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Home My WebLink About205-198C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-10-03_22191_KRU_1J-166_ProductionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22191 KRU 1J-166 50-029-23291-00 Production Profile 03-Oct-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 205-198 T39659 10/11/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.11 13:33:27 -08'00' THE STATE °fALASKA GOVERNOR BILL WALKER John Pierce Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-166 Permit to Drill Number: 205-198 Sundry Number: 318-461 Dear Mr. Pierce: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.olaska.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. t; DATED this 1'4 day of October, 2018. Sincerely, Hollis S. French Chair RBDMSC OCT 19 2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhllll s Alaska Inc. Exploratory ❑ Development • 0 Shatigraphic ❑ Service ❑ 205-198 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23291-00 -00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU U-166 Will planned perforations require a spacing exception? Yes ElNo I] 9. Property Designation (Leaa�cssee� Number) 10. Field/Pool(s): 76669; a r ADL ADL 25661 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): 12,853' 3,718' 12,853 3,718 1,500psi NIA N/A Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 108' 108' Surface 2,338' 103/4 2,368' 2,194' Intermediate 6,324' 75/8 6,350' 3,648' Liner 7,360' 41/2 12,840' 3,712' Perforation Depth MD (ft): I Perforation Depth TVD (ft): ITubing Size: Tubing Grade: Tubing MD (ft): 6360-8698,8945-10031,10648-13650-3656, 10710, 10990-12808 36611-3712,3678- 3668, 3652-371 4.500" L-80 1 4,922' 1 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = ZXP LINER TOP PACKER 4896 MD and 3392 TVD PACKER = ZXP LINER TOP PACKER 5107 MD and 3437 TVD PACKER = HRD ZXP LINER TOP PACKER 5480 MD and 3513 TVD SSSV = NONE NIA 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development I] Service ❑ 14. Estimated Date for 1114/2018 15. Well Status after proposed work: Commencing Operations: OIL E] WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265-6471 Authorized Signature: — Date: ID 11 2.01. 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: Post Initial Injection MIT Req'd? Yes ❑ No Ilr� Spacing Exception Required? Yes ❑ No d/ Subsequent Form Required: /0-404 APPROVED BY I O Approved by: COMMISSIONER THE COMMISSION Date: / U K 1 U 1 N A I BDMs Submit Form d/Z OCT 19 2018 V �a /` Form 10-403 Revised 4/2017 Approved application is valid for 12 months from t e date of approval. Attachments in Duplicate �, KUP PROD Comc(3�'1iffips �'' Well Attributes 1" WE TBA Aiaaka, Inc. WEST SAK sstw0: 1J-166 una91.9 xm.44 AM Last Tag Vertrel vJwem seves, AnnohNoa Last Tag: Ell Doh Dep01111XW tut MOE BY Imosbor ........._. ._..._._........ Last Rev Reason .ad.sn. 3Ia Annotation Entl Mie lea(MW By Rev Reason. Pulled Spartek Gauges Y2Y2018 zembaej Casing Strings caamo Desenpuon OD lml ID (A) TDpmKRI semepib(nKB) set Depth lNDl_. MLen p... Grace TopTbreatl CONDUCTOR Insulated 16 15.25 30.0 108.0 1080 62.50 H40 WELDED fAXLV.CTOR Im,YW:.i16 loan Caslna Description SURFACE DID (in) 10 Y4 ID pn) Tell Set Depth MED 30 Depth INDI.-Wtlbn 6., Grape To Tnrptl 995 30.1 2,3684 2,194.2 45.50 L40 BTC Dasine DescnpWn 00 (in) lDghg Top MB) set Dept01RKB) SM pith 11'aLenp...Gmtle Top The NIGPLE:EEX3 INTERMEDIATE 7518 687 26.4 6,350.0 A606.8 29.]0 680 BTCM I. TUCE, IDC Casing MwriAm. OD (in) IDlln) Top gi Set MpM MKB) Set Depth HVDL.. VAR- 11...Gratle Top TM1rtatl D LINER LEM 4112 396 4,8850 5,13]0 34433 1260 L-80 IBT Liner Details SJRFACE pAI-Zg3i xomma lD ioptttKM Top RVMMe) mp P) Ihm Ma Co. Im) 0,8850 3,389.8 76. 7fi.92 TIE BACK TIE BACK EXTENSION 5 350 OASDFT', 251 4,896.0 3,392.2 77.07 PACKER ZXP LINER TOP PACKER 4.980 4,9040 3,3940 77.18 BE SEAL BORE EXTENSION 190-41 4760 4,9587 3,405. 7791 NIPPLE 3,75- DB NIPPLE 3750 4,994.7 3,413.3 78.13 HANGER LEM ABOVE HOOK HANGER 3.910 GASLLR:4.3195 5,001.5 3.4143 78.12 HANGER LEM INSIDE HOOK HANGER 3.930 5,1337 34426 77.04 SEALASSY NON -LOCATING SEAL ASSEMBLY 3.890 Canna Oescripiion DO (n) ID OnI Top RKBI SeIMgM1 MNBI Set DepN (ND)... VNlen (I... G/etle Top TM1�eatl SLEEVE: 4,mv4 B LINER LEM d 112 3.96 510].5 B.1 3,5197 12.60 L-80 IBT Liner Details GNIGE: i.Blz i Nominal Io Top MKB) ropINOIMKB) Topi (') vein Dee Co. (n) 5,107.5 3,436.8 7743 PACKER ZXP LINER TOP PACKER 4.950 LOCAr3R. AM 5,126. 34410 77.14 SBR 109,] CASING SEAL BORE RECEPTACLE 4390 5,1 5. 34453 7685 TO BUSHING CROSSOVER BUSHING 3.950 SEALAnda.4.891.4 5,1473 34457 76.83 SWNEL BAKER CASING SWIVEL 3.960 5, 6 3,4932 79.61 HANGER LEM ABOVE HOOK HANGER 3.950 5,3773 3495.1 7969 HANGER LEM INSIDE HOOK HANGER 3.68 5,442.8 3,506.5 80.17 NIPPLE CAMCO DBE NIPPLE 3.563 5,4752 3,5120 80.32 BENT JT 3.880 5,5182 3,5192 80.53 SEALA Y BAKER SEAL ASSEMBLY 3.880 Case00es[rlptlan OD pn) ID 9M Top MKB) Bet ..;ARMIp 8tt CepM INOI... LVolen'I Grape iapTMatl A -SAND LINER 4112 396 5,480.0 12,840.0 }]172 12.60 L-80 18T OSANDDNERS00$.1- 12.1 Liner Da}8118 Nominal III Top MKB) Top HYD) IttK Top Incl l•) Mm Des Com (in) 54800 3.511A 80.35 PACKER "HRD" ZXP Litertop Packer S5"X7.6" 4.9]0 54990 3,5160 I SU 44 1 NIPPLE "RS" PaRamnersl Nipple55" 4.8]5 5,511] 3,5181 1 8049 SBE 19047 Casing Seal Bore Est, 4,75-113 A 6.25"DID 4350 O LINER LEM',464505,1T0 Tubing Strings Tubing Mscription Sling MS-113D(Inl TopIKKR) sen Depth (I SN OeOn IND)I...YX6bK[I Grave Toptonneclion TUBING WO 4112 3.9fi 22.4 4,922.0 33980 1260 L40 IBTM Completion Details ropRe.) ro,lIl hms-1 Top ME, (FAR) I P) 1.ces Co. IF p') 224 224 000 HANGER TUBING HANGER 3958 9sAND UNER Sana 5033 5033 057 NIPPLE 3.875'Carrow "DB"Nipple 3875 12..S 4,8314 3,3]].1 7581 SLEEVE BAKER CMD Sliding Sleeve 3.812 4,842.1 33]9] 78.04 Ca4UGE Baker Guardian Guage 4.000 4,893) 33917 7].04 LOCATOR Locator) 2' space out 3.910 4,8974 3,392.6 7].09 SEAL ASSY BAKER 19047 SEAL ASSEMBLY 3880 Other in Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TnpIN D) Top incl Tap lnne) MKa) f) Des Co.qun Dah ID On) 100 100 0.00 HEAT TRACE HEAT TRACE SI17)2008 0000 a LINER LEM', 5,107M,$d 5 perforations B Slots Devi Deni To Btm (NO) (sholsM Top IM(B) B."It) ) MKM MR) IRKM tlnke02ane Mie ) TyS Co. 6,3 80.0 0 3,6499 3,fi55.8 WS J - 11 19)2006 32.0 SLOTS _ALrPHIS T 188 WERFS WELLBORE -Alternating slOKedNlank pipe 0125" x IMERMEDUK E:..,3500 2.5" X 32 Spt 6_9 4 Ciroumhmnbal adjacent rove, 3" Centers staggered 18 deg., 3 8. nonSlaged SLOTS. e.aM.oaMeo� I ends 8.9450 10,0310 3,661A 37117 WS A2, 1J-166 11192006 32.0 BLOTS L 10.6480 10,]100 3678.3 36684 WSA2,1J-166 V1912008 320 6LOT5 10,990.0 12,808.0 3851.8 3715.9lie" ie Ara, 1J-1611 111912006 32.0 SLOi6 Mandrel Inserts IIf'F 5LOr5:Sesso10,wto� st A SLOTS 10,919.010.7100N Top "ES Top IKKB) (XKM Make Mope) 00 (in) Sery Valle Lease portSize TRO Run Type pas (an) IWb Run Mie Com 1 2,5720 2,361.6 CAMCO KBG-2- 1 GAS LIFT GLV BK -5 0.125 1,475. 41231 M R tor9 a: tD.amo-rz.eoe.o-� 2 4, 1 5 3725.8 CAMCO KBG-- 1 GAG LIFT OV BK -5 0313 0 a2Y2008 1R XSAND LINER: 54800- 480612,910.0 12.841 Canoc(3Phillips Alaska, Inc. KUP PROD U-166 F-- I E:::] we3.lMvmla zw:uvM v4nmad�mec la�l ....................... -.......... .............. ... __............................ HANGER; 724 ..._ ............... . ................ Notes: General & Safety End D.. aonoutron 210/2006 NOTEMULTI-LATERAL WELL: IJ-166(4,2-SAND),1J-166L1(B-SAND), 1J-166LY (D -SAND) coxouc7DR mwMne:xio- WM008 NOTE: VIEW SCHEMATIC w19.OREV NIPPLE: 20.3 033 NEPT TRACE,100 SUREACE,MI12,339.4- GASLIrT;Z5T10 GAS LIFT, 4,31as SLEEVE: 4.WI4 CAUSE; 4.521 LOCATOR: 4,SW,T SFAL..; 4,W14 DSSNO UNER: E.O2I- 1iW,7 0 LINER LEM. 4,365.051370 S DLINER:5,3713 12906.3 B LINER LEY: END ELS MI5 INTERMEDIATE: 448,350 SLorS3.31IS" .M.o� I 1 SLOTS', 691561 .,. SLOTS. 10 ENAS10.710.O SLOTS; f0,99061p,BA.O� A SAND LINER, 5.1tl.0 1ZB100 Proposed 1J -164L1 to 1J -166L1 RPPG Treatment of B MBE 1J-1641_1 is a West Sak B Sd horizontal injector Lat. An initial MBE from 1J-164 to 1J-166 offset producer occurred January 2008. On 1/26/08, an IBP was set at 9200' RKB in a 683' blank section of 4.5 liner in 1J-1641-1 to isolate the MBE, but communication resumed 5/24/09 to the B MBE. 6/1/09 IPROF showed all PWI entered 1J -164L1. 6/15/09 IPROF in 1641-1 showed all flow passing a swell packer on 4.5" liner at 8803' RKB to a B MBE toward the toe of the Lat, but no flow was seen past the IBP set at 9200' in the liner. All flow to the B MBE was seen exiting to liner x OH annulus. On 8/4/09, 5' of perfs were shot above the IBP. On 8/6/09, an inflatable Cmt Retainer was set at 9000' RKB above perfs to form a straddle in 4.5" liner, then 24 bbls of 8.5# Cement was pumped into the straddle to Cement 200' in 4.5 liner and 683' of adjacent liner x OH annulus to isolate the B MBE. This MBE isolation lasted 7 months until communication resumed to toe B MBE per 4/6/10 B ]PROF. On 10/31/10, 5' of perfs were shot at 8550 - 8555' RKB. On 11/2/10, a Cmt Retainer was set at 8231' RKB and 28 bbls of Ultra -Lite 8.5 ppg Cement was pumped to add more Cement Plug to reisolate the toe B MBE. This successful job allowed 1J-1641_1 BOI until 2018, before a new MBE occurred. A 4/7/18 IPROF saw all flow to B Lat, and 4/24/18 B IPROF saw a new B MBE at -5100' RKB, but the Cement Plug was still effectively isolating the toe B MBE of 2008. On 9/15/18, a fullbore MARCIT Gel job put 80 bbls of Crosslinked MARCIT in the MBE, but the treatment failed -4 days after 1J-136 BOI. It is now proposed that RPPG slurry be fullbore pumped to treat the MBE 5100' RKB. 1J-164 is currently configured with A Lat Plug set, B Diverter set, and D Iso-Slv set. 1J -164L1 appears to be a very robust MBE, but we have had some recent success using RPPG to treat similar large MBE's. Proposed Procedure: 1) Coil Tubing: RIH with 2" pert gun to shoot big holes in 4.5" Slotted Liner 5095 - 5100' RKB at 6 spf, 60 deg ph, near the MBE to enable good RPPG passage through the slotted liner. POOH with gun. RD. 2) Fullbore Pump RPPG (Reformed Polymer Particle Gel) Treatment to B MBE: RU Pumping unit, and Fullbore Pump: a) -150 bbls Pre -Flush of 2% KCL Brine or Seawater at -2 bpm to establish injection to MBE at -5100' RKB and displace hydrocarbons to liquid pack the wellbore, then SI offset 1J-166 producer and continue pumping into 1J-1641_1 with, b) RPPG Slurry at -0.75 ppg (target) in 2% KCL Brine at steady rate of -2 bpm until WHIP reaches -800 psi, then swap to Flush/Displacement with c) 40 bbls 2% KCL Brine Spacer at established steady rate of -2 bpm, followed by d) 37 bbls Diesel FP at steady rate of -2 bpm, followed by e) SD pumping & RD pumping equipment. 3) Coil Tubing: RIH with jetting nozzle to perform RPPG Fluff & Stuff to as deep as possible in the 1J-1641_1 lateral. RD CTU. Put 1J -164L1 BOI to evaluate MBE treatment. ]WP 10/10/2018 tioF ?It • ��►,§..1" 1///;,.,/ s THE STAR Alaska Oil and Gas 0 -sem �, of T Conservation Commission .,- ALAS � s }#t �, 333 West Seventh Avenue " T ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 q :5 � Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce5��t JUN 1 5 ,..i 1 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool,KRU 1J-166 Permit to Drill Number: 205-198 Sundry Number: 318-233 Dear Peirce: 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, L001; Hollis S. French k` Chair DATED this t1 day of June, 2018. • RBDMS Jul, 9-..... _..- • 0 • RECEIVED STATE OF ALASKA JUN 0 1 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well E Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE MARCIT GEL T tmt0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 • 205-198 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23291-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1J-166 • Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25660,ADL 25661 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): 12,853' • 3,718' • 12,853 3,718 1,500psi 10235 N/A Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 108' 108' Surface 2,338' 10 3/4 2,368' 2,194' • Intermediate 6,324' 7 5/8 6,350' 3,648' Liner 7,360' 4 1/2 12,840' 3,712' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6360-8698,8945-10031, 10648- 3650-3656,3661-3712,3678- 4.500" L-80 4,922' 10710,10990-12808 3668,3652-3716 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER=ZXP LINER TOP PACKER 4896 MD and 3392 ND PACKER=ZXP LINER TOP PACKER 5107 MD and 3437 ND PACKER=HRD ZXP LINER TOP PACKER 5480 MD and 3513 ND SSSV =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service 0 14.Estimated Date for 6/16/2018 15.Well Status after proposed work: Commencing Operations: OIL 0 . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 9 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com ~— Contact Phone: (907)265-6471 Authorized Signature: "Aft G Date: S–./31./ii COMMISSION USE ONLY Conditions of approv I: Notify Commission so that a representative may witness Sundry Number: 317-233 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /d — .4-0_if'' APPROVED BY 1" lie_Approved by: COMMISSIONER THE COMMISSION Date: Oft RB[�I�t� ``JUI� 1101 4,,-7,0,/ ,,,,:4,.___,•(S� f��ro n 10-403 Revised 4/2017 Approved applicati d� ,t n m e date of approval. Attachments in Duplicate 8--------",\ KUP OD 1J-166 ConocoPhillips 3 Well Attrl Max An MD TD Field Name Wellbore APIIUWI Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) Alaska,Sic WEST SAK 500292329100 PROD 99.97 10,663.58 12,853.0 Comment H2S(ppm) Date Annotation I End Date IKB-Grd(ft) Rig Release Date ... SSSV:NIPPLE Last WO: 4/17/2008 31.01 2/11/2006 1J-166,5/30/2018 8:29:51 AM Last Tag Vertical schematic(acarol) Annotation End Date Depth(ftKB) Last Mod By Last Tag: Imosbor Last Rev Reason HANGER;224 Annotation End Date Last Mod By Rev Reason:WELL REVIEW 5/13/2013 osborl ]ram,Casing Strings 1 -Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 16 15.25 30.0 108.0 108.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I....Grade Top Thread _^CONDUCTOR Insulated;3o.D-109.0„„„. ...,SURFACE 10 3/4 9.95 30.1 2,368.4 2,194.2 45.50 L-80 BTC NIPPLE;503.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.87 26.4 6,350.0 3,648.8 29.70 L-80 BTCM HEAT TRACE;10.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D LINER LEM 4 1/2 3.96 4,885.0 5,137.0 3,443.3 12.60 L-80 IBT Liner Details SURFACE;30.1-2,36B.4----.• Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(3 Item Des Com (in) all 4,885.0 3,389.8 76.92 TIE BACK 'TIE BACK EXTENSION 5.750 GAS LIFT;2,572.0 ilt 4,896.0 3,392.2 77.07 PACKER 'ZXP LINER TOP PACKER 4.980 I 4,904.0 3,394.0 77.18 SBE .SEAL BORE EXTENSION 190-47 4.760 4,958.7 3,405.8 77.91 NIPPLE 3.75"DB NIPPLE 3.750 4,994.7 3,413.3 78.13 HANGER LEM ABOVE HOOK HANGER 3.910 5,001.5 3,414.7 78.12 HANGER LEM INSIDE HOOK HANGER 3.930 GAS LIFT;4,319.5 5,133.7 3,442.6 77.04 SEAL ASSY 'NON-LOCATING SEAL ASSEMBLY j 3.890 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread B LINER LEM 4 1/2 3.96 5,107.5 5.521.5 3,519.7 12.60 L-80 IBT SLEEVE;4,831.4 Liner Details GAUGE;4,842.1 f'!. Nominal ID Top(ftKB) Top IND)(ftKB) Top Incl(°) Item Des Com (in) 5,107.5 3,436.8 77.43 PACKER ZXP LINER TOP PACKER 4.950 LOCATOR;4,893.7 7 5,126.6 3,441.0 77.14 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.9 3,445.3 76.85 XO BUSHING CROSSOVER BUSHING 3.950 SEAL ASSY;4,897.4 5,147.3 3,445.7 76.83'SWIVEL 'BAKER CASING SWIVEL 3.960 a 5,366.6 3,493.2' 79.61 HANGER LEM ABOVE HOOK HANGER 3.950 5,377.3 3,495.1 79.69'HANGER 'LEM INSIDE HOOK HANGER 3.688 _. 5,442.8 3,506.5 80.17 NIPPLE CAMCO DB-6 NIPPLE 3.563 5,475.2 3,512.0 80.32 BENT JT 3.880 5,518.2 3,519.2 80.53 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade flop Thread A-SAND LINER 41/2 3.96 5,480.0 12,840.0 3,717.2 12.60 L-80 IBT D-SAND LINER;5,002.1- 12,952.7 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 5,480.0 3,512.8 80.35 PACKER "HRD"ZXP Liner Top Packer 5.5"X 7.6" 4.970 • 5,499.0 3,516.0 80.44 NIPPLE "RS"Packoff Seal Nipple 5.5" 4.875 5,511.7 3,518.1 80.49 SBE 190-47 Casing Seal Bore Ext.4.75"ID x 6.25"OD ' 4.750 Tubing Strings D LINER LEM;4,885.05,137.0 Tubing Description StringMa...ID m TopftKB Set Depth(M..Set Depth(TVD)(...Wt Ibtft Grade Top Connection C) ( ) P ( 1 TUBING WO 41/2 3.96 22.4 4,922.0 3,398.0 12.60 L-80 IBTM Completion Details Top(TVD) Top Incl Nominal B-SAND LINER;5,377.3- Ij Top(ftKB) (ftKB) (°) Item Des Com ID(in) 22.4 22.4 0.00 HANGER TUBING HANGER 3.958 3.875 3.812 4.000 3.910 503.3 503.3 0.57 NIPPLE 3.875"Cameo"DB"Nipple , 12,909.3 4,831.4 3,377.1 75.81 SLEEVE BAKER CMD Sliding Sleeve 4,842.1 3,379.7 76.04 GAUGE Baker Guardian Guage 4,893.7 3,391.7 77.04 LOCATOR Locator/2'space out 4,897.4 3,392.6 77.09 SEAL ASSY BAKER 190-47 SEAL ASSEMBLY 3.880 _�__ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) 1°) Des Com Run Date ID(in) • 10.0 10.0 0.00 HEAT TRACE HEAT TRACE 5/17/2008 0.000 B LINER LEM;5,107.55,521.5 I Perforations&Slots Shot Den Top(TVD) Btm(TVD) (shotslft • Top(ftKB) Brut(ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Com I 6.360.0 8.698.0 3,649.9 3,655.8 WS A2,A3,1J- 1/19/2006 166 32.0 SLOTS ALL PERFS THIS WELLBORE-Alternating slotted/blank pipe 0.125"x 2.5"x32spf@ 4 INTERMEDIATE;26.48,350.0 Circumferential adjacent 1I rows,3"Centers staggered 18 deg.,3 ft.non-slotted ends I I SLOTS;6,360.08,698.0 4 I 8,945.0 10,031.0 3,6611 3,711.7 WS A2,1J-166 1/19/2006 32.0 SLOTS 10,648.0 10,710.0 3,678.3 3,668.4 WS A2,1J-166 1/19/2006 32.0 SLOTS 10,990.0 12,808.0 3,651.8 3,715.9 WS A2,1J-166 1/19/2006 32.0 SLOTS Mandrel Inserts SLOTS;9,945.0-10,031.0 St ab N Top(TVD) Valve Latch Port Size TRO Run SLOTS;10,648.0.10,710.0 _ Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,572.0 2,361.6 CAMCO KBG-2- 1 GAS LIFT GLV BK-5 0.125 1,475.0 4/23/2008 _ 1R • SLOTS;10,990.0.12808.0 2 4,319.5 3,225.8 CAMCO KBG-2- 1 GAS LIFT OV BK-5 0.313 0.0 4/23/2008 1R A-SAND LINER;5,480.0. 12,840.0 KUP000 • 1J-166 ConocoPhillips & "'-' Alaska.inC, 1J-166,5/30/2018 8:29:51 AM Vertical schematic(actual) HANGER;22.4 =721'4a0 ® Notes:General&Safety • 7 I End Date Annotation 2/10/2006 NOTE:MULTI-LATERAL WELL:1J-166(A2-SAND),1J-166L1(B-SAND),1J-166L2(D-SAND) CONDUCTOR Insulated;30.0-- _ IIr,I11�, 6/22/2008 NOTE:VIEW SCHEMATIC w/9.0REV 03.3 ' NIPPLE;5033 HEAT TRACE;10.0 SURFACE;30.1-2,388.4 GAS LIFT;2,572.0 GAS LIFT,4,319.5 SLEEVE;4,831.4 GAUGE;4,842.1 L: LOCATOR;4,893.7 1 SEAL ASSY,4,897.4 I s w I(' I D-SAND LINER;5,002.1- Zl 12,952.7 T : D LINER LEM;4,885.0-5,137.0 P B-SAND LINER;5,377.3- 12,909.3 ,377.312,909.3 i Fri a S LINER LEM;5,107.55,521.5 INTERMEDIATE,26.48,350.0 SLOTS,6,360 0-8,698.0 SLOTS;8,945.0.10,031.0 ISI SLOTS;10,848.0-10,710.0 SLOTS;10,990.0.12,808.0 �. A-SAND LINER;5,4800- 12,840.0 S • Proposed 1J-164L1 to 1J-166L1 MARCIT Treatment of B MBE 1J-164L1 is a West Sak B Sd horizontal injector lateral. An initial MBE from 1J-164 to 1J-166 offset producer occurred January 2008. On 1/26/08, an IBP was set at 9200' RKB in a 683' blank section of 4.5 liner in 1J-164L1 to isolate the MBE, but communication resumed on 5/24/09 to the B MBE. A 6/1/09 IPROF showed 100% of PWI entering 1J-164L1. A 6/15/09 IPROF in 164L1 showed 100% of flow bypassing a swell packer on the 4.5" liner at 8803' RKB to a B MBE located toward the toe of the lateral, but no flow was seen going by the IBP at 9200' inside liner. All flow to B MBE was seen - exiting to liner x OH annulus. On 8/4/09, 5' of `big hole' perfs were shot above the IBP. On 8/5/09, CT Fluff & Stuffed perf debris and circulated lubricant. On 8/6/09, an inflatable Cmt Retainer was set at 9000' RKB at 135' above the perfs to complete a `straddle' in 4.5" liner, then 24 bbls of 8.5 ppg UltraLite Cement was pumped into the straddle to Cement 200' inside 4.5 liner and 683' of adjacent liner x OH annulus to isolate B MBE. This MBE isolation lasted 7 months until communication resumed to toe B MBE (per 4/6/10 B IPROF). On 10/31/10, 5' of big hole perfs were shot at 8550 - 8555' RKB. On 11/2/10, a Cmt Retainer was set at 8231' RKB and 28 bbls of Ultra-Lite 8.5 ppg Cement was pumped to add additional Cement Plug to re-isolate the toe B MBE. This successful job allowed 1J-164L1 BOI until 2018, before a new MBE occurred. A 4/7/18 IPROF saw all flow enter B Lat, and 4/24/18 B IPROF revealed a new B MBE present at 5100' RKB. This confirms the Cement Plug still effectively isolates the toe B MBE of 2008. 1J-164 is currently configured with A Lat Plug set, B Diverter set, and D Iso-Sly set. Per B Diverter issues during B IPROF, successful CT entry into the B Lat has been hit or miss lately. Proposed Procedure: 1) Coil Tubing: RIH with IBP on CT through B Diverter to set IBP at 5263' RKB in middle of 272' OAL Blank section of 4.5" Liner. If more than 3 RIH attempts to pass B Diverter with IBP have failed, we may halt IBP set efforts to pump a MARCIT job without an IBP set. POOH with CT. RD. 2) Accelerated MARCIT Treatment to B MBE: RU Pumping unit & PT equipment. SI 1J-164L1 SWI & MBE offset 1J-166 producer. Fullbore Pump: a) 50 bbls of 2% KCL Brine Pre-Flush at 1 bpm to establish injectivity to MBE at -5100' RKB, then b) 30 bbls of 10000 ppm Lead Linear Gel Spacer (mixed in 2% KCL Brine) at 1 bpm, then c) 80 bbls of Accelerated X-linked MARCIT Gel at 10000 ppm (in 2% KCL Brine) at -0.75 bpm, then d) 35 bbls 10000 ppm Tail Linear Gel Spacer (mixed in 2% KCL Brine) at -0.75 bpm, then e) 10.5 bbls 2% KCL Brine Spacer at -0.75 bpm, then f) 32 bbls Diesel FP at -0.75 bpm, then g) SD pumping & RD pumping equipment. SD is -3.4 hrs after first bbl of X-linked Gel was pumped, to leave viscous Moderately Deformable Non-Flowing Gel in the B MBE at SD. 3) Coil Tubing: (perform if IBP was set per Step 1 above): RIH & latch IBP set at -5263' RKB. POOH w/IBP. RD CTU. Put 1J-164L1 BOI to evaluate treatment. JWP 5/31/2018 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original fiile, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q ~- ~ ~ ~ Well History File Identifier Organizing (aone> RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES ~,.o,cea iuuiuiuiuiuu DIGITAL DATA ~iskettes, No. ^ Other, No/Type: Re.~a,~e~ea iiiuiiiiuuiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ~ Maria Date: ~ ~~DlD~ /s/ Y r ~ Project Proofing III IIIIII IIII) II III BY: Maria Date: ~j D g lsl Scanning Preparation _~~ x 30 = -~` + ~~ =TOTAL PAGES_J~~ (Count does not include cover sheet) BY: Maria Date: _~ .~/1 / ~ 71 /s/ Y V 1 Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ V Q ©Q /s/ ~/) Stage 1 If NO in stage 1, page(s) discrepancies were foundvv: YES NO Y BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: Comments about this file: /s/ o,~~~~e«e, uumiiiiiiimu P P 10/6/2005 Well History File Cover Page.doc ~~ . +~ • • ~ • ~ ~anocoPh~ll~ps October 21, 2009 ~C~ ~ ~ ?~0~ Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, Robert Christensen/Danell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone:(907)659-7535 Faac: 659-7314 ~~~~~~~~ ~asMc~ Uii ~ Ga~ ~on~. Commis~ian Anchora~s ConocoPhillips Alaska, Inc. has pulled a blanking sleeve in the B Lateral Entry Module (LEM) of a West Sak multilateral injection well. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for 1 J-166 (PTD 205-198) and 1 J-166L 1(PTD 205-199). This report records the pulling of the B-LEM isolation sleeve in the L1 lateral water injection well. If you have any questions regarding this matter, please contact myself or Bob Christensen at 659-7535. Sincerely, ~,~ ~ Darrell R. Humphrey Attachments " ~ 3 • ~ ~ ~~~~~~~~~ STATE OF ALASKA OCT Z~~aa~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~$~~ ~~~ ~~~~ ~~n~~ ~Ot~1iSSion REPORT OF SUNDRY WELL OPERATION~ anchoraae 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ~ Other ^~ pull B Sand ISO Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Sleeve Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter S spended Well ^ 2. Operator Name: 4. Current Well Status: . Permit to Drill Number: Co11oCOPhllllps AIBSka, InC. Development ^~ Exploratory ^ 205-198 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23291-00 . KB Elevation (ft): 9. Well Name and Number: R B 28' 1 J-166 . Property Designation: 0. Fieid/Pool(s): ADL 25661 & 25650 Kuparuk River Field/ West Sak Oil Pool 11. Present Well Condition Summary: ~ ~o~Q1J Total Depth measured ~4gQ~2 ~ feet ~ true vertical :"~5~ ~'~ ~ 8 feet ~ Plugs (measured) 10235 Effective Depth measured 12907 feet Junk (measured) true vertical 3590 feet Casing Length Size MD ND Burst Coilapse Conductor 108' 20" 108' 108' Surface 2259' 10-3/4" 2368 2194' Intermediate 6241' 7-5/8" 6356' 3650' Production 7360' 4.5" 12840' 3716' Perforation depth: Measured depth: 6360'-8697', 8945'-10031', 10648'-10710', 10990'-12808' true vertical depth: 3650'-3656', 3662'-3712', 3678'-3669', 3652'-3716' Tubing (size, grade, and measured depth) 4.5", L-80, 4085' MD. Packers & SSSV (type & measured depth) ~(P pkr 4904' No SSSV 12. Stimulation or cement squeeze summary: intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oit-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to weil operation 979 313 14 575 198 Subsequent to operation 1387 138 1249 868 251 14. Attachments . Welt Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations X . Well Status after proposed work: Oii^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N~a if C.o. Exempt: N/A Contact B. Christensen/ D. Humphrey y ritie Production Engineering Specialist Printed Name Darrell R. Hu ~ Signature ~l~~ ~ Phone: 659-7535 Date `~ ° ~ ~ • ~~ ~~Ui~~-~ l(y( ~3(~ ~ !o-LS_oR Submit Oriqinal Only '! • ~ ~•s 1 J-166 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/20/09 PULLED ISO SLEEVE FROM B-LEM @ 5390 CTMD, SLEEVE HUNG UP IN D-LEM, HIT 9 JAR ~ICKS TO FREE UP, JOB COMPLETE. ~ + ConocoPhillips At2Sk~3. IrIC. CONDUCTOR i~~ia~ea, 30.108 NIPPLE,503 HEATTRACE, GAS CS4 s---~~ KUP all Attributes IDora APINWI Fleltl N 500292329100 WESI ent SV: NIPPIE 1 J-166 Last Tag: Rev Reason: PULL ISO SLEEVE IN L1 Imasbor 10/1/2009 Casln Strtn s Caeing Descrlption String 0... String ID ... Top (F[KB) Set Depth (f... Set DepM (TVO) ... String Wt... String ... String Top Thrd CONDUCTOR 20 15.250 30.0 108.0 708.0 62.50 H-40 WELD Insulated Casinp Descrlptlon String 0... Strlnp ID ... Top (ffKB) Set Depth (f... Set DepM ~TVO) ... String Wt.. Strlnp ... S[ring Top Thrtl SURFACE 103/4 9.794 30.1 2,368.4 2,194.1 45.50 L-80 BTC atlnp Descrlptlon 3[rlnp 0... S[rlnp ID ... Top ~Itl(B) Sat Depth ~f... Set ~eplh ~TVU) ... String Wt... Strinp ... Strlnp Top T~rtl INTERMEDIATE 75/8 6.875 26.4 6,350.0 3,648.6 29.70 L-80 BTCM Ca~ing Dotcrlptlon String 0... S41np ID ... Top ~Po(B) Sat Dapt~ (1... Set Oepl~ ~TVD~ _. String Wt... String ... S41ng Top ThtC Windaw 0.SAND 6 7/8 5,005.0 5,046.0 3,424.0 Gsing ~eacriptlon String 0... String ID ... Top (!tl(e) Set OepN ~1... Set Oapl~ (ND) ... S6ing Wt... Strinp ... String Top T~rd Window 8-SAND 6 7/8 5,380.0 5,422.0 3,503.0 Ca~ing Oescription String 0... String ID ... T op (RNB) Set DapN ~/... Sat Depth ~ND~... String Wt... String ... String Top Thra LEM 0.SAND 4 1/2 3.958 4,885.0 5,137.0 3,443.4 12.60 L-80 IBT Caaing ~escripdon String 0... String I~ ... Top (ltHB) Set OepN ~f. Set DepN ~TVD) ... String WL.. String ... String Top ThrO LinerA-SAND 41/2 3.958 5,480.0 12,840.0 3,7172 12.60 L-80 IBT Llner Detaiis Top Oepth (TVD) 7op Incl .......~y..~o...~r.~.... .....~.y..... ....~..y~..... ~..y~~.,..,~ ..Q...~y.~~~~.....~...~y.~~~~...~... ~.,~~~y...... ~.~~~~y... ...~~~~y ~..y~~~i~ TUBING 41/2 3.955 22.4 4,922.0 3,397.8 12.60 L-80 IBTM Com IeUon Detaits Top Depth (T~D) Top Incl Top (~~8~ (RNB) (°) ~psm De~crl0tlon Commenl 10 (inl Top (ftNB) 1~~^~I l"1 Deacrtption Comment Run Date ID ~1n~ 10 10.0 -0.09 HEATTRACE HEATTRACE 5/17/2008 0.000 Perfora tlons 8 Slots Shot 7op ~ItNB) Btm (ftN8) Top (TVD) (RI(B) Btm (TV~~ (RNB) Zona Data Dena (sh~~~ Type Commont 6,360 8,698 3,649.9 3,655.8 WS A2, A3, 1/19/2006 32.0 Slots Altemating slotted/blank pipe 0.725" x 1J-166 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,945 10,031 3,660.8 3,710.3 WS A2, 7J-166 1/19/2W6 32.0 Slots Altemating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers stapgered 18 deg., 3 ft. non-slotted erWs 10,648 10,710 3,678.5 3,669.2 WS A2, iJ-168 1/19l2006 32.0 Slots Altemating slotted/blank pipe 0.125' x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotled ends 70,990 12,808 3,6522 3,715.9 WS A2, 7J-166 1l19/2006 32.0 Slots Altemating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends ~ U@Id118 -: ' ~, '~' - Top Depth Top Port (TVD) Incl OD Valva Latch Size TRO Run Stn Top (!tl(B) (kKB) (°) Make MoOel (~~) Serv Typa Type (In) (psi) Run Date Com... • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 07, 2009 7:50 AM To: Dave Roby; Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: FW: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1 E-102 & 1J-170L1 Attachments: Picture (Metafile); Picture (Metafile) Dave, et al, Here is some information regarding a call I got yesterday on MBE events and isolations in these segments. Have the sundries to convert been approved? Tom From: NSK Prod Engr Specialist,[mailto:n1139Ca~conocophillips.coml Sent: Tuesday, October 06, 2009 5:28 PM To: Maunder, Thomas E (DOA) Cc: Hollar, Eric Andrew; Pierson, Chris R; NSK Well Integrity Proj; NSK Prod Engr & Optimization Supv Subject: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1E-102 & 1J-170L1 Tom, As the startup of the Wsak VRWAG Pilot Project approaches (estimated commencement date of 11/15/09), I have been asked to review the 10-403 Sundry applications submitted in February of this year. Below are the records pertaining to zone isolations due to Matrix Breakthrough Events (MBE) on wells 1 E-102 and 1J-170L1 that were not included in the 10-403 submittals. a o~-a~c~ Well 1 E-102 MBE to offset Producer 1 E-121. Date Well 1 E-102 PTD# 204-231 10/25/2006 BRUSH DB NIPPLE @ 6060' RKB. SET 3.562 DBP PLUG @ 6060' RKB. SET P-PRONG INSIDE DB PLUG BODY @ 6060' RKB (1 3/8 FISH NECK-43" OAL ). (( B-SAND IS ISOLATED )). JOB COMPLETE. Well 1J-170L1 MBE to offset Producer 1.1-.166 ~QS-~~C:~~ Date Well 1J-170L1 PTD# 206-063 8/10/2008 PULL B-SAND DIVERTER AND SET B-SAND ISOLATION SLEEVE AT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED. HIPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE SET. Please provide direction as to what is needed to move the process forward. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. Con ~ . . ocoPhsllips Alaska P,O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • aos-I~g I~/ 6 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl7, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n.,~,. ~~~~ Well Name TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-18A 204-167 15' S" 2.50 44" 10/30/2008 27.2 11/7/2008 1E-168 204-200 15" NA 15" NA 3.4 11/7/2008 1E-17 205-074 13" NA 13" NA 5.53 11/7/2008 1J-12a 207-070 15" NA 15" NA 3.4 11/7/2008 1J-14 200-200 16" NA 16" NA 1.27 11/7/2008 1J-152' 206-016 3' NA 3' NA 19.55 11/17/2008 1 J-158 207-054 6' NA 6' NA 27.2 11 /7/2008 1J-162" 2 7-080 15" NA 15" NA 2.55 11/7/2008 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1J-168 205-060 10" NA 10" NA 3.82 11/7/2008 1J-170 206-062 8" NA 8" NA 1 11/7/2008 1 J-174 207-143 24" NA 24" NA 17 11 /7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 • Page 1 of 2 Maunder, Thomas E (DOA) From: Schwartz, Guy L [Guy.L.Schwartz@conocophillips.com] Sent: Friday, September 19, 2008 8:27 AM ~ a ~ S ~ `~~ To: Maunder, Thomas E (DOA) Subject: RE: 1J-166L1 (205-199) Attachments: 1 J-166 A2 Lat Blank- Slotted Liner detail.xls; 1 J-166 B Lat Blank- Slotted Liner detail.xls; 1 J- 166 D Lat Blank- Slotted Liner detail.xls Here is the liner details... let me know if anything else is needed! Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.I.schwartz@conocophillips.com ~~~~E~ ~~~ ~;: is ~~~i From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, September 19, 2008 8:10 AM To: Schwartz, Guy L Subject: RE: 1J-166L1 (205-199) Guy, Thanks for the information. Yes, would you please send the finer detail and for the other legs as well. I do think it is appropriate to have sent the 404. Having information on potentiaE remedies for MBEs is important. It all goes to maintaining the best available well file possible. Call or message with any questions. Tom Maunder, PE AOGCG From: Schwartz, Guy L [mailto:Guy.L.Schwartz@conocophillips.com] Sent: Thursday, September 18, 2008 4:48 PM To: Maunder, Thomas E (DOA) Subject: RE: 1J-166L1 (205-199) Tom, We have swell packers staged (in some of the blank pipe sections) in the well to give us some options of shutting off part of the well. Thus we set a IBP in a blank section to isolate the lower section from a MBE breakthrough (ie water !!). It seemed to work great.... The B lateral has .125" slotted liner alternating with blank sections. I could forward the liner detail if you want it. the key though is that we ran swell packers too. Good thing in this well as it allowed us to shut off a lower water 9/19/2008 source. • Page 2 of 2 Let me know if this is enough info... I wasn't sure if we needed to send a 404 in as this is a retrievable plug. But in this case we would like to make it at least permanent for the short term. Could be in there for a while!! Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.I.schwartz@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, September 18, 2008 4:13 PM To: Schwartz, Guy L Subject: 1J-166L1 (205-199) Guy, Could you enlighten me a little on this RBP work? Is there an MBE contributing water? Also, looking at the 404, long perforated intervals are listed. Does the liner alternate slotted and solid sections? On the 404 they are listed as perfs. Thanks in advance. Tom Maunder, PE AOGCC 9/19/2008 • • 1J-166'A2' Sand Liner Detail well: 1J-166 Cc~ncxoPhillips 4-112" Slotted and Bank Litter t~1' (7' Date: 111912006 Alaska, lnc. ~vJ , ~, ~s DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS -~ - - 4" DP to Surface =_> 5466.91 _ 5466.91 5466.91 Crossover 4" XT~9 Box x 3-1/2" IF Pin 1.66 5466.91 Liner Runnin Tool 5" Does not sta in hole 11.45 5468.57 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 19.02 5480.02 "RS" Packoff Seal Ni le 5.5" 2.84 5499.04 FlexLock Liner Han er 5.5" X 7.6" 9.82 5501.88 190-47 Casin Seal Bore Ext. 4.75"ID x 6.25" OD 19.68 5511.70 XO Bushin 3.92" ID, 6.02 OD 1.39 5531.38 Pu Jt. - 4-1/2" BTCM 12.6 f, L-80 3.78 5532.77 2 Pu Jts. - 4-112" BTCM 12.6 f, L-80 9.91 + 9.93 19.84 5536.55 Jts 211 to 236 26 Jts 4-112",12.6 f, L-80, IBT Blank Casin 803.33 5556.39 Jts 135 to 210 76 Jts 4-1/2",12.6 f, L-80, IBT Slotted Casin 2337.82 6359.72 Jts 127 to 134 s Jts 4-1/2",12.6 f, L-80, IBT Blank Casin 247.75 8697.54 Jts 92 to 126 35 Jts 4-1/2",12.6 f, L-80, IBT Slotted Casin 1085.82 8945.29 Jts 72 to 91 20 Jts 4-1/2",12.6 f, L-80, IBT Blank Casin 616.98 10031.11 Jts 70 to 71 2 Jts 4-112",12.6 f, L-80, IBT Slotted Casin 61.79 10648.09 Jts 61 to 69 9 Jts 4-1/2",12.6 f, L-80, IBT Blank Casin 279.77 10709.88 Jts 2 to 60 59 Jts 4-1/2",12.6 f, L-80, IBT Slotted Casin 1818.03 10989.65 Jts 1 to 1 1 Jts 4-112",12.6 f, L-80, IBT Blank Casin 31.02 12807.68 ROT Silver Bullet Guide Shoe No float 1.30 12838.70 Bttm of Shoe 12840.00 TD 6 3/4" hole 12,853' MD, 3,723' ND 7- 518 Shoe 6,350' MD/ 3649' ND 'oints 1 thru 135 Total of 129 No S iral liders ran on ~ts with Constrictor ackers Total of 6 Constrictor Packers at: 10,970', 10,725', 10,645, 10,045', 8,940', 8,720' Ran total 64 jts Blank 19 77.60' (Inc.shoe 't) and 172 'ts Slotted 5314.80', Slots are U Wt 180K w/ 32 2.5" Ion x .125" 4 Circumferential ad'acent rows, 3" Centers Dn Wt 60K sta ered 18 de ., 3 ft. non-slotted ends. Block Wt 35K Used Run-N-Seal thread com ound on all connections. Drifted Casin to 3.833" w/ teflon rabbit. Supervisors: Dear/ Gladden /Zane Kuenzler/Dave Egedahl • ~fV~L~ ~41i~ . ,~ v_.______.__ ,,. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and a p5 -l4'~f ~ I (o~s~ ProActive Diagnostic Services, Inc. "~~ ~o~-v« ~I(on'~2 Attn: Robert A. Richey 130 West International Airport Roa Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Production Profile 02-Ju1.O8 1 J-152 aLr EDE 2) Production Profile O3,JuFO8 1 J-166 p~ E~ Signed : ~~ Date Print Name: ,~ ,~ ; 5-E-t ~ ~e ~ ~ ~ ~,~ o~~ 50-029-23298-00 50-029-23291-00 PROACTNE DIAGNOSTIC SERVICES, INC., 1.30 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907j245-88952 E-MAIL : ~sanchar~ge(a(a~l~ernarylag.carra WEBSITE : mvww.l~er~arylag.car~a C:\Docoments and Se[tings\Owner\Desk[op\Truumit_BP.doc ~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # c~~d~0®719~br JU~ S ~ ~~U~ Log Description N0. 4732. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suites 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 05/30/08 iF-04 11964615 INJECTION PROFILE L+ / a ( 05/26/08 1 1 3F-10 11964609 PRODUCTION PROFILE - ~ j~ 05/23/08 1 1 1J-101 11970685 GLS C C 05/23/08 1 1 iJ-166 11970681 GLS / 05/20/08 1 1 2N-306 11964608 INJECTION PROFILE ~.(U (~ 05/22!08 1 1 3K-13 11970688 INJECTION PROFILE ~ 05/26/08 1 1 iB-08A 11970686 INJECTION PROFILE I ~ -r ( 05/24/08 1 1 1Y-11 11964613 INJECTION PROFILE (tj - /(B~G} 05/25/08 1 1 3K-19 11964616 INJECTION PROFILE U"' - f1 05/27/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Page 1 of 2 ~ ~ Il~aunder, ThQm~s E (DC~A) From: Pack~r, J.Brett [J.Bre#t,Packer~c4npcophillips.comj Sent Wedn~sday, May 28, 2008 2:39 PM Ta: Wlaunder, Thomas E (DOA) ~,~~~,~~~ ,~~,t~l ~& ~~~~~~, Subje~ct: RE: 1J-166 (205-198}, et ai - again Tom, '1J-'1C6 {PTD# 205-198) was originally completed as a thru-tubing conveyed ~SP praduc~r. Unfor~unately, due to the wellbore deviation and dogleg severity, we were never able to dummy drift the tubing to the pump setting depth, thus a pump was never run. So, from day one, the well had been on c~as iift. On '12131107, we saw a significant increase in wellbore fluid temperature, indicating a breakthru event or MBE {matrix bypass event) as we have sesn an many West Sak producers where fhere is direct communication from the i,-~jectar and si~nificant water bypass. With this matrix bypass comes a bunch of sand aiso, therefore, production goes down. That was the reason far #he workover; to pu!! the ESP motor, cleanout the we!!, anri re-compie#e st as a gas !ift prodvicer so that we have access wi#h coiled tubing to cleanout the laterals. The v~orkover wen# well, ths weli was averbafanced with 8.6 PP9 seawater, in fact, during the clean~ut, it was taking fluid like crazy, we were only seeing 10% returns. We installed a gas lift compfet+on, and tested the lA to 1000 psi for 30 min. This pressure test may be a!it#le low compared to aur narmal casing test, but 1 was afraid to test tao high due ta the possibility of shearing the SOV early. The SOV in the well was rated to shear a# 200Q psi differe~tial, but often we've seen them to shear anywhere betwsen ~ 500 - 2500 psi clif#erential. That is the reason I went with a 1000 psi casing test. ~n typical gas lift re-comple#ions, we wii! have a piug set downho{e, and will pressure up the tubing to 2540 psi, monitor the annulus, then bleed the tubing of# to 1750 psi_ Whi1e holding 1750 psi on the tubing, we'll pressure test the IA to 2500 psi and chart it for 30 min. Tt~is way we'd get a 2500 pss #est on the casing uvhile s#+fi maintaining only 750 psi differential on the SOV. Once the casing test is complete, we would bleed the tubing off until tt~e ~OV shears. 1 J-166 was different because we did not have a plug set downhoie, thus we could not pressure up the #ubing to apply back pressure on the SOV. P{ease let me knaw if theee are any reguiati~ns regarding casing pressur~ test sequirements, as ! migh# be misinformed of any actual requirements. I searched through the AOGCC website looking for casing pressure test requirements, but did not #ind anything. I've heard the rule-of-thumb #hat vue need to tes# #o a minimum of 25°l0 of the ND of the we9l, but I'm not sure if that +s an in-house rule-of-thumb, an AOGCC regulation, or if somebody just pu!!ed that number out of the air. But based on that, tt~e ND of this welf is 3718 ft, and 25°!D wauld be 930 psi, thus 1 figured 1000 psi would be adequate. vome #o find out, we could have tested this casing ta 2500 psi, due to tt-e SOV not shearing at a19. Our normal procedure on we!!s without a plug in the tubing tail, is to ramp up the IA pressure until the SOV shears, which we fulfy expected ta be at 200Q psi. Consequent{y, we went as high as 350(} psi uri#houf any {uck. Come to find out, they had installed the wrong SOV. lnstead of a csg-to-tbg shear differential, ti~ey had installed a tbg-to-csg shear i~ifferential, and we would have never sheared that SOV. Thus, we had to get slickline aut there #o pu11 that SOV so we could have a circulation point and freeze protect the welt. We weren't terribly concemed about going up to 3500 psi, knovsring that the burst rating of the 7-518" casing is E890 psi anti the coiiapse rating of the 4-1/2" tubin~ is 7500 psi. i hope this clarifies the operations and thoughts behind it. The well is currently making about 925{~ bopd on gas lift, but if needs be, we can shut it in and test the casing again. Please advise. ~ ~recc ~ckgr ~&ttg sZ `WedXc RNarkover~nyineer 8/6/2009 Page 2 of 2 ~ ~ork# 265-6845 Ce~'# 23U~-83T7 From; Maunder, Thomas E (DlJA) [mailtc>:tom.maund~ra~alaska.gs~vJ ~ent: Sunc#ay, M~y 25, ~OQ8 12:U8 RM To: Packer, ~.Brett Cc: Allsup-Drake, Sharon K Subject: RE: 1J-166 (205-198), ~t ai - again Ft~am: Maunde~, Thomas E (DOA) Sent: Sunday, May 25, 2008 11:58 AM TQ: Packer, J,Brett Cc. Atksup-~r~ke, Sharon K Subj~ct: iJ-166 (205-i98), et ai ~ Brett, I am reviewing the 4p4 recently submitted for the workover performed in April. 1 S4'f3 th~' C1GW GQtl1p~G'tFQCI IS ~~~ Itfh, r'~placing the origin~! ESP com~ietion. As t~heck~d our produetion record, it indicates fihat al1 praduction from the vuell was via gas lift. Is this correct? Did the ESP ever run~ Thanks in advance f4r IQ~king in to this. Cail or message with any questions. Tom Maunder, PE AOGGC 8/6/2009 ~~~~~ Y ~~ ~ STATE OF ALASKA • MAY 2 0 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOI~~~`~ ~`~ & aa~~ aoe~ommissiar~ 1. Operations Performed: Abandon ^ Repair Well 0 ~ Plug Perforations ~ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing 0 • PerForate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, 111C. Development ~• Exploratory ~ 205-198 /` 3. Address: SVatigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23291-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' . 1J-166 ~ 8. Property Designation: ~ 10. Field/Pool(s): ADL 25661 & 25650 ~ Kuparuk River Field / West Sak Oil Pool • 11. Present Well Condition Summary: Total Depth measured 12853' • feet true vertical 3718' • feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2259' 10-3/4" 2368' 2194' INTERMEDIATE 6241' 7-5/8" 6356' 3650' PRODUCTION 7360' 4.5" 12840' 3716' Perforation depth: Measured depth: 6360'-8697', 8945'-10031', 10648'-10710', 10990'-12808' true vertical depth: 3650'-3656', 3662'-371 2', 3678'-3669', 3652'-3716' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4922' MD. Packers & SSSV (type & measured depth) Zxp pkr @ asoa' no SSSV 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-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 1529 ~ 1059 2707 -- 251 94. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ' Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer Printed Name Brett PackerM~~~ Signature /~~~,~ Titie Phone: 265-6845 Wells Group Engineer l Date .~/~Z~~~ P ared b~haron Alls D k 263-4612 ~,1 ~ ~'a~' °~ Form 10-404 Revised 04/2006 ~ R' ~ ~ ~ ~ ~ ~~' ~'~~' ~ ~ ~~~~ ~~'r ~°~bmit Or' ' n f : ~~~~~ ~ _, ~ ~ , ~~~~aa~~~~~~p~ A~~ask~, ~~~, KRU 1 J-166 Ca-nc~coPhillips WeJN7ew Web ReportJng Time Log Summary Well Name: 1 J-166 Job Type: RECOMPLETION .: ~~.~~~. `~: ~ ~ ~; ~~~ .. ~~ ~~ ~~.... ~~~ .~ ~~, ~tY~CTi TL~ ';~i~'~y ~~. \` ~ \~~ ' ~ ~~ Ra,.. \ '~ \ ~~ ~.-:. 04/10/2008 00:00 01:30 1.50 COMPZ MOVE MOB P Nordic 3 Pulled off of 1J-135 and clean u ceilar and tree. Move ri to 1J-166. 0130 02:00 0.50 COMPZ MOVE PSIT P Spot and level rig. Set up handi berm. 02:00 05:00 3.00 COMPZ RPCO OTHR P Take on 600 bbls of hot 6% KCL fluid. Load lubricator in pipe shed and (~-~~icate BPV from well. Tie into tree and IA. Open up well: 450 psi tbg, 700 si IA, 500 si OA. 05:00 09:00 4.00 COMPZ RPCOh OTHR P Vent gas off of well to Tiger tank. Shut down to reconfigure Tiger tank for Simm Ops on 1J-10. PT line to tiger tank to 2500 si. 09:00 11:00 2.00 COMPZ RPCOh CIRC P Reverse circulate 340 bbl of 8.4 ppg 6% KCL @~110 deg. Inital tubing press = 330 psi, initial IA press = 680 psi. Tubing and IA press at 0 psi after circulating. 340 bbl of returns to the ti er tank. 11:00 17:30 6.50 COMPZ RPCO NUND P Install BPV, ND tree, NU BOPE. Install blankin lu . 17:30 22:30 5.00 COMPZ WELCT BOPE P Test BOPE 250/2500 si. Test Annular @ 250/2,500 psi. 24 hr Notice was given @ 19:00 hrs on 4-9-08 to AOGCC and witness of test was waived by Chuck Scheve @ 14:00 hrs on 4-10-08. 22:30 00:00 1.50 COMPZ RPCO OTHR P Pull blankinq pluq and BPV. RU ESP E ui . 04/11/2008 00:00 01:30 1.50 COMPZ RPCOti OTHR P Continue to RU ESP Equip. Install Landin Jt. BOLDS. 01:30 02:00 0.50 4,083 4,078 COMPZ RPCOh OWFF P Unland hanger @ 150k• Pull inner hanger above Outer Hanger w/ 130k u wt. Monitor well for flow/Good. 02:00 02:30 0.50 4,078 4,025 COMPZ RPCOh OTHR P Continue to Pull hanger to floor and cut ESP cable below splice. Lay down landing jt. Lay down Hanger and 't. 02:30 11:30 9.00 4,025 4,025 COMPZ RPCOh OTHR P String ESP cable over sheave and tie ! into s ool. POOH 11:30 14:00 2.50 4,025 0 COMPZ RPCO PULD P La down ESP com letion. Recovered all clamps and bands: 68 cannon clamps, 3 protectolizers, 2 flat guards, 4 SS bands. Load out ESP com letion. 14:00 14:30 0.50 0 0 COMPZ RPCOh OTHR P Clean rig floor. , r ; .~ ~~~~~~ ,~~~~ ..i, .~,'~.~.,~. ~ ~'a, . ~~ \ ., ` ..,,~~...:. .:~~ ~ : ......~\ ~ ~ ¢~ F~.E a3~. ~.. ~ \ ~ •#~~4 ~.~r ~rl~ ~ -~ ~ \ r~4^ ~M~~~ ~ ~~~ 04/11/2008 14:30 19:00 4.50 0 189 COMPZ RPCO PULD P PJSM. Picking up cleanout BHA with down 'et and side wash nozzles. 19:00 23:00 4.00 189 4,000 COMPZ RPCOti TRIP P RIH with cleanout assy on 31/2 DP work string. Drifting to 2.38" and filling DP every 10 stands to keep from pulling in trash thru wash nozzies. F! 189' to 4,000' 23:00 00:00 1.00 4,000 COMPZ RPCOh CIRC P Screw in TD and Break Circulation. Circulate Bottoms Up @ 4 bpm @ 1,500 psi while recipricating the DP. 76k u wt, 70k dn wt, 35k block wt 04/12/2008 00:00 01:30 1.50 4,000 4,256 COMPZ RPCOh CIRC P Continue to circulate down Cc~ 4 bom @ 1,500 psi from 4,000' to 4,256' and lost circulation. 01:30 06:30 5.00 4,256 5,140 COMPZ RPCOh CIRC P Continue to circulate down @ 4 bpm @ 1,500 psi from 4,256' to 4,143' w/ lost circulation, filling IA w/ trip tank. Able to identi the to SBE 5 1 2' and was onl able to et down to 5 143' . 8' inside of 20' seal bore. Total fluid loss a of 744 bbls to the well formation. 06:30 10:00 3.50 5,140 189 COMPZ RPCOh TRIP P Decision was made to Pooh and drop the upper lateral nozzle. Run back in and attempt to get more jetting action thru bottom noule and finish cleaning out to bottom of SBE. Pooh f/ 5,140' to 189'. dis I.x3 10:00 11:30 1.50 189 0 COMPZ RPCOh PULD P Breaking back clean out run BHA #1. Removed side wash nozzle. Inspected bottom down wash nozzle. Ran bottom nozzle below well floor and visually observed jetting action. MU clean out run BHA #2 without the side'et nozzle. dis I.x3 11:30 14:30 3.00 0 5,100 COMPZ RPCOh TRIP P RIH with clean out BHA#2. Filling drill i e eve 5 stands. Dis I. x3 14:30 15:30 1.00 5,143 5,143 COMPZ RPCOh CIRC P Make up top drive start pumping 4 bpm @ 2300 psi. Up wt = 85K, Dn wt = 74K. Sat down 10K, hard tag at 143' (same depth as clean out run #1 no pump pressure increase. Continue to circulate, only 10% returns. Indications are that BHA is no- oin on bottom of the SBE. 15:30 16:00 0.50 5,143 5,143 COMPZ RPCOti OTHR P Blowing down top drive, monitorwell. 16:00 19:00 3.00 5,143 189 COMPZ RPCO~ TRIP P POOH to the clean out BHA #2. Dis I.x3 19:00 20:30 1.50 189 0 COMPZ RPCOh PULD P Lay down Clean out BHA Displ.x3 20:30 21:00 0.50 COMPZ RPCOh OTHR P Clean and Clear Rig floor. 21:00 21:30 0.50 COMPZ RPCO SFTY P Held PJSM w/ MWD, Completion Hand and rig crew on picking up and makin u LEM Bha. J--~ 1a~E~~~ 04/12/2008 21:30 00:00 2.50 0 362 COMPZ RPCO PULD P PU and rih w/ LEM assy. PU and MU MWD assy and Rih to 362'. Dispi.x3. Total BBLs lost since 06:00 hrs was 493 bbls to the formation. Total BBLS lost to the formation in 24 hrs was 1 237 bbls. 04/13/2008 00:00 01:00 1.00 362 362 COMPZ RPCOh OTHR P Shallow test MWD @ 150 gpm @ 350 si. Shallow test ood. 01:00 08:00 7.00 362 COMPZ RPCOh RCST P Continue to RIH w/ LEM assy. Displ. x3. Orientate LEM at 19R at 4800' continue in hole. Ran into D lateral at 5023'. Puil up hole and rotate. New LEM orientation is 140R. Continue to RIH. 08:00 10:00 2.00 COMPZ RPCO RCST P Up wt = 85K Ibs, Dw wt = 74K Ibs. Intially stabbed into the B-Sand Lateral SBE at 5123'. Down weight dropped to 70K Ibs while running into the SBE. Sat down with 20K Ibs at 5137'. Orientation went from 140R to 37R. Picked up to 15K Ibs over string wt. insuring that the LEM was latched in @ 5,002'. Sat back down to neutral wei ht. 10:00 11:00 1.00 COMPZ RPCOti PACK P Drop bail and sit down 20K Ibs. Pumping down drill pipe and pressuring up. Observed indication of packer set at 1950 psi w/ Top of D-Sand Lateral Tie back Ext. 4 883' w/ To of SBE 4,902' and Bottom of SBE 4,922'. Continue to pump and pressure up. Observed indication of neutralizing the pusher tool at 3200 psi. Pressure up to 3600 psi, bleed off. 11:00 12:00 1.00 COMPZ RPCO DHEQ P PJSM. Pressure test IA to 2500 psi for 5 min bleed down. Close annular bag and pressure up IA to 500 psi. Pull out setting tool with 95K Ibs, IA pressure dropped to 0 psi after 6ft. O en ba , ri down test e ui ment. 12:00 19:30 7.50 5,106 1,900 COMPZ RPCOti TRIP P POOH (initial up wt = 85K Ibs). Dis lacin x3. 19:30 22:00 2.50 1,900 1,900 COMPZ RPC06 OTHR P RD and remove ESP Spooling unit, Load Heat Trace Spool w/ crane. Clear Pipe shed of un needed materials. 22:00 23:30 1.50 1,900 11 COMPZ RPCO TRIP P Continue to Pooh f/ 1,900' and lay down drill i e. 23:30 00:00 0.50 11 0 COMPZ RPCOh PULD P Break down and lay down Hydrualic i setting tool. Total fluid lost to ' ormation in this 24 hr eriod was 464 ' 04/14/2008 00:00 01:00 1.00 0 0 COMPZ RPCOh OTHR P Un-load pipe shed of un-needed e ui ment. 01:00 04:30 3.50 0 0 ICOMPZ RPCOh OTHR P Load pipe shed w/ 4 1/2 Completion ~ ~ 04/14/2008 04:30 07:30 3.00 0 96 COMPZ RPCOh SFTY P Heid PJSM w/ crew and third party contractors on Rih w/ 4 1/2 Com letion. MU Guardian ua e. 07:30 11:30 4.00 96 1,877 COMPZ RPCO RCST P RIH with 4-1/2 completion with TEC wire. 11:30 12:30 1.00 1,877 1,877 COMPZ RPCOh PULD P Crew change, PJSM. Rig up equipment to start running heat trace cable. 12:3Q 00:00 11.50 1,877 4,418 COMPZ RPCOh RCST P RIH with 4-1/2' gaslift completion with . TEC wire and heat trace cable. 04/15/2008 00:00 02:30 2.50 4,418 4,924 COMPZ RPCOh RCST P Continue to Rih f/ 4,418' to 4,924' w/ 4 1/2 Gas Lift Completion. Tag w/ 24.5' in on 't 157. 82k u wt 74k dn wt. 02:30 03:00 0.50 4,924 4,924 COMPZ RPCOh DHEQ P Fill IA w/ 10 bbls. PT to 500 psi for 5 minutes. Bleed off. 03:00 03:30 0.50 4,924 4,841 COMPZ RPCOti HOSO P Pooh and lay down jts - 157,156,155. 03:30 04:30 1.00 4,841 4,898 COMPZ RPCO HOSO P Rih w/ 3 pup jts = 25' and 1 jt w/ han er. 04:30 0930 5.00 4,898 COMPZ RPCO OTHR P Make Final spice w/ heat trace and I tec wire. Test heat trace - good. Trouble shoot I tec wire - connection roblems. Test ood. 09:30 10:30 1.00 COMPZ RPCOh CIRC P Reverse circulate w/ 130 bbls of 6% KCL w/ 1% b Vol. CRW-132 10:30 11:00 0.50 4,922 COMPZ RPCOti HOSO P Drain stack and land hanqer. RILDS. w/ 3.875" DB Nipple @ 503', GLM #1 @ 2,572' to 2,579', Heat trace starting @ 3,046', GLM #2 @ 4,320 to 4,327', 3.812" ID Sliding Sleeve @ 4,832', Guardian Gauge @ 4,842', Bottom of seals @ 4,922', ZXP Pkr @ 4,885' to 4,904', SBE @ 4,904' to 4,924', 3.75" DB Nipple @ 4,959', Bottom of non locating seals @ 5,137' placed in B Lateral SBE @ 5,123' to 5,143'. Ran 10 - SS Bands, 478 - 5' Clamps, 3- 2' Clamps, 2- 3' Clamps, 1- End Shoe ' and 60 X- Cou lin Clam s. 11:00 12:30 1.50 COMPZ RPCOh DHEQ P PT IA to 1.000 qsi for 30 min. and Iiait, PT Upper/Lower tbg hanger void @ 5,000 psi for 10 minutes. Attempt to shear SOV @ 4,316' @ 2,000 psi - no shear - Pressure to 3,500 si - no shear. 12:30 14:00 1.50 COMPZ RPCOh WOEL T Wait for HES slickline unit to RD off of 1J Pad well and move to 1J-166. 14:00 15:00 1.00 ~COMPZ RPCOh SFTY T Held PJSM w/ crew and RU Slickline. 04/15/2008 15:00 23:30 8.50 COMPZ RPCOti SLKL T Rih to puil SOV @ 4,316. Unable to locate GLM, Rih to 4,340' SLM and couldn't locate. Pooh 4,340'. Decide to Pump diesel down tbg, RU LRS and change in operation. Attempt to locate equipment needed for lubricator - No 4 1/2 full open valve available for well control purposes as well would be of balance when SOV was pulled. RU Slickline again and make attempt w/ no luck, Pooh and redress tools. Rih and attempt to pull dummy valve out of Upper GLM @ 2,568' w/ no success after multi le attem ts. 23:30 00:00 0.50 COMPZ RPCOti OTHR T RU to displace tbg volume w/ 6% KCL 04/16/2008 00:00 00:30 0.50 COMPZ RPCOh CIRC T Pump 100 bbls 6% KCL down tbg @ 5 bpm @ 410 psi. Shut down and ressure bled to 0 si. 00:30 02:30 2.00 COMPZ RPCO SLKL T Rih w/ slickline to 4,400' and pick up to 4,316' and latch on to SOV and recover. Pooh and RD Slickline. 02:30 03:00 0.50 COMPZ RPCO OTHR P Set Two wa h k. 03:00 06:00 3.00 COMPZ RPCO NUND P ND BOPE 06:00 07:30 1.50 COMPZ RPCO NUND P NU prod tree. Tbg hgr will not align with enetrators / tb ad tree ad tr. 07:30 09:00 1.50 COMPZ RPCOh WOOR T Communication with CPAI Anchorage. Decision made to NU BOP, re-align tb h r. 09:00 13:00 4.00 COMPZ RPCO NUND T PJSM, NU BOPE for hgr alignment. 13:00 14:00 1.00 COMPZ WELCT BOPE T PJSM, full body test only (as discussed with Mr John Crisp AOGCC 1100 hrs, 4/16/08) BOPE. 250 / 2500 si. 14:00 16:30 2.50 COMPZ RPCOh HOSO T MU Idg jt to tbg hgr, PU hgr and turn / re-align without aligning pin. Re-test h r ackoff. 16:30 19:30 3.00 COMPZ RPCO NUND T PJSM, ND BOPE. 19:30 21:30 2.00 COMPZ RPCO SFEQ T Install Bonnet and preform final checks on Heat Trace and I Tec Wire. PT void to 5,000 si. 21:30 23:00 1.50 COMPZ RPCO NUND T NU Tree 23:00 00:00 1.00 COMPZ RPCOh SFEQ T Attempt to PT tree to 5,000 psi, Failed attem t- ossible leak in TWC. 04/17/2008 00:00 01:00 1.00 COMPZ RPCOti SFEQ T Make final attempt to test tree against TWC 01:00 02:00 1.00 COMPZ RPCOh OTHR T PU Lubricator and pull TWC and Re lace w/ n 02:00 03:00 1.00 COMPZ RPCOh SFEQ P PT tree 500/5 000 si and chart for 10 minutes. 03:00 03:30 0.50 ~COMPZ RPCOh OTHR P Lubricate out TWC DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2051980 Well Name/No. KUPARUK RIV U WSAK 1J-166 Operator CONOCOPHILLIPS ALASKA INC MD 12853 TVD 3718 Completion Date 2/11/2006 REQUIRED INFORMATION Mud Log No DATA INFORMATI ON Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Typ Med/Frmt Number Name 0 Asc Directional Survey I,~ G 14058~duction/Resistivity Cog 14058 Induction/Resistivity D Lis 13879 vSee Notes Rpt 13879 LIS Verification fPl C Lis i 16074~nduction/Resistivity wog Induction/Resistivity og Induction/Resistivity. Well Cores/Sampl es Information: Name Interval Start Stop ADDITIONAL INFORM~N Well Cored? Y N Chips Received? 'Y~N_ Analysis 1~1.A1--- Received? Completion Status 1-OIL Current Status 1-OIL API No. 50-029-23291-00-00 UIC N Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Scate Media No 25 Blu 25 Col Interval OH / Start Stop CH Received Comments 28 -- 12853 Open 4/17/2006 - - ~ - - -~ 0 12853 Open 8/23/2006 Res, MD Final Print w/Graphics 0 12853 Open 8/23/2006 Res, TVD Final Print w/Graphics ~ 2331 6308 Open 5/10/2006 GR, EWR4, ROP, PWD 2331 6308 Open 5/10/2006 'I 2331 6355 Open 4/2/2008 LIS Veri, GR, RPD, RPM, 219 25 Col 219 Sent Received Daily History Received? Formation Tops RPS, FET, ROP 6355 Open 4/2/2008 MD ROP, DGR, EWR 14- Jan-2006 6355 Open 4/2/2008 TVD ROP, DGR, EWR 14- Jan-2006 I _..__ -_J Sample Set Number Comments ~1J~^NV ~' 1 Comments: DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2051980 Well Name/No. KUPARUK RIV U WSAK 1J-166 Operator CONOCOPHILLIPS ALASKA INC MD 12853 ND 3718 Completion Date 2/11/2006 Completion Status 1-OIL Current Status 1-OIL Compliance Reviewed By: _____. .__ __ Date: API No. 50-029-23291-00-00 UIC N • WELL LOG TRANSMITTAL To: State of Alaska March 21, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-166+L1+L1PB1+L2+L2PB1 AK-MW-4149018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 J-166+L 1+L 1 PB 1+L2+L2 PB l 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23291-00,60,61,70,71 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23291-00,60,61 Digital Log Images 1 CD Rom 50-029-23291-00,60,61,70,71 Some sections of this well have no TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services app !9 ~ '~ llov~~/ Attn: Rob Kalish ~~j ~q~ ~ t 6d ~S~ 6900 Arctic Blvd. Anchorage,,Alaska 9518 X05 ~6c~ ~ I ~d~~ Date: Signed: r~~'-~ ~t ~ ~'~C'i3 .r , ~ ~~~ r~4~ ~is~,1t 08/22/06 h i Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # R~c~~vE'° AUG 2 3 2006 ~~ = ~q ~ Commission ~ ~~~~ a~c8 t)il & Gas Cons. Anchorage Log Description NO. 3936 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2E-05 11249943 SBHP SURVEY 08/08/06 1 1J-109 11235392 CBL/USIT 08/07/06 1 3Q-11 11213793 LDL 08/14/06 1 2T-28 11235394 INJECTION PROFILE 08/16/06 1 iH-17 11213794 PROD PROFILE W/DEFT 08/15/06 1 1L-22 11235395 INJECTION PROFILE 08/17/06 1 1J-166 40013010 MD VISION RESISTIVITY 01/19/06 1 1 1J-166 40013010 TVD VISION RESISTIVITY 01/19/06 1 i3~9 ., WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-166, ~05~ i g ~ May 3, 2006 AK-MW-4149018 1 LDWG formatted Disc with verification listing. API# : 50-029-23291-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date:_~ `~ Signed: ~ _ `~ ~~~r`~--=~ ~~~ i34s~ • • 02-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-166 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window /Kickoff Survey: 12,791.91' MD (if applicable) Projected Survey: 12,853.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~p,~ Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • ConocoPhillips April 7, 2006 ,~ Commissioner 5 =., ~ ~~ ~~'~~' <~~~~~; ~.a ""., State of Alaska ` ~ ~' ~ , w ;I~EiS:i Alaska Oil & Gas Conservation Commission ~,~~, , , M 333 West 7th Avenue Suite 100 ~"r°~= ~°~ ~r ~~ ~ Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-166, 1 J-166L1 and 1 J-166L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk well 1J-166, 1J-166L1 and 1J-166L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, ~~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad C~ V E~::~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ 0 20C' WELL COMPLETION OR RECOMPLETION REPORT AND L~~~~~..~ 1a. Well Status: Oil Q Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: '`T~"~ Development ^/ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Date Comp., Susp., orAband.: February 11, 2006 ~ 12. Permit to Drill Number: 205-198! 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 8, 2006 ' 13. API Number: 50-029-23291-00 4a. Location of Well (Governmental Section): Surface: 1880' FSL, 2508' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: January 19, 2006 14. Well Name and Number: 1J-166' At Top Productive Horizon: 609' FNL, 818' FWL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 562' FSL, 895' FWL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 12838' MD / 3716' ND West Sak Oil Pool '~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558703 ' y- 5945692 ' Zone- 4 10. Total Depth (MD + ND): ' 12853' MD / 3718' ND ~ 16. Property Designation: , ADL 25661 & 25650 TPI: x- 556724 y- 5948467 Zone- 4 Total Depth: x- 556744 - - 5954918 ' Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 468 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2368' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.58# H-40 28' 108' 28' 108' 42" 367 sx AS t 10.75" 45.5# L-80 28' 2368' 28' 2194' 13.5" 46o sx Class G, 166 sx LiteCRETE 7-5/8" 29.7# L-80 28' 6356' 28' 3650' 9-7/8" 470 sx LiteCRETE 4.5" 12.6# L-80 5480' 12840' 3513' 3716' 6.75" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 4085' 5480' slotted liner from 6360'-8697', 8945'-10031', 10648'-10710', 10990'-12808' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production March 26, 2006 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil -shares production with 1J-166L1 and 1J-166L2 Date of Test 4/5/2006 Hours Tested 14 hours Production for Test Period --> OIL-BBL 2425 GAS-MCF 3054 WATER-BBL 0 CHOKE SIZE 21 % GAS-oIL RaTiO 1303 Flow Tubing press. 520 psi Casing Pressure 1009 Calculated 24-Hour Rate -> OIL-BBL 4104 GAS-MCF 5347 WATER-BBL 1 OIL GRAVITY -API (corr) 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". -- ,; i ~~ ~ ~~~. ~~~ ~. z 2006 NONE = Vc:~)a :~I) ~~ Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~ ~ ~ p~ ~ CONTINUED ON REVERSE ~ ~ ~ ~~.~ za. zs. 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 J-166 West Sak A2 Sand 6374' 3651' Base West Sak A2 sand 12853' 3724' N/A 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: Mike Greener @ 263-4820 Printed Name Rand homas- Title: Greater Kuoaruk Area Drilling Team Leader C„f t' '~ ~~~ Signature - ~-'F'139r~e -Z ~, ~- ~. ~ 3 ~ Date INSTRUCTIONS Prepared by Sharon Allsup-Drake 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 12/2003 ConocoPhillips Alaska Operations Summary Report Pale 1 of 25 Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours ~ Code Code 1/7/2006 112;00 - 14:15 I 2.25 1 MOVE I MOVE 14:15 - 16:15 2.00 16:15 - 20:15 4.00 20:15.- 00:00 3.75 1!8/2006 00:00 - 02:45 2.75 02:45 - 07:00 07:00 - 07:30 07:30 - 08:00 08:00 - 09:00 4.25 0.50 0.50 1.00 09:00 - 09:30 09:30 - 09:45 09:45 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 15:30 15:.30 - 16:15 16:15 - 19:45 19:45 - 00:00 /9!2006 ~ 00:00 - 08:15 ~ 0.50 0.25 2.25 1.00 0.50 2:00 0.75 3.50 4.25 8.25 MOVE MOVE MOVE POSN MOVE MOB WELCT NUND DRILL PULD WELCT BOPE Phase MOVE MOVE MOVE MOVE RIGUP RIGUP RIGUP DRILL PULD RIGUP DRILL PULD SURFAC DRILL OTHR SURFAC DRILL DRLG SURFAC DRILL DRLG SURFAC DRILL DRLG SURFAC DRILL TRIP SURFAC DRILL PULD SURFAC DRILL DRLG SURFAC RIGMNT RGRP SURFAC DRILL DRLG SURFAC DRILL ~ DRLG ~: SURFAC Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations PJSM with crew & Peak Truck drivers. Discuss Safety issues and procedure for rig move. Move Pipeshed modules, Rockwasher, Boilers, Motors and Pit Modules to other side of Pad. Move Sub base from 1 J-101 to spot over well 1J-166. Spot Pipeshed modules, Rockwasher, Boilers, Motors and Pit Modules to Rig sub base. Prepare rig for Acceptance. Install all water, steam, hydraulic and air lines. Continue work on Rig Acceptance checklist. Spot pipe shed tioga, berm & trim herculite liner on rockwasher. Apply steam, glycol & air to lines. Set up pipe skate. Rig up mud pump lines, and install all drain plugs in centifugal pumps. Rig Accepted @ 0000 HRS.1/8/2006 Nipple up Diverter system, & Riser. Continue Load pits with water & mix spud mud. Load pipe shed with 5" DP, and HWDP. Strap same. PJSM with crew. Discuss aSafety issues & procedure to PU 5" Drill Pipe. Pick up 29 joints of 5" HWDP and Drilling Jars, Rack back in derrick. Pick up 45 Joints of 5" DP, and rack back in derrick. Pick up 1 stand of 8" Non Mag flex drill Collars. Pick up 1 stand of 5" DP. Perform Diverter Function test. AOGCC rep Chuck Sheave waived the witness of Diverter Fuction Test. No leaks. Pull all tools to rig floor for BHA #1. Held PJSM. Make up BHA. Make up 13 1/2" Hughes MXC1 bit w/ 3 x 20's & 1 x 13 Jets (1.0'), 8" SperryDrill Lobe 4/5 -5.3 Stage Motor (28.71'), 8" Integral Blade stabilizer (5.57'), and a Bottle neck Crossover sub (2.68'). Make up 1 stand of 5" HWDP. 6 1/4" Jar Hrs to start = 87.10 Flood Conductor and fill all lines. Inspect for leaks. Test mud line to 3000 PSI. Observed NO leaks. Begin drilling ICE from 85' to 108'. Spud well and drill from 108' - 151' (43'). ART = 1.57 HRS. PU WT = 50K, SO WT = 50K, ROT WT = 46K JAR HRS Total = 88.67. Bit HRS Total = 1.57. Continue drill from 151' - 215' MD'(68'). TVD = 219' ART = 1.29 HRS. PU WT = 44K, SO WT = 48K, ROT WT = 46K. Torque = 1 K. Pump out of hole from 219' - 32' (187'). 100 SPM - 424 GPM - 350 PSI. Hang off Sheave & line in derrick for GYRO. RU GYRO E-Line unit. Continue make up BHA. Make up 8" Non-mag Crossover sub (1.65'), 8" Non-Mag Pressure drop sub (1.63'), 8" MPT w/ DIR (25.06'), 8" NON-Mag float sub (2.42'), 8" Non-Mag UBHO Sub (2.94'), 3 - Non-Mag Flex Drill Collars (92.77'), and 5" HWDP back to 215'. Orient MWD & UBHO Sub. Continue Drilling 13 1/2" Surface hole from 215' - 252' (3T). ADT =.67 iRS. TVD = 252'. PU WT = 44K, SO WT = 48K, ROT WT = 46K, with torque at 1 K. Observe failed Saver SUb on Top Drive. 'OOH from 252' - 32' (220'). Blow down all lines, and Top Drive. Change out & inspect top drive saver sub. Observed Spacing on pipe lrabber, grabbing in wrong position and damaging saver sub & top 2 oints on 5" HWDP stands. Breakout & lay down top 2 joints. Replace >ame. Correct the Pipe Tally. rrip back in hole and continue driling from 252' - 528' (276'). ADT = i.03 HRS. PU WT = 58K, SO WT = 66K, ROT WT = 64K. Torque on 3ottom = 1.5K, Torque off bottom = 1 K. Total Jar Hrs = 93.70. Total Bit irs = 6.60. 'umps @ #1 - #2, 66 SPM each @ 560 GPM's, 550 PSI. ;ontinue driling from 528' - 1087' (559'). Run GYRO survey after each Printed: 2/13/2006 12:29:18 PM • ConocoPhiflips Alaska Operations:. Summary .Report Page 2 of 2, Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Fhase Code 1/9/2006 ~ 00:00 - 08:15 ~ 8.25 DRILL ~ DRLG SURFAC 08:15 - 09:00 0.75 RIGMNI 09:00 - 12:00 3.00 DRILL 12:00 - 13:15 1..25 DRILL 13:15 - 13:45 0.50 RIGMNT 13:45 - 20:00 6.25 DRILL 20:00 - 00:00 4.00 DRILL 1/10/2006. 00:00 - 01:00 1.00 DRILL 01:00 - 01:45 0.75 DRILL 01:45 - 02:15 0.50 02:15 - 03:00 0.75 )3:00 - 03:30 0.50 )3:30 - 05:00 1.50 )5:00 - 08:15 3.25 )8:15 - 08:30 0.25 DRILL DRILL DRILL CASE CASE CASE 'RGRP SURFAC DRLG SURFAC DRLG SURFAC RGRP SURFAC DRLG SURFAC CIRC SURFAC TRIP SURFAC PULD SURFAC PULD SURFAC PULD SURFAC PULD SURFAC RURD SURFAC RUNC SURFAC RUNC SURFAC Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11./2006 Group: Rig Number: Description of Operations stand to confirm Close Approach issues. ADT = 6.14, ART = 3.58 HRS, AST = 2.66 HRS. PU WT = 85K, SO WT = 91 K, ROT WT = 90K. Torque on Bottom = 2-4K, Torque off bottom = 1 K. Pumps @ 132 SPM - 1900 PSI, 560 GPM's. Mud WT = 9.1 PPG, Visc @ 250-300, YP = 42 MAX Gas = 23 BTU. WOB = 10-38K. Release GYRO Hand & E-Line unit @ 0630 HRS. Good MWD Surveys. Repair Conveyor Belts in pits. Adjust Linkage. Continue driling from 1087' - 1343' (256'). ADT = 1.99, ART = .5 HRS, ....AST = 1.49 HRS. PU WT = 90K, SO WT = 94K, ROT WT = 94K. Torque on Bottom = 4-5K, Torque off bottom = 2-3K. Total Jar Hrs = 100.22. Total Bit Hrs = 13.14. Pumps @ 156 SPM - 1980 PSI, 560 GPM's. Mud WT = 9.1 PPG, Visc @ 250-300, YP = 42 MAX Gas = 23 BTU. WOB = 10-38K. Continue driling from 1343' - 1517' (174'). 1474' TVD. ADT = 1.07,. ART _ .40 HRS, AST = .43 HRS. PU WT = 95K, SO WT = 94K, ROT WT = 96K. Torque on Bottom = 4-5K, Torque off bottom = 2-3K. Pumps @ 156 SPM - 1980 PSI, 560 GPM's. Mud WT = 9.1 PPG, Visc @ 250-300, YP = 42 MAX Gas = 86 BTU. WOB = 10-38K. Pull back to 1453'. Reciprocate & rotate drill string while work on drag chain in pits. Replace motor. Continue driling from 1517' - 2378' MD (861'). 2201.9' TVD. ADT = 4.78, ART = 2.79 HRS, AST = 2.23 HRS. PU WT = 110K, SO WT = 96K, ROT WT = 105K. Torque on Bottom = 4-5K, Torque off bottom = 3-4K. Observed Hydrates up to 3000 BTU's @ 2035' MD. Total Jar Hrs = 106.07. Total Bit Hrs = 18.99. Pumps @ 1980 PSI, 640 GPM's. Mud WT = 9.3 PPG, Visc @ 250-275, YP = 38. WOB = 5-25K. Last survey @ 2378' MD, 2201.9 TVD, 35 Deg INC, 266.73 Deg AZ. Circulate bottoms up 3 times @ 176 SPM - 750 GPM's, 2500 PSI. RPM's = 70 with 4K torque. BROOH from 2378' - 1077' (1301') at drilling rate. Pull to HWDP and lay down 13 1/2" Ghost Reamer. Continue POOH, pumping at a lower rate of 600 GPM's and observe hole unloading and continued to clean up each stand. Pull from 1071' - 104' (967'). PUWT = 85K, SO WT = 84K, 120 SPM- 600 GPM's - 1950 PSI. Breakout & Lay down 3 joints of Non Mag Drill Collars (92.77'), UBHO sub (2.94'), and 8" Float sub (2.42'). Plug in and download MWD assembly. Continue breakout & lay down remaining BHA. Lay down 13 1/2" Hughes MXC1 bit w/ 3 x 20's & 1 x 13 Jets (1.0'), 8" SperryDrill Lobe 4/5 -5,3 Stage Motor (28.71'), 8" Integral Blade stabilizer (5.57'), 8" Non-mag Crossover sub (1.65'), 8" Non-Mag Pressure drop sub (1.63'), 3" MPT w/ DIR (25.06'), Inspect & Gauge 13 1/2" bit to 2 / 2 / BT /ALL / E/I/WT/TD. lean & Clear rig floor area. Send tools outside. 'JSM with crew. Discuss Safety issues and procedure for rigging up rasing equipment, and running casing. Rig up all equipment to run 10 3/4" surface casing string. Vlake up shoe joint, and Float Collarjoints. Check floats. OK. Continue ~IH picking up 58 total joints of 10 3/4" casing installing Bowspring ;entralizers as per detail to 2348'. Make up torque = 10,000 FT /LBs. observe hole taking proper hole fill and no issues in OH. Total :entralizers run = 21. Total Stop Collars =3. flake up 10 3/4" x 18 1/8" Vetco Gray casing hanger and landing joint Printed: 2/13/2006 12:29:18 PM • ConocoPhillips Alaska Operations Summary Report Page 3 of 2~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 08:15 - 08:30 08:30 - 09:15 09:15 - 09:45 09:45 - 11:30 Date From - To Hours '~ Gode 4 Code Phase 1 /10/2006 11:30 - 12:00 1 J-166 1 J-166 ROT -DRILLING n1334@ppco.com Doyon141 0.25 CASE RUNC 0.75 CASE CIRC 0.50 CEMEN RURD 1.75 CEMEN CIRC 0.501 CEMENlf PUMP SURFAC SURFAC SURFAC SURFAC SURFAC 12:00 - 14:15 I 2.251 CEMENIi PUMP I SURFAC 14:15 - 16:30 2.25 16:30 - 18:30 2.00 18:30 - 20:45 2.25 20:45 - 23:30 2.75 23:30 - 00:00 0.50 1/11/2006 00:00 - 06:15 6.25 RURD SURFAC NUND SURFAC NUND NUND BOPE BOPE SURFAC SURFAC SURFAC SURFAC Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number. Description of Operations as per Vetco Gray rep. RIH, land casing in hanger, verifying good set. RKB = 30.11' Circulate 1 bottoms up with Franks fill up tool while recirocating casing 20'. UP WT = 127K, SO WT = 97K, @ 6 BPM- 350 PSI. Breakout & lay down Franks fill up tool. Load plugs into Cement Head. Make up crossover and Cement head & all lines. Continue Circulate & condition mud. Pre job properties - 9.6 PP_G, Viscosity = 225, PV = 41, YP = 62, Gels @ 17 / 32. Properties of mud for cement job = 9.2 PPG, Viscosity = 42, PV = 15, YP = 7, Gels @ 2 / 3. Circulating @ 6 BPM - 350 PSI. Total Circulation time = 3.0 HRS. Held PJSM with crew & Dowell. Designate a spill champion. With Dowell, pump 10 BBLS of CW 100. Pressure test lines to 3500 PSI. Good test.. Continue pumped an additional 40 bbls of CW 100 (50 bbls total), Followed by 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, Pumped 376:0 bbls (460 sxs) of lead cement of 10.7 ppg and 4.45 yield with additives, ave 6.6 bpm at 275 psi, Followed with 75 bbls (1.75 sxs) of DeepCrete tail. cmt at 12.0 ppg and 2.47 yield with add., ave 4.8 bpm at 230 psi, shut down and dropped top plug, Kick plug out with 20 bbls fresh water, Reciprocated casing 10' to 15' until 150 bbls cement around shoe then pipe became tight and landed on hanger, Up 135K, Dn SOK..Turn over to rig and displace cement w/ 220 bbls (Total 199 bbls to bump) of 9.2 ppg mud, Displaced cement at 7.0 bpm, Initial pump pressure 280 psi, max pressure at 7.0 bpm 320 psi, Observed red dye at shakers after pumping 135 bbls mud, Slowed rate down to 3 bpm @ 280 psi 10 bbls prior to bumping plug, Bumped plug w/ 1200 psi, Held 10 min, Check floats- OK, CIP @ 14:00 hrs 1/10/2006, Had full returns through out job with 63 bbls 10.7 ppg cement to surface, Shoe @ 2,368.38', TVD = 2193.66. Float collar @ 2,282.73'. Test Float Equipment.. Floats held. Flush Stack & Lines. Rig down Cement head & lines. Back out & lay down Landing joint. Nipple down Diverter stack and Riser. Lay down XO for Diverter & Conductor. Lay down Knife Valve. Position all equipment in rear of cellar for crane pick & removal. Pull all Diverter stack equipment from rear of cellar using crane. Move & Set wellhead equipment in cellar. Nipple up Multi-bowl wellhead as per Vetco Gray rep. Test same to 5000 PSI - 10 minutes. Nipple up BOP stack & all lines. Change out saver sub on Top Drive, from 4 1/2 IF to 4" XT39, grabbers and bell guide. PJSM, Discuss safety issues and procedures. Rig up equipment to test BOP's. ?JSM - Dicuss testing BOP's & Safety Issues. Perform BOP test. Test 7 5/8" Lower rams, & Annular with 7 5/8" test joint. Test 6"x 3 1/2" /BR's in top set, and Annular with 5" test joint. Continue test 5" Dart /alve, FloorValve, 4" Floor & Dart valves, and 3 1/2" x 6" VBR's with 4" est joint. Test HCR & Choke, and manual valves. Test Choke manifold /aloes #1, #12, #13, #14. Upper IBOP, Choke Manifold valves # 9, #11. test Lower IBOP & choke manifold valves # 5, #8, #10. All test to 250 'SI -low, 3500 PSI High. AOGCC rep, Lou Grimaldi waived witness of est at 2000 HRS, 1/10/2006. Test Dart & Floor valve for 4" DP, Choke Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Operations Summary Report Page 4 of 25 Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To , f-lours i .Code Sub Phase 1 /11 /2006 00:00 - 06:15 6.25 WELCTI~ BOPE SURFAC 06:15 - 07:00 07:00 - 07:45 0.75 WELCTL~ BOPE 0.75 DRILL I PULD SURFAC SURFAC 07:45 - 09:45 2.00 DRILL PULD SURFAC 09:45 - 10:45 1.00 DRILL PULD SURFAC 10:45 - 12:00 1.25 DRILL PULD SURFAC 12:00 - 16:00 4.00 DRILL PULD SURFAC 16:00 - 18:15 I 2.251 DRILL PULD SURFAC 18:15 - 19:15 1.00 DRILL PULD SURFAC 19:15 - 20:30 1.25 DRILL TRIP SURFAC 20:30 - 21:00 0.50 DRILL CIRC SURFAC 21:00 - 22:00 1.00 CASE DEOT SURFAC 22:00 - 23:15 1.25 CEMEN DSHO SURFAC 23:15 - 00:00 0.75 DRILL CIRC SURFAC 1/12!2006 00:00 - 00:30 0.50 DRILL LOT SURFAC 00:30 - 12:00 11.50 DRILL DRLG INTRM1 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations manifold valves # 4, #6, #7 & #2. Test HCR's Choke & Manual valves, Annular. Perform Koomey test. System Pressure = 3000 PSI, Pressure after close = 1900 PSI. First 200 PSI attained in 42 secs, and full pressure attained in 3 min. AVG pressure in Nitrogen bottles = 2200 PSI. Test Blind rams, Choke manifold valves #3, & #4. Install Wear bushing. RILDS. PJSM with crew. Discuss pick up procedure & safety issues. Rig up Short bales on Top Drive, hang elevators. Pick up 63 jnts of 4" XT39 Slick Drill pipe running in hole to 2000'. POOH, rack back 21 stands n Derrick. Pick up 23 joints of 4" XT39 Slick Drill pipe running in hole to 731'. Continue pick up 40 more joint of 4" XT39 Slick DP to 2000'. 63 joints total. POOH rack back 21 stands in derrick for a total of 42 stands of Slick 4" DP. RIH with 21 joints of 4" HWDP, and POOH racking back 7 stands. PJSM. discuss safety issues and procedure to MU BHA. Make up BHA #2. 9 7/8" Hughes MX-CX1 bit with 3 x 20, 1 x 12 jets (1.0') TFA = 1.031 SO. IN., 7" Sperry Drill Lobe 7/8 - 6.0 stage (25.35'), 6 3/4" Float sub (2.49'), 6 3/4" Integral Blade Stabilizer (5.61'), 6 3/4" DM Collar (9.02'), 6 3/4" Gamma/Res/PWD (28.08'), 6 3/4" TM Collar (9.83'). Plug in and Up load MWD assembly. Continue MU 3 - 6 1/2" NonMAg Flex Drill Collars (93.09'), 4 - 5" HWDP (121.72'), 6 1/4" Drilling Jars w/ 106.09 HRS (30.78'), 10 - 5" HWDP (306.69'). Total BHA = 633.66' NOTE: Install Corrosion Ring in top joint of 5" HWDP Serial #19936 RIH from Derrick with 5 stands of 5" HWDP. POOH, breakout & lay down 15 joints of 5" HWDP not needed for this assembly. Trip in hole with 3 stands of 5" Slick DP, Make up 9 7/8" Ghost Reamer (5.08'), and 12 more stands of 5" DP. Crossover to 4" Dp and RIH with 4" DP to 2216'. Perform Shallow pulse test on MWD assembly. Good Test @ 115 SPM -487 GPM -1250 PSI. Continue TIH to tag firm Cement @ 2275' DPM. Circulate & condition mud at 115 SPM - 487 GPM"s - 1250 PSI. PU WT = 100k, SO WT = 82K, ROT WT = 90K. Torque @ 3.5K. Pull 1 stand back to 2211'. Mud wt = 9.0 PPG. Rig up and flush lines to ensure no air in lines. Test 10314" Casing to 3000 PSI for 30 Minutes. Record on chart. Good test. Bleed & blow down lines. RD test equipment. RIH with 1 stand, MU Top Drive & drill cement & float equipment from 2275' - 2400' (22' of new hole). FC @ 2284', & FS @ 2368'. ADT = .23 HRS. PU WT = 100k, SO WT = 82K, ROT WT = 90K. Torque = 4K on bottom, 3.5K off bottom. Mud wt = 9.0 PPG, WOB = 3-10K, Pumps at 107 SPM - 454 GPM - 1100 PSI. Displace well with 9.0 PPG conditioned mud @ 107 SPM - 454 GPM's - 1100 PSI, checking mud properties until same in & out for LOT test. Mud wt = 9.0 PPG, 10 sec Gels = 17. Rig up & perform LOT to 15:3 PPG EMW. Mud wt = 9.0 PPG, 10 sec Gels = 17. Observe pressure breakover @ 724 PSI @ 3 BBLS pumped. 10 Minute shut in, pressure bled from 650 psi - 480 PSI. SHoe depth = 2368' MD, 2193' TVD. Directional drill 9 7/8" Intermediate hole from 2400' - 3895' (1495') MD. TVD = 3057'. ADT = 7.79 HRS, ART = 3.76 HRS, AST = 4.03 HRS. PU dVT = 112K, SO WT = 80K, ROT WT = 90K. Torque on btm = 4-7K, Off Bottom = 3-6K. Pumps - 600 GPM's - 2075 PSI. RPM's = 80. WOB = Printed: 2/13/2006 12:29:18 PM • ConocoPhillips Alaska Operations Summary Report Page 5 of 25 Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Gode Code Phase Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations 1/12/2006 00:30 - 12:00 11.50 DRILL DRLG INTRM1 5-30K. Total Bit HRS = 8.02 HRS. Total Jar HRS = 114.11 Mud Wt = 9.0 PPG, Visc = 75,YP = 27, Gels @ 12 / 21. Max gas units = 49 BTU's, ECD =10.14 PPG. Survey @ 3668' MD, 2970 TVD, INC = 67.15 Deg, AZ = 317.80 Deg. Obtain SPR's at 3709' MD, 2984' TVD Pump #1 , 25 SPM -240 PSI, 35 SPM - 300 PSI. Pump #2, 25 SPM -250 PSI, 35 SPM - 320 PSI. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Continue Directional drill 9 7/8" Intermediate hole from 3895' - 5125' (1230') MD. TVD = 3440'. ADT = 8.35 HRS, ART = 3.28 HRS, AST = 5.7 HRS. PU WT = 115K, SO WT = 76K, ROT WT = 90K. Torque on btm = 5-7K, Off bottom = 5-7K. Pumps - 615 GPM's - 2400 PSI. RPM's = 75. WOB = 15-35K. Total Bit HRS = 16.37 HRS. Total Jar HRS = 122.46 Mud Wt = 9.1 PPG, Visc = 59,YP = 29, Gels @ 14 / 22. Max gas units = 105 BTU's, ECD =10.33 PPG. Survey @ 5067 MD, 3428 TVD, INC = 78.03 Deg, AZ = 1.76 Deg. Obtain SPR's at 4736' MD, 3352' TVD Pump #1 , 25 SPM -270 PSI, 35 SPM - 350 PSI. Pump #2, 25 SPM -270 PSI, 35 SPM - 340 PSI. Pump Hi Visc weighted sweep @ 3895' MD, & 5000' MD observing 20% increase in cuttings at shakers. 1/13/2006 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Continue Directional drill 9 7/8" Intermediate hole from 5125' - 6195' (1070') MD. TVD = 3627'. ADT = 8.29 HRS, ART = 6.95 HRS, AST = 1.34 HRS. PU WT = 123K, SO WT = 73K, ROT WT = 88K. Torque on btm = 7-8K, Off bottom = 5-8K. Pumps - 600 GPM's - 2500 PSI. RPM's = 85. WOB = 10-25K. Total Bit HRS = 24.49 HRS. Total Jar HRS = 130.75 Mud Wt = 9.2 PPG, Visc = 54,YP = 25, Gels @ 12 / 25. Max gas units = 189 BTU's, ECD =10.38 PPG. Survey @ 6153' MD, 3621 TVD, INC = 81.48 Deg, AZ = 2.28 Deg. Obtain SPR's at 5764' MD, 3559' TVD Pump #1 , 25 SPM -270 PSI, 35 SPM - 350 PSI. Pump #2, 25 SPM -260 PSI, 35 SPM - 340 PSI. 12:00 - 13:45 1.75 DRILL DRLG INTRM1 Continue Directional drill 9 7/8" Intermediate hole from 6195' - 6355' (160') MD. TVD = 3650'. ART = 1.13 HRS. PU WT = 125K, SO WT = 76K, ROT WT = 90K. Torque on btm = 7-8K, Off bottom = 5-6K. Pumps - 600 GPM's - 2550 PSI. RPM's = 80. WOB = 10-25K. Total Bit HRS = 25.33 HRS. Total Jar HRS = 131.88 Mud Wt = 9.25 PPG, Visc = 54,YP = 26, Gels @ 12 / 17. Max gas units = 206 BTU's, ECD =10.50 PPG. Survey @ 6312' MD, 3644 TVD, INC = 82.47 Deg, AZ = .45 Deg. Obtain SPR's at 5764' MD, 3559' TVD Pump #1 , 25 SPM -270 PSI, 35 SPM - 350 PSI. Pump #2, 25 SPM -260 PSI, 35 SPM - 340 PSI. Pump Weighted Hi Visc sweep @ 6280'. Observe 5% increase in cuttings at shakers. 13:45 - 14:45 1.00 DRILL CIRC INTRM1 Circulate bottoms up 3 times @ 600 GPM -2550 PSI. Reciprocate & rotate drill string. 14:45 - 17:15 .2.50 DRILL WIPR INTRM1 BROOH from 6355' - 4739' (1616'). Pull last 2 stands @ 10' /minute as to get another bottoms up and clean hole. Observed hole taking proper displacement. 17:15 - 19:30 2.25 DRILL TRIP INTRM1 Monitor well -static. Continue POOH on elevators 5 more stands,with hole taking proper fill. Mix & pump dry job. Continue POOH on elevators to 2030'. (2709'). Shoe @ 2368' ,Monitor well -static. 19:30 - 22:00 2.50 DRILL TRIP INTRM1 Change out elevators, & heads in Iron Roughneck. Continue POOH laying down 45 joints of 5" Drill pipe, 24 joints of 5" HWDP, and drilling jars. 22:00 - 22:15 0.25 DRILL PULD INTRM1 Breakout & lay down 3 - 8" NonMag Flex Drill Collars. 22:15 - 23:00 0.75 DRILL PULD INTRM1 Plug in and download MWD assembly. 23:00 - 00:00 1.00 DRILL PULD INTRM1 Pull up to breakout bit, and drain mud motor. Breakout & lay down Printed: 2/13/2006 12:29:18 PM • s ConocoPhillips Alaska Operations Summary Report Page 6 of 2~ Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code ode ~ Fhase 1/13/2006 23:00 - 00:00 1.00 1/14/2006 00:00 - 00:30 0.50 00:30 - 01:00 0.50 01:00 - 02:45 1.75 02:45 - 07:30 4.75 07:30 - 08:00 0.50 08:00 - 09:15 1.25 09:15 - 09:45 0.50 09:45 - 12:00 2.25 12:00 - 12:45 0.75 12:45 - 13:30 0.75 13:30 - 14:00 0.50 14:00 - 15:45 1.75 15:45 - 17:30 1.75' 17:30 - 18:00 0.50 18:00 - 20:00 2.00 ?0:00 - 21:00 1.00 DRILL PULD INTRM1 DRILL PULD INTRM1 CASE OTHR INTRM1 CASE RURD INTRMI CASE RUNC INTRM1 CASE CIRC INTRM1 CASE RUNC INTRM1 CASE RUNC INTRM1 'CASE RUNC INTRM1 CASE RUNC INTRM1 CASE CIRC INTRM1 CEMEN PULD INTRM1 CEMEN CIRC INTRM1 CEMENIfPUMP IINTRM1 PUMP INTRM1 NUND INTRMI OTHR INTRM1 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations. MWD TM -HOC. Continue breakout & lay down remaining BHA. Inspect & grade bit. Clean & clear floor area, send tools outside. Bit grade = 1 / 2 / WT / A / E/ER/TD. BOLDS, pull wear bushing. PJSM with crew. Discuss safety issues and procedure for rigging up casing equipment. Rig up all 7 5/8" casing equipment. Double check order of casing in shed. Pick up & run 7 5/8" L80 29.7# casing to 2334'. Make up torque = 8K ft/Ibs. Observe casing taking proper fill. At shoe, circulate bottoms up at 5 BPM -300 PSI, through Franks Fill up tool. PU WT = 100K, SO WT = 74K. Monitor well -static. Continue run 7 5/8" casing from 2334' - 3477' (1143'). Continue run 7 5/8" casing, run out of downweight, Circulate @ 4 BPM - 470 PSI, slacking off washing down 2 joints until observing hole cleanning up. Continue run 7 5/8" casing from 3564' - 5779' (2215'). Crew Change Continue run 7 5/8" casing from 5779' - 6355' (576'). Circulate bottoms up with Franks fill up tool @ 6.5 BPM - 600 PSI. PU WT = 170K, SO WT = 87K. Reciprocate casing while circulating approximately 25'. Breakout & lay down Franks fill up tool. Install Crossover and make up cement head with plugs loaded. Continue circulate & condition mud with cement head @ 7 BPM - 850 PSI. PU WT = 170K, SO WT = 87K. Reciprocate casing while circulating approximately 25'. Before conditioned mud = 9.8 PPG, Viscosity = 84, PV = 28, YP = 39, Gels @ 17 / 23. After mud conditioned for cement job .Mud wt = 9.2 PPG, Viscosity = 39, PV =12, YP = 1 3, Gels @ 7 / 9. Turn Rig over to Dowell lines. Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4.7 bpm @ 230 psi, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100 at rate of 4.5 bpm @ 170 psi, Pumped 50 bbls of MudPush at 11.0 ppg at rate of 4.7 bpm @ 215 psi, Dropped btm plug then pumped 144 bbls, (370 sxs - 25% over caliper) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, avg 5.6 bpm at 275 psi, Reciprocated. pipe with full returns 15' to 20'. Drop top plug and Dowell kicked top plug out with 10 bbls fresh water, @5 BPM -200 PSI. Rig displaced cement with 8.9 ppg OBM, Bumped plug after pumping 287.5 bbls MOBM (96% pump eff.) 2867 Strokes, avg 6.8 bpm while displacing cmt, Observed lift pressure f/ 500 psi to 800 psi prior to slowing pump rate to 3 bpm, Slowed pump rate to 3 bpm @ 500 psi Frith 10 bbls left to pump and bumped plug to 1250 psi. CIP at 1730 hrs, 1-14-06. Reciprocated pipe 15` to 20' until MudPUSH at shoe,. Then recip. 10' until Cmt at shoe, then recip. 10' until last 30 bbls, then ~ecip. 5' until last 10 bbls then stopped pipe, Landed csg with Shoe @ 3350', Float Collar @ 6264', Calc TOC @ 3355', Had full returns thru gut job. Well static after shut down. heck Float Equipment. Held, no bleed back. Rig down casing :quipment. ~JSM with crew. Discuss Safety and procedure to complete 7 5/8" rasing run. Nipple down BOP stack and raise. Set 7 5/8" emergency >lips as per Vetco Gray rep, with 75K overpull on casing. luck out all MOBM in 7 5/8" casing down to 40'. Rig up WACHS casing Printed: 2/13/2006 12:29:18 PM _~_ ConocoPhillips Alaska Operations' Summary Report Page 7 of 2 Legal Well Name: 1J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Prase 1/14/2006 ~ 20:00 - 21:00 ~ 1.00 WELCTy OTHR I INTRM1 21:00 - 21:45 0.75 WELCT OTHR INTRM1 21:45 - 22:30 0.75 WELCT NUND INTRM1 22:30 - 23:00 0.50 WELCT BOPE INTRM1 23:00 - 23:30 0.50 WELCTt 23:30 - 00:00 0.50 DRILL 1/15/2006 00:00 - 01:00 1.00 DRILL 01:00 - 06:00 5.00 DRILL 06:00 - 07:00 1.00 DRILL 07:00 - 07:30 0.50 DRILL 07:30 - 10:30 3.00 DRILL 10:30 - 12:00 1.50 DRILL OTHR INTRMI FIT INTRM1 FIT INTRM1 PULD INTRM1 PULD INTRMI PULD INTRM1 PULD INTRM1 'PULD INTRM1 12:00 - 12:30 I 0.501 DRILL PULD I INTRMI 12:30 - 12:45 0.25 DRILL 12:45 - 13:30 0.75 DRILL 13:30 - 14:00 0.50 DRILL 14:00 - 14:15 0.25 DRILL 14:15 - 18:00 I 3.751 DRILL 18:00 - 19:15 1.25 CASE ~ 19:15 - 22:15 3.00 CEMEN 22:15 - 22:45 0.50 DRILL PULD PULD TRIP DEOT TRIP DEOT DSHO CIRC 22:45 - 23:45 I 1.001 DRILL I LOT INTRMI I NTRM 1 I NTRM 1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations cutter. Make beveled cut on 7 5/8" CSG, and dress same. Joint # 148 - length left in well = 38.56'. Cut off piece = 5.02'. POOH, breakout & lay down pups. Install 7 5/8" pack-off as per Vetco rep. Nipple up BOP stack & well head flange. Rig up test pump & lines. Test inner & outer seals on packoff, and the flange connection to 5000 PSI - 15 minutes. Install wear bushing with landing joint. ID of wear bushing = 9.125". Rig up lines and test chart for LOT test & infectivity test on the 10 3/4" x 7 5/8" annulus at 2368' MD. PJSM. Perform LOT d~ Infectivity test on the 10 3/4" x 7 5/8" annulus @ 2368'. Test to 13.t PPG EMW and hold 10 minute shut. in test. Record all on chart. Pump 30 BBLS water down annulus @ 3 BPM - 520 PSI. SIMOPS: Install SGvlumberger MWD standpipe sensor. RU & pick up 90 joints of 4" Drill pipe with super sliders on them. Re-position, inspect and re-torque all sliders while run in hole. POOH racking back 30 stands of 4" DP with super sliders. SIMOPS: Inject 80 rrrore barrels of water down the 10 3/4" x 7 5/8" annulus for Hush @ 3 ~1l1- 510 PSL Rig up Little Red services, pump 90 bBLS of freeze protect diesel down annulus @ 3 BPM. Shut in annulus. Clean & clear floor area. Make up 15 stands of Hybrid Push pipe running in hole. Hybrid = 2 -4 3/4" Drill Collars + 1-4" DP per stand. Re-position 4" HWDP in Derrick. POOH racking back 15 stands of Hybrid push pipe. Crew change. PJSM with crew & SWS. Discuss Safey issues and procedure for making up Schlumberger BHA. Pick up 6 3/4" Hycalog RSX711 M-A2 bit with 2 x11's, 2 x 12' jets (.58'), 4 3/4" BIAS Unit w/ 22 restrictor (2.96'), 4 15/16" Control Collar (10.36'), 5" PD XO (1.17'), 5" Reciever (4.92'), 4 3/4" FIexXO (2.36'), 4 11/16" Periscope (25.01'), 4 3/4" Impulse MWD assembly (33.87'). Note: Bit = #3 RR1 with starting hours of 66.25 HRS from 1J-101 A Lateral. Test Power Drive @ Surface with 62 SPM - 220 GPM - 450 PSI. Good. Continue MU remaining BHA, 5 1/4" Bypass Sub /Float Sub (2.35'), 3 - 4 3/4" NonMag Flex Drill Collars (92.51'), 4 7/8" XO Sub (1.65'), 4 3/4" Drilling Jars (28.81') and 2 joints 4" HWDP (60.48'). Total BHA = 357.80' Trip in hole with singles 4" DP from pipe shed to 670°. Perform Shallow hole pulse test on MWD assembly @ 300 GPM - 1200 PSI. Good test. Continue trip in hole from 670' - 6264' (5594'). Tag Float collar @ 6264' DPM. Pull back to 6245'. Rig up casing test egipment & lines. Test 7 5/8" Casing to 3000 PSI - 30 minutes. Recorded on chart. Good test. Bleed pressures and rig down equipment. Drill out float equipment @.6264', firm cement to shoe @ 6350', and 21' ~f new hole to 6376', at 320 GPM - 2225 PSI. Torque @ 3-5K. ART = 28 HRS. PU WT = 97K, SO WT = 70K. Circulate Bottoms up @ 321 GPM-s - 2225 PSI, until shakers clean. Vlud wt in /out = 8.7+. YP = 18, Gels -18 / 23. Obtai clean hole ECD @ 3.91 PPG. Condition mud for LOT. Blow down Top Drive. Pull 1 stand. =ill lines & Perform LOT on the 7 5/8" casing shoe @ 6350' MD; 3650 iVD. Test to leak off at 1259 PSI = 15.3 PPG Equivalent Mud Weight. Printed: 2/13/2006 12:29:18 PM • ConocoPhillips Alaska Operations Summary Report Pale 8 of 25 Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date ~I From - To Hours Code Sub ~ Phase Code I Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations 1/15/2006 22:45 - 23:45 1.00 DRILL LOT INTRM1 Held 10 minute shut in, observe shut in pressure bled from 860 PSI to 712 PSI. Bleed all pressure. Rig down equipment & lines. 23:45 - 00:00 0.25 DRILL TRIP PROD Pick up 1 stand & TIH back to 6376'. PU WT = 97K, SO WT = 70K, ROT WT = 70K Torque on = 3-7K, Torque off = 5K ECD = 9.91 PPG, Jar HRS = .28, Bit HRs = .28, MAX gas = 25 BTU's. 1/16/2006 00:00 - 12:00 12.00 DRILL DRLG PROD Drill 6 3/4" hole in the A Lateral from 6376' - 7425' (1049'). MD. TVD = 3656'. ADT = 7.94 HRS,TotaLADT = 8.22 HRS. PU WT = 105K, SO WT = 70K, ROT WT = 85K. Torque on/off bottom = 5.5K. Pumps - 345 GPM's - 2500 PSI. RPM's = 160. WOB = 3-5K. Total Bit HRS = 8.23 HRS. Total Jar HRS = 8.22. Mud Wt = 8.75 PPG, Visc = 76,YP = 18, Gels @ 21 / 28. Survey @ 7301' MD, 3656' TVD, 90 Deg INC, .52 Deg AZ. ECD = 10.32 PPG, Max gas = 140 Units. Observed drilling through concretions. from 6384' -6400' (16'), 6409'-6414'(5'), 6570'-6586'. (16'), 6591'-6600' (9'),6920' - 6937' (17'), 7054' -7058' (4'),7255' - 7263' (8'), and 7400'-7406' (6'). Obtain Slow pump rates @ 7176' MD, 3657 TVD. Pump #1 - 20 SPM - 320 PSI, 30 SPM - 440 PSI. Pump #2 - 20 SPM - 330 PSI, 30 SPM - 450 PSI. 12:00 - 00:00 12.00 DRILL DRLG PROD Continue Drill 6 3/4" hole in the A Lateral from 7425' - 8478' (1053'). MD. TVD = 3655'. ADT = 7.69 HRS,Total ADT = 15.91 HRS. PU WT = 116K, SO WT = 63K, ROT WT = 82K. Torque on/off bottom = 6-7K. Pumps - 350 GPM's - 2750 PSI. RPM's = 160. WOB = 2-10K. Total Bit HRS = 7.69 HRS. Total Jar HRS = 15.91. Mud Wt = 8.75 PPG, Visc = 68,YP = 18, Gels @ 21 / 28. Survey @ 8329' MD, 3655' TVD, 90 Deg INC, 1.51 Deg AZ. ECD = 10.35 PPG, Max gas = 92 Units. Observed drilling through concretions from 8021' -8025' (4'), 8415'-8420'(5'), 8473'-8483' (10'). Obtain Slow pump rates @ 8390' MD, 3655 TVD. Pump #1 - 20 SPM - 370 PSI, 30 SPM - 480 PSI. Pump #2 - 20 SPM - 410 PSI, 30 SPM - 500 PSI. Total K-Revs on Super Sliders for the day = 26524 HRS. 1/17/2006 00:00 - 12:00 12.00 DRILL DRLG PROD Drill 6 3/4" hole in the A Lateral from 8478' - 9566' (1088'). MD. TVD = 3692'. ADT = 7.91 HRS,Total ADT =23.82 HRS. PU WT = 120K, SO WT = 60K, ROT WT = 85K. Torque on/off bottom = 6.5K. Pumps - 335 GPM's - 2700 PSI. RPM's = 160. WOB = 3-10K. Total Bit HRS =23.82 HRS. Total Jar HRS = 23.82. Mud Wt = 8.75 PPG, Visc = 60,YP = 16, Gels @ 16 / 23. ECD = 10.38 PPG, Max gas = 167 Units. Observed drilling through concretions from 8469' -8485' (16'), 8643'-8658'(15'), 9100'-9110' (10'), 9488'-9502' (14'), 9533' - 9535' (2'). Obtain Slow pump rates @ 9418' MD, 3687 TVD. Pump #1 - 20 SPM - 350 PSI, 30 SPM - 480 PSI. Pumped hi-vis sweep @ 9415' and observed 5% increase in cuttings over the shakers. 12:00 - 00:00 12.00 DRILL DRLG PROD Continue Drill 6 3/4" hole in the A Lateral from 9566' - 10543' (977'). MD. TVD = 3711'. ADT =7.88 HRS,Total ADT = 31.70 HRS. PU WT = 126K, SO WT = 47K, ROT WT = 82K. Torque on/off bottom = 6K. Pumps - 320 GPM's - 2700 PSI. RPM's = 160. WOB = 3-10K. Total Bit HRS = 31.70 HRS. Total Jar HRS = 31.70. Mud Wt = 8.75 PPG, Visc = 64,YP = 17, Gels @ 19 / 24. ECD = 10.91 PPG, Max gas = 102 Units. Obtain Slow pump rates @ 10353' MD, 3734' TVD. Pump #1 - 25 SPM - 460 PSI, 35 SPM - 630 PSI. Pump #2 - 25 SPM - 470 PSI, 35 SPM - 610 PSI. 1/18/2006 00:00. - 12:00 12.00 DRILL DRLG PROD Drill 6 3/4" hole in the A Lateral from 10543' - 11462' (919') MD. TVD = 3669'. ADT = 8.17HRS,Total ADT =39.87 HRS. PU WT = 135K, SO WT = 49K, ROT WT = 88K. Torque on/off bottom = 7.5K. Pumps - 320 Printed: 2/13/2006 12:29:18 PM • ConocoPhllips Alaska Operations Summary Report Page. 9 of 25 Legal Well Name: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ,Hours Code ode Phase 1/18/2006 ~ 00:00 - 12:00 I 12.00 I DRILL I DRLG I PROD 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLG ~ PROD 1/19/2006 00:00 - 03:00 3.00 03:00 - 07:00 4.00 07:00 - 08:30 1.50 1 /20/2006 08:30 - 12:00 12:00 - 13:15 13:15 - 14:45 14:45 - 17:00 17:00 - 18:00 18:00 - 20:15 20:15 - 00:00 00:00 - 00:15 00:15 - 00:45 00:45 - 03:30 3.50 1.25 1.50 2.25 1.00 2.25 3.75 0.25 0.50 2.75 DRILL DRLG PROD DRILL CIRC PROD DRILL CIRC PROD DRILL TRIP DRILL TRIP WELLS EQRP DRILL TRIP DRILL PULD CMPLTN RURD CASE RUNC CASE SFTY CASE RURD CASE PULR 03:30 - 04:30 1.00 CASE PULR 04:30 - 05:00 0.50 CASE RURD 05:00 - 11:00 6.00 CASE RUNL 11:00 - 12:00 1.00 CASE DEOT PROD PROD PROD PROD PROD CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations GPM's - 3300 PSI. RPM's = 160. WOB = 3-12K. Total Bit HRS =106.37 HRS. Total Jar HRS =39.87. Mud Wt = 8.75 PPG, Visc = 64 ECD = 10.91 PPG, Max gas = 165 Units. Observed drilling through concretions from 10675-10691' (16'), 11059-11067' (8'), 11093-11103' (10'), 11216-11225' (9'), 11269-11300' (31'). Obtain Slow pump rates @ 11279' MD, 3656' TVD. Pump #1 - 25 SPM - 500 PSI, 35 SPM - 660 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM -670 PSI. Continue Drill 6 3/4" hole in the A Lateral from 11462'-12461' (999') MD. TVD = 3705'. ADT =8.12 HRS,Total ADT = 47.99 HRS. PU WT = 155K, SO WT = 50K, ROT WT = 101 K. Torque on/off bottom =5K/SK. Pumps - 315 GPM's - 3500 PSI. RPM's = 160. WOB = 3-10K. Total Bit HRS = 114.5 HRS. Total Jar HRS = 47.99. Mud Wt = 8.75 PPG, Visc = 64 ECD = 11.31 PPG, Max gas = 94 Units. Observed drilling through concretions from 11980-11983' (3'), 11992-11995' (3'), 12051-12065' (14'), 12088-12090' (2'), 12416-12435' (19'). Obtain Slow pump rates @ 12276' MD, 3693' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 790 PSI. Pump #2 - 25 SPM - 580 PSI, 35 SPM - 780 PSI. Total K-Revs=173,414 Drilled from 12,461' to 12,853' MD / 3,724' ND. ADT=2.05 TDT=50.04 Jar Hours=50.04 PUW=175K SOW=60K ROT= 110K TOon/off=8K Max Gas=101 Units ECD=11.56 Pumped hi-vis weighted sweep @ 338 gpm, 4100 psi. Pumped total 22188 stks. Final ECD=11.20 Held PJSM for displacement to SFOBM. Displaced well to SFOBM. SPRs, UD single, dropped 1 7/8" rabbit. SPR#1=25stk/620psi, 35stk/780psi SPR#2=25stk/620psi, 35stkR90psi @ 12,822' MD 3,722' TVD 8.7 MW. POOH from 12,826' to 9,515'. Start PUW=190K SOW=40K End PUW=140K SOW=45K Cont'd to POOH from 9,515' to 6,338'. Serviced TD, slipped and cut 76' drill line. POOH from 6,338' to 357'. UD BHA, rack back 2 stds HWDP w/jars, UD NMFDCs, MWD, Periscope tool, break bit, UD Powerdrive. Cleared rig floor, R/U csg equip, loaded pipe shed 4 1/2" balnks and slots, Sim-Ops, R/D Schlumberger. RIH w/ 4 1/2" slotted liner. Ran 120 jts to 3739'. PUW=68K SOW=64K Held PJSM and reviewed liner detail. P/U liner pups to rig floor. R/U back-up casing tongs, as others had washed out hyd. valve. Cont'd to run 4.5" liner as per detail. Ran a total of 64 jts blank pipe and 172 jts slotted liner (4.5", L-80 12.6# IBT) with 2 pups. PUW=83K SOW=60K Make up XO Bushing, Casing Seal Bore Ext, Flexlock Liner Hanger, RS Packoff Seal nipple, and HRD ZXP Liner Top PKR, with BOT running tools. Total BHA length of liner assembly = 7359.98'. PU WT = 85K, SO WT = 60K. R/D Doyon casing equip. Continue RIH with Liner on Drill Pipe from7360' - 12840' with no problems. Get PUW=180K SOW=60K. Drop 1 7/16" ball, Position liner w/ shoe Printed: 2/13/2006 1229:18 PM GonocoPhillips /alaska Operations Summary Report Page 10 of2~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 /20/2006 1 /21 /2006 1 J-166 1 J-166 ROT -DRILLING n1334@ppco.com Doyon 141 From - To Hours Code Code Phase 11:00 - 12:00 12:00 - 14:45 14:45 - 15:15 15:15 - 15:30 15:30 - 15:45 15:45 - 18:30 18:30 - 21:15 21.:15 - 23:00 23:00 - 00:00 00:00 - 00:15 00:15 - 01:15 01:15 - 05:45 05:45 - 07:15 07:15 - 09:45 09:45 - 11:00 11:00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 19:30 19:30 - 23:00 1.001 CASE I DEQT 2.75 DRILL TRIP 0.50 DRILL PULD 0.25 DRILL RIRD 0.25 WINDO ULD 2.75 WINDO ULD 2.75 WINDO RIP 1.75 WINDO THR 1.00 WINDO RIP 0.25 WINDO ETW 1.00 WINDO IRC 4.50 WINDO TWP 1.50 WIN 2.50 WIN 1.25 WIN 1.00 DRILL OTHR 1.00 DRILL OTHR 1.00 WELCT BOPE 1.00 WELCT BOPE 4.501 WELCTu BOPE 3.50 WELCT) BOPE 23:00 - 23:30 0.50 DRILL OTHR 23:30 - 00:00 0.50 RIGMNT RSRV 1/22/2006 00:00 - 01:30 1.50 DRILL PULD 01:30 - 03:00 1.50 DRILL PULD 03:00 - 03:30 0.50 DRILL PULD 03:30 - 04:15 0.75 DRILL DEOT 04:15 - 05:15 1.00 DRILL TRIP Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations CMPLTN @ 12840' & top of liner @ 5480.02'. Circa ball down w/ 3 BPM and pressure up to set .Set down 55K to set slips as per BOT rep, continue pressure up to 4000 PSI, to complete setting PKR. Bleed pressure, Rig up and pressure test down annulus to test PKR at 1000 PSI - 10 Minutes. Blow down Top Drive and Kill Line. Monitor well -Static. PUW=130K SOW=100K after setting ZXP. CMPLTN Monitored well and POOH. CMPLTN Lay down liner running tools. CMPLTN Clear & clean rig floor. PROD2 P/U whipstock and associated BHA from beaverslide. PROD2 P/U and M/U whipstock BHA. PROD2 TIH from 388' to 4,570'. Shallow tested MWD w/ 80 spm 1150 psi @ 1,789' (good test). PROD2 MAD passed from 4,570' to 4,725' w/ 80 spm and 2200 psi. PROD2 TIH from 4,725' to 5,372'. PUW=115K SOW=95K. PROD2 TIH from 5,372' to 5,480' MD. Orient whipstock @ 5 deg left of high-side and set trip anchor, sheared off bolt w/ 60 K downweight. PUW=125K SOW=90K ROT=109K TO=3-7K. PROD2 Held PJSM and displaced well to MOBM @ 80 spm, 2200 psi. SPR#1=25stks/350psi, 35stks/550psi SPR#2=25stks/370psi, 35stks/530psi PROD2 Milled window from 5,380' to 5,392'. Milled 20' of gauge hole to total depth of 5,422'. PROD2 Pumped 30 bbl weighted hi-vis sweep and worked mill through window. Rotated through window w/ pumps on 8 times. Repeated sliding 4 more times, sliding w/o pumps 2 times. PUW=120K SOW=90K PROD2 Monitored well, static. Pumped dry job and POOH from 5,422' to 286'. PROD2 UD BHA. S/B 2 stds push pipe, UD 2 bumper subs. Plugged in and downloaded MWD. Cont'd to UD BHA including: TM HOC, MWD, DM HOC, NMFS, 1 jt 3.5" FiWDP, upper mill (in gauge), lower mill and window mill. PROD2 Pulled wear bushing, cleaned rig floor, C/O elevators. PROD2 R/U and flush stack w/ stack washer after milling operations. PROD2 R/U and begin to test BOPE. PROD2 -Valve #13 on manifold failed along with HCR choke valve. Began to repair equipment. PROD2 Removed and rebuilt choke valve bonnet assy. on #13. Removed bonnet on HCR choke and C/O seals and-seat assy. PROD2 Tested ROPE w/ low pressure test @ 250 psi and high @ 3500 psi. Tested annular, top 3.5"X6" rams, blinds, IBOP, lower IBOP, dart valve, floor valve, manual choke and kill, HCR choke and kill. Choke manifold valves 1-14. Performed accumulator test 3000 psi decreased to 1800 psi with all elements closed (3 min 25 sec recovery time to 3000 psi). Five nitrogen bottles showed avg. pressure of 2100 psi. R/D test equip. Witnessing of test waived by J. Spaulding of AOGCC. PROD2 Set wear bushing. PROD2 Inspected saver sub and serviced T/D. PROD2 M/U BHA. PROD2 Uploaded MWD tools PROD2 Confd to M/U BHA. PROD2 Shallow tested MWD @ 453'. Rotated to break-in seals on Geo-Pilot tool w/ 80 spm, 20 rpm, 1200 psi. PROD2 RIH from 453' to 2,239' MD and filled pipe. Shallow-tested to ensure Printed: 2/13/2006 12:29:18 PM • ConocoPhillips Alaska: Operations Summary Report Page 1 1 of 25 Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To .Hours Code Code Phase I Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations 1/22/2006 04:15 - 05:15 1.00 DRILL TRIP PROD2 downlink w/ Geo-Pilot. 05:15 - 06:45 1.50 DRILL TRIP PROD2 Cont'd to RIH from 2,239' to 5,322'. Washed down to 5,422' w/ 80 spm 2000 psi. Ran through window w/ no problems. 06:45 - 08:45 2.00 DRILL DEQT PROD2 Trouble-shot MWD smart tools. 08:45 - 12:00 3.25 DRILL DRLH PROD2 Drilled from 5,422' to 5,490' MD / 3,514' TVDRRT=ADT=2.8 hrs Jar hrs=52.90 PUW=102K SOW=65K ROT=85K TOon/off=5K ECD=9.71 Calc clean hole ECD=9.75 Max Gas=51 units SPR#1=25stk/340psi, 35stk/500psi SPR #2=25stk/350psi, 35stk/510psi @ 5,490' MD / 3,516' TVD EMW= 8.7+ Concretion depths: 5465-5476' (12') 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drilled from 5,490' to 6,790' MD / 3,521' TVDRRT=ADT=9.1 hrs Jar hrs=62 PUW=117K SOW=64K ROT=82K TOon/off=5K/5:5K ECD=10.28 Calc clean hole ECD=9.75 Max Gas=48 units SPR#1=25stk/420psi, 35stk/590psi SPR #2=25stk/440psi, 35stk/610psi @ 6,534' MD / 3,510' TVD EMW= 8.7+ Concretion depths: 5466-5488' (12'), 5489-5493' (4'), 5531-5534' (3'), 5670-5685' (15'), 5706-5724' (18'), 5787-5788' (1'), 5873-5880' (7'), 5946-5967' (21'), 6564-6567' (3'), 6652-6661' (9'), 6671-6677' (6'). 1/23/2006 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 6790' - 7793' (1003') MD. TVD = 3515'. ADT = 9.6 hrs. PU WT = 116K, SO WT = 60K, ROT WT = 81 K. Torque on/off bottom = 5.5/6.OK. Pumps - 330 GPM's - 2700 PSI. RPM's = 140. WOB = 3-15K. Total Bit HRS =21.5 hrs. Total Jar HRS = 71.6. Mud Wt = 8.75 PPG, Visc = 72, ECD = 10.25 PPG, Max gas = 47 Units. Observed drilling through concretions from 6950'-6960', 7047'-7055', 7062'-7070', 7202'-7204', 7548'-7553', 7589'-7590', 7620'-7630', 7637'-7639', 7640'-7648', 7729', 7746', 7749'-7762', 7776'-7778'. Obtain Slow pump rates @ 7374' MD, 3525' TVD. Pump #1 - 25 SPM - 460 PSI, 35 SPM - 650 PSI. Pump #2 - 25 SPM - 440 PSI, 35 SPM -570 PSI. 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 7793' - 8723' (930') MD. TVD = 3522'. ADT = 9.45 hrs. PU WT = 130K, SO WT = 50K, ROT WT = 82K. Torque on/off bottom = 6.5K. Pumps - 330 GPM's - 2800 PSI. RPM's = 120. WOB = 3-15K. Total Bit HRS =30.95 hrs. Total Jar HRS = 81.05. Mud Wt = 8.70 PPG, Visc= 72, ECD = 10.83 PPG, Max gas = 47 Units. Observed drilling through concretions from 7781'-7795', 7820'-7829', 7970'-7974', 8030'-8032', 8056'-8061', 8445'-8447', 8473'-8478', 8480'-8495', 8541'-8549', 8568'-8573', 8584'-8590', 8599'-8604', 8624'-8629', 8682'-8689'. Obtain Slow pump rates @ 8496' MD, 3527 TVD. Pump #1 - 25 SPM - 490 PSI, 35 SPM - 650 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM -670 PSI. Pumped 35 bbl Hi-vis weight sweep @ 8483' w/ 10% increase in cuttings. K-REV's 44852 (6 stands on sliders in hole) 1/24/2006 00:00 - 10:30 10.50 DRILL DRLH PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 8723' - 9617' (991') MD. TVD = 3541'. ADT = 8.9 hrs. PU WT = 130K, SO WT = 55K, ROT WT = 82K. Torque on/off bottom = 7/6.OK. Pumps - 330 GPM's - 2900 PSI. RPM's = 120. WOB = 5-15K. Total Bit HRS =21.5 hrs. Total Jar HRS = 90.04 Mud Wt = 8.75 PPG, Visc = 79, ECD = 11.19 PPG, Max gas = 457 Units. Observed drilling through concretions from 8727-8732', 8769'-8773', 8792'-8801', 8849'-8871', 8883'-8895', Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Page 12 of 2~ Operations: Summary Report Legal Well Name: 1 J-166 Common W ell Name: 1J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLIN G Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To ,Hours Code .Code Phase Description of Operations 1/24/2006 00:00 - 10:30 10.50 DRILL DRLH PROD2 8904'-8911', 8941'-8955', 8981'-8995', 9078'-9084', 9259'-9260', 9290'-9292'. Obtain Slow pump rates @ 9430' MD, 3537' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 790 PSI. Pump #2 - 25 SPM - 620 PSI, 35 SPM -800 PSI. 10:30 - 12:00 1.50 DRILL CIRC PROD2 Wait on geology decision from town. 12:00 - 12:45 0.75 DRILL CIRC PROD2 Worked pipe from 9527'-9617' while waiting on geology to evaluate log data w/ 84 spm, 2600 psi, 120 rpm, TO off=6K Pulled up to 9340' to begin sidetracking operations. 12:45 - 19:30 6.75 DRILL OTHR PROD2 Cut groove and trough from 9340' to 9380'. Time drilled to 9389'. Checked for sidetrack, no good. Pulled up to 9383' and cut trough. Time drilled again to 9389'. ADT=3.49 hrs. 19:30 - 22:00 2.50 DRILL DRLH PROD2 Drilled from 9389' to 9617'. ADT=1.75 hrs. 22:00 - 00:00 2.00 DRILL DRLH PROD2 Drill 6 3/4" B Lateral w! Sperry-Sun GeoPiolt from 9617' - 9714' (97') MD. TVD = 3566'. ADT = 1.25 hrs. PU WT = 135K, SO WT = 55K, ROT WT = 82K. Torque on/off bottom = 6/7.OK. Pumps - 330 GPM's - 3050 PSI. RPM's = .120. WOB = 4-15K. Total Bit HRS before sidetrack =43.43 hrs. Total Jar HRS = 98.28ud Wt = 8.75 PPG, Visc = 74, ECD = 11.19 PPG, Max gas = 43 Units. Observed drilling through concretions from 9598'-9601', 9615'-9626', 9672'-9686'. Obtain Slow pump rates @ 9430' MD, 3537' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 790 PSI. Pump #2 - 25 SPM - 620 PSI, 35 SPM -800 PSI. Krevs=187393 1/25/2006 00:00 - 08:00 8.00 DRILL DRLH PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 9714' - 10458' (744') MD. TVD = 3555`. ART=6.4 08:00 - 08:30 0.50 DRILL CIRC PROD2 Wait on geology decision from town. Circa @ 57 spm, 200 gpm, 1600 psi, 100 rpm, TO ofF=6K. 08:30 - 12:00 3.50 DRILL DRLH PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 10458' - 10755' (297') MD/ 3555' TVD. ADT =2.1 hrs. Total Bit HRS =54.93 hrs. Total Jar HRS =106.8 PU WT = 140K, SO WT = OK, ROT WT = 80K. TQ on/off=7/6.5K. Pumps - 330 GPM's - 3250 PSI. RPMs = 120. WOB = 5-15K. Mud Wt = 8.75 PPG, Visc = 79, ECD = 11.76 PPG, Max gas = 54 Units. Observed drilling through concretions from 9760'-9775', 9780'-9784', 9796'-9800', 9804'-9810', 9867'-9870', 9883'-9886', 9897'-9901', 9944'-9952', 10034'-10037', 10053'-10065'. SPR#1=25stk/680psi,35stk/790psi SPR#2=25spm/680psi,35stk/850psi @ 10458 MD/ 3555 TVD 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 10755' - 11745' (990') MD / 3542' TVD. Pumped a 30 bbl hi-vis weighted sweep @ 10,739' and observed a 10% increase in cuttings across the shakers. Total Bit HRS=63.96. Total Jar HRS =115.81 ADT =9.03 hrs. PU WT = 170K, SO WT = OK, ROT WT = 90K. TO on/off = 8.5/8 Pumps - 330 GPM's - 3600 PSI. RPM's = 120. WOB = 4-16K. Mud Wt = 8.75 PPG, Visc = 72, ECD = 11.94 PPG, Max gas = 52 Units. Observed drilling through concretions from 10768'-10772', 10804'-10807', 11075'-11076', 11105'-11106', 11110'-11112', 11116'-11120', 11123'-11126', 11136'-11138', 11149'-11157, 11163'-11178', 11185'-11190', 11200'-11208', 11248'-11253', 11263'-11270', 11290'-11294', 11510'-11518', 11521'-11533' SPR#1=25stk/680psi,35stk/850psi SPR#2=25spm/670psi,35stk/850psi @ 11381 MD/ 3533TVD KREVs=335868 1/26/2006 00:00 - 09:45 9.75 DRILL DRLH PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 11,745' - 12,524' Printed: 2/13/2006 12:29:18 PM • ConocoPhillips Alaska Operations Summary Report Page 13 of 2~ Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date ~ From - To Hours Code Code Phase 1/26/2006 00:00 - 09:45 9.751 DRILL DRLH PROD2 ',09:45-10:15 1 /27/2006 10:15 - 12:00 12:00 - 16:45 16:45 - 18:30 18:30 - 18:45 18:45 - 00:00 00:00 - 05:15 05:15 - 06:15 06:15 - 09:30 09:30 - 12:00 12:00 - 12:45 12:45 - 15:30 15:30 - 16:45 16:45 - 17:00 17:00 - 21:30 ? 1:30 - 21:45 0.501 DRILL I CIRC 1.751 DRILL I DRLH 4.751 DRILL I DRLH 1.751 DRILL I CIRC 0.251 DRILL OBSV i 5.25 DRILL WIPR 5.25 DRILL WIPR 1.00 DRILL CIRC 3.25 DRILL WIPR 2.50 DRILL WIPR 0.75 DRILL WIPR 2.75 DRILL CIRC 1.251 DRILL I CIRC 0.251 DRILL I OBSV 4.50 DRILL TRIP 0.25 DRILL OBSV IPROD2 IPROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Start: 1 /7/2006 Rig Release: 2/11/2006 Rig Number: Spud Date: 1/8/2006 End: 2/11 /2006 Group: Description of Operations (779') MD. TVD = 3566'. ART=7.43 PUW=165K SOW=O ROT=107K Wait on geology decision from town. Pumped 30 bbl weighted hi-vis sweep @ 93 spm, 330 gpm. Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 12,524' - 1700' (176') MD/ 3583' TVD. ADT =1.02 hrs TDT=8.45. Total Bit HRS =75.41 hrs. Total Jar HRS =124:3 PU WT = 170K, SO WT = OK, ROT WT =105K. TO on/off=8.9/8.5K. Pumps - 330 GPM's - 4000 PSI. RPMs = 120. WOB = 5-15K. Mud Wt = 8.75 PPG, Visc = 72, ECD = 12.05 PPG, Max gas = 40 Units. Observed drilling through concretions from 12015'-12021', 12056'-12062', 12146'-12154', 12159'-12162', 12207'-12219', 12257-12261', 12268'-12281', 12546'-12550'.. SPR#1=25stk/730psi,35stk/920psi SPR#2=25spm/730psi,35stk/920psi @ 12524 MD/ 3566 TVD Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 12700' - 12952' (252') MD / 3591' ND. Pumped a 30 bbl hi-vis weighted sweep @ 12,745' and observed a 50% increase in cuttings across the shakers. (Pumped another sweep @ 12,952' and observed 100% increase in cuttings. ECD prior to 1st sweep=11.89 after last sweep =11.45) Total Bit HRS=79.5. Total Jar HRS =128.4 ADT =4.09 hrs. PU WT = 205K, SO WT = OK, ROT WT = 111 K. TO on/off = 10.5/9K Pumps - 330 GPM's - 4050 PSI. RPM's = 120. WOB = 4-15K. Mud Wt = 8.75 PPG, Visc = 67, ECD = 12.01 PPG, Max gas = 41 Units. Observed drilling through concretions from 12843'-12854', 12861'-12868', 12905'-12918', 12935'-12938'. KREVs=158305 Pumped hi-vis sweep @ 12,952' and 2X BU w/ 90 spm, 4000 psi, 140 rpm, and TQoff=8K. Garnered SPRs. Observed well, static. SPR#1=25stk/700psi,35stk/910psi SPR#2=25spm/730psi,35stk/940psi @ 12952 MD/ 3591 TVD BROOH from 12,952' to 9,620' w/ 140 rpm, 3500 psi, 330 gpm. BROOH from 9,620' to window @ 5,380' w/ 140 rpm, 330 gpm, 3000 psi. Pumped weighted hi-vis sweep @ 5,380' w/ 330 gpm, 2200 psi. Observed a negligible 5% increase in cuttings. Monitored well, static. RIH from 5,380' to 10,368' where SOW=O. Washed through a bridge @ 9,246'. Washed and reamed from 10,368' to 12,290' w/ 248 gpm, 2800 psi, 120 rpm, TO=7.5K. PUW=155K SOW=45K ROT=110K Washed and reamed from 12,290' to 12,952' Pumped a 35 bbl weighted hi-vs sweep followed by 3 BUs @ 85 spm, 302 gpm, 3900 psi, 140 rpm, TQ=8.5K Displaced to SFOBM w/ 85 spm, 302 psi, 3900 psi, 120 rpm, TQ=8.5. PUW=190K SOW=OK ROT=112K 3arnered SPRs. Monitored well, static. Dropped 1 7/8" rabbit. 5PR#2=25stk/550psi, 35stk/830psi @ 12,952' MD/ 3592' TVD w/ 8.8 'PG SFOBM. POOH from 12,952' to above window @ 5,347'. Jbserved well, static Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Page ~4 of 2E Operations Summary Report Legal Well Name: 1 J-166 Common W ell Name: 1J-166 Spud Date: 1/8/2006 Event-Nam e: ROT -D RILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number. Date From - To Hours Code Sub Code Phase Description of Operations 1/27/2006 21:45 - 00:00 2.25 DRILL TRIP PROD2 POOH from 5,34T to BHA @ 369'. KREVs=218619 1/28/2006 00:00 - 00:15 0.25 DRILL PULD PROD2 Rack back 2 stds HWDP w/jars, 1 std NMFDCs. UD BHA SMT sub, flt sub. 00:15 - 01:00 0.75 DRILL OTHR PROD2 Downloaded MWD. 01:00 - 01:45 0.75 DRILL PULD PROD2 Cont'd to UD BHA including: DM HOC, NMFDC, Geo-pilot, and bit. 01:45 - 02:15 0.50 DRILL PULD PROD2 Cleaned and cleared rig floor. UD BHA tools. 02:15 - 02:45 0.50 WINDO ULD CMPLT2 M/U BHA including: 1 jt 3.5" HWDP, hook, flt sub, bumper sub, oil jars, XO, and 3 stds push pipe. 02:45 - 05:45 3.00 WINDO RIP CMPLT2 RIH retorquing super sliders on the way in (90 total). RIH to 5,333'. PUW=130 SOW=95 05:45 - 06:00 0.25 WINDO RIP CMPLT2 Washed down to 5,386' and attempted to hook whipstock. Turned 1/4 turn 3 times and hooked on 4th try. Pulled 50K over; jars fired w/ no release. Second try pulled 60K over; jars fired w/ release and shear of trip anchor. PUW=140K 06:00 - 06:45 0.75 WINDO IRC CMPLT2 Pulled up to 5,363' and CBU @ 56 spm, 200 gpm, 950 psi. 06:45 - 09:45 3.00 WINDO RIP CMPLT2 POOH from 5,363' to 61'. 09:45 - 11:15 1.50 WINDO ULD CMPLT2 UD XO, oil jars, bumper sub, float sub, 1 jt 3.5" HWDP, hook. UD whipstock debris sub, shear disc sub, bottom trip anchor blanking sub, flex jt, 2 jts 3.5" DP, unloader sub, locator sub w/seal unit. 11:15 - 12:00 0.75 WINDO ULD CMPLT2 Cleared and cleaned rig floor. 12:00 - 12:30 0.50 CASE RURD CMPLT2 R/U to run 4 1/2" liner in "B" Lateral. 12:30 - 16:30 4.00 CASE RUNC CMPLT2 Held PJSM. Ran 4 1/2" liner to 5,591'. Tagged up on "D" Lateral ZXP. 16:30 - 17:00 0.50 CASE RUNC CMPLT2 Pulled up to 5,365'. Attempted to go through window, no luck. Turn 90 deg, try again -through window @ 5380+'. 17:00 - 18:30 1.50 CASE RUNC CMPLT2 Cont'd to run liner from window to 7,500'. PUW=83K SOW=60K 18:30 - 19:45 1.25 CASE RUNL CMPLT2 PJSM. Discuss safety issues and procedure for making up Slim Hole MWD assmy. Make up Baker Model B1 FHH Hook Hanger assembly, pups, with crossoverjoint, Casing Swivel, running and setting tools. Make up Ball seat shear sub and Slimhole MWD assembly, oriented 180 DEG from Hook on hanger. Ran in 2 stds and SHT MWD equip. PUW=84K SOW=62K 19:45 - 21:45 2.00 CASE RUNL CMPLT2 TIH on DP to 11,636'. Slack-off weight nearly equal to block weight. PUW=137 SOW=36K 22:45 - 00:00 1.25 CASE RUNL CMPLT2 Worked pipe to 12,727' with very little down weight. PUW=185 SOW=36-38K 1/29/2006 00:00 - 02:00 2.00 CMPLTN OTHR CMPLT2 Cont'd to RIH w/ DP and very little down weight. Oriented hook to high side and worked liner to 12,919' w/ the hook 10' past the window. Pulled up and re-oriented hook, set hook @ 5394' (2' low) and 29? right of highside (whipstock for window milling set @ 5? left of high-side). Pulled up and re-hooked to verify with same toolface and depth. Top of hook assembly @ 5,377.27' and bottom of hook assembly @ 5,394.13'. PUW=185K SOW=40K 02:00 - 02:30 0.50 CMPLTN OTHR CMPLT2 Dropped ball and pumped down w/ 2 bpm, 680 psi. Ball bumped @ 511 stks and pressured up to 3500 psi. Released from hook, continued to pressure up to 4200 psi to shear out ball seat. 02:30 - 03:00 0.50 CMPLTN CIRC CMPLT2 Racked back 1 std push pipe, UD 1jt 4" DP. CBU w/ 70 spm, 1300 psi, 247 gpm. 03:00 - 04:45 1.75 RIGMNT RSRV CMPLT2 Slipped and cut drilling line, serviced top drive, inspected saver sub. 04:45 - 07:00 2.25 CMPLTN TRIP CMPLT2 TOOH from 5,254' to 56'. Trip out displacements Calc=42.21 bbls Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Operations Summary Report Page 15 of 25 Legal Well Name: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To I ' Hours Code ~. Code 1/29/2006 04:45.-07:00 2.25 CMPLTN TRIP 07:00 - 08:00 1.00 CMPLTN PULD 08:00 - 09:45 1.75 RIGMNT RGRP 09:45 - 10:15 0.50 CMPLTN RURD 10:15 - 12:00 1.75 CMPLTN PULD 12:00 - 14:30 14:30 - 15:00 1 /30/2006 15:00 - 15:30 15:30 - 16:00 16:00 - 18:00 18:00 - 18:45 18:45 - 21:45 21:45 - 00:00 00:00 - 01:15 01:15 - 01:45 01:45 - 02:30 02:30 - 06:15 06:15 - 07:15 D7:15 - 09:30 D9:30 - 10:45 10:45 - 12:15 12:15 - 12:30 2.50 0.50 0.50 0.50 2.00 0.75 3.00 2.25 1.25 0.50 0.75 3.75 1.00 2.25 1.25 1.50 0.25 CMPLTN TRIP CMPLTN PCKR CMPLT PCKR CMPLTN CIRC CMPLTN TRIP CMPLT PULD WINDO ULD WINDO RIP Phase '' CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 I CMPLT2 CMPLT2 CMPLT2 CMPLT2 PROD3 PROD3 PROD3 PROD3 RC PROD3 ;ML PROD3 WINDO IRC PROD3 WINDO RIP PROD3 WINDO ULD PROD3 WELLS EQRP PROD3 WINDO ULD PROD3 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations Actual=48.0 bbls. UD BHA, liner running tool, slim hole MWD. C/O saver sub. R/U casing equip. Held PJSM. M/U LEM to 430.2'. Baker Seal assembly (3.26'), Crossoverjoint IBT x STL (43.04'), 4 1/2" IBT pup (30.88'), Camco "DB" Nipple 3.563" ID (1.55'), 4 1/2" IBT JNT (31.38'), 4 1/2" IBT pups (9.83), LEM assembly (35.93'), 7 - JNTs of 4 1/2" IBT (215.49'), 4 1/2" IBT pup (3.82'), Baker Casing Swivel (2.82'), XO Bushing (1.40'), 109-47 Casing Seal Bore receptacle (19.69'), ZXP Liner Top Packer (19.03'). Total tools to stay in hole 417.2'. TIH w/ LEM assy. from 430' to 5,521'. PUW=133K SOW=100K Good indication of latch up w/ 35K over on downweight. Pulled up gently w/ 5K overpull to 138K. Set down 40K. LEM in .place with top,@ 5367.22'. Top of ZXP packer element @ 5104.38'. Dropped 1.75" ball and pumped down w/ 30 spm, 350 psi. Seated ball and pressured up to 2200 psi release pressure. Slowly pressure up to 4400 psi. Bled pressure to zero. Release from LEM. Tested ZXP packer to 1000 psi for 5 mins. P/U 8' with PUW=128K down from 133K. Verify top of ZXP @ 5104 with tag. POOH to 5039'. CBU w/ 1300 psi, 70 spm. Monitored well, static. POOH from 5039' to 42'. Trip out displacements Calc=44 bbls Actual=47.0 bbls. UD running tool. Cleaned and cleared rig floor. P/U and M/U whipstock and mill BHA. Uploaded MWD, SHT MWD w/ 82 spm, 291 gpm, 900 psi. TIH from 466' to 3,362'. PUW=84K SOW=74K Made MAD pass from 4,660' to 4,690'. Oriented 15? left of high side. RIH to 4,997' and oriented @ 15? left of high side w/ 86 spm, 300 gpm, 2450 psi. Tagged ZXP @ 5104'. Set trip anchor w/ 20K down weight. Pulled up to 130K to confirm setting. Whipstock set @ 18? left of high side. Set down w/ 50K down weight to shear bolt. Mill @ 5,005' for window cutting. Held PJSM and displaced well to MOBM. Garnered SPRs. SPR#1=25stk/340psi, 35stk/490psi SPR#2=25stk/350psi, 35stk/500psi @ 5046' MD / 3423' TVD 8.8+MW Milling from 5,005' to 5046'. Milled window from 5,005' to 5,017' + 20' of gauged hole to 5037'. TD= 5,046' Milled w/ 80 spm, 2400 psi, 120 rpm. TOW=5,005' BOW=5,017" Worked mill through window w/ 120 rpm, 86 spm, 300 gpm, 2400 psi. Rotated through window up and down 6 times. Slid through window twice w/pumps on, no problems. Monitored well, static. Pumped dry job and POOH from 5,046' to 98'. PUW=125K SOW=90K prior to POOH. UD mill, XO, bumper sub, downloaded MWD, TM, MWD, DM, F/S, 1 jt 3.5" HWDP, window mill, lower and upper mill (upper mill in gauge). Removed mill and BHA from rig floor. Drained stack after milling operations. Pulled wear bushing. R/IU and flushed stack. R/D stack washer. UD mining BHA from rig floor. Printed: 2/13/2006 12:29:18 PM • ConocoPhillips Alaska Operatiolns Summary Report Page 16 of 2~ Legal Well Name: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code ode 1/30/2006 ~ 12:30 - 15:30 ~ 3.00 ~ WELCTL BOPE 15:30 - 15:45 0.25 WELLSF 15:45 - 18:00 2.25 DRILL 18:00 - 20:00 2.00 DRILL 20:00 - 00:00 4.00 DRILL 1/31/2006 00:00.- 12:00 12.00 DRILL EORP PULD TRIP DRLH DRLH Phase IPROD3 PROD3 PROD3 IPROD3 ~PROD3 PROD3 12:00 - 16:45 4.751 DRILL DRLH I PROD3 16:45 - 17:00 0.25 DRILL 17:00 - 17:45 0.75 DRILL 17:45 - 20:30 2.75 DRILL ?0:30 - 22:30 2.00 DRILL DRLH PROD3 TRIP PROD3 TRIP PROD3 TRIP PROD3 ?2:30 - 00:00 1.501 DRILL I PULD I PROD3 Spud Date: 1/8/2006 Start: 1/7/2006. End:. 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of ©perations R!U and test BOP stack, HCR's & manual valves. Test Choke mainfold valves 1-14, upper & lower IBOP valves, floor safety valve & dart valve.All tests 250 PSI Low / 3500 PSI High. Recorded on chart. Accumulator test: Starting=3000 psi Ending=1900 psi after all elements closed. Recovery time=3 min 4 sec. Nitrogen bottle pressure=2100 psi Chuck Shieve with AOGCC waived witness of test. Tested gas alarms and PVT and high flow alarms. R/D test equipment. Set wear bushing. P/U and M/U BHA #9 including: bit, geo-pilot, pony collar, DM, smart stab, slimphase, PWD, TM, NM F/S, stab. Uploaded MWD. Cont'd M/U NM flex DCs, XO, 2 std HWDP, jars, .Broke in geo-pilot bearings and SHT MWD w/ 84 spm, 1400 psi. TIH from 369' to 4,949'. Went through window, and TIH to 5,036'. Reamed to 5,046' w/ 90 rpm, 84 spm, 2100 psi, TQ=4K. PUW=91 K SOW=75K Drilled from 5,046' to 5,506' MD / 3,460' TVD. ADT=2.51 hrs. Jar hrs=125.89 PUW=107K SOW=65K ROT=80K TQon/off=5/4.5K Max Gas=149 Units Max ECD=10.09 SPR#1=25stk/380psi, 35stk/550psi SPR#2=25stk/390psi, 35stk/560psi @ 5133' MD / 3441' TVD 8.9+MW Drilled from 5,506' to 7188' MD / 3,465' TVD. ADT=8.12 hrs. Jar hrs=136.52 PUW=110K, SOW=60K, ROT=80K, TQon/ofF=6K, 6K Max Gas=184 Units. Max ECD=10.24 SPR#1=25stk/420psi, 35stk/610psi SPR#2=25stk/460psi, 35stk/600psi @ 7094' MD / 3447' TVD 8.8+MW Concretions @ 5713'-5722' (9'), 5757'-5761'(4'), 5769'-5774'(5'), 5787'-5789'(2'), 6039'-6040'(1'), 6981'-6984'(3'), 6993'-6998'(5'). Total concretions this tour = 29'. Drilled from 7,188' to 7,530' MD / 3,448' TVD. ADT=4.17 hrs. Jar hrs=140.69 PUW=108K, SOW=60K, ROT=80K, TQon/off=6K, 6K Max Gas=81 Units. Max ECD=10.26 SPR#1=25stk/420psi, 35stk/580psi SPR#2=25stk/430psi, 35stk/600psi @ 7530' MD / 3448' TVD 8.7+MW Concretions @ 7453'-7474' (19'), 7481'-7499'(18'), 7506'-7528'(22'). Total concretions this tour = 59'. Last survey @ 7494.91' MD, 3451.91 TVD, INC = 89.81 DEG, AZ = 352.77 DEG. Pump up surveys. Obtain SPR's. Monitor well -static. POOH on elevators from 7530'-7191' (339'). Observe hole not taking groper fill 3ROOH from 7191' - 5136' (2055'), @ 92 SPM, 326 GPM, and 2500 'SI. Pull assembly through window @ 5005' with no issues up to 4949'. Monitor well -static. POOH 15 stands, observed well 3 BBLS behind in `ill. Continue POOH to 2735'. Hole fill good, well static. Calcualted iisplacement = 29.5 BBLS. Zack back 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill ;ollars. Plug in and download MWD assembly. Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Operations Summary Report Page 17 of 2E Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date 2/1 /2006 I Sub ', From - To ~ Hours ~ Code .Lode 00:00 - 00:30 I 0.501 DRILL PULD 00:30 - 01:30 1.00 01:30 - 02:45 1.25 02:45 - 03:15 0.50 Phase PROD3 DRILL PULD PROD3 DRILL OTHR PROD3 DRILL TRIP PROD3 03:15 - 03:45 0.50 DRILL OTHR PROD3 03:45 - 06:45 3.00 DRILL TRIP PROD3 06:45 - 12:00 5.25 DRILL DRLH PROD3 12:00 - 17:00 I 5.001 DRILL I DRLH I PROD3 17:00 - 18:00 1.00 DRILL WIPR 18:00 - 21:45 3.75 DRILL DRLH ?1:45 - 23:00 1.25 ?3:00 - 00:00 1.00 DRILL DRLH DRILL DRLH PROD3 PROD3 PROD3 PROD3 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations Continue POOH, Breakout & lay down BHA. Lay down NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR &RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'), 5200 Geo Pilot #002 (16.19') & 6 3/4" Hycalog CRXE 1005H+ bit. Inspected bit & gauged to a 1 / 1, we will rerun. Observed bearing pack in Geo -Pilot seized up. Housing would not spin freely. Make up BHA #9. Make up 6 3/4" Hycalog bit (5RR1) on backup 5200 Geo-Pilot (16.19'), NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR &RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'). Plug in and upload MWD assembly. Trip in hole to 1304'. Picking up 3 -Non Mag Flex Drill collars (92.70'), Crossover (1.61'), 3 - 4" HWDP (90.77'), 4 3/4" Drilling jars (28.81'), & 2 - 4" HWDP (60.48'). Total BHA = 369.79' Rig up and perform Shallow pulse test on MWD assembly. Good test. Break in seals on Geo-Pilot, downlink same. All tests good. Continue trip in hole from 1304' - 7530' (6226'). Wash from 7471' - 7530' at 94 SPM, 330 GPM, 2750 PSI, Rotating 50 RPM's with 6K torque. Continue Directional drilling from 7,530' to 7,845' MD / 3,452' TVD. ADT=4.00 hrs. Jar hrs=144.69 PUW=110K, SOW=56K, ROT=80K, TQon/off=6K, 6K Max Gas=43 Units. Max ECD=10.09 Concretions @ 7540'-7555' (15'), 7560'-7562'(2'), 7595'-7604'(9'), 7650'-7660' (10'),665'-7670' (5'),7749'-7824'(75'). Total concretions this tour = 116'. Last survey @ 7494.91' MD, 3451.91 TVD, INC = 89.81 DEG, AZ = 352.77 DEG. Continue Directional drilling from 7845' to 8359' MD / 3455' TVD. ADT=4.52 hrs. Jar hrs=149.91 PUW=114K, SOW=56K, ROT=80K, TQon/off=6K, 6K Max Gas=46 Units. Max ECD=10.47 SPR#1=25stk/450psi, 35stk/640psi SPR#2=25stk/450psi, 35stk/620psi @ 8030' MD ! 3441' TVD 8.7 MW Concretions @ 7834'-7855' (21'), 7869'-7890'(21'), 8009'-8022'(13'), 8132'-8136' (4'), 8150'-8158' (8'). Total concretions this tour = 67'. Last survey @ 8359' MD, 3455 TVD, INC = 86.25 DEG, AZ = 352.59 DEG. Geologist decided to pull back and sidetrack as we were out of zone. BROOH from 8359' - 7845' (514') for sidetrack. Back ream at 93 SPM - 330 GPM -2850 PSI, 120 RPM's with 6.5K torque. No hole issues. Cut trough from 7845' - 7855' (10'). NOTE: We have 21 feet of concretions on either side of picked sidetrack point. Trough hole @ 330 GPM"s 2850 SPI, 120 RPM's, and 6K torque. Begin time drilling @ 3 :minutes per inch from 7855' -7869' observing no change in inclination and indication of falling back in OLD hole. Pull back to old hole @ 7845'. Cnce again, cut trough from 7845' - 7855' at same parameters as above. PU WT = 110K, SO WT = 56K, ROT WT =80K. TO = 6K. Time drill from 7855'-7856' at 4 minutes per inch, as per DD. ADT = .7 Printed: 2/13/2006 12:29:1 S PM • ConocoPhillips Alaska Operations Summary Report Page 18 of 25 Legal Well Name: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ~ Hours Gode Sub Code 2/1/2006 23:00 - 00:00 1.00 DRILL DRLH 2/2/2006 00:00 - 04:30 4.50 DRILL DRLH 04:30 - 05:00 0.50 05:00 - 06:00 1.00 06:00 - 12:00 6.00 12:00 - 15:30 3.50 15:30 - 19:30 4.00 19:30 - 20:00 0.50 20:00 - 20:30 0.50 20:30 - 21:00 0.50 21:00 - 00:00 3.00 2/3/2006 00:00 - 02:00 2.00 02:00 - 04:00 2.00 DRILL WIPR. DRILL DRLH DRILL DRLH DRILL DRLH DRILL DRLH Phase PRODS PRODS PRODS PRODS PRODS PRODS PRODS DRILL DRLH PRODS DRILL DRLH PRODS DRILL WIPR PRODS DRILL WIPR PRODS DRILL WIPR PRODS DRILL TRIP PRODS 04:00 - 05:00 1.00 DRILL OTHR PRODS 05:00 - 06:00 1.00 DRILL PULD PRODS Spud Date: 1!8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations HRS. TVD = 3452'. Continue time drill @ 4 minutes per inch from 7856' - 7870' (14'). Observed inclination @ 92 Degrees indicating bit being in Old Hole. Note: we have a 21' concretion on each side of the attempted sidetrack point. We need to make at least 10' of hole to obtain a good survey. Pull back up hole to 7658' after dicussing with DD & Geologist to a better sidetrack point. PU WT = 110K, SO WT = 56K. Work drill string and cut trough from 7670'-7680', at 100 RPM's, 94 SPM, 330 GPM, 2700 PSI with 6K torque. Time drill from 7680' until verified kicked off and good survey indications. Continue Directional Drill 6 3/4" hole in the "D" lateral to 7835' MD. 3473' TVD. ART = 5.11 HRS. PU WT = 110k, SO WT = 65K, ROT WT = 80K. MAx gas observed = 37 BTU's, Torque on /off bottom = 6K. Max ECD = 10.0 PPG. Jar HRS = 149.80 WOB = 0-2K, 110 RPM's, Pump at 93 SPM, 330 GPM & 2700 PSI. Continue Directional drilling from 7835' to 8359' MD / 3,472' TVD. ADT=2.91 hrs. PUW=112K, SOW=55K, ROT=80K, TQ on/off=6.5K, 6.5K Max Gas=64 Units. Max ECD=10.80 Concretions @ 7888'-7889' (1'). NOTE: 8359' =last Hole depth before sidetrack. Continue Directional drilling from 8359' to 8860' MD / 3478' TVD. ADT=3.09 hrs. Total Jar hrs=156.09 Total ADT = 6.29 HRS PUW=120K, SOW=50K, ROT=80K, TO on/off=6.5K, 6.5K Max Gas=64 Units. Max ECD=11.65 SPR#1=25stk/480psi, 35stk/650psi SPR#2=25stk/490psi, 35stk/650psi @ 8901' MD / 3479' TVD 8.7 MW Concretions @ 8563'-8568' (5'), 8604'-8609'(5'), 8611'-8613'(2'), 8620'-8622' (2'), 8839'-8844' (5'). Total concretions this tour = 20'. Last survey @ 8835' MD, 3475 TVD, INC = 86.43 DEG, AZ = 358.74 Total K-revs for the day = 27014 Trouble shooting Geo-Pilot Assembly. Indications are Geo-Pilot is not holding. desired tool face. Repeat trouble shooting attempts. Continue Directional. Drill From 8860' - 8901 (41'), while trouble shooting Geo-Pilot Assembly. Indications are Geo-Pilot is not recognizing commands and will not hole desired tool face. Suspect internal electronics failure as per DD. Repeat trouble shooting attempts with no success. Obtain Slow pump rates. Monitor well -static. Attempt to POOH on elevators, observe well swabbing. BROOH to 6817' (2084') @ 93 SPM , 330 GPM, 2800 PSI, 120 RPM's with 6.5K torque @ 60 -75 ft/ hr. Continue BROOH from 6817' - 5150' (1667'). Pull drilling assembly through window area @ 5005' with no issues. Continue POOH on elevators observing hole taking proper fill. Rack back 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars. Plug in and down load MWD assembly. POOH, breakout & lay down BHA #9. Lay down Lay down NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR & RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'), 5200 Geo Pilot #002 (16.19') & 6 3/4" Hycalog CRXE 1005H+ bit. Inspected bit & gauged to a 1 / 1/ WT / A / X / I ! NO Printed: 2/13!2006 12:29:18 PM • ConocoPhillips Alaska Operations' Summary: Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date !From -To Hours CodeCode Phase 2/3/2006 05:00 - 06:00 1.00 DRILL PULD PROD3 06:00 - 06:30 0.50 DRILL PULD PROD3 06:30 - 08:00 1.50 DRILL PULD PROD3 08:00 - 09:15 1.25 DRILL OTHR PROD3 09:15 - 09:30 0.25 DRILL TRIP PROD3 09:30 - 10:00 I 0.501 DRILL OTHR PROD3 2/4/2006 10:00 - 12:00 2.00. DRILL TRIP PROD3 12:00 - 12:30 0.50 DRILL TRIP PROD3 12:30 - 15:00 I 2.501 DRILL TRIP PROD3 15:00 - 00:00 I 9.001 DRILL I DRLH I PROD3 00:00 - 01:30 I 1.501 DRILL I DRLH I PROD3 01:30 - 02:00 0.501 DRILL DRLH I PROD3 02:00 - 12:00 I 10.001 DRILL I DRLH I PROD3 Page 19 of 2~ Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations / DTF. Clean & Clear floor area. Send tools outside. PJSM, Discuss safety issues and procedure for BHA make up. Make up BHA #10. MU 6 3/4" Security FSF2641 bit w/ 3 x 21 Jets TFA = 1.015sq in (1.27'), 5200 Geo Pilot #002 (16.22'), NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR & RES (24.51'), 4 3/4" Smart Stabilizer (3.59'),.4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'). Plug in and Up Load MWD assembly. Trip in hole making up 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars. Total BHA = 369.82'. Perform Shallow pulse test and break in Geo-Pilot bearings @ 81 SPM, 290 GPM, 1300 PSI, and 50 RPM's. Good test. Trip in hole from 455' - 4949' (4504'). PU WT = 90k, SO WT = 70K. PJSM, crew change -new crew. Fill drill string, and inspect saver sub on Top Drive. Continue trip in hole from 4949' - 8901' (3952'). Observe hole taking proper hole fill. Work assembly through window area with no issues. Continue RIH to 8873' MD. Wash & ream from 8873' - 8901'. Shoot 'survey @ 8873'. Continue Directional drilling from 8901' to 9750' MD / 3493' TVD. ADT=6.05 hrs. Total Jar hrs=162.14 Total ADT = 6.05 HRS PUW=125K, SOW=50K, ROT=85K, TO on/off=6.5K, 6.5K Max Gas=138 Units. Max ECD=10.45 SPR#1=25stk/ 530psi, 35stk/ 730psi SPR#2=25stk/ 530psi, 35stk/ 730psi @ 9244' MD / 3486' TVD 8.7 MW Concretions @ 8900'-8903' (3'), 9112'-9116'(4'), 9359'-9364'(5'), 9365'-9374' (9'), 9376'-9383' (7'), 9399'-9401' (5'), 9407'-9411' (4'), 9420'-9430' (10'), 9574'-9579' (4'), 9581'-9588' (7'), 9590'-9595' (5'). Total concretions this tour = 61'. Last survey @ 9675' MD, 3492 TVD, INC = 89.98 DEG, AZ = 354.87 Total K-revs for the day = 89530 Continue Directionakl Drill 6 3/4" D lateral from 9750',- 9898'. (148'). ART = 1.08 HRS. Trouble Shoot MWD. Could not get a good signal, and surveys were false & misleading. Repeat survey attempts until verifying tool working correctly and we had good surveys. Continue Directional drilling from 9898' to 10926' MD / 3455' TVD. ADT=7.63 hrs. Total Jar hrs=176.90 Total ADT = 8.71 HRS, Total Bit Hrs = 14.76. PUW= 125K, SOW= 40K, ROT= 80K, TO on/off=7K, 6K Max Gas=88 Units. Max ECD=11.55 SPR#1=25stk/ 600psi, 35stk/ 790psi SPR#2=25stk/ 620psi, 35stk/ 800psi @ 10269' MD / 3460' TVD 8.7+ MW Concretions @ 9574'-9579' (5'), 9581'-9588'(7'), 9590'-9595'(5'), 9740'-9755' (15'), 9758'-9778' (20'), 9932'-9935' (3'), 10164'-10169' (5'), 10251'-10255' (4'), 10391'-10409' (18'), 10468'-10470' (2'), 10560'-10571' (11'), 10678'-10685" (7'). Total concretions this tour = 102'. Pump A 30 BBL Hi Visc Weighted sweep @ 10552', observed a 5% increase in cuttings upon return. Survey @ 10422' MD, 3453 TVD, INC = 89.01 DEG, AZ = .96 NOTE :Drilled through a Fault @ 10160' MD, 3469' TVD, with an 81' Throw up. Printed: 2/13/2006 12:29:18 PM • GonocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code I Sub' Phase ~ Code_ ~ 2/4/2006 02:00 - 12:00 __ 10.00 DRILL DRLH PROD3 12:00 - 00:00 12.00 DRILL DRLH PROD3 2/5/2006 100:00 - 12:00 I 12.001 DRILL I DRLH I PROD3 12:00 - 13:45 I 1.751 DRILL DRLH PROD3 13:45 - 15:30 I 1.751 DRILL I CIRC I PROD3 15:30 - 00:00 I 8.501 DRILL I WIPR I PROD3 2/6/2006 100:00 - 02:15 I 2.251 DRILL I WIPR I PROD3 02:15 - 03:30 I 1.251 DRILL ~ CIRC ~ PROD3 03:30 - 04:45 1.251 RIGMNTI RSRV I PROD3 04:45 - 07:30 I 2.751 DRILL I WIPR I PROD3 07:30 - 12:00 I 4.501 DRILL I REAM I PROD3 Start: 1 /7/2006 Rig Release: 2/11/2006 Rig Number: Page 20 of 25 Spud Date: 1J8/2006 End: 2/11/2006 Group: Description of Operations Continue Directional drilling from 10926' to 12000' MD / 3489' ND. ADT=8.09 hrs. Total Jar hrs=184.99 Total ADT = 16.80 HRS, Total Bit HRS = 22.85. PUW= 145K, SOW= 35K, ROT= 95K, TQ on/off=9-10K, 8K Max Gas=61 Units. Max ECD=11.51 SPR#1=25stk/ 680psi, 35stk/ 830psi SPR#2=25stk/ 630psi, 35stk/ 850psi @ 11292' MD / 3467' ND. 8.7+ MW Concretions @ 11010'-11017' (7'), 11220'-11225' (5'), 11350'-11357' (7'), 11475'-11481' (6'), 11485'-11493' (8'), 11555'-11561' (6'), 11566'-11573' (7'), 11590'-11594' (4'), 11708'-11716' (8'). Total concretions this tour = 58'. Pump A 30 BBL Hi Visc Weighted sweep @ 11473', observed a 20% increase in cuttings upon return. Survey @ 11892' MD, 3488 ND, INC = 88.61 DEG, AZ = 1.08 Total K-revs for the day = 74338 Continue Directional drilling from 12000 ' to 12866' MD / 3525' ND. ADT=8.97 hrs. Total Jar hrs=193.96 Total ADT = 25.77 HRS, Total Bit HRS = 31.82. PUW= 177K, SOW= 35K, ROT= 106K, TQ ~ on/off=9-10K, 9.5K Max Gas=163 Units. Max ECD=11.75 SPR#1=25stk/ 740psi, 35stk/ 900psi SPR#2=25stk/ 760psi, 35stk/ 910psi @ 12198' MD / 3479' ND. 8.7+ MW Concretions @ 12003'-12018' (15'), 12023'-12037' (14'), 12039'-12058' (19'), 12556'-12559' (3'j, 12566'-12570' (4'), 12611'-12614' (3'), 12670'-12676' (6'), 12708'-12717' (9'). Total concretions this tour = 73'. Continue Directional drilling from 12866' to 12994' MD / 3530' ND. Well TD'd as per Geologist & Directional Driller: ADT=1.76 hrs. Total Jar hrs=195.72 Total ADT = 27.53 HRS, Total Bit HRS = 33.58. PUW= 180K, SOW= 35K, ROT= 110K, TO on/off=9-10K, 9.5K Max Gas=155 Units. Max ECD=11.80 g.7+ MW. Concretions @ 12936'-12940' (4'), 12946'-12954' (8'). Total concretions this tour = 12'. Survey @ 12994' MD, 3530.64 ND, 86.99 Deg INC., 3.93 Deg AZ. Total K-revs for the day = 120717. Total AVG ROP for bit = 122' FUHr Reciprocate & Rotate Drill String while CBU 2 times @ 300 GPM - 3900 PSI. Pump up final survey. Montor well -static. BROOH form 12994' - 7004' (5990'). Back ream at rates of 20 - 80 ft/minute @ 330 GPM - 3900 PSI to start, and then 2800 PSI at 7004'. 120 RPM's, with 7K - 9K torque. Continue BROOH at rates of 60 - 80 ft/minute @ 330 GPM - 2800 PSI at 120 RPM's, with 7K - 9K torque. Pulled assembly through window area with no issues. Pump a 30 BBL Hi Vis Weighted sweep, and circulate 3 bottoms up to verify clean hole conditions. Pump @ 330 GPM - 2550 PSI. Observed 5-10 % increase in cutting upon return of sweep. PJSM, Discuss safety issues and procedure for Slip & Cut. Slip & Cut 68' of drilling line. Inspect brakes & Top Drive. Trip back in hole on elevators, until run out of downweight @ 10087'. Observed good hole conditions and no issues. Make up Top Drive on each stand and wash & ream from 10087' - 12928' (2841'). Pump @ 44 SPM -1000 PSI Rotating @ 100 RPM's with Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Page 21 of 25 Operations Summary. Report Legal Well Name: 1 J-166 Common W ell Name: 1J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLIN G Start: 1/7/2006 End: 2/11/2006 (Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: Sub;: ~ Date From - To Hours Code Code Phase Description of Operations 2/6/2006 07:30 - 12:00 4.50 DRILL REAM PROD3 7K Torque. We were able to TIH on elevators from 11294' - 11496' (202') with 35 - 40K downweight, and no pump or rotation needed. 12:00 - 14:45 2.75 DRILL CIRC PROD3 Continue wash & ream from 12928'-12994' MD (66') 3530' TVD. Pump a 30 BBL Hi Vis Weighted sweep, and circulate 3 bottoms up to verify clean hole conditions While reciprocat & rotate drill string. Pump @ 82 SPM -300 GPM, 4000 PSI. 120 RPM's, 7-8K torque. PU WT = 180K, SO WT = 35K, Rotating WT = 105K. 14:45 - 16:00 1.25 DRILL CIRC PROD3 Monitor well -static. Held PJSM. Discussed Safety & Spill Issues. Assigned a Spill Champion for Displacement. Displace well with 8.7 PPG SFMOBM @ 300 GPM - 3950 PSI. Observe drill string tdrque up and stalled@ 11 K, 100 strokes short of displacement. Finish Displacement. Suspect difference in Lubricity from MOBM would not allow free rotation without excessive torque. 16:00 - 22:00 6.00 DRILL TRIP PROD3 POOH on elevators from 12994' - 369'. (12625'). Observed pulling up to 40K over at times initially off bottom, and hole taking proper fill. No issues while POOH. 22:00 - 23:30 1.50 DRILL PULD PROD3 Breakout & lay down BHA # 10. Layed down 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars, Stabilizer & Float Collar. 23:30 - 00:00 0.50 DRILL OTHR CMPLT3 Plug in and down toad MWD assembly. Total K-Revs= 46783 2/7/2006 00:00 - 00:15 0.25 DRILL SURV CMPLT3 Continue Download MWD assembly. 00:15 - 01:15 1.00 DRILL PULD CMPLT3 Breakout & lay down remaining BHA #10. Lay down 6 3/4" Security FSF2641 bit w/ 3 x 21 Jets TFA = 1.015sq in (1.27'), 5200 Geo Pilot #002 (16.22'), NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3!4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR & RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (i 1.54'). Grade Bit @ 1 / 1 / ER ! A/X/I/NO/TD. 01:15 - 02:15 1.00 DRILL PULD CMPLT3 Clear & Clean rig Floor Area. Pull 31 Lo-Tads to floor. Held PJSM. Discuss Safety issues and installation of Lo-Tads. 02:15 - 02:30 0.25 DRILL PULD CMPLT3 Make up BHA # 11. MU Baker Retrieving Hook (7.50'), 1 -jnt of 3 1/2" HWDP (28.84'), 4 3/4" Float Sub (2.41'), 4 3/4" Bumper Jar (7.87'), 4 3/4" Oil Jar (11.14'), Crossover (1.04') and 3 -stands of Hybrid Push Pipe (270.06'). 02:30 - 06:45 4.25 DRILL TRIP CMPLT3 Trip in hole from 328' -5000' (4672'). Install 31 total Lo-Tads on stands while RIH. PU WT = 128K, SO WT =98K. Observe hole taking proper fill 06:45 - 07:15 0.50 DRILL CMPLT3 Locate & wash retrieving slot pumping @ 4 BPM - 700 PSI. Attempt to engage slot. Work drill string installing 3/4 RH turns in string until observe engaged whipstock slot. Pull up to verify and fire jars with 75K overpull, whipstock free. Increase in upweight 5K. Pull up 30' no swabbing observed. 07:15 - 07:45 0.50 DRILL CIRC CMPLT3. Circulate bottoms up @ 7 BPM - 72 SPM - 1400 PSI. No gas or fluid loss 07:45 - 11:00 3.25 DRILL TRIP CMPLT3 Monitor well -static. POOH from 4972' -328' (4644'). Observe hole taking proper Hole fill. 11:00 - 12:00 1.00 DRILL PULD CMPLT3 Rack back 3 stands of Hybrid Push pipe, Breakout & lay down retrieving Hook BHA. Layed down Baker Retrieving Hook (7.50'), 1 -jnt of 3 1/2" HWDP (28.84'), 4 3/4" Float Sub (2.41'), 4 3/4" Bumper Jar (7.87'), 4 3/4" Oil Jar (11.14'), Crossover (1.04') 12:00 - 13:00 1.00 DRILL PULD CMPLT3 Breakout & Lay down Whipstock and space out assembly. Inspect Whipstock slide. Indications of milling full 12' on slide. Seals looked good. 13:00 - 13:45 0.75 CASE RURD CMPLT3 Clear & Clean rig floor area. Pull tools to floor. RU Liner running tools. Printed: 2/13!2006 12:29:18 PM ConocoPhillips l~laska Page 22 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLIN G Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.co m Rig Release: 2/11/2006 Group: Rig Name:. Doyon 141 Rig Number: Sub I Date From - To Hours Code . Phase Description of Operations Code 2/7/2006 13:45 - 17:30 3.75 CASE RUNC CMPLT3 PJSM, Discuss Safety Issues and procedure to run 4 1/2" Liner assembly. Make up 31/2" Bent joint with Guide shoe & crossover. Continue RIH picking up 4 1/2" liner. Avg. make up torque = 3500 ft/Ibs. Install total of 250 Hydroform Centralizers on each joint except constrictor jnts. Constrictors installed as to be spaced out at 10505', 9806', 8565', 8347', 8005', and 7825'. Total Slotted joints ran = 217, length = 6681.05'. Total Blank joints ran = 39. Total length = 1204.07'. 1.92 total stop rings run on first 160 joints, and last 32 joints. 17:30 - 18:15 0.75 RIGMNT RGRP CMPLT3 Trouble shoot hydraulic problem with Power Tongs. Motor failed. Lay down bad tings, and RU backup set. 18:15 - 22:00 3.75 CASE RUNC CMPLT3 Continue run 4 1/2" Liner to 7960'. PU WT = 86K, SO WT = 55K. Obtain TAD parameters every 10 joints on TIH. 22:00 - 00:00 2.00 CASE RUNC CMPLT3 PJSM. Discuss Safety issues and procedure for making up Slimhole MWD assembly. Pull tools to floor and RU tongs. Make up Slimhole MWD assembly as per MWD & BOT hands. Orient MWD to 180 Degrees out from Hook Hanger hook. 2/8/2006 00:00 - 00:15 0.25 CASE RUNC CMPLT3 Continnue Making up Slim Hole MWD Assembly, and Hook Hanger. PU WT = 87K, SO WT = 60K. Pick up 1 stand of DP, perform shallow pulse test @ 33 SPM, 117 GPM, 600 PSI. Good test. 00:15 - 00:45 0.50 CASE RUNL CMPLT3 Continue run liner on Drill pipe from 7960' - 8359' (399'). Observed Guide shoe tracked ion to Old hole and bottomed out. Set down 10K. 00:45 - 02:30 1.75 CASE RUNL CMPLT3 POOH with 5 stands of Drilll pipe, and stand back 3 stands of 4 1/2" liner. With guide shoe above kick off point, rotate 3.5 right hand turns in liner. PU WT = 97K, SO WT = 55K. 02c30 - 03:00 0.50 CASE RUNL CMPLT3 Run in hole with 4 1/2" liner from derrick and continue with Drill Pipe. NOTE: We did not breakout MWD asembly as it was stood back in Derrick with Hook Hanger. Observed Guide shoe assembly in new hole. 03:00 - 06:00 3.00 CASE RUNL CMPLT3 Continue RIH with liner on drill pipe from 8444' - 12906'. No issues running through fault area at 10160'. Tagged bridge at 12906'. PU WT = 187K. 06:00 - 07:00 1.00 CASE RUNL CMPLT3 Work string to observe getting past bridge area, and continue to RIH, observing weight falling off, and having to pick up and work through spots. Locate bottom of window @ 5019', working string to allow Hook Hanger to Hook. Obtain good MWD reading @ 20 Deg. L, set Hook on window @ 5019' MD, and observe survey @ 8 deg. L two times. PU 20', turn string 180 Deg. Work torque to Hook ,and slack off 8' past bottom of window. Observe difficulty in moving string as the weight did not allow us to move freely. Pull up hole 30'. Install 180 Deg turn in string. Work torque down to Hook. MWD survey at 8 Deg. Left. Set Hook Hanger with better movement in string as we worked it, observing MWD survey @ 6 Deg Right when set. Repeat same operation with the same 6 Deg. Right survey 2 times to confirm definite Hook Hanger Hooked on window @ 5019' MD = 2' Low . UP & Down weights while working string 175-200K up, 50 -30K down. 07:00 - 07:30 0.50 CASE RUNC CMPLT3 Rig up, drop 29/32" ball. Pump ball down @ 3 BPM - 700 PSI until observe ball seated @ 448 strokes. Bring pressure up to 2950 PSI, wait 3 minutes, continue bring pressure up to 4200 PSI to shear ball seat. Bleed all pressures. Pick up to verify free of Hook Hanger and loss of weight. PU WT = 125K, SO WT = 105K. 07:30 - 12:00 4.50 CMPLTN TRIP CMPLT3 POOH with Drill pipe, inspecting & removing all Lo-Tads, and Super Sliders. Racking back drill pipe in derrick to drain. Crew Change 12:00 - 15:00 3.00 CMPLTN TRIP CMPLT3 Continue POOH standing back DP, inspecting and removing all Printed: 2/13/2006 12:29:18 PM GonocoPhillips Alaska Page 23 of 25 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-166 1 J-166 ROT -DRILLING n 1334@ppco. com Doyon141 Spud Dater 1/8/2006 Start: 1 /7/2006 End: 2/11 /2006 Rig Release: 2/11/2006 Group: Rig Number: Date From - To Hours ~ Code Code Phase 2/8/2006 12:00 - 15:00 3.00 CMPLTN TRIP CMPLT3 15:00 - 15:45 0.75 CMPLTN SFTY CMPLT3 15:45 - 17:00 1.25 CMPLT TRIP CMPLT3 17:00 - 18:00 1.00 CMPLTN TRIP CMPLT3 18:00 - 18:30 0.50 CMPLTN OTHR CMPLT3 18:30 - 19:30 1.00 CMPLTN SFTY CMPLT3 19:30 - 20:00 0:50 CMPLTN OTHR CMPLT3 20:00 - 00:00 4.00 CMPLTN OTHR CMPLT3 2/9/2006 00:00 - 09:15 9.25 CMPLTN OTHR CMPLT3 09:15 - 09:45 0.50 CMPLTN OTHR CMPLT3 09:45 - 10:00 0.25 CMPLTN OTHR CMPLT3 10:00 - 10:15 0.25 CMPLTN OTHR CMPLT3 10:15 - 11:15 1.00 CMPLTN PULD CMPLT3 11:15 - 12:00 0.75 CMPLTN PULD CMPLT3 12:00 - 15:45 3.75 CMPLTN PULD CMPLT3 15:45 - 17:30 1.75 CMPLTN PULD CMPLT3 17:30 - 18:00 0.50 CMPLTN NUND CMPLT3 18:00 - 00:00 6.00 CMPLTN RUNT CMPLT3 2/10/2006 00:00 - 00:30 0.50 CMPLTN RUNT CMPLT3 00:30 - 01:00 0.50 CMPLTN RUNT CMPLT3 01:00 - 02:30 1.50 CMPLTN RUNT CMPLT3 Description of Operations Lo-Tads & Super Sliders. Floor hand pinched fingers between Iron Roughneck, and Stump. Send hand to Medic immediately. Safety stand down on rig. Review & investigate incident with crew. Lay down last Lo-Tad. Stand back last stand. Clean off all Lo-Tads for SPCC, load & send outside. Clean off all sliders and send outside. Clear & clean floor area. Rig up, Breakout, inspect & lay down all Liner running tools and MWD assembly. All tools looked good. Rig up Mouse hole for laying down drill string. PJSM. Discuss safety issues and procedure for laying down drill pipe from derick. Incident investigation of accident on floor. Re-enact accident and inspect all equipment. All day & night supervisors participated. Discuss accident & prevention with crew. Change out hinge pins on doors of Iron Roughneck. Pull barrells of thread protectors to floor, rig up floor area and pipe shed to lay down drill pipe. Lay down dril pipe from derrick. PJSM. Discuss Safety issues and procedure to lay down DP using mousehole.. Continue lay down 74 stands of DP, 15 Stands of Hybrid Push Pipe, and 7 stands of 4" HWDP. Clear & Clean rig floor area. Send tools out. PJSM. Discuss safety issues and forward plan with crew. Changing out Geo-Span unit, Rigging up 4 1/2" Liner running equipment, & Running 4 1/2" Tbg in hole. Change out Geo-span unit on rig floor. Send old one to town for inspection. Rig up 4 1/2" Tubing running equipment. Double stack tongs. Run 4 1/2" Tubing in hole to 300'. Crew Change PJSM, with crew. Discuss Safety issues and forward plan as above. Continue RIH with a total of 123 joints of 4 1/2" tubing. POOH, rack back 41 stands of 4 1/2" tubing. 123 joints. Rig up bushing puller. BOLDS & pull wear bushing. Pull Centrilift equipment to rig floor. Stack, count & record clamps. PJSM with entire rig team &centrilift. Discuss safety issues including well control, and all pinch points & lifting procedures for equipment. Pull ESP cable to floor and hang sheave. Make up Baker Centrilift 5.62" OD 418 HP KMHFER 2610 Motor (33.85'), with 4.60" A-Well pump gauge (2.11') and 6" OD centralizer (2.00'). MU 5.13" Tandem Seal Section GSB 3 DB AB/HSN PFSA (13.80'),5.13" OD TTC Crossover w/ Screen Intake with 4-1/2" IBT pup (20.43'). Install oil, and CPAI witness free rotation of motor, utilizing CPAI checklist for installation of ESP assembly. SIMOPS: Change out mud pump liners to 6" in #1 pump. PJSM with entire rig team &centrilift. Discuss safety issues including well control, and all pinch points & lifting procedures for equipment.Continue running ESP Completion. Pick up #1 & #2 joints of 4 1/2" tubing.Start to PU A-Well Discharge Pressure sub. Observed that the OD of the Discharge Pressure sub measured at 6 3/8" OD. The ESP line OD = 5/8" Total = 7" OD. 7 5/8 casing ID = 6.875". Discuss options with town. Decision to run completion without it. Lay down Pressure sub & send out. Install 4 1/2" pup joint in place of Pressure sub. 9.87' long. Secure & plug unused "I" Line from A-well pump. Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Page 24 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date ~ From - To Hours Code Sub ~ Phase _ Code 2/10/2006 02:30 - 03:00 0.50 CMPLT RUNT CMPLT3 03:00 - 04:30 1.50 CMPLT RUNT CMPLT3 04:30 - 05:00 05:00 - 06:15 06:15 - 07:00 07:00 - 07:30 07:30 - 12:00 0.501 CMPLTNI RUNT I CMPLT3 1.25 CMPLT RUNT CMPLT3 0:75 CMPLTN RUNT CMPLT3 0.50 CMPLTN PULD CMPLT3 4.50 CMPLT PULD CMPLT3 12:00 - 14:00 14:00 - 16:45 16:45 - 20:15 20:15 - 21:00 21:00 - 00:00 2/11/2006 00:00 - 01:30 01:30-02:15 03:30 - 04;15 04:15 - 04:30 2.001 CMPLTNI PULD I CMPLT3 2.751 CMPLTNI RUNT I CMPLT3 3.501 CMPLTNI RUNT I CMPLT3 0.751 CMPLTNI RUNT I CMPLT3 3.001 CMPLTNI RUNT I CMPLT3 1.501 CMPLTNI RUNT I CMPLTN Description of Operations Conduct Insulation test on ESP Line. Good Test. Continue RIH with 4 1/2" tubing. Install GLM's # 1 & #2 to be positioned in well at depths of 3215' & 2606' as planned. Avg. Make up torque on tubiing = 3000 Ft / lbs. Conduct Insulation test on ESP Line. A-well Representative indicated a bad test, but advised continu running in hole as he believed the test unit he used was faulty. He repaired unit while continue RIH. Continue RIH with 4 1/2" tubing to 1775' . Conduct Insulation test on ESP Line. A-well Representative indicated a bad test, after repairing test unit and verifying bad test on A-Well pump. Recommend POOH to A-Well Pump. PJSM. Discuss safety issue & procedure on POOH, and prepare matting boards with pit liner for ESP line, for Spill prevention. POOH with 4 1/2" ESP completion tubing. Removing all Clamps, SS Bands. Standing back tubing in Derrick, and lay down GLM's. Disconnect ESP line from motor. Attempt to break out centrailizer, threads galled. Remove A-Well Pump Gauge. Crew Change. Observe "I" line was damaged when initially clamped up to motor assembly. Continue remove A-Well Pump gauge from Motor. Remove unused & damaged "I" line. Install new A-Well Gauge & Centralizer. Service Motor. Re-attach ESP line, service seals, and test equipment. RIH with Motor Assembly. Pick up 2 joints of 4 1/2" tubing from shed, 10' pup. RIH making up GLM's as mentioned above, installing cannon clamps on every other joint of tubing as per Centrilift Rep. RIH back to 1775'. Continue RIH with ESP conpletion assembly on 4 1/2" Tbg. Install Cannon Clamps on every other joint as per Centrilift Rep. Pick up GLM's #3 & #4, spaced out to be located in well at 148', and 94' as planned. Pick up landing joint. MU Vetco Gray 11" x 4 1/2" Hanger with 4.909" MCA top with 4 1/2" tubing joint made up on it, (30.00'). Install TWC. into hanger for RIH. MAke up joint to string and obtain UP WT = 82K, SO WT = 68K. Located hanger close to floor for Slice as per Centrilift Rep. Used a total of 68 Cannon Clamps, 4 stainless steel bands, 3 Protectolizers, and 2 Flat Guards. Splice ESP cable to hanger pigtail as per Centrilift Rep. SIMOPS:. Clear & Clean Floor area. Lay down all tubing running equipment. Count used clamps. Lay down Sheave with unused ESP line. Clean up all pit liner on matting boards and prepare Spooling unit for removal. Observed NO SPILLS on ground from ESP line & Spooling Unit. Continue Splice ESP cable to hanger pigtail as per Centrilift Rep. SIMOPS:. Clear & Clean Floor area. Lay down all tubing running equipment. Count used clamps. Lay down Sheave with unused ESP line. Rig down Spooling unit, prepare to move unit. 0.75 CMPLTN RUNT CMPLTN Make up Pigtail ESP to Penetrator on Hanger. Band line to tubing 7 perform Insulation test on ESP line. Good test. RIH land Tbg Hanger as per Vetco Gray Rep. UP WT =82K, SO WT = 70K. Ensure hanger seated. RILDS. Perform packoff tests on upper & lower packoff seals. Test to 250 PSI LOW, 5000 PSI High. 10 Minutes each. Witnessed by Co. Rep. 0.75 CMPLTN NUND CMPLTN Nipple down BOP stack, lines and Flow nipple. 0.25 CMPLTN NUND CMPLTN Perform insulation test on ESP line after Nipple Down. Good Test. r Printed: 2/13/2006 12:29:18 PM ConocoPhiffips'Afaska Page 25 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Sub ~ ~ Date Frum - To Hours Code ~ Code Phase Description of Operations 2/11/2006 04:30 - 06:30 2.00 CMPLTN NUND CMPLTN Nipple up Adapter Flange & Tree. Install Actuator valve. Perform Insulation test on ESP line afrter NU. Final test. Good. 06:30 - 07:00 0.50 CMPLT NUND CMPLTN Fill Tree with Diesel. Rig test equipment & test tree to 250 PSI LOW, 5000 PSI High. Good Test. 07:00 - 07:30 0.50 CMPLTN FRZP CMPLTN PJSM with crew and Little Red Hot Oil Reps. Discuss Safety issues and procedure to pump freeze protect Diesel as well as Spill prevention. Rig up Little Red, test lines to 2500 PSI. Good test. SIMOPS: Rig up Scaffold in cellar. Pull TWC. 07:30 - 08:30 1.00 CMPLTN FRZP CMPLTN Freeze protect well by pumping 180 BBLS of Diesel down annulus with returns to tubing, and pits. Pump at 4 BPM - 1175 PSI. 08:30 - 09:00 0.50 CMPLTN FRZP CMPLTN Blow down & rig down Little Red. Secure Tree closing valves. 09:00 - 10:00 1.00 CMPLTN OTHR CMPLTN Rig up Lubricator & install BPV as per Vetco Gray Rep. Rig down Lubricator & Scaffold. Clean out cellar area with Super Sucker. 10:00 - 11:15. 1.25 MOVE DMOB MOVE Clean out Rockwasher & last pit. Prepare Rig for Move. 11:15 - 12:00 0.75 MOVE DMOB MOVE Blow down all Steam, water lines, and disconnect all neccessary Hydraulic, air, water, and steam lines. Rig Released at 1200 HRS for move Rig to 1 J-159. Printed: 2113/2006 12:29:18 PM Halliburton Company Global Report Compan~~: ConocoPhillips Alaska Inc. 1)atc 3/3/2006 Cinn~: 14:24.18 Pa,e: 1 Ficl~l: Kuparuk River Unit C„-urdiu~tc(\'I:) Rc fcrcucc: W211: 1J-166.. True North Site: Kuparuk 1J Pad ~'crtic,il("I'~71) Kcfc rcncc: 1J-166:109.0 1~cll: 1J-166 Secliuu (~~K~ Hefcrc ucc: Well (O.OON_O.OOE.O.OOAzi) ~lellpaih: 1J-166 Sur~~ec ('alculatiun ~icthod: Minimum Curvatu re I)b: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre. Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: 0.45 deg Well: 1 J-'166 Slot Name: Well Position: +N/-S -227.23 ft Northing: 5945691.74 ft Latitude: 70 15 44.023 N +E/-W -89.01 ft Easting : 558702.73 ft Longitude: 149 31 31.597 W Position Uncertainty: 0.00 ft Wellpath: 1J-166 Drilled From: Well Ref. Point .500292329100 Tie-on Depth: 28.00 ft Current Datum: 1 J-166: Height 109.00 ft Above System D atum: Mean Sea Level Magnefic Data: 1/6/2006 Declination: 24.22 deg Field Strength: 57564 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 3/3/2006 Validated: No Version: 5 Actual From To Survey Toolcode Tool Name ft ft 50.00 723.00 1J-166 gyro ( 50.00-723.00) CB-GYRO-SS Camera based gyro single shot 755.46 6312.36 1J-166 (755.46-6312.36) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6367.34 12791.91 1 J-166 Anadrill (6367.34-12791 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey 11D lncl lzim 7~1) S c,"IVI) ti'S E;~~ TipA' ~lapt: 7~uril ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945691.74 558702.73 TIE LINE 50.00 0.11 163,00 50.00 -59.00 -0.02 0.01 5945691.72 558702.74 CB-GYRO-SS 100.00 0.22 163.87 100.00 -9.00 -0.16 0.05 5945691.58 558702.78 CB-GYRO-SS 200.00 0.16 96.82 200.00 91.00 -0.36 0.24 5945691.38 558702.97 CB-GYRO-SS 300.00. 0.15 129.50 300.00 191.00 -0.46 0.48 5945691.28 558703.21 CB-GYRO-SS 400.00 0.22 89.10 400.00 291.00 -0.54 0.77 5945691.21 558703.51 CB-GYRO-SS 448.00 0.37 .50.51 448.00 339.00 -0.44 0.98 5945691.31 558703.72 CB-GYRO-SS 540.00 0.70 272.11 540.00 431.00 -0.23 0.65 5945691.52 558703.38 CB-GYRO-SS 630.00 4.15 258.63 629.90 520.90 -0.85 -3.09 5945690.86 558699.64 CB-GYRO-SS 723.00 9.11 253.90 722.25 613.25 -3.56 -13.47 5945688.08 558689.29 CB-GYRO-SS 755.46 10.23 253.96 754.25 645.25 -5.07 -18.71 5945686.53 558684.06 MWD+IFR-AK-CAZ-SC 800.29 11.50 250.47 798.28 689.28 -7.66 -26.75 5945683.87 558676.04 MWD+IFR-AK-CAZ-SC 844.21 11.01 247.29 841.35 732.35 -10.74 -34.74 5945680.73 558668.07 MWD+IFR-AK-CAZ-SC 934.25 12.79 252.02 929.46 820.46 -17.14 -52.16 5945674.19 558650.71 MWD+IFR-AK-CAZ-SC 1025.65 14.38 250.54 1018.30 90930 -24.05 -72.48 5945667.13 .558630.44 MWD+IFR-AK-CAZ-SC 1123.61 16:73 248.45 1112.66 1003.66 -33.28 -97.07 5945657.71 558605.93 MWD+IFR-AK-CAZ-SC 1218.57 18.46 251.58 1203.18 1094.18 -43.05 -124.05 5945647.73 558579.03 MWD+IFR-AK-CAZ-SC Halliburton Company • Global Report ('iunp:ui~: ConocoPhillips Alaska Inc. 1 icld: Kuparuk River Unit ~tiilc: Kuparuk 1J Pad ~~ cl I: 1 J-166 ~~'ellpath: 1 J-166 Surce~ ail) Lrcl ~zim ft deg deg 1312.43 23.25 251.77 1405.28 26.40 251.15 1496.25 29.08 251.96 1588.67 31.16 251.74 1681.66 31.48 250.28 1774.60 29.77 250.85 1866.00 31.26 251.58 1959.32 33.33 252.47 2052.31 33.19 251.09 2144.84 33.32 258.24 2237.05 34.20 266.36 2328.42 32.70 266.73 2425.32 34.42 273.37 2452.74 2546.43 2639.81 2734.07 2827.46 2916.42 3013.64 3107.78 3212.63 3293.01 3387.01_ 3480.85 3574.21 3668.21 3759.77 3854.31 3948.54 4042.25 4135.67 4229.40 4323.14 4416.59 4509.82 4602.46 4695.65 4789.72 4882.78 4976.26 5067.31 5161.52 5255.35 5347.17 5440.72 5534.00 5629.30 5723.37 5816.22 5909.59 6002.21 6096.18 34.40 35.67 36.99 40.43 44.92 48.89 51.39 54.97 63.29 67.08 67.12 67.18 67.77 67.15 67.37 66.02 66.04 66.49 67.17 66.96 69.48 72.03 71.51 72.84 74.40 74.94 76.89 78.15 78.03 76.62 76.64 79.46 80.16 80.60 80.60 80.85 81.60 80.23 79.85 81.03 276.43 281.89 286.70 293.17 296.60 302.39 304.85 308.08 312.15 314.30 314.00 316.43 317.21 317.80 317.37 318.81 318.80 317.82 319.34 324.69 329.50 335.04 339.57 348.30 352.02 355.52 358.45 1.69 1.76 2.33 1.74 1.37 2.81 1.34 2.59 2.31 1.74 1.70 2.17 3.12 llatc: 3/3/2006 liner: 14:24~1o Pater. ('u-urdiu~itc(\E) 12cCcrcncc: Well: 1J-166. True North Vcrtirrl (lll)) Itrfcrcncc: 1J-166 . 109.0 tircfiun (1ti1 Reference: Well (O.OON.O OOE O OOAziI tiunet~ C~rlculation :~lct[uui: Minimum Curvature Ub: Oracle l1D S~s~ll~11 ft ft 1290.86 1181.86 1375.12 1266.12 1455.63 1346.63 1535.57 1426.57 1615.01 1506.01 1694.98 1585.98 1773.72 1664.72 1852.60. 1743.60 1930.36 1821.36 2007.77 1898.77 2084.47 1975.47 2160.70 2051.70 2241.47 2132.47 2264.10 2155.10 2340.83 2231.83 2416.07 2307.07 2489.64 2380.64 2558.29 2449.29 2619.09 2510.09 2681.40 2572.40 2737.82 2628.82 2791.58 2682.58 2825.32 2716.32 2861,89 2752.89 2898.34 2789.34 2934.10.. 2825.10 2970.14 2861.14 3005.53 2896.53 3042.93 2933.93 3081.21. 2972.2.1 3118.93 3009.93 3155.69 3046.69 3192.24 .3083.24 3227.04 3118.04 3257.86 3148.86 3287.04 3178.04 3315.44 3206.44 3341.73 3232.73 3366.61 3257.61 3389.26 3280.26 3409.47 3300.47 3428.26 3319.26 3448.93 3339.93 \;ti ft -53.55 -65.95 -79.34 -93.78 -109.52 -125.27 -140.21 -155.59 -171.53 -184.92 -191.73 -194.77 -194.65 -193.33 -184.74 -171.05 -150.86 -124.17 -92.12 -50.79 -5.98 52.05 102.02 .162.33 .223.70 286.59 350.60 412.94 477.55 542.34 606.40 670.80 738.80 811.87 889.94 971.60 1056.26 1144.33 1234.50 1324.63 1415.88 1504.93 1596.79 I~a~1~ ft -155.76 -192.71 -232.88 -276.95 -322.65 -367.29 -411.23 -458.65 -507.09 -555.95 -606.64 -656.91 -710.40 -725.84 -778.88 -832.44 -887.74 -945.10 -1001.53 -1063.65 -1124.20 -1192.86 -1245.99 -1308.12 -1369.03 -1428.04 -1486.69 -1543.65 -1601.65 -1658.36 -1715.41 -1772.22 -1825.33 -1872.57 -1913.57 -1947.73 -1972.08 -1987.35 -1997.19 -2001.92 -2001.80 -1999.12 -1995.84 ~IspA ]iapl~; ~frwl ft ft 5945636.99 558547.41 MWD+IFR-AK-CAZ-SC 5945624.29 558510.56 -MWD+IFR-AK-CAZ-SC 5945610.60 558470.50 MWD+IFR-AK-CAZ-SC 5945595.81 558426.55 MWD+IFR-AK-CAZ-SC 5945579.72 558380.98 MWD+IFR-AK-CAZ-SC 5945563.62 558336.46 MWD+IFR-AK-CAZ-SC 5945548.34 558292.65 MWD+IFR-AK-CAZ-SC 5945532.60 558245.35 MWD+IFR-AK-CAZ-SC 5945516.28 558197.04 MWD+IFR-AK-CAZ-SC 5945502.51 558148.29 MWD+IFR-AK-CAZ-SC 5945495.30 558097.66 MWD+IFR-AK-CAZ-SC 5945491.87 558047.42 MWD+IFR-AK-CAZ-SC 5945491.57 557993.94. MWD+IFR-AK-CAZ-SC 5945492.77 557978.49 MWD+IFR-AK-CAZ-SC 5945500.95 557925.39 MWD+IFR-AK-CAZ-SC 5945514.22 557871.73 MWD+IFR-AK-CAZ-SC 5945533.98 557816.27. MWD+IFR-AK-CAZ-SC .5945560.22 557758.71 MWD+IFR-AK-CAZ-SC 5945591.82 557702.04 MWD+IFR-AK-CAZ-SC 5945632.67 557639.61 MWD+IFR-AK-CAZ-SC 5945677.00 557578.72 MWD+IFR-AK-CAZ-SC 5945734.48 557509.62. MWD+IFR-AK-CAZ-SC. 5945784.03 557456.10 MWD+IFR-AK-CAZ-SC 5945843.85 557393.51 MWD+IFR-AK-CAZ-SC 5945904.74 557332.13 MWD+IFR-AK-CAZ-SC 5945967.16 557272.63. MWD+IFR-AK-CAZ-SC 5946030.71 557213.49 MWD+IFR-AK-CAZ-SC 5946092.60 557156.06 MWD+IFR-AK-CAZ-SC 5946156.74 557097.56 MWD+IFR-AK-CAZ-SC 5946221.08 557040.36 MWD+IFR-AK-CAZ-SC 5946284.69 556982.81 MWD+IFR-AK-CAZ-SC 5946348.64. 556925.50 MWD+IFR-AK-CAZ-SC 5946416.22 556871.87 MWD+IFR-AK-CAZ-SC 5946488.91 556824.07 MWD+IFR-AK-CAZ-SC 5946566.65 556782.47 MWD+IFR-AK-CAZ-SC 5946648.04 .556747.67 MWD+IFR-AK-CAZ-SC 5946732.49 556722.66 MWD+IFR-AK-CAZ-SC 5946820.44 556706.72 MWD+IFR-AK-CAZ-SC 5946910.52 556696.17 MWD+IFR-AK-CAZ-SC 5947000.59 556690.74 MWD+IFR-AK-CAZ-SC 5947091.54 556690.14 MWD+IFR-AK-CAZ-SC 5947180.90 556692.13 MWD+IFR-AK-CAZ-SC 5947272.76 556694.69 MWD+IFR-AK-CAZ-SC 5947364.01 556697.22 .MWD+IFR-AK-CAZ-SC 5947453.80 556698.96 MWD+IFR-AK-CAZ-SC 5947545.83 556701.60 MWD+IFR-AK-CAZ-SC 5947637.75 556704.21 MWD+IFR-AK-CAZ-SC 5947731.72 556706.70 MWD+IFR-AK-CAZ-SC 5947824.50 556709.95. MWD+IFR-AK-CAZ-SC 5947916.22 556712.47 MWD+IFR-AK-CAZ-SC 5948008.38 556714.52 MWD+IFR-AK-CAZ-SC 5948099.57 556716.89 MWD+IFR-AK-CAZ-SC 5948192.15 556720.45 MWD+IFR-AK-CAZ-SC 3470:62 3361.62 1688.01 -1992.60 3489.63 3380.63 1777.80 -1990.17 3506.19 3397.19 1869.81 -1986.81 3521..77 3412.77 1961:72 -1983.48 3537.34 3428.34 2055.68 -1980.25 3552.50 3443.50 2148.44 -1976.29 3566.67 3457.67 2240.14 -1973.04 3581.41 3472.41 2332.29 -1970.28 3597.43 3488.43 2423.47 -1967.20 3613.04 3504.04 2516.03 -1962.92 . Halliburton Company Global Report Cornp:m~: Conoco Phillips Alaska Inc. Darc: 3/3/2006 ]inu~: 1424:18 Pa~,r. 3 I~icIJ: Kuparuk River Unit ('~,-urdin:+tcl~F.) ReR~rcncc: WeIL 1J-166, True North Ji~c: Kuparuk 1J P2d ~'crtical (Ill)) Kcfcrcncc: 1J-166 ~ 109-0 1~ell: 1J-166 Secii~m (~~S) IYcfcrcnrr. Well (0-OON.O-OOE,O-OOAziI ~~'ellpath: 1J-166 Sun~e~~ C'alcul:itiun ~lcthnd: Minimum Curvature Ilb: Oracle Sm~c~ X11) Intl ~ziw 11~U ti~ti IIU t.5 I~::1V ~ia~~A llapl~: I'nol ft dey dig ft ~ ft ft ft ft ft 6153.03 81.48 2.28 3621.68 3512.68 2572.16 -1960.27 5948248.29 556722..65 MWD+IFR-AK-CAZ-SC 6189.58 81.48 1.81. 3627.09 3518.09 2608.28 -1958.98 5948284.42 556723.66 MWD+IFR-AK-CAZ-SC 6284.53 82.23 0.55 3640.55 3531.55 2702.25 -1957.05 5948378.39 556724.86 MWD+IFR-AK-CAZ-SC 6312.36 82.47 0.45 .3644.25 3535.25 2729.83 -1956.81 5948405.97 556724.89 MWD+IFR-AK-CAZ-SC 6367.34 84.14 358.48 3650.66 3541.66 2784.43 -1957.32 5948460:56 556723.95 MWD+IFR-AK-CAZ-SC 6460.92 88.95 357.86 3656.30 3547.30 2877.76 -1960.30 5948553.86 556720.24 MWD+IFR-AK-CAZ-SC 6553.65 92.27 358.60 3655.31 3546.31 2970.43 -1963.17 5948646.49 556716.66 MWD+IFR-AK-CAZ-SC 6647.72 88.69 357.26 3654.53 3545.53 3064.42 -1966.56 5948740.44 556712.53 MWD+IFR-AK-CAZ-SC 6742.66 89.49 .356.51 3656.03 3547.03 3159.20 -1971.72 5948835.17. 556706.63 MWD+IFR-AK-CAZ-SC 6833.62 90.00 356.11 3656.44 3547.44 3249.97 -1977.58 5948925.89 556700.07 MWD+IFR-AK-CAZ-SG 6926.47 90.21 354.93 3656.27 3547.27 3342.54. -1984.83 5949018.38 556692.10 MWD+IFR-AK-CAZ-SC 7020.94 90.07 356.75 3656.04 3547.04 3436.76 -1991.68 5949112.53 556684.51 MWD+IFR-AK-CAZ-SC 7113.88 89:85 354.53 3656.10 3547.10 3529.42 -1998.75 5949205.13 556676.72 MWD+IFR-AK-CAZ-SC 7208.12 90.91 354.89 3655.48 3546.48 3623.26 -2007.43 5949298.89 556667.31 MWD+IFR-AK-CAZ-SC 7301.72 90.06 359.42 3654.68 3545.68 3716.71 -2012.08 5949392.30 556661.93 MWD+IFR-AK-CAZ-SC 7397.13 89.79 4.35 3654.81 3545.81 3812.04 -2008.94. 5949487.64 556664.33 MWD+IFR-AK-CAZ-SC 7428.89 90.16 7.42 _3654.82 3545.82 3843.63 -2005.69 5949519.25 556667:34 MWD+IFR-AK-CAZ-SC 7462.76 91.46 10.16 3654.34 3545.34 3877.09 -2000.51 5949552.75 556672.25 MWD+IFR-AK-CAZ-SC 7490.43 90.71 11.10 3653.82 3544.82 3904.28 -1995.41 5949579.98 556677.14 MWD+IFR-AK-CAZ-SC 7584.76 89.69 14.67 3653.49 3544.49 3996.22 -1974.38 5949672.07 556697.45 MWD+IFR-AK-CAZ-SC 7677.79 88.83 16.19 3654.69 3545.69 4085.89 -1949.63 5949761.91 556721.50 MWD+IFR-AK-CAZ-SC 7770.33 88.68 15.13 3656.70 3547.70 4174.97 -1924.65 5949851.18 556745.77 MWD+IFR-AK-CAZ-SC 7863.97 90.81 11.11 3657.12 3548.12 4266.14 -1903.41 5949942.50 556766.31 MWD+IFR-AK-CAZ-SC 7956.58 90.06 5.95 3656.42 3547.42 4357.69 -1889.67 5950034.15 556779.33 MWD+IFR-AK-CAZ-SC 8049.54. 90.94 2.31 3655.60 3546.60 4450.39 -1882.98 5950126.89 556785.30 MWD+IFR-AK-CAZ-SC 8143.01 90.02 2.67 3654.82 3545.82 4543:77 -1878.92 5950220.29 556788.63 MWD+IFR-AK-CAZ-SC 8235.92 90.59 1.38 3654.33 3545.33 4636.62 -1875.64 5950313.15 556791.19 MWD+IFR-AK-CAZ-SC 8329.74 90.06 1.32 3653.79 3544.79 4730.41 -1873.43 5950406.95 556792.67 MWD+IFR-AK-CAZ-SC 8420.19 90.88 2.06 3653.05 3544.05 4820.82 -1870.76 5950497.36 556794.63 MWD+IFR-AK-CAZ-SC 8513.55 88.78 0.61 3653.33 3544.33 4914.14 -1868.58 5950590.69 556796.08 MWD+IFR-AK-CAZ-SC 8608.16 89.32 1.16 3654.90 3545.90 5008.73 -1867.12 5950685.28 556796.80 MWD+IFR-AK-CAZ-SC 8700.16 .89:49 359.50 3655.85 3546.85 5100.72 -1866.59 5950777.26 556796.61 MWD+IFR-AK-CAZ-SC 8792.36 89.04 359.06 3657.04 3548.04 5192.90 -1867.75 5950869.43 556794.73 MWD+IFR-AK-CAZ-SC 8884.59 88.60 359.79 3658.94 3549.94 5285.11 -1868.68 5950961.61 556793.09 MWD+IFR-AK-CAZ-SC 8983.15 86.37 0.04 3663.26 3554.26 5383.57 -1868.82 5951060.06 556792.18 MWD+IFR-AK-CAZ-SC 9075.09 86.61 358.96 3668.89 3559.89 5475.33 -1869.62 5951154.80 556790.66 MWD+IFR-AK-CAZ-SC 9168.78 86.63 358.76 3674.41 3565.41 5568.84 -1871.48 5951245.28 556788.07. MWD+IFR-AK-CAZ-SC 9263.42 88.16 358.51 3678.71 .3569.71 5663.35 -1873.74 5951339:77 556785.08 MWD+IFR-AK-CAZ-SC 9354.01 88.32 357.39 3681.50 3572.50 5753.84 -1876.98 5951430.22 556781.14 MWD+IFR-AK-CAZ-SC 9449.35 88.35 358.14 3684.27 3575.27 5849.06 -1880.69 5951525.40 556776.68 MWD+IFR-AK-CAZ-SC 9544.86 88.28 357.40 3687.08 3578.08 5944.46 -1884.41 5951620.76 556772.22 MWD+IFR-AK-CAZ-SC 9638.07 88.58 358.01 3689.63. 3580.63 6037.56 -1888.14 5951713.82 556767.77 MWD+IFR-AK-CAZ-SC 9729.11 87.05 2.80 3693.10. 3584.10 6128.50 -1887.50 5951804.75 556767.70, MWD+IFR-AK-CAZ-SC 9796.34 86.46 3.55 3696.91 3587.91 6195.52 -1883.78 5951871.79 556770.89 MWD+IFR-AK-CAZ-SC 9840.93 84.33 3.24 3700.49 3591.49 6239.88 -1881.15 5951916.17 556773.18 MWD+IFR-AK-CAZ-SC 9893.21 87.06 3.04 3704.41 3595.41 6291.93 -1878.29 5951968.24 556775.63 MWD+IFR-AK-CAZ-SC 9918.41 86.95 2.52 3705.73 3596.73 6317.07 -1877.07 5951993.38 556776.65 MWD+IFR-AK-CAZ-SC 10010.98 87.02 1.94 3710.60 3601.60 6409.44 -1873.48 5952085.77 556779.53 MWD+IFR-AK-CAZ-SC 10104.40 86.17 1.23 3716.15 3607.15 6502.66 -1870.90 5952178.99 556781.38 MWD+IFR-AK-CAZ-SC 10195.04 87.10 1.31 3721.47 3612:47 6593.12 -1868.89 5952269.46 556782.68 MWD+IFR-AK-CAZ-SC 10289.06 90.23 2.66 3723.66 3614.66 6687.04 -1865.63 5952363.40 556785:20 MWD+IFR-AK-CAZ-SC 10380.13 94.87 5.12 3719.61 3610.61 6777.78 -1859.47 5952454.17 556790.66 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report (7~mpanc: ConocoPhillipsAlaskalnc. Uatc: 3i3/2006 Iin~e: 142418 l':~;;c: -t Field: Ku paruk P.iver U nit Cn-urd inatc(~~I~:) Kc fcrcncr. Well: 1J-166. Trua North ~itc: Ku paruk 1J Pad ~ crtic sl (ll'U) Ncf crcncc: 1J -166:109.0 ~Fcll: 1 J -166 tirction 11~~) Refere nce: Well l0.OON,QOGE O OOAzi) ~1cllpaitii: 1J -166 Sur~~c~ ~(~alculatinn ~IcUuul: Ml nimumCurvatur e Dh: Oracle Sin~cc ail) lucl ~rini llU Scslli) \i5 FJ~1 ~Ia~iS ~IaipF; Tnnl ft deg deg ft ft ft ft ft ft 10478,98 99.65 6.25 3707.12 3598:12 6875.33 -1849.76 5952551.78 556799.61 MWD+IFR-AK-CAZ-SC 10570.63 99.83 5.77 3691.61 3582.61 6965.16 -1840.30 5952641.67 556808.36 MWD+IFR-AK-CAZ-SC 10663.57 99.97 4.41 3675.63 3566.63 7056.35 -1832.18 5952732.92 556815.77 MWD+IFR-AK-CAZ-SC 10758.49 95.76 2.37 3662.64 3553.64 7150.19 -1826.63 5952826.79 556820.59 MWD+IFR-AK-CAZ-SC 10851.08 91.81 1.38 3656.53 3547.53 7242.51 -1823.61 5952919.12 556822.89 MWD+IFR-AK-CAZ-SC 10941.84 92.21 359.72 3653.35 3544.35 7333.21 -1822.74 5953009.81 556823.06 MWD+IFR-AK-CAZ-SC 11033.96 90.83 0.12 3650.91 3541.91 7425.29 -1822.87 5953101.88 556822.21 MWD+IFR-AK-CAZ-SC 11124.22 89.06 357.02 3650.99 3541.99 7515.51 -1825.12 5953192.07 556819.25. MWD+IFR-AK-CAZ-SC 11216.15 88.53 357.12 3652.93 3543.93 7607.30 -1829.82 5953283.81 556813.84 MWD+IFR-AK-CAZ-SC 11306.82 87.54 357.32 3656.04 3547.04 7697.81 -1834.21 5953374.27 556808.74 MWD+IFR-AK-CAZ-SC 11397.58 88.67 358.77 3659.04 3550.04 7788.46 -1837.31 5953464.89 556804.94 MWD+IFR-AK-CAZ-SC 11489.38 87.97 359.40 3661.73 3552.73 7880.21 -1838.77 5953556.62 556802.76 MWD+IFR-AK-CAZ-SC 11581.72 87.82 0.04 3665.12 3556.12 7972.48 -1839.22 5953648.88 556801.59 MWD+IFR-AK-CAZ-SC 11671.22 85.96 359.02 3669.98 3560.98 8061.84 -1839.96 5953738.22 556800.16 MWD+IFR-AK-CAZ-SC 11762.23 86.21 358.18 3676.19 3567.19 8152.61 -1842.18 5953828.96 556797.24 MWD+IFR-AK-CAZ-SC 11852.05 88.40 359.62 3680.41 3571.41 8242.31 -1843.90 5953918.63 556794.82 MWD+IFR-AK-CAZ-SC 11942.44 88.97 359.84 3682.49 3573.49. 8332.67 -1844.32 5954008.98 .556793.69 MWD+IFR-AK-CAZ-SC 12032.62 89.08 0.29 3684.02 3575.02 8422.84 -1844.22 5954099.14 556793.08 .MWD+IFR-AK-CAZ-SC 12123.00 87.61 359.69 3686.63 3577.63 8513.18 -1844.24 5954189.47 556792.36 MWD+IFR-AK-CAZ-SC 12214.94 87.94 358.61 3690.20 3581.20. 8605.04 -1845.60 5954281.30 556790.29 MWD+IFR-AK-CAZ-SC 12305.49 87.95 358.58 3693.45 3584.45 8695.50 -1847.82 5954371.74 556787.36 MWD+IFR-AK-CAZ-SC 12394.91 87.14 356.71 3697.28 3588.28 8784.76 -1851.49 5954460.96 556783.00 MWD+IFR-AK-CAZ-SC 12486.15 87.19 355.55 3701.79 3592.79 8875.68 -1857.64 5954551.82 556776.14 MWD+IFR-AK-CAZ-SC 12578.19 87.08 354.96 3706.39 3597.39 8967.29 -1865.24 5954643.36 556767.82 MWD+IFR-AK-CAZ-SC 12669.70 87.85 355.71 3710.44 3601.44 9058.41 -1872.68 5954734.40 556759.68 MWD+IFR-AK-CAZ-SC 12759.83 87.69 355.60 3713.95 3604.95 9148.21 -1879.50 5954824.14 556752.15 MWD+IFR-AK-CAZ-SC 12791.91 87.64 355.32 3715.25 3606.25 9180.16 -1882.04 5954856.07 556749.37 MWD+IFR-AK-CAZ-SC 12853.00 .87.64 355.32 3717.77 ' 3608.77 9241.00 -1887.02 5954916.86 556743.91 ~ PROJECTED to TD [Fwd: FW: Corrected Sectional Coordinates for Toe 1J-166] • • Subject: [Fwd: FW: Corrected Sectional Coordinates for Toe 1J-166] From: Thomas Maunder <tom maunder@adminstate.ak.us> Date: Mon, 12 Dec 2005 08:41:42 -0900 To: Steve Davies <steve davies@adminstate.ak.us> Steve, Here is the updated information on 1J-166. Would you mind printing? You said your little printer beats the big color one hands down. Thanks, Tom -------- Original Message -------- Subject: FW: Corrected Sectional Coordinates for Toe 1J-166 Date: Fri, 09 Dec 2005 15:44:04 -0900 From: Greener, Mike R. <Mike.R.Greener@conocophillips.com> To: Tom Maunder <tom maunder@admin.state.ak.us> FYI. the corrected plan for the 1J-166. -----Original Message----- *From:* Hartwig, Dennis D *Sent:* Friday, December 09, 2005 11:49 AM *To:* Greener, Mike R. *Subject:* Corrected Sectional Coordinates for Toe 1J-166 *Importance:* High Mike - my apologies, Attached is the pdf wellpacket for the 1J-166 (wp07) with corrected toe coordinates. All files on the S-drive have been updated to the correct coordinates of 560 FSL & 94? FWL Sect 23-T11N-RlOE ~ ~___.. Thx...Dennis -----Original Message----- *From:* Dennis Hartwig [mailto:Dennis.Hartwig@HALLIBURTON.com] *Sent:* Friday, December 09, 2005 11:43 AM *To:* Hartwig, Dennis D *Subject:* *Importance:* High *Dennis HBrtwiq* Technical Professional / Well Design Halliburton / Sperry Drilling Services Alaska Operations ** Office (907) 265-6024 Cell (907) 632-2294 FAX (907) 265-6224 T~.c~c-~. wcAS 4 ~ ~~ ~ ~ << w~~~L.~ ~~s~ ~o~ ~ ~~ ~ wG S ~h~c-e~ ~~ "~ '~ rvc ~~ ~"rcC"'t~ OI~G ~a l~R ~E Cssl~W~~~©rS G-C~ vx~s cQ~~~e~ ~~ ~ ~~E. -~~~~~ ~oSr~'O~ r ~a l~ [~. ~ .~ ~« ~ ------------------------------------------------------------------------ This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient (or authorized to receive information for the intended recipient), please contact the sender by 1 of 2 12/12/2005 2:24 PM [Fwd: FW: Corrected Sectional Coordinates for Toe IJ-166] reply e-mail and delete alrcopies of this message. Content-Type: application/octet-stream 1J-166 (wp07).pdf Content-Encoding: base64 2 of 2 12/12/2005 2:24 PM • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-166 Plan: 1J-166 (wp07) Proposal Report 04 November, 2005 HALLIBURTON Sperry Drilling Services ~ to~~ N J J O HN OUfOQ QQ VJN ~I~~ ~ ~ J H W O O U m Q M R N N M N ~Fp jFp NNNNNN C C N~ C C C PI YI iA » YO N N o L n" M Ot o~ tT~ d d d d d J E_ ~ `D N . N ~ ~ J J tp tp O t~aFYF»>Y~i33333 yy ~ ~ n a ~ ~ o0 Z N r A O 0 ~ ~ Z 0 2 'iN NA V N~Onn~}~O t~D p f ~~yt tONNb~~800 NO NA Om ~ QOA OI tD X010 C'!O W ~ Ur O O O ~p r2~en NN~Q O<NNYHiN N~ Z mNOO W m ~ 3 ~ ~00pO 00 00000< O O S O S O O S O O O O O n 'f~Of~t'lN 1` NYI aOTOt7 f/J Q N10 /V r J ~ ~ tp ~ ~ t HH W tOntC tO p~ppNp Nnfay O~~~NNtOf MMMM~Mt~f N (,) QOO V O ~00 AO o to ui to ~ C C (p {p a a Z~Nne~n tonrom°.~-~.H-~ mmVe~ N t+Of tA+l ~~~ 2rNtov ~+ C ~ .~ a me ~ ~~~ O. Y Y r' 3 3 ~' r ~ G C ® r 3 7!0 O~ Y Ya~r ~.; m ~ 3 L ON~ a a` d' H J m 0 l(7 N ot} J ti O pm V J N O O pN~ C/ m O O f00 _ D O ID ~ ~~ ~ \ M n r 7 pp n O r 3 p Cl ,~ F _ tD m ~ O 3 \ ~ \ a 3 F t0 N s _aa o S O ~ o °' V O C O ~ U O O ' - ' ~ m O A O ~ ~ to O L1 ~ ~ Y7 to _ ~ 0 ~ N Y ' N ~ ~ t r ~ ~~~ C ~ +l to N a ~ ~ m O N ~ ~ ~ ', ' ~ \ \ ~ ~ ~ r p ^ ,~ , rn \ ~ G Q ~ H o ro O ~ ~ J ~ ~ ~ X V O i ~ ~ W C n ° _~ o n :d . i ao Z _ Q ~ Q m to N O I ~ ~ ~ 0D \ C \ ~ O i N ~ ~ l0 to ~ ~ H o v O 7 ~ U j \ m m ~ O ~ ~ w ~ \ a \ ' 4 A ' ~ ~ ~ m ate} 0.r ~ p M N ~ f0 O \ C N C \ \ \ ~ O C _~ ~ ~'`\ =~ O \ tD O o N ~ ` ~ c \ \ F ~~ ~ m I ~ { \ 3 p c7 I ~~ \ ~' o. 6 ~ ~ \ r' °v ~ ~ ~ \ a Y ~I ~ to ~ ? \ \ c ` \ w a ~ ~ ~ v \ W > v H v c O N o \ \ \ '\ f \ \ O ~ _ 01 O to ~ \ \ \ \ \ ~~ \ \ t0 m p ° \ \ \ \ ` \ f ~ v \ ~ v ~ ~ in ~ v v v ~ \i , r o ~ \ \\ \ ~ ` \ i .. ` ~ \ \\ \\ \ ~: ~ \ \ ~ ~ _a i ~ ~ \\ \ ~\ a1 \ 3 ~.. ~ ~ a m \ \ \ \ \ r ~ N ~ \ \\ \\ \\ \\ W , N ~ I CI U ~ C \ \ \ \ \ \ \ \ `~ \\ o F- N : i ~ i m ~ I I \ \ \ \ \ ` 1 F" ~ ~ I \ \ \: , ~ ~ ~ - I \\ \ ~ I I to \ \ ; \ \ \ a~ z °n 0 r O O c7 `Vi \ \\ \ \ \ \ - \~ ~ \ ~ tD \ \ \ \ \ \ ~ ~ \ \ \\ ~ \ ~ ~ ~ \ \ \ ` \ °v W \ \\ \ \ ~ \ \\ \1 3 / ~ V M ~ a ~ \~ O O \ \ \ \. \ \ .0. ~ ~ \ C \ \ ~ \ ~ ;\ \ a \ \ ~' - - \ ~ I~ to \ \ \~ \ \ ~ ` ~ \ ~ , N \ \ ~ \ \ ;\ O f I I \ \\ \ \ \ \ ~ I N \ \ \ l \\\ \ ~ I ~ ^ R7 C \ ~ °Ot : \\ \\ ~~ "' m d c U o `\ \ Y vv v \ ` ` \\` \\ \ t `~9 ! m _, \ \1 '~U~ a[ ~Yp y Jq( o ~ on- ~ '1y[ Vl (p N p ~ o^ ~ m ~ ~ p ie I".vI O O O O O O N O N O O O rn V 0 N m n O A O c~0 O O 0 C o 0 O ~ O 0 O ~ O ~ O l6 o C o °v O U ~~ O O N O N O N O u~i O O tt) 110E 81 Project: Kuparuk River Unit T ConocoPhilli 5 p i Site: Kuparuk 1J Pad ~ M az~muus ±o rrw Nortn ate' Well: Plan 1J-166 Wellbore: 1J-166 agnetic North: 24.26° Plan: 1J-166 (wp07) Magnetic Field Strength:57562.3nT " Dip Angle: 60.76° 4 1/2 Date: 12/12005 _- -. - ----__.__ BHL@12841ft MD, 3733ft TVD S60ft FSL8947ft FWL-- Sec 23-T11N-810E=i ModeI:BGGM2005 -r --'~ ------- ----- ~~'-1 1J-186 T8 (wp07) - - - - -- --- - - - 0° ~ CASING DETAILS ~~ ~ No TVD MD Name Size 1J-166 T7(wp071- _ _ _ _ _ _ 1 80.00 80.00 20" 20 \ 2 2183.00 2359.67 10 314" 10-3/4 3 3645.74 6288.39 7 5/8" 7-518 4 3733.0012841.06 41/2" 4-1/2 0° 1J-166 T51wp07~1~- -- - _____ ~--- 0° 31 1 -1 0° End Undulations Geosteer in Upper Lobe, 8964ft MD, 3665ft TVD --- -- --- 1J-166 T5 Peak 2 (wp07i 0° ~ 1 J-166 T4 Trough 2 (wp07i ~_ ~ i ~, I Begin Undulations -Begin Dir ~ 1.10°lt00ft, 6639ft MD, 3675ft TVD 0 + I L r O Z Begin Dir (~ 4°/100ft, 6468ft MD, 3867ft TVD; t 1 J-166 T3 Peak 1 (wp07 ~ - - - ~ - , . 0 -' ~ 7 5/8 CSG -Top of Productive Interval @ 6288ft MD, 3646ft TVD ~~ 3' - - - _- __ - _. _ - _ - -Begin Dir ~ 4°/100ft, 6188ft MD, 3632ft TYD 1 J-168 T2 Trough 1 (wp07) Sail ~ 60°Inc & 2.51°Azi : 5368ft MD, 34898 TVD 3° / - - - Begin Dir ~ 4°lt00ft, 5293ft MD, 3474ft TVD Sail ~ 77.00°Inc 8 2.51 °Azi : 4968ft MD, 3401ft TVD 3° -- - - - - - --- _ - - 1J-166 1 Dtop(wpU~/J .. - _ _ _ _ - - - - - - - _ - - - ~ ~° I End Purt~q Tarperrt: Begin Dir Q 5°NOOR, 41038 MD, 31198 1. _ _ - - - -'I 3~ - - . -:~ _-- __ ° ----------------- Top of200'PumpTangent;3803RMD, ~~' -,5-tig - - - -4375 ~~~ ~ i i _ ---- _ 66.68°Inc & 318.11°AZi : 3334ft MD, 2815ft TVD - - „ ~ `o ~, ~ ~ - - - - _ _ ~T- - - - °, i ~~ -----_' \X~ ~ ~, SHL~1880ftFSL&2508ftFEL-Sec 35-T11N-R10E ,~ 10314" CSG (flj 2360ft MD, 2183ft TVD ~ , ~/ ~ ~ -- - ~, -- Sail @ 32.54°Inc & 250°Azi : 1558ft MD, 1509ft TVD. CorlSnue Build @ 3.5/100ft ,700ft MD, 7008 TVD - - ~Begin Dir (~ 5°/100ft, 2158ft MD, 2015ft TVD; !~ KOP (dJ 6008 MD, 600ft TVD - Build ~ 2.5°/t00ft -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 West(-)/East(+) (1250 Win) W` N "' ~UmQQQ OON~ N . '~~ O O O l0 N 10 l0 /0 R N ~ A~ a ~ n u~ J ~ ~ ~UmQ NN(AfAfl7(n 13 7 3 3 ~+ w a+ m Q E£ O} C C C M W N H N N Ul m V: - m ~ O d M ~ M 01 O> OIL m m m d d d fA ap N -'j t __ ~ a aa~xr»>x333333 J ~oo'~~ ~i Q ZN~r~a ~ I-~ ~ d LOP PIBNTN10 tONON~1 W ~ '`~~ ~~ ~i o z ~ U OO1 CDC O ~ O -.. ~ N M V a ~ 00 ~ ~ 0 N ~ ? ~ O f•Of N ~ __ ~I :... ~ i Q -. r O L O O O O O O O O O O O O O V Q N O S ~- ~ N O O O O O O O O O O O O O h O I~ ~ ~ fD ~ avoioriMaior:MVir.:~oNVi V QOOOn°o ti O ~ ~a°r°atOOO~NVy~'vvNiv~i~ ~oaiuiri ~n^. ti lL ~ ~ ~ ~ N N M M M M !'~ M M M M O r~ ti d 'n o O O r N M I N M M 3 V I ~ Z~ NC7~tt7 (Dl~aOOf rr a-r-i- Z ~ H z~NM~ tD f 1 1D V O ~ w O LL ~ ~TTy~• ~ '^ I O v O O: ~,~ 13 ~ ~ o O ~, N ~ Y i _ _ ~ j ~ I I ~ ~ _ a Y '~ I _ t- Q' o 0 I ~ I ~~ ~ ~ ~ ~ w m ~ C }~ ~ N Z x ~ ~, O o ~ L o ~ ~ o -o d o w ~ Q v Y Y a- ' 3 '. ~ tD I, Q o 0 L `TAO A! ~ i O 3 3!~ c~ ~~'' c Y Yaa`' ~ ~ ~ o ~ c~i$ ~3 m ~ 3 v ~t N CN?~ d I ~ _ _ ~! fA ~~//~~ ~ a l v° y v/ ~ f > ~I i o ~i, ~ V ~! >° >° a w+ ~ ; n r o W o 0 0 ~ n n ~ ~- t 3 3 I~~ ~ p F J J ~ I ~ (O f0 O N d f~0 r r 31 n i ~~ Z J J p o F W tD (O N fr W ~ ~ r r J r O O d 0 tw ~ - (O fD 3 O Y / ~fi Q ~ r r O •~ ~ C C ~ = Q ^ ~ f0 l0 ~ .~ ~ ~ d a ~ o o ,a o ~ ~~~ O O ~° ~ ~ 3 O N J J V o °° o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ ~ ~ ~ ~ rri rcOi ~ °v a v ui da eai a anru ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: GonocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-166 Wellbore: 1 J-166 Design: 1 J-166 (wp07) Halliburton Company ~ HALI.IBUFiTON Planning Report -Geographic -- ------~_---,--- Sperry Drilling Services LocalCo-ordinate Reference: Well Plan 1J-166 TVD Reference: Planning RKB @~ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB ~ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calcu~tion Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map-System:. 11S State Plane 1927 (6cact solution) System Datum.: :Mean Sea_Level 3ecf {)atom: NAD 1927 (NADCON CONUS) Using WeB Reference Pant Nap Zone: Alaska Zone 04 Using geodetic scale factor .Well Well Position Plan 1J-166 +N/-S 0.00 ft Northing: 5,945,691.74 ft Latkude: 70° 15' 44.023" N . +E/-W 0.00 ft Easting: 558,702.73 ft Longitude: 149° 31' 31.597" W Position Uncertainty 0.00 ft Wellhead E levation: ft Ground Level: 81.OOft I Wellbore 1J-166 i N~gnetu~ Model Name Sample Dats Declination Dip Angle FIe1d Strength ~ BGGM2005 12/1(2005 24.26 80.77 57,562 Design 1J-166 (wp07) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +N/S +E/-W Directio n 1~) t~) i~) (°) ~ 2s.oo o.oo o.oo o.oo 11/4/2005 12:24:26PM Page 2 of 10 COMPASS 2003.11 Buifd 48 f ` Conoco Phillips Alaska Database: EDM 2003.11 Single User Db Company: , ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-166 Weilbore: 1 J-166 Design: 1J-166 (wp07) Halliburton Company ~ HALLIBURTON Planning Report -Geographic - -~--~- ~-------~--_------_--- Sperry Drilling Services Local t:o-0rdinate Reference: Weil Plan 1J-166 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB Q 109.OOft (Doyon 141 (28+81)) NoM Reference: True Survey hali5ulation Nlsthod: Minimum Curvature Plan Summary IYteasured Vertical ~9~9 Build Tum Depth Inclination :Azimuth Depth +W$ +E/-W ~~ Rate Rate TFO (SI! (°) (°1 (R) (ftl {ft) (°HOOft) (°MOOtt) (°MOOft) (°) 28.D0 OAD QOD 28.OD 0.OD 0.00. 0.00 O.DD 0.00- O.DO 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0,00 0.00 0.00 700.03 2.50 250.00 700.00 -0.75 -2.05 2.50 2.50 0.00 250.00 1,558.17 32:54- 250.00 1;509.60 -88.08 -242.01 3.50 3:50 0:00 D.00 2,158.17 32.54 250.00 2,014.83 -198.45 -545.24 0.00 0.00 0.00 0.00 3,334.38 66.68 318.11 2,814.96 124.25 -1,267.65 5.00 2.90 5.79 84.92 4,103.31 68.88 318.11 3,119.34 649.89 -1,739.14 0.00 0.00 0:00 0.00 4,968.39 77.00 2.51 3,401.38 1,402.73 -1,998.33 5.00 1.19 5.13 84.22 5,033.39 77.00 2.51 3,416.00 1,466.00 -1,995.55 0.00 0.00 0.00 0.00 5293:39 77:00 2.51 3,474.49 1,719:09 -1,884.46 0.00 O.OD 0.00 O.OD 5,368.39 80.00 2.51 3,489.44 1,792.51 -1,981.24 4.00 4.00 0.00 359.99 6,188.39 80.00 2.51 3,631.83 2,599.28 -1,945.87 0.00 0.00 0.00 0.00 6,288.39 84.00 2.51 3,645.74 2,698.19 -1,941.54 4.00 4.00 0.00 0.00 6,488.39 84..00 2.51 3;666.65 2,896:90 -1,932.83 0.00 0.00 0:00 0.00 6,638.89 90.02 2.51 3,674.50 3,046.98 -1,926.25 4.00 4.00 0.00 0.00 6,948.89 93.43 2.51 3,665.17 3,356.50 -1,912.68 1.10 1.10 0.00 0.00 7,103.89 93.43 251 3,655.89 3,511.08 -1,905.90 0.00 0.00 0:00 0:00 7,413.89 90.34 2.24 3,645.69 3,820.60 -1,893.07 1.00 -1.00 -0.09 -175.00 7,723.89 86.37 1.54 3,654.58 4,130.24 -1,882.85 1.30 -1.28 -0.23 190.00 7,878:89 86:37 1:54 3,864:38 4,284.88 -1,878:69 D:00 O.DO U:00 0:00 8,188.89 87.87 1.14 3,679.95 4,594.39 -1,871.46 0.50 0.48 -0.13 -15.00 8,498.89 91.76 0.10 3,680.94 4,904.31 -1,868.13 1.30 1.26 -0.34 345.00 8,653.89 93.31 0.10 3,674.08 5,059.15 -1,867.87 1.00 1.00 0.00 0.00 8,963.89. 90.2.1. 0.1D 3,664.x4 5,368.97 -1,867.36 1.OD -1.00 0.00. -180.00 9,273.89 87.43 0.34 3,670.90 5,678.87 -1,866.18 0.90 -0.90 0.08 175.00 9,523.89 87.43 0.34 3,682.10 5,928.61 -1,864.71 0.00 0.00 0.00 0.00 9,543.06 88:00 0.44 3,882.86 5;947:78 -1,864.58 3.00 2.95 0:52 10.00 9,793.06 88.00 0.44 3,691.58 6,197.60 -1,862.67 0.00 0.00 0.00 0.00 9,993.51 98.01 1.03 3,681.10 6,397.51 -1,860.12 5.00 4.99 0.29 3.34 10,182.89 98.fl1 1.03 3,854:75- 8,584.81 -1,856.77 0.00 0:00 fl.00 fl.00 10,398.91 87.21 0.45 3,644.93 6,800.47 -1,853.99 5.00 -4.99 -0.27 -176.93 11,098.91 87.21 0.45 3,679.00 7,499.62 -1,848.50 0.00 0.00 0.00 0.00 11,208.77 9D.51 0.45 3,681.19 7,609.44 -1,847:64 3.D0 3.00 D.OD -0:07 11,894.23 90.51 0.45 3,675.14 8,294.85 -1,842.30 0.00 0.00 0.00 0.00 11,997.09 87.42 0.45 3,677.00 8,397.68 -1,841.50 3.00 -3.00 0.00 179.93 12,044.61 85.99 0.45 3,679.73 8,445.12 -1,841.13 3.00 -3.00 -0.01 -179.85 12,745.:87 85.99 D:45 3,728.72 .9,144:65 -1,835:68 0.00 0.00 D.00 0:00 12,841.07 88.85 0.45 3,733.00 9,239.73 -1,834.94 3.00 3.00 0.00 0.07 11/4/1005 12:24:26PM Page 3 of 1D COMPASS 2003.11 Build 48 o Conoc Phillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Weil Plan 1 J-166 VYellbore: 1 J-166 Desigm 1J-166 (wp07) lialliburton Company Planning Report -Geographic HALLIBURTON Sperry Drilling Services Local Co-ondinaibee Reference: Weil Plan 1J-166 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Norte Reference• True Survey Calculation Method: 'Minimum Curvature Planned Sunray 1J-166 (wp07) Map Map MD inclination Azimuth TVD SSTVD +N(,S +E/-W :Northing Eastin9 DLSEV Vert Section (ft) (°) (°) (ft) (ftj (ft) 1ft) (ft) (~) (°HOpft) (ft) ~I 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 SHL @ 1880ft FSL & 2508ft FEL -Sec 35 - T11 N - R10E ~! 80.00 0.00 0.00 80.00 -29.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 ', 20" ', 100.00 0.00 0.00 100.00 -9.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 j 200.00 D.00 D.DD 200.OD 91.DD O.DD 0.00. 5,945,691..74. 558,702J3 0.00- O.DO 300.00 0.00 0.00 300.00 191.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 400.00 0.00 0.00 400:00 291:00 0:00 0:00 5;945;691:74 558,702.73 0:00 0:00 500.00 0.00 0.00 500.00 391.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 600.00 0.00 0.00 600.00 491.00 0.00 fl.00 5,945,699.74 558;702.73 0.00 0.00 KOP @ 600ft MD, 600ft TVD -Build @ 2.5°/100ft 700.03 2.50 250.00 700.00 591.00 -0.75 -2.05 5,945,690.98 558,700.69 2.50 -0.75 Continue Bu ild @ 3.5i100ft , 700ft MD, 700ft TVD 800.00 6.00 250.00 799.68 690.68 -3.28 -9.01 5,945,688.39 558,693.74 3.50 -3.28 ~ 900:00 9:50 250:00 898:75 789.75 -7:89 -21:68 5,945,683:68 558;681:11 3:50 -7:89 ' I 1,000.00 13.00 250.00 996.81 887.81 -14.56 -40.01 5,945,676.87 558,662.84 3.50 -14.56 1,100.00 16.50 250.00 1,093.50 984.50 -23.27 -63.93 5,945,667.98 558,638.99 3.50 -23.27 1,200.00 20.00 250.00 1,188.46 1,079.46 -33.98 -93.35 5,945,657.04 558,609.65 3.50 -33.98 1,300.00 23.50 250.00 1,281.32 1,172.32 -46.65 -128.17 5,945,644.10 558,574.94 3.50 -46.65 1,400.00 27.00 250.00 1,371.76 1,262.76 -61.24 -168.25 5,945,629.20 558,534.98 3.50 -61.24 1,500.00 30.50 250.00 1,459.42 1,350.42 -77.68 -213:44 5,945,Fi12.40 558,489.93 3_50 -77.68. 1,558.17 32.54 250.00 1,509.00 1,400.00 -88.08 -242.01 5,945,601.78 558,461.44 3.50 -88.08 ~ Sail @ 32.54°Inc 8~ 250°Azi : 1558ft MD, 1509ft TVD ~ 1,564.10 32.54 250.00 1,514.00 1,405.00 -89.18 -245.01 5,945,600.67 558,458.45 0.00 -89.48 Permafrost I 1;600:00 32.54 254:00 1,544:27 1;435.27 -95.78 -263:15 5;945;593.92 558,440:36 0.00 -95.78 1,700.00 32:54 250.00 1,628.57 1,599.57 -114:17 -313.69 5,945,575:14 55$,389.97 0.00 -114.17 1,712.37 32.54 250.00 1,639.00 1,530.00 -116.45 -319.94 5,945,572.81 558,383.74 0.00 -116.45 T3 I 1,800.00 32:54 250.00 1,712.88 1,603.88 -132.57 -364.23 5,945,556.35 558,339.58 0.00 -132:57 ~ 1,900.00 32.54 250:00 1,797.1$ 1,888:18 -150.96 -414:77 5,945,537:56 558,289.19 0:00 -150.96 i 2,000.00 32.54 250.00 1,881.49 1,772.49 -169.36 -465.31 5,945,518.78 558,238.80 0.00 -169.36 2;057.54 32.54 250:00 1,930:00 1;821.00 -179.94 X94.39 5,945,507.97 558,2D9:81 0:00 -179.94 K15 2,1(}0.00 32.54 250.00 1,965.80 1,856.80 -187.75 -515.85 5,945,499.99 558,186:41 0.00 -187.75 ~ 2,:158:17 32:54 25D.00 2,014.83 1,905:83 -198:45 -545.24 5,945,489.06. 55$,159,10- 0.00 -19845 i ~ Begin Dir @ 5°/100ft, 2158ft MD, 2015ft TVD 2,200.00 32.78 253.85 2,050.06 1,941.06 -205.45 -566.69 5,945,481.90 558,137.71 5.00 -205.45 2,300.00 33.83 262.76 2,133:68 2,024:68 -216.49 -620.34 5,945,470.44 558,0&4.15 5:00 " -216.49 2,359.87 34.74 267.80 2,183.D0 2,D74.00 -219.24 X53.82 5,945;467,43 558,050.71 5.00 -219.24 10 3/4" CSG @ 2360ft MD, 2183ft TVD -1561ft FSL 8< 2118ft FWL -Sec 35 - T11 N - R10E - T3+550 -10 3/4" 2,400.00 35.47 271.07 2,215.99 2,106.99 -219.46 X77.00 5,945,467.03 558,027.52 5.00 -219.46 2,500.00 37.64 278.64 2,296.35 2,187 35 -214.33 -736.24 5,945,471.70 55796825 5:D0 -214:33 2,600.00 40.25 285.44 2,374.16 2,26516 -201.13 -797.61 5,945,484.42 557,906.79 5.00 -201.13 2,700.00 43.21__.. .291..49 2,448.81 2,33981. -179.97 -860.64 5,945,505.08 557,843.60 5.00 -179.97 11/42005 12:24:26PM Page 4 of 10 COMPASS 2003.11 Build 48 ConocoPhillips Alaska Database:. EDM 2003.11 Single User Db Company: GonocoPhillips Alaska (Kuparuk) Project:... Kuparuk River Unit Si6e• Kuparuk 1 J Pad Welk Plan 1J-166 YWatlboreo- " 1 J-166 Design: 1J-166 (wp07) Ha!liburton Company Planning Report -Geographic MAI.LIBURTON _...r ~_......._-____ ~~_____~ Sperry Drilling Services Local Co-ondenate Reference: Well Plan 1 J-166 TVD Reference: Planning RKB ~ 109.OOft (Doyon 141 (28+81)) MD References Planning RKB Q 109.OOft (Doyon 141 (28+81p North Reference• True ' Survey Catculetion Method.: Minimum Curvature Planned Survey 1J-166 (wp07) i Map Map MD Inclination Azimuth TVD SSTVD +N/-S +EI W No~iD9 ~~n9 DLSEV Vert Bastian (ft} (°} C) ttt) tft} (ft) t~) (~) ; (ftI (°n00ft) (fy 2,800.00 46.45 296.89 2,519.74 2,410.74 -151.02 -924.86 5,945,533.53 557,779.17 5.00 -151.02 i 2,900.00 49.93 301.72 2,586.42 2,477.42 -114.48 -989.76 5,945,569.55 557,713.98 5.00 -114.48 3,000.00 53.58 306.07 2,648.33 2,539.33 -70.65 -1,054.87 5,945,612.88 557,648.54 5.00 -70.65 3,100.00 57.38 310.02 2,705.01 2.,596.01 -19.85 -1,119.68 5,945,663.17 557,583.34 5.00 -19.85 3,200.00 61.29 313.64 2,756.01 2,647.01 37.54 -1,183.71 5,945,720.05 557,518.88 5.00 37.54 i 3,300.00 65.29 317.00 2,800.97 2,691.97 1D1.D7 -1,246.48 5,945,783:08 557;455.&4 5:0(3 101.07 i 3,334.38 66.68 318.11 2,814.96 2,705.96 124.25 -1,267.65 5,945,806.09 557,434.27 5.00 124.25 I Sail @ 66.68°Inc & 318. 11°Azi : 3334ft MD, 281 5ft TVD 3,400.A0 66.68 318.11. 2,84D.93 2,731.93 169.1.0 -1,307.88. 5,945,850.62 557,393.69- d_00 169.90. 3,455.75 66.68 318,11 2;863:00 2;754.fl0 207:21 -1,342:07 5,945;888.46 557,359:22 O.t30 207:21 Ugnu C 3,500.00 66.68 318.11 2,880.52 2,771.52 237.46 -1,369.20 5,945,918.50 557,331.85 0.00 237.46 3,600.00 66.88 318:11 2,92D.10 2,$11:10 305.82 -1,430.52 5,945,986.37 557,27D:D1 O:DO 305.$2 3,700.00 66.68 318.11 2,959.69 2,850.69 374.18 -1,491.84 5,946,054.25 557,208.17 0.00 374.18 3;800.00 66.68 318:11 2,999.27 2;890.27 442:55 -1;553.95 5,946,122:12 557,446.32 0.00 442.55 3,900.00 66.68 318.11 3,038.85 2,929.85 510.91 -1,614.47 5,946,190.00 557,084.48 0.00 510.91 3,903.OD 66.68 318..11 3;040:04 2.93'1.04 .512.96 -1;6'16.31 5,946,f92.03 557,0ffi.83 U_00 512.96 Top of 200' Pump Tangent ; 3903ft MD, 3040ft ND 4,000:00 66.fj8 3f8.11 3,078:44 2,969.44 579.27 -1,675.79 5;946,257.87 557;022:64 0:00 579.27 4,001.42 66:68 318.11 3,fl79.00 2,970.00 58fl.24 -1,676:66 5,948,258.83 557;021,78 O.fl0 58fl.24 Ugnu B 4,100.00 66.68 3.18.19 3,118.42- 3,009.02 647.63 -1,737.11 5,946,325.74 556,96D.79 0.00 847.63. 4,103.31 66.88 318.11 3;119:34 3,010.34 849:89 -1,739.14 5;948,327.99 556;958.75 0:00 649:89 ~ End Pump Tangent: Begin Dir @ 5°/100ft, 4103ft MD, 3119ft TVD ~ I 4,200.00 67.25 323.32 3,157.19 3,048.19 718.74 -1,795.44 5,946,396.39 556,901.91 5.00 718.74 i 4;207.29 67.30 323.72 3,160.00 3,051.00 724.14 -1,799.44 5;946,401.78 556,897,87 5.01 724.14 Ugnu A 4,300.00 68.02 328.67 3,195.25 3,086.25 795.38 -1,847.13 5,946,472.62 556,849.64 5.00 795.38 4,400.00 68.98 333.95 3,239.94 3,122.94 878.98 -1,891 J6 5,946,55,3..84 556,804.37 5.~ 876,98 1 4,500.00 70.06 339.15 3,266.96 3,157.96 962.86 -1,929.01 5,946,639.44 556,766.46 5.00 962.86 4;500.92 70:06 339.15 3,267:00 3;158.00 962:97 -1,929.05 5,946;639:55 556;766.42- 0.00 962:97 4 ~ K13 I i I 4,600.00 71.31 344.28 3,300.05 3,191.05 1,052.44 -1,958.58 5,946,728.78 556,736.19 5.01 1,052.44 ~ 4;700.00 72,70 349:33 3,330.96 3,221.96 1,145.09 -1,980.2& 5,946,$21.16 556;713.79 S:OD 1,145.01 4,800.00 74.21 354.31 3,359.45 3,250.45 1,239.86 -1,993.88 5,946,915.90 556,699.44 5.00 1,239.86 4,900.130 75.83 359.20 3,385.31 3,276.31 1;336.27 -1,999.33 5,947,092.25 556;693.24 5.00 1,338.27 4,968.39 77.00 2.51 3,401.38 3,292.38 1,402.73 -1,998.33 5,947,078.71 556,693.72 5.00 1,402.73 Sail @ 77.00°Inc 8~ 2.51 °Azi : 4968ft MD, 3401ft ND 5;000.00 77:00 2.51 3,408.49 3;299h9 1;433:50 -1,996.98 5;947,109.49 556,694:83 0:00 1;433.50 i 5,fl20:06 77.00 2.51 3;443.00 3,304:00 1,453.02 -1,996.92 5,947,929:02 556,$95.53 fl.00 1;453.02 West Sak D 5,033.39 77.00 2.51 3,416.00 3,307.00 1,466.00 -1,995.55 5,947,142.00 556,696.00 0.00 1,466.00 1J-166 T1 Dtop (wp07) 5,100.00 77.00 2.51 3,430.98 3,321.98 1,530.84 -1,992.71 5,947,206.85 556,698.34 0.00 1,530.84 L 5,200:DD 77:OD 2:51 3;453:48 3;344:48 1,628:1$ -i;988:44 5;947;304:22 556,701:85 0:00 t;628:f8 11/42005 12:24:26PM Page 5 of 10 COMPASS 2003.11 Build 48 ~-' ~ Halliburton Company ~ HALLIBURTON COt1000P~'tl~ p 5 Plannin ra hic Re ort -Geo - ~---°---°~--------m---- ~ g g p p ~ Sperry Drilling Services Datable: EDM 2003.11 Single User Db Local Co-ordinate Reference:.. > Well Plan 1J-166 Company: ConocoPhillips Alaska (Kuparuk) Ti/D-Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True VYell: Plan 1J-166 Sunray Calculation Method: Minimum Curvature iMelibore:. 1 J-166 Design: 1 J-166 (wp07) Planned Survey 1J-166 (wp07) Map Map MD incNnation Azimuth TVD SSTVD +I~il-S +E!-W Northing Fasting DLSEV Vert Section 5,206.76 77.00 2.51 3,455.00 3,346.00 1,634.77 -1,988.16 5,947,310.80 556,702.08 0.00 1,634.77 West Sak C 5,293.39 77.00 2.51 3,474.49 3,365.49 1,719.09 -1,984.46 5,947,395.45 556,705.12 0.00 1,719.09 Begin Dir aLD 4°NOOft, 5293ft MD, 3474ft TVD ~ 5,300.00 77.26 2.51 3,475.96 3,366.96 1,725.53 -1,984.18 5,947,401.58 556,705.35 3.99 1,725.53 5,354.72. 79.45 2.51 3,487.00 3,37$.OD 1,779.07 -1,981.83 5,947,455.14 556,7D7.28- 4.OD 1,779.D7 ~ West Sak B 5,368.39 80.00 2.51 3,489.44 3,380.44 1,792.51 -1,981.24 5,947,468.58 556,707.77 4.00 1,792.51 Sail @ 80°Inc 8 2.51°Azi : 5368ft MD, 3489ft TVD 5,400.00 80.00 2.51 3,494.93 3,385.93 1,823.61 -1,979.88 5,947,499.68 556,708.89 0.00 1,823.61 5,500.00 80.00 2.51 3,512.29 3,403.29 1,921.99 -7,975.58- 5,947,598.09- 556,712.43 0.00 1,927.99. 1 5,578.94 80.00 2.51 3,526.00 3,417.00 1,999.66 -1,972.16 5,947,675.78 556,715.23 0.00 1,999.66 West Sak A4 5,600.00 8D.DD 2.51 3,529.66. 3,420.66 2,D20.38 -1,971.25 5,947,696.5D 556,715.98 D.OD 2,02D_38 5,700.00 80:00 2.51 3;547:02 3,438:02 2,118.77 -1;966.94 5;947,794.91 556;719:52 O:OE1 2,118.77 5,800.00 80.00 2.51 3,564.39 3,455.39 2,217.15 -1,962.62 5,947,893.31 556,723.07 0.00 2,217.15 5,843.85 8fl.i10 2:51 3;572.D0 3,463.Ofl 2,26D.29 -1,96fl.73 5;947,936.46 556;724:$2 0.00 2,260.29 ~ West Sak A3 5,900.00 80.00- 2.51 3,581.75 3,472.75 .2,315.54 -1,95$.31 5,947,991.72- 556,726.62 O.OD 2,315.54. 6,flW:(30 80.00 2.51 3,599:12 3,490.12 2;413.92 -1,954.00 5,948,090.13 556;730:16 0.00 2;413.92- 6,100.00 80.00 2.51 3,616.48 3,507.48 2,512.31 -1,949.69 5,948,188.54 556,733.71 0.00 2,512.31 8,188:39 80.00 2.51 3;631:83 3,522.83 2,599.28 -1,945.87 5,948,275,52 556,736.84 0:00 2,599.28 Begin Dir @ 4°/100ft, 6188ft MD, 3632ft TVD 6;200.00 80.46 2.51 3;633.80 3,524:80 2;610:71 -1,945.37 5;948;286.95 556,737.25 3.99 2,810.71. 6;288:39 84:fl0 2:51 3,645:74 3;536:74 2,696.19 -1,941.54 5;948,374.45 556;740.40 4:00 2,698.19 7 5/8 CSG -Top of Productive Interval ~ 6288ft MD, 3646ft TVD - 702ft FNL & 833ft FWL - Sec35 - T11 N - R10E -West Sak A2 - 7 5/8" 6,30D.OD 84.00- .2.51. 3,646.96. 3,53.7.98. .2,709.72. -1,941.03. 5.,948,385.99. 556,740.82.. 0.00 2,.709.72_ 6;400.00 84.00 2.51 3,657:41 3,548.41 2,809.08 -1,936.68 5,948,485.37 556,744:40 0.00 2,809.08 6,488.39 84.00 2.51 3,666.65 3,557.65 2,896.90 -1,932.83 5,948,573.21 556,747.57 0.00 2,896.90 Begin Dir @ 4°/100ft, 6488ft MD, 3667ft TVD 6,5W.00 84.46 2.51 3,&67:82 3,558.82 2,908.44 -1,932.32 5,948,584:75 556,747.98 3:99 2,90$.44 6';600.00 88:46 2:51 3,673:98 3;554:98 3;006:13 -1,927:95 5;94$;684:48 556,751:57 4:00 3;008:13 6,638.89 90.02 2.51 3,674.50 3,565.50 3,046.98 -1,926.25 5,948,723.32 556,752.97 4.00 3,046.98 Begin Undulations -Begin Dir @ 1.10°/100ft, 6639ft MD, 3675ft TVD -1J-166 T2 Trough 1 (wp07) 6,700.00 90.69 2.51 3,674.12 3,565.12 3,108.03 -1,923.57 5,948,784.38 556,755.17 1.10 3,108.03 6,800.00 91.79 2.51 3,671.95 3,562.95 3,207:91 -1,919.19 5,948;884:28 556,758.77 '1.10 3,207.91 6,900.00 92.89 2.51 3,667.86 3,558.86 3,307.73 -1,914.82 5,948,984.13 556,762.37 1.10 3,307.73 6,948.89 93.43 2.51 3,665.17 3,556.17 3,356.50 -1,912.68 5,949,032.91 556,764.13 1.10 3,356.50 7,000.00 93.43 2.51 3,662.11 3,553.11 3,407.47 -1,910.45 5,949,083.88 556,765.96 0.00 3,407.47 7,100.00 93.43 2.51 3,656.13 3,547.13 3.,507.19 -1,906.07 5.,949,183.63 556,769.56 0.00 3,507.19 7,103.89 93.43 2.51 3,655.89 3,546.89 3,511.08 -1,905.90 5,949,187.51 556,769.70 0.00 3,511.08 7,200.00 92.47 2.43 3,650..94 3,541.94 3,606.96 -1,901.77 5,949,283.42 556,773.08 1.00 3,606.96 7,300.00 91.48 2.34 3,647.50 3,538.50 3,706.82 -1,897.62 5,949,383.30 556,776.46 1.00 3,706.82 7;400.00 90:48 2:25 3;645.79 3;536.79 3,806.72 -1,893:61 5,949,483.22 556;779:68 1,00 3;806.72 1 1/4/100 5 1 2:24:26PM Page 6 of 10 COMPASS 2003.11 Build 48 ~' a Halliburton Company ~ HALLIBURTON ConocoPllillips ra hic Plannin Re ort -Geo - °~---------- ------°-------- g p g p Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordirntte Reference:.. Well Plan tJ-466 Consparry: ConocoPhillips Alaska (Kuparuk) TYD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Projects: Kuparuk River Unit MD Reference: Planning RKB Q 109.OOft (Doyon 141 (28+81)) Site: Kupatuk 1J Pad North Reference: True Well: Plan 1 J-166 Survey Calculation Method: Minimum Curvature Wellbona: 1J-166 Design: 1J-166 (wp07) .Planned Survey 1J-166 (wp07) Map Map MD Inclination Azimuth. TVD `SS'1'ND +N/S +E/-W ~~ing Emoting DLSEV Vert Section (ftl (°l ,1°? ift) IfU (ft) Fft) (ftY (~) {°1100ft) {ft) 7,413.89 90.34 224 3,645.69 3,536.69 3,820.60 -1,893.07 5,949,497.10 556,780.12 1.00 3,820.60 1J-166 T3 Peak 1 (wp07) 7,500.00 89.24 2.05 3,646.01 3,537.01 3,906.65 -1,889.85 5,949,583.16 556,782.67 1.30 3,906.65 7,600.00 87.96 1.82 3,648.45 3,539.45 4.,006.56 -1,886.48 5,949,683.09 556,785.26 1.30 4,006.56 7,700.00 86.68 1.59 3,653.13 3,544.13 4,106.40 -1,883.50 5,949,782.94 556,787.46 1.30 4,106.40 7,723.89. 86..37 1.54 3,554.58 3,545.58 4,130.24 -1,882..85 5,949,806.78 556,787.92 1.30. 4,130,24 7,800.00 86.37 1.54 3,659.39 3,550.39 4,206.17 -1,880.81 5,949,882.72 556,789.37 0.00 4,206.17 7,878:89 86:37 1:54 3;664:38- 3,555.38 4,284.$$ -1,87-8:59 5;949,961.43 556,790:87 O:flO 4,284.88 7,900.00 86.47 1.51 3,665.70 3,556.70 4,305.94 -1,878.13 5,949,982.49 556,791.27 0.50 4,305.94 B,DDD:00 86:96- 1.38- 3,671.43 3;562.43 4,4D5.74 -1,875.61 5,95D;082:3D 55fi;793:01 0:50- 4,4D5.74 8,100.00 87.44 125 3,676.31 3,567.31 4,505.59 -1,873.32 5,950,182.16 556,794.53 0.50 4,505.59 8;188.89 87.87 1,14 3;579:85 3,570,95 4,594.39 -1,871.46 5,950;27D:96 556,795:69- 0.50 4;594:39. 1J-166 T4 Trough 2 (wp07) 8,200.00 88.01 1.10 3,680.35 3,571.35 4,605.49 -1,871.25 5,950,282.06 556,795.82 1.30 4,605.49 8;3DO:OD" 89:27 0.7fi 3;682:72- 3,573.72 4,705.45 -1,$69.62 5;95D;382:D2 556;796:67 1.30 4,70545- 8,400.00 90.52 0.43 3,682.91 3,573.91 4,805.44 -1,868.58 5,950,482.01 556,796.93 1.30 4,805.44 8,498.89 91.76 0.10 3,680.94 3,571.94 4,904.31 -1,868.13 5,950,580.87 556,796.61 1.30 4,904.31 8,500.00 91.77 0.10 3,680.91 3,571.91 4,905.42 -1,868.13 5,950,581.97 556,796.60 0.97 4,905.42 8,60D.DD 92.77 0.10 3,676.94 3,562.94 5,005.34 -1,867.96 5,950,BSL88 556,795.99 1.00 5,OD5.34 8,653.89 93.31 0.10 3,674.08 3,565.08 5,059.15 -1,867.$7 5,950,735.69 556,795.66 1.00 5,059.15 8;7DO.D0 92.85 0.1D 3,671.60 3,562.60 5,1D5.19 -1,867.79 5,950,7$1.73 556,795:38 1:00 5,1Q5:19 8,800.00 91.85 0.10 3,667.49 3,558.49 5,205.11 -1,867.63 5,950,881.63 556,794.76 1.00 5,205.11 8,900:00 90:85- 0.10 3,665:93 3,356.13 5,305:08 -1,867.46- 5;950;981:59 556;794.15 1.00 5;305:08 8,963.89 90.21 0.10 3,664.54 3,555.54 5,368.97 -1,867.36 5,951,045.47 556,793.76 1.00 5,368.97 End Undulations Geosteer in Upper Lobe, 8964ft MD, 3665ft TVD -1J-166 T5 Peak 2 (wp07) 9,000.00 89.89 0.12 3,664.51 3,555.51 5,405.07 -1,867.29 5,951,081.57 556,793.54 0.90 5,405.07 9;100:00 88:99 D.20 3,665.48 3,551.48 5,5D5.07 -1,867:00 5,951,181.51 556,793:D5 D:90 5,505.D7 9,200.00 88.10 0.28 3,668.02 3,559.02 5,605.03 -1,866.58 5,951,281.51 556,792.69 0.90 5,605.03 9,273.89 87.43 0.34 3,670.90 3,561.90 5,678.87 -1,866.18 5,951,355.34 556,792.51 0.90 5,678.87 9,300.00 87.43 0.34 3,672.07 3,563.07 5,704.95 -1,866.03 5,951,381.42 556,792.46 0.00 5,704.95 9,400.00 87.43 0.34 3,676.55 3,567.55 5,804.85 -1,865.44 5,951.,481.31 556,792.28 0.00 5,804.85 9,500.00 87.43 0.34 3,681.03 3,572.03 5,904.75 -1,864.85 5,951,581.20 556,792.09 0.00 5,904.75 9,523.89 87.43 0.34 3.,682.10 3,573.iD 5,928.61 -1,864.71 5,951,605A7 556,792.04 0.00 5,928.61 9,543.06 88.00 0.44 3,682.86 3,573.86 5,947.76 -1,864.58 5,951,624.22 556,792.02 3.00 5,947.76 9;600:00 88:00 ©:44 3,684:85 3,375.85 6;OOd:67 -1,864.44 5,951,669:12 556,792:01 0:00 6,004:67 9,700.00 88.00 0.44 3,688.34 3,579.34 6,104.60 -1,863.38 5,951,781.05 556,792.00 0.00 6,104.60 9;793:06 88.00 0:44 3,691.58 3,582.58- 6,t9T.60 -1,862.67 5,951,874:04 556,791:99 O:OD 6,197.60 9,800.00 88.34 0.46 3,691.81 3,582.81 6,204.54 -1,862.61 5,951,880.98 556,791.99 4.97 6,204.54 9,900.00 93.34 0.75 3,690.34 3,581.34 6,304.49 -1,861.56 5,951,980.92 556,792.26 5.00 6,304.49 9,993.51 98.01 1.03 3,681.10 3,572.10 6,397.51 -1,860.12 5,952,073.94 556,792.98 5.00 6,397.51 10,000.00 98.01 1.03 3,680.19 3,571.19 6,403.93 -1,860.00 5,952,080.37 556,793.04 0.00 6,403.93 10,100.00 98.01 1.03 3,666.27 3,557.27 6,502.94 -1,858.23 5,952,179.38 556,794.04 0.00 6,502.94 10,182.69 98.01 1.03 3,654.75 3,545.75 6,584.81 -1,856.77 5,952,261.25 556,794.87 0.00 6,584.81 10,200.OD 97.14 0.98- 3,652.47 3,543.47 6,601.97 -1,856.47 5,952~Z8.40 556,795,04 4.99. 6,601.97 10,300.00 92.15 0.71 3,644.37 3,535.37 6,701.60 -1,855.00 5,952,378.03 556,795.73 5.00 6,701.60 90,398:91 87.21 U.45 3;644:93 3,535:93 6;800.47 -1,853:99- 5;952,47$:90 556,795:96 5:Of1 6,800,47 10,400.00 87.21 0.45 3,644.98 3,535.98 6,801.56 -1,853.98 5,952,477.99 556,795.96 0.00 6,801.56 1D,50D:00 87.21 0:45 3,149.85 3;540.85 1,901.44 -1,853:2fl 5,952,577:86 556,795.97 D.00 8,9D1.44 10,600.00 87.21 0.45 3,654.72 3,545.72 7,001.32 -1,852.42 5,952,677.73 556,795.97 0.00 7,001.32 11/4/2005 12:24:26PM Page 7 of 10 COMPASS 2003.11 Build 48 ti-' . Halliburton Company • WALi IBURTON COtl~CO~'11~~Ip5 Plannin Re ort -Geo ra hic . ~-._~_--~-----------~-~~--~- g g p p Alaska Sperry Drilling Services Databsaces EDM 2003.11 Single User Db Local-Co-ordlna~ Refanance: Well Plan 1 J-166 Gomparry: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Proj~ ' Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Refenuu:e: True Weli: Plan 1J-166 SunreyCatcu~tion Method: Minimum Curvature Wetiborec - 1J-166 Design: -1J-166 (wp07) Planned Survey 1J-166 (wp07) Map Map MD In¢tinaNon Azimuth ' TVD SSTVD +N(-S +E/.W Northing Fasting DLSEV Vert Section (ft) (°} °) (ft) (ft) (fty (ft) Ift) (ft) (°nooft) (ft) 10,700.00 87.21 0.45 3,659.58 3,550.58 7,101.20 -1,851.63 5,952,777.60 556,795.98 0.00 7,101.20 10,800.00 8721 0.45 3,664.45 3,555.45 7,201.08 -1,850.85 5,952,877.48 556,795.98 0.00 7,201.08 10,900.00 87.21 0.45 3,669.32 3,560.32 7,300.95 -1,850.06 5;952,977.35 556,795.99 0.00 7,300.95 11,000.00 87.21 0.45 3,674.19 3,565.19 7,400.83 -1,849.28 5,953,077.22 556,795.99 0.00 7,400.83 11,098.91 87.21 0.45 3,679.00 3,570.00 7,499.62 -1,848.50 5,953,176.00 556,796.00 0.00 7,499.62 1J-166 T6 (wp07) 11,100.00 87.24 0.45 3,679.05 3,570.05 7,500.71 -1,848.49 5,953,177.09 556,796.00 2.88 7,500.71 11,200.00 90.24 0.45 3,681.25 3,572.25 7,600.67 -1,847.71 5,953,277.05 556,796.00 3.00 7,600.67 11,208.77 90.51 0.45 3,681.19 3,572.19 7,609.44 -1,847.64 5,953,285.81 556,796.00 3.00 7,609.44 11,300.00 90.51 0.45 3,680.38 3,571.38 7,700.67 -1,846.93 5,953,377.03 556,796.00 0.00 7,700.67 11,400.00 90.51 0.45 3,679.50 3,570.50 7,800.66 -1,846.15 5,953,477.02 556,796.00 0.00 7,800.66 11,500.00 90.51 0.45 3,678.62 3,569.62 7,900.65 -1,845.38 5,953,577.01 556,796.00 0.00 7,900.65 11,600.00 90.51 0.45 3,677.74 3,568.74 8,000.64 -1,844.60 5,953,676.99 556,796.00 0.00 8,000.64 11,700.00 90.51 0.45 3,676.85 3,567.85 8,100.64 -1,843.82 5,953,776.98 556,796.00 0.00 8,100.64 11,800.00 90.51 0.45 3,675.97 3,566.97 8,200.63 -1,843.04 5,953,876.97 556,796.00 0.00 8,200.63 11,894.23 90.51 0.45 3,675.14 3,566.14 8,294.85 -1,842.30 5,953,971.18 556,796.00 0.00 8,294.85 11,900.00 90.33 0.45 3,675.10 3,566.10 8,300.62 -1,842.26 5,953,976.95 556,796.00 2.98 8,300.62 11,997.09 87.42 0.45 3,677.00 3,568.00 8,397.68 -1,841.50 5,954,074.00 556,796.00 3.00 8,397.68 1J-166 T7 (wp07) 12,000.00 87.33 0.45 3,677.13 3,568.13 8,400.59 -1,841.48 5,954,076.91 556,796.00 2.95 8,400.59 12,044.61 85.99 0.45 3,679.73 3,570.73 8,445.12 -1,841.13 5,954,121.44 556,796.00 3.00 8,445.12 12,100.00 85.99 0.45 3,683.60 3,574.60 8,500.37 -1,840.70 5,954,176.69 556,796.00 0.00 8,500.37 12,200.00 85.99 0.45 3,690.59 3,581.59 8,600.13 -1,839.92 5,954,276.44 556,796.00 0.00 8,600.13 12,300.00 85.99 0.45 3,697.57 3,588.57 8,699.88 -1,839.14 5,954,376.18 556,796.00 0.00 8,699.88 12,400.00 85.99 0.45 3,704.56 3,595.56 8,799.63 -1,838.37 5,954,475.93 556,796.00 0.00 8,799.63 12,500.00 85.99 0.45 3,711.54 3,602.54 8,899.38 -1,837.59 5,954,575.67 556,796.00 0.00 8,899.38 12,600.00 85.99 0.45 3,718.53 3,609.53 8,999.14 -1,836.81 5,954,675.42 556,796.00 0.00 8,999.14 12,700.00 85.99 0.45 3,725.51 3,616.51 9,098.89 -1,836.04 5,954,775.17 556,796.00 0.00 9,098.89 12,745.87 85.99 0.45 3,728.72 3,619.72 9,144.65 -1,835.68 5,954,820.92 556,796.00 0.00 9,144.65 12,800.00 87.62 0.45 3,731.73 3,622.73 9,198.69 -1,835.26 5,954,874.96 556,796.00 3.00 9,198.69 12,841.07 88.85 0.45 3,733.00 3,624.00 9,239.73 -1,834.94 5,954,916.00 556,796.00 3.00 9,239.73 BHL @ 12841ft MD, 3733ft TVD : 560ft FSL & 947ft FWL --Sec 23 - T11 N - R10E - 4 1 /2" -1J-166 T8 (w p07) 11/4!2005 12:24:26PM Page 8 of 10 COMPASS 2003.11 Build 48 v-' ~ Halliburton Company • HALLIBURTON ConocoPhillips Plan i R rt G hi ----~-----~--~------------------~---- eograp n ng epo - c PJaska Sperry Orllling Services Database: EDM 2003.11 Single User Db Loca1 Co-ordinate Reference: Well Ptan 1J-166 Companyr ConocoPhiliips Alaska (Kuparuk) TVD Reference: Planning RKB (c~ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB (c~ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1 J-166 Survey Calculation: Mettrod: Minimum Curvature 1Nellbore: 1 J-166 Design: 1J-166 (wp07) Geologic. Targets. 1 J-166 TVD Target Name +N/-S , +E/ W Northing Fasting (ft} -Shape ft ft (ft) (ft) 3,679.95 1J-166 T4 Trough 2 (wp07) 4,594.39 -1,871.46 5,950,270.96 556,795.69 - Point 3,679.00 1J-166 T6 (wp07) 7,499.62 -1,848.50 5,953,176.00 556,796.00 ', -Point ~I 3,674.50 1J-166 T2 Trough 1 (wp07) 3,046.98 -1,926.25 5,948,723.32 556,752.97 ~ - Point 3,677.00 1J-166 T7 (wp07) 8,397.68 -1,841.50 5,954,074.00 556,796.00 - Point 3,416.00 1J-166 T1 Dtop (wp07- 1,466.00 -1,995.55 5,947,142.00 556,696.00 - Point 3,645.69 1J-166 T3 Peak 1 (wp07) 3,820.60 -1,893.07 5,949,497.10 I 556,780.12 - Point 3,733.00 1J-166 T8 (wp07) 9,239.73 -1,834.94 5,954,916.00 556,796.00 - Point 3,664.54 1J-166 T5 Peak 2 (wp07) 5,368.97 -1,867.36 5,951,045.47 556,793.76 - Point j Progr-osed Casing Points Measured Ver'dt~l Casing Hole Depth Depth Diameter Diameter (~) (~) (") _ ,1") ~ so.oo so.oo 20 zs 2,359.67 2,183.00 10-314 13-1/2 ~ 6,288.39 3,645.74 7-518 9-7/8 12,841.06 3,733.00 4-1l2 6-3/4 11/4!2005 12:24:29M Page ~f 10 COMPASS 2003.11 Build 48 f ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: ', Kuparuk River Unit She• Kuparuk 1J Pad Weii: Plan 1J-166 Weiiborec 1J-166 Design:. 1 J-166 (wp07} Halliburton Company • HAL~.IBURTON Planning Report -Geographic ---~-~__~.~_-~--~mm--~---•---- Sperry Driiling Services Lacat Co-oMinate Reference:. ° Well Plan 1J-166 TVD Reference: Planning RKB (a~ 109.OOft (Doyon 141 (28+81 )) MD Refererce: Planning RKB Q 109.OOft (Doyon 141 (28+81)) Norte Reference• True Survey CaiculatFon Method: Minimum Curvature Prognosed Forrnation IMersectfanPoMts Measured Vertical ~Pth inclination Azimuth ~i~ +N!-E +El-W Name 1~) (°) 1°i I~j (ft) 1ft1 1,564.10 32.54 250.00 1,514.00 -89.18 -245.01 Permafrost 1,712.37 32.54 250.00 1,639.00 -116.45 -319.94 T3 2,057.54 32.54 250.00 1,930.00 -179.94 X94.39 K15 2,359.67 34.74 267.80 2,183.00 -219.24 -653.82 T3+550 3,455.75 66.68 318.11 2,863.00 207.21 -1,342.07 Ugnu C 4,001.42 66.68 318.11 3,079.00 580.24 -1,676.66 Ugnu e 4,207.29 67.30 323.72 3,160.00 724.14 -1,799.44 Ugnu A 4,500.12 70.06 339.15 3,267.00 962.97 -1,929.05 K13 5,020.06 77.00 2.51 3,413.00 1,453.02 -1,996.12 WestSakD 5,206.76 77.00 2.51 3,455.00 1,634.77 -1,988.16 West Sak C 5,354.72 79.45 2.51 3,487.00 1,779.07 -1,981.83 West Sak B 5,578.94 80.00 2.51 3,526.00 1,999.66 -1,972.16 West Sak A4 5,843.85 80.00 2.51 3,572.00 2,260.29 -1,960.73 West Sak A3 6,288.35 84.00 2.51 3,645.74 2,698.15 -1,941.54 West Sak AZ f 1/4/2D05 12:24:2BM Page 10 of 10 COMPASS 2003.11 Build 48 ~ ~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River tit Kuparuk 1J Pad Plan 1J-166 1 J-166 Anticollision Summary 04 Novembr, 2005 HALLII~URTC7N Sperry Drilling Services SURVEY PROGRAM NAD 27 ASP Zane 4 : WELL DETAILS: Plan iJ-166 ConocoPhllllps Ahsks (Kuparuk) -- ------------ Date: 2U0.S-11-0JTOO:OU:W Vatldated: Yea Vertlon: ANTI~OLIJSION SETnN08 Ground Level: 81 00 Drilling 8 Welk IrtterpoAdon Method: MD ItdarvN: 60Sbtiorts . +W.S +EI-W Northing Fasting Lathtude Longitude Slot West Sak Depth Rrom Depth To Sorvn~IPlsa Tool Depth Range From: 28,00 To 12847.07 0.00 0.00 5849991.74 958702.73 7D'iS44.023N 148'31'71.587W 29.tq &IU.W IJ-166 (wp07) CB-CYROSS Masknwn Range;1481,706564288g1 Cakulation Method: Minimum Curvature BOII.W 12811,07 IJ-166 (wp07) MWD+IAR-AKCA~SC Rehnnu: Pkn: 1J-199 (wp07) Error System: ISCWSA Sun Method: Tmv. Cylinder North Error Surface: Elliptical Conit an Warning Method: Rules Based CJ-154 ' 330 / ~~09 / wSP~2~ 1J-10'i, Plan 1J-164 Plan 1J-156 (M4)~ T ° , _\ - ~ 1J-03 ~ ~ ~ :_~_ ~, ~ 20 ~ ~ ~ % ` 3o Plan 1J-109 300 ~ ~ 60 ; _ 1 3 { ~ CSP-02I 1 Plan 1J-158 (M3) y` __ ~ ~ Plan 1J-111 (M12) 'rs ,~ p ~ 1 ,~ 60~ (' ;~;~ 22 + I _ Plan 1J-159 ~~ .--,i, ,300 WSP-03 ~ -.~- _ ~ ~ t ~ WSP-20 - 1 1 ~ _ „-~ " 270 ,7 ( ~ i ~-- i.., -,WSP-04 ~ ,„ Plan 1J-162 _ _ /,~,.t- '} Plan 1J-115 (L9)ii 5 i 1 ~ -- --il /~ r ' - ^"~, _WSP-051 ~ `( r _ ~ ~ -,Plan 1J-118 (L10)~ 1 (~q~ X a._ ~j~, "' " -~ WSP-06~ -_ ~ ~ _,~ 1 270 ~+;_~ '~ Plan 1J-120 (L11)~ 240 120 _ c-~ • ~_ I" ~ lart 4J 722 (L12)~ / 20 ,~ ( / # T WSP-07 a % / f - + ~'' iPlan iJ-127 (LB) ~ 25 ~~' ~ ~ ~ ~ ~ 210 150 _ r' ~ 1 _ ,fit ~ ~ Plan 1J-124 (L13)~ 30 1J-188 ,~ $ ~ ~ 240 _, . ~ 12 180 ~ / WSP-06:. Travelling Cylinder Azi muth (TF/~AZl) (°) vs Centre to Centre Separation (15 ftlinJ 2 ~ ~-- ~ ''~ - - % T From COlour To MD BECTgN nETNIE i~ ~- r ~ i! i ~ ~ ~ - --- ~ I ~ _ ~ 9c aO Inc t v m o oo YI lVD Nei ~EIYI TFC~ Vac Taepr 00 0~ 6 0m om o m m oo o m o __ -.. f' 3 - ~ ' ' _ 210 --r - - 28 150 250 . . z am.m 9.m 9 /m.m 2w . . . . 0.00 600.00 o.m o.o0 z60.oo Too.m a.n s.oe . 6.m 0m a.m a.m xwm a.n - 1 j I 250 500 ~ I6m.n ss.W s xt6e.n Sx.e/ xw.u t6a.oo a.oe au.o+ xm.m mtae] -19eA6 a/6z1 aeo 0m ae.m o.m 0m nce.u _ _ -..- l Pld i ~ i i d 500 750 a uaaa u.n T ItW.]t mu a uu ]9 n.m ]t9.tt mlaw tu.a -tazm ae.n mt9.x sum -Ins.u zbt ]ut.le luzn ns9ea] s.m aux tar.» a.u am wm 6m Nn I/o2n --~ ~ 750 1000 . io ~a:]mi n:o00o isi aialmi irn:a iwA, 00.0 Demo ilwa 111NT11ttoplwpWl 16D it 6]fi9.]9 80.00 261 3189.6{ 1nx.a1 -198121 0.00 amm 1]9281 Plan 1J-176 Q2 ~ ( )~ 1000 ~',PIaO 1J-152 (M5)~~ 1250 tx sle9>o w.m tz ex99u u.a6 1/ (169 ]0 84 m zm ]pt.e] xW919 -1918a1 26t ]fits.]/ x69s.u .Iwta/ 261 NB6 B6 xpa90 -lpzl] om 0.m z6s9a am o.m za9e.u 0.06 0 00 3996.10 _ -- - ~ _ `- 1250 1500 . . 16 B6uA9 eaA3 . 261 ]811.80 mum -tree . 0.m O.m ]W.M 1}tp nTf0u8911wpMl Plan 1J-17 QB 3 ~ ( ). 1500 1750 a cs19.9s eau n TIa3A1 uAl z61 ]ca6.n ]9m.f0 -mzee z61 ws6.m ]en.u -1s0sm u0 0.m Sa61.ao 0.00 0m a6n.u -- Travelling Cylinder Azimuth (TFO+AZI) ~°] v s Ceotre to Centre Separation ~i50 t't/in] n5o zooo 16 Tnz es W.>. 19 nx].u Bali m nn.n M.]T e z.z1 ]au.a9 um.u -teu.01 1.81 3666.68 1190.21 -tm.eb , W ]661a1 /x...m n6n..9 6 t.m nnm Sem.te 1}teanta.atl9moT1 t.m tmm 11m.M 9.m em .ea.r IWIS 1}1ta Tl T x ol 20DD 3DDD x3 M96a8t 91.71 880.91 e0/9, -iNe.~ 0.10 3 _ ro,q, ) l+w 1.m ]um 3000 - 4000 x] Ba6].6a 9].91 31 neze9 w.xt 0.10 381x08 WW.18 -1m1.81 o.1o SBN61 61m.91 -1pT.u 1.00 Om 80N.16 I.u -16oa0 ean.n 1}Im nwwxlwo011 4DDD SDDD m 9xn.89 91.1] a f6m.e9 BTA2 0.]I a6T0A0 61nA1 -iMa.18 O.LI 368x.10 9mA1 -1M1.T1 0.90 116.00 86n.M O.m O.m um.e1 SODD 6000 ]7 960.1.08 BBm a 9n961 M.01 O.M 388286 691T.i6 -1661.68 1.N ]801.0 69n.8mt -1N013 ].m 10m ta41.n [m 9A1 e]9TA1 6000 7000 9a loln.a u.ol ]t 1wu.n n]1 1.0] aN1.n fime.et nem.n oA6 36M.93 soon -1M].w o.m 0.m 66eaet au -tnA] c9ooa 7000 8000 u ttufi.n nit ss +txu.n pat 0A6 ]819.m 11n.a: -tawm o.u ]6n.u Tam.u a1w1.u om o.m rlp.s2 1}lanlwofl am as1 16m.N REFERENCE INFORMATON 8000 9000 >a 11996.m 10b1 J6 1199109 B1A2 ]a tma.at N.n 0.16 ]616.11 BeIK -IM2a0 0.16 ]6TT.D0 eeT.u -1M/a0 oA6 Mn.T] 81u.tz -t801.t] O.m Om 8x90.16 ].m Ina] 8]91.0 i}1N 11Iw1oT1 Sm -mm 9u6u 90DD 1DD00 ]7 13116.8] 9619 N 12811.0] 96x6 O.K ]128.]3 91M.a6 ~19M.M 0.16 3T3].OD r1]9.n -1830.N 0.00 O.m 911Atd 9.00 O.OT 92]B.n 1}1M nIw9W) Coardinah (WE) Rehrena: Well Plan 1J-198, True North Vertical (ND) Rahnnce: Planning RKB ~ 709.OOn (Doyon 141 (28+91)) 10000 11000 Sactlon (VS) Refemnu: Slot-(O.OON, O.OOE) 11000 12000 Measured Depth Rehmnce: Planning RKB ~ 109.OOR (Doyon 147 (28+91)) Calcule8on Method: Minimum Curwturo 12000 13000 ConocoPhillips Alaska Company:. ConocoPhillips Alaska {Kuparuk) Project: ; Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error. O.OOft Reference Well: Plan 1J-166 WeH Error..: O.OOft Reference Wellbre 1J-166 Reference Design: 1J-166 (wp07) Mlit7rton Com pany ~ HALLIBURTON Anticollision Report ~°_-~°~~-°~°---°~~--------~- Sperry Drllling Servlees Local Co-ordlr~ate Reference: Well Plan 1 J-166 TVD Reference: Planning RKB ~ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Output errore are at 2.57 sigma Data6se: EDM 2003.11 Single User Db t)ffset TVD Reference:. Offset Datum Reference 1 J-166 (wp07) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,481.31ft Error Surface: Elliptical Conic blaming Levels evaluated at: 0.00 Sigma j Survey Tool Program Date 11!3!2005 ~ From To jft) (ft) Survey (Wellbre) Tool-Name Description 28.00 800.00 1J-166 (wp07) (1J-166) CB-GYRO-SS Camera based gyro single shot 800.00 12,841.07 1J-166 (wp07) (1J-166) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to enter distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/4/2005 4:45:38PM Page 2 of 3 COMPASS 2003.11 Build 48 ~: ConocoPhillips Alaska company:.. ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference-Site: Kuparuk 1 J Pad Site Error: O.OOft Reference WeIL Plan 1J-166 Well Error.: O.OOft ReferenceWeltbne 1J-166 Reference Design: 1J-166 (wp07) bllihrton Com pany ~ MA~.~.IBURTON Anticollision Report ~~-~-- °-~~-~-~---_-~-~°-~----• Sperry Drilling Services t.ocal Caadinate Reference: Well Plan 1 J-166 TVD Reference: Planning RKB (a~ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB ~ 109.OOft (Doyon 141 (28+81p North Reference: True Survey Calculation Method: Minimum Curvature Out~wt errors are at 2.57 sigma Dataltse: EDM 2003.11 Single User Db Offset TVD Reference: 'Offset Datum Summary Reference Offset Centre to No-Go Aflowale Measured Measured Centre'- Distance Deviation Warning $ite Name Depth Depth ,Distance (ft), from Plan .Offset We11- Wellbre -Design (ft) (ft) {it) (Tt) Kuparuk 1 E Pad 1 E-105 -1 E-105 - 1 E-105 11,327.88 13,150.00 1,269.24 222.16 1,047.08 Pass -Major Risk 1 E-105 -1 E-105L1 - 1 E-105L1 10,929.34 13,529.00 1,284.65 235.17 1,049.48 Pass -Major Risk 1 E-105 -1 E-105L2 -1 E-105L2 12,101.21 12,350.00 1,319.53 220.41 1,099.12 Pass -Major Risk 1 E-105 -1 E-105PB2 -1 E-105PB2 12,281.07 12,208.00 1,249.68 229.25 1,020.43 Pass -Major Risk Kuparuk 1J Pad 1J-03 -1J-03 - 1J-03 142.88 150.00 244.25 2.52 241.73 Pass -Major Risk 1J-09 - 1J-09 -1J-09 293.93 300.00 280.40 5.37 275.03 Pass -Major Risk 1J-10 - 1J-10 -1J-10 644.43 650.00 122.41 11.97 110.44 Pass -Major Risk 1 J-154 -1 J-154 -1 J-154 Rig 599.87 600.00 266.85 13.16 253.69 Pass -Major Risk 1J-154 -1J-154 L1 - 1J-154 L1 589.87 600.00 266.85 13.16 253.69 Pass -Major Risk 1 J-168 -1 J-168 -1 J-168 Rig 349.94 350.00 40.98 7.64 33.34 Pass -Major Risk 1J-168 - 1J-168 L1 -1J-168 L1 Rig 349.94 350.00 40.98 7.64 33.34 Pass -Major Risk 1J-168 -1J-168 L2 -1J-168 L2 349.94 350.00 40.98 7.64 33.34 Pass -Major Risk 1J-168 -1J-168 L2 PB1 -1J-168 L2 PB1 Rig 349.94 350.00 40.98 7.64 33.34 Pass -Major Risk Plan 1J-109 -Plan 1J-109 -1J-109 (wp01) BHI 287.99 300.00 231.76 6.38 225.38 Pass -Major Risk Plan 1J-111 (M12} -Plan 1J-M12 Lat A -Plan 1J-I 350.99 350.00 202.53 6.75 195.79 Pass -Major Risk Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1J-L9 L 550.99 550.00 158.09 10.49 147.59 Pass -Major Risk Plan 1 J-118 (L10) -Plan 1 J-L10 Lat A -Plan 1 J-L' 450.99 450.00 146.24 8.62 137.62 Pass -Major Risk Plan 1 J-120 (L11) -Plan 1 J-L11 Lat A -Plan 1 J-L' 450.99 450.00 151.79 8.62 143.17 Pass -Major Risk Plan 1J-122 (L12) -Plan 1J-L12 Lat A -Plan 1J-L' 350.99 350.00 166.94 6.75 160.20 Pass -Major Risk Plan 1 J-124 (L13) -Plan 1 J-L13 Lat A -Plan 1 J-L' 300.99 300.00 189.46 5.81 183.66 Pass -Major Risk Plan fJ-127 (L8) -Plan 1J-L8 LatA -Plan 1J-LS Le 695.74 700.00 232.64 13.23 219.41 Pass -Major Risk Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDispc 350.99 350.00 360.75 6.75 354.00 Pass -Major Risk Plan 1J-152 (M5) -1J-152 -1J-152 (wp04) 4,368.61 4,799.98 168.74 89.98 78.76 Pass -Major Risk Plan 1J-152 (M5) -1J-152 L1 -1J-152 L1 (wp04) 4,368.61 4,799.98 168.74 89.96 78.78 Pass -Major Risk Plan 1 J-152 (M5) -1 J-152 L2 -1 J-152 L2 (wp04) 4,368.61 4,799.98 168.74 89.96 78.78 Pass -Major Risk Plan 1 J-156 (M4) -Plan 1 J-M4 A Lat -Plan 1 J-M4 650.10 650.00 221.97 12.41 209.56 Pass -Major Risk Plan 1J-158 (M3) -1J-158 -1J-158 (wp2A) BHI 350.92 350.00 181.17 6.80 174.36 Pass -Major Risk Plan 1 J-159 -1 J-159 -1 J-159 (wp03) 797.52 800.00 161.23 17.42 143.81 Pass -Major Risk Plan 1J-159 -1J-159 L1 -1J-159 L1 (wp03) 798.49 800.00 161.25 16.05 145.20 Pass -Major Risk Plan 1J-159 -1J-159 L2 -1J-159 L2 (wp03) 798.49 800.00 161.25 16.05 145.20 Pass -Major Risk Plan 1J-160 -Plan 1J-160 -1J-160 (wp01) BHI 349.92 350.00 140.90 7.58 133.32 Pass -Major Risk Plan 1J-162 -1J-162 - 1J-162 (wp03.1-North Heel 350.92 350.00 80.85 7.44 73.41 Pass -Major Risk Plan 1J-162 -1J-162 L1 -1J-162 L1 (wp3.1) 350.92 350.00 80.85 7.34 73.51 Pass -Major Risk Plan 1J-162 - 1J-162 L2 -1J-162 L2 (wp3.1) 350.92 350.00 80.85 7.34 73.51 Pass -Major Risk Plan 1 J-164 -1 J-164 -1 J-164 Rig 499.99 500.00 40.95 10.83 30.11 Pass -Major Risk Plan 1 J-170 -Plan 1 J-170 -1 J-170 (wp01) 549.85 550.00 81.55 11.92 69.63 Pass -Major Risk Plan 1J-174 -Plan 1J-174 - 1J-174(wp01) 249.99 250.00 160.39 5.41 154.98 Pass -Major Risk Plan 1 J-176 (Q2) -Plan 1 J-Q2 B Lat -Plan 1 J-Q2 300.99 300.00 200.52 5.80 194.72 Pass -Major Risk Plan 1 J-178 (Q3) -Plan 1 J-Q3 B Lat -Plan 1 J-Q3 300.99 300.00 240.67 5.80 234.87 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 638.65 650.00 239.36 13.36 226.00 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 649.85 650.00 205.94 17.62 188.32 Pass -Major Risk WSP-04 - WSP-04 -WSP-04 638.94 650.00 179.84 13.36 166.48 Pass -Major Risk WSP-05 -WSP-05 -WSP-05 680.78 700.00 182.00 18.30 163.70 Pass -Major Risk WSP-O6 - WSP-O6 -WSP-O6 634.36 650.00 202.13 16.92 185.21 Pass -Major Risk WSP-07 -WSP-07 -WSP-07 681.21 700.00 228.71 20.95 207.76 Pass -Major Risk WSP-08 -WSP-08 -WSP-08 786.18 800.00 270.71 37.32 233.39 Pass -Major Risk WSP-20 -WSP-20 -WSP-20 956.06 950.00 44.66 24.30 20.37 Pass -Major Risk CG -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/4/2005 4:45:38PM Page 3 of 3 COMPASS 2003.11 Build 48 • • FRANK H. MURKOWSKI, GOVERNOR Re: West Sak 1J-166 ConocoPhillips Alaska, Inc. Permit No: 205-198 Surface Location: 1880' FSL, 2508' FEL, Sec. 35, T 11 N, R l OE, UM Bottomhole Location: 552' FSL, 947' FWL, Sec. 23, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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 to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager) . DATED this day of December, 2005 cc: Department of Fish 8~v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Chairman Conoco hillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com November 28, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ~~~ ~ ~~~~ Alaska pil $~ ~~s ~o~s, ~t~m~ea~e>~ ArICh~!r~f Re: Applications for Permit to Drill, West Sak Producer, 1J-166, 1J-166 L1, iJ-166 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a trilateral horizontal well in the West Sak "A2", "B"and "D" sands. The main bore of the well will be .designated 1J- 166, and the lateral bores of the well will be designated 1J-166L1 and 1J-166L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-166 is January 1, 2006. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, ~ ~.~~ ~~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA , ~~~~ ~~~~~'°'~ ALASKA OIL AND GAS CONSERVATION COMMISSION DEC a ~ 005 PERMIT TO DRILL 20 AAC 25.005 Alaska Oil & Gas Cons.~Corrnnisso 1 a. Type of Work: Drill ^ Redrill Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ~ ple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone Q 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: 1J-166 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12841' " TVD: 3733' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1880' FSL, 2508' FEL, Sec. 35, T11 N, R10E, UM' 7. Property Designation: ADL 25661 & 25650 West Sak Oil Pool Top of Productive Horizon: 702' FNL, 833' FWL, Sec. 35, T11N, R10E, UM 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 1/1/2006 Total Depth: ~ G~t~~f ~'H/L, ~,~ , g•o s~ 552' FSL, 1 FWL, Sec. 23, T11 N, R10E, UM ~ 9. Acres in Property: 2560 14. Distance to ~- % p~;~A Nearest Property: ~9' l.~puit,a~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558703 y- 5945692 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1 D-127 , 647' @ 12980' 16. Deviated wells: Kickoff depth: 600 ~ tt. Maximum Hole Angle: 98° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1680 psig Surface: 1269 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Size ica ons pec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2360' 28' 28' 2360' - 2183' ~ 460 sx ASLite, 170 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 6288' 28' 28' 6288' 3646' ~ 360 sx DeepCRETE 6.75" 4.5" 12.6# L-80 IBTM 7383' 5458' 3501' 12841' . 3733' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Perforation Depth MD (tt): Perforation Depth TVD (ft): 20. Attachments: Filing Fee O BOP Sketch ^ Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` ---- Phone Z~~ 6.~ ~ v Date i t ~2 $r`®S P a b haro II k Commission Use Only Permit to Drill Number: ZC~S-~ ~ API Number: 50- C7 Z4 - Z. 3Zg ~ r ~O Permit Approval Date: s See cover letter for other requirements Conditions of approval : ~~ ~~~~~'~ ~ ~ ~ ~ rO vk ~ ~ CSC CtaM M«~ 5 ZJ ~+ ~C v°~ ~~'~{S . amp s required Yes ^ No JI~~ Mud log required ~ Yes ^ No r gen sulfide measures Yes ^ No ~ Directional survey required Yes ~ No ^ Other: ~ ~ ~~ ~~~~ APPROVED BY r ' ~~ Appro THE COMMISSION Date. /~ y~' J~~ Form 10 01 Re~ 06/2004 ~ ~ („~ ~ ~ :~ ~ '~~~ ~ ~~~. S~bmit in uplic~ cation for Permit to Drill, Well 1J-166 Revision No.O Saved: 28-Nov-05 Permit It -West Sak Well #1J-166 ~~~~~ .., ;, Application for Permit to Drill Document„ II~IaWell M d x i m i x E Well Volue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (1) ....................................................................................................... 2 2. Location Summary ................................................................................................... 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. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c) (4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 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. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10.Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1J-166 PERMIT /T.doc Page 1 of 8 Printed: 28-Nov-05 O.IGINAL • cation for Permit to Drill, Well 1 J-166 Revision No.0 Saved: 28-Nov-05 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 Attachment 5 1/4 Mile Radius Effect for Injector ...................................................................... 8 1. Well Name Requirements of 20 AAC 25.005 (fl Each we/l must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC25.040(b). For a well with mu/tiple wel/branches, each branch mustsimilar/y be identified by a unique name and API number by adding a suffix to the name designated for the we// 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 1J-166. ,~-.---~ 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drif/ must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (2) a p/at identifying the properfy 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 (B) the coordinates of the proposed location of the we/l at the surface, referenced to the state p/one coordinate system for this state as maintained by the Nations/ Geodetic Survey in the Naliona/ Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at tots/ depth; Location at Surface 1 880' FSL, 2 508' FEL Section 35, T11N R10E ASP Zone 4 NAD 27 Coordinates RKB E/evation 109.0' AMSL Northings: 5,945,692 ~ Eastings; 558,703 ~ Pad E/evation 81.0' AMSL Location at Top of Productive Interval West Sak "A2" Sand 702' FNL, 833' FWL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 6 288 Northings: 5,948,374 Eastings: 556,740 Total 1/ertical De th RKB; 3 646 Total 1/ertical De th SS.• 3 537 Location at Total De th 552' FSL ' FWL, Section 23 T11N, R10E ASPZone 4 NAD 27 Coordinates Measured De th RKB: 12,841 - Northings: 5,954,915 Eastings: 557,796 Tota/ 1/ertica/De th, RKB: 3,733 - Tota/ 1/ertical De th SS.- 3 624 1J-166 PERMIT IT.doc Page 2 of 8 Printed.' 28-Nov-05 ORIGINAL cation for Permit to Drill, Well 1 J-166 Revision No.O Saved: 28-Nov-05 and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a we/l is to be intentionally deviated, ffie application for a Permit to Drill (Form 10-401) must (1) inc/ude a plat, drawn to a suitable sca/e, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed wel% 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 discoverab/e 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 fo/%wing items, except for an item already on file with the commission and identified in the app/ication: (3) a diagram and description of the tr/owout prevention equipment (BOPS) a r~~wired by 20 AAC 25.035, 20 AAC 25.036,lpr~20~/1" AAC 25.037, as applicable; ~~ S~G.c~IL.c~C'v-`~~^~(c~C\v~~c3 c ~jJ~' ~~ h~~cs~,. , ~a~-' Y~~t~~-(3 An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-166. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled ~`/.-. ~~Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the ~~ annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 7-5/8" OD. •~ ~~~~ ~~ c..o~~o.~S ~ _ '-\~5U P~ ~ 4. Drilling Hazards Information 3©~~~,~~~ Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on Ble with the rnmm/scion and identified in the application: (4) information on drilling hazards, inc/uding (A) the maximum downho% pressure that maybe 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 iJ area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. 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 A2 sand formation is 1,269 psi, calculated thusly: MPSP = (3,733 ft TVD)(0.45 - 0.11 psi/ft) = 1,269 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 ho% problems such as abnormal/y geo pressured strata, iast circulation zones, and zones that have a propensity for differentia! sticking; Please see Attachment 2: 1J-166 Drilling Hazards Summary. 1J-166 PERMIT IT.doc Page 3 of 8 Printed: 28-Nov-05 ~~~ ~~~L cation for Permit to Drill, Well 1J-166 Revision No.O Saved: 28-Nov-05 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dril/ must be accompanied by each of the fo/%wing 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 AAC 25.030(t); 1J-166 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance 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 fo/%wing items, except for an item already on file with the commission and identified in the app/ication: (6) a complete proposed easing and cementing program as required by 10 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be insta/led; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top etm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ibfft Grade Connection ft ft ft Cement Pro ram 20 x 34 4z 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,360 28 / 28 2,360 /2,183 460 sx ASLite Lead, drift 170 sx DeepCREfE Tail Cement Top planned @ - 9-7/8 29.7 L-80 BTCM 6 28 / 28 6,288 / 3,646 3,355' MD / 2,816' TVD. ented 360 sx DeepCRETE 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 7,383 5,458 / 3,501 12,841 / 3,733 Slotted- no cement Slotted Lateral (1J-166) Th15 ~~k- 12.6 - IBTM 7,577 5,368 45 / 3 58 Slo ed- no cem Slotted Lateral (1J-166 Ll) 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 7,947 5,033 / 3,418 12,980 / 3,531 Slotted- no cement Slotted Lateral (1J-166 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dri/l must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1J-166. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and /dentified in the application: (8) a drilling ttuid program, including a diagram and description of the drilling fluid system, as required by 20 AAC Zs.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-166 PERMIT IT.doc Page 4 of 8 Printed: 28-Nov-05 • Surface Hole Mud Program (extended bentonite) cation for Permit to Drill, Well 1 J-166 Revision No.O Saved: 28-Nov-05 S ud to Base of Permafrost Base of Permafrost to 10-3/4"Casio Point Initial Value Final Value Initial Value Final Value Density (pp5) 8.9 9.2 9.5 9.6 Funnel Viscosity 150 250 200 300 seconds Yield Point 50 70 30 50 (cP) Plastic Viscostiy 20 45 15 20 Ib/100 s pH 8.5 9.0 8.5 9.0 API Fi-trate NC 8 0 0 5 7 0 cc / 30 min . . . *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals 10-3/4ryCs Shoe to 7-5/8"Cs Point Value Density (ppg) 9.0 - 9.1 Funnel Viscosity 45 - 60 seconds Plastic Viscostiy 12 - 18 Ib/100 s Yield Point 26 - 35 (cP) API Filtrate 4 - 6 cc / 30 min Chlorides (mg/I) <500 pH 9.0 - 9.5 MBT <20.0 Value Densit ( ) 8.6 Plastic Viscostiy 15 - 25 Ib/100 st) Yield Point 18 - 28 cP HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 70 / 30 Electrical >600 Stabili Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dril/must be accompanied by each of the fol%wing items, except for an item a/ready 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 abnormal/y geo pressured strata as required by 20 AAC 15.0330; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dril/must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the app/ication: (10) for an exp/oratory or stratigraphic test wel% 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. 1J-166 PERMIT /T.doc Page 5 of 8 Printed: 28-Nov-05 ORIGINAL ication for Permit to Drill, Well 1 J-166 Revision No.O Saved: 28-Nov-05 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(91) An application for a Permit to Dri// must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the app/ication: (11) far a well drilled from an offshore p/atform, mobi/e bottom-founded structure, jack-up rig, or floating dri//ing vess% an ana/ysis ofseabed conditions as required by 20 AAC25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the app/ication: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Install 21-1/4" Annular with 16"diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2,360' MD / 2,183' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. ,~~;~~ A~~~C i 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above ~c ~~(~3 and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8" bit andd 6-1/4"drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 6,288' MD / 3,646' TVD, the prognosis top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 3,355' MD / 2,816' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD~logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (Expected ECD's in 6-3/4" lateral modeled to be less than 12.5 ppg). . 14. Directionally drill 6-3/4" hole to TD at +/- 12,841' MD / 3,733' Ti/D as per directional plan. 1J-166 PERMIT IT.doc Page 6 of 8 Printed: 28-Nov-05 ~~~~ ~ication for Permit to Drill, Well 1 J-166 Revision No.O Saved: 28-Nov-05 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. ~ ` 1 ~~S ~~~~~~. 16. PU and run 4-1/2" slotted liner. 17. Land liner, set liner hanger @ +/- 5,458' MD / 3,501' TVD. POOH. Note: Remaining operations are covered under the iJ-166L1 Application for Permit to Drill, and are provided here for information only. ----~ ~~ _ ~c,~~ 18. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,368' MD / 3,489' TVD, the top of the B sand. 19. Mill 6-3/4" window. POOH. 20. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of B sand lateral at +/- 12,945' MD / 3,588' TVD, as per directional plan. 22. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH. 27. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the iJ-166L2 Application for Permit to Drill, and are provided here for information only. -------~ ~~_~ 28. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,033' MD / 3,416' TVD, the top of the D sand. 29. Mill 6-3/4" window. POOH. 30. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 31. Drill to TD of D sand lateral at +/- 12,980' MD / 3,531' TVD, as per directional plan. 32. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 33. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 34. PU and run 4-1/2" slotted liner. 35. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 36. Release hanger running tool. POOH. 37. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 38. POOH, laying down drill pipe as required. 39. PU completion and ESP as required and RIH to depth. Land tubing. Set BPV. 40. Nipple down BOPE, nipple up tree and test. Pull BPV. 41. Freeze protect well with diesel. 1J-166 PERMIT IT.doc Page 7 of 8 Printed: 28-Nov-05 ~~~!~~~1 42. Set BPV and move rig off. ~ication for Permit to Drill, Well 1 J-166 ~ Revision No.O Saved: 28-Nov-05 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri!l must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified in the application: (14) a genera/ description of how the operator plans to dispose of dril/ing mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annu/ar disposal operation in the wel%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J 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 iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic 1J-166 PERMIT IT.doc Page 8 of 8 Printed: 28-Nov-05 ORIGINAL ~ i ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-166 Closest Well in Pool Scan 18 November, 2005 HA,LL.~1BtJRTt3N Sperry Drilling Services ORIGINAL 1 81 1875 1 _1 ConocoPhillips ~ '~~~ Alaska _- -- ~O, / ,_ m ~ v°1 ~ / V O Cfl c_ 0 u7 N t 0 z r 0 1J-166 1/4 mile @ Heel Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-166 Wellbore: 1J-166 Plan: 1J-166 (wp07) _ _ 1J-166 1/4 Mile @ Toe CASING DETAILS No TVD MD Name Size 1 80.00 80.00 20" 20 2 2183.00 2359.67 10 3/4" 10-314 3 3645.74 6288.39 7 5l8" 7-5/8 4 3733.0012841.06 4112" 4-112 Closest Existing wells within Pool 1 J-164, 1 E-105, 1 D-127, 1 J-09 1 D-127 is closest well in the pool @ 12980' MD the 1 D-127 is approximately 647' from the 1 J-164 L2 Lateral T 1\ M Azimuths to True North Magnetic North: 24.26° Magnetic Field Strength: 57562.3nT Dip Angle: 80.76° Date: 12/1 /2005 Model: BGGM2005 -5625 -5000 -4375 -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-166 Plan: 1J-166 (wp07) Proposal Report 04 November, 2005 L~ Sperry Drilling S~rvic~es OR161NAL y ~aD N yyryry OU10~¢¢ yNO~^V a Y Y Y Y Y Y v~ ~ ••~ma ~,~~ Rp{~~v~ Rp{ ~~~y ~ J ~ - ~ ~ODN E_ M, p M~I~I y ~ i u. HYr-»>Y >~~>~ Q 1000'4 ZN hV q O _ ~°r rAi .~e~.Nr R'i .N-~~n~pp~~~enp ~ tV p ~ ~ Yf ~ 1p N 8 R O ~ n eD 8 ~ ~ ~ W ^ ~ ~ O tAp M O p 1 ~ p p N p N N ~ N N ~ N b N N ~ Q R N Z m M N O~0 ! [Y57 LL p p p p p p p p p p p p p AOOOOOOOOOOOOOIQ~, a V Ol O Ml ~eCppl 0e! a ~INp~ Oa/ ~yyH~ Ip•~p IO tV Wa ^cGq NtMO W NNe~/e~~l e'!e'1 Ml Ml Mil ebq e0'f C ~ N h O N N A tD 01 ~ ~ ~ ~ ~ Q U NtD~ ~OOf~ O ~oMinM ~~ f0 f~ N M M Z ~ N M a N M M M H r ~ M ro ~ N o M °~ >O ~ ~ 0 C 0D Y ~ O N ~ ~ ~ N ~ \ pp V a ~o ~p o ~ ~ U v in Y ~' 3 ~ (~ _ ' ~•' tD G l0 ~ ~ a ~ ~ '~ ~ ~ N ~ M O Y Ya$~ ~ m c d3!~ ~ ~ ~ •0~3 a ~ o a` ~ °' ~ O m N N O A ot} V ~ ~ C ~ O r ppM,, V O N u ~+j ~ ~ a m' ~' ~ C W z ° V ~ o co 2 p H M ~ 0 ~ ~ ~ ~ a Y J W O O ~ J ~ LL O N ~ O ro ~~ m 3 3 ' N~ J J ~ Q~ ~ ~ ~ ~ r r ~ A ' ~ l N J J r i 0 n O o 0 ~ ~ ~ ~ 3 Z ~ W ~ ~ ~ h 0 0 pp ^ I O ~ (D O ~ ~ -O 111 0 D. ( 0 ( ', r 3 ~~ ~ v J 3 ~ ' ', A ~ ~ rn OD ~ 0 ~ ~ ~ l0 N ' ~ Q `~ O a a ~ , I m ~ 1° ~ n L ~ ~ a _ A a ~ M O I C _ _ ~ A I- ~ 1D ~ ~ ~ N O f0 C7 0 ~ ~_ O ~ ~ Y d r N C ~ O O ~ r i d ~ m M ~ ~ C ~ ~ O ~ V ~ O ~ ~ ~ _ 0 C .L' p j a ~ r ~ LIJ m p M f`I Q O : b .~ ~ ~' y ~ C A y 47 N , O t 0 C ~ N ~ p) q ~ ~ M 1~ ', O ~ ~ C U C O F 'O Q . ~ ~ ~ a o ~ ', rn m c A n ~ m ~ N ` ,p V a O C w ~ h ~ O 3 O ,F a j _ ~ Y !.i\ d y V ~ a o W H c O ~ O .' m \ ni ~ . t °' e , : ~ ~ N M \ ~ F ~ ~ ~ O ~ ~ m 4 O °d' o \ ~ ~ m ` .. - ~ n , ~, °0~' ~ D M °`9 Of \ Y m S m -" ~ 0 0 °~y Y ~ ~ ~ ° c° o M c.~ ~ ' °o ,n a < Y 3 a m U ~ ~ ~ 'rn iy 0 0 0 0 0 0 0 0 o ~°n o u°~ .°n oo ion N ~ ~ ~ O 0 O A O A O O O O 0 N C_ O O o p o 0 0 ~ O ? 0 m o C o .o a o o N M O M O N °o N uo~ 00 0 N O 0 0 v~ 0 Project: Kuparuk River Unit T ~ Philli C Site: Kuparuk iJ Pad M o noco ps Well: Plan 1J-166 Z~m~tn5 co True North 10625 Alaska Wellbore: 1 J-166 agnetic North: 24.26° Plan: 1 J-166 (wp07) Magnetic Field Strength:57562.3nT 41/2 ~ ~ ~ Dip Angle: 80.76° 10000 Date: 12/1/2005 Model: BGGM2005 BHL @ 12841ft MD, 3733ft ND 552ft L & 1947ft FW --Sec 23 - T11 N - 810E ~ ' ~ ~~~ -~ W1 \~ I ~~ 9375 - __ _ _ -~ -- 1J-166 T8(wp07) - - - - - - - ~~. : ~-- ---- ~~ ---- ~~ \ _ 8750 ~ ~ p° CASING DE ~.. TAILS 1J-t66 T7 (wp07) _ No ND MD 1 80.00 80.00 Name Size 20" 20 2 2183.00 2359.67 10 3/4" 10-3/4 8125 3 3645.74 6288.39 7 5/8" 7-5/8 4 3733.0012841.06 4112" 4-112 0° 7500 1J-166 T6 lwp07) - _ ~ ~~ 0° - -- 6875 6250 0° ~ End Undulations Geosteer in Upper Lobe, 8964ft MD, 3665ft ND 1 J-166 T5 Peak 2 (wp07) 0° 5625 c '.1 J-166 T4 Trough 2 (wp07) 5000 0 N (' Begin Undulations -Begin Dir @ 1.10°/1 OOft, 6639ft MD, 3675ft ND 4375 z i 0 Z ~I Be in Dir 4°/100ft, 6488ft MD, 3667ft ND 9 @ 3750 w ~~ 1J-166 T3 Peak 11.wp07ji- - O 7 5/8 CSG -Top of Productive Interval @ 6288ft MD, 3646ft ND 3125 - ' " 3, _ - -- - - - - ~ Begin Dir ~ 4°/t00ft, 6188ft MD, 3632ft ND 1J-166 T2 Trough 1 (wp07) 1 _ _ - - - 2500 Sail @ 80°Inc & 2.51 °Azi : 5368ft MD, 3489ft ND 3° _ - Begin Dir @ 4°/100ft, 5293ft MD, 3474ft ND 1875 1 Sail @ 77.00°Inc 8 2.51 °Azi : 4968ft MD, 3401ft ND 1J-166 T1 Dtop (wp07) - - - - - 3' _ - - _ - - 1250 360° ~ , End Pump Tangent: Begin Dir ~ 6°HOOR, 41038 MD, 31198 625 / ~ ii '~~ '1~. Top of 200' Pump Tangent ; 3903tt MD, 3040h ~ s ~~ ~i~~l ~~ o //~20" Sail ~ 66.68°Inc & 318.11 °Azi : 3334ft MD, 2815ft ND ~ ~ ~ ~ - - - _ _ _ o -- ° -625 ` I ~ 10 3/4" CSG ~ 2360ft MD, 2183ft ND - SHL ~ 1880ft FSL & 2508ft FEL -Sec 35 - T11 N - 810E ' -1250 ~ ~ / ,~ _ - Sail ~ 32.54°Inc & 250°Azi : 1558ft MD, 1509ft ND Continue Build (Q 3.5/100ft , 700ft MD, 700ft ND Begin Dir ~ 5°/100ft, 2158ft MD, 2015ft ND KOP @ 600ft MD, 600ft ND - Build ~ 2.5°I100ft -4375 -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 West(-)/East(+) (1250 ft/in) 41 ~.-' Project: Kuparuk River Unit ConocoPhillips Site: Kuparuk 1J Pad Well: Plan 1J-166 Alaska Wellbore: 1J-166 Plan: 1J-166 (wp07) Vertical Scale exaggerated 5 1J-166 T1 Dtop (wp07) D-Lat Window Top ~ 77° - - - - -_ - - - B-Lat Window Top ~ 80° 7 5/8" ~-~-_~ ~ ~- 1J-166 T3 Peak 1 (wp07) 1J-166 T5 Peak 2 (wp07) 1J-166 T2 Trough 1 (wp07) 1J-166 T4 Trough 2 (wp07) LEGEND $ Plan 1J-166, 1J-166 L1, 1J-166 L1 (wp07) VO ~ Plan 1J-166, 1J-166 L2, 1J-166 L2 (wp07) VO $ 1J-166 (wp07) FORMATION TOP DETAILS No7VDPath MDPath Formation 1 1514.00 1564.10 Permafrost 2 1639.00 1712.37 T3 3 1930.00 2057.54 K15 4 2183.00 2359.67 T3+550 5 2863.00 3455.75 Ugnu C 6 3079.00 4001.42 Ugnu B 7 3160.00 4207.29 Ugnu A 8 3267.00 4500.12 K13 9 3413.00 5020.06 West Sak D 10 3455.00 5206.76 West Sak C 11 3487.00 5354.72 West Sak B 12 3526.00 5578.94 West Sak A4 13 3572.00 5843.85 West Sak A3 14 3645.74 6288.35 West Sak A2 CASING DETAILS No TVD MD Name Size 1 80.00 80.00 20" 20 2 2183.00 2359.67 10 3/4" 10-3/4 3 3645.74 6288.39 7 5/8" 7-5/8 1J-166 T7 (wp07) __ 4 1/2" 'y ~_ I 1J-166 T6 (wp07) 1J-166 T8 (wp07) [UNDULATION PEAK TO TROUGH SPACING 775'MD~ 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 Vertical Section at 0.00° (1000 fbin) r - --- - - - • ' ' Halliburton Company HALL1BURTON ~01 1QC0 ~ 11~~1pS Planning Report -Geographic --- --- - mn __ ...._~ Alaska Sperry Orllling ServlCes Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-166 Company: ConocoPhiltips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1 J Pad North Reference: True ' Well: Plan 1J-166 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-166 Design: 1J-166 (wp07) Project Kuparuk Rwer Unit, North Slope Alaska, United States Map System: US State Plane 1927 (F~cact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor -- ---- -- Well Plan 1J-166 Well Position +N/-S 0.00 ft Northing: 5,945,691.74 ft ~ Latitude: 70° 15' 44.023" N +E/-W 0.00 ft Easting: 558,702.73 ft Longitude: 149° 31' 31.597" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.00 ft - --- '~ Wellbore 1J-166 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 12/1/2005 24.26 80.77 57,562 Design 1J-166 (wp07) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 `' Vertical Section: Depth From (TVD) +NlS +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 0.00 11/4/2005 12:24:25PM COMPASS 2003.118ui1d 48 ~ • CI~CK4~'11~~1~5 Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-166 Wellbore: 1 J-166 Design: 1J-166 (wp07) • Halliburton Company HAI-LIBURTON Planning Report -Geographic --- - ..,.,_. Sporty Drily Sorvlcos Local Co-ordinate Reference: Well Plan 1J-166 ND Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NI-S +E!-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°I100ft) (°/100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 700.03 2.50 250.00 700.00 -0.75 -2.05 2.50 2.50 0.00 250.00 1,558.17 32.54 250.00 1,509.00 -88.08 -242.01 3.50 3.50 0.00 0.00 2,158.17 32.54 250.00 2,014.83 -198.45 -545.24 0.00 0.00 0.00 0.00 3,334.38 66.68 318.11 2,814.96 124.25 -1,267.65 5.00 2.90 5.79 84.92 4,103.31 66.68 318.11 3,119.34 649.89 -1,739.14 0.00 0.00 0.00 0.00 4,968.39 77.00 2.51 3,401.38 1,402.73 -1,998.33 5.00 1.19 5.13 84.22 5,033.39 77.00 2.51 3,416.00 1,466.00 -1,995.55 0.00 0.00 0.00 0.00 5,293.39 77.00 2.51 3,474.49 1,719.09 -1,984.46 0.00 0.00 0.00 0.00 5,368.39 80.00 2.51 3,489.44 1,792.51 -1,981.24 4.00 4.00 0.00 359.99 6,188.39 80.00 2.51 3,631.83 2,599.28 -1,945.87 0.00 0.00 0.00 0.00 6,288.39 84.00 2.51 3,645.74 2,698.19 -1,941.54 4.00 4.00 0.00 0.00 6,488.39 84.00 2.51 3,666.65 2,896.90 -1,932.83 0.00 0.00 0.00 0.00 6,638.89 90.02 2.51 3,674.50 3,046.98 -1,926.25 4.00 4.00 0.00 0.00 6,948.89 93.43 2.51 3,665.17 3,356.50 -1,912.68 1.10 1.10 0.00 0.00 7,103.89 93.43 2.51 3,655.89 3,511.08 -1,905.90 0.00 0.00 0.00 0.00 7,413.89 90.34 2.24 3,645.69 3,820.60 -1,893.07 1.00 -1.00 -0.09 -175.00 7,723.89 86.37 1.54 3,654.58 4,130.24 -1,882.85 1.30 -1.28 -0.23 190.00 7,878.89 86.37 1.54 3,664.38 4,284.88 -1,878.69 0.00 0.00 0.00 0.00 8,188.89 87.87 1.14 3,679.95 4,594.39 -1,871.46 0.50 0.48 -0.13 -15.00 8,498.89 91.76 0.10 3,680.94 4,904.31 -1,868.13 1.30 1.26 -0.34 345.00 8,653.89 93.31 0.10 3,674.08 5,059.15 -1,867.87 1.00 1.00 0.00 0.00 8,963.89 90.21 0.10 3,664.54 5,368.97 -1,867.36 1.00 -1.00 0.00 -180.00 9,273.89 87.43 0.34 3,670.90 5,678.87 -1,866.18 0.90 -0.90 0.08 175.00 9,523.89 87.43 0.34 3,682.10 5,928.61 -1,864.71 0.00 0.00 0.00 0.00 9,543.06 88.00 0.44 3,682.86 5,947.76 -1,864.58 3.00 2.95 0.52 10.00 9,793.06 88.00 0.44 3,691.58 6,197.60 -1,862.67 0.00 0.00 0.00 0.00 9,993.51 98.01 1.03 3,681.10 6,397.51 -1,860.12 5.00 4.99 0.29 3.34 10,182.69 98.01 1.03 3,654.75 6,584.81 -1,856.77 0.00 0.00 0.00 0.00 10,398.91 87.21 0.45 3,644.93 6,800.47 -1,853.99 5.00 -4.99 -0.27 -176.93 11,098.91 87.21 0.45 3,679.00 7,499.62 -1,848.50 0.00 0.00 0.00 0.00 11,208.77 90.51 0.45 3,681.19 7,609.44 -1,847.64 3.00 3.00 0.00 -0.07 11,894.23 90.51 0.45 3,675.14 8,294.85 -1,842.30 0.00 0.00 0.00 0.00 11,997.09 87.42 0.45 3,677.00 8,397.68 -1,841.50 3.00 -3.00 0.00 179.93 12,044.61 85.99 0.45 3,679.73 8,445.12 -1,841.13 3.00 -3.00 -0.01 -179.85 12,745.87 85.99 0.45 3,728.72 9,144.65 -1,835.68 0.00 0.00 0.00 0.00 12,841.07 88.85 0.45 3,733.00 9,239.73 -1,834.94 3.00 3.00 0.00 0.07 11/42005 12:24:26PM Page 3 of 10 COMPASS 2003.11 Build 48 '!R!6!NAL w r'` , Halliburton Company ~OnOCd ~~~~1p5 Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) ND Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-166 Survey Calculation Method: Wellbore: 1 J-166 Design: 1J-166 (wp07) • NALLfBfJpT©N Sperry Drilling Services Well Plan 1J-166 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Planned Survey 1 J-166 (wp07) Map Map MD Inclination Azimuth ND SSND +N!-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 SHL ~ 7880ft FSL & 2508ft FEL - Sec 35 - T11 N - R10E ' 80.00 0.00 0.00 80.00 -29.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 20" 100.00 0.00 0.00 100.00 -9.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 400.00 0.00 0.00 400.00 291.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 500.00 0.00 0.00 500.00 391.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 600.00 0.00 0.00 600.00 491.00 0.00 0.00 5,945,691.74 558,702.73 0.00 0.00 KOP ~ 500ft MD, 800ft ND - Build ~ 2.5°I100ft ' 700.03 2.50 250.00 700.00 591.00 -0.75 -2.05 5,945,690.98 558,700.69 2.50 -0.75 Continue Build @ 3.5/100ft , 700ft MD, 700ft ND 800.00 6.00 250.00 799.68 690.68 -3.28 -9.01 5,945,688.39 558,693.74 3.50 -3.28 900.00 9.50 250.00 898.75 789.75 -7.89 -21.68 5,945,683.68 558,681.11 3.50 -7.89 1,000.00 13.00 250.00 996.81 887.81 -14.56 -40.01 5,945,676.87 558,662.84 3.50 -14.56 1,100.00 16.50 250.00 1,093.50 984.50 -23.27 -63.93 5,945,667.98 558,638.99 3.50 -23.27 1,200.00 20.00 250.00 1,188.46 1,079.46 -33.98 -93.35 5,945,657.04 558,609.65 3.50 -33.98 1,300.00 23.50 250.00 1,281.32 1,172.32 -46.65 -128.17 5,945,644.10 558,574.94 3.50 -46.65 1,400.00 27.00 250.00 1,371.76 1,262.76 -61.24 -168.25 5,945,629.20 558,534.98 3.50 -61.24 1,500.00 30.50 250.00 1,459.42 1,350.42 -77.68 -213.44 5,945,612.40 558,489.93 3.50 -77.68 1,558.17 32.54 250.00 1,509.00 1,400.00 -88.08 -242.01 5,945,601.78 558,461.44 3.50 -88.08 Sail ~ 32.54°I nc & 250°Azi : 1558ft MD, 1509ft ND 1,564.10 32.54 250.00 1,514.00 1,405.00 -89.18 -245.01 5,945,600.67 558,458.45 0.00 -89.18 Permafrost 1,600.00 32.54 250.00 1,544.27 1,435.27 -95.78 -263.15 5,945,593.92 558,440.36 0.00 -95.78 1,700.00 32.54 250.00 1,628.57 1,519.57 -114.17 -313.69 5,945,575.14 558,389.97 0.00 -114.17 1,712.37 32.54 250.00 1,639.00 1,530.00 -116.45 -319.94 5,945,572.81 558,383.74 0.00 -116.45 T3 1,800.00 32.54 250.00 1,712.88 1,603.88 -132.57 -364.23 5,945,556.35 558,339.58 0.00 -132.57 1,900.00 32.54 250.00 1,797.18 1,688.18 -150.96 -414.77 5,945,537.56 558,289.19 0.00 -150.96 2,000.00 32.54 250.00 1,881.49 1,772.49 -169.36 -465.31 5,945,518.78 558,238.80 0.00 -169.36 2,057.54 32.54 250.00 1,930.00 1,821.00 -179.94 -494.39 5,945,507.97 558,209.81 0.00 -179.94 K15 2,100.00 32.54 250.00 1,965.80 1,856.80 -187.75 -515.85 5,945,499.99 558,188.41 0.00 -187.75 2,158.17 32.54 250.00 2,014.83 1,905.83 -198.45 -545.24 5,945,489.06 558,159.10 0.00 -198.45 Begin Dlr ~ 5°/100ft, 2158ft MD, 2015ft ND 2,200.00 32.78 253.85 2,050.06 1,941.06 -205.45 -566.69 5,945,481.90 558,137.71 5.00 -205.45 2,300.00 33.83 262.76 2,133.68 2,024.68 -216.49 -620.34 5,945,470.44 558,084.15 5.00 -216.49 2,359.67 34.74 267.80 2,183.00 2,074.00 -219.24 -653.82 5,945,467.43 558,050.71 5.00 -219.24 10 3/4" CSG ~ 2360ft MD, 2183ft ND -1851ft FSL 8 2118ft FWL -Sec 35 - T11 N - R10E - T3+550 -10 3/4" 2,400.00 35.47 271.07 2,215.99 2,106.99 -219.46 -677.00 5,945,467.03 558,027.52 5.00 -219.46 2,500.00 37.64 278.64 2,296.35 2,187.35 -214.33 -736.24 5,945,471.70 557,968.25 5.00 -214.33 2,600.00 40.25 285.44 2,374.16 2,265.16 -201.13 -797.61 5,945,484.42 557,906.79 5.00 -201.13 2,700.00 43.21 291.49 2,448.81 2,339.81 -179.97 -860.64 5,945,505.08 557,843.60 5.00 -179.97 11!4!2005 12:24:26PM Page 4 of 10 COMPASS 2003.11 Build 48 OR161N4L • / ~ Halliburton Company MALLIBUAT©N CanocaPh~ll~p5 Planning Report -Geographic - _ __ ._ _____n Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-166 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-166 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-166 Design: 1J-166 (wp07) Planned Survey 1J-166 (wp07) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section it (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°NOOft) (ft) ~ 2,800.00 46.45 296.89 2,519.74 2,410.74 -151.02 -924.86 5,945,533.53 557,779.17 5.00 -151.02 2,900.00 49.93 301.72 2,586.42 2,477.42 -114.48 -989.76 5,945,569.55 557,713.98 5.00 -114.48 3,000.00 53.58 306.07 2,648.33 2,539.33 -70.65 -1,054.87 5,945,612.88 557,648.54 5.00 -70.65 3,100.00 57.38 310.02 2,705.01 2,596.01 -19.85 -1,119.68 5,945,663.17 557,583.34 5.00 -19.85 3,200.00 61.29 313.64 2,756.01 2,647.01 37.54 -1,183.71 5,945,720.05 557,518.88 5.00 37.54 3,300.00 65.29 317.00 2,800.97 2,691.97 101.07 -1,246.46 5,945,783.08 557,455.64 5.00 101.07 3,334.38 66.68 318.11 2,814.96 2,705.96 124.25 -1,267.65 5,945,806.09 557,434.27 5.00 124.25 Sail ~ 88.68°Inc & 318.11°Azi : 3334ft MD, 281 5ft TVD 3,400.00 66.68 318.11 2,840.93 2,731.93 169.10 -1,307.88 5,945,850.62 557,393.69 0.00 169.10 3,455.75 66.68 318.11 2,863.00 2,754.00 207.21 -1,342.07 5,945,888.46 557,359.22 0.00 207.21 Ugnu C 3,500.00 66.68 318.11 2,880.52 2,771.52 237.46 -1,369.20 5,945,918.50 557,331.85 0.00 237.46 3,600.00 66.68 318.11 2,920.10 2,811.10 305.82 -1,430.52 5,945,986.37 557,270.01 0.00 305.82 3,700.00 66.68 318.11 2,959.69 2,850.69 374.18 -1,491.84 5,946,054.25 557,208.17 0.00 374.18 3,800.00 66.68 318.11 2,999.27 2,890.27 442.55 -1,553.15 5,946,122.12 557,146.32 0.00 442.55 3,900.00 66.68 318.11 3,038.85 2,929.85 510.91 -1,614.47 5,946,190.00 557,084.48 0.00 510.91 3,903.00 66.68 318.11 3,040.04 2,931.04 512.96 -1,616.31 5,946,192.03 557,082.63 0.00 512.96 Top of 200' Pump Tangent ; 3903ft MD, 3040ft TVD 4,000.00 66.68 318.11 3,078.44 2,969.44 579.27 -1,675.79 5,946,257.87 557,022.64 0.00 579.27 4,001.42 66.68 318.11 3,079.00 2,970.00 580.24 -1,676.66 5,946,258.83 557,021.76 0.00 580.24 Ugnu B 4,100.00 66.68 318.11 3,118.02 3,009.02 647.63 -1,737.11 5,946,325.74 556,960.79 0.00 647.63 4,103.31 66.68 318.11 3,119.34 3,010.34 649.89 -1,739.14 5,946,327.99 556,958.75 0.00 649.89 End Pump Tangent: Begin Dir ~ 5°H OOft, 410 3ft MD, 3119ft TVD 4,200.00 67.25 323.32 3,157.19 3,048.19 718.74 -1,795.44 5,946,396.39 556,901.91 5.00 718.74 4,207.29 67.30 323.72 3,160.00 3,051.00 724.14 -1,799.44 5,946,401.76 556,897.87 5.01 724.14 Ugnu A 4,300.00 68.02 328.67 3,195.25 3,086.25 795.38 -1,847.13 5,946,472.62 556,849.64 5.00 795.38 4,400.00 68.96 333.95 3,231.94 3,122.94 876.96 -1,891.76 5,946,553.84 556,804.37 5.00 876.96 4,500.00 70.06 339.15 3,266.96 3,157.96 962.86 -1,929.01 5,946,639.44 556,766.46 5.00 962.86 4,500.12 70.06 339.15 3,267.00 3,158.00 962.97 -1,929.05 5,946,639.55 556,766.42 0.00 962.97 K13 4,600.00 71.31 344.28 3,300.05 3,191.05 1,052.44 -1,958.58 5,946,728.78 556,736.19 5.01 1,052.44 4,700.00 72.70 349.33 3,330.96 3,221.96 1,145.01 -1,980.26 5,946,821.16 556,713.79 5.00 1,145.01 4,800.00 74.21 354.31 3,359.45 3,250.45 1,239.86 -1,993.88 5,946,915.90 556,699.44 5.00 1,239.86 4,900.00 75.83 359.20 3,385.31 3,276.31 1,336.27 -1,999.33 5,947,012.25 556,693.24 5.00 1,336.27 4,968.39 77.00 2.51 3,401.38 3,292.38 1,402.73 -1,998.33 5,947,078.71 556,693.72 5.00 1,402.73 Sail ~ 77.00°Inc & 2.51° Azi : 4968ft MD, 3401ft TVD 5,000.00 77.00 2.51 3,408.49 3,299.49 1,433.50 -1,996.98 5,947,109.49 556,694.83 0.00 1,433.50 5,020.06 77.00 2.51 3,413.00 3,304.00 1,453.02 -1,996.12 5,947,129.02 556,695.53 0.00 1,453.02 West Sak D 5,033.39 77.00 2.51 3,416.00 3,307.00 1,466.00 -1,995.55 5,947,142.00 556,696.00 0.00 1,466.00 1J-166 T7 Dtop (wp07) 5,100.00 77.00 2.51 3,430.98 3,321.98 1,530.84 -1,992.71 5,947,206.85 556,698.34 0.00 1,530.84 5,200.00 77.00 2.51 3,453.48 3,344.48 1,628.18 -1,988.44 5,947,304.22 556,701.85 0.00 1,628.18 11/4/2005 12:24:26PM Page 5 of 10 COMPASS 2003.11 Build 48 ORIGINAL Cone Database: Company: Project: Site: Wetl: Welibore: Design: co~illips Adasl<a EDM 2003.11 Single User Db ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-166 1 J-166 1J-166 (wp07) Planned Survey 1J-166 (wp07) • Halliburton Company Planning Report -Geographic Mp-r..r.rsuQrow __ ~ _v _....~ __ _._._.__.._ Sperry i~rilling Services Local Co-ordinate Reference: Well Plan 1J-166 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Map Map MD In clination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) lft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 5,206.76 77.00 2.51 3,455.00 3,346.00 1,634.77 -1,988.16 5,947,310.80 556,702.08 0.00 1,634.77 West Sak C 5,293.39 77.00 2.51 3,474.49 3,365.49 1,719.09 -1,984.46 5,947,395.15 556,705.12 0.00 1,719.09 Begin Dlr ~ 4°/100ft, 5293ft MD, 3474ft TVD 5,300.00 77.26 2.51 3,475.96 3,366.96 1,725.53 -1,984.18 5,947,401.58 556,705.35 3.99 1,725.53 5,354.72 79.45 2.51 3,487.00 3,378.00 1,779.07 -1,981.83 5,947,455.14 556,707.28 4.00 1,779.07 West Sak B 5,368.39 80.00 2.51 3,489.44 3,380.44 1,792.51 -1,981.24 5,947,468.58 556,707.77 4.00 1,792.51 Sail ~ 80°Inc 8 2.51°Azi : 5368ft MD, 3489ft TVD 5,400.00 80.00 2.51 3,494.93 3,385.93 1,823.61 -1,979.88 5,947,499.68 556,708.89 0.00 1,823.61 5,500.00 80.00 2.51 3,512.29 3,403.29 1,921.99 -1,975.56 5,947,598.09 556,712.43 0.00 1,921.99 .5,578.94 80.00 2.51 3,526.00 3,417.00 1,999.66 -1,972.16 5,947,675.78 556,715.23 0.00 1,999.66 West Sak A4 5,600.00 80.00 2.51 3,529.66 3,420.66 2,020.38 -1,971.25 5,947,696.50 556,715.98 0.00 2,020.38 5,700.00 80.00 2.51 3,547.02 3,438.02 2,118.77 -1,966.94 5,947,794.91 556,719.52 0.00 2,118.77 5,800.00 80.00 2.51 3,564.39 3,455.39 2,217.15 -1,962.62 5,947,893.31 556,723.07 0.00 2,217.15 5,843.85 80.00 2.51 3,572.00 3,463.00 2,260.29 -1,960.73 5,947,936.46 556,724.62 0.00 2,260.29 West Sak A3 5,900.00 80.00 2.51 3,581.75 3,472.75 2,315.54 -1,958.31 5,947,991.72 556,726.62 0.00 2,315.54 6,000.00 80.00 2.51 3,599.12 3,490.12 2,413.92 -1,954.00 5,948,090.13 556,730.16 0.00 2,413.92 6,100.00 80.00 2.51 3,616.48 3,507.48 2,512.31 -1,949.69 5,948,188.54 556,733.71 0.00 2,512.31 6,188.39 80.00 2.51 3,631.83 3,522.83 2,599.28 -1,945.87 5,948,275.52 556,736.84 0.00 2,599.28 Begin Dir ~ 4°/100ft, 8188ft MD, 3832ft TVD 6,200.00 80.46 2.51 3,633.80 3,524.80 2,610.71 -1,945.37 5,948,286.95 556,737.25 3.99 2,610:71 6,288.39 84.00 2.51 3,645.74 3,536.74 2,698.19 -1,941.54 5,948,374.45 556,740.40 4.00 2,698.19 75/8 CSG -Top of Productive Interval ~ 8288ft MD, 3648ft TVD - 702ft FNL ~ FWL - Sec35 - T11 N - R10E -West Sak A2 - 7 5/8.. 6,300.00 84.00 2.51 3,646.96 3,537.96 2,709.72 -1,941.03 5,948,385.99 556,740.82 0.00 2,709.72 6,400.00 84.00 2.51 3,657.41 3,548.41 2,809.08 -1,936.68 5,948,485.37 556,744.40 0.00 2,809.08 6,488.39 84.00 2.51 3,666.65 3,557.65 2,896.90 -1,932.83 5,948,573.21 556,747.57 0.00 2,896.90 Begin Dir ~ 4°/100ft, 6488ft MD, 3687ft TVD 6,500.00 84.46 2.51 3,667.82 3,558.82 2,908.44 -1,932.32 5,948,584.75 556,747.98 3.99 2,908.44 6,600.00 88.46 2.51 3,673.98 3,564.98 3,008.13 -1,927.95 5,948,684.46 556,751.57 4.00 3,008.13 6,638.89 90.02 2.51 3,674.50 3,565.50 3,046.98 -1,926.25 5,948,723.32 556,752.97 4.00 3,046.98 Begin Undulations -Begin Dir ~ 1.10°/100ft, 6839ft MD, 38 75ft TVD -1J-166 T2 Trough 1 (wp07) 6,700.00 90.69 2.51 3,674.12 3,565.12 3,108.03 -1,923.57 5,948,784.38 556,755.17 1.10 3,108.03 6,800.00 91.79 2.51 3,671.95 3,562.95 3,207.91 -1,919.19 5,948,884.28 556,758.77 1.10 3,207.91 6,900.00. 92.89 2.51 3,667.86 3,558.86 3,307.73 -1,914.82 5,948,984.13 556,762.37 1.10 3,307.73 6,948.89 93.43 2.51 3,665.17 3,556.17 3,356.50 -1,912.68 5,949,032.91 556,764.13 1.10 3,356.50 7,000.00 93.43 2.51 3,662.11 3,553.11 3,407.47 -1,910.45 5,949,083.88 556,765.96 0.00 3,407.47 7,100.00 93.43 2.51 3,656.13 3,547.13 3,507.19 -1,906.07 5,949,183.63 556,769.56 0.00 3,507.19 7,103.89 93.43 2.51 3,655.89 3,546.89 3,511.08 -1,905.90 5,949,187.51 556,769.70 0.00 3,511.08 7,200.00 92.47 2.43 3,650.94 3,541.94 3,606.96 -1,901.77 5,949,283.42 556,773.08 1.00 3,606.96 7,300.00 91.48 2.34 3,647.50 3,538.50 3,706.82 -1,897.62 5,949,383.30 556,776.46 1.00 3,706.82 7,400.00 90.48 2.25 3,645.79 3,536.79 3,806.72 -1,893.61 5,949,483.22 556,779.68 1.00 3,806.72 11/42005 12:24:26PM Page 6 of 10 COMPASS 2003.11 Build 48 ORIGIN~It. • • ~-' ' Halliburton Company HA~.~.rBUATOn~ Connca P h~ll p s Planning Report -Geographic i Dri~~iing ~~~~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-166 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1 J Pad North Reference: True Well; Plan 1J-166 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-166 Design: 1J-166 (wp07) ', Planned Survey 1 J-166 (wp07) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100ft) (ft) 7,413.89 90.34 2.24 3,645.69 3,536.69 3,820.60 -1,893.07 5,949,497.10 556,780.12 1.00 3,820.60 1J-168 T3 Peak 1 (wp07) 7,500.00 89.24 2.05 3,646.01 3,537.01 3,906.65 -1,889.85 5,949,583.16 556,782.67 1.30 3,906.65 7,600.00 87.96 1.82 3,648.45 3,539.45 4,006.56 -1,886.48 5,949,683.09 556,785.26 1.30 4,006.56 7,700.00 86.68 1.59 3,653.13 3,544.13 4,106.40 -1,883.50 5,949,782.94 556,787.46 1.30 4,106.40 7,723.89 86.37 1.54 3,654.58 3,545.58 4,130.24 -1,882.85 5,949,806.78 556,787.92 1.30 4,130.24 7,800.00 86.37 1.54 3,659.39 3,550.39 4,206.17 -1,880.81 5,949,882.72 556,789.37 0.00 4,206.17 7,878.89 86.37 1.54 3,664.38 3,555.38 4,284.88 -1,878.69 5,949,961.43 556,790.87 0.00 4,284.88 7,900.00 86.47 1.51 3,665.70 3,556.70 4,305.94 -1,878.13 5,949,982.49 556,791.27 0.50. 4,305.94 8,000.00 86.96 1.38 3,671.43 3,562.43 4,405.74 -1,875.61 5,950,082.30 556,793.01 0.50 4,405.74 8,100.00 87.44 1.25 3,676.31 3,567.31 4,505.59 -1,873.32 5,950,182.16 556,794.53 0.50 4,505.59 8,188.89 87.87 1.14 3,679.95 3,570.95 4,594.39 -1,871.46 5,950,270.96 556,795.69 0.50 4,594.39 1J-188 T4 Trough 2 (wp07) 8,200.00 88.01 1.10 3,680.35 3,571.35 4,605.49 -1,871.25 5,950,282.06 556,795.82 1.30 4,605.49 8,300.00 89.27 0.76 3,682.72 3,573.72 4,705.45 -1,869.62 5,950,382.02 556,796.67 1.30 4,705.45 8,400.00 90.52 0.43 3,682.91 3,573.91 4,805.44 -1,868.58 5,950,482.01 556,796.93 1.30 4,805.44 8,498.89 91.76 0.10 3,680.94 3,571.94 4,904.31 -1,868.13 5,950,580.87 556,796.61 1.30 4,904.31 8,500.00 91.77 0.10 3,680.91 3,571.91 4,905.42 -1,868.13 5,950,581.97 556,796.60 0.97 4,905.42 8,600.00 92.77 0.10 3,676.94 3,567.94 5,005.34 -1,867.96 5,950,681.88 556,795.99 1.00 5,005.34 8,653.89 93.31 0.10 3,674.08 3,565.08 5,059.15 -1,867.87 5,950,735.69 556,795.66 1.00 5,059.15 8,700.00 92.85 0.10 3,671.60 3,562.60 5,105.19 -1,867.79 5,950,781.73 556,795.38 1.00 5,105.19 8,800.00 91.85 0.10 3,667.49 3,558.49 5,205.11 -1,867.63 5,950,881.63 556,794.76 1.00 5,205.11 8,900.00 90.85 0.10 3,665.13 3,556.13 5,305.08 -1,867.46 5,950,981.59 556,794.15 1.00 5,305.08 8,963.89 90.21 0.10 3,664.54 3,555.54 5,368.97 -1,867.36 5,951,045.47 556,793.76 1.00 5,368.97 End Undulations Geosteer in Upper Lobe, 8964ft MD, 3885ft TVD -1J-186 T5 Peak 2 (wp07) 9,000.00 89.89 0.12 3,664.51 3,555.51 5,405.07 -1,867.29 5,951,081.57 556,793.54 0.90 5,405.07 9,100.00 88.99 0.20 3,665.48 3,556.48 5,505.07 -1,867.00 5,951,181.56 556,793.05 0.90 5,505.07 9,200.00 88.10 0.28 3,668.02 3,559.02 5,605.03 -1,866.58 5,951,281.51 556,792.69 0.90 5,605.03 9,273.89 87.43 0.34 3,670.90 3,561.90 5,678.87 -1,866.18 5,951,355.34 556,792.51 0.90 5,678.87 9,300.00 87.43 0.34 3,672.07 3,563.07 5,704.95 -1,866.03 5,951,381.42 556,792.46 0.00 5,704.95 9,400.00 87.43 0.34 3,676.55 3,567.55 5,804.85 -1,865.44 5,951,481.31 556,792.28 0.00 5,804.85 9,500.00 87.43 0.34 3,681.03 3,572.03 5,904.75 -1,864.85 5,951,581.20 556,792.09 0.00 5,904.75 9,523.89 87.43 0.34 3,682.10 3,573.10 5,928.61 -1,864.71 5,951,605.07 556,792.04 0.00 5,928.61 9,543.06 88.00 0.44 3,682.86 3,573.86 5,947.76 -1,864.58 5,951,624.22 556,792.02 3.00 5,947.76 9,600.00 88.00 0.44 3,684.85 3,575.85 6,004.67 -1,864.14 5,951,681.12 556,792.01 0.00 6,004.67 9,700.00 88.00 0.44 3,688.34 3,579.34 6,104.60 -1,863.38 5,951,781.05 556,792.00 0.00 6,104.60 9,793.06 88.00 0.44 3,691.58 3,582.58 6,197.60 -1,862.67 5,951,874.04 556,791.99 0.00 6,197.60 9,800.00 88.34 0.46 3,691.81 3,582.81 6,204.54 -1,862.61 5,951,880.98 556,791.99 4.97 6,204.54 9,900.00 93.34 0.75 .3,690.34 3,581.34 6,304.49 -1,861.56 5,951,980.92 556,792.26 5.00 6,304.49 9,993.51 98.01 1.03 3,681.10 3,572.10 6,397.51 -1,860.12 5,952,073.94 556,792.98 5.00 6,397.51 10,000.00 98.01 1.03. 3,680.19 3,571.19 6,403.93 -1,860.00 5,952,080.37 556,793.04 0.00 6,403.93 10,100.00 98.01 1.03 3,666.27 3,557.27 6,502.94 -1,858.23 5,952,179.38 556,794.04 0.00 6,502.94 10,182.69 98.01 1.03 3,654.75 3,545.75 6,584.81 -1,856.77 5,952,261.25 556,794.87 0.00 6,584.81 10,200.00 97.14 0.98 3,652.47 3,543.47 6,601.97 -1,856.47 5,952,278.40 556,795.04 4.99 6,601.97 10,300.00 92.15 0.71 3,644.37 3,535.37 6,701.60 -1,855.00 5,952,378.03 556,795.73 5.00 6,701.60 10,398.91 87.21 0.45 3,644.93 3,535.93 6,800.47 -1,853.99 5,952,476.90 556,795.96 5.00 6,800.47 10,400.00 87.21 0.45 3,644.98 3,535.98 6,801.56 -1,853.98 5,952,477.99 556,795.96 0.00 6,801.56 10,500.00 87.21 0.45 3,649.85 3,540.85 6,901.44 -1,853.20 5,952,577.86 556,795.97 0.00 6,901.44 10,600.00 87.21 0.45 3,654.72 3,545.72 7,001.32 -1,852.42 5,952,677.73 556,795.97 0.00 7,001.32 11/4/2005 12:24:25PM Page 7 of 10 COMPASS 2003.11 Build 48 ORIGINAL 4 ~ ~/ ' Halliburton Com an P Y NALLIBURTON COt1fK~J 11~~1 $ ~ Planning Report -Geographic _. _-..-._ ,_ _...__~._....__ A~ska Sperry Drilling Serrlcss Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-166 Company: ConocoPhillips Alaska (Kuparuk) ND Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1 J Pad North Reference: True Well: Plan 1J-166 Survey Calculation Method: Minimum Curvature Welibore: 1 J-166 Design: 1J-166 (wp07) Planned Survey 1J-166 (wp07) Map Map MD Inclination Azimuth ND SSND +NI-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ftl 10,700.00 87.21 0.45 3,659.58 3,550.58 7,101.20 -1,851.63 5,952,777.60 556,795.98 0.00 7,101.20 10,800.00 87.21 0.45 3,664.45 3,555.45 7,201.08 -1,850.85 5,952,877.48 556,795.98 0.00 7,201.08 10,900.00 87.21 0.45 3,669.32 3,560.32 7,300.95 -1,850.06 5,952,977.35 556,795.99 0.00 7,300.95 11,000.00 87.21 0.45 3,674.19 3,565.19 7,400.83 -1,849.28 5,953,077.22 556,795.99 0.00 7,400.83 11,098.91 87.21 0.45 3,679.00 3,570.00 7,499.62 -1,848.50 5,953,176.00 556,796.00 0.00 7,499.62 1J-168 T8 (wp07) 11,100.00 87.24 0.45 3,679.05 3,570.05 7,500.71 -1,848.49 5,953,177.09 556,796.00 2.88 7,500.71 11,200.00 90.24 0.45 3,681.25 3,572.25 7,600.67 -1,847.71 5,953,277.05 556,796.00 3.00 7,600.67 11,208.77 90.51 0.45 3,681.19 3,572.19 7,609.44 -1,847.64 5,953,285.81 556,796.00 3.00 7,609.44 11,300.00 90.51 0.45 3,680.38 3,571.38 7,700.67 -1,846.93 5,953,377.03 556,796.00 0.00 7,700.67 11,400.00 90.51 0.45 3,679.50 3,570.50 7,800.66 -1,846.15 5,953,477.02 556,796.00 0.00 7,800.66 11,500.00 90.51 0.45 3,678.62 3,569.62 7,900.65 -1,845.38 5,953,577.01 556,796.00 0.00 7,900.65 11,600.00 90.51 0.45 3,677.74 3,568.74 8,000.64 -1,844.60 5,953,676.99. 556,796.00 0.00 8,000.64 11,700.00 90.51 0.45 3,676.85 3,567.85 8,100.64 -1,843.82 5,953,776.98 556,796.00 0.00 8,100.64 11,800.00 90.51 0.45 3,675.97 3,566.97 8,200.63 -1,843.04 5,953,876.97 556,796.00 0.00 8,200.63 11,894.23 90.51 0.45 3,675.14 3,566.14 8,294.85 -1,842.30 5,953,971.18 556,796.00 0.00 8,294.85 11,900.00 90.33 0.45 3,675.10 3,566.10 8,300.62 -1,842.26 5,953,976.95 556,796.00. 2.98 8,300.62 11,997.09 87.42 0.45 3,677.00 3,568.00 8,397.68 -1,841.50 5,954,074.00 556,796.00 3.00 8,397.68 1J-168 T7 (wp07) 12,000.00 87.33 0.45 3,677.13 3,568.13 8,400.59 -1,841.48 5,954,076.91 556,796.00 2.95 8,400.59 12,044.61 85.99 0.45 3,679.73 3,570.73 8,445.12 -1,841.13 5,954,121.44 556,796.00 3.00 8,445.12 12,100.00 85.99 0.45 3,683.60 3,574.60 8,500.37 -1,840.70 5,954,176.69 556,796.00 0.00 8,500.37 12,200.00 85.99 0.45 3,690.59 3,581.59 8,600.13 -1,839.92 5,954,276.44 556,796.00 0.00 8,600.13 12,300.00 85.99 0.45 3,697.57 3,588.57 8,699.88 -1,839.14 5,954,376.18 556,796.00 0.00 8,699.88 12,400.00 85.99 0.45 3,704.56 3,595.56 8,799.63 -1,838.37 5,954,475.93 556,796.00 0.00 8,799.63 12,500.00 85.99 0.45 3,711.54 3,602.54 8,899.38 -1,837.59 5,954,575.67 .556,796.00 0.00 8,899.38 12,600.00 85.99 0.45 3,718.53 3,609.53 8,999.14 -1,836.81 5,954,675.42 556,796.00 0.00 8,999.14 12,700.00 85.99 0.45 3,725.51 3,616.51 9,098.89 -1,836.04 5,954,775.17 556,796.00 0.00 9,098.89 12,745.87 85.99 0.45 3,728.72 3,619.72 9,144.65 -1,835.68 5,954,820.92 556,796.00 0.00 9,144.65 12,800.00 87.62 0.45 3,731.73 3,622.73 9,198.69 -1,835.26 5,954,874.96 556,796.00 3.00 9,198.69 12,841.07 88.85 0.45 3,733.00 3,62 .00 9,239.73 -1,834.94 5,954,916.00 556,796.00 3.00 9,239.73 BHL ~ 12841ft MD, 3733ft ND : 552ft FSL & 1 FWL --Sec 23 - T11 N - R10E - 4 1/2" -1J-186 T8 (wp07) ~ t /~~~ nNO~{, p%y~ is - ~r~ ~ / 11/4!1005 12:24:26PM Page 8 of 10 COMPASS 2003.11 Build 48 ORIGINAL ConocoPhiliips Aiaslta Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1 J Pad Well; Plan 1J-166 Wellbore: 1 J-166 Design: 1J-166 (wp07) Geologic Targets 1J-166 • Halliburton Company MAI_LIBUt~TC1N Planning Report -Geographic - ~ ~_.__ ~~ ~~ Sperry Orilling Services Local Co-ordinate Reference: Well Plan 1J-166 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature TVD Target Name +N/-S +E/-W Northing Easting !, (ft) -Shape ft ft (ft) (ft) 3,679.95 1J-166 T4 Trough 2 (wp07) 4,594.39 -1,871.46 5,950,270.96 556,795.69 - P in of 3,679.00 1J-166 T6 (wp07) 7,499.62 -1,848.50 5,953,176.00 556,796.00 - Point 3,674.50 1J-166 T2 Trough 1 (wp07) 3,046.98 -1,926.25 5,948,723.32 556,752.97 - Point 3,677.00 1J-166 T7 (wp07) 8,397.68 -1,841.50 5,954,074.00 556,796.00 - Point 3,416.00 1J-166 T1 Dtop (wp07) 1,466.00 -1,995.55 5,947,142.00 556,696.00 - Point 3,645.69 1J-166 T3 Peak 1 (wp07) 3,820.60 -1,893.07 5,949,497.10 556,780.12 - Point 3,733.00 1J-166 T8 (wp07) 9,239.73 -1,834.94 5,954,916.00 556,796.00 - Point 3,664.54 1J-166 T5 Peak 2 (wp07) 5,368.97 -1,867.36 5,951,045.47 556,793.76 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") f') 80.0o so.oo zo zs 2,359.67 2,183.00 10-314 13-1/2 6,288.39 3,645.74 7-518 9-7/8 12,841.06 3,733.00 4-1l2 &3/4 11/4/2005 12:24:26PM ORIGINAL COMPASS 2003.11 Build 48 ~ rr' Hallibulton Com an P y WALLIBUAT©N ~Q114C0 ~11~~1p5 Planning Report -Geographic ~ - Alaska Spent Drilling Services Database: EDM 2003.11. Single User Db Local Co-ordinate Reference: Well Plan 1J-166 Company: ConocoPhillips Alaska (Kuparuk) ND Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-166 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-166 Design: 1J-166 (wp07) ~' Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°) (ft) (ft) (ft) Name 1,564.10 32.54 250.00 1,514.00 -89.18 -245.01 Permafrost 1,712.37 32.54 250.00 1,639.00 -116.45 -319.94 T3 2,057.54 32.54 250.00 1,930.00 -179.94 -494.39 K15 2,359.67 34.74 267.80 2,183.00 -219.24 -653.82 T3+550 3,455.75 66.68 318.11 2,863.00 207.21 -1,342.07 Ugnu C 4,001.42 66.68 318.11 3,079.00 580.24 -1,676.66 Ugnu B 4,207.29 67.30 323.72 3,160.00 724.14 -1,799.44 Ugnu A 4,500.12 70.06 339.15 3,267.00 962.97 -1,929.05 K13 5,020.06 77.00 2.51 3,413.00 1,453.02 -1,996.12 West Sak D 5,206.76 77.00 2.51 3,455.00 1,634.77 -1,988.16 West Sak C 5,354.72 79.45 2.51 3,487.00 1,779.07 -1,981.83 West Sak B 5,578.94 80.00 2.51 3,526.00 1,999.66 -1,972.16 West Sak A4 5,843.85 80.00 2.51 3,572.00 2,260.29 -1,960.73 West Sak A3 6,288.35 84.00 2.51 3,645.74 2,698.15 -1,941.54 West Sak A2 11/4/2005 12:24:25PM Page 10 of 10 COMPASS 2003.11 Build 48 ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-166 1J-166 • Anticollision Summary 04 November, 2005 Sperry Driliin~ Services ~~ Date: 201L~11-03TOO:W.IM1 Validated: Ycs Version: Depth Fmm Depth To Suncy/Plan Twl 28.W 8110.00 IJ-166 (MIM17) C&CYRO-SS 800.110 13141.117 IJ-16G (wp07) MWD+IFR-AK-CAZSC Plan 1J-156 (M4) Plan 1J-158 (M3) Plan 1J-160 300 'S~ Plan 1J-162. r 270 1J-168. 240 Plan 1J-170 1J-09 1J-154 1J-10 0 I~1 Plan 1J-124 (L13) 12(~-P-081 \~~ ~ ~ j, From Colour To MD 210 0 ~ 150 28 ~ ' 250 1 ~ - 250 600 Plan 1J-174 ~+ -, _ J~ 500 750 750 1000 180 Plan 1J-176 (Q2) Plan 1J-152 (MS) 1000 1250 1250 Plan 1J-178 (Q3) 1500 1500 1750 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation ~ 1S0 R/ink 1750 2000 2000 - ~~-_-~- - 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 - 8000 REFERENCE INFORMATION 8000 9000 CooMinate (N/E) Reference: Well Plan 7J-166, True North 9000 10000 Vertical (TVD) Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) 10000 11000 Section (NS) Reference: Slot - (O.OON, O.OOE) 11000 12000 Measured Depth Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Calculation Method: Minimum Curvature 12000 13000 NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-768 ConocoPhillips Alaska (Kuparuk) ANTI-COLLISION SETTINGS Ground Level: 81.00 Drilling & Wells Interpolation Method: MD Interval: SOStations +WS +FJ-W Northing Easting Latittude Longkude Slot West Sak Depth Range Fran: 28.00 70 7 2841.07 0.00 0.00 5945691.74 558702.73 70°15'44.023N 149°37'31.b97W Maximum Range:1481.30656428891 Calcuation Methotl: Minimum Curvature Reference: Plan: 1J-166 (wp07) Error System: ISCWSA Plan 1J-164 1J-03 30 Plan 1J-109) ~~~ IWSP-021 Plan 1J-111 (M1~ so Plan 1J-159 Scan McMOd: Trav. Cylinder North EROr Surtace: Elliptical Conic 30 Warning Method: Rules Based 330 =~~.- ~WSP-20 -- - 20 _ ~/ 300 60 15 1 5 1 1 240 120 2 2 210 150 30 180 Travelling Cylinder Azimuth (TFO+AZI) I°I vs Centre t0 Centre Separation 115 n/inl Sx MD Irc 1 R.00 0.% Azl TVD H115 ~FJYY DLe9 0.% 20.00 0.00 0 % 0.% )Face VSec Tar9e1 0 % 0.% 2 fi00.% 0.% 0.% %0.00 0% 0.% 0.00 0% 0% 3 T%.81 2.fi0 4 1560.1] ]2.60 260.00 ]00.00 O.T6 3.% 2.60 260.00 1609.00 8008 -262.01 3.fi0 26000 0)6 000 68.08 6 2168.1] 32.66 260.00 2016.83 -1900.5 1i16.2d 0.% 0% -1%45 6 3331.38 fifi 68 T 010].]1 %.fi8 310.11 2916.% 12626 -1267.% 6.% 319.11 J11830 668.89 -1)39.16 0.% %.82 12115 0% 618.89 0 0.960.39 ]].% 9 6033.39 T).% 2.61 3101]0 1602.]3 -1999.33 6.% 2.61 361800 166800 -1896.% 000 M.II 1602)3 0.00 16%.00 1J-t6fi T1 pop 1-veTl 10 6293.39 ]].% 11 63fi8.39 %.% 2.61 36T4A8 1)18.09 -1%6.18 0.% 2.61 3198./6 1)92.61 -1%116 600 0.00 1]19% 338.% 1]9261 12 81 %.39 %00 13 8289.39 81.% 261 363183 2698.20 -1916.8] 0.% 261 3865.)d %98.19 -1%1.61 6.% 0.% 2599.29 0.00 28%.19 16 8680.39 0100 2.61 388686 2896.% -1%2.03 0.00 0% 28%.% 5 %36.88 %.02 16 fi919.89 93.61 2.61 ]fi)1.60 3068.98 -19%.M 6.% 2.61 3%6.1 ] 3366 60 -1912.89 1.10 0.00 306fi.90 1J-166 T3 TragM1 11rN01) 0 % 3358.50 1] 7103.89 9].0.1 10 ]113.89 %.31 2.61 3666.99 M11.09 -19%.% 0.% 2.20 3616.fi9 ]820.60 -10%.OT 1.00 0% 161108 -116.00 3820.60 1J-166 T3 Pdk11wpOT) 19 7)23.% %.J] 1.61 ]666.68 6130.26 -108206 1.30 1%00 6130.24 20 ]0]8.89 %.31 21 0180.09 8].BT 1.61 ]681.]9 6296.80 -19]8.69 0.00 1.16 ]6]9.96 1641.39 -19)1.16 0.60 0% 629168 -16.00 66%.39 1J-166 T6 Traph 20+p0]I 22 Bl%.89 91.76 23 %63.89 93.J1 0.10 3600.91 1906.]1 -1%9.1] 1.]0 0.10 ]8]6.08 6069.16 -1 %)8) 1.% 31600 1901 J1 0.00 6%915 2d 8963.89 %.21 0.10 ]861.61 6368.9) -1 %).38 1.00 -1%00 6386.9] 1J-188 T5Pak21wP01) % 92)1.89 8IA3 % %23.09 87A3 0.]0 ]8]0.% 6fi18.8T -1%8.18 0% 0.31 3882.10 6838.81 -1%1.]1 0.00 1)600 %]8.87 0.00 6928.61 2) 9613.% %.% OM 3863.% 681).)8 -18W 68 ].% 10.% 6911.)6 R 9]81% %.% 29 %93.61 %.O1 ON 3891.60 819).80 -1%267 0.00 1.W 3691.10 6391.61 -1880.12 600 0.00 8191.fi0 3.]0 8391.61 ]0 10182.89 %.01 ]1 10J%.91 81.21 1 O3 ]861.]6 6686.81 -1068.]] 0.00 0.66 ]641.93 68%A1 -186) % 6% 0 % 6581.81 -118 % 68%O) 32 110%.91 B).Z7 >7 11208.)) %6t 0.66 ]619.00 ]6%62 -1818.60 0% 016 3881.19 )80914 -1811M ]% 0.00 ]6%62 1}186 T8 (wp0)) d.01 ]609N 31119%.23 90.61 % 1199].09 BTA3 006 %)61l 828606 -1862.b 0.% 066 3617.% 8391.88 -1861.60 3% 000 8291.% 1]8.93 839160 1116fi T)I.mO]I 38 11044.61 %.% 3] 12)16.87 %.% 0.16 38)9.]3 8116.12 -1811.11 ].00 O.d6 3]28.13 9116.86 -1836.60 0.% -119.% 9616.12 0.00 9146.% >8 12011.07 8066 066 313300 92]9.13 -1834.W ].% O.OT 92]9.13 111%TBIw611 ConatoPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-166 Well Error: O.OOft Reference Welibre 1J-166 Reference Design: 1J-166 (wp07) bllif,rton Com pany Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Datat~.se: Offset TVD Reference: WALL.IBURTON .......~..~ M_.a_~~.~_., ........: Sperry Drilling Services Well Plan 1J-166 Planning RKB @ 109.OOft (Doyon 141 (28+g1)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.57 sigma EDM 2003.11 Single User Db Offset Datum Reference 1J-166(wp07) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,481.31ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma >urvey Tool Program Date 11/3/2005 From To (ft) (ft) Survey (Welibre) Tool Name Description 28.00 800.00 1J-166 (wp07) (1J-166) CB-GYRO-SS Camera based gyro single shot 800.00 12,841.07 1J-166 (wp07) (1J-166) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/4/2005 4:45:38PM Page 2 of 3 COMPASS 2003.11 Build 48 ~ a..t° rte' ~ 611ihrton Com an A Y ~41"10CQ~'t1~~1~J5 Anticollision Report Alaska Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1J Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1J-166 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbre 1J-166 Datable: Reference Design: 1J-166 (wp07) Offset ND Reference: MALLIBURTON Sperry Drilling Servicaa Well Plan 1J-166 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.57 sigma EDM 2003.11 Single User Db Offset Datum Summary Reference Offset Centre to No-Go Allowahe Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbre -Design (ft) (ft) (ft) (ft) Kuparuk 4E .Pad 1 E-105 - 1 E-105 - 1 E-105 11,327.88 13,150.00 1,269.24 222.16 1,047.08 Pass -Major Risk 1 E-105 - 1 E-105L1 - 1 E-105L1 10,929.34 13,529.00 1,284.65 235.17 1,049.48 Pass -Major Risk 1 E-105 - 1 E-105L2 - 1 E-105L2 12,101.21 12,350.00 1,319.53 220.41 1,099.12 Pass -Major Risk 1 E-105 - 1 E-105PB2 - 1 E-105PB2 12,281.07 12,208.00 1,249.68 229.25 1,020.43 Pass -Major Risk Kuparuk 1J Pad 1J-03 - 1J-03 - 1J-03 142.88 150.00 244.25 2.52 241.73 Pass -Major Risk 1J-09 - 1J-09 - 1J-09 293.93 300.00 280.40 5.37 275.03 Pass -Major Risk 1J-10 - 1J-10 - 1J-10 644.43 650.00 122.41 11.97 110.44 Pass -Major Risk 1J-154 - 1J-154 - 1J-154 Rig 599.87 600.00 266.85 13.16 253.69 Pass -Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 599.87 600.00 266.85 13.16 253.69 Pass -Major Risk 1J-168 - 1J-168 - 1J-168 Rig 349.94 350.00 40.98 7.64 33.34 Pass -Major Risk 1J-168 - 1J-168 L1 - 1J-168 L1 Rig 349.94 350.00 40.98 7.64 33.34 Pass -Major Risk 1J-168 - 1J-168 L2 - 1J-168 L2 349.94 350.00 40.98 7.64 33.34 Pass -Major Risk 1J-168 - 1J-168 L2 P61 - 1J-168 L2 P61 Rig 349.94 350.00 40.98 7.64 33.34 Pass -Major Risk Plan 1J-109 -Plan 1J-109 - 1J-109 (wp01) BHI 287.99 300.00 231.76 6.38 225.38 Pass -Major Risk Plan 1J-111 (M12) -Plan 1J-M12 Lat A -Plan 1 J-I 350.99 350.00 202.53 6.75 195.79 Pass -Major Risk Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1J-L9 L 550.99 550.00 158.09 10.49 147.59 Pass -Major Risk Plan 1J-118 (L10) -Plan 1J-L10 Lat A -Plan 1J-L' 450.99 450.00 146.24 8.62 137.62 Pass -Major Risk Plan 1J-120 (L11) -Plan 1J-L11 Lat A -Plan 1J-L' 450.99 450.00 151.79 8.62 143.17 Pass -Major Risk Plan 1J-122 (L12) -Plan 1J-L12 Lat A -Plan 1J-L' 350.99 350.00 166.94 6.75 160.20 Pass -Major Risk Plan 1J-124 (L13) -Plan 1J-L13 Lat A -Plan 1J-L' 300.99 300.00 189.46 5.81 183.66 Pass -Major Risk Plan 1J-127 (L8) -Plan 1J-L8 LatA-Plan 1J-L8 L~ 695.74 700.00 232.64 13.23 219.41 Pass -Major Risk Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDispc 350.99 350.00 360.75 6.75 354.00 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 - 1J-152 (wp04) 4,368.61 4,799.98 168.74 89.98 78.76 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 L1 - 1J-152 L1 (wp04) 4,368.61 4,799.98 168.74 89.96 78.78 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 L2 - 1J-152 L2 (wp04) 4,368.61 4,799.98 168.74 89.96 78.78 Pass -Major Risk Plan 1 J-156 (M4) -Plan 1 J-M4 A Lat -Plan 1 J-M4 650.10 650.00 221.97 12.41 209.56 Pass -Major Risk Plan 1J-158 (M3) - 1J-158 - 1J-158 (wp2A) BHI 350.92 350.00 181.17 6.80 174.36 Pass -Major Risk Plan 1J-159 - 1J-159 - 1J-159 (wp03) 797.52 800.00 161.23 17.42 143.81 Pass -Major Risk Plan 1J-159 - 1J-159 L1 - 1J-159 L1 (wp03) 798.49 800.00 161.25 16.05 145.20 Pass -Major Risk Plan 1J-159 - 1J-159 L2 - 1J-159 L2 (wp03) 798.49 800.00 161.25 16.05 145.20 Pass -Major Risk Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI 349.92 350.00 140.90 7.58 133.32 Pass -Major Risk Plan 1J-162 - 1J-162 - 1J-162 (wp03.1-North Heel 350.92 350.00 80.85 7.44 73.41 Pass -Major Risk Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) 350.92 350.00 80.85 7.34 73.51 Pass -Major Risk Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp3.1) 350.92 350.00 80.85 7.34 73.51 Pass -Major Risk Plan 1J-164 - 1J-164 - 1J-164 Rig 499.99 500.00 40.95 10.83 30.11 Pass -Major Risk Plan 1 J-170 -Plan 1 J-170 - 1 J-170 (wp01) 549.85 550.00 81.55 11.92 69.63 Pass -Major Risk Plan 1 J-174 -Plan 1 J-174 - 1 J-174(wp01) 249.99 250.00 160.39 5.41 154.98 Pass -Major Risk Plan 1J-176 (Q2) -Plan 1J-Q2 B Lat -Plan 1J-Q2 300.99 300.00 200.52 5.80 194.72 Pass -Major Risk Plan 1J-178 (Q3) -Plan 1J-Q3 B Lat -Plan 1J-Q3 300.99 300.00 240.67 5.80 234.87 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 638.65 650.00 239.36 13.36 226.00 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 649.85 650.00 205.94 17.62 188.32 Pass -Major Risk WSP-04 -WSP-04 -WSP-04 638.94 650.00 179.84 13.36 166.48 Pass -Major Risk WSP-05 -WSP-05 -WSP-05 680.78 700.00 182.00 18.30 163.70 Pass -Major Risk WSP-06 -WSP-06 -WSP-O6 634.36 650.00 202.13 16.92 185.21 Pass -Major Risk WSP-07 -WSP-07 -WSP-07 681.21 700.00 228.71 20.95 207.76 Pass -Major Risk WSP-08 -WSP-08 -WSP-08 786.18 800.00 270.71 37.32 233.39 Pass -Major Risk WSP-20 -WSP-20 -WSP-20 956.06 950.00 44.66 24.30 20.37 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/4/2005 4:45:38PM Page 3 of 3 COMPASS 2003.11 Build 48 t € ~~ r~1te°$ 1J-16~rilling Hazards ~knmarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pum ing out, backreaming 1J-166 Drilling Hazards Summary.doc prepared by Shane Cloninger `" ~ ~ 11/16/2005 11:23 AM ~ a ~6 Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 11/10/2005 Prepared by: Mike Martin ~i Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,563' MD (1,513' TVD) < Top of Tail at 1,610' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 2,360' MD (2,183' TVD) Mark of Schlumberger GemCADE Prelimina 10 3/4" Surface Preliminary Job Desi°n based on limited in°ut da Job Design purposes Scl~~nl~r~r Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 1,610' MD. Lead Slurry Minimum pump time: 200 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (80') x 1.00 (no excess) = 109.2 ft3 0.3637ft3/ft x (1563' - 80') x 3.50 (250% excess) = 1887.8 ft3 0.3637 ft3/ft x (1610' - 1563') x 1.35 (35% excess) = 23.1 ft3 109.2 ft3 + 1887.8 ft3+ 23.1 ft3 = 2020.1 ft3 2020.1 ft3 / 4.45 ft3/sk = 454 sks Round up to 460 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 140 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x (2360' - 1610') x 1.35 (35% excess) = 368.2 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 368.2 ft3 + 43.2 ft3 = 411.4 ft3 411.4 ft3/ 2.47 ft3/sk = 166.6 sks Round up to 170 sks BHST = 47°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) Ibbll (min) Iminl CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 ASL 7.0 359.8 51.4 86.4 DeepCRETE 5.0 73.3 14.7 101.1 Drop top plug 0.0 0.0 5.0 106.1 Water 5.0 20.0 4.0 110.1 Switch to rig 0.0 0.0 5.0 115.1 Mud 7.0 190.3 27.2 142.3 Slow & bump plug 3.0 9.0 3.0 145.3 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint throughout tail slurry column ~~ ~y~~ ~~~~~~~~ CemCADE*well cementing recommendation for 10 3/a" Surface Casing Operator : CPAI Well 1J-166 Country :USA Field Kuparuk State :Alaska Prepared for :Mike Greener Location 1J Pad Proposal No. : V1 Service Point Prudhoe Bay Date Prepared :November 10, 2005 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by :Mike Martin Phone (907) 265-6205 E-Mail Address martinl3C~slb.com ~~~,N ~ 4 t n C ~G -9~~ ' Ai ~ Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger ~ .~~;~ • Client CPAI Well 1J-166 String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :2360.0 ft BHST : 42 degF Bit Size : 13 1/2 in Previous String MD OD Weight ID (ft) in Ib/ft (in) 80.0 20 94.0 19.124 Landing Collar MD :2280.0 ft Casing/liner Shoe MD :2360.0 ft SI~ar~~r Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2360.0 10 3/4 40.0 45.5 9.950 M-65 2270 4230 STC Mean OH Diameter :13.500 in Mean Annular Excess :174.8 Mean OH Equivalent Diameter: 17.287 in Total OH Volume :661.9 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1563.0 13.500 250.0 18.681 2360.0 13.500 35.0 14.338 1j-166 cem~t.ctw ; 11-092005 ; Loadcase 1075 Surface ;Version wcs-cem45_B9 Page 2 iy E ~~°~~~r • • Client CPAI Well 1J-166 String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Max. Deviation Angle : 35 deg Max. DLS :5.000 deg/100ft MD ft Directional Survey Data TVD Deviation Azimuth (ft) de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 80.0 80.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 0.0 0.0 0.000 500.0 500.0 0.0 0.0 0.000 600.0 600.0 0.0 0.0 0.000 700.0 700.0 2.5 250.0 -2.500 800.0 799.7 6.0 250.0 3.500 900.0 898.7 9.5 250.0 3.500 1000.0 996.8 13.0 250.0 3.500 1100.0 1093.5 16.5 250.0 3.500 1200.0 1188.5 20.0 250.0 3.500. 1300.0 1281.3 23.5 250.0 3.500 1400.0 1371.8 27.0 250.0 3.500 1500.0 1459.4 30.5 250.0 3.500 1558.0 1508.9 32.5 250.0 3.517 1712.0 1638.7 32.5 250.0 0.000 1800.0 1712.9 32.5 250.0 0.000 1900.0 1797.2 32.5 250.0 0.000 2000.0 1881.5 32.5 250.0 0.000 2058.0 1930.4 32.5 250.0 0.000 2100.0 1965.8 32.5 250.0 0.000 2158.0 2014.7 32.5 250.0 0.000 2200.0 2050.0 32.8 253.8 4.979 2300.0 2133.6 33.8 262.8 5.000 2360.0 2183.2 34.7 267.8 4.968 Formation Data MD Frac. Pore Name Lithology (ft) (Ib/gal) (Ib/gal) 1563.0 12.50 8.20 P-Frost 1712.0 12.50 8.70 T3 2058.0 12.50 8.70 K15 2360.0 12.50 8.70 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) ft de F) (de F/100ft) 0.0 0.0 25 0.0 1563.0 1513.1 28 0.2 2360.0 2183.2 42 0.8 tj-166 cemem.cfw ; 77 -092005 ; Loadcase 1075 Surface; Version wcs<em45_89 SIr~~r Page 3 ~''~ M ,wT ~ • Client CPAI Well 1J-166 String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 2: centralizer placement Top of centralization :1600.0 ft Bottom Cent. MD :2340.0 ft Casing Shoe :2360.0 ft NB of Cent. Used :19 NB of Floating Cent. :0 Scbl~~r~~r Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 2360.0 19 1/1 S1103610-10 3/4-6~6 31.3 1620.0 (3/16")C Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) S1103610-10 3/46- 10 3/4 14.500 11.874 No Houma 13.500 447.37 1548.93 36 (3/16")C (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10Dspecifications Page 4 1j-166 cementcfw; 11-092005; Loadcase 1075 Surface; Version wcstem45_69 ORIGINAL C. Client CPAI Well 1J-166 String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 9.60 Ib/gal Job volume :199.3 bbl Fluid No: 2 Fluid No: 3 Fluid No: 5 Rheo. Model :BINGHAM At temp. : 65 degF DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water 51~rg~r CW100 DESIGN Density :8.321b/gal Job volume :50.0 bbl MUDPUSH II DESIGN Density :10.501b/gal Job volume :50.0 bbl ASL DESIGN Density :10.701b/gal Pv :28.660 cP Tv :16.971bf/100ft2 Gel Strength : (Ibf/100ft2) SLURRY Mix Fluid :8.629 gal/sk Yield :2.52 ft3/sk Porosity :62.3 Job volume :359.8 bbl Quantity :454:44 sk Solid Fraction :37.7 Density :8.321b/gal • Base Fluid :8.259 gal/sk DeepCRETE DESIGN Fluid No:6 Density : 12.00 Ib/gal Rheo. Model :BINGHAM Pv :105.064 cP At temp. : 63 degF Tv :11.81 Ibf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid :8.231 gal/sk Job volume :73.3 bbl Dry Density : 199.77 Ib/ft3 Yield :2.47 ft3/sk Quantity :166.54 sk Sack Weight : 94 Ib Porosity :44.5 % Solid Fraction :55.5 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Base Fluid :8.131 gal/sk Additives Code Conc. Function D046 0.600 %BWOC ANTIFOAM B160 0.170 %BWOC Low Temp Dis D186 0.100 gal/sk blend ACCELERATOR 1j-168 cement.cfw ; 11-092005 ; Loadcase 1075 Surface ;Version wcscem45_89 Page 5 ~~ A ~ `~e; f ~• a '°.~* i f Client CPAI Well 1J-166 String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 4: fluid sequence SIr~~r P~ :15.000 cP Ty :30.00 Ibf/100ft2 Displacement Volume 219.3 bbl Total Volume 752.4 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) CW100 50.0 0.0 8.32 viscosity:5.000 cP MUDPUSH II 50.0 0.0 10.50 Pv.23.000 cP Ty:30.00 Ibf/100ft2 ASL 359.8 1610.0 0.0 10.70 Pv.28.ti60 cP Ty:16.97 Ibf/100ft2 DeepCRETE 73.3 750.0 1610.0 12.00 Pv.105.Oti4 cP Ty:11.81 Ibf/100ft2 Water 20.0 2072.0 8.32 viscosity:1.000 cP Mud 199.3 0.0 9.60 Pv.15.000 cP Ty:30.00 Ibf/100ft2 Static Security Checks Frac 7 psi at 80.0 ft Pore 10 psi at 80.0 ft Collapse 2022 psi at 2280.0 ft Burst 4230 psi at 0.0 ft Csg.Pump out 35 ton Section 5: pumping schedule Name Flow Rate (bbUmin) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. (degF) Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW100 5.0 40.0 8.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 5.0 50.0 10.0 50.0 80 ASL 7.0 359.8 51.4 359.8 80 DeepCRETE 5.0 73.3 14.7 73.3 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 5.0 20.0 4.0 20.0 80 SLB Displace Pause 0.0 0.0 5.0 0.0 80 Switch to Rig Mud 7.0 190.3 27.2 190.3 80 Mud 3.0 9.0 3.0 199.3 80 Slow & bump plu Total 02:25 752.4 bbl hr:mn D namic Securit Checks Frac 7 psi at 80.0 ft Pore 0 psi at 80.0 ft Collapse 2022 psi at 2280.0 ft Burst 4009 psi at 0.0 ft 1j-166 cemenccfw; 11 A92005 ; Loadcase 1075 Surface; Version wacem45_69 • Page 6 3~ Y ~~ ,¢ • • Client CPAI Well 1J-166 String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface ft 8 N Fluid Sequence Ib/gal 12 16 -----1----T•-i - Hydrostatic ; - Min. Hydrostatic --- Max. Dynamic - Min. Dynamic i --- Frac i i .-- Pore ; - _._-_! -- -- . ~ O. a 1 i , is i i i i Dynamic Well Security Scl~l~~rg~r 0 50 100 150 Time (min) Depth = 2360 ft 0 1 C_ N Annular Velocity 1 ~ , 1 1 ----•-•-•-•----- i i i ,~' O i ~! O i K •1 U N 1 ' L^~ f 1 F .-. ~ 1 i 1 i s i IAI C i' ' i it i ~i Q pi:...-'-----,-•-•------1.11-•----ti 0 50 100 150 Time (min) ~ ueptn = ~:tr;u tt ~ - --_- Frac 1 1 I _•_-_•-.•_- - ---- Pore 1 1 pl - -_- H drostanc 1 1 ~ - -• -•_•- _ y---•-•-•-•;•-•---------•-----• - -•-•-----•-•-•-•-•-• --•---•-•-•-•-------•-------- •-- - -- a N ----Dynamic ~ -i 1 i i y ~ _-_-_-_._._-_._._._ i i i ._._. I• N 1 1 i _. N O 1 d ~~ ~ 1 _. C i _-_._._-_-_._._._._._-_._•_-_-_._._. 1 1 i --i---i•-•-°•-•-•-•-•-•-•-•-•-----•-•-•-•-•---•-•---------•-•-•--r------° m t•-•-•-•-----•-r-•--•-•-•--T-•-•-•--a--~-r._.-.-------•r•-•-•-•---•-•-r•-•-•-•-•-._.~-------L---~--._._._._._._. 0 20 40 60 80 100 120 140 16 Time (min) Fluids at 2360 ft T-_-- 0 0 oc~-----•-•-•-----•---•-•---i---i_._._.------_._-_._•_._..---•-•-•-•-•---•-----•-----•---•--~-------_._._.._....-- I o i n 1.'-j ~ I--- I ii (t i .E L._._._._._._._ i i ~ m~ i ~ i _. a ~ -. !~ i LL II i ~ i ~ I t 1 11 I i , ~ = I 0 20 40 60 80 100 120 140 16 Time (min) tj-766 cementcfw ; 11-092005: Loadcase 7075 Surface ;Version wcscem45_69 Page 7 ORIGINAL CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 11/10/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. < 10 3/4", 45.5# casing at 2,360' MD < Top of Tail at 3,355' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 6,288' MD (3,645' TVD) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 100' MD above Ugnu C - (2933' MD annular length). Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 2933' x 1.25 (25% excess) = 787.5 ft3 0.2578 ft3/ft x 80' 3(Shoe Joint) = 20.6 ft3 787.5 ft3 + 20.6 ft = 808.1 ft3 808.1 ft3/ 2.25 ft3/sk = 359.2 sks Round up to 360 sks BHST = 85°F, Estimated BHCT = 73°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) Ibbl) (min) Iminl CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 DeepCRETE 5.0 143.9 28.8 63.8 Drop top plug 0.0 0.0 5.0 68.8 Mud 6.0 276.0 46.0 114.8 Slow & bump plug 3.0 9.0 3.0 117.8 MUD REMOVAL Recommended Mud Properties: 9.1 ppg, Pv < 15, TY < 20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" I I, Pv< 21-24, TY ? 35-40 Centralizers: Weatherford Tandem Rise run at: 3378 - 4328 @ 1 per joint 4768 - 6208 @ 3 per 2 joints 6208 - 6288 @ 2 per joint ~ a~P~~~~~`c • CemCADE*well cementing recommendation for 7-5/8" Intermediate Casing Operator : CPAI Well 1J-166 Country :USA Field Kuparuk State :Alaska Prepared for :Mike Greener Location Proposal No. : V1 Service Point Prudhoe Bay Date Prepared :November 10, 2005 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by Phone E-Mail Address Mike Martin (907) 265-6205 martin13C~slb.com I~J`~~ Q C"1 C ~G \~~ATE Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of [he well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infrin emen[ of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger tr F ~ ~ "~ ~ ~ e ~~ <._~. • • Client CPAI Well 1J-166 Sllr~~r String 7-5/8 District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :6288.0 ft BHST : 83 degF Bit Size : 9 7/8 in Previous String MD OD Weight ID ft (in) (Ib/ft in 2360.0 10 3/4 45.5 9.950 Landing Collar MD :6208.0 ft Casing/liner Shoe MD :6288.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 6288.0 7 5/8 40.0 29.7 6.875 L-80 4790 6890 BTC Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 25 0.0 1563.0 1513.0 28 0.2 2360.0 2183.2 45 0.9 3455.0 2862.4 63 1.3 6288.0 3645.3 83 1.6 tj-166 cement.cfw ; 11 -102005 ; Loadcase 758 Imennediate ; Version wcs-cem45_89 Page 2 ~., s ~)~(~~ .a r fem... . • • Client CPAI Well 1J-166 ~ hp~r~~r String 7-5/8 District Prudhoe Bay Country USA Loadcase 7581ntermediate Mean OH Diameter :9.875 in Mean Annular Excess :25.0 Mean OH Equivalent Diam eter: 10.361 in Total OH Volume :409.7 bbl (including excess) Max. Deviation Angle : 84 deg Max. DLS :5.319 deg/100ft MD (ft) Directional Survey Data ND Deviation Azimuth (ft) (deg) (deg) Dogleg Sev. (deg/100ft) 0.0 0.0 0.0 0.0 0.000 2360.0 2183.2 34.7 267.8 4.968 2400.0 2215.9 35.5 271.1 5.042 3456.0 2862.8 66.7 318.1 0.000 4001.0 3078.5 66.7 318.1 0.000 4207.0 3159.6 67.3 323.7 5.319 4500.0 3266.6 70.1 339.1 4.993 5020.0 3412.6 77.0 2.5 0.000 5207.0 3454.6 77.0 2.5 0.000 5355.0 3486.6 79.4 2.5 3.982 5579.0 3525.6 80.0 2.5 0.000 5600.0 3529.2 80.0 2.5 0.000 5700.0 3546.6 80.0 2.5 0.000 5800.0 3564.0 80.0 2.5 0.000 5844.0 3571.6 80.0 2.5 0.000 5900.0 3581.3 80.0 2.5 0.000 6000.0 3598.7 80.0 2.5 0.000 6100.0 3616.1 80.0 2.5 0.000 6161.0 3626.6 80.0 2.5 0.000 6166.0 3627.5 80.0 2.5 0.000 6178.0 3629.6 80.0 2.5 0.000 6188.0 3631.3 80.0 2.5 0.000 6200.0 3633.4 80.5 2.5 3.833 6288.0 3645.3 84.0 2.5 4.023 MD (ft) Frac. (Ib/gal) Formation Data Pore Name Lithology (Ib/gal) 3455.0 12.50 8.20 Ugnu C 4004.0 12.50 8.70 Ugnu B 4208.0 12.50 8.70 Ugnu A 4500.0 12.50 8.70 K-13 5020.0 12.50 8.70 West Sak D 5207.0 12.50 8.70 West Sak C 5349.0 12.50 8.70 West Sak B 5580.0 12.50 8.70 West Sak A4 5843.0 12.50 8.70 West Sak A3 6268.0 12.50 8.70 West Sak A2 6288.0 12.50 8.70 TD 7j-166 cemern ctw ; 11-102005 ; Loadcase 7581ntennediate ;Version wcs<em45_09 Page 3 ~~~` ~ . - ;~ ~ P '~ ~~ ~' k~ F ,. • • Client CPAI Well 1J-166 String 7-5/8 District Prudhoe Bay Country USA Loadcase 7581n[ermediate Section 2: centralizer placement Top of centralization :3378.0 ft Bottom Cent. MD :6278.0 ft Casing Shoe :6288.0 ft NB of Cent. Used :81 NB of Floating Cent. :0 Schl~~rger Centralizer Placement Bottom MD Nbr. Cent. I Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 4328.0 23 1/1 7-5/8 TR 76TR 0.0 4310.6 4768.0 0 0/0 0.0 4328.0 6208.0 54 3/2 7-5/8 TR 76TR 0.0 4785.4 6288.0 4 2/1 7-5/8 TR 76TR 92.7 6288.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) 7-5/8 TR 76TR 7 5/8 10.500 9.000 No Weatherford t'~ 9.875 375.00 3168.00 (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 4 1j-766 cementcfw : 11-1 0 2005 ; L°adCase 7581ntermediate ; Version wcstem45_89 OR161NAL • • Client CPAI Well 1J-166 String 7-5/8 District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 9.10 Ib/gal Job volume :285.0 bbl CW100 DESIGN Fluid No: 2 Density : 8.32 Ib/gal Job volume :50.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 11.00 Ib/gal Job volume :50.0 bbl DeepCRETE DESIGN Fluid No:4 Density Rheo. Model : HERSCHEL_B. k At temp. : 80 degF n Ty Gel Strength DESIGN BLEND SLURRY Name : G Mix Fluid :7.558 gal/sk Dry Density : 199.77 Ib/ft3 Yield :2.25 ft3/sk Sack Weight : 94 Ib Porosity :44.9 BASE FLUID Type :Fresh water Density : 8.32 IbJgal Additives Code Conc. Function D046 0.600 %BWOC ANTIFOAM B 160 0.600 %BWOC Low Temp Dis D167 0.300 %BWOC FLUID LOSS D 186 0.140 gal/sk blend ACCELERATOR SIr~~r 12.50 Ib/gal 8.69E-3 Ibf.s^n/ft2 0.833 0.00 Ibf/100ft2 (Ibf/100ft2) Job volume :143.9 bbl Quantity :359.07 sk Solid Fraction :55.1 Base Fluid :7.418 gal/sk tj-166 cemen[dw ; 11-1 0 2005 ; Loadcase 758 Intermediate ; Version wcs-cem45_89 Page 5 DRIGf,JAL Client CPAI Well 1J-166 String 7-5/8 District Prudhoe Bay Country USA Loadcase 7581ntermediate • SI~r~~r Section 4: fluid se uence Original fluid Mud 9.10 Ib/gal k : 1.13E-2 Ibf.s^n/ft2 n :0.517 Tv : 6.47 Ibf/100ft2 Displacement Volume 285.0 bbl Total Volume 528.9 bbl TOC 3355.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) CW100 50.0 1259.6 1039.2 8.32 k:6.68E-31bf.s^n/ft2 n:0.177 Tv:0.001bf/100ft2 MUDPUSH II 50.0 1056.1 2298.9 11.00 k:8.59E-2 Ibf.s^n/ft2 n:0.279 Tv:11.821bf/100ft2 DeepCRETE 143.9 2933.0 3355.0 12.50 k:8.69E-31bf.s^n/ft2 n:0.833 Tv:0.001bf/100ft2 Mud 285.0 0.0 9.10 k:1.13E-21bf.s^n/ft2 n:0.517 Tv:6.471bf/100ft2 Static Security Checks Frac 425 psi at 2360.0 ft Pore 63 psi at 2360.0 ft Collapse 4454 psi at 6208.0 ft Burst 6846 psi at 2298.9 ft Cs .Pump out 43 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. (degF Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW100 5.0 40.0 8.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 5.0 50.0 10.0 50.0 80 DeepCRETE 5.0 143.9 28.8 143.9 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Mud 6.0 276.0 46.0 276.0 80 Mud 3.0 9.0 3.0 285.0 80 Slow & bump plug Total 01:57 528.9 bbl hr:mn D namic Securit Checks Frac 222 psi at 6288.0 ft Pore 47 psi at 4081.9 ft Collapse 4350 psi at 466.4 ft Burst 6430 psi at 0.0 ft 1j-166 cement.cfw; 11-102005 ; Loadcase 7581ntennediate;version wcstem46_89 Page 6 ~ ~ ~` ~,~. fir. • Client CPAI Well 1J-166 String 7-5/8 District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 6: WELLCLEAN II Simulator ft o- ~- o- o- o: 0 o- ~. o: o- ~, _ ~- o- o- ~_ o: 0 o- ~, _ o: 0 o- a- o- o- ~_ Cement Coverage ~. S 0 0 O Z 3 ~ Mud ~ MUDPUSH II ~ DeepCRETE CVJ100 10 Schlum~rg~r Risk Mud on the Wall ~ i s ._ ~ _ °_ _ 3500- ~.- _ i_~ 3500 I AD00- ~ X400 .-r' '~ asoa- ~ ssoo _ j S t 9ooa saoo o a 9500 5500 6000 6000 a 3 0° ~ o # High ~ Low 0 Medium ~ None 1j-166 cementcfw ; 11-1 0 2005: Loadcase 758 In[ennediate ; Version wcs-cem45_89 Fluids Concentrations ~ s ,~ 3500 aeoo .>^soo c t 5400 0 5500 • Page 7 ORIGINAL Client CPAI S~hl~m~rg~r Well 1J-166 String 7-5/8 District Prudhoe Bay Country USA Loadcase 7581ntermediate Ib/gal ft 8 12 16 0 -~-----1----T•-i '--~ Hydrostatic ; ;- Min. Hydrostatic i I O I _..-----'---- I i- Max. Dynamic ~ O ,- ~ o ~- - Min. Dynamic I l17 ~ Calc. WHP i o O i...... Frac I ---•-----•-------.. i I i ~- Pore , ~ i ._._._._._._._._J i i pp :~ _ :N i fl.0 i I i ~ 'r fl N i O I N ! j I > i I I i O i 8 I i Ch I Ot._._._._.-i -•-•---•7 ~ 0 40 80 120 ' Time (min) ~ i i De th = 6288 ft_ _ _ _ o 0 t ~ N -- Annular Velocity ~ f ~ --------- -----~ n ^'~ I I i O f ~`O li ! li I~ i i 8 U OKi ! I' i f i t r O`- ii I I! t i ~i cD ~ ~ it i ! I i ' i ~ ~i i ~ ~ i ii i O i' c i, 'I V ; p0 ` C i I.' i 0 40 80 120 Fluid Sequence Dynamic Well Security Time (min) ~ D e p t_h--_- 6 2 8 8-f t-----•-•-~°-------~--.._._._._...._._. _._._..--- -•- ~ - _._. Frac I ... _._. _._._. _ I I - ---- Pore I 1 i a -_ _._tiY£!2St3LD_.I ~ _.-._.- - -.-.-._ I _._._._._._._._._._.-.- i I i d -.-._._._.-.-.-._._ i i .E_._ N I 1 1 1 1+ °L _•_ i w i i _._ r 1,..-.J , i i c _ _ __ _ __ _ ___ ~ ;^--•---•----- - -•------- - --- -- --- - - - - - -•-•-•-•-•i•-•-•-•-•1•-----•--t------•-•-•-•-•-•-•---•- 0 25 50 75 100 12 Time (min) _ _ Fluids at 6288 ft r T ---- ~ o ut~-•_._._._._._._._._._._._._._._._._._._._._. _._.-._._._.i . .1... In _ ---- -•-•--- - -._._._ ._._._._...----.._._._.---~~--- I ~ In ' 1 i I i^--.__ _ --- i C L._._._._._. _.J ~ .-TT__I ~_--` H Ici I /~~~ i i -~- -..i. , , i i 1 I O I~ i - `\~ 1 I I ~ ~ I 1 i ; _--i i ' ~ J. .-._.J._._._._.1._._._ O t _•-•-•-•-•-•-•-•-•-•-•1--•-•-•-•-•-•-•-•_•-•-•-Y.-.-._._._._.-.-....-• 7 - f-•-•-•-•-•-•-_-•-•-•-•- 0 25 50 75 100 12 Time (min) Page 8 1j-166 cementcfw ; 11-1 0 2005 ; Loadcase 7581n[ermediate ;Version wcs<em45_89 ~~I~I~IAL Q Insulated Conductor n Casing, 20", 94#, K55 x ~~ 34", 0 312" WT ~ +/- 80' MD ~. c Vf O /~''~ V l G n .,y m l*1 ~ ter; ~ w ~ ~ o' 0 3 0 ~' m ~' = n . a c 10-3/4", 68#, L-80, BTC, R3 2,360' MD / 2,183' TVD _~ rt 34.7 degrees TD 13-3/8" hole Top of I)gnu C @ 3,456' MD / 2,863' TVD ~ Top of West Sak B 5,355' MD / 3,487' TVD Wellhead /Tubing Head /Tree, 10-3/4" x 4-''/z", 5,000 ksi - Tubing String: 4-I/2", 126#, L-80, IBTM -- Lateral Entry Module#I (LEM), Baker, with seal bore and ZXP packer above. e Q; ~~ o g b' 'm m K tio; ~~:' Top of Wes[ Sak A C~ ~ 5,579' MD / 3,526' TVD Tubing, 4-'/" IBTM, from LEM [o A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. Seal bore and ZXP packer for A2liner +/- 90' below "B" window 7-5/8", 40#, L-80, BTCM, R3 Csg a. 6,288' MD / 3,645' T VD 84 degrees TD 9-5/8" hole (I)Gas Lift Mandrel, CAMCO 4-I/2"xl" ModeIKBG- 2, one (1) set n 2,400' M D, 2,216' TVD. (I)Gas Lift Mandrel, CAMCO 4-I/2"x I" ModeIKBG- 2, one (I) set at < 72 deg, 4,700' MD, 3,331' TVD. Electric Submersible Pump, Centrilift 418 HP motor, I with FC6000 wireline deployed pump. Bottom at 5,000' MD, 3,408' TVU / Ibb L2 "D" Sand Window ~ 5,033' MD / 3,416' TVD 77 degrees "D" Liner, 4-I/2", 12.8#, L80, BTCM, R3 (0.125" x 2.5" slots, 32 per foot, 5.9%open area) 166 LI "B" Sand Window /~ @ 5, 368' MD / 3,489' TV D / 80 de~ees "B" Liner, 4-1/2", 12.8#, L80, BTCM, R3 i/ (0.125" x 2.5" slots, 32 per foot, 5.9°/ open area) -- _ \ A2 Sand Liner, 4-1/21i1, 28#-, L-80 (~ t!J `~ BTCM, R3'/z slotted and'/ blank, v cnnslriclas j<rr isolnGou I1-Ibb L2: b-3/4" D sand lateral TD 12,980' MD / 3,531' TVD Angle 87.15 degrees I1-166L1. b-3/4" "B" sand lateral TD 12,945' MD / 3,588' TVD Angle 87 degrees 6-3/4 A2 sand lateral-~ TD 12,841' MD / 3,733' TVD _ Angle 88.85 degrees f E~26~ y l E-31 P8 ~ f lE 119 -09 iL-28 1E-35 tE-32 J 1 iL-29 f_ 1J-1 ----~ .~ 1 L-2M 1 1L-21D RJ ~~ f l D- 12' _' 1 1 1 1 D 38 ' 21J 11~~ ~ - 1J-164 '°-'23 ~D_0e '° KRU 1 J-166 IE-1osP i n~-n*c, _-~ 2 ~~~ _i ~'t IE-34 i€=i®5 1J-168 2~~ tE-35 11000 10000 34 ~~~~. $~ t 7 ~~ ` 0 ~ tE-117LY ~4 O O ~~ d d 2s Proposed 1-Oil 1 West Sak "A2" Sand 2051980 ~f11 i~4, Jf}Fi ,6 :`'~~' fi E~ jf..`rl SFD 12/8/2005 35 J tD-38 ~`. i '~':F'I _ z ~~-11 'yam aP-13 'HSP } 1 4 • ~~, T10N, R11 E, UM Feet D 1 ,000 2,000 3,000 4,000 1 • ._ 1121 -,.. SHARON K. ALLSUP-DRAKE. CONOCOPHILLIPS L G ATO 1530 ss-1 ssi /aai 700 G ST. DATE.. ~ ANCHORAGE AK 99501 f~1T ~ ~S~- $ ~~~ s PAV TQ THE. ,~/J~' ' ~F i ; ~, ~ ~ ~d2~=---vu~LARS ORDER OF 12,~iZz~%^' ° `" "~'" " ~ Valid Up To 5000Doliars I; JPMorganChase ~1 ' ~ JPMorgan Chase Bank, N.A. Columbus, OH t/ M' ~S MEMO - ----- -- ry' ~:044LL55LL11:528747L90792711'LL2L • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSvIITTAL LETTER WELL NA1~IE ,~~!/2GC I ~T-~~'~ PTD# ~ ~~ l 9~ ~ ~~ ~\og~~ ~.~ CHECK WHAT i ADD-ONS APPLIES ~ (OPTIONS j i MULTI LATER4L (If API number last two (2} digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well , Permit No, API No. Production should continue to be reported as a function of .the original API number stated above. PILOT HOLE , In accordance with 20 AAC as.uu~~tl, aii (per records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (~0 - 70/80) from records, data and Logs acquired for well (name on permit). SPACL'~G The permit is approved subject to full EXCEPTION ;' compliance with 20 AAC 25.05. Approval to Ii perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing j exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE j Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and ` ; 10' sample intervals through target zones. 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N, °' m' U' n a ~' ~, J U E' o o ~ -~ -~ , > a -~ ~ ~ ~~ c -~ 3; °i ~ ° ° > H' C c > H H ° 'v a ° `~~ ° ~~ '~~ a~ ~~ o~ ~~ ~~ ~~ ~~ ~ ° ~~ ~~ c, m Y >, ~ a~, a~~ . c, °~~ °~ ~ ~ , a i ~, °~ °, ~ 4 ~' a~~ , ~ °, a~ d m °' - ~ ~~~ U , ` , o, °: ~~~ ~ ~; i a m, a. i~ a ~ a, 'v' •- g , ~ O~ O. L, °~ °~ ~ ~' ~'' ' ~ ~ a~, ~: ~ ~ o~~ a~ o, p ~ U c a,~, ~, ; ; ,m,~;O, O,a;a;U ;Q. a.¢; U, m, U, V, U, U, ¢, ~;¢, ~; m.m,U. , ,~ , a,g m,m, U, W n. ~"" _ ~ O _ N M [I' ~ O~ O O O N M ~ ~~ ~ fD 00 O O N _ N N N M d' N N ~ f0 N N h d0 N N _ O O N M M N M V M M M to CO M M 1` O M M m M U 'Lr O C a0+ N a0+ N w N U Cp ~ ~ ~ M ~ O U ~ W ~+ f6 ~ ~ ~ ~ ~ O y p ' ~+ N •C O ~ ~ ~ ~ Q~ d W p G 0 U W 'S a ¢ ¢ m ' ~ w G . ¢ ~ c7 ¢m • • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify rending intorrnation, 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. Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon May 01 15:38:06 2006 ~~~ i3s~~I ~ Reel Header Service name .............LISTPE Date .....................06/05/01 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/05/01 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 ~ Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0004149018 P. ORTH D. GLADDEN ao5 -fig S` Scientific Technical Services Scientific Technical Services 1J-166 500292329100 ConocoPhillips Alaska, Inc. Sperry Drilling Services O1-MAY-06 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 35 11N l0E 1880 2508 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 2368.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. SDS/HALLIBURTON PROVIDED DIRECTIONAL AND MWD SERVICES FOR RUNS 1 & 2 OF 1J-166 (DOWN TO THE INTERMEDIATE CASING POINT). THE RESERVOIR SECTION WAS DRILLED AND LOGGED BY ANADRIL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-2 REPRESENT A PORTION OF WELL 1J-166 WITH API#:50-029-23291-00. THIS WELL SECTION REACHED A TOTAL DEPTH (TD) OF 6355'MD/3650'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/01 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2331.0 6308.5 RPD 2350.0 6301.0 RPM 2350.0 6301.0 0 RPS 2350. 6301.0 RPX 2350.0 6301.0 FET 2350.0 6301.0 ROP 2378.5 6355.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2331.0 6355.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2331 6355 4343 8049 2331 6355 RPD MWD OHMM 1.21 2000 18.9393 7903 2350 6301 RPM MWD OHMM 3.47 1073.44 14.1563 7903 2350 6301 RPS MWD OHMM 3.6 74.04 12.9839 7903 2350 6301 RPX MWD OHMM 3.22 49.64 11.6558 7903 2350 6301 FET MWD HOUR 0.18 53.06 0.907472 7903 2350 6301 GR MWD API 23.81 114.32 71.0008 7956 2331 6308.5 ROP MWD FT/H 0.91 461.05 195.072 7954 2378.5 6355 First Reading For Entire File..........2331 Last Reading For Entire File...........6355 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/01 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 • • Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/01 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2331.0 6308.5 RPD 2350.0 6301.0 RPM 2350.0 6301.0 RPS 2350.0 6301.0 RPX 2350.0 6301.0 FET 2350.0 6301.0 ROP 2378.5 6355.0 LOG HEADER DATA DATE LOGGED: 13-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6355.0 TOP LOG INTERVAL (FT) 2378.0 BOTTOM LOG INTERVAL (FT) 6355.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.4 MAXIMUM ANGLE: 82.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 2368.0 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 TERMPERATURE: MUD FILTRATE AT MT: Other 9.25 59.0 9.5 100 4.4 2.900 60.0 1.580 116.0 3.500 60.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .... ..............Down Optical log depth units. .........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 3.000 6~ Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2331 6355 4343 8049 2331 6355 RPD MWD020 OHMM 1.21 2000 18.9393 7903 2350 6301 RPM MWD020 OHMM 3.47 1073.44 14.1563 7903 2350 6301 RPS MWD020 OHMM 3.6 74.04 12.9839 7903 2350 6301 RPX MWD020 OHMM 3.22 49.64 11.6558 7903 2350 6301 FET MWD020 HOUR 0.18 53.06 0.907472 7903 2350 6301 GR MWD020 API 23.81 114.32 71.0008 7956 2331 6308.5 ROP MWD020 FT/H 0.91 461.05 195.072 7954 2378.5 6355 First Reading For Entire File..........2331 Last Reading For Entire File...........6355 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/01 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date ....................~05/O1 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................06/05/01 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services End Of LIS File