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Home My WebLink About204-124THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E -126L2 Permit to Drill Number: 204-124 Sundry Number: 319-515 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www, aog cc.a laska.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, Jere . Price Chair �{ DATED this � ✓ day of November, 2019. RBDMS <<�Nov 14 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED N^o. OV �t 2 220119a 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TRTMU 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: V r Sr} ConocoPhilli s Alaska Inc. Exploratory ❑ Development p . Stratigraphic ❑ Service ❑ 204-124 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 W0, 50-029-23215-61-00 7. If perforating:] 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU IE -126L2 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25651, ADL 25660 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,457' 3,382' 12401 3378 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 82' 20" 108' 108' Surface 3,765' 133/8 3,795' 2,304' Intermediate 7,083' 95/8 8,088' 3,605' Liner 5,332' 51/2 12,435' 3,380' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7136-12402 3425-3378 4.500" L-80 7,062' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): LEM PRODUCTION PACKER PACKER= 7076 MD and 3410 TVD 12. Attachments: Proposal Summary l7 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development p Service ❑ 14. Estimated Date for 12/1/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ El WDSPL ❑ Suspended ❑ GAS ❑ WAG tjr GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ (lr 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: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com ,f 'j J�„ Contact Phone: (907) 265-6471 - -- Authorized Signature: z , W .p'- Date: /. - COMMISSION USE ONLY Conditions of approval. Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3BDMS ��✓ NOV 14 2019 Post Initial Injection MIT Req d? Yes ❑ No ❑ i Spacing Exception Required? Yes ❑ No ©/ Subsequent Form Required: �) APPROVED BY Approved by: V COMMISSIONER THE COMMISSION Date: l J 3- 17 .��1�� i-,z•�i L.Y( t (�� I `t � � �� Submi[Form and rm 10-403 Re sed4 201] Approved applicatl0 f r4AY+e date of approval. Attachments in Duplicate J Proposed 1E-1051-2 to 1E -126L2 RPPG D MBE Treatment 1E-105 Tri-Lat injector has 4.5" tubing and horizontal laterals in West Sak A, B, and D sands. The 1E-1051-1 B lateral has had 3 separate MBE's, but all these MBE's have now been sealed with Crystal Seal and RPPG jobs. After the last B Lat RPPG job of 12/10/18, evaluation of 1E-105 B Lat only injection and 1E-126 production indicated all B Lat MBE's appeared to be sealed. However, an open 1E -105L2 'D' Lat MBE still remains open. 1E-1051-2 'D' Lat has 5.5", L-80 slotted liner between 7258 - 13536' RKB. On 9/18/17, a D IPROF saw all injection exiting D Lat at -7260' RKB (near D LEM), with all injection then flowing down backside of 'D' Liner to the first liner slots 764' below D LEM. The [PROF showed no down flow inside the 764' blank liner section of D Lat. The exact location of the D MBE is unknown, but IPROF data suggests the 'D' MBE is most likely somewhere behind the upper 764' blank liner section above all the liner slots in 1 E-1051-2. On 2/2/18, a Plug was set at 7578' RKB to isolate the A Lat, and it remains set. On 10/2/19, a 'D' Iso-Slv was pulled and a 'B' Diverter was pulled, from 7258' RKB & 7524' RKB respectively. On 10/3/19, a 'B' Iso-Slv was set and a 'D' Diverter was set, and CT drifted a 2.75" OD Dummy Drift into D Lat to 10378' RKB. 1E-105 is now configured to perform a 'D' MBE RPPG treatment It is proposed that RPPG slurry be fullbore pumped to the D lateral with intent to halt all flow exiting D Lat near the D LEM to restore normal matrix injection to D Lat liner, and to seal the D MBE that likely exists above 8024' RKB behind the -764' blank liner section. ea Procedure: Coil Tubing: 1) RIH with inflatable Bridge Plug & set it inside 4.5" OD blank liner section at 7360' RKB in D Lat. 2) RIH with pert gun & shoot 5' OAL large hole perfs in 4.5" OD blank liner at 7310' RKB in D Lat. Pumping: 3) At -12 hours before planned RPPG job, put 1E -105L2 on PWI 1000 BPD to displace Diesel FP and gas head from the tubing to the open D MBE to 1E-1261-2. RU pumping equipment at 1E-105 the next morning. ----�� SI 1 E-126 and 1 E-1051-2, and then immediately start fullbore pumping into 1 E-1051-2 with 112 bbls (-1 tubing volume) of 2% KCL Brine at steady rate between 1.5 - 4.0 bpm (pump rate needed Enue what r eedee . let the pump keep up with the vacuum rate of the well), followed by XX bRPPG slurry mixed th 2% KCL Brine while adding 0.5 - 0.75 lbs/gal RPPG on -the - fly. opumping - ppg slurry at a steady rate until the WHIP reaches 500 to 800 psi, then swap to pumping 64 bbls of 2% KCL Brine displacement, followed by 47 bbls Diesel FP to 2000' TVD (3103' RKB), followed by SD to leave RPPG treatment -1 bbl underdisplaced to MBE. W it48 s for RPPG to cure in MBE to crosslinked non -flowing RPPG before returning 1 E-1051-2 to injection or 1 E-126 to production. Return 1 E-1051-2 to PWI to evaluate results of the RPPG D MBE treatment. After sufficient evaluation time to verify that D MBE is sealed, 1E-105 will be reconfigured to jG restore PWI to all three laterals. JWP 11/11/2019 KUP PROD WELLNAME 1E-126 WELLBORE 1E-126 ConocoPhiliips I �, �— Alaska,Inc. Make SURFACE;R 3 7R LOCATES ',]CEI FISX', 0. 41)LINER RSentl WiMx, 8 SAND LINER INiERMEONTE YI.. W..0 IFERF: Bp58.p8.I4 . KUP PROD WELLNAME 1E-126 WELLBORE 1E -126L2 ell Attributes Max Angle COf10CUPIIilIipS li';," g & MD TD WrepPV11Wl W¢II Wre 8181us cl' MD Ha .dav RKn Akaska. irlC. 'WFSTaRAH � mm."'p-1 neon un" � [_ ° Mip ._ .__ 1 1 1E 13ati, 11/121181`CM M PM .. ...... °..°..-...� +r... wo ueaor Last Tag Vatlnl¢Fe,rnpc(vduvp Annphfron pepm (X881 Entl Date Weneore Last Mca By Last Tag1E-125L2 ilmosbor Last Rev Reason .GER', R5.1 Annotated End Eme WeI1Wre Last Mca By Rev Reason: WELL REVIEW 1012312013 tE-126L2 Dsborl Casing Strings wamp oeacnpaon oolml to lm) Top (nLal semepin tnlee) sel9apm lrvol... WULen o... Gaaa rop Thread 0 -SAND LINER 51/2 4.95 ],103.4 12,435.0 3,3804 15.50 L-80 DWC Liner Details ieptttKa) Nominal lD ToplN01 (nNa) Top Incl l°) INm pea Com tint ],103.4 3,416.] ]4.88 HANGER BAKER MODEL B-1 LEM HOOK HANGER 3.960 � CONDUCTOR: 366109.0 Perforations & Slots aM1at NIPPLE: 5180 Ilenrnn:;emo Top IXBB) atm lflXRl Topj13)aM (flKe) (NDI 1111(91 Llnkea Zone Oatr Dens tSM1afs/ff 1 Type Can ],13fi.0 12,4020 3,424.6 3,3]].9 W - 126L2 8/152004 40.0 (PERF Alternating w/blank pipe, Sims 2.5"x.125", 4 Cimumferential rows/n- Applies W all Perls Notes: General &Safety End pateAn-wen 9/8/2004 NOTE:TRI-LATERAL WELL: 1E-126(A-SAND),1E-126L1 (Fp,SAND), 1E-126L2(D-SAND) 223/2009 NOTE View Sc6ema80 W/ Alaska Scbemafics!) SURFACE', M.6a.]Yv.C� OPb LIR: 4,101 B G46 LIR. N'.. NIPPLE. 6,68,1 LOCATOR: 7.MI SEAL ASSY:]OW.I D-SPNO LINER LEM: 7.M.8 - 7.M2 0.6aM Wlttlwr, I Ind 0. 1.1za0 INTERMEDL4TE', n 08.Ass e —I IPERF:7,1wp.izeSo-- t PBAND LINER: 71Mf M.0� Via, KUP PROD WELLNAME 1E-126 WELLBORE 1E-126 ConocoPhdlips �''Irw;' wen wttnbutes Max Angle & MD TD Fleltl Name WallCore APVUWI Wellbore 5latus Icl (°) MD (XK9) qq 9tm 1X1(81 .0] 11,058.79 12,611 0 Comment H35 (ppml Dnla LanOMW End Oah KalM Rip Release Date SSpromm" PLE 60 8242012 JA Last WO: 513/200] 33.]1 81312004 eF-Iss, tin12m i?.Sl:44PM Last Tag Vemavlx'rearN ans, Annobtun I Depth lnne) I End pear WeIIM,e Lem mW ey _............................ ......................... ......... .......... ............... Nei HANGER ys:1 'ham C0ND11CTCR: 300.1 W.0 NIPPLE', 5189 NntTFE ZgJ00 sVREACE;..e,.a- W9DFT:4,10a GASLIR;epa11,9 M NIPPLE 8981 GAUGE; She .7 LOCATOR; 7.1 SEALMSY: 7.W0.9 DsArvO LWER; 21oaa- +35A armawlmm. nos.a mo FISH:>.1310 DaAxo uNER L9a; Tog% al - 2 ILS.wDuxER', Tal u,4S.9 as.ee yr ao>:7seO.a >'a'10 E-9AW0 LINER LEM', 72osa 7,ea.s HSH:7.ae0.D INTERMEDIATE: 2709,[69.0 IPERF, goes -1-6-i I I _I _ IPERR 8,91 D8.33a0- _ IPERF:e,>99.oa.9eao- IPERF,9,3i109.91a0� - _ I i _ .ERF 10.0870Tm,>sl o� - PEREn.1u.o-1?uzp- _ IPERE,I;amalzs>4o- _ XvND UNER;>,412a 12,11mu Last Tag: 1E-126 Imosbor Last Rev Reason Annotation End Da. Wellbore Leat MM By Rev Reason: WELL REVIEW 10232013 1E-126 osbull Casing Strings C -Ind Deamiptpn oD (Int In (in) Top IXKa) Set reddb (XKeI SH pepeh (Top)... WGIen IL.. Gmde Top TM1read CONDUCTOR 20 19.12 26.0 108.0 108.0 94.00 K-55 WELDED Cuing Dnedptlan Go (in Ip(Inl Top(.Kel Set OapN dGIN SN ON, LingD)... MLen(L.. Greg Top Thread SUPEACE 1339 12.41 296 3,]960 2,304.3 68.00 LA0 BTC Casing Description Op ping ID lin) roomallatM1(KKB) Set peptM1 (TVpL.. WVLen IL.. Grade Top TM1reed INTERMEDIATE 9516 6.84 D.0 8,088.0 3,605.3 40.M LA0 BTC -M Ceasing Desctlptlan DD(ml poll rop IXKBI Set Depeh(XKB) Sat Depth (Pog... .,an ot.. GMe Top Threat .Zoll Wind.. 95/8 6]0 7,1050 7,124.0 3p220 40.00 L-80 BTC -M Caeing Description DD (in) ID bad roplXKBI Set pepth ME) Set Depth rvia. YNLen 11... Grade Top Thread B-Sentl WlntlOW 959 6)0 ],305.0 ],321.0 3,469.2 40.00 LA0 BTC -M Caainp De nw. DDlinl Imbed Top al se Depth MKIN I Bet Drops IND)... WtlLen(I... Grade Top TM1read A -SAND LINER 512 495 7,412.8 126070 3,5724 15.50 L-80 DWC Liner Details Top (XKD) TOp(NDI (flKB) Tep Incl l°) I@m Des Cam Nominal lD (in) 7,4128 3,4872 79.64 PACKER PRO ZAP LINER TOP PACKER 7.000 7,431.4 3,49p.5 79.91 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4875 7,434.3 3,4910 79.92 HANGER FLEXLOCK LINER HANGER 4.853 7,4458 3,493.0 79.93 SBE 19047 CASING SEAL BORE EXTENSION 4.750 7,465.1 3,496.4 79.94 XO BUSHING CROSSOVER BUSHING 3.930 Casing Description ODDn) ID(inl Tap dr -K Sad DepIM1 (nKBI Set Dapm (rvDL.. wvLen (L_Graee TOp Th -ad 0 -SAND LINER LEM 4112 3.96 ],029.8 ],286.2 3,4fi1 7 12.60 LA0 IIBT Liner Details Noni Top(nlop TopmD)(XKBI-ropindr) IN. Dez cam An) 7,029.8 3,3974 7496 SLEEVE 'HR'LINER SETTING SLEEVE 7.500 7,038.1 3,399.5 74.8] %O BUSHING 4.880 ],044.1 3,401.1 7481 SBE .760 7,062.4 3,4059 7473 XO BUSHING 3.960 7,0763 3,4093 74,78 PACKER LEM PRODUCTION PACKER 3.870 ],0934 3,414.1 )4.85 HANGER LEM HH ABOVE 3.950 7,1065 3,4172 7489 HANGER LME HH BELOW 3.680 7,283.0 3,481.0 ]7.0] SEALASSY NON -LOCATING SEAL ASSEMBLY 3.890 Cazlne Destliplion Op(inl IDgh) Top(XKBI Set Deptin(MB) BN Oepan(TVIS legal (I B -SAND LINER LEM 41/2 3.96 ],245.2 7,45].5 3,495.0 1260 Grade Top Thread LA0 IBT Liner Details Top MKal Tc p NommallD Top (rvpl lnlcal Top Inm (°) Ihm pea cc. (in) 7,245.2 3,4523 76.32 PACKER -1 LINER TOP PACKER 6.278 7,2638 3456S 7669 %OBUSHING CROSSOVER BUSH ING 7"75.5" 4.760 7,265.6 3,457.0 76.72 SBE SEAL BORE EXTENSION 4750 7,204.8 3,461.4 77.10 To BUSHING CROSSOVER BUSHING 55"x4.5" 3910 7,292.6 3,463.1 7726 HANGER LEM ABOVE HOOK HANGER 4.020 7,3025 3,465.3 ]].46 -RANGER LEM INSIDE HOOK HANGER 4.020 7,327.3 3,470.6 77.95 NIPPLE CAMEO'DBP NIPPLE 3562 7,4543 3,4945 79.93 6EALASSY BAKER SEAL ASSEMBLY 3.875 Tubing Strings Tubing Description SYing Ma... ID (nl IT -1, (HKBI Bel Depeh (X.. $e[DepehlNDl (... WI(IbM) G,ade Top COnneclion TUBING WO 41/2 3.83 25.1 7,062.4 3,405.9 12.60 L-811 4.51BT Completion Details top (WD) Top incl Nominal Tap post (11KB) (°I Mm Des Cam ID (in) 25.1 25.1 0.00 HANGER TUBING HANGER 3.900 5169 515.4 10.68 NIPPLE CAMC03.8)5'DS stipple @500' 3.875 6,972.1 3,3827 75.56 NIPPLE EJUAGO 3.813'•"DB"Nipple 3.813 4987.3 7586.5 7 5 AF XO 3.830 6,988.7 3,3869 75.38 GAUGE A -well Gauge Mandrel (VJeatberfDN)4 117Bb BxP 3.950 7,039.1 3,399.8 74.86 LOCATOR LOCATOR SUB 3890 7,040.2 3,400.1 7485 SEAL ASBY Baker GBH -22 Seal Assembly 3.890 Other In Hole (Wirellne retrievable plugs, valves, pumps, fish, etc.) Top ITVGI .1 ba Top InKBI yead.) C)pea Com RYn Dab ID (In) 2,970.0 2,005.8 6923HI:at Trace HEAT TRACE 2970'-3063' 5fL200> 0.000 7,1310 3,423.8 ]499 FISH TYPE 1150 SLEEVE STUCK IN D LEM 61152010 0.000 7,660.0 3,565) ]9.90 FISH I oolstrin9Including coil connecter tagged 4118108 12T12008 1 0.000 Qns & Slots Shot rop (aleun(rvDl laDo.. Tolima) Steir ) MB) (me) Unketl Zone Dere I sh Type Co. 8,056.0 8,1480 3,600.1 3,814.2 W A3, AS A2 81152004 40.0 ]PERE Aledutm9 lablank are, 1E-126 Slots 25•'X.125°,4 circumiarentieliowe/it- Applies W all redid 8,2]10 8,333.0 3,627.4 3,6307 WS A2, 1E-126 81 400 PERE 8,]88.0 8,984.0 3,6223 3,6118 WSA2, 1E-126 8/152004 40.0 WERE 0.336.0 9,918.0 3,5937 3,582.0 WSA2, 1E-126 811512004 40.0 PERE 10,0870 10,]61.0 3,591) 3,561.0 WS A2, 1E-12 81152004 40.0 IPERF 11,1040 12,122.0 3,55 A3,553.8 WS A21E-126 8/152004 40.0 IPERF Carlisle, Samantha J I ! ZqC From: Loepp, Victoria T (CED) Sent: Thursday, November 7, 2019 9:43 AM To: Carlisle, Samantha J (CED) Subject: FW: Request to Cancel 10-403 Approvals 318-068 and 318-069 Attachments: 1 E -105L2 APPROVED 10-403 MARCIT D MBE Trtmnt Sundry App.pdf, 1 E-12612 APPROVED 10-403 MARCIT D MBE Trtmnt Sundry App.pdf Sam, Please handle. Thanx, Victoria From: Peirce, John W <John.W.Peirce @conocophill ips.com> Sent: Thursday, November 7, 2019 9:33 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Hagge rty-Sherrod@contractor.conocophilIips.com> Subject: Request to Cancel 10-403 Approvals 318-068 and 318-069 Hi Victoria, I wish to request that 10-403 Sundry Approvals #318-068 and #318-069 be canceled. These approvals were granted 2/26/18 for a proposed MARCIT MBE Treatment involving West Sak 1E -105L2 and 1E -126L2 which are connected by an open Matrix Bypass Event (aka: Void Space Conduit). The approved 10-403 Sundries to be canceled are attached for reference: The reason for the requested cancellation is based on accumulated treatment performance results data for MARCIT MBE vs. RPPG MBE treatments. Per our performance data to date, we now believe that we have a much better chance of obtaining a long term successful MBE treatment by treating 1E -105L2 MBE using RPPG rather than MARCIT. I will be sending new 1E -105L2 and 1E-1261-2 10-403's to AOGCC next week to request approval for an RPPG MBE treatment to be fullbore pumped into 1E -105L2 as soon as possible. Regards, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office RBfl tb�AVOvV9ayV THE STATE °fALASKA GOVERNOR BILL WALKER John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E -126L2 Permit to Drill Number: 204-124 Sundry Number: 318-069 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of February, 2018. REDARS " FAD 4 7 2f18 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 NECEIVED FEB 21 ✓�d'S Z�Z3 p/ 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate E] Other Stimulate El Pull Tubing E] Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MARCIT DMBE Trtni 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhilll sAlaska Inc. Exploratory ❑ Development 121. Stratigraphic ❑ Service ❑ 204-124 , 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-23215-61 P 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A' KRU 1E -126L2 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25651, ADL 25660 1 1 Kuparuk River Field / West Salk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,457' 3,382' • 12,401'. 3,378' 1500psi NONE 7131,7860 Casing Length Size MD TVD Burst Collapse Conductor 82' 20" 108' 108' Surface 3,765' 133/8 3,795' 2,304' Intermediate 7,083' 95/8 8,088' 3,605' D Sand Liner 5,332' 5112 12,435' 3,380' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7136-12402 3425-3378 41/2 L-80 7,062' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKERS = 7076 MD and 7077 TVD - LEM PRODUCTION PACKER 12. Attachments: Proposal Summary ❑, Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch [I Exploratory ❑ Stratigraphic ❑ Development E] • Service ❑ 14, Estimated Date for 4/1/2018 15, Well Status after proposed work: Commencing Operations: OIL O ' 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: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265-6471 ,f Authorized Signature: Date:2,6z 1 - COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31-z Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No er RBDMS i-� F--'B'L' 7 2018 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: 10-404 APPROVED BY Approved by:OM7 COMMISSIONER THE COMMISSION Date: va 7/t* ' R I G I N A L Form 10403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate KUP PROD 1E-126 CanocaPAla O . s Well Attributes Max Angle & MD TD We^IWre APYUWI FceIJ Nam¢ Alaska, Inc. .,,.,.,,,, ,.____ wmleme scows .a r. ».e. $URF E. SBJ.M0, LOCATOR; LM aM RINI Oea 'mar oe, I Lem Cam Cam Perfs e GmICOPFillms KUP PROD 1E-126 I E::] 1E1 �. b11VM18 T.b:@MI X ER: 25.1 Perforations & Slots CONO CTOR',$6108 S110L Dans NIFPLE:5169 TOPMDI BbI11NDl lanalalll I Top MRD) BM,(..)WB) We) Zona DAM I Type Com .I— 12,3]8.0 12,5]!0 3,588.1 3,5]1.8 WS A2, 1E-128 &152004 40.0 IPERF Mandrel Inserts a SURFRLE: ]B 83]EG.0� Pm N T Tap(ND) M,40 Mab V.M. 1eRD OD �In) Sery Typ Typ Pott31[¢ iRORun 02 (psq Run Lom ws uFr:!+me 4,101 1 !101.9 2,409.8 CAMCO KBG-2- 1 GAS LIFT OV BK TG -2- 1R 0250 00 12 ]I1012012 2 5,280.9 2,825.5 CAMCO 1BG-2- 1 GASLIFT OV BK 0.250 0.0 52P2012 1R ws un; s.xe9e Notes: General & Safety End D'M Anndatlan wPPle'. e.9rz1 91H�2004 NOTE TRI -LATERAL WELL: 1 E-128(ABAND),1E-1MU(M-SAND), 1E-128L2(D-SAND) U1&2008 NOTE: ESTIMATE iOP OF FISH �J880'CTMD GAUGE', 89W.7 12312(109 NOTE: View SMEe .ULW/AM.0 SChemSUC9.0 10CAICA;11.11 �® SFALASV.I..M. D- a DUNER:7103a Tza o o-so„e wmw,]71NO � oza0 7,1810 6&WD LINER LEM, T010b TB2 B84ND LINER: ]3@.6 12,%B 66¢M WINwv 1 7.3210 &SViO LINFF IEM', ],2x52- ]0.5/.5 F18X:2,89J0 INTERMEDNTE: 27.0-0.LYO PERF; B,C59.Od.+aB.O` i { IPERF; BZl10 =0---- PERFBT980d.9Ba.0� IPERFAXMLd ,9180 IPERF: 10091610.7810 IPERF:11.1M0.12,1230� IPERF, 12.9R.0.12.5T10� _ ' AEPNOUNER:7,I126 12w.0� KUP PROD cc, IOLOP illip5 Well Att i6utes EIV6Vf!"' WellEare APVUWI WE¢ AlAlyskB.IDL, 5002923215fi1 WE: NIPPIF I 801 8242012 ILEAtWO: 1 51312007 1E -126L2 tEtxl2 ildYMa]1AMAM Last Tag AnnoMlbn .W rel En00¢@ t-Go.sa Last Ta B' Impstor Last Rev Reason gxndatlan EnOwte lastMM By Rev Reason: WELL REVIEW 102312013 Csborl xaxcER, 2a Casing Strings Cesmpw11.Plmn ODlln) ID lml rop 17,10 seL TopC wILm24 selwpm (NBL.. .5,50 D -SAND LINER 512 4950 7,1054 12,435.0 3,3804 1550480 DWC L40 Liner Details N urinal l0 TnplRHel I ]uplrvDl Btl(61 Tapllwl r) lam Ben cwn (m) /,103.4 3,416, ]4.88 HANGER BAKER MODEL B-1 LEM HOOH HANGER ,980 Perforations& SlOia LONOUCTOft:x01oA0 Shot Ben NIPPLE: 5189 Top IMLBI BM61MB1 Top(NDI (BKa) S.DVD) (XILBI Zmis B%o IMOIem 1 Type CRM 7,136.0 12,402.0 3,424.6 3,3)].9 WS D, 1E- 311512004 40D IPERF Altemating wMiank pipe, 126U sksh2.6'k.126",4 xem Tm'x:2,9]Y.0 arcumleren11a1 row5/lt- Applies to all Parts Notes: General & Safety Entl wle Annotaton f' 9/812004 NOTE: TRl-ATERALWELL IE-126(A-SAND4/E-126L1(D/C-SAN01.1E-02fiL2(D-$AND) u I 2,232009 INUlt,: View 6cnematc wl Alaska SchemaliC)b SURPACE,Ma MOO J GASUF ,1 t0IA W.S LIR: S,ffit8 NIPPLE:..1 GPUOE:BPJe.] LOCANR: 70391 SEALASSY:].01]3 I INTERMEOIATE: 27 M,MO 0 Sentl.,., ],1M6 T¢ao Dsnxo LINER LEM. 2.pN6 2.x9.2 mEND ].1Sa.0,,2,1020- 0.&WOLINER2t%.a 4050 Proposal 1 E-1051-2 to 1 E-1261_2 D MBE Treatment with MARCIT Gel 1 E-105 Tri-Lat injector has 4.5" tubing and horizontal laterals in the West Sak A, B, and D sands. 1E -105L2 D Lat exists at 7258 - 13536' RKB with 5.5", L-80 slotted liner. A 1E -105L1 B MBE RPPG job was pumped 5/1/17 with A & D Lats isolated. Post RPPG FCO, the'B Lat only' was BOI for 1 month with offset 1E-126 showing lower WC% and rising BOPD, so the A Lat Plug & D Iso Slv were pulled to gett all Lats back on injection, but this resulted an immediate spike up in 1 E-126 WC%. On 6/18/17, a 1E-105 mainbore IPROF saw 73% D, 26% B, 1% A (to suggest a D MBE). On 9/18/17, a D [PROF found all injection exited the D Lat at 7260' RKB at the D LEM junction, with injection possibly flowing down backside of D Liner to top of the first slotted liner -764' below the D LEM. The IPROF shows no down flow occurs in the first 764' of D Lat (blank liner section), but there may be some upflow in this section back up to the leak at 7260' per Spinner responses. We conclude all flow exits at D LEM, and some injection may flow -764' behind blank liner to enter the D Lat at the first slots at 8024' RKB. We cannot quantify flow splits that may go to a D MBE above 8024', or flow back into the D Lat below 8024', but the IPROF shows significant matrix injection exists at 8024 to 9500' RKB. D MBE location is unknown, but IPROF results suggest that an MBE (or very high perm thief) most likely exists somewhere behind the 764' blank liner section. On 2/2/18, a Plug was set at 7578' RKB to isolate A Lat, a B Diverter was set at 7520' RKB, and a D Iso-Slv was set. We would need to reconfigure 1E-105 for a proposed D Lat MARCIT MBE job. It is proposed that MARCIT Gel be pumped through the leak at -7260' RKB at D LEM with intent of, a) Halting all flow exiting D Lat at D LEM to restore all injection to the inside of D Lat liner, and to b) Seal D MBE, or high perm thief, that likely exists behind blank liner section at 7260-8024' RKB. Proposed Procedure: Coil Tubing: 1) RIH & pull D Iso-Slv from D LEM at 7240' RKB. 2) RIH & pull B Diverter from B LEM at -7520' RKB. 3) RIH & set B Iso-Slv in B LEM at 7520' RKB. 4) RIH & set D Diverter at 7240' RKB. Fullbore Pumping: 5) MIRU MARCIT Gel pumping equipment. Fullbore pump a Crosslinked Accelerated Viscosity MARCIT Gel job down 4.5" Tubing at 0.6 - 1.0 bpm to meet objectives listed above as follows: Pre -Flush with 50 bbls 2% KCL Brine, followed by 30 bbls Lead 10,000 ppm Linear Gel Spacer mixed in 2% KCL Water, followed by -35 bbls of Accelerated MARCIT Gel at 10,000 ppm mixed in 2% KCL Water, followed by 35 bbls Tail 10,000 ppm Linear Gel Spacer mixed in 2% KCL Water, followed by 28 bbls 2% KCL Water, followed by 47 bbls Diesel FP to 2000' TVD, followed by Shutdown to complete a full displacement of all Accelerated X-linked MARCIT into the D MBE. Leave well SI 5 days to let treatment cure. Return 1 E-1051-2 to injection to 'D sand only' to evaluate results of the D MBE treatment, and to consider performing another D lateral ]PROF to verify any changes in D Lat injection performance. JWP 2/21/2018 • .,~,~__~ ~~: MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE • F:\LaserFiche\C~vrPgs_InsertslMicrofilm Marker.doc · RECEIVED STATE OF ALASKA. MAY 2 5 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONSAlsska Oil & Gas Cons. Commission 1. Operations Performed: Abandon D Repair Well Q ~ Plug Perforations D Stimulate D Other Ae9norage Alter Casing D Pull Tubing Q Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory D 204-124/ ~ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23215-61 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 E-126L2 8. Property Designation: 10. Field/Pool(s): ADL 25651'& 25660 ' Kuparuk River Field / West Sak Oil Pool ~" 11. Present Well Condition Summary: Total Depth measured 12457' , feet true vertical 3382' / feet Plugs (measured) Effective Depth measured 12401' feet Junk (measured) true vertical 3378' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3767' 13-3/8" 3795' 2306' PRODUCTION 8060' 9-5/8" 8088' 3605' LINER 5332' 5.5" 12435' 3380' Perforation depth: Measured depth: 7136'-12402' 1 4 2007 ~)JUN true vertical depth: 3421'-3378' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7062' M) (tubing in main wellbore) Packers & SSSV (type & measured depth) Baker pkr @ 7076' in main wellbore Cameo 'DS' nipple @ 517' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation SI Subsequent to operation 174 665 116 -- 467 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory D Development Q Service D Daily Report of Well Operations _X 16. Well Status after work: OilQ GasD WAGD GlNJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Jill Long @ 265-1102 Printed Name Jill Long Title Wells Group Engineer OS/2+/07 Signature ell í i 7h/r'(((L Phone Date PreDared bv Sharon AI/sun-Drake 263-4612 U U f.Þ >.Z>;'ð7 Form 10-404 Revised 04/2006 ORIGINAl 3~ ..A S~~.ø~ . . ConocoPhiUips Alaska, Inc. KRU 1 E-126L2 ~. TUBING ~ API: 500292321561 (0-7062, SSSV Type: NIPPLE Or¡q Completion: 8/31/2004 Anqle (¡¡) TD: 86 deq (¡¡) 12457 00:4.500, Annular Fluid: LastW/O: 5/3/2007 Rev Reason: WORKOVER 10:3.958) Reference Loa: 28' RKB Ref Log Date: Last Update: 5/15/2007 Last Taa: TD: 12457ftKB Last Taa DescriDtion Size Top Bottom TVD Wt Grade Thread ( SURFACE 13.375 0 3795 2303 68.00 L-80 BTC SURFACE PRODUCTION 9.625 0 8088 3416 40.00 L-80 BTC-M (0-3795, r~~_ 00:13.375, Wt:68.00) .....IIIIIIlIIlIl\t,..... ..."........,."........ '" DescriDtion I Size Top Bottom TVD Wt Grade Thread r I 3378 I 15.50 I L-80.~ Size Top Bottom TVD Wt 1 Grade 1 Thread ~ 7062 I 34! Interval TVD Zone I Status I' Ft SPF Date Type Comment ~~~~£l; I'''~ '''RF 1;;0 n"~. _..~ slots 2.5"x.125"" 4 St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 85 5/12/2007 2 5281 OV 0 5/12/2007 n , ~ DeDth TVD TVDe ' Description ID 25 25 HANGER MCA 4.909 TUBING HANGER set 5/212007 3.900 517 515 NIP CAMCO 'DS' NIPPLE set 5/212007 3.875 2970 2006 Heat Trace HEAT TRACE 2970-3063' set 5/2/2000 0.000 6972 3383 NIP CAMCO 'DB' NIPPLE set 5/2/2007 3.813 6989 3387 Gauge A-WELL GAUGE MANDREL (WEATHERFORD) set 5/212007 3.950 Mandrel 7038 3400 LEM L2 D-SAND LATERAL ENTRY MODULE (LEM). TOTAL LENGTH 248' - includes "HR" 3.870 Liner Setting Sleeve, ID 7.6", XO Brushing ID 4.88", Seal Bore Extension ID 4.75", Production Packer ID 3.87", LEM HH Above Hook ID 3.95", LEM HH Below Hook ID 3.68", Non-Locatinq Seal Assemblv ID 3.89" SET 5/1/2007 7040 3400 SEAL BAKER GBH-22 SEAL ASSEMBLY 5/2/2007 3.890 7103 3417 HANGER L2 BAKER MODEL B-1 HOOK HANGER FOR LEM, FOR D-SAND LATERAL LEG 6.200 II 7104 3417 XO 5.500 7132 3421 PUP 4.950 ~ ~378 PUP 4.950 ~ Date Note 9/8/2004 I NOTE: TRI-LA TERAL WELL: 1 E-126CA-SAND , 1 E-126L 1 B/C-SAND , 1 E-126L2CD-SAND 'RODUCTION (0-8088, 00:9.625, Wt:40.00) HANGER L2 'OR (7103-7104, OO:8.500) PUP II:; (7132-7136, 00:5.500) Perf : (7136-12402) I I -. .. I · 'Y' ConocoPhillips ¡''lel/ylew Web Reporting Time Log Summary 04/17/2007 12:00 15:00 3.00 DEMOB MOVE DMOB P Move rig to let camp pass. Break down stack and secure on skid. Camp moved to 1 E. 15:00 00:00 9.00 DEMOB MOVE WOEQ T Waiting on cats for descent down hill between 2L & 2M 04/18/200700:00 03:00 3.00 MIRU MOVE WOEQ T Waiting on cats for descent down hill between 2L & 2M. Stage 2 Cats at 2L. 03:00 13:30 10.50 MIRU MOVE MOB P Move rig from 2N to hill, about 5 miles. ~(!rJ.#' .\ Tie Cats onto back of rig and move qp <O~ \ down hill to bridge. Release Cats to y.¡...¿ \. Gr D load out back at 2L Pad. Move rig W ~ \\J¡¡\1I1 across bridge and continue moving to />. ~ 2B Pad. w~~ ~j 13:30 00:00 10.50 MIRU MOVE WOW T Wait on weather / storm to subside. \ÌCtf vP ~IJ¡' Equipment needed to clear way for rig. 1'Y Rig currently waiting on 2B pad. 3\1~ Roads & Pads equipment tied-up \0\'''1\'' keeping spine roads open, will also need dozer to knock down drifts on both sides of road for ri to clear. 04/19/2007 00:00 00:00 24.00 MIRU MOVE WOW T Wait on weather / storm to subside. Equipment needed to clear way for rig. Rig currently waiting on 2B pad. Roads & Pads equipment tied-up keeping spine roads open, will also need dozer to knock down drifts on both sides of road for rig to clear. Winds subsiding around noon. Roads & Pads equipment catching-up to open roads, but equipment break downs (snow blower) limiting availability to clean out roadside drifts ahead of ri . 04/20/2007 00:00 12:00 12.00 MIRU MOVE WOW T Wait on weather / storm to subside. Equipment needed to clear way for rig. Rig currently waiting on 2B pad. Roads & Pads equipment tied-up keeping spine roads open, will also need dozer to knock down drifts on both sides of road for rig to clear. Roads & Pads equipment catching-up to open roads, but equipment break downs (snow blower) limiting availability to clean out roadside drifts ahead of ri . 12:00 13:00 1.00 MIRU MOVE MOB P Prep rig to move, warm up moving s stems Move rig from 2B pad to 2C pad. Rig catching up to road clearing e ui ment. 15:30 19:00 3.50 MIRU MOVE WOW T Set rig down and standby. Roads & Pads clearing drifts and road ahead of ri . 19:00 00:00 5.00 MIRU MOVE MOB P Move rig from 2C pad to 1 E - turn off spine onto 1 E access raod at midni ht. 04/21/200700:00 04:00 4.00 MIRU MOVE MOS P Continue move Nordic rig 3 from 1 E to 1 E pad. Arrive 1 E, cross pad, spot rig over well 1 E-126. 04:00 06:00 2.00 COMPZ RPCOII. RURD P PJSM, RU over 1 E-126, take fluids to pits, begin prep for ND tree, lay hard lines for kill tank, berm in selected equip. Accept Nordic rig 3 0400 hrs this date 4/21/07 06:00 08:00 2.00 COMPZ RPCOII. RURD P RU 2" circulating lines to manifold. Check hardlines to Tiger Tank. Bring seawater into pits and mix in 6% KCI. Srin in lubricator. 08:00 10:00 2.00 COMPZ RPCOII. RURD P PJSM. RU crane & hoist ESP spooler and empty spool onto rig floor. Set up s ooler. RD crane. 10:00 10:30 0.50 COMPZ RPCOII. OTHR P RU Vetco Gray lubricator. Pull BPV. 10:30 13:30 3.00 COMPZ RPCOII. RURD P RU circulating lines & PT with rig air. Thaw frozen outside line and blow clear. Finish RU line to Tiger tank & PT with ri air. 13:30 14:00 0.50 COMPZ WELCT OTHR P Check well pressures. Tubing & IA = 200 si. OA = 100 si. 14:00 17:30 3.50 COMPZ P PJSM. Circulate 8.8 ppg SeaWater/6% KCI down tubing, taking diesel returns from IA through choke to outside Tiger tank, 5 SPM. Had diesel returns until a full circulation, then got 8.8 ppg KCI/SW returns with diesel cut. Circulated to 470 Bbls and had trace of diesel in 8.8 ppg KCI/SW returns. Shut down 30 minutes to let diesel separate, circulated 15 Bbls, good 8.8 ppg KCI/SW with trace diesel. Let set 30 minutes more, then reversed 5 Bbls, 8.8 ppg returns from tubin with no diesel. 17:30 20:30 3.00 COMPZ WELCT OWFF P Monitor well, bleed slight gas migration, monitor well, no gas, no press build. Set BPV. 20:30 22:30 2.00 COMPZ WELCT NUND P PJSM, test packoffs / seals, repair threads on test port cover cap. ND tree. 22:30 00:00 1.50 WELCT NUND P PJSM, NU BOPE. 04/22/2007 00:00 03:30 3.50 COMPZ WELCT NUND P Cont NU BOPE. Page 2000 · 04/22/2007 03:30 08:00 4.50 COMPZ WELCT BOPE P PJSM, RU / test BOPE 250/2500 pSI 08:00 09:30 1.50 COMPZr RPCOII. RURD P Rig down lines, pull balancing plug & back pressure valve 09:30 10:00 0.50 COMPZr RPCOII. RCST P PJSM, Make up landing joint BOLDs, pull hanger to floor, broke free at 150k. PU 95k. 10:00 11 :30 1.50 COMPZr RPCOII. CIRC P Break circulation, lost 32 BBLS. Filled at 5.5 BPM 140 psi. 11:30 12:00 0.50 COMPZr RPCOII. OWFF P Monitor well, well static 12:00 14:30 2.50 COMPZ~ RPCOII. RURD P Rig up to spool ESP cable, lay down hanaer and landing joint 14:30 22:00 7.50 COMPZr RPCOII. RCST P Pull completion, spooling ESP cable and lavina down iewelry 22:00 23:30 1.50 COMPZr RPCOII. RCST P Drain, break down and lay down motor and seal. 23:30 00:00 0.50 COMPZr RPCOII. RURD P Clear floor 04/23/2007 00:00 02:00 2.00 COMPZr RPCOII. RURD P Continue clear rig floor, unload tools and equipment from rig. Bring in Baker equipment for cleanout BHA. Strap & caliper BHA. 02:00 02:30 0.50 COMPZr RPCOII. RURD P Set wear bushing. 02:30 04:30 2.00 COMPZr RPCOII. OTHR P Change elevators. PU & MU cleanout BHA #1: 4-11/16" smooth OD Shoe & Globe Basket (3-1/4" ID) + 2 XO + 8 Jts 2-7/8" PAC DP + 2 XO + 2 Boot Baskets + BS + Bumper + Oil Jar + Pump Out Sub + XO. 04:30 14:00 9.50 COMPZr RPCOII. TRIP P RIH PU 9 DC. RIH PU 4" DP. Tag fill at 6705' MD, set down to 6711' MD. 14:00 14:30 0.50 COMPZr RPCOII. OTHR P PU and MU head pin and hose. RU to reverse circulate and wash out fill. 14:30 16:00 1.50 COMPZI RPCOII. FCO P Close bag, reduce closing pressure. Reverse circulate and wash out fill from 6705' to 6718'. Reverse bottoms up, got very fine sand returns. 70 SPM, 4 BPM, 450 psi. 16:00 22:30 6.50 COM pzr RPCOII. FCO P Continue washing down singles, reversing, 70 SPM, 4 BPM, 440 psi. Clean out fill from 6718' to 6861 ft. No further proaress. Will not wash. 22:30 00:00 1.50 COMPZr RPCOII. FCO P PJSM, Press check, open BOPE, flow check, line up for conventional circ, commence wash, immediate success, cont wash to 7038 ft. 140 spm /990 I psi. Fine sands to shaker. 04/24/2007 00:00 04:00 4.00 COMPZI RPCOII. FCO P Wash to tag (btm SBR) at 7293 ft. Lose circ, 100% loss, no returns. Monitor well, no gas / wellbore not on vacuum. 04:00 05:30 1.50 COMPn RPCOII. CIRC P Call DHD for fluid level shot. Pump sweep dn tbg and annulus for cleanout residual sands while wait on equip. .......... D, .. 1(1 '" ..... ." .<01:1".... 04/24/2007 05:30 06:00 0.50 COMPZ~ RPCOII. OWFF P PJSM, RU / shoot fluid level resulting in level at 420 ft. Hole will fill at surface at 6 bpm, immediately falling to 420 ft, but no returns while pump dn DP or annulus. 06:00 07:30 1.50 COMPZ~ RPCOII. TRIP P POOH from 7293' to 6369'. Overfill hole for trip volume. 07:30 09:00 1.50 COMPZ~ RPCOII. OTHR P PJSM. RU crane. Remove old ESP cable spool. Bring in I-wire on spooler. Bring in clamps, etc. Set in heat trace cable and spooler. RD crane. 09:00 15:00 6.00 COMPZr RPCOII. TRIP P Continue POOH from 6369' to 570'. Overfi!1 hole for trip volume, pumping an extra 5 Bbls fill-up each 5 stands. 15:00 17:30 2.50 COMPZr RPCOII. TRIP P LD 9 DC & cleanout BHA #1. All tools in good shape. Recovered only a few small pieces of thin metal from original window milling in globe basket. Only a small amount of fine sand in boot baskets. 17:30 18:30 1.00 COMPZr RPCOII. OTHR P Clear floor. Pull wear bushing, verify LEM equipment will pass through WB, OK. Set test pluq. 18:30 19:30 1.00 COMPZ~ WELC1 BOPE P Test variable PR with 4", retest annular, 250 psi & 2500 psi. 19:30 21:00 1.50 COM PZ~ WELC1 BOPE P R/D and UD test equipment. Set Wewar Rinq. 21:00 00:00 3.00 COM PZ~ RPCOII. PULD P P/U and assembly LEM #2. Shoot fluid level at 2300 hrs, TOF @ 150 ft. 04/25/2007 00:00 01:00 1.00 COMPZ~ RPCOII. PULD P M/U LEM. Orient w/ MWD, RIH. 01:00 01:30 0.50 COMPZ~ RPCOII. TRIP P Shuffle DC's and Drillstring for RIH. RIH w/ 5 stds DP. 01:30 02:00 0.50 COM PZ~ RPCOII. OTHR P Shallow test MWD. 02:00 06:00 4.00 COM PZ~ RPCOII. TRIP P RIH w/ LEM Assembly. 06:00 09:00 3.00 COMPZ~ RPCOII. TRIP P Cont RIH w/ LEM Assembly. 09:00 11 :00 2.00 COMPZ~ RPCOII. HOSO P Locate and attempt to latch into hook hanger w/ LEM. Orient and circulate, wash to 7283', unable to latch. Pump 50 bbls down annulus to flush seal bore. Pump addnl 50 bbls, attempt to set again. Unable to circulate, fluid level w/ pumping just below bell nipple on stack. 11:00 18:30 7.50 COMPZr RPCOII. FCO T Continue attempting to set LEM w/ alternate pumping/ rotating and recip. Unable to land and latch into Hook Hanger. Possible sand fill in wellbore. Decision made to POOH w/ LEM as no progress. 18:30 00:00 5.50 COMPZ~ RPCOII. FCO T POOH w/ LEM assy f/7115' - 269'. 1\ "';. ....'." .....iAlt .. '. ..... .... ...~... ....... . ./ 04/26/2007 00:00 01 :00 1.00 COMPZr RPCOI\ FCO T POOH to LEM. Prepare to layout MWD and LEM components. 01:00 06:00 5.00 COMPZr RPCOI\ FCO T While breaking out setting sleeve running tool, inner string backed off. Unable to extract inner string due to excessive sand pack-off. PJSM, begin break out inner string and LEM via individual component. Break out all. Extract MWD tools, inspect and prepare LEM I running equipment for shipment to shop for inspection and clean-up. Visual on Hanger and latch assembly revealed untouched paint so failure to set likely due to excessive sand in wellbore. 06:00 08:00 2.00 COMPZr RPCOI\ FCO T Load and strap 2 7/8" PAC pipe and handling tools in pipe shed for CIO run. 08:00 12:00 4.00 COM pzr RPCOI\ FCO T PJS~1I1 R!H \AJf CIO 2 7/8" P.A~C pipe clean-out assembly on end of 4" DP work strinq to 7071'. 12:00 14:30 2.50 COMPZr RPCOI\ FCO T RU to pump down DP and annulus simultaneously. Pump at 3 bpm down annulus, 2 bpm dn DP wI annular SI fl 7071' -7166'. 14:30 18:30 4.00 COM pzr RPCOI\ FCO T Work pipe wI pumping f/7166' - 7324'. Hit obstruction at 7286 and work through wI tbg. At end of clean-out, located hook wI no-go collar at 7103'. Mule shoe depth 7324'. 18:30 20:30 2.00 COMPZr RPCOI\ FCO T Blow dn top drive, and POOH w/5 stands wI pumping. SD and wait for 1 hr to observe. 20:30 21:30 1.00 COMPZr RPCOI\ FCO T RIH wlo pumping to determine fill, none detected, again locate and land on hook at 7103'. Pump 20 bbls wI pumping at 3 bblsl min dn annulus and 2.5 bbllmin dn DP. 21:30 00:00 2.50 COMPZr RPCOI\ FCO T POOH f/7324' - 3078'. Overdisplace hole x 2 pipe displacement in attempt to minimise sand inflow. 04/27/2007 00:00 02:00 2.00 COM pzr RPCm TRIP T TOH, Top Drive developed probem. 02:00 03:00 1.00 COMPZr RIGMN RGRP T Work on Top Drive electrical problem. 03:00 03:30 0.50 COMPZr RIGMN SVRG P Service and lube rig. 03:30 06:00 2.50 COMPZr RPCOI\ TRIP T POOH wI workstring and PAC clean-out strinq. 06:00 06:30 0.50 COMPZr RPCOI\ TRIP T Finish wI Clean-out string. LD 2 7/8 PAC pipe and XO's. 06:30 08:00 1.50 COMPZr RPCOI\ PULD T Make up LEM. 08:00 12:00 4.00 COMPzr RPCOI\ PULD T Wait on pups for inner string and make up bull nose shoe jt. Work on Top Drive. l:: .,,> ..' . '.; ...X .... . Page 5 of1lJi! .... ....... . 04/27/2007 12:00 15:00 3.00 COMPZr RPCOI\ PULD T PJSM. Make up inner string tools for LEM run. Assemble inner string wI MWD and install in LEM Run In tool. 15:00 15:30 0.50 COMPZI RPCOI\ TRIP T @ 320 psi. PU 45klbs, SO 46klbs 15:30 23:30 8.00 COMPZr RPCOI\ TRIP T BD TD and RIH wI LEM f/473' - 7019'. PU 125 klbs, SO 58 klbs. 23:30 00:00 0.50 COMPZI RPCOI\ SFTY T PJSM wI Drlr, Tool Hnd, Co Rep and rig crew. Discuss procedure and wash-in I set procedure for LEM. 04/28/2007 00:00 01:30 1.50 COMPZI RPCOI\ CIRC T Break circulation, rate 52 spm @ 460 psi. Orient assembly wI MWD, pump wI slowly work in hole to 7264', near top of cSQ seal bore assy. 01:30 05:00 3.50 COMPZI RPCOI\ RCST T Cut pump rate to 10 spm, 50 psi and cont RIH to land hook hanger. Stack out at 7279. Based on PU and SO, determine top SBE at - 7273' dd. Unable to land assy. PU and try a!t LEM orientation. Noted pump press increase to 510 psi at 52 spm. Press same wI or wlo seals stabbed into Csg SBE, possible plugged hole on bullnose circ jt. Cont wI landing attempt by alternating LEM orientation and recip. Unable to proceed, noted stack-out depth same as original LEM run attempt. Decision made to POOH and alter Ie nth of seal spacer pups. 05:00 06:00 1.00 COMPZr RPCOI\ TRIP T PJSM, POOH wI LEM assembly for modification. Pumping fld down backside at 16 - 20 bblsl hr. 06:00 07:00 1.00 COMPZI RPCOI\ TRIP T Cont TOH to 6366'. 07:00 08:30 1.50 COMPZI RIGMN SVRG T PJSM, Slip and Cut Drill Line. 08:30 14:00 5.50 -- COMPZI RPCOI\ TRIP T TOH wI LEM assembly. f/6366' - 0' 14:00 16:30 2.50 COMPZ' RPCOI\ PULD T Break out and lay down LEM assembly & MWD tools. 16:30 19:00 2.50 COMPZI RPCOI\ WOEQ T Wait on composite bridge plug, clean floor and rig upkeep. 19:00 00:00 5.00 COMPZI RPCOI\ PULD T PU and MU Bridge Plug on 2 7/8" PAC DP. RIH to 7299' MD. 04/29/2007 00:00 01:30 1.50 COMPZr RPCOI\ PACK T Set 4" Baker model 360 Quik-Drill composite bridge plug @ 7295' dd inside tubing below csg seal bore assembly. Test wI tag. OK. Break circulation at 2 bpm to monitor for returns, 100 %. 01:30 05:30 4.00 COMPZI RPCOI\ TRIP T PJSM, POOH wI setting tool. Break out running tool, LD 2 7/8" PAC stri~ 05:30 06:00 0.50 COMPZI RPCOI\ PULD T PJSM, PU LEM assembly wI wash string for hook hanger latch test. (Test only, to confirm latch possible) 06:00 08:00 2.00 COMPZI RPCOI\ PULD T PU LEM assembly wI MWD, RIH 3 stds. '.' .......... .' ..' . l:J""n ~t\f ···.1 . . ..~ . · 04/29/2007 08:00 08:30 0.50 COMPZr RPCOfl. CIRC T Shallow test MWD @ 53 spm, 350 Dsi, OK. 08:30 11:30 3.00 COMPZr RPCOfl. TRIP T Cont RIH wI LEM - 6888'. 11 :30 12:30 1.00 COMPZI RPCOfl. CIRC T Circulate wI TI H wI LEM 6888' - 7107'. 65 spm @ 650 psi, 120 klbs up, 57 klbls dn I wash through collet lock area wI ietted sub to remove debris. 12:30 19:30 7.00 COMPZI RPCOfl. DHEQ T Multiple attempts to latch in LEM. Vary orientation, set weights, circulating, washing etc in attempt to set and latch LEM. Last 5 attempts to latch succesful. LEM set and Latch depth 7105.5'0 Total TD BHA = DP 7133'. PU 125 klbs, SO 53 klbs. Last attempt after full pick-up and rotation of pipe to insure repeatability, OK. 19:30 21:30 2.00 COMPZr RPCm, C!RC T Circulate hi-vis sweep, CBU and prepare to POOH. 21:30 00:00 2.50 COMPZr RPCOfl. TRIP T TOH wI LEM and MWD assembly. fl 7133' - 3559'. 04/30/2007 00:00 02:30 2.50 COMPZr RPCOI\ TRIP T TOH wI LEM and MWD. Break out and LD LEM after inspection. No visible sign of damage or other. Inspection of collet latch and hook reveal latch OK. 02:30 03:00 0.50 COMPZr WELC1 BOPE T Clear floor and prepare for BOPE test. 03:00 06:00 3.00 COMPZr WELC1 BOPE T PJSM, Test BOP equipment. 06:00 09:00 3.00 COMPZr WELC1 BOPE T Finish BOPE test. Test all components 250 12500 psi, all ok. Pull test pluq, set wear bushing. 09:00 12:00 3.00 COMPZr RPCOfl. PULD T PJSM, PU Globe baske on 2 7/8" PAC tail pip. RIH wI 4" DP U6440'. Calc disp 36 bbls, Acutal 34 bbls) 12:00 15:30 3.50 COMPZr RPCOfl. CIRC T Cont RIH f/6440' - 7203'. Attempt to reverse circulate, Pump 70 bbls, no returns, no fluid observed at surface in well. Pump addnl 30 bbls, no returns. RIH tag bottom of SBE 7295' wI no fill detected. P/Up 6', pump addnl25 bbls, FL shot TOF @ 282' in DP. PU 125 klbs, SO 60 klbs. POOH 3 stds U 7010', shoot fluid level, TOF @ 282' in DP. 15:30 20:30 5.00 COMPZr RPCOI\ TRIP T TOH wI clean-out assembly f/7010'- 262'. 20:30 21:00 0.50 COMPZr RPCOI\ PULD T LD clean-out BHA. 21:00 00:00 3.00 COMPZr RPCOI\ PULD T PJSM. PU LEM assembly wI packer and seal assv, 05/01/2007 00:00 01:00 1.00 COM PZ~ RPCOfl. PULD T Finish PU I MU of LEM-2 assy wI packer, seal assy & MWD for orientation. .... ;. ..... .'. '.' P~9.eT I .... ..... / 05/01/2007 01:00 01:30 0.50 COMPZr RPCOI\ CIRC T Shallow test MWD, OK. 01:30 09:00 7.50 COM pzr RPCOI\ TRIP T TIH wI LEM-2 assembly at max trip speed of 30 ftlmin. Observe fluid loss while TIH to 7296 ft. Losses at rate of 24+ bbllhr, no returns. 09:00 10:30 1.50 COM pzr RPCOI\ PACK T Work hook assy, orient to hook. In place at 18 deg to right. Pull up 10ft, partial rotation, set dn, confirm with return to 18 deg to right. No collet "snap" felt at surface after multiple attempts. Partial returns during procedure. Up 140, Dn 70 10:30 11 :30 1.00 COMPZr RPCOI\ CIRC T Circ with partial returns while mix I pump 1 % lube. Note Up I Dn wts. decreased to 132 Up, Dn 70. 11:30 12:00 0.50 COMPZr RIGMN SVRG P Service rig while circ lube. 12:00 1 ':I."'" 1.50 ICOMPZr RPCm, PACK P Latch LEM, Defined collet indicator. y.....,'" Confirmed "snap" in I out of position. Drop ball, pump dn to pkr. Build to 4030 psi, pkr set. PKR 7076 ft, Top hook 7105.5 ft. 13:30 15:30 2.00 COMPZr RPCOI\ DHEQ P PJSM, test pkr (9-5/8 X 4" DP) to 2500 psi I 30 min and chart. Bleed and re-test 3 times to obtain final straight line test. (Aired I foamed fluids) 15:30 16:00 0.50 COMPZr RPCOI\ TRIP P Blow down top drive, monitor well, taking fluid, PJSM. 16:00 00:00 8.00 COMPZ RPCOI\ TRIP P Continue POOH wI lay down 4" DP workstring. POOH f/7076' - 1537'. 05/02/2007 00:00 03:30 3.50 COMPZI RPCOI\ TRIP P POOH lay down workstring. Lay down runninç tools, MWD and other. 03:30 04:30 1.00 COMPZI RPCOI\ PULD P Clear floor, pull wear bushing and prepare for running of completion. Load remaining 4 1/2" IBT tubing in 'pipeshed and strap. 04:30 06:00 1.50 COMPZ RPCOI\ RURD P RU to run completion on 4 1/2" IBT tbg. Pull wear ring, RU and Tee-wire and heat trace spoolers, fct test. 06:00 12:00 6.00 COMPZr RPCOI\ PULD P PJSM, Connect TEC-wire tI inst sub, RIH wI completion flO - 2722'. Installing TEC-wire wI single channel Cannon clamps as per proçram. 12:00 15:30 3.50 COMPZ~ RPCOI\ PULD P Continue RIH wI completion fl 2722' - 4185'. 15:30 16:30 1.00 COMPZr RPCOI\ RURD P RU fl start of Heat Trace installation. 16:30 00:00 7.50 COMPZr RPCOI\ PULD P Cont RIH wI completion f/4185' - 6768' wI TEC-wire and heat trace attached wI dual channel Cannon clamps as ¡per program. ... , '.' Pagø , .,.(1 >..... > ..... .'. ., . Continue RIH w/4 1/2" IBT tubing to top of seal bore extension. Tag no go at 7041'. Fill annulus, monitor well. No losses. Determine PU/SO to insure tubing landed in tension wI locator at 7039ft, i.e. 2' off bottom. 06:30 10:00 3.50 COMPZ RPCOII. HOSO P Space out, MU pups I tbg hgr Ildg jt. Total TEC-wire and Heat trace clamps used as follows: (131) Single channel Cannon @ 1/jt below heat trace. (455) 5' dual channel clamps, (9) 4' dual channel clamps, (9) 3' dual channel clamps, (9) 2' dual channel clamps, 89 Cplg dual channel clamps @ collars, 2 bands at hanger area. Heat trace start at 4092'. 10:00 14:00 4.00 COMPZ RPCOII. OTHR P Prep hngr, terminate TEC wire I heat trace to h r. Test all connections. 14:00 16:00 2.00 COMPZ. RPCm, C!RC p Attempt reverse circ. No returns. Pump 170 bbls 1 % CRW32 inhibitor dn tbg to 4-1/2 X 9-5/8 annulus. Approx 30% returns to surface during circ. 16:00 17:00 1.00 RPCOII. HOSO P PJSM, land hgr, RILDS. Confirm hgr dn. 17:00 19:00 2.00 RPCOII. DHEQ P RU I test IA wI chart recorder. Build I hold 1000 psi, 30 min. OK. Build I hold 1500 psi 30 min, OK. Pressure up to shear SOV. SOV sheared out ;/ at 1960 psi. Pump addnl18 bbls to insure clear. RD pressure sensors and clear floor for next task. 19:00 23:00 4.00 COMPZ WELCT NUND P PJSM. SET BPV, ND Stack wI service breaks for storage. Remove stack and clear area for settin tree. 23:00 00:00 1.00 COMPZ WELCT NUND P Test heat trace and TEC-wire DMS, OK. Prepare connections and wellhead for settin tree. 05/04/2007 00:00 03:00 3.00 COMPZ RPCOII. NUND P Finish prep of wellhead set in place. Install tree. Pull BPV, Set 2-way / check, pressure test pack-off 5000 psi OK. Test tree 250/5000 psi, OK. Pull 2-wa check, set BPV. 03:00 05:00 2.00 COMPZ RPCOII. RURD P Work on rig prep for move, while wait on hot oil for freeze protect. RU hard line, ull tar s etc.. 05:00 07:00 2.00 COMPZ RPCOII. FRZP P RU, hot oil, PJSM, ptest lines 2500 psi. Freeze protect IA wI 160 bbls diesel, had 5 bbls total returns. Swap valves and freeze protect tbg by bullheading 60 bbls. ICP 100 psi, FCP 1375 wI pumping IA. ICP 150 psi, FCP 500 wI pumping tbg. Final static tbg press 200 psi, IA 400 psi. RD, release Hot Oil. 07:00 08:00 1.00 COMPZ RPCOII. RURD P PU lubricator, set BPV. Page 9 of 10 Finish clean pits & prep rig for move, NORDIC RIG #3 RELEASED THIS DATE 1000 HRS. 1~~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permitto Drill 2041240 Well Name/No. KUPARUK RIV U WSAK 1E-126L2 Operator CONOCOPHILLlPS ALASKA INC .JJf'lJ Æ'l ~~V( API No. 50-029-23215-61-00 MD 1245¡- TVD 3382- Completion Date 8/31/2004 Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ves DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: (data taken from Logs Portion of Master Well Data Maint Interval . OH/ Start Stop CH Received Comments 7105 12457 Open 9/22/2004 -, I 108 12457 Open 2/6/2005 MPR/GR 108 12457 Open 2/6/2005 MPR/GR I 108 12457 Open 2/6/2005 MPR/GR I 108 12457 Open 2/3/2005 multiple propagation I resistivity, gamma ray, rwd . ~ Log/ Electr Data Digital Dataset Type Med/Frmt Number Name fRPt Directional Survey I~ C Lis 13005 Induction/Resistivity ~C Pds 13005 Induction/Resistivity f-ø' C Asc 13005 LIS Verification ~~' Induction/Resistivity L Log Log Run Scale Media No 25 Blu Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? V@ Daily History Received? ~N ~/N . Chips Received? - Y I 14 Formation Tops Analysis Received? ~ ---~ Comments: Comptlanoo ".vlewed By, _ _ ~ · Date: ¿;z (0 ~~ 20J - /z-¿ . c;;;'OL/ - /2:3 ¿?(o tf - /2 c¡ I~~II [=;;~,:-:-;~=--I ~. ~:;;'~:-;i";:';';_u "1 BAKER ' HUGHES f:_:~~~t::___j :~~ :~.. "':-. ...... \ Anchorage GEOScience Center :'.. :::::' ; _.\ '. Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: / *l :,c5b'1 lE-126, lE-126Ll, & lE-126L2 Robin Deason Reference: Contains the following for each wellbore: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 707446 Date: Feb 4, 2005 Date: ~; j-' Received 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 . . --. ~~~.~ ~,"I'-'''''',''' ~~:," ~~~":':"'~'--~~:' j n__. -..____nu___ o__."__n_._n... ~ !~ ...... p",,:t.¡ : ¡ ~.. : " ì--'-- 'i ì I í ¡ , i-',·:¡· : ; t-~ ", !' [:1':-: 1"---' fLi- 'Kt-lc ¡ ~r., !'::~;1 i,F;f~ !-:'~: ~t ,~r~rj }fL.:; r ~..... ~.. ~¡0",f, _." !' ;...~.~~~ "'0 ....,; "'~ i''--- ..- )_._---.;~.-_..-:-:-------.-.,- ~:~.- r"::,?ïi' i r"··· I"',' i [ , i--'~::'::":::'::'~~'""' l._______L______ . STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COM "ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged 0 Abandoned 0 Suspended 0 WAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions _ Other - Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: / ConocoPhillips Alaska, Inc. or Aband,: August 31,2004 204-124/ 3. Address: 6. Date Spudded: 1-'1 P'P.¡ 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 August~ 2004 IC'f,;,'" 50-029-23215-61 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 852' FSL, 631' FEL, Sec. 16, T11 N, R1OE, UM August 26, 2004 1E-126L2 At Top Productive 8. KB Elevation (ft): 15. FieldlPool(s): Horizon: 1616' FNL, 1439' FEL, See, 22, T11N, R1OE, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool 1639' FNL, 1935' FEL, Sec. 27, T11N, R1OE, UM 12401' MD 13378' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 549890 . y- 5960439 Zone-4 / 12457' MD I 3382' TVD / ADL 25651 & 25660 TPI: x-554383 y- 5958002 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x-553934 y- 5952697 Zone- 4 none ALK 469 & 470 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of NIA feet MSL Permafrost: 1746' MD 21. Logs Run: '7 i.U~6"1t) "7 I ó,> "/nO ""Þ GRlRes I F rv þ.¿,.o'f .3 ,",/7' Þ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD PULLED CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 20"x34" 94# K-55 28' 108' 28' 108' 42" 348 sx AS1 13-3/8 " 68# L-80 28' 3795' 28' 2306' 16" 740 sx AS Lite, 210 sx DeepCrete 9-5/8" 40# L-80 28' 8088' 28' 3605' 12.25" 726 sx DeepCrete 5.5" 15.5# L-80 7103' 12435' 3417' 3380' 8.5" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6093' 7413' slotted liner - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. slots in liner from 7136'-12402' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 20, 2004 Flowing (shares production with 1 E-126 and 1 E-126L 1) Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 9/21/2004 6 hours Test Period --> 270 253 0 15% 998 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. o psi not available 24-Hour Rate -> 1045 1043 1 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary), Submit core chips; if none, state "none", RECEIVED fGãr¡,?:r'T:5f¡--¡ ¡ Sl. U~'f. ClJ NONE OCT 06 2004 l ,seD , OR'Gr~lAL Alaska Oil & Gas ecms, (;ommissitm ._._ '--;;:J Anchorage Gf/ - ~pn~ ROO~S Bfl 0C10~ Form 10 407 Revised 12/2003 CONTINUED ON REVERSE 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 E-126L2 West Sak D 7099' 3416' RECEIVED OCT 0 62004 ,Alaska Oil & G:1S C"", Co .. "',,<1. mmlSSlcn Am::homge NIA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31, I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 PrintedNam~~ Signature \ \ ~ l Title: - Phone KUDaruk Drillino Team Leader 2-"r b"S3D Date \0(5/0'7' Prepared by Sharon Allsup-Drake 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness, Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none", Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: Blow down rig, Move pipe shed, Boilers, Motors, Pumps, Pits, Rockwasher & Sub complexes off 1 E-112. Spot Sub & all complexes over 1 E-126. Hook up Air, Water, Steam, Glycol, Mud lines, Prep. rig for accept. Accept rig @ 09:30 hrs 8/1/2004, Nipple up Diverter system, Take on water and mix Spud mud. Change out saver subs, Change to new drilling line spool. Pick up 50 stands 5" drill pipe and stand back in derrick. Note: Rig up on Injection well 1 E-34, Flush with 140 bbls Fresh water at rate of 1 bpm @ 1550 psi. Pick up 29 jts HWDP, Jars and stand back in derrick. Function test Diverter system, Test waived by AOGCC John Crisp. Service Top drive & Blocks. Pick up & Make up 16" BHA, Bit, Motor, Short NMDC, NM Stab, MPR, MWD, NMDC's, Orient & Program MWD tools, Flood Conductor and check for leaks. Spud well @ 05:00 hrs 8/2/04, Drill 16" hole f/1 08' to 558' MD / 557' TVD, (450') ART = 1.5 hrs, AST = 3.2 hrs, WOB 20/35K, RPM 0/40, 570 gpm @ 1150 psi, UP 66K, DN 68K, 67K, Mud wt. 8.8 ppg, Vis 300+. Drill 16" hole fl 558' to 2000 MD' 11662' TVD, (1,442') ART = 0.0 hrs, AST = 9.1 hrs, 100% Sliding, WOB 40/45K, 607 gpm @ 2300 psi, UP 98K, DN 80K, Mud wt. 9.2 ppg, Vis 200+. Drilled 16" hole per directional plan from 2,000' to 3,331' MD/2, 133' TVD (1,331') ART 3.4 hrs, AST 2.7 hrs, 5-45K wob, 80 rpm's, 175 spm, 740 gpm, off btm pressure 2,550 psi, on btm 2,700 psi, off btm torque 5K ft-Ibs, on btm 8K ft-Ibs, rot wt 84K, up wt 100K, dn wt 75K 1.00 RIGMNT RGRP SURFAC Changed out swab and liner on #2 mud pump 6.50 DRILL DRLG SURFAC Drilled 16" hole per directional plan from 3,331' to 3,802' MD/2,308' TVD (471'), surface csg point, ART 2.8 hrs, AST 1.3 hrs, 5-45K wob, 80 rpm's, 175 spm, 740 gpm, off btm pressure 2,500 psi, on btm 2,700 psi, off btm torque 8K ft-Ibs, on btm 10K ft-Ibs, rot wt 87K, up wt 125K, dn wt 65K, 9.4 ppg MW, began seeing gas hydrates after drilling below 3,792' Backreamed out of hole from 3,802' to 1,100', backreamed at 80 rpm's and 150 spm, 636 gpm at 1,700 psi, worked thru tight spots at 3,170', 2,550' and 1,100', gas hydrates stopped after backreaming out at 2,200' Pumped out of hole from 1,100' to 360', circ at 636 gpm at 1,600 psi, attempted to pull on elevators at 730' and 550' and was pulling tight, pumped out to 360' Stood back 2 stds HWDP and jars, LD 1-short NMDC and stabilizer, drained motor and broke out bit Downloaded MWD LD MWD, MPR and mud motor Made dummy run with hanger and landing jt with no problems RU Doyon's 133/8" csg equipment with Franks fill-up tool Held PJSM with rig crew and tong operator on running of surface csg PU 133/8" float shoe and jt #1 & RIH, PU float collar and jt #2 and attempted to MU float collar, was unable to get float collar to MU into shoe jt, threads appeared ok, collar possibly egg shaped, LD float collar jt and shoe jt 1.50 WAlTON EQIP SURFAC Waited on new float shoe and float collar to be delivered to rig 8.00 CASE RUNC SURFAC Ran 133/8" 68#, L-80, BTC csg and landed same at 3,795', MU new 13 3/8" float shoe onto jt #1, MU new float collar on Jt #2 then onto shoe jt, 02:00 - 08:00 MOVE 08:00 - 09:30 MOVE 09:30 - 13:30 SURFAC 13:30 - 18:30 5.00 RIGMNT RSRV SURFAC 18:30 - 00:00 5.50 DRILL PULD SURFAC 8/212004 00:00 - 01 :30 1.50 DRILL PULD SURFAC 01 :30 - 02:00 0.50 WELCT BOPE SURFAC 02:00 - 02:30 0.50 RIGMNT RSRV SURFAC 02:30 - 05:00 2.50 DRILL PULD SURFAC 05:00 - 12:00 7.00 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 8/3/2004 00:00 - 11 :00 11.00 DRILL DRLG SURFAC 11 :00 - 12:00 12:00 - 18:30 18:30 - 00:00 5.50 DRILL REAM SURFAC 8/4/2004 00:00 - 01 :30 1.50 DRILL TRIP SURFAC 01 :30 - 02:45 1.25 DRILL PULD SURFAC 02:45 - 03:15 0.50 DRILL PULD SURFAC 03: 15 - 04:00 0.75 DRILL PULD SURFAC 04:00 - 04:15 0.25 CASE OTHR SURFAC 04:15 - 06:00 1.75 CASE RURD SURFAC 06:00 - 06:30 0.50 CASE SFTV SURFAC 06:30 - 08:30 2.00 CASE RUNC SURFAC 08:30 - 10:00 10:00 - 18:00 Printed: 9/1012004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/412004 10:00 - 18:00 8.00 CASE RUNC SURFAC thread locked connections below float collar and tack welded btm of collar below fit collar since float equipment was not bucked up at machine shop, RIH with Jt #3 and circ thru float equip and floats ck ok, cont to RIH with 90 jts 133/8' csg (93 jts total), MU landing jt and hanger and landed csg with float shoe at 3,795' MD/2,306' TVD and float collar at 3,756', ran 15 bow spring centralizers, worked thru tight spot at 800' then RIH, broke CÎrc and washed down jts # 68 thru 71 due to heavy mud back and very little returns, after washing down had good returns and cont RIH to btm with no other problems, St wt when landed, Up Wt 225K, Dn Wt 115K 18:00 - 19:30 1.50 CEMEN CIRC SURFAC Circ btm's up with Frank's tool. Broke circulation at 2.5 bpm and staged pump rate up 7 bpm @ 300 psi. Reciprocated csg, St Up wt 205K, Dn Wt 110K. 19:30 . 20:00 0.50 CEMEN RURD SURFAC LD Franks fill-up tool and MU Dowell's cement head 20:00 . 23:00 3.00 CEMEN CIRC SURFAC Cont to circ and condition mud for cementing, circ at 7 bpm at 400 psi, reciprocated csg with 215K up wt and 115K dn wt, final MW, 9.3 ppg, 40 vis, 9 YP and 16 PV, held PJSM with Dowell, vac truck drivers and rig crew on cementing surface csg while circ hole 23:00 - 00:00 1.00 CEMEN PUMP SURFAC Began cementing 133/8" csg, Dowell pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 42 bbls of 10.5 ppg mudpush, began mixing and pumping Arcticset lead slurry, as of 24:00 hrs have mixed and pumped 100 bbls of lead cement at 10.7 ppg and 4.45 yield with additives, ave 4 bpm at 100 psi, reciprocating csg while pumping cement 8/5/2004 00:00 - 01 :45 1.75 CEMEN PUMP SURFAC Cont cementing 133/8" csg, finished mixing and pumping 485 bbls of lead cement at 10.7 ppg and 4.45 yield with additives, pumped a total of 585 bbls (740 sxs) of ArticSet Lite cmt, ave 6.5 bpm at 110 psi, followed with 93 bbls (210 sxs) of DeepCrete tail cmt at 12.1 ppg and 2.47 yield with add., ave 6 bpm at 110 psi, reciprocated csg and had full returns, shut down and dropped top plug 01 :45 - 03:30 1.75 CEMEN DISP SURFAC Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 541 bbls of 9.4 ppg mud, displaced cmt at 7 bpm, initial circ pressure 400 psi, max pressure 850 psi, slowed rate to 4 bpm and bumped plug on calc displacement, pressured up to 1,350 psi, checked floats and held, CIP @ 03:15 hrs, had full returns during job and had 100 bbls of 10.7 ppg cmt back to surface, reciprocated csg till 02:00 hrs with approx 60 bbls of lead cmt around shoe 03:30 - 04:15 0.75 CASE DEQT SURFAC Tested 133/8" csg to 3,000 psi for 30 min, good test 04:15 - 05:30 1.25 CEMEN RURD SURFAC RD cement head and LD landing jt, cleared rig floor 05:30 - 10:00 4.50 WELCT NUND SURFAC ND 21 1/4" 2M divertor and lines, set out same 10:00 - 12:00 2.00 WELCT NUND SURFAC NU & Orient Vetco Gray MB 222 Wellhead, Tested seals to 5,000 psi for 10 min. 12:00 - 15:00 3.00 WELCT NUND SURFAC NU 135/8" 5M BOP stack 15:00 - 19:00 4.00 WELCT BOPE SURFAC RU and tested BOPE, tested rams, valves and choke manifold to 250 psi low and 5,000 psi high, tested annular to 250 psi and 3,500 psi, lower IBOP failed to test, NOTE: Lou Grimaldi W/AOGCC waived witnessing of test 19:00 - 21 :30 2.50 RIGMNT RGRP SURFAC Changed out lower IBOP on top drive and tested to 250 psi and 5,000 psi and tested ok 21 :30 - 22:00 0.50 WELCT OTHR SURFAC RD test equipment and installed wear bushing 22:00 - 00:00 2.00 DRILL PULD SURFAC Began MU 12 1/4" BHA #2 with AutoTrak and initialized same 8/6/2004 00:00 - 01 :00 1.00 DRILL TRIP SURFAC Fin MU 12 1/4" BHA #2 and RIH with HWDP to 1,055', surface tested Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/612004 00:00 - 01 :00 1.00 DRILL TRIP SURFAC MWD/Autotrak 01 :00 - 01 :30 0.50 RIGMNT RSRV SURFAC Serviced top drive and blocks 01 :30 - 03:15 1.75 DRILL TRIP SURFAC MU ghost reamer and RIH, PU 5" DP from pipe shed to 2,546' 03:15 - 04:15 1.00 DRILL DEaT SURFAC Shallow tested Autotrak downlink 04:15 - 05:30 1.25 DRILL TRIP SURFAC Cont RIH PU 5" DP from pipe shed to 3,746', washed down and tagged plugs above float collar at 3,753', had +1- 10' of soft cement on top of plugs 05:30 - 07:30 2.00 CEMEN DSHO SURFAC Drilled out cement plugs, float collar at 3,756', shoe jt and float shoe at 3,795', cleaned out to 3,802' then drilled 20' of new formation to 3,822' MD/2,314'TVD, 5-25K wob, 90 rpm's 700 gpm at 2,150 psi 07:30 - 08:45 1.25 DRILL CIRC SURFAC Circ hole clean and conditioned mud with 9.3 ppg MW in & out 08:45 - 09:15 0.50 DRILL LOT SURFAC RU and performed LOT to 13.4 ppg EMW, 492 psi, 9.3 ppg MW at 2,306' TVD 09:15 - 21:30 12.25 DRILL DRLG INTRM1 Drilled 12 1/4" hole WIAutotrak from 3,822' to 5,151' MD/2,773' TVD, (1,329') ADT 7.2 hrs, 10-25K wob, 120-150 rpm's 155 spm, 657 gpm, off btm pressure 1,900 psi, on btm 1,950 psi, off btm torque 9.5K ft-Ibs, on btm 11 K ft-Ibs, rot wt 99K, up wt 132K, dn wt 74K, 9.2 ppg MW, ... NOTE····Drilled hydrates section from shoe to 4,500', max gas 2,210 units, below 4,500' BGG ave 250-300 units 21 :30 - 22:45 1.25 DRILL CIRC INTRM1 Circ hole at a reduced rate evaluating Autotrak tool, unable to get desired tum rate from tool, decision made to POOH and PU mud motor, downlinked tool for ribs off on Autotrak 22:45 - 00:00 1.25 DRILL TRIP INTRM1 Pumped out of hole from 5,151' to 4,236', pumped out at 339 gpm at 600 psi, backreamed thru tight spot at 4,456' - 4,385' 8m2004 00:00 - 00:30 0.50 DRILL TRIP INTRM1 Fin pumping out of hole from 4,236' to 3,750', (inside csg shoe) 339 gpm at 600 psi with no problems 00:30 - 01 :15 0.75 DRILL CIRC INTRM1 Circ btms up from 3,750' and clean at shakers, circ at 613 gpm at 1,725 psi 01:15-01:30 0.25 DRILL OBSV INTRM1 Monitored well-static, pumped dry job 01 :30 - 02:45 1.25 DRILL TRIP INTRM1 POOH to BHA at 1,060' 02:45 - 03:00 0.25 DRILL OBSV INTRM1 Monitored well at BHA-static 03:00 - 05:15 2.25 DRILL PULD INTRM1 LD ghost reamer and POOH standing back HWDP and jars, LD stab and bit, downloaded MWD, found steering tool on AutoTrak had failed, found a seal leaking on one of the hatches on AutoTrak tool along with a 1 1/2" O-Ring found inside of bit, LD AutoTrak tool 05:15 - 08:45 3.50 DRILL PULD INTRM1 MU directional BHA #3, adjusted MM to 1.4 deg bend, MU short NMDC, MWD and programmed MWD, RIH with HWDP and jars to 1,100' 08:45 - 10:15 1.50 DRILL TRIP INTRM1 TIH with BHA #3 to 3,795' (csg shoe) 10:15 - 12:00 1.75 RIGMNT RSRV INTRM1 Slip and cut 58' of drlg line, serviced top drive, blocks and drawworks coupling 12:00 - 12:45 0.75 DRILL TRIP INTRM1 TIH from 3,795' to 5,002', 12:45 - 13:15 0.50 DRILL REAM INTRM1 Washed 149' to btm with no problems, took check shot survey at 5,095', circ at 420 gpm at 1,200 psi 13:15 - 22:45 9.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole per directional plan from 5,151' to 5,850' MDI 3,033' TVD (699') ART -0-, AST 5.4 hrs, 10-20K wob, -0- rpm's, 145 spm, 615 gpm, off btm pressure 1,900 psi, on btm 2,100 psi, off btm torque 10K ft-Ibs, rot WI 106K, up wt 141 K, dn wt 76K, 9.2 MW, ave bgg 100 units 22:45 - 00:00 1.25 DRILL TRIP INTRM1 Backreaming out of hole to 5,268' at drlg rate, 615 gpm at 2,100 psi, POOH to PU AutoTrak tool 8/8/2004 00:00 - 01 :45 1.75 DRILL TRIP INTRM1 Backreamed out of hole at drlg rate from 5,268' to 5,002', pumped out of hole from 5,002' to 3,795', (csg shoe) 615 gpm at 2,100 psi 01 :45 - 02:30 0.75 DRILL CIRC INTRM1 Circ btms up and till clean at shakers, circ at 615 gpm, 1,800 psi and 40 rpm's, CÎrc out large amount of sand, max gas 250 units and dropped Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-126 1 E-126 ROT - DRILLING n 1334@ ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/812004 01 :45 - 02:30 0.75 DRILL CIRC INTRM1 out to 50 units 02:30 - 02:45 0.25 DRILL OBSV INTRM1 Monitored well at shoe-static, pumped dry job 02:45 - 03:30 0.75 DRILL TRIP INTRM1 Began POOH from 3,609' to 3,516' had 25-30K overpull and well swabbing, had 7 bbl gain, ran back in hole to 3,700' 03:30 - 04:15 0.75 DRILL CIRC INTRM1 Circ 1 complete hole volume to circ out dry job and check gas at btms up, at btms had a max gas of 200 units and dropped right out to 50 units, circ at 615 gpm at 1,800 psi 04:15 - 06:00 1.75 DRILL TRIP INTRM1 Pumped out of hole 5 stds to 3,238' at 148 gpm at 300 psi with no problems, then pulled 3 stds wet and hole was taking calc fill, pumped dry job and POOH to BHA at 1,1 03' 06:00 - 08:45 2.75 DRILL PULD INTRM1 POOH standing back HWDP and jars, downloaded MWD and LD MWD, MPR and mud motor, cleared rig floor, BHA was clear, swabbing possibly due to sand inside csg 08:45 - 10:45 2.00 DRILL PULD INTRM1 MU 12 1/4" BHA #4 with AutoTrak tool, program AutoTrak and MWD, RIH with BHA #4 to 1,060' 10:45 -13:15 2.50 DRILL TRIP INTRM1 TIH with BHA #4 from 1,060' to 5,400', tested AutoTrak tool at 1,895', filled pipe at 3,752' and tagged tight spot at 5,400' 13:15 - 13:45 0.50 DRILL TRIP INTRM1 Washed thru tight spot from 5,400' to 5,414', PU and went thru spot with pumps off and had no problems, cont RIH to 5,795' 13:45 - 14:00 0.25 DRILL REAM INTRM1 Washed 55' to btm at 5,850', circ at 678 gpm at 1,750 psi, no problems washing to btm 14:00 - 20:30 6.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole with AutoTrak tool from 5,850' to 6,656' MD/3,303' TVD, (806') ADT 3.4 hrs, 5-25K wob, 120 rpm's, 720 gpm, off btm pressure 1,850 psi, on btm 1,900 psi, off btm torque 15K ft-Ibs, on btm 16K ft-Ibs, rot wt 109K, up wt 163K, dn wt 77K max gas at btms up from trip 80 units, ave BGG 50 units, max gas from Ugnu A, 325 units, screens blinding off, Top of Ugnu A @ 6,240' MD/3, 170' TVD 20:30 - 21 :30 1.00 DRILL OTHR INTRM1 Changed out shaker screens due to blinding off from Ugnu A 21 :30 - 00:00 2.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole with AutoTrak tool from 6,656' to 6,905' MD/3,366' TVD, (249') ADT 1.8 hrs, 5-25K wob, 120 rpm's, 720 gpm, off btm pressure 1,850 psi, on btm 1,900 psi, off btm torque 15K ft-Ibs, on btm 16K ft-Ibs, rot wt 109K, up wt 163K, dn wt 77K, ave BGG 75 units with 9.2 ppg MW 8/9/2004 00:00 - 11 :00 11.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole with AutoTrak tool from 6,905' to 8,094' MD/3,607' TVD (1,189') 95/8" Csg Pt., ADT 7.1 Hrs, 1 0-25K wob, 120 rpm's, 720 gpm, off btm pressure 2,000 psi, on btm 2,000 psi, off btm torque 18K ft-Ibs, on btm torque 20K ft-Ibs, rot wt 11 OK, up wt 190K, dn wt 70K. While drlg West Sak sands, BGG ave 200-400 units, max gas 1,200 units with 9.3+ MW, Pumped 30 bbl weighted hi-vis sweep prior to T.D. 11 :00 - 12:00 1.00 DRILL CIRC INTRM1 Circ out wt'd hi-vis sweep, had 20% increase in cuttings back from sweep, circ hole at 720 gpm at 2,000 psi and 120 rpms, BGG ave 250 units, down linked AutoTrak to Ribs Off 12:00 - 14:00 2.00 DRILL TRIP INTRM1 Monitored well-static, backreamed out of hole at drlg rate from 8,094' to 6,997', overlapping ghost reamer from point of last trip 14:00 - 18:30 4.50 DRILL TRIP INTRM1 Pumped out of hole from 6,997' to 3,752', (inside 133/8' csg) pumped out at 720 gpm at 1,800 psi 18:30 - 19:30 1.00 DRILL CIRC INTRM1 Pumped weighted hi-vis sweep and circ out of hole, had 10% increase in cuttings back from sweep, circ 1-add. btms up and was clean at shakers, circ hole at 720 gpm, 1,400 psi and 80 rpm's 19:30 - 19:45 0.25 DRILL OBSV INTRM1 Monitored well at shoe, well-static 19:45 - 21:00 1.25 DRILL TRIP INTRM1 POOH wet 5 stds and hole took calc fill, pumped dry job and POOH to BHA at 1,060' 21 :00 - 00:00 3.00 DRILL PULD INTRM1 Monitored well at BHA-static, LD ghost reamer, POOH standing back Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: HWDP and Jars, downloaded MWD and LD BHA #4 with AutoTrak, cleared rig floor, calc fill on trip out 44 bbls, actual fill 52 bbls Pulled wear bushing, installed test plug, changed out upper set of VBR's to 9 5/8" csg rams, tested same to 250/3,000 psi, RD test jt and pulled test plug RU Doyons 9 5/8" csg equipment with Franks fill up tool Held PJSM on running 9 5/8" csg with rig crew and tong operator MU 9 5/8" Float shoe, 2 jts csg, float collar, thread locked btm 3 conn's and circ thru float equip and ch ok, RIH with 93 add. jts along with pup jts for spacing out to 3,725', ran 65 tandem bowspring centralizers on 52 stop rings per well plan (avg MU - 8,000 ft-Ib) 1.00 CASE CIRC INTRM1 Circ a 9 5/8" csg cap at 13 3/8" shoe, staged pump rate up to 6.5 bpm at 350 psi, st wt up 140K, dn wt 87K, 6.25 CASE RUNC INTRM1 Cont RIH with 9 5/8" csg, worked thru tight spot at 5,738', RIH to btm, MU hanger and landed 9 5/8" csg at 8,088' MD/3,605' TVD with float collar at 8,010', ran a total of 207 jts 9 5/8", 40#, L-80 BTC-M csg with 3-pup jts and hanger (Total 8,061') 1.75 CEMEN CIRC INTRM1 Circ btms up with fill up tool, circ and cond mud, staged pump rate up to 6 bpm at 400 psi, reciprocated csg with 285K up wt, 80K down wt, max gas while circ 178 units 0.50 CEMEN RURD INTRM1 RD Franks fill up tool and MU cement head 1.75 CEMEN CIRC INTRM1 Fin circ and condo mud for cementing, circ at 6 bpm at 400 psi, reciprocated pipe with 305K up wt and 75K down, conditioned mud to 9.2 ppg MW, 42 vis, 13 PV, 16 VP, Held PJSM with Dowell, APC vac truck drivers and rig crew while circ and conditioning mud 1.50 CEMEN PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped 30 add. bbls (40 total) of CW 100, pumped 57 bbls of MudPush at 10.5 ppg, dropped btm plug then pumped 290 bbls, (726 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6 bpm at 275 psi, reciprocated pipe with full returns, shut down and dropped btm plug 1.50 CEMEN DISP INTRM1 Dowell pumped 3 bbls FW and turned over to rig and rig displaced cement with 9.1 ppg OBM, bumped plug after pumping 605.5 bbls OBM (95% pump eft.) (Calc Disp 607.75 bbls) ave 7 bpm while displacing cmt, max pressure 1,050 psi, slowed pump rate to 4 bpm with 15 bbls left to pump and bumped plug to 1,600 psi, ck floats and held CIP at 23:55 hrs, reciprocated pipe 1800 strokes into displacement when hole began getting tight and stopped reciprocating, had full returns throughout job, est TOC @ 4,170' Tested 95/8" csg to 3,000 psi for 30 min, good test RD cement head and 9 5/8" csg equipment, LD landing jt. Installed 9 5/8" pack-off, energized seals and tested both seals and pack-off to 250 I 5,000 psi for 10 min each RU on 133/8" x 9 5/8" annulus, pressured up to 800 psi and was able to pumped 2.5 bbls into annulus (9.3 ppg mud in annulus) Installed test plug, changed out upper set of pipe rams FI 9 5/8" to 3 1/2" x 6" VBR's, tested same to 250/5,000 psi, pulled test plug and installed wear bushing Serviced top drive and blocks MU 8 1/2" BHA #5 W/Autotrak tool and programmed MWD tool, RIH with 3- flex Dc's, 2 stds of 5" HWDP and jars to 330' TIH with BHA #5, PU 21 jts of 5" DP from pipe shed, MU ghost reamer and cont TIH PU add 104 jts of DP, TIH to 4,703' 8/10/2004 00:00 - 02:00 INTRM1 02:00 - 03:30 1.50 CASE RURD INTRM1 03:30 - 03:45 0.25 CASE SFTV INTRM1 03:45 - 09:45 6.00 CASE RUNC INTRM1 09:45 - 10:45 10:45 - 17:00 17:00 - 18:45 18:45-19:15 19:15 - 21 :00 21 :00 - 22:30 22:30 - 00:00 8/11/2004 00:00 - 01:15 1.25 CASE DEQT INTRM1 01:15-02:45 1.50 CASE RURD INTRM1 02:45 - 04:15 1.50 WELCT EQRP INTRM1 04:15 - 05:15 1.00 DRILL INTRM1 05:15 - 07:30 2.25 WELCT INTRM1 07:30 - 08:00 0.50 RIGMNT RSRV INTRM1 08:00 - 10:30 2.50 DRILL PULD INTRM1 10:30 - 15:00 4.50 DRILL PULD INTRM1 Printed: 9/10/2004 9: 19:43 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-126 1E-126 ROT - DRilLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/11/2004 15:00 - 17:00 2.00 DRILL TRIP INTRM1 TIH from 4,703' to 7,860' with DP fl derrick 17:00 - 18:45 1.75 CEMEN DSHO INTRM1 RIH and tagged cement at 8,000', (top of fIt Collar @ 8,010'), drilled out plugs and float collar at 8,010', firm cement in shoe jts and float shoe at 8,088', cleaned out to TD at 8,094', drilled at 5-15K wob, 100 rpm's, 509 gpm at 2,500 psi, rot wt 104K up wt 137K, dn wt 82K 18:45 - 19:30 0.75 DRILL DRLG INTRM1 Drilled 20' of new hole from 8,094' to 8,114' MD/3,610' TVD for LOT, ADT .7 hrs 19:30 - 20:15 0.75 DRILL CIRC INTRM1 Circ btms up evening MW in and out at 9.1 ppg OBM, circ at 600 gpm at 3,000 psi 20:15 - 21:15 1.00 DRILL LOT INTRM1 RU and performed LOT to 14.4 ppg EMW, 1,000 psi, at 3,605' TVD with 9.1 ppg OBM mud 21:15 - 23:00 1.75 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 8,114' to 8,228' MD/3,624' TVD, (114') ADT.7 hrs, 5-18K wob, 120 rpm's, 140 spm, 600 gpm, off btm pressure 3,000 psi, on btm 3,050 psi, off btm torque 8K ft-Ibs, on btm 9K ft-Ibs, 9.1 ppg OBM, rot wt 105K, up wt 140K, dn wt 79K 23:00 - 00:00 1.00 DRILL CIRC PROD Circ btms up and performed PWD baseline, with 9.1 ppg mud at 600 gpm and 120 rpms, clean hole ECD = 10.47 ppg 8/12/2004 00:00 - 09:30 9.50 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 8,228' to 9,156' MD/3,604' TVD, (928') ADT 5.2 hrs, 5-25K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,600 psi, on btm 3,675 psi, off btm torque 10.5K ft-Ibs, on btm 1 0.5K ft-Ibs, 9.1 ppg OBM, rot wt 104K, up wt 157K, dn wt 67K, ave BGG 350 units, max gas 725 units. Elbow on #2 mud pump pulsation dampner washed out 09:30 - 20:15 10.75 RIGMNT RGRP PROD Changed out #2 mud pump pulsation dampner, backreamed slowly out of hole from 9,156' to 8,045' (csg Shoe) while working on mud pump, backreamed out at 80 rpm's, 339 gpm at 1,190 psi, changed out pulsation dampner and mud cross 90, found bladder to be bad and changed out also, tightened drive belts on on #2 pump, pressure tested pump to 3,500 psi and checked ok. TIH from 8,048' to 9156' with no problems 20:15 - 00:00 3.75 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 9,156' to 9,518' MD/3,584' TVD, (362') ADT 1.9 hrs, 5-20K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,650 psi, on btm 3,675 psi, off btm torque 12K ft-Ibs, on btm 11 K ft-Ibs, 9.1 ppg OBM, rot wt 100K, up wt 161 K, dn wt 63K, ave BGG 250 units, max gas 675 units 8/13/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 9,518' to 10,641' MD/3,585' TVD, (1123') ADT 6.3 hrs, 5-25K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,800 psi, on btm 3,810 psi, off btm torque 15K ft-Ibs, on btm 13K ft-Ibs, rot wt 101 K, up wt 173K, dn wt 63K, ave BGG 250-350 units, max gas 850 units, 9.0+ OBM, aye ECD 10.9 ppg NOTE: at 11 :45 a spill at the injection skid occured, 25 bbls of OBM was caught inside containment under the injection skid with 3-4 gals going onto the ground 12:00 - 00:00 12.00 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 10,641' to 11,848' MD/3,547' TVD, (1207') ADT 7.0 hrs, 5-20K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,850 psi, on btm 3,890 psi, off btm torque 14K ft-Ibs, on btm 15K ft-Ibs, rot wt 97K, up wt 175K, dn wt 45K, ave BGG 200-350 units, max gas 2000 units, 9.0+ OBM, ave ECD 11.0 ppg, max ECD 11.2 ppg 8/14/2004 00:00 - 06:45 6.75 DRILL DRLG PROD Drilled 8 1/2" hole from 11,848' to 12,394' (763') ADT 3.0 hrs 06:45 - 08:45 2.00 RIGMNT RGRP PROD Repaired top drive service loop, circ hole at a reduced rate and worked pipe slowly 08:45 - 10:30 1.75 DRILL DRLG PROD Drilled 81/2" hole with AutoTrak from 12,394' to 12,611' MD/3,573' Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/14/2004 1.75 DRILL DRLG PROD 08:45 - 10:30 10:30 - 11 :45 1.25 DRILL CIRC PROD 11:45 -12:00 0.25 DRILL OBSV PROD 12:00 - 20:30 8.50 DRILL REAM PROD 20:30 - 21 :45 1.25 DRILL CIRC PROD 21 :45 - 22:00 0.25 DRILL OBSV PROD 22:00 - 00:00 2.00 DRILL TRIP PROD 8/15/2004 00:00 - 02:30 2.50 DRILL TRIP PROD 02:30 - 05:00 2.50 DRILL TRIP PROD 05:00 - 06:00 1.00 DRILL PULD PROD 06:00 - 06:30 0.50 CASE RURD CMPL TN 06:30 - 06:45 0.25 CASE SFTV CMPL TN 06:45 - 11 :30 4.75 CASE PULR CMPL TN 11 :30 - 12:45 1.25 CASE OTHR CMPL TN 12:45 - 13:00 0.25 CASE CIRC CMPL TN 13:00-15:15 2.25 CASE RUNL CMPL TN 15:15 - 16:00 0.75 CASE CIRC CMPL TN 16:00 - 19:15 3.25 CASE RUNL CMPL TN 19:15 - 20:30 1.25 CASE OTHR CMPL TN TVD, T.D. (546') ADT 1.3 hrs, 10-20K wob, 120 rpm's, 150 spm, 635 gpm, off btm pressure 4,050 psi, on btm 4,100 psi, off btm torque 15K ft-Ibs, on btm 14K ft-Ibs, rot wt 112K, up wt 190K, dn wt 61 K, ave BGG 250-350 units, max gas 1100 units, 9.0 OBM, ave ECD 11.2 ppg, max ECD 11.35 ppg, PU 8 stds of HWDP to TD well, pumped 30 bbl weighted hi vis sweep while drlg last std down Fin circ out wt'd hi vis sweep, had 10% increase in cuttings back from sweep, circ at 635 gpm, 4,050 psi at 120 rpm's, took survey on btm and slow pump rates Monitored well-static Backreamed out of hole from 12,611' to 8,041', inside 9 5/8" csg. Washed and reamed thru tight spot at 11,680', backreamed out at 120 rpm's, 135 spm, 572 gpm, initial circ pressure 3,425 psi, final circ pressure 2,700 psi, no other problems backreaming out Pumped 30 bbl weighted hi vis sweep and circ hole clean, had no increase in cuttings back from sweep, circ a total of 2X btms up, circ hole clean at 572 gpm, 2,700 psi at 80 rpm's, rot wt 96K, up wt 138K, dn wt 75K, off btm torque 9K ft-Ibs Monitored well at shoe-static, dropped 1 7/8" rabbit on wire and pumped dry job POOH with BHA #5 to 6,560', while POOH, installed 17 Lo-Tads onto DP (1/std) POOH 23 stds from 6,560' to 4,424' with BHA #5, MU 23 add. Lo-tads (40 total) POOH from 4,424' to 50', stood back HWDP and BHA to AutoTrak tool Downloaded MWD and stood back AutoTrak tool RU Doyon's 5 1/2" liner running equipment Held PJSM with rig crew and tong operator on running liner PU and ran 5 1/2" liner per well program, ran 5 1/2" ROT silver bullet guide shoe with no float, 159 jts, 5,139.10' of 5 1/2" 15.5#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 69 jts (2,369') of blank liner and 90 jts (2,768') of slotted liner, ran 1- 5 1/2" x 8 1/4" spiralglide centralizers 1/jt to shoe (137 total) then ran 12 restrictor packers with 24 spacer rings placed on blank liner to isolate shale sections per geology. MU Baker 190-47 csg seal bore ext, 7" x 9 5/8" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,204' Est circ at 1.5 bpm at 30 psi, st wt up 85K, dn wt 64K, est rotation at 10 rpm's with 3K ft-Ibs torque and 70K rotating wt RIH with liner on 5" DP to 8,001' Circ 2 DP volumes at 9 5/8" csg shoe, circ at 2 bpm at 200 psi, st wt up 122K, dn wt 80K, rotated at 10 rpm's with 7K ft-Ibs torque and 95K rotating wt RIH with liner in open hole from 8,001' to TD at 12,611' with no problems, tagged btm and PU liner 4' to liner setting depth, 12,607' Dropped 29/32" ball and pumped down to seat, staged up pump rate to 4 bpm at 575 psi, slowed to 3 bpm at 400 psi, with ball on seat pressured up to 2,500 psi to set hanger, then pressure up to 3,500 psi to set packer, cont to set packer by PU and releasing dogs then setting 50K string wt down, then rotated at 10 rpms and set 80K down w/rotating, packer set with no problems, set lower lateral liner with TOL @ 7,413' and shoe at 12,607', st wt up after setting liner 11 OK Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/15/2004 20:30 - 20:45 0.25 CASE DEOT CMPL TN Tested ZXP liner top packer to 1,000 psi for 5 min, good test 20:45 - 21 :45 1.00 CASE CIRC CMPL TN Circ hole with reconditioned 9.0 ppg OBM, circ at 339 gpm at 900 psi 21 :45 - 22:30 0.75 DRILL TRIP CMPL TN Monitored well-static, pumped dry job and began POOH from 7,413', POOH to 6,184' when chain on drawworks broke 22:30 - 00:00 1.50 RIGMNT RGRP CMPL TN Began changing out chain on drawworks 8/16/2004 00:00 - 02:15 2.25 RIGMNT RGRP CMPL TN Finished changing out chain on drawworks 02:15 - 05:00 2.75 DRILL TRIP CMPL TN POOH from 6,184' to 20' to liner running tool 05:00 - 05:30 0.50 DRILL PULD CMPL TN Made service breaks and LD running tool 05:30 - 09:00 3.50 WINDO ULD CMPL TN PU Whipstock and mills to rig floor, MU Baker seal assembly, 2 jts of 5" DP for space out and 9 5/8" Baker btm trip whipstock, milling assembly with LWD/MWD, uploaded MWD and oriented BHA #6 09:00 - 13:00 4.00 WINDO CMPL TN TIH with whipstock assembly BHA #6, RIH with 9 stds HWDP and slick DP to 6,705', shallow tested MWD at 2,345' and ck ok 13:00 - 13:45 0,75 WINDO CMPL TN Est Circ and made MAD pass to correlate DP to K-13 sand, Logged down from 6,705' to 6,742' (GR Depth 6,645' to 6,682') corrected MWD 2.5' to put on depth, circ at 510 gpm at 1,975 psi, st WI 142K, dn WI 81K 13:45 - 14:15 0.50 WINDO CMPL TN TlH from 6,742' to 7,358' 14:15 - 14:45 0.50 WINDO CMPL TN Oriented whipstock and RIH, tagged top of liner at 7,413', set btm trip anchor and whipstock at (0 deg) high side, set top of whipstock at 7,305', worked 45K WI down and sheared bolt, no problems shearing bolt, str. WI up after setting whipstock 142K and 81 K dn 14:45 - 18:00 Milled window in 9 5/8" csg, top of window at 7,305', btm of window at 7,321', drilled 8 1/2" hole to 7,343' MD/3,474' TVD (38'), 2-6K wob, 60-100 rpm's, 510 gpm, 1,800 psi, rot WI 100K, up WI 142K, dn WI 81K, torque off btm 7K ft-Ibs, on btm 9-13K ft-Ibs 18:00 - 19:00 1.00 WINDO CIRC CMPL TN Pumped hi vis sweep and circ hole clean while working mills thru window, had no increase in cuttings back from sweep, circ at 510 gpm at 1,800 psi, ran mills thru window without any problems 19:00 - 19:15 0.25 WINDO RIP CMPL TN Monitored well-static, pumped dry job and POOH from 7,343' to 7,151' 19:15 - 20:30 1.25 RIGMNT RSRV CMPL TN Slip and cut 123' of drlg line, serviced top drive and drawworks 20:30 - 22:30 2.00 WINDO RIP CMPL TN POOH from 7,151' to HWDP at 936' 22:30 - 00:00 1.50 WINDO ULD CMPL TN POOH to 110', LD 27 jts 5" HWDP and bumper sub, Note: HWDP to be sent in for inspection, and replacement HWDP is on location 8/17/2004 00:00 - 01 :00 1.00 WINDO CMPL TN Rack back MWD in Derrick, Lay down Milling assembly, Jars & HWDP. 01 :00 - 09:45 8.75 WELCT PROD2 Pull wear bushing, Wash out stack, Rig & test BOPE to 250 psi low & 5000 psi high, Hydril to 250 low & 3500 psi high, Test witnessed by AOGCC Jeff Jones, Install wear bushing. 09:45 -11:15 1.50 DRILL PULD PROD2 Pick up 29 jts. HWDP, Jars & stand back in derrick. 11:15-15:30 4.25 DRILL PULD PROD2 Pick up Bit, Motor, MWD tools, Orient & Program same, RIH wI HWDP, Jars, Drill pipe & Ghost reamer, Surface test tools. 15:30 - 18:30 3.00 DRILL TRIP PROD2 RIH to 7,206', Orient & slide thru window @ 7,305' with no problems, Ream down to 7,343' w/ 510 gpm @ 2775 psi. 18:30 - 00:00 5.50 DRILL DRLH PROD2 Drill 8-1/2" hole f/7,343' to 7,943' MD/3,465' TVD (600') ART = 2.4 hrs, AST = 1.4 hrs, WOB 5/20K, 80/100 RPM, 550 gpm @ 2800 psi, UP 155K, DN 104K, ROT 73K, BGG 275 units, Ave. ECD's 10.1 ppg wI 9.2 ppg mud. 8/18/2004 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole fl7,943' to 9,093' MD/3,446' TVD (1150') ART= 4.7 hrs, AST = 2.5 hrs, WOB 5/25K, 100 RPM, 550 gpm @ 2750 psi, UP 153K, DN 76K, ROT 105K, TO on btm 10/15K off 11/12K ftIlb, Ave. BGG 400 units, Max gas 1302 units, Ave. ECD's 10.3 ppg w/9.1 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole f/9,093' to 10,060' MD/3,442' TVD (967') ART = 6.0 hrs, AST = 2.2 hrs, WOB 5/25K, 90/110 RPM, 550 gpm @ 2800 psi, UP Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/18/2004 12:00 - 00:00 12.00 DRILL DRLH PROD2 160K, DN 70K, ROT 105K, TO on btm 10/11 K off 12K ftIlb, Ave. BGG 450 units, Max gas 1022 units, Ave. ECD's 10.4 ppg wI 9.0 ppg mud. 8/19/2004 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole f/1 0,060' to 11,197' MDI 3,427' TVD (1,137') ART = 5.2 hrs, AST= 2.0 hrs, WOB 5/20K, 120 RPM, 550 gpm @ 2950 psi, UP 164K, DN 63K, ROT 100K, TO on btm 12/13K off 13/14K ftIlb, Ave. BGG 450 units, Max gas 912 units, Ave. ECD's 10.6 ppg wI 9.0 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole f/11,197' to 12,215' MD/3,405' TVD (1,018') ART= 5.2 hrs, AST= 2.1 hrs, WOB 5/25K, 120 RPM, 550 gpm @ 3200 psi, UP 170K, DN 65K, ROT 108K, TO on btm 15K off 14/15K ftIlb, Ave. BGG 410 units, Max gas 795 units, Ave. ECD's 10.8 ppg w/9.0 ppg mud. Note; Last 24 hours, having extreme difficulty keeping sand content down below 2% due to fine sand. 8/20/2004 00:00 - 02:30 2.50 DRILL DRLH PROD2 Drill 8-1/2" hole f/12,215' to 12,468' MD/3,394' TVD (253') ART= 1.7 hrs, AST = 0.2 hrs, WOB 5/25K, 120 RPM, 550 gpm @ 3300 psi, UP 176K, DN 74K, ROT 115K, TO on btm 14K I off 14K ftIlb, Ave. BGG 410 units, Max gas 738 units, Ave. ECD's 10.9 ppg w/9.0 ppg mud, Pumped Hi-vis weighted sweep on last connection. 02:30 - 03:30 1.00 DRILL CIRC PROD2 Circ out sweep- had 10% increase in cuttings, Survey, Monitor well. 03:30 - 10:30 7.00 DRILL TRIP PROD2 Back ream out of hole to 7,200' at drilling rate, No problems - hole in good shape. 10:30 - 12:00 1.50 DRILL CIRC PROD2 Pump Hi-vis sweep & circ hole clean w/3 times btm's up. 12:00 - 13:30 1.50 DRILL TRIP PROD2 Monitor well, Dry pipe, POOH 11 stands to 6,177' (Hole not taking proper fill). 13:30 - 14:30 1.00 DRILL TRIP PROD2 RIH to 7,200', Circ btm's up. 14:30 - 17:30 3.00 DRILL TRIP PROD2 Pump out of hole f/7,200' to 3,800' due to hole not taking proper fill. 17:30 - 20:30 3.00 DRILL TRIP PROD2 Monitor well, POOH on elevators to MWD. 20:30 - 22:00 1.50 DRILL PULD PROD2 Down load MWD tools, Lay down BHA. 22:00 - 00:00 2.00 DRILL TRIP CMPL TN Make up Fixed Lug whipstock retrieving tools, RIH w/ HWDP. 8/21/2004 00:00 - 03:15 3.25 CMPL TN TRIP CMPL TN Continue RIH to 7,260', Break circ wI 253 bpm @ 600 psi, Record weights- UP 136K, DN 86K, Hook whipstock on third attempt @ 7,312', Pull up to 175K & bleed open Jars, Pull on up to 225K and whipstock released, Pull up to 7,260', Observed indicator weight of 142K. 03:15 - 04:00 0.75 CMPLTN CIRC CMPL TN Circ btm's up at rate of 630 gpm @ 2750 psi, Monitor well - Static, Drop rabbit. 04:00 - 09:30 5.50 CMPL TN TRIP CMPL TN Pull 2 stands and observe well for swabbing- OK, Pump dry job, POOH, Lay down whipstock tools to whipstock- No recovery of whipstock, Fixed lug retrieving tool showed damage to upper part of lug where whipstock slipped off. 09:30 - 10:30 1.00 CMPL TN PULD CMPL TN Make up whipstock retrieving BHA #2. 10:30 - 11 :30 1.00 RIGMNT RSRV CMPL TN Service rig, Drawworks, Top drive. 11 :30 - 15:00 3.50 CMPL TN TRIP CMPL TN Make up New Fixed lug retrieving tool, RIH to 7,260', Break circ wI 253 bpm @ 600 psi, Record weights- UP 136K, DN 86K, Hook whipstock @ 7,312', Pull up to 175K & bleed open Jars, Pull on up to 225K and whipstock released, Pull up to 7,260', Observed indicator weight of 142K. 15:00 - 15:30 0.50 CMPL TN TRIP CMPL TN Circ btm's up at rate of 510 gpm @ 1800 psi, Monitor well - Static. 15:30 - 21:30 6.00 CMPL TN TRIP CMPL TN Pull 10 stands and observe well for swabbing- OK, Pump dry job, POOH, Lay down whipstock tools to whipstock- Recovered whipstock. 21 :30 - 23:00 1.50 CMPL TN PULD CMPL TN Lay down whipstock assembly and clear floor. 23:00 - 00:00 1.00 CASE RURD CMPL TN Rig to run 5-1/2" liner. 8/22/2004 00:00 - 04:00 4.00 CASE PUTB CMPL TN Pick up Total of 152 joints 5-1/2",15.5#, L-80, DWC Slotted liner w/4 jts blank w/2 Swell packers, Ran 150, 5-1/2"x 8-1/4" Centralizers Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/22/2004 00:00 - 04:00 4.00 CASE PUTB CMPL TN sliding on every jt., Btm joint blank and bent. 04:00 - 04:30 0.50 CASE PUTB CMPL TN Pick Baker 7"x 9-5/8" B-1 Hook Hanger for LEM. 04:30 - 12:00 7.50 CASE RUNL CMPL TN RIH w/liner, Work liner thru window @ 7,305' to 7,321' (Made thru on 2nd attempt), Continue to RIH to btm UP 170K, DN 88K, Hook liner in window @ 7,324.5' (3.5' low)- Rehook liner to comfirm, TOL @ 7,302.51' wI Shoe @ 12,455.80'. 12:00 - 13:00 1.00 CASE CIRC CMPL TN Drop ball, Circ down at rate of 5 bpm @ 800 psi, Release liner, Shear out ball wI 4800 psi, Circ btm's up. 13:00 - 16:00 3.00 CMPL TN TRIP CMPL TN Observe well, Dry pipe, POOH, Lay down Baker liner running tools. 16:00 - 18:00 2.00 CMPL TN RURD CMPL TN Clear floor, Rig & make up LEM assembly. 18:00 - 21 :30 3.50 CMPL TN TRIP CMPL TN RIH wI LEM assembly to 7,300', RIH slow & Latch LEM in Hook hanger @ 7,302' wI ZXP liner top packer @ 7,245', Check for proper set w/10K over pull- OK. 21 :30 - 00:00 2.50 CMPL TN CIRC CMPL TN Drop ball, Circ down at rate of 5 bpm @ 800 psi, Set ZXP Packer, Release fl running tool & Neutralizer push tool wI 3800 psi, Pressure test annulus & ZXP packer wI 1500 psi f/5 min- OK, Rig & shear out ball wI 5100 psi, Circ btm's up, Observe well, Dry pipe. 8/23/2004 00:00 - 03:30 3.50 CMPL TN TRIP CMPL TN POOH & Lay down LEM running tools. 03:30 - 05:00 1.50 WINDO ULD CMPL TN Make up Whipstock & Milling assembly, Orient tools wI MWD tools. 05:00 - 09:30 4.50 WINDO RIP CMPL TN RIH wI Whipstock to 6,724'. 09:30 - 10:00 0.50 WINDO CIRC CMPL TN Circ & Madd pass f/6,724' to 6,758'. 10:00 - 11 :30 1.50 WINDO SETW CMPL TN RIH to 7,220', Orient whipstock to 15 deg. Left, Tag top of ZXP packer @ 7,249' (3.5' low), Set Anchor, Shear off whipstock bolt w/ top of whipstock @ 7,305'. 11:30 - 15:30 4.00 WINDO CMPL TN Mill window f/7,105' to 7,143', (Window f/7, 105' to 7,121'). 15:30 - 16:00 0.50 WINDO CMPL TN Pump Hi-vis sweep, Circ hole clean. 16:00 - 20:00 4.00 WINDO CMPL TN Observe well, Dry pipe, POOH & Lay down Mill assembly. 20:00 - 21 :00 1.00 WELCT PROD3 Rig & wash metal from stack. 21 :00 - 22:30 1.50 DRILL PROD3 Make up 8-1/2" BHA #8, Orient & Program same. 22:30 - 00:00 1.50 DRILL PROD3 RIH wI BHA to 1,850' 8/24/2004 00:00 - 02:00 2.00 DRILL TRIP PROD3 RIH w/8-1/2" BHA #10 to 7,021' 02:00 - 03:30 1.50 RIGMNT RSRV PROD3 Cut & slip drilling line, Service rig. 03:30 - 04:15 0.75 DRILL TRIP PROD3 Break circ, Orient & slide thru window @ 7,105' to 7,121' (Window in good shape- No obstructions), Ream out of guage hole f/7, 126' to 7,143'. 04:15 - 12:00 7.75 DRILL DRLH PROD3 Drill 8-1/2" hole f/7,143' to 7,870' MD/3,407' TVD (727') ART = 2.3 hrs, AST= 2.7 hrs, WOB 2/15K, 120 RPM, 550 gpm @ 2850 psi, UP 146K, DN 70K, ROT 100K, TQ on btm 10K I off 10K ftllb, Ave. BGG 300 units, v" Max gas 388 units, Ave. ECD's 10.4 ppg wI 9.0 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8·1/2" hole f/7,870' to 8,970' MD/3,407' TVD (1,100') ART = 601 hrs, AST= 2.2 hrs, WOB 2/1 OK, 120 RPM, 550 gpm @ 2800 psi, UP 155K, DN 70K, ROT 100K, TQ on btm 12K / off 13K ftllb, Ave. BGG 300 units, Max gas 1230 units, Ave. ECD's 10.4 ppg wI 9.0 ppg mud. 8/25/2004 00:00 - 12:00 12.00 DRILL DRLH PROD3 Drill 8-1/2' hole f/8,970' to 9,805' MD/3,408' TVD (835') ART = 7.0 hrs, AST = 1.9 hrs, WOB 2/10K, 120 RPM, 550 gpm @ 2900 psi, UP 160K, DN 63K, ROT 102K, TQ on btm 12/13K I off 13/14K ftllb, Ave. BGG 250 units, Max gas 500 units, Ave. ECD's 10.5 ppg wI 9.0 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/9,805' to 10,895' MD/3,402' TVD (1,090') ART= 4.1 hrs, AST= 3.1 hrs, WOB 2/5K, 120 RPM, 550 gpm @ 3000 psi, UP 180K, DN 65K, ROT 105K, TQ on btm 15K I off 15K ftllb, Ave. BGG 520 units, Max gas 700 units, Ave. ECD's 10.6 ppg wI 9.0 ppg mud. 8/26/2004 00:00 - 06:30 6.50 DRILL DRLH PROD3 Drill 8-1/2" hole f/1 0,895' to 11,469' ART = 1.8 hrs, AST = 1.6 hrs, WOB 5/10K, 120 RPM, 550 gpm @ 3350 psi, UP 195K, DN 60K, ROT 116K, Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/26/2004 00:00 - 06:30 6.50 DRILL DRLH PROD3 TQ on btm 16K I off 17K ftIIb, Ave. BGG 500 units, Max gas 580 units, Ave. ECD's 10.8 ppg wI 9.0 ppg mud. Running out of weight to slide with. 06:30 - 07:45 1.25 DRILL TRIP PROD3 Monitor well, Backream out of hole to 11,101', Pick up 12 jts. HWDP. 07:45 - 17:00 9.25 DRILL DRLH PROD3 Drill 8-1/2" hole f/11 ,469' to 12,115' ART:= 3.6 hrs, AST:= 1.8 hrs, WOB 5/1 OK, 120 RPM, 550 gpm @ 3400 psi, UP 207K, DN 55K, ROT 133K, TQ on btm 17K I off 18K ftIlb, Ave. BGG 400 units, Max gas 580 units, 01 Ave. ECD's 10.8 ppg wI 9.0 ppg mud. Running out of weight to slide with. 17:00 - 18:00 1.00 DRILL TRIP PROD3 Monitor well, Backream out of hole to 11,654', Pick up 15 jts. HWDP. 18:00 - 23:00 5.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/12, 115' to TD 12,457' MD I 3,382' TVD ART:= 2.3 hrs, AST:= 0.3 hrs, WOB 2/5K, 120 RPM, 550 gpm @ 3400 psi, UP 225K, DN 65K, ROT 126K, TQ on btm 18K / off 18K ftIlb, Ave. BGG 400 units, Max gas 648 units, Ave. ECD's 10.9 ppg wI 9.0 ppg mud, Pump Hi-vis weighted sweep on last connection. 23:00 - 00:00 1,00 DRILL CIRC PROD3 Circ Hi-vis sweep out of hole - 10% increase in cuttings. 8/27/2004 00:00 - 07:00 7.00 DRILL TRIP PROD3 Survey, Monitor well- Static, Back ream out of hole at drilling rate 550 gpm @ 3400 to 2500 psi, 120 RPM, Pulling at rate of 40/45 ftImin., No tight spots - Hole in very good shape. 07:00 - 08:30 1.50 DRILL CIRC PROD3 Pump Hi-vis weighted sweep, Circ hole clean wI 550 gpm @ 2500 psi, while rotating and reciprocating pipe, Monitor well. 08:30 - 13:00 4.50 DRILL TRIP PROD3 POOH to BHA. 13:00 - 14:00 1.00 DRILL PULD PROD3 Lay down NMDC's, Down load & lay down MWD/LWD, Lay down Motor & Bit. 14:00 - 20:30 6.50 DRILL CMPL TN Lay down 60 stands 5" drill pipe from derrick in mouse hole. 20:30 - 00:00 3.50 WINDO CMPL TN Make up Whipstock retrieving tools, RIH to 6,200'. 8/28/2004 00:00 - 00: 15 0.25 WINDO CMPL TN Continue RIH w/ Whipstock retrieving tools to 7,111'. 00:15 - 00:45 0.50 WINDO CMPL TN Break circ, Work & latch onto Whipstock, Jar same loose w/ 90K overpull, Pull whipstock up to 7,068' (Whipstock dragging 10K over) 00:45 - 01 :30 0.75 WINDO CMPL TN Circ btm's up at rate of 320 gpm @ 800 psi, Observe well- OK. 01 :30 - 06:15 4.75 WINDO CMPL TN POOH slow due to mild swabbing and hole not taking proper fill, Work pipe up & down in order to make well take proper fill, Hole began taking proper fill after 15 stands, Dry pipe & continue to POOH to BHA slow wI whipstock. 06:15 - 09:45 3.50 WINDO ULD CMPL TN Stand back HWDP, Lay down whipstock retrieving tools and whipstock tools, Clear & clean floor. 09:45 - 15:30 5.75 CASE PULR CMPL TN Rig & run Baker 5-1/2" Guide shoe, 1 Bent Blank jt. 5-1/2",15.5#, L-80, DWC liner, 129 jts. Slotted 5-1/2",15.5#, L-80, DWC liner, Pick up Baker 7" x 9-5/8" Model B-1 Hook Hanger for LEM, Rig down casing tongs, Clean floor. 15:30 - 20:00 4.50 CASE RUNL CMPL TN RIH wI liner, Work liner thru window @ 7,105' to 7,121' (Took 3 attempts), Continue RIH wI liner with no restrictions until the last 25', Work liner to btm- OK. 20:00 - 20:30 0.50 CASE RUNL CMPL TN Run Hook Hanger down and Hooked window on first attempt @ 7,123', Turn Hook & run past window 7'- OK, Turn Hook & rehook window at a final depth (A definite solid hook- Checked 3 times) of 7,124.73', Top of liner @ 7,103.65', Shoe @ 12,435.24'. 20:30 - 22:00 1.50 CASE CIRC CMPL TN Drop & circ down ball on seat at rate of 5 bpm @ 800 psi, Release from liner hanger wI 3800 psi, Set back 1 stand HWDP, Rig & shear out ball wI 5300 psi using BOP test pump, Circ btm's up at rate of 510 gpm @ 1800 psi. 22:00 - 22:45 0.75 CMPLTN TRIP CMPL TN Monitor well, Dry pipe, POOH w/6 stands HWDP, (Broke Hi gear chain in drawworks). Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/28/2004 8/29/2004 8/30/2004 Replace Hi gear chain in drawworks. Continue Replacing Hi gear chain in drawworks. POOH, Lay down Baker liner running tools, Clean rig floor. Rig & RIH w/17 stands HWDP, 7 stands drill pipe, Lay down 17 stands HWDP & 1 stand drill pipe- Pipe skate chain broke. Repair pipe skate chain. Finish laying down drill pipe. Rig & Pick up 192jts. 4-1/2", 12.6#, L-80,IBTTubing. Circ hole clean at rate of 425 gpm @ 1200 psi, Reciprocate pipe while CÎrc. Monitor well, Pump dry job, POOH & stand back tubing in derrick. Rig & Lay down remaining 5" drill pipe and Lo-Tad's from derrick in mouse hole. Finish laying down remaining 5" drill pipe and Lo-Tad's from derrick in mouse hole. Pull wear bushing, Rig to run 4-1/2" ESP Completion, Held PJSM with all personnel. Make up Motor centralizer to motor, Pump guage, Motor, Seal section, XJO, Screen Intake, Fill motor wI oil, Test & Clamp ESP wire, RIH installing clamps every other jt, Test ESP wire every 10 stands. Make up Vetco Gray hanger UP 85K, DN 60K, Install penetrator, Cut wire & splice same to penetrator. Cont to splice ESP wire and test same, landed tbg at 6,155' MD, RILDS, LD landing jt and tested upper and lower hanger seals to 5,000 psi for 15 min, ck ok, installed TWC ND BOP's NU Vetco Gray tree and adapter, tested adapter void to 5,000 psi for 15 min, ck ok, tested tree to 250 psi low and 5,000 psi high for 5 min each and tested ok, pulled TWC, check ESP penetrator continuity and checked ok 3.50 CMPL TN FRZP CMPL TN RU and displaced out 9.0 ppg OBM to diesel, pumped 460 bbls diesel down 9 5/8" x 4 1/2" annulus at 6,093', initial CÎrc pressure 450 psi at 3 bpm, final circ pressure 875 psi at 3 bpm (thru willis choke) 1.00 WELCT EQRP CMPL TN RU lubricator and installed BPV 2.00 CMPL TN OTHR CMPL TN Secured well, finished cleaning out mud pits, RD scaffolding around well and cleaned out cellar RELEASED RIG @ 12:00 hrs, 8/31/04 22:45 - 00:00 1.25 RIGMNT RGRP CMPL TN 00:00 - 01 :00 1.00 RIGMNT RGRP CMPL TN 01 :00 - 04:15 3.25 CMPL TN TRIP CMPL TN 04:15 - 06:30 2.25 CMPL TN TRIP CMPL TN 06:30 - 07:30 1.00 RIGMNT RGRP CMPLTN 07:30 - 08:00 0.50 CMPL TN TRIP CMPL TN 08:00 - 15:30 7.50 CMPL TN TRIP CMPL TN 15:30 - 16:30 1.00 CMPLTN CIRC CMPL TN 16:30 - 20:30 4.00 CMPL TN TRIP CMPL TN 20:30 - 00:00 3.50 CMPL TN PULD CMPL TN 00:00 - 03:45 3.75 CMPL TN PULD CMPL TN 03:45 - 07:30 3.75 CMPLTN RURD CMPL TN 07:30 - 21 :30 14.00 CMPLTN RUNT CMPL TN 21 :30 - 00:00 2.50 CMPL TN RURD CMPL TN 8/31/2004 00:00 - 02:30 2.50 CMPL TN RUNT CMPL TN 02:30 - 03:30 1.00 WELCT NUND CMPL TN 03:30 - 05:30 2.00 WELCT NUND CMPLTN 05:30 - 09:00 09:00 - 10:00 10:09 - 12'00 Printed: 9/10/2004 9:19:43 AM -. ../ ConocoPhillips ConocoPhillips Alaslnc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY LING Page 1 Wellbore: 126L2 Well path: MWD wI Sag <7336 - 12457'> Date Printed: 16-Sep-2004 J&i. BAKER HUGHES INTEQ 1~l1bØr'!1 126L2 I creat~ 25-Au -2004 I Last R~vised 29-Au -2004 [Vi"1 ~ I ~~~~~~~\I~OO-OO I ~~~u~~;~~ Installation 550528.194 True Pad 1 E I=:~lm' I Easti ~87754 6208 North· 1~~8985 8206 I~~= INOOIJ<Y."- I - - -- R .",CAN D.l1JM 1927 -Dl Tru, All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8734.13 Feet on azimuth 152.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~ D ~( - f ~e-r Conoc;p.,illips ConocoPhillips Alastnc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . SURVEY LISTING Page 2 Wellbore: 126L2 Wellpath: MWD w/Sag <7336 - 12457'> Date Printed: 16-Sep-2004 "~i. BAKER HUGHES INTEQ WellDath (Grid) ReDort MD[ft] Inc(deg] Azi[deg] TVD[ft] Station Station Dogleg 8everit) Vertical Easting Northing Position(Y) Posi!iön(X) Sectionrftl 710!> 00 74 RQ 1R? O!> :u 17 OR ">A". ">"" n 00 ?O?!> 'I? !>'i4'1R? 1 R n~f)~5 QO 4f) 1R1 Q7 :U4f)4Q f)7'1 ??!>~ M <;~ ~7<; f;7 ~.. 7433.81 94.45 182.91 3442.31 2797.14S 4464.54E 4.21 2350.85 554372.17 5957672.29 7!>?Q ?4 Q40!> 1R? M :U'l!> ?4 o !>1 ?44!> QO <;~ ~f;R ?n 7f)2fì24 Q258 1R2?R :U?Q f)~ .~~ ..n~ 1 !>f) ?'i425Q <;~'IR4 f;0 A" 7723.12 93.68 181.75 3424.34 3085.628 4452.38E 1.26 2639.14 554361.93 5957383.77 781Q 70 Q? 7f) 1 R'I M :U1R Q? ~1A1 a~c:: ?17 ?7'1!> 44 <;~ ~<;R n~ A'> 791528 91~8 1R~.f)9 :U1!>.4f) 'I?77.?!>~ 4441.74F 1.44 ?R~0.90 5'i4~52 .5f) 8011.70 89.45 183.55 3414.77 3373.47S 4435.65E 2.01 2927.26 554347.11 5957095.84 810R f)8 RQ.n 1R<l1f) :u 1!> RR 44?Q QRF 04fi <l0?41f) <;~<tð.? nR 820445 8997 18419 :u 1f)!>!> 1.~? ~119.88 <;~'I'Ifi<;R 41 8301.55 91.75 183.52 3415.09 3662.71S 4417.31E 1.96 3216.92 554330.69 5956806.51 8~984~ 9?02 1R14R :U11.Q1 ~7!>Q 44~ IA.'> "o~ ?1? ~~n.f)O 5'i4~27. 11 5956709 76 8493.96 91.87 179.00 M08.f)f) '>D". 01 C' 2BO M08.6f) 554327.35 5956614.30 8591.47 89.88 178.04 3407.18 3952.378 4415.20E 2.27 3505.41 554330.51 5956516.87 8f)8870 91 R1 17f) f)7 :UO!> 74 .n on .n~ ?4<1 <If)01B'I <;~~~<; R4 8784.40 90.~7 17f).04 MO~9? A1A. 07C' .~~ ....~ 1M ~f)96.07 <;<;4'\4? 'Ifi """"""> '>7 8881.54 88.16 175.13 3405.17 4241.808 4433.25E 2.46 3791.73 554350.48 5956227.60 89780~ 91~2 17757 M05f)1 414 ~88f).95 554~57 .26 <;o<;fi1 'Ii 'IR 9075.60 91.56 17f).29 MO~.15 4444 fi1 F 1.~~ 3983.38 ""A~f;~ 1~ """"0" ,,"> 9171.47 89.39 179.32 3402.36 4531.25S 4448.29E 3.89 4078.35 554367.43 5955938.28 92f)806 9000 17R8~ MO?R7 ..~ n~~ 0.81 4174.~2 <;<;4'1fiO fi'l 5955841.73 o<lfi!> fiO 89.08 180.62 MO~.f)f) 2.0f) 4271.35 ""A ~7n 7<; 9458.40 87.64 181.79 3406.31 4818.10S 4448.36E 2.00 4363.84 554369.41 5955651.47 9550.28 9018 1R'I.f)O MOROf) 4444 O4F ~~Q 445557 <;~'Ifi<; 7() 70 9642.68 90.00 184.7~ M0791 44~7.~~E 1.24 4547.94 <;"A~<;a e;1 9736.11 90.98 185.52 3407.11 5095.05S 4428.99E 1.35 4641.37 554351.88 5955374.42 982844 90.40 184.M MOf)OO 44?10!>F 14? 47~~.f)8 554344.56 A" 9921.16 90.15 18~.67 M05.5f) 4414.58E 0.77 4826.37 554338.70 10013.67 90.52 183.03 3405.02 5371.878 4409.17E 0.80 4918.80 554333.90 5955097.50 1010f).87 9107 18415 '\40::1 7? "A". ODC' 1M 5011.94 <;~'I?A fiO """",,,,, A" 101007R 89.23 182.61 MO~.48 2.58 5104.77 ""A~?~ A~ !>Q'i4Q11 70 10291.39 91,38 183.40 3402.99 5649.10S 4393.06E 2.50 5196.28 554319.63 5954820.20 10'lA<; fiO 89.51 18~.47 M02.2f) 4~R7 41F 1.98 5290.51 ""A~1A e;1 1M7A ~<; Qn 1R 1R<l17 :UO? !> 1 o 7Q !>'IR<I 1 0 <;~ ~na $If; ~n 10569.92 88.47 183.09 3403.59 5927.15S 4377.04E 1.87 5474.58 554305.47 5954542.08 10f)fi? 17 RQ'i4 1 R'I '\4 3405.19 A~71 $17<:: 1.19 !>!>fifi7<1 <;<;A ~nn Q() 1075541 90 R9 1R<l7!> :U04 84 1 !>1 5f)!>Q91 <;~?O" 7fi nn 10845.52 90.86 184.18 3403.47 6202.18S 4359.88E 0.48 5749.98 554290.13 5954266.97 1na~f; 00 QO 4f) 1Rfi ?O 3402.41 4351.60E 2.25 5841.4<1 !>'i4?R? 4f) 59'i417584 110~OB~ 91?9 1R79<1 '\400 QR f;~Rf; 1Re:: 4'\40 OQF ? O!> 59~!>0~ 5'i4271.56 0" 11121.23 91.29 189.16 3398.94 6475.758 4326.63E 1.36 6025.48 554258.70 5953993.21 11?141Q QO 4<1 1QO f)Q <1<197 !>!> 6567.30S 4310.61E 1.89 f)11R if) !>'i4?4~?9 <;a"~on1 <;f; 11~Ofì40 905R 1 Q1 7~ 'I'I9f).7<1 4?M f)RF 114 f)209.92 <;~??" 07 5953811.01 11398.79 91.32 193.80 3395.20 6747.84S 4272.27E 2.38 6301.56 554206.16 5953720.80 114RQ 00 Q? 15 19fi ?!> <I<IQ? 47 "0" "'>,, 4248.90E ? R7 f)'IQO.4Q !>'i41 8~.~7 ".. 1158102 9245 194 f)f) <I<IR8 7R A">">, A"~ 17f) M81.07 5'i4159.46 0" 11673.99 92.67 196.33 3384.63 7013.03S 4199.59E 1.81 6572.55 554135.24 5953455.15 117f)702 91Q~ 1Q!> 71 <I<IRO RQ 104 f)f)f)~97 5'i4110.19 fi<; 11860.58 92.~9 19484 ~~77~f) 1.05 675f).12 554086.16 'Ii 11952.61 91.41 193.95 3374.31 7281.668 4126.44E 1.44 6847.01 554063.88 5953186.07 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8734.13 Feet on azimuth 152.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc;p.,illips ConocoPhillips Alaslnc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY LtJG Page 3 Wellbore: 126L2 Wellpath: MWD w/Sag <7336 - 12457'> Date Printed: 16-Sep-2004 "~i. BAKER HUGHES INTEQ Well MD[ft] Dogleg Seve' Easting Northing 5952920.35 5952699.18 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8734.13 Feet on azimuth 152.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated .. '. .... Conoc;p.,illips ConocoPhillips Ala~nc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY LING Page 4 Wellbore: 126L2 Wellpath: MWD w/Sag <7336 - 12457'> Date Printed: 16-Sep-2004 '&íí. BAKER HUGHES INTEQ 677.815 Hole Sections Start MDft Wellbore Casin s Name All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8734.13 Feet on azimuth 152.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Bookl.xls - j?7 f) ~6>+'- /.2 Y Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 7/22/20043:24 PM · 4fTL) ¿)O~-lc2ý Total Depth __ 1E-126 TVD /~.~ CO/:- ~ /ß-/tJ,6~~ Ckv~ Effective MD Effective TVD ~~ J!SPL ?M-tJ.y Casing Length Size Cement Volume MD TVD Conductor 80' 20"X34" 260 cf Surface 3858' 13 3/8" 730 sx ASLite,200 sx Deepcrete 3886' 2300' Intermediate 8093' 9 5/8" 710 sx DeepCrete 8121' 3617' Production N/A N/A N/A N/A N/A Liner 4454' 51/2" Slotted Liner 12575' 3571' ç ,~\~\\ .,." ,~~ ¡(,. ~-- . (ffi~ ~~ . @ f1f( æJ U\:1 FRANK H. MURKOWSKI, GOVERNOR AI4ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-126L2 ConocoPhillips Alaska, Inc. Permit No: 204-124 Surface Location: 4428' FNL, 631' FEL, SEC. 16, TIIN, RlOE, UM Bottomhole Location: 1636' FNL, 1961' FEL, SEe. 27, TIIN, RI0E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new well bore segment of existing well KRU lE-126, Permit No. 204-122, API 50-029-23215-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t tness any required test. Contact the Commission's petroleum field inspector at (907) 659. 6 ager). 81 BY ORDER OF )ìHE COMMISSION DATED thismay of July, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. 1a. Type of Work: Drill 0 Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . ~ /-Jr1 (( ð- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL RedrillU 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 4428' FNL, 631' FEL, Sec. 16, T11N, R10E, UM Top of Productive Horizon: 1603' FNL, 1424' FEL, Sec. 22, T11N, R1OE, UM Total Depth: 1636' FNL, 1961' FEL, Sec. 27, T11N, R1OE, UM / Surface: x- 549890 4b. Location of Well (State Base Plane Coordinates): / y- 5960439 / Zone- 16. Deviated wells: Kickoff depth: 7054' ft. 18. Casing Program Size Hole Casing 42" 20"x34" 16" 13-3/8 " 12.25" 9-5/8 " 8.5" 5.5" 19 Total Depth MD (It): /øZ ~O ¿ALJ Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee Property Plat / / Maximum Hole Angle: 94° Specifications Weight Grade Coupling Length 94# K-55 Welded 80' 68# L-80 BTC 3858' 40# L-80 BTCM 8093' 15.5# L-80 DWC 5380' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature \ PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) 3$7/ ØA.- Length Size ..J :-J )!J BOP SketchD D Diverter Sketch D . it jL f2 <01 )nntl ExploratoryU Development Oil 0 Multiple Zone D Service D Develppm8J:It9~sD Single Zone 0 5. Bond: ~ Blanket TI Single Well 11.,Well Name and Number: Bond No. 59-52-180 1E-126L2 6, Proposed Depth: 12. Field/Pool(s): ./ .I MD: 12434' TVD: 3335' Kuparuk River Field 20 AAC 25.005 7. Property Designati~n: / ADL 25651 & 25660 8. Land Use Permit: West Sak Pool 13. Approximate Spud Date: 8/18/2004 ALK 469 & 470 9. Acres in Property: 2560 14. Distance to Nearest Property: 8924' 10. KB Elevation 15. Distance to Nearest 4 Well within Pool: 1E-112, 953' @ 7054' (Height above GL): 28 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1536 psig Surface: 1154 psig ./ Setting Depth Quantify of Cement Bottom c. f. or sacks TVD (including stage data) 108' 260 cf ArcticCrete 2300' 730 sx AS Lite, 200 sx DeepCrete 3617' 710 sx DeepCrete 3335' slotted liner Top MD 28' 28' 28' 7054' TVD 28' 28' 28' 3418' MD 108' 3886' 8121' 12434' (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) /;25$S'"lrrJ,.v 357L/ð~ CemenfVolume MD rvD Perforation Depth TVD (ft): Drilling Program 0 Seabed Report D Time v. Depth Plot D Drilling Fluid Program 0 Date: Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 ~ Randy Thomas "'\~ J Commission Use Only API Number: Permit Approval 50-Ó2-q-z32/~-~ I Date: 7/;éJ-/tJI Conditions of approval: Samples required DYes M No Mud log required -. D Ves fa No ~y ,gen sulfide measures 0 Ves ~ No Directional survey required B Ves q No Other: "3>7J1t. -' If' ""'" '?,O ? ~~ "".w ~\ ~'Nc.. \ .",,\ ~r\""''' \1-\ ~> 0 ",t>i~> "'./ .- BY ORDER OF lA / /AJ / I.. V Approved byt ; V\" " 1"\ I _ I .. t & i THE COMMISSION Date: ¥1/7"f Or u t\ J lJll\lAL Number: Permit to Drill 2D l./ -- j'¿ê.f v...,.- Form 10-401 Revised 12/2003 Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone "2..bl b3>o Date ?!j(O, Prpn"f .,... ron Al/suD-Drake See cover letter for other requirements I I Submit in Duplicate · APP1ie for Permit to Drill, We1l1E-126 L2 Revision No.O July 3, 2004 Permit It - West Sak Well #1 E-126 L2("D" Sand} Application for Permit to Drill Document MQxir'nizE Well Vgll,J~ Table of Contents 1. Well Name..................................................................................................................... 2 Requirements of 20 AAC 25.005 (f) ..... ........ ...... ...... ........ ....... ..... ........ ............ .............. ...... ....... ........ 2 2. Location Su m mary ....................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) .... ....... ....... ..... .......... ............. ....... ...... ............ ........... ........ ...... 2 Requirements of 20 AAC 25.050(b) ... .... ...... ......... ............. ...... ...... ....... ............ ........ ....... ..... ....... ....... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(c)(3) . .............. ...... ............... ............ ....... ...... ...... ....... ..... ........ ......... 3 4. Dri II i ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ...............................................................................................3 5. Procedure for Conducting Formation Integrity Tests .............................................3 Requirements of 20 AAC 25.005 (c)(5) ..... ....... ....... ......... ...... ...... ...... ....... ....... ..... ........ ..... ........ ...... ... 3 6. Casing and Cementing Program................................................................................4 Requirements of 20 AAC 25. 005(c)(6) ................................................................................................ 4 7. Diverter System Information ......................................................................................4 Requirements of 20 AAC 25.005(c)(7) ..... ........ ....... ....... ........ ..... ...... ....... ....... ....... ........... ...... ......... ... 4 8. Dri II i ng Flu i d Prog ram................................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ......... ....... ...... ........ ....... ..... ................... ....... ....... ...... ........ ....... 5 Lateral Mud Program (MI FloPro NT) ......... ........ ...... ........ ............ ........ ....... ..... ........ ..... ............... ....... 5 9. Abnormally Pressured Formation Information ........................................................ 5 Requirements of 20 AAC 25.005 (c)(9) ...............................................................................................5 1 o. Seism ic Analysis.......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ............................................................................................. 5 11. Seabed Condition Analysis ........................................... ............................................. 5 Requirements of 20 AAC 25.005 (c)(11) ............................................................................................. 5 12. Evidence of Bon ding ................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ............................................................................................. 6 f~'Gl~1AL L2 PERMIT IT (Producer) RevO.doc Page 1 of? Printed: July 3, 2004 · APP'. for Permit to Drill, Well 1 E-126 L2 Revision No.O July 3, 2004 13. Proposed Dri Iling Program .........................................................................................6 Requirements of 20 AAC 25.005 (c)(13) .............................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6 Requirements of 20 AAC 25.005 (c)(14) ............................................................................................. 6 15. Attach ments.................................................................................................................. 7 Attachment 1 Directional Plan.. ...... ...... ...... ........ ...... ....... ....... ..... ....... ....... ...... ...... ....... ...... ..... ............ 7 Attachment 2 Dril/íng Hazards Summary...... ... ..... ..... ....... ............. .............. ..... ....... ....... ...... ....... ........ 7 Attachment 3 Well Schematic.... ........ .... ...... ........ ...... ........ ....... ..... ....... ....... ..... ....... ...... ..... ......... ...... 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branche~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1E-126 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (2) a plat identitying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUlvey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface I ASP Zone 4 NAD 27 Coordinates Northings: 5,960,439 Eastings: 549,890 FNL:4428', FEL:631', Sec 16, Tl1NfRlOE, UM ¡/ I RKB Elevation I 94.3' AMSL I Pad Elevation I 66.3' AMSL Location at Top of Productive Interval West Sak "D" Sand ASP Zone 4 NAD 27 Coordinates Northings: 5,958,015 Eastings: 554,398 FNL:1603', FEL:1424', Sec22, Tl1NfRlOE, UM V' Measured De. th, RKB: Total Vertical De. th, RKB: Total Vertical De. th, 55: 7054' 3418' 3323.7' Location at Total Depth I FNL:1636', FEL:1961' See 27,Tl1NfRlOE, UM ./ ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12434' v Northings: 5,952,699 Eastings: 553,908 Total Vertical Depth, RKB: 3335' v Total Vertical Depth, 55: 3240.7' and (D) other information required by 20 MC 25.050(b); J(JI~J.AL L2 PERMIT IT (Producer) RevO.doc Page 2 ofl Printed: July 3, 2004 · APPI. for Permit to Drill, Well 1 E-126 L2 Revision No.O July 3, 2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent well bores within 200 feet of any portion of the proposed well,' Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail," or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-126 L2. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1E-126 L2 area vary from 0.0.42 to 0.0.45 :/ psi/ft, or 8.1 to 8.6 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1154.46 psi, calculated thusly: MPSP =(3470 ft)(0.0.45 - 0.11 psi/ft) ./ =1154.46 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25. 030(f); The parent wellbore,lE-126, will be completed with 95/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance f~ I hi ~JAL I.i \, n \.J~ lJ ~'1 L2 PERMIT IT (Producer) RevO.doc Page 3 of 7 Printed: July 3, 2004 · APPle for Permit to Drill, Well 1 E-126 L2 Revision No.O July 3, 2004 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.03~ and a description of any slotted liner, pre- perforated liner, or screen to be installed/ ) ~ _.~--~/' 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2}/ Casing and Cementing Program See also Attachment 3, APO for 1E-126: Cement Summar, Hole Top Btm Csgífbg Size Weight Length MOífVO MOífVO 00 (in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 X 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE 13 3/8 16 68 L-80 BTC 3858 28 / 28 3886 /2300 Cemented to Surface with 730 sx ASLite Lead, 200 sx OeepCRETE Tail 9 5/8 12 1/4 40 L-80 BTCM 8093 28 / 28 8121/3617 Cement Top planned @ 4266' MO / 2440' TVO. Cemented w/ 710 sx OeepCRETE 51/2 8 1/2" "A" 15.5 L-80 OWC 4454 8121/3617 12575/3571 Slotted- no slotted Lateral (lE- cement 126) 51/2 81/2" 15.5 L-80 OWC 5138 7300/3475 12438/3401 Slotted- no slotted "B" Lateral cement .--.....--'J ( lFI26 Ll) , , '. 51/2 81/2 15.5 L-80 OWC 5380 7054/3418 12434/3335 Slotted-no slotted "0" Lateral cement 1E-126 L2) No diverter system will be utilized during operations on 1E-126 L2 F\ I ~ I t\! A L t~tlJl!~.j L2 PERMIT IT (Producer) RevO.doc Page 40f7 Printed: July 3, 2004 · APPlie for Permit to Drill, We1l1E-126 L2 Revision No.O July 3, 2004 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c){8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25. 033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Value Density (ppg) 9-9.2 Funnel 30 Viscosity (seconds) Yield Point 18-28 (cP) Electric Stability 650-900 Chlorides (mg/I) 40000 pH N/A API filtrate <4 (cc / 30 min) **HTHP filtrate <10 (cc /30 min) MBT (Ib / gal) <5 ./ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c){10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test we/~ a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vesse~ an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. OR\Gt~Jt\L L2 PERMIT IT (Producer) RevO.doc Page 5 of 7 Printed: July 3, 2004 e APPen for Permit to Drill, Well 1 E-126 L2 Revision No.O July 3, 2004 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (12) evidence showing that the requirements of 20 AAC 25. 025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program for lE-126 L2 is listed below. Note: Previous operations are covered under the 1E-126 Application for Permit to Drill. 1. Run al)Æf'set Baker WindowMaster whipstock system, at window point of 7054' MD 3418' 1VD, the top of theY~nd.~?y\i\ '1 (\)~oy..\ 2. Mill 8 112" window. POOH. 3. Pick up 8 1/2" dri~ assembly with LWD and MWD and PWD. RIH. ./ 4. Drill to TD of ~i' sand lateral at 12434' MD / 3335' 1VD, as per directional plan. 5. POOH, back re~~~f{~~a?.100H. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 5 1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. Displace liner annulus and liner to 9-9.2 ppg weighted brine, POOH 10. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 11. Nipple down BOPE, nipple up tree and test. Pull BPV. 12. Set BPV and move rig off. 13. Freeze protect well with diesel by pumping into 4 1/2"" X 9 5/8" annulus, taking returns from tubing and allowing to equalize. 14. Rig up wire line unit. Pull BPV and install gas lift valves 15. Operate well on gas lift for +/- 180 days. 16. Replace gas lift valves with dummies. 17. Run ESP through tubing 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accomp¿mied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. 080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids / into a permitted annulus on 1E Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1E Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved ~ ,,,",, NP" ' !) ¡~ I \ I > %,' ' I :' t:~,;t_J íi! '~;;o::'!'!IIIifI L2 PERMIT IT (Producer) RevO.doc Page 6 of 7 Printed: July 3, 2004 · APPle, for Permit to Drill, Well 1 E-126 L2 Revision No.O July 3, 2004 disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic (l1~Jh ...,,< ;" ';. i. '\./...,t~ L2 PERMIT IT (Producer) RevO.doc Page 7 of 7 Printed: July 3, 2004 · . lE-126L2 Drilling Hazards Summarï (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 8 1/2" Open Hole / 5 1/2" Liner Interval Low Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole o ener, Decreased mud wei ht Reduced urn rates, Mud rheolo , LCM Trip speeds, Proper hole filling (use of trip sheets ,Pum in out Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Lost Circulation Hole Swabbing on Trips Moderate High O~UGINAL 1E-126 Drilling Hazards Summary prepared by Steve Shultz 5/27/2004 9:43 AM Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 92.56 92.56 92.56 92.56 92.56 92.56 92.56 92. 92.56 92,56 92.56 92,56 . . -.,' . . ConocóPhillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Well bore: 126L2 Well path: 126L2 Ver#4 Date Printed: 29-Jun-2004 ... ... INTEQ 126L2 487754.6208 5948985,8206 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185,57 degrees Bottom hole distance is 8722,22 Feet on azimuth 152.94 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated L . . ~llips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 126L2 Wellpath: 126L2 Ver#4 Date Printed: 29-Jun-2004 ... 'ilLs INTEQ I......... LL .....~. C..>L' . . ." > ... .'.'...., .... .'...'., .< ...., ....,...,.....'...,. ,.. , IMD[ftl/ . ,"" -..=, I Stati Of! Statio/J. /'" 9ogl~g y~rtical "C ...,'. ..'... .< .. 'T~'JJ ,.IVUlTtj ''''',,''''' .... t:;ä.::'lLJ'] ..' ',... > ...'... .,..,. ',.. < 'North) East\ ..'......... ótti'" tf .,.. ....' < ...... .... .,.,. ./ 7054.45 75.00 185.57 3418,00 3319.00 2454,58S 4492.6!'i.E 1-_5958015.00 554398.00 0,00 2007.17 Too Whiostock face. End of Hold. Tie or 7070.95 77.24 185.57 3421.96 3322.96 2470.528 4491.09E 5957999.05 554396.55 13.60 2023.19 Base Whiostock Face End of Build 7090.95 77.24 185.57 3426,37 3327,37 2489,93$ 4489.20E 5957979.63 554394.79 0.00 2042.69 End Milled Ooenhole KOP End of Hold 7190.95 83.24 185.57 344331 3344,31 2587.98S 447965E 5957881.53 554385.88 6.00 2141.20 7290,95 89,24 185.57 3449.86 3350.86 2687.258 4469.97E 5957782,21 554376.87 600 2240.94 7322,65 91,15 185.57 3449.75 3350.75 2718.80S 446_~ c--9_95775064 554374.00 6.00 2272.64 End of Build 7400.00 93.47 185.54 3446,64 3347.64 2795.71S 4459.41E 5957673.68 554367.04 3.00 2349.92 7422,66 94.15 185.53 3445.14 3346 13 2818.228 4457.23E 5957651,17 554365.00 3,00 2372.53 End of BuildlTurn 7500,00 94,15 185,53 3439.54 3340.54 2895.008 4449,79E 5957574,35 554358,08 000 2449,67 7600,00 94.15 185.53 3432.31 3333.31 2994.27S 4440.18E 5957475.02 554349,12 0.0.9~ ..2º4~t 41 7700.00 94.15 185,53 342508 3326,08 3093.54S 4430,56E 5957375.70 554340.16 0.00 2649.15 -- 7743,95 94,15 18553 3421.91 3322.91 3137.17S 4426.33E 595733204 554336.22 0.00 2692,98 3DJ Kick off Point 7800.00 92.46 185.53 3418.67 3319.67 3192,87S 4420,93E 5957276.32 554331.20 3.00 2748.94 7843,96 91,15 185.53 3417.29 3318.29 3236.608 4416.70E 5957232.57 554327.25 3.00 2792.87 End of DroolTurn 7900.00 91.15 185,53 3416.17 3317.17 3292.37S 4411.30E 5957176.77 554322.22 0,00 2848.90 8000,00 91.15 18553 3414.17 331517 3391.88S 4401.66E 5957077.20 554313.25 0.00 2948,88 8058.46 91.15 185.53 3413.00 3314,00 3450,06S 4396,03E 5957019.00 554308.00 0.00 3007.33 WS 1E D5 D-MDPT#1 RVSD060204, 3DJ Kick off Point 8100,00 90.97 184.30 3412.23 3313.23 3491.44S 4392.47E 5956977.60 554304.72 3.00 3048.86 8200.00 90.53 181.33 3410,93 3311,93 3591,30S 4387,56E 5956877.72 554300.47 3.00 3148.72 8300.00 90.10 178.36 3410.38 3311,3tL ~1.28S 4387,83E 59!i6777.75 554301.41 3.00 3248.21 8309.61 90,06 178,08 3410.36 3311.36 3700.898 4388.13E 5956768,14 554301,77 3,00 3257.74 End of DroplTurn 8400,00 90.06 178.08 3410,28 3311.27 3791.23S 4391.16E 5956677.84 554305.40 0.00 3347,36 8500.00 90.06 178.08 3410.18 3311,18 3891,178 4394.52E 5956577.93 554309.42 0.00 3446.51 8600,00 90,06 178,08 3410.08 3311.08 3991,128 4397.88E 5956478.02 554313.45 0,00 3545,66 8700,00 90,06 178.08 3409.98 3310.98 4091.068 4401.24E 5956378.11 554317.47 0.00 3644.80 -- 8800.00 90.06 178,08 3409.89 3310.88 4191.00S 4404.60E 5956278.20 554321.~ ~QO 3743.95 - 8900.00 90.06 178,08 3409.79 3310.79 4290.95S 4407.95E 5956178.29 554325.51 0.00 3843.09 9000.00 90.06 178.08 3409.69 3310.69 4390,898 4411,31E 5956078.38 554329.53 0.00 3942.24 9100,00 90,06 178,08 3409.59 3310.59 4490.838 4414.67E 5955978.47 554333,55 000 4041,39 9200,00 90,06 178,08 3409.49 3310.50 4590.78S 4418.03E 5955878.56 554337.57 000 4140.53 9300.00 90.06 178.08 3409.40 3310.40 4690,728 4421,39E 5955778.65 554341.59 O.,QQ_ ~98 9400,00 90,06 178.08 3409.30 3310.30 4790.67S 4424~Z4E ~5567874 554345,61 0.00 4338,83 9500,00 90.06 178.08 3409.20 3310.20 4890,618 4428,10E 5955578.83 554349.64 0.00 4437.97 9600.00 90.06 178.08 34!)..9.,ll 3310.11 4990.558 4431.46E 5955478.93 554353.66 0,00 4537.12 9700.00 90.06 178,08 340901 3310,01 5090.508 4434 82E 5955379.02 554357.68 0.00 4636.27 9708.02 90.06 178.08 3409.00 3310,00 5098,528 4435,09E 5955371.00 554358.00 0.00 4644.22 WS 1E D5 D-MDPT#2 RVSD050504, 3DJ Kick off Point 9800,00 90.35 180,82 3408.67 3309.67 5190.48S 4435.97E 5955279.05 554359.50 300 4735.66 9900.00 90.67 1!33.80 3407.78 3308,78 5290,38S 4431,94E 5955179.14 554356.13 3.00 4835.49 9931,68 90.77 184.75 3407.38 3308.38 5321978 4429.58E 5955147.54 554353.98 3.00 4867,15 End of BuildlTurn 10000,00 90.77 184.75 3406.45 3307.45 5390.05S 4423,93E 5955079.43 554348.78 0.00 4935.46 -- 10100.00 90.77 184,75 3405.10 3306.10 5489.708 4415,65E 5954979.74 554341.17 0,00 5035.44 10200,00 90,77 184.75 3403.75 3304.75 5589.35S 4407.38E 5954880.05 554333.55 0.00 5135.42 10300.00 90.77 184.75 3402.40 3303.40 5688,99S 4399,10E 5954780.35 554325.94 0.00 5235.40 ~Q.OO 90.77 184.75 3401.05 3302.05 5788.648 43g0,83E 5954680.66 55431833 0.00 533539 rÍo50000 90,77 184,75 3399.70 3300.70 5888.298 4382.55E 5954580.97 554310.72 0,00 5435Æ -" 10600.00 90.77 184,75 339834 3299 35 5987.948 4374.28E 5954481.28 554303.11 0,00 5535.35 10700.00 90.77 184.75 3396,99 3297,99 6087,58S 4366,OOE 5954381.59 554295.49 0,00 5635.33 10800.00 90.77 184.75 3395.64 3296.64 6187,238 4357,73E 59542.81.90 554287.88 0.00 5735.31 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O,OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8722.22 Feet on azimuth 152,94 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORlr>! ~k . I ·V" ~. ',./ l (, f t,) l l\L . . .,' . ConocoPhillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 3 Well bore: 126L2 Well path: 126L2 Ver#4 Date Printed: 29-Jun-2004 III. ... INTEQ ... .. , ...... '-".. '.,... ...,.. .,....~ '.'.'. ..,. » '>' ..'.. ,i ..'...'.. / ,..,.. > ". IMDfftl ~""'W"l¡ IVLi[TtJ Vertiçal Ea$t{ftl ¡station $tatiOI1.. DÓ()I~d vel'Qqar > - - , '..... ¡""....", . Ë~~K. .h#i~. t1 .. ..... . .....,. .,.. '. '. ....,'. > ,'.., 10900.00 90,77 184.75 3394.29 3295.29 6286,888 434945E 5954182.21 554280.27 0.00 5835.29 10995.51 90,77 184.75 3393,00 3294,00 6382,058 434155E 5954087.00 554273.00 0.00 5930,78 WS 1E D5 D-MDPT#3 RVSD050504, f----. .-- 3DJ Kiqk off Point 11000.00 90,79 184.88 3392,94 3293.94 6386.538 4341,18E 5954082.52 55427265 3.00 5935.27 11100.00 91.24 187,85 339116 3292.16 6485.88S 4330.09E 5953983.10 554262.23 3,00 6035,23 11200,00 91.68 190,82 3388.61 3289. 61 6584.528 4313.89E 5953884.37 554246,68 3,00 6134.97 ..- 11300.00 92.12 193,79 3385.29 3286.29 6682.16S 4292.60E 5953786.60 554226,04 3.00 6234.22 11400,00 92,55 196.76 3381.22 328222 6778,53S 4266.28E 5953690.06 554200.37 3.00 6332.69 11402.04 92.56 196.82 3381.13 3282.13 6780498 426569E 5953688.10 554199.80 3.00 6334.70 End of Buildrrurn 11500.00 92.56 196.82 3376,75 3277. 75 6874.168 4237.38E 5953594.25 554172.11 0,00 6430.67 11600.00 92.56 196.82 3372.28 3273.28 6969.79S 420848E 595349845 554143,85_ 0.00 6528,65 11700.00 92.56 196.82 3367,81 3268,81 706542S 417958E 5953402.64 554115.58 0,00 6626.63 11800.00 92.56 196.82 3363.35 3264,35 7161.058 4.1QMIÇ 5953306.8.~ _9540ß7.32 0.00 6724,62 11900.00 92.56 196,82 335888 3259,88 7256.67S 4121.77E 5953211.02 554059.05 0,00 6822.60 12000.00 92,56 196.82 335441 325541 7352.308 4092.87E 5953115.21 554030.79 0.00 6920.58 12100.00 92.56 196.82 3349.94 3250,94 744793S 4063.97E 595301941 554002.52 0.00 7018.56 12200,00 92,56 196,82 334547 324647 7543.56S 4035,06E 5952923,60 553974.26 0.00 7116.54 12300.00 92.56 196,82 3341.01 3242.01 7639.198 4006.16E 5952827.79 553945,99 0.00 7214,52 12400.00 92,56 196.82 3336.54 3237.54 7734.818 3977.26E 5952731.98 553917,73 0.00 7312.50 1243443 92,56 196.82 3335.00 3236,00 7767,73S 3967,31E 5952699,00 553908.00 0.00 7346.23 TD, 5 1/2in Liner All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185,57 degrees Bottom hole distance is 8722,22 Feet on azimuth 152.94 degrees from Wellhead Calculation method uses Minimum CUNature method Prepared by Baker Hughes Incorporated t'\. r·'\ ê ,"'." ~ i J. Ií 1:.. ,} ~ .. . 7 t~ (' í ("r ~ ,". ~ " ',""" \ 't ¡; ¡',J t I; . . ~llips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 4 Well bore: 126L2 Well path: 126L2 Ver#4 Date Printed: 29-Jun-2004 ..: INTEQ 300.00 300.00 O,OOE O,OON KOP 585.71 584.27 24.77E 2.17S BldfTrn 4/100 837.57 827.24 89,14E 11.58S BldfTrn 5/100 1916.89 1584.37 796.38E 179.95S EOC 4950.66 2686,54 3526.55E 9H49S Turn 4,5/100 579362 3004,49 4149.28E 1354.33S EOC 5906.07 3045.34 4208,12E 1441.02S Start 200' Pum Tan ent 6106.07 3118.00 4312.77E 1595.19S End 200' Pum Tan ent BldfTrn 4.5/100 6954.45 3392.12 4502.02E 2358.45S EOC 7054.45 3418.00 4492,65E 2454.58S TQQ WhipStock face 7070.95 3421,96 4491.09E 2470.52S Base Whi tock Face 7090.95 3426,37 4489,20E 2489,93S End Milled Openhole KOP ,- 12434.43 3335.00 3967.31E 7767.73S TD 5 112in Liner WS 1 E D5 5098.52S 4435.09E 3409.00 N70 17 19.5456 W149 33 35.9984 554358.00 5955371.00 D-MDPT#2 RVSD050504 WS 1 E D5 D TOE 7767,73S 3967,31 E 3335.00 N70 16 53.2966 W149 33 49.6690 553908.00 5952699.00 RVSD060704 --- WS 1 E D5 3450.06S 4396.03E 3413,00 N70 17 35,7583 W149 33 37.1084 554308,00 5957019.00 D-MDPT#1 RVSD060204 WS 1 E D5 6382.05S 4341.55E 3393.00 N70 17 6,9227 W149 33 38.7453 55427300 5954087.00 D-MDPT#3 RVSD050504 649014 Planned All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8722.22 Feet on azimuth 152.94 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . ~illips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 5 Wellbore: 126L2 Wellpath: 126L2 Ver#4 Date Printed: 29-Jun-2004 ... ~ INTEQ 647616 Planned All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O,OOE on azimuth 185.57 degrees Bottom hole distance is 8722.22 Feet on azimuth 152.94 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated R~ r ,! L 4Iaker Hughes Incorporatl Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 7054.45 to 12434.13 ft Maximum Radius: 5280,00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Wellpath Date: 1/12/2004 Validated: No Planned From To Survey ft ft 0.00 7054.26 Planned: 1E-126 Vers#4 V29 (0) 7054.26 12434.13 Planned: 1E-126L2 Vers#4 V17 Version: Toolcode Tool Name MWD+SAG MWD+SAG MWD + Sag correction MWD + Sag correction Summary Pad 1 E 105 105 A2-Lateral VO Plan 9707.74 11225.00 1246.80 404.55 842.24 Pass: Major Risk Pad 1 E 105 105 B-Lateral VO Plan: 9707.74 11200.00 1219.24 398.27 820.97 Pass: Major Risk Pad 1E 105 105 D-Lateral VO Plan: 9707.74 11200.00 1215.52 401.79 813.73 Pass: Major Risk Pad 1 E 112 1E-112L1 VO Plan: 1E-1 12431.73 10975.00 1067.06 478.56 588.50 Pass: Major Risk Pad 1 E 112 1E-112L2 VO Plan: 1E-1 12415.77 10950.00 1070.42 480.30 590.12 Pass: Major Risk Pad 1 E 168 168 A2-Lateral V3 Plan 7072.79 6300.00 422.23 209.73 212,51 Pass: Major Risk Pad 1 E 168 168 B-Lateral VO Plan: 7072.79 6300.00 422.23 209.73 212.51 Pass: Major Risk Pad 1E 168 168 D-Lateral VO Plan: 7072.79 6300.00 422.23 209.73 212.51 Pass: Major Risk Pad 1 E 22 1 E-22 VO 7622.06 6100.00 1126.36 175.97 950.39 Pass: Major Risk Pad 1J 1J-DU 1J-L3 A Lateral V1 Pia Out of range OR1G~NtAL --4 ^.~ cc¡,,,,·~~ \",\ C'1>c¡,~ ~ ~6\£i\'" lI.S'ò- ~ ~ec¡, -<"oç I I I ¢:: 0 <X> II E u Q) ïii u ~ (/) _ 3040 ..... G> ~ ~ 3200 ..... Q. G> C 3360 ñi tI 3520 ~ G> 3680 ~ ::s ... .... I ~ V 3840 .- .... ""--"'~--"" INTEQ ~ '1>~ >t--0<? c.~ '<.'<J.c.~ \O\e, >t--0<? ~~\~~\çc¡,'ßçe'" ð- ~'1>~~'t~e, -<" 0%'1>c¡,~ ~V:.\èò 'i-\o"?\~,df~çe~ ~ oç, ~c¡,è~*,e 92.46 oC ~~;:.<Q«..",Ò··..,m""'...'...".'.. ~e:~~"~~ C ~OC'1>~ ~Á~4· ' .<oç 'Õ c¡,\CJ \ ~e -<"oç A-3 1760 1920 2080 2240 2400 2560 2720 Scale 1 cm = 80 ft ¢:: 0 <X> II E u Q) ïii u (/) _ 3040 ..... G> . 3200 Õ. (1) C 3360 ñi ..90.3,5 CJ .90.33. :e 3520 ~ G> 3680 ::s ... .... I V 3840 4160 4320 4480 4640 4800 4960 5120 Scale 1 cm = 80 ft ConocoPhillips Alaska, Inc. Con~illips Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot#126 Well: 126 Well bore: 126 reate y ; anner Date plotted: 30-Jun-2004 lot reference Is 126, Ref well path is 126 Ver#4 ' Coordinates are in feet reference Siot #126, True Vertical Depths are reference Rig Datum, , Measured Depths are reference Rig Datum, I Rig Datum: Datum #1 Rig Datum to mean sea level: 99,OO ft. I Plot North is aligned to TRUE North, 126L2 126L 1 90,52 Bid 4/100 84,00 92,60 EOC 2880 3040 3200 3360 3520 3680 3840 4000 4160 4320 4480 4640 4800 4960 5120 5280 Vertical Section (feet) .> Azimuth 185.57 with reference 0.00 N, 0.00 E from Slot #126 TD, 5 1/2in Liner 126L2 126L1 91.68 91.78 TD, 5 1/2in Liner 92,99 TD,5 1/2 Liner PI. ~ 5280 5440 5600 5760 5920 6080 6240 6400 6560 6720 6880 7040 7200 7360 7520 7680 Vertical Section (feet) .> Azimuth 185.57 with reference 0.00 N, 0.00 E from Slot #126 . -e--- ConocoPhillips Alaska, Inc. .- .... fNTEQ Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #126 Well: 126 We II bore: 126 Scale 1 em == 300 ft -2400 -1800 -1200 -600 Cono~illips Created by: Planner Date plotted: 30-Jun-2004 Plot reference is 126. Ref wellpath is 126 Vert14 . Coordinates are in feet reference Slot #126. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99,00 ft. Plot North is aligned to TRUE North. /' 600 East (feet) -> 1200 t800 2400 3000 3600 4200 4800 5400 6000 o SURFACE LOCATION: 852' FSL, 631' FEL SEC. 16, TIIN, R10E t>,\ "R'tQ fJ &'- 'f.O« ~~~~~~'"f}\~"Q~-s.~o <Ò~\ò~~~~e '«~~ ~ ~ 'Q 'í?'3'~O ~o'y " ~ d.\'Ç\~ 'f.: (flF ~ Oç '"f}\'iP ,,'"f} ------<J ~ Tura.4.5/100 C lOp Ugnu Start 200' Pump Tangent End 200' Pump Tangent, BldlTrn 4.5/100 EOC Top Ugnu B Top Ugnu A 1E-126 TOP WEST SAK D LOCATION: 1603' FNL, 1424' FEL SEC. 22, T11N, R10E 1E-126 TOP WEST SAK B LOCATION: 1841' FNL, 1448' FEL SEC, 22, T11N, R10E 1 E-126 TOP WEST SAK A2 LOCATION: 2634' FSL, 1528' FEL SEC. 22 T11 N, R10E 1E-126LI & 1E-126L2 ill LOCATIONS: 1636" FNL, 1961' FEL SEC. 27, T11 N, R10E 7"\",1"""-,. ¡: ;ç I J; ,y r. ~q",~ U·' Gt S K-13 EOC Top West Sak D Bid 3/100 C EOC Top West Sak B A-4 A-3 Top West Sak A2, Int Csg. pt. J L 9 5/8in Casing / / 1E-126 ill LOCATION: 1796' FNL, 1952' FEL SEC. 27, T11N. R10E 600 0 -600 -1200 -1800 -2400 -3000 -3600 ^ I -4200 Z 0 ;:a. ::T -4800 -::;; CD CD - - -5400 -6000 -6600 -7200 -7800 -8400 en o II ëõ -9000 ;:: 3 II -9600 ~ o ;:I! Note: Intermediate and bottom lateral to be drilled with rotary steerable, upper laterals with motor 16" Hole (Spud Mud) 13 3/8" Casing KOP: 300' Build at 3-5 degrees/ 100' Hydraulics: Surface: 900-1000 gpm Intermediate: 700-800 gpm Laterals: 500-600 gpm Pore Pressure TVDss TVD MWE o ;:0 1530 psi 3340 ft 3435 ft 8.8 ppg . Top of Ugnu ~ ,// +/-4266' MD ,/ Window @ 7054' M~ ~ ///""b" Sand (Oil Base Mud) ---- \ 81/2" Hole 5 1/2" Liner _,_ "B" Sand (Oil Base rv1LJd) Window @ 73~Hole/ _// -~ 5 1/2" Line 12,438' MD 3401 TVD ..;:¡;¡¡~ ~~ y)' J> r-. t Top of Cement MD Tangent Angle: 69 degrees 12 1/4" Hole (LSND) 9 5/8" Casing 8121' MD 3617' TVD 12,434' MD 3335' TVD . "A-2" Sand (Oil Base Mud) 8 1/2" Hole (Undulating) 5 1 /2" Liner 12576' MD 3571' TVD ~ ConocoPhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com July 3, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 / Anchorage, Alaska 99501 ( / Re: Application for Permit to Drill, West Sak Producer, £26 L2 / \ // Dear Commissioners: '-,--------- ,ÁÞ ,l t,Þ" 1.1 ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production well bore, the upper lateral well bore of a æultilateral horizontal well, in the West Sak "D" sand. The main bore of this well will be designated l~i~ has been permitted under a separate application, submitted on July 3, 2004. This application is for the upper lateral of that well, to be designated 1E-126L2. The expected date that operations will begin on 1E-126L2 is August 18, 2004. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. Under separate cover, ConocoPhillips is applying for a spacing exception for this well bore, under the terms of 20 MC 25.055 Please contact Steve Shultz at 263-4620 if more information is needed to issue a Permt to Drill for lE- 126L2. Sincerely, ~~~ Randy Thomas GKA Drilling Team Leader . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,f"Ru IE-I2&L2- PTD# 26 L/'--I'Z <j t/ Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a pew w~lbore segment of LATERAL existing wen K R Ii IC" -. Z ~ _ r/ Permit No,JoV'- IUAPI No. 5ò -"21- ~3 Z/~ - (If API number Production. should continue to be reported as last two (2) digits a function ·of tbe original API number. stated are between 6.0-69) above. PILOT HOLE )n accordance witb 2.0 AAC 25..o.o5(f), an (PH) records, data and Jogs acquired for tbe pilot bole must be dearly differentiated In both name (name on permit plus PH) and API Dumber (5.0 - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·to full EXCEPTION compJiance witb 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·than 3.0' sample interv~¡)s from below tbe permafrost or from wbere samples are first caugbt and J 0' sample h:iter:vals through target zones. Cò Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1E-126L2 Program DEV PTD#: 2041240 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On 1 P~rmit fee attacheq. . . . . . . . . NA. . . Multilateral well~ fee waived per 20.AAC 25~Q05(e) . . . , . . . . . . . . . . . . 2 .Lease Mmberappropriate . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . Surface location an.d.top produçtiVf~ jntervaJ ill ADL025651; TD inADL.025660 3 .U.nique well.n.am~.and oumb.er . . . . . . . . . . . . . . . . . . . . . . _ . _ _ _ . . . . . . . . . . . .V~S . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . _ . . . . 4 WellJQcat~d inad.efineqppol. . . . . Y~s _. _ _ . . KRU WestSak.o.iIPool,goYernedby.C.onseNation.Order.No, 4Q6A. 5 WellJQcat~d proper distance. from driJling unitb.ound.ary. . . Y~s . lIIoruinal spa.cing within the pOQI is 10.acres. . 6 Well JQcat~d pr.oper .distance. from other wells. . . . . . . . . . . . . . . . . . . Y~s . 7S.utficientacreage.ayailable in.drilJiog unjt .V.es. . . . . . . . . . . . 18 Jfd~viated, js. weJlbQre plaUlJcJuded . . . . . . . Y~s . . . . . .. ..................... . . . . . . . . . 9 Operator only affected party. . . . . Y~s . . . . . . . . . . . . . . . . . . . .. ...................... 10 .Oper.ator bas.appropriate.bond inJorce _ . _ . . _ . . . . . . . . . . . . . . . . Y~s . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P~rmit c.an be issued wjthQut conservation order . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 12 P~rmit can be issued wjthQut ae!.milJistratilleapprpvaJ . Yes. . . . . . . . . . . SFD 7/12/2004 13 Can permit be approved before 15-day wait Ves 14 WellJQcated wi.thin area and. strata authorized by.lnjectipo Ord~r # (pu!lO# in.cpmm.ents). (For. NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 AJI wells. witÞin .114.milearea.of review jd~otified (Fpr servjc.e well OlJly). . . . . . . . . . . . . . . NA _ . . . . . . . . _ . . . . . . . . . . _ . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre-producee!. injector; qurationof pre-proquG!ipnl~ss. than 3 months (For.servLce well QnJy) . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . I 117 ACMP Fïndjngof Con.si$tency. h.as bee.n Js.sued.for.tbis pr.oject . . . . . . . . . . . . . .NA . . . . . . . Multilateral weU .bpre, Administration Engineering Appr Date TEM 7/12/2004 ~'"t{{) ---.-.-- Geology Appr SFD Date 7/12/2004 Geologic Commissioner: rSTS Well bore seg Annular Disposal ~ - - - - - - - - - - - - - - 18C.onductor string.prQvided ... .NA . Conductor JnstaJled. in1 E-126. . 19Surfac~casing.pJotec.ts. all.known USDWs . . . . . . . . . . . . . .NA . . . . . . 81l aquifers ex.el'T1pt~d 40 CFR 147.. t02(b)(3), . 20 .CMTvoladec¡uate.to circuLateoncPlJd.uctpr.& su.rf.C$g . . . . . . NA . . Surface ca$Lng instalJe.djn 1E-126, . 21 .CMT v.ol adec¡u.ate.to tie-inJQngstring to surf csg. . . . . . . . . . . . . . . . . . . . . . . . . . . . NA . Intermedjate casing Lnstalled jn tE-126,. 22 .CMTwill coyeraJl klJownpro.ductiye bQri;!:on.s. . . . . . . . . . . . . . . . . . . . . . . . . No. . . SlottedJinercompletion pLaOlJed.. lnteJmedJate ce.mellt p1anllee!. above an.ny/all hydrocarbQn$.. . . . . . . . 23 .C.asing designs adeC1uate fpr C,T:, B&.permafrost . . . . . . . . . " Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ,. . . . . . . . . . . . . . . 24 .Mequate.tan.kage.oJ re.serve pit. . . . . . . . . . . Y~s . . . . . . . Rig jsequippedwith steelpits. No reserve.pjtplanlJed, AJI waste toallapprOlledaonuJusor Classll well, 25 Jfa.re-drilt basa tOA03 fQr abandonment be~o apPJQved . NA . . . . . . . . . . . . . . . . . . . . . . 26 AqequateweJlboreseparatjo.n.proposed................................. .V~s...... . I? rOJ5im ity analYSis performe.d, O.nly.close approach is B.salJd.s.eçtjo.n.abou.t 5Q'tvd.belp w............... . 27 Jfdjverter Jequired, dQes jtmeet reguJatiolJs. . . . . . . . . . . ., ................. NA . . .. .. 6op.stack will.alrea.dy be in.p!ace.. .. .......... 28 .DJilliog fluid program schematic.& eq.uip Jistadequate. . . . . . . . . . . . . . . . . . Yes . . 61:11:1 expectee!. betwe.en 8..1.- 8..8.EMW.. I?laoned MW 9.0.- 9.2 jn West .Salç.. 29 .BOPEs,dotheymeetreguJatiolJ. . . . . . . . . . . . . . . . . . . . . . . Y~s. 30 .BOPE.press ra.tiog appropriate; .testto.(pu.t psig in .commelJts). . . . . . . . . Y~s . . M8S¡:> calcuJate.d.at 11.54 psi, 35QO.p$iapproprjate.. .CPAJ p1alJs.to tesUo 50QOp$L . 31CholçemanjfOld cQmpJies w/API 801='-53 (May 84). . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 WQrlç will pccur withput.operatjoll.sbutdown. . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ........................... 33 Jspresence QfH2S gas.prob.able. ........ ...... ............. . No... . . 1:i2SisuoILkely..Mud.s.hpuldpr.eclue!.e.H2.S.0.n.the.rig. .Rig is equjpped with.s.ensors.and.alarms.. ......... 34 Mecha.nicalcoodJtion of wells withilJ 80R yerifiee!. (for.s.ervice welJ onM. . . .NA - - - - - - - - - - - - - - - - - 35 P~rmit can be issued w/Q hydrogen sulfide measures. . . . . Y~s . . . . KRU WestSak wells. 112 miJe tp ~ast rn~asure.dJess .th.an J 0 ppm H2S in 2003 and 2002.. . . 36 .D.ata.PJeseotedon.pote.ntialove.rpres.sure.zOlJe$...... ............... Y~s...... .Expectee!.r.eservoirpre.ssuJei$.8,1.-.8.6.ppgEMW;wj.b~.drilledwjth 9,O.-9.2ppg mud. 37 .s~isl'T1icallalysjs Qf shaJlow gaszooes . . . . . . . . . . . . . . . . . . . . . . . . .NA 38 .S~abed .condjtipo survey .(if off-sh.ore) . . . . . . . . . . . . . . . . . . . . . . . . . .NA. ...................... 39 CQnta.ct lJarn.elpÞoneJorweelçly prpgressreports [exploratory only] . . . . . . . . . . .NA . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date ìll~ ~ D . . e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. " **** REEL HEADER **** LDWG 05/02/04 AWS 01 **** TAPE HEADER **** LDWG 05/02/04 01 *** LIS COMMENT RECORD *** . ¥ !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !! !! !! !! ! ! ! ! ! ! ! ! !!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 G. SUTING D. GLADDEN MWD RUN 4 7 S. TUFTON P. WILSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 16.000 12.250 8.500 . r- )3Ö ~" 1E-126L2 500292321561 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 04-Feb-05 MWD RUN 2 2 S. TUFTON P. WILSON MWD RUN 9 MWD RUN 3 3 LABRECQUE D. GLADDEN MWD RUN C. WONG F. HERBERT 16 UN 10E 99.00 71. 00 CASING SIZE (IN) 20.000 13.375 9.625 DRILLERS DEPTH (FT) 120.0 3795.0 7143.0 12457.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE ~O'l- /2t-f . . GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 18' 09.70" LONG: W149 DEG 35' 45.22" LOG MEASURED FROM D.F. AT 99.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ run 1 utilized a directional tool with Gamma Ray to drill from 108 to 3802 feet MD (108 to 2306 feet TVD) completing the 16 inch hole section. 2) Baker Hughes INTEQ run 2 utilized an Autotrak G1.5 tool along with RNT (Reservoir Navigation Tool) Resistivity, and Gamma Ray services to drill from 3802 to 5151 feet MD (2306 to 2773 feet TVD). 3) Baker Hughes INTEQ run 3 utilized a directional tool with a Multiple Propagation Resistivity (MPR) and Gamma Ray to drill from 5151 to 5850 feet MD (2773 to 3034 feet TVD) . 4) Baker Hughes INTEQ run 4 utilized an Autotrak G1.5 tool along with RNT Resistivity, and Gamma Ray to drill from 5850 to 8094 feet MD (3034 to 3606 feet TVD). This D-Sand Lateral was kicked off off the parent wellbore at 7143 feet MD. 5) Baker Hughes INTEQ run 9 utilized a Multiple Propagation Resistivity (MPR) with Annular Pressure from 7143 to 12457 (3426 to 3382 feet TVD). REMARKS : 1) Depth of 13 3/8" Casing Shoe - Driller: 3795 feet MD (2303 feet TVD). Depth of 13 3/8" Casing Shoe - Logger: 3798 feet MD (2304 feet TVD). 2) Due to the change in Resistivity tool type on Run 3, the presentation goes from 2 curves (RPD & RPS) to 4 curves (RPD, RPM, RPS, & RPX) . 3) This D-sand lateral (lE-126L2) was kicked off the parent wellbore (lE-126) through a window in the 9 5/8" casing. Top of Casing Window: 7105 feet MD (3417 feet TVD). Bottom of Casing Window : 7143 feet MD (3426 feet TVD). 4) Due to the change in Resistivity tool type on Run 7, the presentation goes from 2 curves (RPD & RPS) to 4 curves (RPD, RPM, RPS, & RPX) . 5) The interval from 12419 to 12457 feet (3379 to 3382 feet TVD) was not logged due to sensor offsets at TD. $ Tape Subfile: 1 95 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER . . FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 234.0 STOP DEPTH 12457.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 9 MERGE TOP 234.0 3752.0 5134.0 5802.0 7143.0 MERGE BASE 3752.0 5134.0 5802.0 7143.0 12457.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT le-126L2 5.xtf 150 ConocoPhillips Alaska, Inc. lE-126L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPCLM 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPCHM 0.0 RPX RPX RPCSHM 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 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: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F . ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 ------- 28 Total Data Records: 789 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 234.000000 12457.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 834 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 . log header data for each bit run in separate files. 1 .2500 START DEPTH 234.0 STOP DEPTH 3752.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) 03-AUG-04 MSB 18704 8.5 GAM MEMORY 3802.0 234.0 3752.0 o . MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: BIT RUN 1 (MWD Run 1). GR/Dir. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1e-126L2.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1E-126L2 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM ROPA 0.0 0.0 GRAM ROPA GRAM ROPA * 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: 0.250000 Frame spacing units: [F ] . 0.0 70.8 TOOL NUMBER DHA 6437 SRIG 58017 16.000 120.0 SPUD 9.10 .0 .0 200 .0 .000 .000 .000 .000 80.0 .0 .0 .0 .00 .000 .0 o . . Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAM MWD ROPA MWD 68 68 1 1 GAPI FPHR 4 4 4 4 ------- 8 Total Data Records: 168 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 234.000000 3752.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 241 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 2 .2500 START DEPTH 3752.0 STOP DEPTH 5134.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): 06-AUG-04 MSB 18704 8.5 ATK MEMORY 5151. 0 3752.0 5134.0 o . HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 67.8 70.4 TOOL NUMBER ATK 08 20067 20067 12.250 3795.0 LSND 9.25 .0 .0 200 .0 .000 .000 .000 .000 76.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-126L2.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-126L2 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPCH ROPA RPTH 0.0 0.0 0.0 0.0 0.0 GRAM RPCL RPCH ROPA RPTH GRAM RPCLM RPCHM ROPA RPTHM . . * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 MINS 4 4 ------- 20 Total Data Records: 132 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3752.000000 5134.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 4 212 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 log header data for each bit run in separate files. 3 .2500 START DEPTH 5134.0 STOP DEPTH 5802.0 . # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RES. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 07-AUG-04 MSB 18704 8.5 MPR MEMORY 5850.0 5134.0 5802.0 o 66.2 70.8 TOOL NUMBER 6437 23579 58017 12.250 3031.0 LSND 9.20 .0 .0 200 .0 .000 .000 .000 .000 90.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3 (MWD Run 3). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1e-126L2.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-126L2 FN Kuparuk River COUN North Slope . . STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 87 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5134.000000 5802.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 171 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 . *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE014.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 5 . log header data for each bit run in separate files. 4 .2500 START DEPTH 5802.0 STOP DEPTH 7143.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 09-AUG-04 MSB 18704 8.5 ATK MEMORY 8094.0 5802.0 7143.0 o 68.2 80.1 TOOL NUMBER ATK 23702 2058 2058 12.250 3795.0 LSND 9.25 .0 .0 200 .0 .000 .000 .000 .000 96.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2RR (MWD Run 4). GR/RNT. This D-sand lateral (lE-126L2) was kicked off the parent wellbore (1E-126) through a window in the 9 5/8" casing at 7143' MD. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) REMARKS: . RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-126L2.xtf 150 conocoPhillips Alaska, I lE-126L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 MINS 4 4 ------- 20 Total Data Records: 128 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5802.000000 7143.000000 0.250000 feet **** FILE TRAILER **** . . . Tape Subfile: 6 211 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .006 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE015.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 6 . log header data for each bit run in separate files. 9 .2500 START DEPTH 7143.0 STOP DEPTH 12457.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RES. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 26-AUG-04 MSB 18704 6.75 MPR MEMORY 12457.0 7143.0 12457.0 o 85.5 94.5 TOOL NUMBER 6289 6010 6010 8.500 7143.0 Oil Based 9.05 .0 .0 32000 .0 .000 .000 .000 .000 130.0 .0 .0 .0 . . MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 5RR (MWD Run 9). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-126L2.xtf 150 ConocoPhillips Alaska, I 1E-126L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 ... . . 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 686 Tape Fíle Start Depth Tape Fíle End Depth Tape Fíle Level Spacíng Tape Fíle Depth Units 7143.000000 12457.000000 0.250000 feet **** FILE TRAILER **** Tape Subfíle: 7 770 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/02/04 01 **** REEL TRAILER **** LDWG 05/02/04 AWS 01 Tape Subfile: 8 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes