loss (> 5°~) are recorded throughout the 3.5" tubing and liner logged. Caliper recordings indicate buckling from 6,476' to 6,786' in the 3.5" liner, including severe buckling in joint 203, restricting the I.D. to 2.68". ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~CANNE[~ MAR 2 5 2008 ~do-1~ ~ ~ lr!°~J • Deposits restrict the I.D. to 2.67" (7,357') in joint 231. A graph illustrating the minimum I.D. recorded on a joint-by joint basis is included in this report. MAXIMUM RECORDED WALL PENETRATIONS Isolated Pitting (29%) Corrosion (22%) Corrosion (20%) Corrosion (20%) Corrosion (20°~) Jt. 195 @ 6,207 Ft. (MD) Jt. 189 @ 6,011 Ft. (MD) Jt. 181 ~ 5,767 Ft. (MD) Jt. 183 ~ 5,832 Ft. (MD) Jt. 192 @ 6,093 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall loss (> 5%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS Deposits Minimum f.D. = 2.67° Jt. 231 ~ 7,357 Ft. (MD) Severe buckling Minimum l.D. = 2.68" Jt. 203 @ 6,497 Ft. (MD) Deposits Minimum I.D. = 2.69" Jt. 244 ~ 7,785 Ft. (MD) No other sign cant I.D. restrictions are recorded throughout the tubing and liner logged. Field Engineer: J. Halvorsen Analyst: HY. Yang / M. Lawrence Witness: J. Hansen ProActive Dia~~nostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDSa~nemorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: (907) 659-2314 • • Correlation of F~ec;orded Damage to Borehole Profile '~" Pipe 1 3.5 in (18.3' -8107.1') Well: 1R-01B Feld: Kuparuk Company: ConocoPhi~ipsAlaska, Inc. Country: USA Survey Date: March 12, 2008 ^ A pprox. Tool D eviation ^ A pprox. Borehol e Profil e 1 22 799 1580 2360 GLM 1 3161 GLM 2 3944 c t a v 4745 ~ Gt1Vl 3 5540 GLM 4 GLM 5 6384 7164 7949 255 8107 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of 8arvey = 255 25 50 ,® ~ 75 100 v .~ z 150 175 200 225 250 1 1 1 1 1 1 1 1 1 1 1 1 1 • • ~~ M inimum Diameter Profile Well: 1 R-01 B SLrvey Date: M azch 12, 2008 Feld: Kuparuk Tool: UWMF~24No.212330 Company: Conoco Phillips Alaska Tool Sze: 1.69 inches Country: US4 Tubing I.D.: 2.992 inches ~~.~. ~..~ ~1 ......J I1:......~Ai.... /t .. \ 0.1 4 c 11 - 17 _ 24 31 =_ 38 45 - 52 59 66 73 80 84 91 98 105 112 = i 119 E 125 ~ 130 Z = e 137 ~_ ~O 144 ~- 151 157 i 162 169 176 160 t87 193 1= 196 i_ 200 207 214 I= 221 i- 227 234 241 I~_~-;, 248 255 -- - -_- ---~ • PDS Report Overview ~---~ s. Body Region Analysis Well: 1 R-01 B ~rvey Date: March 12, 2008 Reld: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillipsAlaska, Inc. Tool Sze: 1.69 Country: USA No. of Fingers 24 Anal ~: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L$0 EUE8md 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and M etal Moss (% wall) ~ penetration body ;,~~ metal loss body 200 150 100 50 0 0 to 1 to 10 to 1 % 10% 20% 20 to 40 to over 40% 85°i6 85°r6 N umber of 'o ints anal se d total = 271 pene. 0 164 104 loss 95 176 0 3 0 0 0 0 0 Damage Configuration (body ) 50 40 30 20 10 0 Mated genera line ring hole/ pow pitting corroson corroson con-oson ible hole Number of ~ointsdama total = 65 24 41 0 0 0 Damage Profile (°/. wall) ~ penetration body . ; metal loss body 0 50 100 GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Bottom of Survey = 255 Analyss Overview page 2 Pf pe: Body Wall: Upset Wall: Nominal I.D ~ ~ PDSR~ORT.DINTTABULAl10N SH~f 3.5 in 9.3 ppf L~0 BJE8md Well: 1R-01B 0.254 in Feld: Kuparuk 0.254 in Company: ConocoPhilipsAlaska, Inc. 2.992 in Country: USA Survey Date: March 12, 2008 .hint No. .#. Depth (R.) Pen. Upset (Ins.) Pen. Body (Ins) Pen. % Metal Loss % Min. I.D. (Ins) Comments Damage Profile (°~wall) 0 50 100 .1 18 0 0.02 7 1 2.94 PU P 1 22 0 0.01 6 1 2.93 1.1 54 0 0.02 6 2 2.91 PU P 1.2 58 0 0.04 17 5 2.95 PU P Shall ow itti n . 1.3 66 0 0.0 7 2 2.93 PU P 2 74 0 0.02 7 1 2.95 3 106 0 0.01 6 0 2.93 4 137 0 0.02 7 1 2.95 5 169 0 0.01 5 2 294 6 200 0 0.02 7 2 2.94 7 231 0 0.02 9 2 2.94 8 263 0 0.02 7 2 2.90 9 294 0 0.02 8 1 .93 10 325 0 0.01 6 1 2.94 11 357 0 0.02 7 2 2.94 1 388 0 0.01 6 1 2.95 13 420 0 0.0 7 1 2.94 14 451 0 0.02 7 1 .95 14.1 462 0 0 0 0 .88 Cam DSNi e 15 484 0 0.02 8 1 95 16 516 0 0.02 7 1 2.95 17 547 0 0.02 8 1 2.95 18 579 0 0.02 8 1 2.94 19 611 0 0.02 7 1 2.95 20 64 0 0.0 8 1 2.95 21 674 0 0.02 8 1 2.95 22 705 0 .0 8 2 2.95 23 736 0 0.02 7 1 2.95 24 7 0 0.02 8 1 2.96 25 799 0 0.02 8 1 2.93 26 831 0 0.02 8 1 2.93 27 862 0 0.02 7 1 2.93 28 893 0 0.02 7 1 2.94 29 925 0 0.02 7 2 2.95 30 954 0 0.02 7 1 2.94 31 984 0 0.01 6 1 2.94 32 1016 0 0.02 9 2 .93 33 1047 0 0.02 8 2 2.92 34 1079 0 0.02 8 2 2.94 35 1110 0 0.02 7 1 2.94 36 1141 0 0.0 9 2 2.94 37 1173 0 0.02 9 0 2.94 38 1 4 0 0.02 9 2 2.94 39 1236 0 0.02 7 2 2.95 40 1267 0 0.01 6 2 2.94 41 1298 0 0.02 8 1 2.95 42 1330 0 0.02 9 1 2.94 43 1361 0 0.02 8 0 2.91 44 1393 0 0.2 8 1 2. 45 1424 0 0.02 8 2 2.93 Penetration Body Metal Loss Body Page 1 ~ i PDS RB~O RT ,~ INT TABU LAT1O N SH ~T Ffpe: 3.5 in 9.3 ppf L~0 flJE8md Well: 1R-016 Body Wall: 0.254 in Feld: Kuparuk Upset Wall: 0.254 in Company: ConocoPhitlipsAlaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 12, 2008 .hint No. .#. Depth (R.) Pen. Upset (Ins.) Peen. Body (Ins) Pen. % Metal Loss % Min. I.D. (Ins) Comments Damage Profile (%wall) 0 50 100 46 1455 0 0.02 9 1 2.94 47 14 7 0 0.02 8 0 .94 48 1518 0 0 02 8 1 2.95 49 1 9 0 0.0 7 1 2.93 50 1580 0 0.02 9 0 2.93 51 1611 0 0.02 7 1 .95 5 1643 0 0.02 8 1 .95 53 1674 0 0.02 8 2 2.92 54 17 5 0 0.02 7 1 2.91 55 1737 0 0.0 7 3 2.92 56 1767 0 0 01 5 1 2.93 57 1799 0 0.02 7 1 2.94 8 1830 0 0.0 8 1 .92 59 1862 0 0.01 5 1 2.94 60 1893 0 0.02 8 1 2.94 61 1924 0 0.02 7 1 2.91 62 1956 0 0.02 8 2 2.93 63 1986 0 0.02 7 1 2.93 64 2018 0 0.02 7 1 2.92 65 049 0 0.0 8 1 2.94 66 2080 0 0.02 8 1 2.93 67 2111 0 0.0 8 1 .94 68 2142 0 0.01 6 1 .95 69 2174 0 0.02 8 1 2.93 70 220 0 0. 8 1 2.93 71 2237 0 0.02 8 2 2.94 72 2267 0 0.02 8 0 2.93 73 2298 0 0.02 8 0 2.92 7 2329 0 0. 7 2 2.91 75 2360 0 0.02 9 2 2.93 76 392 0 0.02 7 0 2.93 77 2423 0 0.02 7 2 2.93 78 2454 0 0. 2 8 0 .92 79 2485 0 0.02 8 1 2.94 80 2516 0 0.0 8 1 2.92 81 2548 0 0.02 8 0 2.94 82 2578 0 0.02 8 0 .93 82.1 2610 0 0.02 9 1 2.92 PU P 82.2 2613 0 0 0 0 N/A GLM 1 Latch 5:00 82.3 2622 0 0.02 8 2 2.9 PU P 3 2628 0 0.0 9 1 2.93 84 2660 0 0.02 7 2 2.93 85 2691 0 0.02 8 2 2.93 86 2723 0 0.02 7 2 2.94 8 2754 0 0.02 8 2 2.90 88 2785 0 0.02 8 1 2.92 89 2816 0 O.D2 8 1 .94 90 2847 0 0.02 7 1 2.94 91 2878 0 0 03 11 0 2.94 92 2910 0 0.02 7 1 2.94 Renetration Body Metal Loss Body Page 2 Pf pe: Body Wall: Upset Wall: Nominal I.D.: • • PDSR~ORT,~INTTABULATION SHAT 3.5 in 9.3 ppf L-80 BJE8md Well: 1R-016 0.254 in Feld: Kuparuk 0.254 in Company: ConocoPhiNipsAlaska, Inc. 2.992 in Country: US4 Survey Date: March 12, 2008 .hint No. .Y. Depth (Ft.) Fin. Upset (Ins.) Pert. Body (Ins) Fin. % Metal Loss % Min. I.D. (Ins) ~rnm~ts Damage Profile (%wall) 0 50 100 93 2941 0 0.02 8 1 2.94 94 2973 0 0.0 9 2 2.94 95 3004 0 0.03 10 2 2.93 96 3036 0 0.0 8 2 .94 97 3067 0 0.02 8 1 2.93 98 3098 0 0.02 9 1 .92 99 3130 0 0.02 8 1 2.92 100 3161 0 0.03 10 1 2.92 101 3192 0 0.02 7 1 2.94 102 3224 0 0.02 7 2 2.90 103 3 55 0 0.02 8 2 2.91 104 3287 0 0.02 8 2 2.92 105 3318 0 0.02 9 2 2.91 1 3349 0 0.02 8 2 2.93 107 3380 0 0.02 8 1 2.93 108 3412 0 0.02 8 2 .93 109 3443 0 0.02 8 1 2. 3 1 0 347 0 0.02 7 2 2.92 111 3506 0 0.02 9 2 2.91 112 3537 0 0.02 8 2 2.91 113 3569 0 0.02 8 2 2.91 114 3600 0 0.02 8 1 2.92 115 3631 0 0. 2 9 1 2.92 Lt. D sts 116 3663 0 0.03 12 0 2.90 Lt. De sts 117 3694 0 0.02 7 1 2.92 Lt. De os s 118 3724 0 0.02 8 2 2.92 Lt. De sits 119 3756 0 0.02 7 2 2.9 Lt. De 'ts 120 3787 0 0.03 10 0 2.91 Lt. De oats 121 3819 0 0.0 7 0 2.92 Lt. De sts 122 3850 0 0.02 8 2 2.89 Lt. De ~ts 123 3881 0 0.02 9 2 .91 Lt. De sts 124 3913 0 0.03 12 0 2.91 125 3944 0 0.02 9 1 292 Lt. De sts 125.1 3976 0 0.02 9 4 2.92 PU P 125.2 3980 0 0 0 0 /A GLM 2 h 0 125.3 3988 0 0.02 7 0 2.90 PU P 126 3994 0 0.03 12 2 .90 Lt. a sts 127 4025 0 0.03 10 2 2.90 Lt. De sts 1 8 4057 0 0.03 11 2 2.9 129 4088 0 0.03 10 2 2.90 Lt. De 'ts 130 4119 0 0.03 11 2 2.91 131 4151 0 0.02 9 1 2.91 1 4182 0 0.03 12 2 2.91 Lt. De sts 133 4214 0 0.02 9 2 2.90 134 4244 0 0.02 9 2 2.89 Lt. De s s 135 4275 0 0.03 12 2 2.91 Lt. De 'ts 136 4307 0 0.02 9 1 2.92 137 4338 0 0.04 14 2 2.85 Shallow ~tti Lt. De 'ts 138 4369 0 0.03 12 0 2.90 . De 't 139 4400 0 0.03 11 2 2.89 Lt. De sts Penetration Body Metal Loss Body Page 3 • PDS RB'ORT ,1~ INT TABU Fipe: 3.5 in 9.3 ppf L~0 aJE8md Well: Body Wall: 0.254 in Feld: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: LATIO N SH ~f 1R-016 Kuparuk ConocoPhi~ipsAlaska, Inc U~ March 12, 2008 ,bint No. ,t. Depth (Ft.) Pen. Upset (Ins.) Fin. Body (Ins) Pen. % Metal Loss % Min. I.D. (Ins) Comments Damage Profile (%wall) 0 50 100 140 4431 0 0.03 12 4 2.89 Lt. De ' s 141 4463 0 0.03 10 3 2.90 Lt. De 'ts 142 4494 0 0.03 12 2 2.90 143 4526 0 0.0 11 2 2.90 144 4557 0 0.02 9 2 2.89 . D e ~ts 145 4 88 0 0.02 9 2 2.89 Lt. D e ~ts 146 4620 0 0.03 10 2 2.88 Lt. De oats 147 4652 0 0.02 9 2 2.87 Li. De oats 148 4683 0 0.03 13 2 2.87 Shallow 'ttin Lt. De ~ts 149 4715 0 0.04 15 2 2.88 Shallow Corroaon. Lt. De ats 150 4745 0 0.03 13 2 2.89 Shallow Corroaon. . De ~ts 151 4776 0 0.0 9 :~ 2.87 allow 'ttin . Lt. De ats 152 4807 0 0.04 14 2.88 Shallow ~ttin Lt. De ats 153 4839 0 0.04 15 2 2.87 Shallow ~ttin Lt. De ats 154 4870 0 0.04 17 2 2.88 Shallow Corroaon. . De ats 155 4901 0 0.04 17 3 2.88 Shallow Corroaon. Lt. De 'ts 156 4933 0 .04 15 3 2.87 Shallow ~ttin . Lt. De 'ts 157 496 0 0.04 15 3 2.87 allow Corroaon. Lt. De ats 157.1 4993 0 0.03 12 2 2.92 PU P 157.2 4998 0 0 0 0 N/A GLM 3 Latch 4:00 157.3 5006 0 0. 3 10 2 2.84 PU P 158 5012 0 0.04 17 2 .87 Shallow Corroaon. Lt. De ats 159 5042 0 0.05 18 4 2.85 Shallow Corroaon. Lt. De ~ts 160 5073 0 0.04 15 3 2.86 Shallow Corroaon. Lt. De ats 161 5104 0 0.05 18 2 2.86 Shallow Corroaon. Lt. De ats 162 5134 0 0.04 16 3 2.86 Shallow Corroaon. Lt. De ats 163 5166 0 0.04 17 2 2.85 Shallow Corroaon. l1. De ats 164 5196 0 0.04 14 3 2.85 Shallow Corroaon. Lt. De ats 165 5226 0 0.04 15 3 2.86 Shallow Corroaon. Lt. De ~ts 166 5257 0 0.04 17 2 2.87 Shallow Corroaon. Lt. De ~ts 167 5289 0 0.05 18 2 2.84 Shallow Corroaon. Lt. De ~ts 168 5320 0 0.04 17 2 2.85 Shallow Corroaon. Lt. De ats 169 5352 0.05 0.04 17 3 2.85 Shallow Corroaon. Lt. De ats 170 5383 0 0.04 17 3 2.86 Shallow Corroaon. Lt. De ats 171 5414 0 0.05 19 3 2.87 Shallow Corroaon Lt. De ats 172 5446 0 0.04 17 2 2.87 Shallow Corroaon. Lt. De ats 173 5477 0 0.05 19 3 2.87 Shallow Corroaon. Lt. De ats 174 5509 0 0.05 19 4 2.85 Shallow Corroaon. Lt. De 'ts 175 5540 0 0.04 17 3 2.85 Shallow Corroaon. Lt. De ats 176 5572 0.05 0.04 16 4 2.86 Shallow Corroaon. Lf. De ats 177 5603 0 0.05 19 2 2.87 Shallow Corroaon. Lt. De ~ts 178 5633 0 0.04 18 3 2.86 Shallow Corroaon. Lt. De ats 179 5665 0 0.04 16 2 2.85 Shallow Corroaon. Lt. De ats 179.1 5696 0 0.03 11 0 2.88 PUP 179.2 5700 0 0 0 0 N/A GLM 4 Latch 2:0 179.3 5709 0 0.04 15 1 2.89 PUP Shallow ittin . Lt. De ats 180 5715 0 0.05 19 3 2.85 Shallow Corroaon. Lt. De ats 181 5746 0 005 20 3 2.86 Corroaon. Lt. De ~ts 182 5778 0 0.04 17 3 .86 Shallow Corroaon. Lt. De s s 183 5809 0 0.05 20 3 2.81 Corroaon. Lt. De 'ts Penetration Body Metal Loss Body Page 4 i PD S RHO RT ,~ IN T TABI I~pe: 3.5 in 9.3 ppf L~0 BJE8md Well: Body Wall: 0.254 in Feld: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • 1 LATI O N SH ~ 1R-01B Kuparuk ConocoPhihipsAlaska, Inc USA March 12, 2008 .hint No. ,t. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins) Pen. % Metal Loss % Min. I.D. (Ins) Comments Damage Profile (%wall) 0 50 100 184 5841 0 0.04 16 3 2.85 Shallow Corroson. Lt. De sts 185 5872 0.05 0.05 20 4 2.86 Shallow Corroson. Lt. De sts 186 5904 0 0.04 15 2 2.84 Shallow Corroson. Lt. De sts 187 5935 0 0.06 22 4 2.85 Corroson. Lt. De sts 188 5966 0 0.04 14 2 2.83 Shallow 'ttin . Lt. De sts 189 5997 0 0.06 22 ~ 2.86 Corroson. Lt. De 'ts 190 6029 0 0.04 17 4 2.86 Shallow Corroson. . De sts 191 6060 0 0.05 19 3 2.86 Shallow Corroson. Lt. De sts 1 6091 0 0.05 20 4 2.85 Corroson. Lt. De sts 193 6122 0 0.04 15 4 2.86 Shallow Corroson. Lt. De sts 193.1 6153 0 0.03 10 2 2.95 PU P 193.2 6157 0 0 0 0 N/A GLM 5 Latch 10:00 193.3 6167 0 0.02 9 :~ 2.91 PU P 194 6174 0 0.04 16 ~ 2.87 Shallow ~ttin Lt. De ~ts 194.1 6205 0 0 0 0 2.81 Camco SNi e 195 6206 0 0.07 29 4 2.88 Isolated ~ttin Lt. De ~t 195.1 6238 0 0.02 9 2 2.89 PU P 196 6244 0 .04 14 2 2.86 Shallow ~ttin . Lt. De sts 196.1 6269 0 0 0 0 4. 8 Baker ZXP LT Packer 197 6271 0 0.05 19 4 2.87 Frst ~oint of liner allow 'ttin Lt. De sts 197.1 6302 0 0 0 0 4.38 Bake r H M C H an r 197.2 6305 0 0.03 10 2 2.86 PUP Lt. De sts 198 6322 0 0.03 12 2 2.84 Lt. De ~ts 199 6353 0 0.03 11 2 2.85 Lt. De ~ts 2 0 638 0 .03 13 2 2.85 Shallow ~ttin Lt. De oat 201 6414 0 0.03 10 2 2.86 Lt. De 'ts 202 6445 0 0.03 12 2 2.88 Lt. De sts 203 6477 0 0.04 16 2 2.68 Severe bucldin 204 6508 0 0.03 11 2.85 Bucldin Lt D sts 205 6539 0 0.03 13 3 2.85 Buddin Shallow Corroson. Lt. De sts 206 6571 0 0.03 10 2 2.89 Bucldin Lt De sts 07 6602 0 0.02 7 2 2.90 BucMin 208 6633 0 0.03 11 4 2.84 Bucldin 209 6664 0 0.03 12 2 2.84 Buddin Lt De sts 210 6694 0 0.03 11 2 2.88 Bucldin Lt. De sts 211 6725 0 0.04 14 3 2.85 Bucklin Shallow ittin Lt. De sts 212 6757 0 0.03 13 2 2.86 Bucldin Shallow Corroson. Lt. De sts 213 6786 0 0.03 10 2 2.87 Lt. De sts 214 6817 0 0.03 12 2 2.89 Lt. De sts 215 6849 0 0.03 10 2 2.90 216 6879 0 0.02 7 2 2.90 217 6908 0 0.02 9 2 2.90 Lt. De 'ts 18 6939 0 0. 3 11 2 2.87 Lt. De sts 219 6969 0 0.03 11 2 2.90 Lt. De oats 0 7000 0 0.0 11 3 2.88 Lt. D e sts 221 7030 0 0.03 11 2 2.87 Lt. D e oats 222 7062 0 0.03 10 0 2.88 L2. D e sts 222.1 7093 0 0.01 6 0 2.91 Marker~oint 223 7103 0 .03 13 3 2.89 Shallow ~ttin Lt. De 'ts 224 7133 n 0.02 9 2 2.85 Lt. De oats Penetration Body Metal Low Body Page 5 • PDS RHO RT ,~ INT TABI Pipe: 3.5 in 9.3 ppf L-80 BJESmd WeN: Body Wail: 0.254 in Feld: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • I LAT1O N SH ~I" 1R-01B Kuparuk ConocoPhiNipsAlaska, Inc USA March 12, 2008 .hint No. .i. Depth (Ft.) Fin Upset (Ins) Pin. Body (Ins) Fin. % Metal Loss % Min. I.D. (Ins) Comments Damage Profile (%wail) 0 50 100 225 226 7164 7196 0 0 0.03 0.03 10 11 2 3 2.85 2.88 . De sts De sts 227 7226 0 0.03 11 3 2.79 . Lt De sts 228 229 7257 7289 G 0 0.02 0.02 9 9 2 2 2.88 2.91 . . De sts 230 7320 0 0.03 12 2 2.83 Lt. De sts 231 7351 0 0.04 14 2 2.67 Shallow ittin . De sts 23 7384 0 0.02 9 2 2.88 Lt De sts 233 7415 0 0.03 10 2 2.85 . Lt D e sts 234 7447 0 0.03 12 3 2.87 . Lt. De sts 235 7478 0 0. 3 11 2 2.90 236 7509 0 0.03 12 2 2 88 237 7541 0 .03 10 2 . 2.88 Lt De ' s 238 7572 0 0.03 11 2 2.89 . 239 7603 0 0.02 9 2 2.89 240 7634 0 0.03 12 2 2.88 Shallow 'tti 241 242 7665 769 0 0 0.03 0.03 13 10 3 2 2.85 .88 Shallow corroson. Lt. De ~ts Lt. De oats 243 244 7729 7760 0 0 0.03 0.03 11 12 2 3 2.87 2 69 Lt. De sts D e sits 245 7792 0 0.03 12 3 . 2.88 Lt De oats 46 78 4 0 0.03 12 3 2 86 . Lt De ~ts 247 7855 0 0.03 11 3 . 2 88 . Lt De 'ts 248 7887 0 0.03 11 3 . 2.86 . Lt. De sts 24 791 0 .03 12 3 2 86 a sits 250 251 7949 7981 0 0 0.03 0.03 13 12 3 2 . 2.86 2 87 Shallow ~ttin . Lt. De sts Lt D e oats 252 53 254 2 5 8013 8045 8077 8107 0 0 0 0 0.03 0.04 0.05 0 13 14 19 0 0 0 1 0 . 2.87 2.87 2.81 0.00 . Shallow ~ttin . Lt. De sts Shallow ~ttin . Lt. De sts Shallow ittin . Lt. De sts Penetration Body Metal Loss Body Page 6 ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ 1 _ ~~, PDS Report Cross Sections Well: 1R-01B Survey Date: March 12, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8md Analyst: HY. Yang Cross Section for Joint 195 at depth 6208.773 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 29 ° • • Finger 7 Penetration = 0.074 ins Isolated Pitting 0.07 ins = 29% Wall Penetration HIGH SIDE = UP ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~- ~c~ PDS Report Cross Sections ~u Well: 1R-01B Survey Date: March 12, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Toot Size; 1.69 Country: USA No. of Fingers: 24 Tubin 3,5 ins 9.3 f L-80 EUE Smd Anal st: HY. Yan Cross Section for Joint 231 at depth 7356.963 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 26 ° e ~I Finger 14 Projection = -0.2 78 ins Deposits Minimum I.D. = 2.67 ins HIGH SIDE = UP ~ i ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~ .~ PDS Report Cross Sections ,~ Well: 1R-016 Survey Date: .March 12, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE 8md Anal st: HY. Yan Cross Section for Joint 203 at depth 6496.874 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 Tool deviation = 44 ° Finger 10 Projection = -0.148 ins Severe Buckling Minimum I.D. = 2.68 ins HIGH SIDE = UP • • °;"~ PHILLIPS Alaska, Inc. KRU 1R-o~B F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Permit to Drill 200t 560 DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. KUPARUK RIV UNIT 1R-01B Operator CONOCOPHILLIPS ALASKA INC MD 12611 TVD 6683 Completion Dat 1/13/2001 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-21404-02-00 UIC N ._ REQUIRED INFORMATION Mud Log N._~o Sample N__~o Directional Survey N._~.o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint OH ! Dataset CH Received Number. Comments. Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? y Chips Recei~ ! Daily History Received? Formation Tops ~N Comments: Compliance Reviewed By: Date: Transmittal Form BAKER HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Anchorage GEOScience Center Reference: 1R-01B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log * Note: No GR/Direetional TVD Log was generated LAC Job#: 86679 Sent By: Glen Hotel Received B,~ {~(~Z, tgx_,~ I Date: Feb 6, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ['~ Gas D Suspended D Abandoned E] Service D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. ,.~.~e,;~ 200-156 3. Address yl'~;" ). APl Number P. O. Box 100360 Anchorage, AK 99510-0360 .~.~~ i, 50-029-21404-02 ,4. Location of well at surface ~~ ~. Unit or Lease Name 153' FNL, 5140' FEL, Sec. 20, T12N, R10E, UM (asp's 539830, 5991050) ~-'-;".'~.i'~*.'/?-~- Kuparuk Unit At Top Producing Interval ! F'.: -i'? ;~ 10. Well Number ~ ../~. / ~'. ~:/."_. i 1R-01B 1104' FNL, 2277' FEL, SEC 20, T12N, R10E, UM (asp's 542701 5990116) At Total Depth = .,~) . 11. Field and Pool 602' FNL, 3240' FEL, SEC 29, T12N, R10E, UM (asp's 541780, 5985332) "' ...... Kuparuk Field 5. Elevation in feet (indicate KB, DF, etc.) 16, Lease Designation and Serial No. RKB 79.9 feetI ADL 25640 ALK 2571 Kuparuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions October 13, 2000 October 17, 2000 December 21,2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth(MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12611' MD / 6683' TVD 8118' MD / 6602' TVD YES [~] No D 'I n/a feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD & GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI j~ i~'[~=LI~.ED,,_._ 16" 62.5# H-40 Surface 115' 24" 260 sxcs ,1 ' %L. 9-5/8" 36.0# J-55 Surface 4380' 12-1/4" 1250 Sx PFE III & 420 Sx PFC 7" 26.0# J-55 Surface 6479' 8-1/2" 65 Sx Class G J,~ 3-1/2" 9.3# L-80 6243' 10915' 6-1/8" 475SxClassG ' *" '~ 4. UUI 2-3/8" 4.43# L-80 10036' 11850' 3" Uncemented pre-drilled liner Alaska Oil & Anchoran~ 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) 8588' - 8665' MD; 6685' - 6700' TVD; @ 4 SPF 3-1/2" 6285' 6243' 8868' - 9232' MD; 6709' - 6718' TVD; @ 4 SPF 9338' - 9390' MD; 6720' - 6718' TVD; @ 4 SPF 9403' - 9850' MD; 6718' - 6714' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10010' - 10350' MD; 6704' - 6698' TVD; @ 4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10036' - 11850' MD; 6702' - 6669' TVD; pre-drilled liner @ 4 SPF 11850' - 12171' MD; 6669' - 6678' TVD; 6-1/8" open hole (See Sidetrack Summary for details) 12171' - 12611' MD; 6678' - 6683' TVD; 3" open hole 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 16, 2001 1800 hrs Flowing Date of Test -Iours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I 1/17/2001 6.0 Test Period > I 399 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (cow) Press. -194 psi 24-Hour Rate > 1594 636 1 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved October 5, 2000 (Permit #200-156) ** No 10-407 for a P&A was submitted with this permit because this completion report is for a we#bore extension. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKER~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverecl and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Kuparuk D 7682' 6365' Top of Kuparuk A3 8370' 6650' RECEIVE£ JAN 2 9 2001 Alaska Oil & Gas Cons. Commission 4nchorage 31. LIST OF ATTACHMENTS Summary of 1R-01 B CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed i~~ 01~,,~~ Title CTDEn,qineer Date ~..~/'~/{~" Lamar Gantt Prepared by Paul Rauf 564-5799. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIG, i qAL 1 R-01 B DESCRIPTION OF WORK COMPLETED COILED TUBING EXTENSION DRILLING OPERATIONS SUMMARY Date Event Summary 10111/2000: 10112/2000: 10/1312000: 10114/2000: 10/15/2000: 10/1612000: 10/17/2000: 1011812000: 1011912000: 10/2012000: 10/21/2000: 11/2312000: 11/24/2000: 11/25/2000: 11/26/2000: 11/27/2000: 11/28/2000: 11/29/2000: MIRU CTU#4 & Nabors 3S. Continued RU. Completed BOP test of reconfigured BOP stack. RIH w/BHA. Swapped well to 1% KCL Water & Biozan. Milled cement / landing collar / float collar f/10735' to 10905' MD. Milled float shoe to 10908' until CT became stuck. Dropped ball & disconnected. POOH leaving fish in hole. H2S drill. RIH & latched fish. POOH - 100% recovery. Made 1 run w/ venturi junk basket. RIH & milled remainder of float shoe to 10910' MD. Milled FM to 10928'. Found oricdaal hole. RIH to 10935'. Conditioned OH. Pumped Brine & POOH. '~ECE[VEO Made a venturi junk basket run. RIH & swapped to 10 ppg FIo Pro. JAN ~, 9 ZOO1 Cleaned out old OH to 12171' MD. Drilled ahead to TD @ 12611 '. ,41aska Oil & Gas Cons, Commission Conditioned OH & circulated KWF. POOH. RIH w/2-3/8" pre-drilled FL4S liner. Anchorage Liner stuck @ 11850'. TOL = 10036'. Attempted to move liner- unsuccessful, Released GS running tool, PUH to 8112' & GS running tool became stuck too. Dropped ball & released f/ running tool. POOH. Evaluated options. Decided to turn fishing job over to service CTU. Swapped well over to 11.6 ppg Brine w/2000' Diesel cap. Attempted to run tubing plug. Installed BPV. RDMOL. Nabors 3S rig released 1400 hrs. MIRU service CTU. PT'd equip. RIH & cleaned out to top of fish @ 8117' CTM. No metal in rtns. Layed in 11.9 ppg Brine f/5000' - 2050'. FP'd well. POOH. LDFN. RIH w/venturi junk basket & cleaned out to 8118'. POOH - recovered metal shavings. Made 2 runs w/venturi junk basket & fishing motor to top of fish. Recovered metal chunks on both runs. Performed FCC w/11.9 ppg Brine & Biozan to 8122'. Cleaned out to 8125' w/venturi junk basket & fishing motor - recovered few pieces of metal (indentations indicated that we were on top of fish & that it was clean). RIH w/ HIPP-Tripper w/ blind box. Engaged fish @ 8118'. PU &hammered @ 8116'. Unable to move fish. POOH. Attempted to mill over fish w/wash pipe & cutover shoe. Slight wear observed on mill face. Sidetrack Summary Page I 1 R-01 B . DESCRIPTION OF WORK COMPLETED COILED TUBING EXTENSION DRILLING OPERATIONS SUMMARY Date Event Summary 1113012000: 12/01/2000: 12/1612000: 1 2/1712000: 1 2/18/2000: 12/1912000: 12/20/2000: 12/2112000: 1102/2001: 1103/2001: 110412001: 1/05/2001: 111312001: Burned over fish to top of GS. Attemped to jar fish down - jars would not go off. Milled on fish w/burning shoe on wash pipe w/motor. Fish did not move. RD CTU. MIRU CTU. PT'd equip. Made 2 venturi junk basket runs to top of fish. Recovered significant metal shavings f/previous milling operations & 9 brass tattletails. LDFN. Made 2 more venturi junk basket runs w/good recovery of metal shavings & 1 brass tattletail. Basket fingers were lodged partially open, may have dumped debris while POOH. LDFN. Began 24 hr fishing operation. Made 3 venturi junk basket runs - heavy recovery on first 2 runs & third run recovered small fines & large piece of metal. Switched over to motor / wash pipe / burning shoe operation. Made 2 washover shoe runs. First one milled to 9119.3' CTM & second to 8117.1 CTM. Milled over fish w/washover shoe to 9119' - could not get any deeper & little wear on shoe. Milled over fish w/2.75" washover shoe to 8120.6 CTM w/some motor work. Unable to get deeper - most likely on GS spear. FP'd well. RD CTU. MIRU CTU. PT' equip. RIH w/washover pipe to top of fish. Milled to 8118.6' MD. Good motor work throughout job. POOH. Burn shoe worn w/taperd btm. RIH & milled to set screws on GS Spear. POOH. RIH w/LIB. POOH. RIH w/nozzle & FCO'd w/Biozan. POOH w/CT. RIH w/HIPP Tripper & pushed fish to 8150' CTM. POOH. Attempted to run venturi to wash up cutting but could not get past 8118'. Recovered 1/3 cup metal cuttings. RIH w/HIPP Tripper but could not get beyond 8127'. POOH. RIH w/motor & 2.625" venturi junk basket to 8118'. Unable to pass obstruction so POOH. Recovered tablespoon of metal- obvious metal scarring on exterior of basket & HIPP Tripper. FP'd well. RD CTU. RIH & drifted tubing to 8054' MD. Recovered small amount of metal junk. Set CS Lock w/ flow through sub @ 6221' Despite the GS Running tool lodged in the wellbore as a fish, the decision was made to place well 1R-01B on initial production. Obtained a valid well test. Sidetrack Summary Page 2 RECEIVED JAN 2 9 Z001 Alaska Oil & Gas Cons. Commission Anchorage BP Amooo WELLPATH DETAILS IR-OIB 500292140402 Parent Wellpath: fR-OIA Tie on MD: 12145.00 Vertical Section Origin: Slot. (0.00,0.00) VerticalSectionAngle: 197.00' Rig: Nabors 3S Depth Reference: 1R-OrA ~ 79.90ft? . .,, REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: 1R-01, True N(xth Vertical (TVD) Reference: System: Mean Sea Level Sacfion (VS) Reference: Slot- (0.00,0.00) Measured Del~h Reference: 1R-OIA 79.9 Calculation Method: Minimum Curvature ANNOTATIONS ~D 6597.81 12145.00 66O2,93 12611.OO ProjededtoTD io Tree North lq[,'lagnclic North: 26.'17" m Cf,cared ay: arij Potnis Dal~: 1117120OI ~'lt..',.. It. ,,,.,..' , :.'. l[" ' ; ' Model: BGGM2000 I I ~ ~ ...................................... -2do0 "~ ....... ~ .............. i"' ;:~ .... ~ .................. i .......... i .... ( ......... , ....... r-' ~ ..... . .......... f ........... 2 .......... .~ ......... ! .......... ~ ........... ~... f .... ~... z_ ~ ~ ..... ~. [ ........ g ..... ~ ......... ~. ........... g ...................... _,-- .......... .,~ ........... -1000 0 1000 2000 3000 6000 8000 2000 4000 West(-)lEast(+) [2000rdin] ...- _-: ............ 4000 5000 6000 Vertical Section at 197.00° [1000ft/in] .. : I ~ i 7000 8000 ;;;0 /"n Plot 1/17/2001 12:51 PM PHILLIPS Alaska, Inc. Baker Hughes INTEQ Survey Report I~T~Q COml~ny: Phillips Alaska, Inc. Ftebl: Kuperuk River Unit $11~ KRU 1R Pad Well: 1R-01 Weal~th: 1R-01B lhte: 3/19/2(X)1 Time: 13:36:51 Page: 1 C.~or4hnte(NE) Rerere=~: Well: 1R-01, True North Vernal (TVD) Referemce: 1R-01A 79.9 Sec~n O/S) Reference: Well (0.00E,0.00N,197.OOAzt) S.r~ CnleMation Method: Minimum Curvature Db: Sybase Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: AlaSka, Zone 4 Coordinate System: Well CenVe Geomapetic Model: BGGM2000 Site: KRU 1R Pad UNITED STATES: North Slope Site Position: Northing: 5991203.26 ff From: Map Easting: 539689.59 ff Position Uncertainty: 0.00 ff Ground Level: 0.00 ff Latitude: 70 23 12.884 N Longitude: 149 40 37.889 W North Reference: True GrM Convergence: 0.30 de0 Well: 1R-01 Well Position: +NI-S -154.04 ft Northing: 5991049.98 ff +K/-W 138.99 ff gusting: 539829.38 ft Position Uncertainty: 0.00 ff Slot Name: Latitude: 70 23 11.369 N Longitude: 149 40 33.820 W Wellpath: 1R-01B Drilled From: 1R-01A 500292140402 Tie-on Depth: 12145.00 ft ,.~ ,-. ~.~, Current Datnm: 1R-01A Height 79.90 ff Above System Datum: Mean Sea Level Magnetie Data: 9/29/2000 Declination: 26.37 deo Field Strength: 57428 nT Mag Dip Angle: 80.72 de0 "',.'.:,"~/ Vertical Section: Depth From (TVD) +N/-S +E/-W Direction '~!...~'_! ff ff ff deg 0.00 0.00 0.00 197.00 Survey: MWD Start Date: 12114/2000 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard . Tied-to: From: Definitive Path Annotation MD TvD ' . '" ft' ft' 12145.00 6677.71 Kick-off Point 12611.00 6682.83 Projected to TD Survey MD . Incl Azim TVD SSTVD' N/S E/W MapN MapE. DLS VS . fi: 'deg deg ff ff ff ff" ft ft. deg/100ft ff' 12145.00 88.43 198.85 6677.71 6597.81 -5364.86 2199.84 5985697.43 542057.54 0.00 12177.00 89.80 201.40 6678.20 6598.30 -5394.90 2188.84 5985667.34 542046.70 9.04 12203.00 91.40 205.00 6677.93 6598.03 -54 18.79 2178.60 5985643.40 542036.56 15.15 12235.00 93.20 206.00 6676.65 6598.75 -5447.65 2164.83 5985614.47 542022.98 6.43 12269.00 93.70 209.50 6674.60 6594.70 -5477.68 2149.03 5985584.36 542007.34 10.38 12291.00 91.20 212.00 6673.66 6593.76 -5496.57 2137.80 5985565.41 541998.20 16.06 12312.00 89.40 214.10 6673.55 6593.65 -5514.17 2126.34 5985547.75 541964.85 13.17 12348.00 89.00 219.70 6674.05 6594.15 -5542.94 2104.74 5985518.87 541963.40 15.59 12379.00 87.50 223.90 6675.00 6595.10 -5566.04 2064.09 5985495.67 541942.88 14.38 12408.00 88.80 228.20 6675.94 6598.04 -5586.15 2063.23 5985475.45 541922.12 15.48 12435.00 89.80 233.10 6676.27 6598.37 -5603.26 2042.36 5985456.22 541901.35 18.52 12468.00 89.10 232.40 6676.58 6598.68 -5623.23 2016.09 5985438.11 54 1875.19 3.00 12505.00 87.80 227.10 6677.59 6597.69 -5647.12 1987.87 5985414.08 541647.10 14.74 12531.00 86.40 223.20 6878.90 6599.00 -5665.43 1989.47 5985395.67 541828.79 15.92 12559.00 86.80 219.70 6680.56 6600.66 -5686.38 1950.97 5985374.63 541810.41 12.56 12573.00 86.60 217.30 6681.37 6601.47 -5697.32 1942.27 5985363.65 541801.77 17.17 12611.00 89.00 213.00 6682.83 6602.93 -5728.35 1920.41 5985332.49 54 1780.08 12.95 4487.27 4519.22 4545.06 4576.68 4610.02 4631.36 4651.54 4685.38 4713.50 4738.83 4761.30 4788.08 4819.17 4842.06 4867.50 4880.51 4916.58 1FL01 (IR4)1} /? lVJdaSncfic North: 2§37°~ ('mucd By: Ufij Pomi, D, tc: J;19;2001 1R-OIB ..,'~-~DipAnsle: 80.72°! u-,~,;/. ,,,; ~,,,, ~ Date: 9/29/20001 PamntWel~/~th: fR. OIA Tinon MD: lZ14~00 Ver~d Sasfinn Origin: Slot- (0.00,0~0) Ve .rdr. d Sm=fion Angle: t97.00° R~:~: Nebom 3S 1FAOIA REFERENCE INFORMATION. Co-ordinate (N/E) Reference: Well Centre: 1R-01. True North VesrteiCal (TVD) Reference: Sv~lm: Mean Sea Level orion (V~ Reference: Slot- (0.00,0.00) Measured Depth Reference: 1R-OIA 7g.9 Calculation Method: Minimum Curveture :: ] : : - ! ' ; [ · _ ! ~ : ! J · ,. : : : :... ;. ~ -"T--' .'r- ..'-"-F ............. '~ ...... ! ...... T ................ -- ............ ~ , ........... ' ; ; ~ ( : ; i i i t ii i i '~ .................................................... ~-.-+-,--t...~ .................. 4 ...... .~ ..... [ ........... ' i .. ! '"[' 4~ ....... ~ ....... ~ ....... ~ ....... : ....... ~ ........ . ...... ~ ....... ~ ...............~~~ ....... , ....... , ....... ~ ....... ~..L....[ .: .................... J ....... J ............... ~ .............. ~ ....... ] ........ : .............. ; ................ ~ ....... ~ ..... ....... 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ANNOTATIONS TVD MD AnnoMliofl 6597.81 121,15.00 Kick-off Point ~02.93 12611.00 Projected ~o TD i ! -"~- i ~ i ~- ." i i i ' -6500 ii ii il i ~ i ~ i i i , i i i i i i i [ i i , , i : , ] , . ~ , .:i i , i ~ ' ~i ~, i ~ i~'--~-F ....... .--'~ ; E ...... ........ .................... ~' ............. ~ ' ........ ' '""~" , I ar -~-:- .............. ~ ....... ~, ............... ,~ ....... i ....... ~ ....... ~- .............. -"- ....... ~ ....... ~ ....... ~ ............. ~ ....... ~ ....... L ....... '~ ............... ~. ........ i ....... ! ....... ~ ...................... ~ ....... r ....... ! ........................ i ....... ~"" - : ~ 4~ I :,.. i ....... .~ ....... ~ ....... -~ ....... ~ ............... ~- ....... ~ ....... : ....... .~ .............. -~ ....... ~- ............... ~- .............. : ........ i ....... i ........ i .............. ! ....... ~ .............. ! ................................. , ; i- ..'-: t ~ , : ~ - ~ ~ ~ : : .~ ~ ~ i ~, ....... i j i ....... ....... ........ i ...................... J ........ L ................................ i i ....... .... ~ .4~, ....... I ....... ~' ....... ~* ............... '~ ....... ~ ....... ~ ....... '~ ............... ~* ....... ~ ....... ( ....... ' .............. ' ....... ' ....... '~ ....... ' ....... ! '1 i i i {i J i i '. i ii i i : i ; i i . i i ; i , i --t--"--i" ' +--"~ .... r .............. ~"--'"i' ...... i''-- ~ ! ~ ~ 1000 1500 2000 2500 3000 3500 :! !J ;i ;' West(-)/East(+) [50Oft/in] i c~ ffPoi~ - i i , :. ,i.' ,' :.i . ' , 1 i ' !1R4 )1 fll ~-01A , I'IR-E f ; i ' " ' _ _~- ..... ---j'-----? i ' j I J ' i i · 'l ---- i i iI I 'r~e~,,d~ J ! ! I R-I]I.IR'I 1B.PIm# , -? ~ , i j I I J ' I , j-~ iJ ..... · j I I i I I I I I I I I I I I 4200 4400 4600 4800 - 5000 5200 5400 5600 5800 Vertical Section at 197.00' [200ft/in] 3/19/2001 1:58 PM ALASIIA OIL AND GAS CONSERVATION CO~IlSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Lamar Gant Coil Tubing Engineer Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1R-01B Phillips Alaska, Inc. Permit No: 200-156 Sur Loc: 153'FNL, 5140'FEL, Sec. 20, T12N, R10E, UM Btmhole Loc. 1160'FNL, 3189'FEL, Sec. 29, T 12N, RI 0E, UM Dear Mr. Gant: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law. from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Commissioner BY ORDER OF THF_~CO~ISSION DATED this ~"~$'~ day of September, 2000 dlf/Enclosures Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA {i ALASKA OIL AND GAS CONSERVATION COMMISSION PER IT TO DRILL 20 AAC 25.005 la. Type of work:. Drill i--I ,~,,, El I lb. Type of well. Exploratory D Strafigraphic Test D Development Oil [~] Re-entry D Deepen DI Service D Development Gas D Single Zone ['~ Multiple Zone D (Extetl$iotl) 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool BP ~), Inc. /'z"O~Zl//', .-~..s ~i~'/,~.~:c. _/~_ . ~,~ RKB 82 feet 3. Address /~O~) ' ~,~/,~;Z)/,_.~..~ ~.~) " 6. Property Designation ~5'~;,j~',-,,z.~.~ Kuparuk Field P. O. Box~[,96e'l'2'-Anchorage, AK 9_~ o_,~s ADL 25640 / ALK 2571 '4~2 Kuparuk Oil Pool 4. Location of well at surface ~' ~' ~/' 7. Unit or pmpe~j Name 11. Type Bond (see 2O AAC 25.0251) 153' FNL, 5140' FEL, Sec. 20, T12N, R10E, UM Kuparuk Unit Statewide At top of productive Interval 8. Well number Number 1957' FNL, 1997' FEL, SEC. 20, T12N, R10E, UM 1R-01 B ~2S100302630-277 At total depth 9. Approximate spud date Amount 1160' FNL, 3189' FEL, Sec 29, T12N, R10E, UM October 5, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) ADL 25635, 1160' O TD feetI No Close Approach feet 2.459 13182 MD / 6695 'I'VD 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 2S.0SS (e)(2)) Kickoff depth: 10915' MD Maximum hole angle 101 ° Maximum surface 3140 pslg At total depth (TVD) 3800 psig @ 6609' · 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casinc. I Wel~lht Grade Couplin~l Len~h MD TVD MD TVD (include sta~le data) 3" 2-3/8" 4.6 L-80 FL4S 2382' 10800' 6708' 13182' 6695' uncemented 3Er'ElSIED \L~-L! v L. 19. To be completed for Redrlll, Re-entry, and Deepen Operations. Present well condition summary TotalDep, h: measured 12171 feet ~'~ Plugs(measured) SEP 2 8 2000 true vertical 6678 feet ~ Alaska Oil & Gas Cons. Comrrlission Effective Depth: measured 10850 feet Junk (measured) ., Anchorage true verfical 6702 feet Casing Length Size Cemented Measured depth True Vertical depth CONDUCTOR 115' 16" 260 Sx CS II 115' 115' SUR. CASING 4298' 9-5/8" 1250 Sx PFE III & 420 Sx PFC 4380' 3867' PROD. CASING 6397' 7" 65 Sx Class G 6479' 5315' Liner 4672' 3-1/2" 475 Sx Class G 10915' 6698' Perforation depth: measured 8588' - 8665'; 8868' - 9232'; 9338' - 9390'; 9403' - 9850'; 10010' - 10350'. true verfical 6685'- 6700'; 6709'- 6718'; 6720'- 6718'; 6718'- 6714'; 6704'- 6698'.ORIGINAL 20. Attachments F,i.gfee Prope,y P at I--I BOP Sketch 1'71 ave,erSketch I--I Dr,,.g p ogram 1'71 Ddlling fluid program Time vs depth plot r'~ Refraction analysis r~ Seabed report r-] 20 AAC 25.050 requirements r-~ 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Mark Johnson O 564-5666 or ~ ...~~, Dan Venhaus ~ 564-5273. Signed Title: Coil Tubing Engineer Date e/Z'~/O~ Lamer ~antt Prepared by Paul Rauf 564-5799 Commission Use Only Perm, Number .~.../.~ I APInumber ~"~l Approvaldate ISeecoverletter 50- ~>Z.~-- ~Z./f..~'o~:~) / ~- ~,~'~;)~) ifor other requirements Conditions of approval Samplasrequired r'~ Yes. ~ No Mud logrequired ~] Yes .~ No Hydrogen sulfldemeasures [~ Yes D No' Dlrectlonal survey required ~ Yes r"] No Required working pressure for BOPE r'~2M; D 3M; D 5M; D lOM;D r~ 3500 psi for cTu Other: ORIGINAL SIGNED BY by order of Approved by D Taylor Seamount Commissioner the commission Date /~) "*.~""~ ~O Form 10-401 Rev. 12/1/85 · Submit in triplicate SFNT BY: 10- 3- 0 ; 2:09PM : PHILLIPS AK KRU 1R-O1B CT Extension Intended Procedure INC~ {" Objective: Mill through float equipment. Directionally drill a horizontal extension to this arcady horizontal well. Complete with 2-3/8" pre-drilled liner. 907 276 7542:# 2/ 2 Intended PFoced,,uFe: · Mill landing collar/float collar/float shoe w/2.8" mill. Directionally drill a 2-3/4" (Y' bi-center) well using dynamically overbalanced drilling techniques. Planned TD is 131112' md. · Run 2-3/8" pre-drilled liner to TD. Place on production. Drilling fluids will be injected into a dedicated Class H disposal well. Dynamically overbalanced drilling techniques will be employed to address high reservoir pressure. Plans are to use -- 8.9 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the upper BOP pipe/slips (2-3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as stripper. Lower BOP rams will be used only for primary well control. At least two times hole volume of kill weight fluid will be on location as a contingency. October 3, 2000 Kuparuk 1R-01B Potential Drilling Hazards POST ON RIG H2S was measured at 80 ppm in June 2000. The IR pad is a designated H2S area. H2S procedures must be followed according to the AK Safety Handbook. Ensure H2S monitoring equipment is functional. All personnel must be supplied with adequate PPE, e.g. monitors, scat packs, etc. Influxes of reservoir fluid could result in H2S in pit area, although KRU CTD sidetracks in the past have not seen this. BHP: 3800 psi @ 6609' TVD, 6529'ss (11.1 ppg EMW) based on static survey 2/27/00. Reservoir frac gradient is ~0.8 psi/ft or 15.4 EMW, 5290 psi. Plans are to drill with less than kill-weight fluid (8.9 ppg Flo-Pro). While circulating at least 1 bpm, BHP will exceed reservoir pressure due to high ECD. However, when circulation is shut down, the reservoir will be underbalanced by ~760 psi. Maintain at least 950 psi WHP when not circulating to prevent reservoir in-flux and maintain formation stability. Monitor return-line flow rate and pit volume continuously. If crude enters the pits, take all returns to an outside tank first. Maximum anticipated WHP w/full column of gas: ~3140 psi assuming 0.1 psi/ft gas gradient. No gas saturated intervals are expected. September 27, 2000 1 R-01 B CTD Extension - 493' MD 3-1/2" Cameo 'DS' landing Proposed Com pletion nipple with 2.875" ID 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to surtaee. Depth's are 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to 'DS' landing nipple wi 3-1/2" x 1" Cameo 'KBMM' mandrels based on Pool 6 GLM# MD TVD RKB to the 1 6175 5096 hanger 80' 2 5718 4779 3 5015 4297 4 3998 3601 5 2632 2597 6221' MD 3-1/2" Cameo 'DS'landing nipple with 2.812" ID and No-Go profile ( 6259' MD Baker 3-1/2" 'GBH-22' Tubing Seal Assembly. 3" ID Liner TOD 6243' MD Baker 5" x 7" 'ZXP' Liner Top Isolation Packer 6257' MD Baker 5" x 7" 'HMC' Liner Hanger 6264' MD Baker '80-40' PBR (12' Length wi 4" ID seal bore) Window in 7"@ 6308' MD Baker OS wi pack-off 6479' MD Solid Liner 3-1/2" 9.3# L-80 EUE 8rd Mod from Liner Hanger to Landing Collar. 7" Baker Bridge Plug set @ +/.6515' MD. Note: 3-1/211 liner was unable to reach TD and was set @ 10915'. Due to cemented completion, CTD BHA is unlikely to follow old l' hole. New directional plan is west of old 6-1/811 openhole. \ I - 10800' MD 2-3/8" proposed 12171' 6-1/8" 0 h I TD Abandoned C-Sand liner top j , pen 0 e Perts ;----------, !! ' . ... .,. i 3" openhole 2-3/8" FL4S Pre-drilled liner + Abandoned A-Sand I I Proposed TD @ Perts - - - - - - - - - J +/- 13 200' 10850' MD 3-1/2" Baker Landing Collar ' 10851' MD 3-1/2" Gemeeo Float Collar 10914' MD 3-1/2" Gemeeo Float Shoe 7",26#, J-55 casing @ 8535' MD 9/15/00 by DEV ARCO Plan.xlt AR C 0 A1 a s k a, I n c. '--*'~-*~-~ .................. ~~ Sfrucfure:Pad 1R Well: 1R-O1BPIon ~ Field : Kuparuk River Unit Location : North Slope, Alaska~ East ee -> i i I i i i i i i i i i i i i i i i i i i i i , ~ / . K~k--o¢ Point 4200 / ~:iR-01 T4 , 5 4500 ]~R--01 T5 / :- ' /,._o,../t./ ,.o~ / t ? , ~o- ?.-o, ~ /' 1R-01 TS~ .? ' 61~0. ~~j/~ , ~600 '' ~ ~- ' 7 1~-01 T11 6~0 <~ ~ 5 , :: ~' -~ TD 6750 ] , . , , . . 2850 ~00 3150 ~00 ~ 3~ 37~ 39~ ~ 42~ ~0 45~ 4650 48~ 4950 5100 52~ 54ffi5550 57~ 58~ 60~ 6150 Ve~icol Section (feet) -> Azimuth 197.00 with reference 0.00 N, 0.00 E from 1R-01 Prepared by BHI 9/26/2000 MD 11914.00 11939.00 11964.00 11989.00 12000.00 12014.00 12039.00 12064.00 12089.00 12100.00 12114.00 12137.16 12139.00 12164.00 12189.00 12200.00 12214.00 12239.00 12264.00 12289.00 12300.00 12314.00 12339.00 12364.00 12389.00 12400.00 12414.00 12439.00 12464.00 12489.00 12500.00 12514.00 12539.00 12564.00 12589.00 12600.00 12614.00 12639.00 12664.00 12689.00 12700.00 12714.00 12739.00 12764.00 12789.00 12800.00 12814.00 12839.00 12864.00 12889.00 12900.00 12914.00 12939.00 12964.00 12989.00 13000.00 13014.00 13039.00 13064.00 13089.00 13100.00 13114.00 13139,00 13164.00 13181.75 Azi 1R-01BV2NPD.XLS 213.74 215.32 216.90 218.48 219.18 220.07 221.65 223.23 224.81 225.51 226.39 227.86 227.74 226.14 224.54 223.84 222.95 221.35 219.75 218.15 217.45 216.56 214.96 213.36 211.76 211.06 210.16 208.57 206.97 205.37 204.67 203.77 202.18 200.58 198.98 198.28 197.38 195.78 194.19 192.59 191.88 190.99 189.39 187.79 186.20 185.49 184.60 183.00 181.40 179.81 179.10 178.21 176.61 175.01 173.41 172.71 171.82 170.22 168.62 167.02 166.32 165.43 163.83 162.23 161.10 TVD (BRT) 6661.28 6662.15 6662.99 6663.80 6664.15 6664.58 6665.33 6666.06 6666.75 6667.O5 6667.41 6668.00 6668.05 6668.67 6669.30 6669.58 6669.94 6670.58 6671.23 6671.89 6672.18 6672.55 6673.22 6673.89 6674.57 6674.87 6675.25 6675.93 6676,62 6677.31 6677.61 6677.99 6678.68 6679.37 6680.06 6680.36 6680.75 6681.44 6682.12 6682.80 6683.10 6683.48 6684.16 6684.83 6685.50 6685.79 6686.16 6686.82 6687.47 6688.11 6688.39 6688.75 6689.38 6690.00 6690.61 6690.88 6691.22 6691.81 6692.40 6692.97 6693.22 6693.53 6694.08 6694.62 6695.00 TVD (MSL) 6581.28 6582.15 6582.99 6583.80 6584.15 6584.58 6585.33 6586.06 6586.75 6587.05 6587.41 6588.00 6588.05 6588.67 6589.30 6589.58 6589.94 6590.58 6591.23 6591.89 6592.18 6592.55 6593.22: 6593.89 6594.57 6594.87 6595.25 6595.93 6596.62 6597.31 6597.61 6597.99 6598.68 6599.37 6600.06 6600.36 6600.75 6601.44 6602.12 6602.80 6603.10 6603.48 6604.16 6604.83 6605.50 6605.79 6606.16 6606.82 6607.47 6608.11 6608.39 6608.75 6609.38 6610.00 6610.61 6610.88 6611.22 6611.81 6612.40 6612.97 6613.22 6613.53 6614.08 6614.62 6615.00 542221.89 542207.84 542193.22 542178.05 542171.20 542162.34 542146.09 542129.33 542112.06 542104.31 542094.30 542077.42 542076.06 542057.90 542040.21 542032.59 542023.03 542006.36 541990.22 541974.61 541967.92 541959.56 541945.06 541931.14 541917.80 541912.12 541905.06 541892.93 541881.40 541870.50 541865.90 541860.23 541850.60 541841.62 541833.29 541829.83 541825.61 541818.61 541812.28 541806.62 541804.35 541801.65 541797.36 541793.75 541790.84 541789.78 541788.62 541787.10 541786.27 541786.14 541786.30 541786.71 541787.97 541789.93 541792.58 541793.96 541795.92 541799.95 541804.67 541810.07 541812.66 541816.15 541822.90 541830.33 541836.00 Page 2 of 2 5985900.23 5985879.57 5985859.31 5985839.46 5985830.86 5985820.04 5985801.05 5985782.53 5985746.89 5985731.05 5985729.81 5985712.65 5985694.99 5985676.85 5985658.23 5985639.16 5985619.64 5985610.92 5985599.70 5985579.35 5985558.59 5985537.46 5985528.05 5985515.97 5985494.13 5985471.96 5985449.47 5985439.48 5985426.69 5985403.64 5985380.32 5985356.76 5985346.32 5985332.98 5985309.00 5985284.82 5985260.49 5985249.73 5985236.00 5985211.38 5985186.65 5985161.84 5985150.89 5985136.95 5985112.01 5985087.03 5985062.04 5985051.05 5985037.06 5985012.10 5984987.19 5984962.34 5984951.44 5984937.58 5984912.92 5984888.38 5984863.98 5984853.29 5984839.74 5984815.68 5984791.81 5964775.00 Company: Well: Calculation Method: Vertical SecL Plane: Measured Depth ~om: ~D 10864,04 10889,00 10898,47 10900,00 10914,00 10915,00 10939.00 10964.00 10980,90 10989,00 11014,00 11020,00 11039,00 11061,25 11064,00 11085,00 11089,00 11100,00 11114.00 11139,00 11164,00 11189,00 11200,00 11214,00 11239,00 11264.00! 11289,00 11300,00 11314,00 11339,00 11350,00 11364,00 11389,00 11400,00 11414,00 11439,00 11464,00 11489,00 11500,00 11514,00 11539,00 11549,78 11564.00 11589,00 11600,00 11614,00 11639,00 11664,00 11689,00 11700,00 11714,00 11739,00 11764,00 11789,00 11800,00 11814,00 11839,00 11864,00 11889,00 11900,00 1R-01BV2NPD,XLS Arco Alaska Inc, 1R-01B Version#2 Minimum Curvature 197,00 RKB 80,00 Azi TVD (BR'I') TVD (MSL) 195,81 6702.02 196.09 6700,16 196,19 6699,43 196,17 6699,31 196,02 6698,21 196,00 6698,13 196,00 6695,93 196.00 6692,98 196,00 6690,61 196,00 6689,36 196,00 6685,08 196,00 6683,95 196,00 6680,52 196,00 6676,98 196,00 6676,58 196,00 6673,79 195,76 6673,30 195,09 6671,98 194,25 6670,33 192.73 6667,47 191,22 6664,74 189,70 6662,12 189,04 6661,00 188,19 6659,62 186,68 6657,24 185,18 6654.99 183,67 183,01 6651,98 182,17 180,66 6649,01 180.00 6648,23 180.75 6647,31 182,09 6645,95 182,68 183,42 6644,96 184,76 6644,34 186,09 6644,08 187,43 6644,19 188,01 6644,36 188,76 190,10 6645,52 190,67 6646,00 191,57 6646,67 193,16 6647,85 193,86 6648,36 194,74 6649,00 196,33 6650,14 197,91 6651,26 199,49 6652,36 200,19 6652,84 201,08 6653,44 202,66 6654,50 204,24 6655,54 205,83 6656,56 206,52 6657,00 207,41 6657,55 208,99 6658,52 210,57 6659,47 212,16 6660,39 212,85 6660,78 X Y 6622,02 542468,61 5986905,40 6620.16 542461,90 5986881.43 6619,43 542459,33 5986872,35 6619,31 542458,91 5986870,88 6618,21 542455,11 5986857,45 6618,13 542454,84 5986856,49 6615,93 542448,38 5986833,49 6612,98 542441.66 5986809,59 6610,61 542437,13 5986793,49 6609,36 542434,97 5986785,78 6605,08 542428,30 5986762,07 6603,95 542426,71 5986756,40 6600,52 542421,65 5986738,41 6596,98 542415,71 5986717.27 6596,58 542414,97 5986714,65 6593,79 542409,34 5986694,62 6593,30 542408,27 5986690,79 6591,98 542405,42 5986680,25 6590,33 542401,97 5986666,78 6587,47 542396,31 5986642,61 6584,74 542391,29 5986618,27 6582,12 542386,90 5986593,80 6581,00 542385,18 5986583,00 6579,62 542383,16 5986569,21 6577,24 542380,07 5986544,52 6574,99 542377,63 5986519,75 6572,87 542375,84 5986494,91 6571,98 542375,26 5986483,96 6570,87 542374,71 5986470,01 6569,01 542374,22 5986445,09 6568,23 542374,22 5986434,12 6567,31 542374,20 5986420,15 6565,95 542373,72 5986395,20 6565,47 542373,32 5986384,22 6564,96 542372,65 5986370,24 6564,34 542371,00 5986345,31 6564,08 542368,77 5986320,41 6564,19 542365,95 5986295.58 6564,36 542364,53 5986284,67 6564,67 542362,57 5986270,81 6565,52 542358,60 5986246,15 6566,00 542356,72 5986235,55 6566,67 542354,05 5986221,60 6567,85 542348,84 5986197,18 6568,36 542346,33 5986186,48 6569,00 542342,94 5986172,91 6570,14 542336,39 5986148,82 6571,26 542329,16 5986124,91 6572,36 542321,28 5986101,22 6572,84 542317.61 5986090,86 6573,44 542312.75 5986077.75 6574,50 542303,57 5986054,52 6575,54 542293,75 5986031,56 6576,56 542283,30 5986008,87 6577,00 542278,51 5985998,98 6577,55 542272,23 5985986,48 6578,52 542260.55 5985964,41 6579,47 542248,25 5985942,66 6580,39 542235,37 5985921,26 6580,78 542229,51 5985911,96 . Page 1 of 2 KRU CTD BOP Detail ~ CT Injector Head Methanol Injection ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I - 7" Riser tis 7" WLA Quick onnect ----- I 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Hydril Model B HCR Flanged Fire Resistant Kelly Hose to Dual Choke Manifold Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure 12 3/8" Pipes I I 2 318" Slips I Manual valves Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic XO Spool 3 1/8' x 7 1/6' or as necessary 2' Side outlets I Blind/Shear I 2" Combi Pipe/Slip 2 flanged gate valves Single or Double Manual Master Valves THA Tubing Spool 7" Annulus MOJ 9/16/OO 9 5/8" Annulus ARCO Alaska, Inc. NIP (493-494, oo:4~2} Gasut MandreUVa~ 1 (2632-2633, 0D:6.018) andrel/Dun~j Va~e2 (3m8-3~9, 00:6.018) Gas Ut ManclrelNalve 3 (50155016, OD:6.018) Gas Ut andml/Dummy Valve 4 (5718-5719, O0:6.018) Gas Lift MandmlNalve 5 (6174-6175, 0D:6.018) NIF OD:4.520) TUBING (0.6265, ID:2.992) HANGER (6257-6258, 0D:5.875) SEAL (6259-6260, GKA 1R-01A · 1R-01A APl: 1500292140401 ' ._..W..e.!l Type.:_.pROD ......... .Angle_~ T...S. LLde~' ~ ........ ' - '$'SS~T~/~e:]NONE ..... OrigCompletion: 12/25/99 ..... Angie~TD:188deg~1~"~1 ' Annular Fluid: I SWIDSL Last W/O: Rev Reason:I GLV das'.~n by Reference L.Og:1 ...... . R_of Log Date:, ; ...... .L__a,~. t. U .p<J. ate:_~3/~-0~T~'' -."- * .... '£~-st'T~g:I .......... 'rD: ":f~'l Y'I ftK'~'- ....... / Last Tag Date.:l Max Hole AngJ~....98 deg~ 11187 Casing String - ALL like_ ........... T..OP... L. _.._Botto..m..._I'~_.D.. !_. ~ .... ~..Grade ........ Thread 9.625 0 4380 ; 3867 36.00 J-55 BTC 7.000 O 6479 .5.315 26.00 J-55 .......... .BTC 16.000 0 121 121 62.58 H-40 WELDED ....... --"__:_'._3...5IX)__.-'_-'" ...:~22t"3-'.'- .... '.":'7i_091~::'..~..' ..... ~.98'-':_-'::_9_...30 ~.'-.[.-.'~---..' ..... ._ E___.UE 8m_~d __. :Tubing String - TUBING : Size I .Top I Bottom TVD wt ~ Grade L_' Thread .. ' EUE 8md 3.500 ........ 0 ..... 6285 .......... 5175 ...... .9:_3_0 ,::.~-__80 :'". ........... -Perfo~iions Summ.._a~: -"i'n~-i .......... ~/5 ..... ~'~' "'~-~§Si'~' ~J~F ~-t-~"~"~-~'~'-, ........ comment '8588.- 8665 668~ - ~00 (4,{~5 77 4 2/18/00 IPERF . 2_1_./~..H.S_.D_~.p._ow~.f..__~.t, 60 ~ ....... 8868- 9232 6709 - 6718 364 ..4_ .2/. 18~.0._[P. ER.F.-.2 1./2_.H..SD.~_.P .oW~.._r_J_e..t, 6_0 deg ........ ".93'~:'¢~3.~b-'' ~'~2~': ~.7~'~ ............ I,&4~ ....... 52 4 2/18/00.1PERF 2 1/2 HSD, PowerJet, 60deg 9403- 9650 6716 - 6714 447 4 2/18/00 IPERF 2_l./2.._H,.SD,._P...mve..r.Jet, 60 .d..ag ............. 10010- 6704-6698 340 4 2/t8/00 IPERF .2 l/2HSD, UltraJet, 8Odeg · .]..o_3_5...o,._~.. · ............... ~ Gas Lift Mandrels/Valves Mfr . .Type ................................. ~ ........ R.u_.n. .... C_o__m. me._._qn! "I '_'"':~8:~2' "2597 I~:AJ~I~O KBMM CAMCO' GLV _. 1.0 BK-5 20.!56 1342 3/8/00 2. 3998 3601 CAMCO KBMM, CAMCO DMY 1.0 BK-5 0.000 0 12/25/99 3 . 5015~ 4297 CAMCO KBMM CAMCO' ~=LV 1.0 BK-5 0.168 1~65[ 3/8/00 ..... .4..' 5718 4779 CAMCO KBMM CAMCO DMY 1.0 BK-5 0.000 0 ,12/25/99 .............. 5 6174.. 5096 CAM-CO MMM CAM~O .OV 1.5 RK ...=.0.188 0 3/8/00 Other (plugs, e(luip. Letc.) - JEWELRY Depth, TVD; Type Description ' ID 493 493 NIP CAMCO DS. , .................. 2._8.75.. ..... i~221'-' ~-1'29': ........ NI~ ......CAMC~ DS. ' .............................. 2.812, 6243' 5145 PKR BAKER ZXP LT. ' 4.375 6257 5155 HANGER BAKER HMC. ' 4.375 6259 5157 SEAL BAKER GBH-22. ' 4.~0-'~ .... 6264 5160 $BE ' 4.000 !"1~85~)-. '~703'-[.~NDI~I~ ........................................................ :' ~,.'~-Oo .... .......... c., .O..L.LA~_ ................... SBL (6264-6265, 00'~.000) (8588-8665) (8868.9232) P~ (10010-10350) LANDING COLLAR (1O850-10851, OD:5.000) ,FW: 1R-O i B Anti-collision Views Subject: FW: 1R-01B Anti-collision Views Date: Tue, 3 Oct 2000 02:06:11 +0100 From: "Rauf, Paul C" <RautPC~BP.com> To: '"steve_davies~admin. state.ak.us'" <steve_davies~admin. state.ak.us> Steve, Enclosed is the close approach graphs for 1G-09 / 1R-01B proposed plans. ..... Original Message ..... From: Potnis, Brij P (BHI) Sent: Monday, October 02, 2000 10:53 AM To: 'Dan Venhaus (BP) '; 'Dan Venhaus (PP) ' Cc: Rauf, Paul C; 'Paul Rauf (PP)'; Gantt, Lamar L; Gantt, Lamar L (Phillips); 'Brij Potnis (BHI) ' Subject: 1R-O1B Anti-collision Views <<IR-O1B Plan #2 Anticollision Views.xls>> The closest approach for 1R-O1B Plan #2 with 1G-09 is 1024.81 feet (center-to-center distance). [Rauf, Paul C]. Brij Potnis Technical Support Engineer Baker Hughes INTEQ, Alaska * (907) 267-6613 * Brij. Potnis~inteq. corn * PotnisBP~BP. corn x4102 Cube 754B - NW Corner Name: 1R-0 lB Plan #2 Anticollision Views.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) .Enc?ding.:.....bas. e64 ............................................................................................ ::.__..~.:::::......::.:. ................. ::....: ................ :~:.::.~.....: ............ ::.:..:::..: 1 of 1 10/3/00 11:15 AM 1R-01B PLAN #2 CLOSE APPROACH TO 1G-09.TXT BP Amoco Anti col l i si on Report Company: BP Amoco Page: 1 Field: Kuparuk River unit Reference Site: KRU iR Pad North Reference well: 1R-01 Reference well pathPlan#2 1R-01B Db: sybase NO GLOBAL SCAN: using user defined selection & scan criteria & PLANNED PROGRAM Interpolation MethodMD Interval: 10.00 ft Depth Range' 79.90 to 13180.32 ft Azimuth Maxi mum Radi us: 1510.04 ft Casing Survey Program for Definitive wellpath Date' 9/29/2000 validated: No Planned From TO Survey ft ft 97.90 6397.90 unknown - Gyro (0) 6490.64 10864.04 unknown - MWD (1) 10864.04 13180.32 Planned: Plan #2 vi Casing Poi nts MD TVD Diameter Hole si ze Name Date: 10/2/2000 Ti me: 13: 43: 11 Co-ordinate(NE) Reference: well: 1R-01, True Vertical (TVD) Reference: 1R-01A 79.9 Reference: Error Model: Scan Method: Error surface: Principal Plan ISCWSA Ellipse High side + Ellipse + Version: Tool code UNKNOWN UNKNOWN MWD Too1 Name Unknown survey unknown survey MWD - Standard summary A11 owabl e site Deviation Warning well KRU 1G Pad 1G-09 No Reference Casings Offset wel 1 path wel 1 path 1G-09 v2 MD ft I3036.57 Page 1 Reference offset Ctr-Ctr No-Go MD Di stanceArea ft ft ft ft 8280 00 1024 81 ~]~.- . .. · · , · · -,~¢, .:~ ': , ~," '~ : '" ' -- 'i ~': · . · F 0 5 ,'\i~,SkEi ('Jif c],~ {it~:.'.-:.'. i;Oi]~. site: KRU 1G Pad we] ]: 1G-09 Risk We] 1 path: 1G-09 V2 ft Reference Al ] owab] e MD TVD Deviation Warning ft ft MD 1R-01B PLAN #2 CLOSE APPROACH TO 1G-09.TXT offset TVB ft Rule Assigned: Major Inter-Site Error: 0.00 semi-Major Axis Ctr-Ctr No-Go Ref offset TFO+AZI TFO-HS Casing DistanceArea ft ft deg deg i n ft ft ft 13180.32 6694.85 7530.00 6218.77 208.73 183.07 227.60 66.10 FAlL 13180.32 6694.85 7540.00 6227.44 208.73 183.38 227.95 66.45 NO Reference casings 13180.32 6694.85 7550.00 6236.13 208.73 183.69 228.29 66.79 No Reference casings 13180.32 6694.85 7560.00 6244.84 208.73 183.99 228.64 67.14 No Reference casings 13180.32 6694.85 7570.00 6253.56 208.73 184.30 229.00 67.50 No Reference Casings 13170.31 6694.57 7580.00 6262.31 208.63 185.31 229.98 67.84 No Reference Casings 13168.41 6694.52 7590.00 6271.08 208.61 185.74 230.46 68.20 No Reference casings 13166.52 6694.47 7600.00 6279.86 208.59 186.18 230.94 68.57 NO Reference casings 13164.64 6694.41 7610.00 6288.66 208.57 186.60 231.43 68.93 NO Reference casings 13162.78 6694.36 7620.00 6297.48 208.55 187.02 231.92 69.31 NO Reference Casings 13160.92 6694.31 7630.00 6306.31 208.53 187.45 232.41 69.68 NO Reference Casings 13159.07 6694.26 7640.00 6315.16 208.51 187.87 232.91 70.06 NO Reference Casings 13150.00 6694.00 7650.00 6324.02 208.41 188.77 233.86 70.43 No Reference Casings 13150.00 6694.00 7660.00 6332.90 208.41 189.06 234.25 70.83 NO Reference Casings 13150.00 6694.00 7670.00 6341.79 208.41 189.36 234.64 71.22 No Reference casings 13150.00 6694.00 7680.00 6350.70 208.'41 189.65 235.04 71.62 No Reference casings 13150.00 6694.00 7690.00 6359.62 208.41 189.94 235.45 72.02 No Reference Casings Page 2 1222.83 1217.60 1212.42 1207.30 1202.24 1197.16 1192.19 1187.27 1182.42 1177.63 1172.90 1168.23 1163.67 1159.11 1154.62 1R-01B PLAN #2 CLOSE APPROACH TO 1G-09.TXT 13150.00 6694.00 7700.00 6368.55 208.41 190.23 235.86 72.43 No Reference Casings 13150.00 6694.00 7710.00 6377.50 208.41 190.53 236.27 72.84 No Reference casings 13150.00 6694.00 7720.00 6386.43 208.41 190.82 236.68 73.26 NO Reference Casings 13150.00 6694.00 7730.00 6395.37 208.41 191.10 237.10 73.67 No Reference Casings 13150.00 6694.00 7740.00 6404.30 208.41 191.39 237.51 74.09 No Reference casings ~13150.00 6694.00 7750.00 6413.23 208.41 191.68 237.94 74.51 No Reference Casings 13150.00 6694.00 7760.00 6422.16 208.41 191.97 238.36 74.94 NO Reference casings 13135.56 6693.60 7770.00 6431.08 208.19 193.21 239.68 75.34 NO Reference Casings 13133.74 6693.54 7780.00 6440.00. 208.17 193.61 240.22 75.77 No Reference Casings 13131.93 6693.49 7790.00 6448.92 208.14 194.02 240.76 76.20 No Reference Casings 13130.10 6693.44 7800.00 6457.83 208.11 194.42 241.31 76.63 No Reference Casings 13128.27 6693.39 7810.00 6466.74 208.08 194.83 241.86 77.07 NO Reference Casings 13126.43 6693.34 7820.00 6475.64 208.06 195.25 242.42 77.50 No Reference Casings 1141.59 1137.38 1133.24 1129.16 1125.14 1121.18 1117.28 1113.25 1109.42 1105.66 1101.95 1098.31 1094.76 Company: BP Amoco Page: 2 Field: Kuparuk River Unit Reference Site: KRU 1R Pad North BP Amoco Anti col 1 i si on Report Date' 10/2/2000 Ti me' 13' 43' 11 Co-ordinate(NE) Reference- well: 1R-01, True Page 3 1R-01B PLAN #2 CLOSE APPROACH TO 1G-09.TXT Reference well · 1R-01 vertical (TVD) Reference' 1R-01A 79.9 Reference well pathPlan#2 1R-018 Db' Sybase Site: KRU 1G Pad wel 1: 1G-09 Risk wellpath: 1G-09 V2 ft Reference A11 owabl e MD TVD Deviation Warning ft ft MD offset l~D ft Rule Assigned: Major Inter-Site Error: 0.00 semi-Major Axis Ctr-Ctr No-Go Ref offset TFO+AZI TFO-HS casing DistanceArea ft ft deg deg i n ft ft ft 13124.58 6693.28 7830.00 6484.53 208.03 195.66 242.97 77.94 No Reference Casings 13122.71 6693.23 7840.00 6493.42 208.00 196.07 243.54 78.39 NO Reference Casings 13120.83 6693.18 7850.00 6502.29 207.97 196.48 244.10 78.83 No Reference Casings 13118.94 6693.13 7860.00 6511.17 207.94 196.90 244.67 79.28 NO Reference Casings 13117.04 6693.07 7870.00 6520.03 207.91 197.31 245.24 79.73 NO Reference Casings 1091.29 1087.91 1084.61 1081.40 1078.28 13115.13 6693.02 7880.00 6528.88 207.89 197.72 245.81 80.18 No Reference casings 13100.00 6692.59 7890.00 6537.73 207.66 198.92 247.20 80.61 No Reference Casings 13100.00 6692.59 7900.00 6546.57 207.66 199.21 247.66 81.08 No Reference Casings 13100.00 6692.59 7910.00 6555.40 207.66 199.52 248.12 81.54 NO Reference casings 13100.00 6692.59 7920.00 6564.24 207.66 199.82 248.59 82.01 NO Reference casings 1075.25 1072.48 1069.57 1066.77 1064.05 13100.00 6692.59 7930.00 6573.09 207.66 200.12 249.06 82.48 No Reference Casings 13100.00 6692.59 7940.00 6581.93 207.66 200.42 249.53 82.95 NO Reference casings 13100.00 6692.59 7950.00 6590.78 207.66 200.72 250.01 83.42 No Reference Casings 13100.00 6692.59 7960.00 6599.62 207.66 201.03 250.48 83.90 No Reference Casings 13100.00 6692.59 7970.00 6608.48 207.66 201.33 250.96 84.37 No Reference Casings Page 4 1061.43 1058.91 1056 48 · -._; .. ~_ - 1054.15 ' ~'' i".' :.' · :. ¥ )' 1051.91 'C/> ,. ~,.~/ ?,.. '-' ',ki':-. . -, ...-:. {,>~.. , ,.; ~ '~ ..; :;.~. " !': ~7':-~ .' 13100. O0 No Reference 13100. O0 NO Reference 13100.00 NO Reference 13100.00 No Reference 13100.00 No Reference 6692.59 Casi ngs 6692.59 Casi ngs 6692.59 Casi ngs 6692.59 Casi ngs 6692.59 Casi ngs 1R-01B PLAN #2 CLOSE APPROACH TO 1G-09.1'XT 7980.00 6617.33 207.66 201.63 251.44 84.86 7990.00 6626.18 207.66 201.92 251.92 85.34 8000.00 6635.04 207.66 202.22 252.41 85.82 8010.00 6643.90 207.66 202.53 252.89 86.31 8020.00 6652.76 207.66 202.83 253.38 86.80 13085.90 6692.19 8030.00 6661.63 207.37 203.94 254.74 87.26 NO Reference Casings 13083.94 6692.13 8040.00 6670.49 207.33 204.35 255.35 87.75 No Reference Casings 13081.98 6692.08 8050.00 6679.36 207.29 204.76 255.97 88.24 No Reference Casings 13080.02 6692.02 8060.00 6688.22 207.25 205.17 256.58 88.73 No Reference Casings 13078.06 6691.96 8070.00 6697.09 207.20 205.58 257.20 89.23 NO Reference Casings 13076.10 6691.91 8080.00 6705.96 207.16 205.99 257.82 89.72 NO Reference Casings 13074.13 6691.85 8090.00 6714.83 207.12 206.39 258.44 90.22 No Reference Casings 13072.17 6691.80 8100.00 6723.70 207.08 206.80 259.06 90.71 No Reference Casings 13070.21 6691.74 8110.00 6732.58 207.04 207.21 259.68 91.21 No Reference Casings 13068.24 6691.68 8120.00 6741.45 207.00 207.61 260.30 91.71 No Reference Casings 13066.27 6691.63 8130.00 6750.33 206.96 208.02 260.93 92.21 No Reference Casings 13064.30 6691.57 8140.00 6759.20 206.92 208.42 261.55 92.71 No Reference Casings 13050.00 6691.16 8150.00 6768.08 206.63 209.45 262.94 93.19 No Reference Casings 13050.00 6691.16 8160.00 6776.95 206.63 209.75 263.44 93.70 No Reference Casings 13050.00 6691.16 8170.00 6785.83 206.63 210.05 263.95 94.20 No Reference Casings 13050.00 6691.16 8180.00 6794.71 206.63 210.36 264.45 94.71 No Reference Casings 13050.00 6691.16 8190.00 6803.59 206.63 210.66 264.96 95.21 No Reference Casings Page 5 1049.77 1047.74 1045.80 1043.95 1042.19 1040.32 1038.68 1037.12 1035.65 1034.25 1032.94 1031.71 1030.57 1029.51 1028.55 1027.67 1026.88 1026.35 1025.69 1025.12 .. 1024. 64 -, 1024.25 . ..., . 1R-01B 13050.00 6691.16 8200.00 6812.46 NO Reference Casings 13050.00 6691.16 8210.00 6821.34 No Reference Casings 13050.00 6691.16 8220.00 6830.22 NO Reference Casings PLAN #2 CLOSE APPROACH TO 1G-09.TXT 206.63 210.96 265.47 95.72 206.63 211.26 265.98 96.23 206.63 211.56 266.48 96.74 13050.00 6691.16 8230.00 6839.10 206.63 211.87 266.99 97.25 No Reference Casings 13050.00 6691.16 8240.00 6847.98 206.63 212.17 267.50 97.75 NO Reference Casings 13050.00 6691.16 8250.00 6856.85 206.63 212.47 268.01 98.26 No Reference Casings 13050.00 6691.16 8260.00 6865.73 206.63 212.77 268.52 98.77 No Reference Casings 13050.00 6691.16 8270.00 6874.61 206.63 213.07 269.02 99.28 No Reference casings 13036.57 6690.78 8280.00 6883.49 206.28 214.03 270.35 99.76 No Reference Casings 13034.57 6690.72 8290.0d 6892.37 206.22 214.42 270.98 100.26 No Reference Casings 13032.58 6690.66 8300.00 6901.24 206.17 214.81 271.61 100.76 No Reference Casings 13030.58 6690.60 8310.00 6910.12 206.12 215.06 272.24 101.26 NO Reference Casings 13028.57 6690.55 8320.00 6919.00 206.07 215.30 272.86 101.76 No Reference Casings 6690.49 Casings 8330.00 6927.88 206.02 215.54 273.49 102.26 13026.57 No Reference 1023.95 1023.74 1023.63 1023.61 1023.69 1023.87 1024.15 1024.53 1024.81 1025.32 1025.92 1026.61 1027.39 1028.26 Company: Page: Field: BP Amoco Kuparuk River Unit BP Amoco Anti col 1 i si on Report Date: 10/2/2000 Page 6 Ti me: 13:43:11 1R-01B PLAN #2 CLOSE APPROACH TO 1G-09.TXT Reference site: KRU iR Pad Co-ordinate(NE) Reference: Well: 1R-01, True North Reference well: 1R-01 Vertical (TVD) Reference: 1R-01A 79.9 Reference Well pathPlan#2 1R-01B Db: Sybase Site: KRU 1G Pad Wel 1: 1G-09 Ri sk weq 1 path: 1G-09 V2 ft Reference A11 owabl e MD TVD Deviation Warning ft ft MD offset TVD ft Rule Assigned: Major Inter-Site Error: 0.00 semi-Major Axis Ctr-Ctr No-Go Ref offset TFO+AZI TFO-HS casing DistanceArea ft ft deg deg i n ft ft ft 13024.56 6690.43 8340.00 6936.76 205.96 215.79 274.11 102.76 No Reference Casings 13022.55 6690.37 8350.00 6945.64 205.91 216.03 274.74 103.26 NO Reference Casings 13020.54 6690.32 8360.00 6954.51 205.86 216.27 275.36 103.75 NO Reference Casings 1029.21 1030.25 1031.38 Page 7 Ez598,95O'.D ,.' : : : I , : · . Kupamk River Unit - KRU IR Pad All depths referenced to 1R-01A 79.9ft 1R-03 1R-01 1R-03 #4 1R-0: , · ~ , , , .. I-, .i ' '' 10-09 (10-09) , . . . · . . r r! i ' i ' : ' ~Plan/f2 1R-01B 11 1( 1302013030130401305013060130701308013090131001311013120131301314013150131601317013180 Measured Depth [ft] 40t .... i'"-~i---'i'-~-F-i-- ! -- -i i'-F_jj'-'-!-5--~i-71-=-- i .... ~-~-~-'-F.FjF-i-i[5a'T[ .......... ?"]" "i-i"i i 'i i il! /I 11 --,~-i-~-~r--r'--, ,-"-'L!-'~-~-r-~-~---r ..... - --L_~'-"-~'-'m-,_LL'"~---F'~ , ......... F.--.-, ................................ ,' '~' ................. ................ ,J,: .......... [l'""'t: .......... ,.' ...... l .... ~--~-- k-i'--,-- ~ ........ ~-~- -~ ..... ~--=-- --.,,---~- -..- .......... ,,.~ -. ...... ~ ......... 4 ................................ , ............................ ,. .......... ; .................... t-.--. ........ I ..... '=-"'--~--~'-'-"~'"~P"--V- "-='?=~= -- ------i---~I~, '""'~'""~'"""~m'~'"'"~'~"~m'"" '"'"~l ,...,.-,~ ~ k-,,, ~'"'"m'""~ ~," .......... ~- -~:--?-"~,,'""~i~r""'" . ~'~" ~ "I-"-' .......... , - !-"~=~ - i ----.i----~-- ~-,,- ~,,,,-',-- 4=~-- -! - --- ~-----4 ------ 4--'""~ 4-''"''' ----,,~ i,-,,-,-- k,,,,- 4-- ~ ~,,,~-- ~,, --,-,,44---- ,,.,,-,,~1~-- ~-- ~-~-- ~-- --~ ..... i-,- .. ...... i-..!-.~g ....... I ....... ~---,l~--i'..,.~ .... ~i~,,,,,.~.....L_....i ..... ~ ~,,,~i,,..~] : !,,..,,~ _...L....t...._: .... i... i.. [ .. . !. i i~,..~ ~ i . i !i ..... ~ ~ !..~ ~.. ,,.......j~_ __ ~ ,_,...,..L_~.~I .... ~: .._~.~..,~_.~L.. 4 .... i i i i i i i i i I i i i : i i '~ i i ' i i ! i i i i I~ t t i i ! ..... Z .......... --...i ............ -, ...... ..... .... '- --.-~ ........ ~-- .... -i ...... - -- ~ ~-r ...... !...... i ......,: ............ ......... t ...... ....... =,.=.~=_ _ 51 ~-- l-t -,--, mT- +-,H- ~ ' '"- '"'":'~-"" :: ~- = '-'"", ...... i ~Z:.. ';:i'.--.!-! ['-' =] '- -""~i":~': :=m-'-i=" ~ :-'...."' - -"-i '"'" " ': i' ' iZ]m=m--m ........ -i--~- I I I I I I I I I I I I 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 Measured Depth [ft] FW: 1R-01B Plan #2 Close approach Report Subject: FW: 1R-01B Plan #2 Close approach Report Date: Mon, 2 Oct 2000 20:07:05 -0500 From: "Rauf, Paul C" <RaufPC~bp.eom> To: "'steve_davies~admin.state.ak.us'" <steve_davies~admin.state.ak.us> Steve, Here is a text file for you to view concerning the 1R-Olb well permit. pcr ..... Original Message ..... From: Potnis, Brij P (BHI) Sent: Monday, October 02, 2000 1:46 PM To: 'Dan Venhaus (BP)'; Rauf, Paul C Cc: 'Brij Potnis (BHI) ' Subject: 1R-O1B Plan #2 Close approach Report <<IR-O1B PLAN #2 CLOSE APPROACH TO 1G-09. TXT>> Brij Potnis Technical Support Engineer Baker Hughes INTEQ, Alaska * (907) 267-6613 * Brij. Potnis~inteq. corn * PotnisBP~BP. corn x4102 Cube 754B - NW Corner ~IR-01B PLAN #2 CLOSE APPROACH TO 1G-09.TXT Name: 1R-01B PLAN #2 CLOSE APPROACH TO 1G-09.TXT Type: Plain Text (text/plain) Encoding: quoted-printable ............................. 1 ofl ~o/3/0o ~):~7 A,M' / DATE CHECK NO. H 1 7:5:575 f)a~=,~,/oo ~30173375I · v~-Nu~,r~ Ir.~L~ ~:~,l~Ir'~:=) I ~ I · u DATE INVOICE I CREDIT MEMO DE~RI~ION GRO~ DISCOUNT NET 0~2200 3KOB2200g 100. O0 100. O0 HANDLI ~G INST: TEER [E HUBBLE X46;28 A~ACHED CHECK IS I" PAYMEm mR ~m DE~RIB~ A~. ~ 1 OO_ OO I OO ~O . -' "-': - 'FIRST NATIOI'-'AL. BANK OF ASHLAND. .", "'" '' . . .AN AF. PIUATE 0.'~ :?'- ;-:'i'-' "" '::: :: :- '-' ':'":':::' ':: "' ' ':" I' "' i:).0.~'~X"196612 ;ii~'-'!;;:?.!;:!_..,'-::-~";-;;':*:;:i~..;:i;ii_:'~!!;;." :::~!~i:.""'.'-'-';!!!;" i:.:ii;!". .... :,...:'.;;;"-:-;'::;;!!;;~ ' . .^~,O,^LC, n'..~,< ......... :2- ---::::.._. -:.......--.::--:.: !-':-:.::!.- .:i.-":::::-. I?:,!: ~! ;- .'.?i : '.:~-.,:,..';.:_ :, . ...- .. ~..:--. -...:~..:- . .:.' - ... -~ ... . '.' . - .,~ '-:.' . . · ~. ': - . . . " . "- . - . . . . . ,- .'.:.:,~' =;...'-.; :::~: .'<~,.;:,r-,:. .:,.::':' ,.... "'': ': .'.;.'-. ' .-:'2" . . " ' ' ' . . . '. ........... . ..... ' . ~;~¢;;i?-?~i':-;;':/;;:"'!'?:::-'-"?' ....... .'":.?'/.:-.'~'"¢'-':; '"'""':~';;:;" · ' '" ..... ' ' ""-i:'""' .... "":'"' ' 0e/22/-08': : '::"- ' -:' "-:"'-'."'$-:tO~:.":O0": ~}'~'"'"~h~!~'''' ;'II~".T~T~ '-'OF' hl'-"-A~:':~::~: '~?~:?:'" .-- :" ;.-:~i ...---.:::::':.: .... --'r-:?.-'{: .:,i"::; -.:.;':-'."::::. :i.:~.~?r. ~qr--.-~.v~..~o am'£a ~o ~v$ :./.....:.:.~'-;:.-'--..-., ::.::": ::.;:;',:; ..... i'~-,-:..~'-.5,~'~..' ./",:~.~ .:~.?q:" '~ '.-' '--.¢:::.- ' ' -:-.':-' [i:-::.-'~:' :::ii:~:': ?:. ':-i:' -'i: -'.":~:" ?;i:: ~::.i¢;.. ?.?':-:'- :'" :::' :- .:..!:: J "-;--' "':-. :4 '!..:;- :.'?-." '::::-'.~: .-."."':: ..... ~:'.. !-'*' ~:~:'}~¢-:~.¢ 4-?;~-::'"' ":'~ :'-:.-":": · '.-- · ~"'"- ............. ' ........... ._.:::'.' . ..... -,.. __-..:._: -: .-:- ..-. ::~;:..?- ~::.:..-.-~:. :~;~i~.-.v-'-¢~:~:F'~¢i;.;.::-~NC--.HOR~E.:.~'::.: -:~-- - ,,-~' ';'"':~'!:" ~¢":~'--;¢':':":~;~ ~: :'"";::"";'"~'";:'":'!'::';-"'-: '"'-"' :' ""' ;-" "'"':': ::'-':':" ...." .... "?" AK': ':'"' ..... c7c~501~'"::'": ....... :';-'. "::":~'"-: '". '''~: '-'" ' "% "' "'. -" I ..- .._.~. ,.' CHECKLIST COMPANY -~L, [/,.~.G WFI L NAME ! ~' O//~E~ PROGRAM: exp dev ~ red~l WELL PERMIT , ~ . ~ _ -- , . FIELD & POOL ~ ~/~ INIT C~SS ~ ~ /~/~ GEOL AREA ~ ADMINISTRATION 1. Permit fee a~ached ....................... 2. Lease number appropriat~~ .~"~~. ~'. ~ ~ 3. Unique well name and,number .................. 4. Well Io~ted in a defined pool .................. 5. Well lo.ted proper distance from ddlling uni~a~ .... 6. Well lo.ted proper distan~ ~om other well~ ...... I~NGINEERING 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... ' 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. A~ DATE Conductor string provided ............ ' ....... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long' string to surf csg .... ..... CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling Waste .... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. COMMISSION: /-/ serv wellbore seg ann. disposal para req UNIT" ~)////~/_~ ON/OFFSHORE Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press' rating appropriate; test to '~_~;~C) Dsig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... N . ~ ' , · Is presence of H2S gas probable ................. ~N' Permit can be issued wlo hydrogen sulfide measures ..... Y[ NJ ' ,, ,, · . ~" ~,-=},_- ,-_._ ,, _-._ ~t,.,,~.~ '-~ Data presented on potential overpressure zones .' ....... Jt ~ '~ ~ _....,,3 . ~ , , ,. / ~ -- -- Seismic analysis of shallow gas zones .......... '. '. Seabed condition survey (if off-shore) ....... '. Contact name/phone for weekly progress reports, J~t'plorato~ only] Y N ' ' (j c~ ' ' Y N Y N ~o, ~u~-,~t3~s,~. ~)~..Ar,~=~3 · ~,.~-~- u,~ 14.~.0 r_.,~,,55"~~-.. ENGINEERING: UlClAnnular GEOLOGY: Y N Y N Y N 'comments/instructions: O Z --I -I- c:~nsoffide\wordian~iana\checklist (rev. 02117100) .. Well Histo[y File APPENDIX Information of detailed nature that is not particularly germane to the Well ,Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 03/02/06 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 03/02/01 86679 01 1.75" TINY *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: ldwg.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block $MNEM.UNIT Data Type STRT.FT 10467.0000: STOP.FT 12650.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: ~Parameter Information Block #MNEM.UNIT Value #. CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska, Inc. 1R-01B Kuparuk River Unit 154' FNL, 139' FWL North Slope Alaska Baker Hughes INTEQ 1.75" TINY 17-Oct-00 500292140402 Description SECT. 20 TOWN.N 12N RANG. 10E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 79.9 DMF . KB EKB .F 79.9 EDF .F N/A EGL .F N/A CASE.F 10915 OS1 . DIRECTIONAL ~Remarks : Section : Township : Range : Permanent Datum : Elevation Of Perm. Datum : Log Measured from : Feet Above Perm. Datum : Drilling Measured From : Elevation of Kelly Bushing : Elevation of Derrick Floor : Elevation of Ground Level : Casing Depth : Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAM) presented is memory data. (4) Well 1R-01B was kicked off as a sidetrack to well 1R-01A at 12172' MD (6598' SSTVD) and was drilled to TD at 12611' MD (6603' SSTVD) on Run 1. (5) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) curve suplied by PAI (Deirdre L Schwartz) via e-mail on 24-Sep-2002. PDC curve for this well is the Sperry Sun's MWD Gamma Ray dated 12-Dec-1999. (6) A magnetic declination correction of 26.37 degrees has been applied to the Directional Surveys. MNEMONICS: GRAM -> Gamma Ray MWD-API [RWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 26.13 ft. 1 21.31 ft. CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10554.9, 10522.1, ~ -32.8398 10590 , 10558.4, ! -31.6055 10628.5, 10597.6, ! -30.8643 11015.4, 11008 , ! -7.40723 11051.9, 11042.7, ! -9.13574 11100.8, 11088.2, ! -12.5918 11114.7, 11103.1, ! -11.6055 11121.9, 11110.8, ! -11.1104 11126.6, 11115 , ~ -11.6045 11151.8, 11141 , ! -10.8643 11170.8, 11161.3, ! -9.50586 11181.1, 11170.2, ! -10.8643 11186 , 11184.3, ! -1.72852 11195 , 11193.3, ! -1.72852 11228.6, 11219 , ! -9.62988 11330.3, 11328.8, ! -1.48145 11337.3, 11337.3, ! 0 11516.1, 11515.1, ! -0.987305 11525.4, 11522.7, ~ -2.71582 11650.3, 11640 , ! -10.3701 11667.4, 11658.5, ~ -8.88867 11820.1, 11811.7, ! -8.39453 11830.2, 11819.6, ~ -10.6172 11987.8, 11975.7, ~ -12.0986 12045.1, 12032.8, ! -12.3457 12047.6, 12038.5, ! -9.13574 12093.4, 12088.7, ! -4.69141 EOZ END BASE CURVE: GROH, OFFSET CURVE: GRAM Tape Subfile: 1 90 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN md.xtf LCC 150 CN Phillips Alaska, Inc. WN 1R-01B FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) curve suplied by PAI (Deirdre L Schwartz) via e-mail on 24-Sep-2002. 3. The PDC used is a Sperry Sun MWD Gamma Ray dated 12-Dec-1999. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAM02 0.0 ROP ROP ROPS02 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 API 2 ROP MWD 68 1 F/HR Size Length 4 4 4 4 Total Data Records: 52 Tape File Start Depth = 10467.000000 Tape File End Depth = 12650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: 61 records... 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN md.xtf LCC 150 CN Phillips Alaska, Inc. WN 1R-01B FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAM GRAM GRAM 0.0 ROPS ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F . ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRAM MWD 68 1 API 2 ROPS MWD 68 1 F/HR Size Length 4 4 4 4 Total Data Records: 52 Tape File Start Depth = 10467.000000 Tape File End Depth = 12650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 61 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/02/01 86679 01 **** REEL TRAILER **** MWD 03/02/06 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 10467.0000 -999.2500 -999.2500 10467.5000 -999.2500 -999.2500 10500.0000 23.5478 -999.2500 10600.0000 34.8835 -999.2500 10700.0000 57.1262 -999.2500 10800.0000 59.6469 -999.2500 10900.0000 70.7158 -999.2500 11000.0000 59.7459 -999.2500 11100.0000 66.4479 -999.2500 11200.0000 42.2265 -999.2500 11300.0000 71.9295 -999.2500 11400.0000 46.5145 -999.2500 11500.0000 61.5973 -999.2500 11600.0000 64.9828 -999.2500 11700.0000 61.9570 -999.2500 11800.0000 78.0393 -999.2500 11900.0000 34.5338 -999.2500 12000.0000 62.1859 -999.2500 12100.0000 49.4832 -999.2500 12200.0000 38.8240 78.6606 12300.0000 76.2243 71.9814 12400.0000 34.4489 71.5970 12500.0000 33.1723 93.3740 12600.0000 -999.2500 71.0193 12650.0000 -999.2500 -999.2500 Tape File Start Depth = 10467.000000 Tape File End Depth = 12650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GRAM ROPS 10467.0000 -999.2500 -999.2500 10467.5000 -999.2500 -999.2500 10500.0000 -999.2500 -999.2500 10600.0000 40.3200 -999.2500 10700.0000 54.7010 -999.2500 10800.0000 49.7470 -999.2500 10900.0000 57.7050 -999.2500 11000.0000 60.9940 -999.2500 11100.0000 60.3550 -999.2500 11200.0000 47.8870 -999.2500 11300.0000 66.2150 -999.2500 11400.0000 46.7240 -999.2500 11500.0000 63.2200 -999.2500 11600.0000 58.3020 -999.2500 11700.0000 65.8690 -999.2500 11800.0000 81.7070 -999.2500 11900.0000 37.7120 -999.2500 12000.0000 53.9330 -999.2500 12100.0000 49.1660 -999.2500 12200.0000 49.7920 57.5780 12300.0000 75.0500 72.6480 12400.0000 32.8530 72.0000 12500.0000 32.0570 84.3890 12600.0000 -999.2500 71.4330 12650.0000 -999.2500 -999.2500 Tape File Start Depth = 10467.000000 Tape File End Depth = 12650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS