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Development❑ Exploratory LI 204-173 3.Address: P. O. Box 100360,Anchorage, Stratigraphic❑ Service E 6.API Number: Alaska 99510 50-029-23223-61 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1 E-114L2 ADL 25651 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: RECEIVED Total Depth measured 11,833 feet Plugs measured None feet true vertical 3,539 feet Junk measured None feet SEP 11 2017 Effective Depth measured 11,833 feet Packer measured 7414,7732,8569 feet AiGcc true vertical 3,539 feet true vertical 3478,3547,3697 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 20 " 108'MD 108 TVD SURFACE 4,168 feet 10 3/4" 4,198' MD 2296 TVD PRODUCTION 7,450 feet 7 5/8" 7,477' MD 3725 TVD LINER L2 4,346 feet 4 1/2 " 11,810' MD 3540 TVD Tubing(size,grade,measured and true vertical depth) 4.5" L-80 7,446' MD 3,486'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Liner Top Packer 7414 MD 3478 TVD SSSV = NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A p p� DECTreatment descriptions including volumes used and final pressure: SCANNED D 1 4 201z 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - - - - Subsequent to operation: - - 558 165psi - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations U Exploratory ❑ Development ❑ Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 1=1 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 317-232 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce©cop.com Authorized Title: Sr.Wells Engineer , / Contact Phone: (907)265-6471 Authorized Signature: f4 .. t_��'— Date: /7lj7 V`/Z lool i �0I-7- RBDMS P 1 2017 Form 10-404 Revised 4/2017 �f /Q/,�.�7 Submit Original Only • • 1E-114L2 DTTMSTd JOBTYP SUMMARYOPS 8/14/17 PUMPING FULLBORE MARCIT GEL TREATMENT. PUMPED 20 BBLS LINEAR GEL, TRACKING 66 BBLS CROSSLINKED GEL, &ANOTHER 20 BBLS LINEAR GEL DOWN ONLY TBG FOLLOWED BY 95 BBLS DSL DOWN TBG FOR DISPLACEMENT& FREEZE PROTECT(JOB COMPLETE) KUP a 1E-114L2 Cont coPhillips 1., Well Attribu' Max Angle&MD TD AaSki8 BIC. Wellbore API/UWI Field Name Wellbore Status incl(°) MD(ftKB) Act Btm(ftKB) Canoco?fdlbps 500292322361 WEST SAK INJ 92.81 11,654.82 12,435.0 ... Comment H2S(ppm) Date (Annotation End Date KB-Grd(ft) -Rig Release Date 1E-114L2,9/]201710:27:58 AM SSSV:NIPPLE ]Last WO. 31.52 10/26/2004 Vertical echhornatic.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER.,22.2 ,.,e Last Tag: Rev Reason:MARCIT JOB see NOTES pproven 9/6/2017 ■� 4 i� 3 Casing Sings I Casng Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER L2 41/2 3.958 7,463.2 11,809.6 3,539.6 12.60 L-80 DWC Liner Details CONDUCTOR;31.0-108.0 NIPPLE;522.3 " Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com Nominal ID _ (in) 7,463.2 3,489.3 77.50 HANGER D-SAND BAKER MODEL B1 FLANGED HOOK 4.500 HANGER ,i , i '� 11,771.9 3,541.1 92.26 BUSHING D-SAND DRILLABLE PACK-OFF BUSHING 3.958 SURFACE;29.9-4,197.7— . 11,788.2 3,540.5' 92.32 XO Reducing CROSSOVER 4.5 x 3.5 3.500 GAS LIFT;4,476.9 Perforations&Slots GAS LIFT;7,069.9 A Shot Dens Top(TVD) Min(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com ^ SLEEVE-C;7,370.0 7,490.0 11,738.0 3494.5 3,542.4 WS D,1E- 10/23/2004 40.0 SLOTS 114L2 LOCATOR,7,418.0 Notes:General&Safety SEAL ASSY,7,419.7 End Date Annotation 10/26/2004 NOTE:TRI-LATERAL WELL 1E-114(A-SAND)1E-114L1(B-SAND)1E-114L2(D-SAND) SLEEVE,7,457.02/16/2011 NOTE:View Schematic w/Alaska Schematic9.0REV WINDOW L2;7,465.0-7,477.01 PRODUCTION;26.9-8,736.0 I 7/27/2012 NOTE:PROFILE MODIFICATION-PUMPED 1320 LBS(4MM)CRYSTAL SEAL @ 4200'TARGETING'B'MBE D LINER LEM;7,414.1-7,763.2 8/14/2017 NOTE:MARCIT Treatment was pumped to D MBE. r t 8- 1 1 1 1 [ 1 SLOTS;7,490.0-11,738.0 1 1 1 4 z f 7... [ 1.R LINER L2;7,463.2-11,809.6 • • OF T4 ,w\8Iyy„'"sA THE STATE Alaska Oil and Gas ALAsKAConservat1on Commission 333 West Seventh Avenue rte _ Anchorage, Alaska 99501-3572 'wtw, GOVERNOR BILL WALKER g 7 Main: 907.279.1433 O4'4%.1 Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer SCAM , NEC `-' =i ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool,KRU 1E-114L2 Permit to Drill Number: 204-173 Sundry Number: 317-232 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair 44— DATED this /Z day of June,2017. RBDMS VKUN 1 3 2017 • 0 • RECEIVED STATE OF ALASKA JUN 0 6 ALASKA OIL AND GAS CONSERVATION COMMISSION JUNi)r6J)201724 17 APPLICATION FOR SUNDRY APPROVALS A0 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 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: MARCIT GEL MBJ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 204-173 ' . 3.Address: Stratigraphic ❑ Service 2, 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-029-23223-61 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1E-114L2 • Will planned perforations require a spacing exception? Yes ❑ No 0 I 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651 , 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 ND: MPSP(psi): Plugs(MD): Junk(MD): 11,833' 3,539' ` 11833 3539 . 1480 NONE NONE Casing Length Size MD ND Burst Collapse Conductor 77' 20" 108' 108' Surface 4,168' 10 3/4 4,198' 2,296' Production 7,450' 7 5/8 7,477' 3,725' Liner 4,346' 41/2 11,810' 3,540' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7490-11738 3494-3542 4.500" L-80 7,446' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER=ZXP Liner Top Packer ` 7414 MD,3478 ND PACKER=ZXP Liner Top Packer ' 7732 MD,3548 TVD PACKER=HRD ZXP Liner Top Packer + 8570 MD,3697 ND SSSV: =NONE N/A 12.Attachments: Proposal Summary D Wellbore schematic D 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic❑ Development❑ Service 2 • 14.Estimated Date for 6/1/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ 2 ' WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@conocophillips.com ‘/S�� Contact Phone: (907)265-6471 Authorized Signature: !/ Date: 7 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 \-7 - 23Z Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 ,f- c-. C. (C211- Other: Post Initial Injection MIT Req'd? Yes ❑ No I21/ 6 Spacing Exception Required? Yes ❑ No Ri Subsequent Form Required: /0 --- 'l O /- RBDMS G t�/ JUN 1 3 2017 APPROVED BY Approved by: ,.?"-e... .--- COMMISSIONER THE COMMISSION Dater,/Z•_I 7 fm 6i� l? � - TZ(o N-7-Form 10-403 Revised 4/2017 Gdp+A Submit Form and Lalid for 12 months from the date of approval. Attachments in Duplicate KUP 11E-1141_2 CIonocaPhillips Well Attribute MaxAngle D TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btrn(ftKB) CanoccPFlilli.. 500292322361 WEST SAK INJ 92.81 11,654.82 12,435.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-1141_2.5/23/20173:52:07 PM SSSV:NIPPLE Last WO: 31.52 10/26/2004 Vertical a hemeto(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER 222 6sAimLast Tag: Rev Reason:RESET ISO SLV,SET DIVERTER hipshkf 7/10/2015 ■s ■ ..e...r,,.,,,,,,,,,,,,,,,,,,,,,,.....,,, 11_ irk' Casing Strings II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TV3D0L. Wt/Len p...Grade Top Thread �1J .;I LINER I Liner LDetails I 41/21 3.9581 7,463.21 11,809.61 3,539.61 12601 L-80 IDWC CONDUCTOR.31.0-108.0 1: '11111 Nominal ID NIPPLE.571.3 — Top(ftKB) Top(TVD)(ftKB) Top Incl() Item Des Com (in) 7,463.2 3,489.3 77.50 HANGER D-SAND BAKER MODEL B1 FLANGED HOOK 4.500 1 1 HANGER 11,771.9 SURFACE;291-4,197.7---43,541.1 92.26 BUSHING D-SAND DRILLABLE PACK-OFF BUSHING 3.958 11,788.2 3,540.5 92.32 XO Reducing CROSSOVER 4.5 x 3.5 3.500 GAS LIFT;4,476.9 rill Perforations&Slots GAS LIFT;7,069.9 . dens ITop(TVD) Btu)(TVD) (shots/ SLEEVE-C;7,370.0 �'I Top(ftKB) Btu)(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com N 7,490.0 11,738.0 3,494.5 3,542.4 WS D,1E- 10/23/2004 40.0 SLOTS 1141_2 LOCATOR;7,418.0 31EMBI Notes:General&Safety SEAL ASSY;7,419.7 End Date Annotation 10/26/2004 NOTE:TRI-LATERAL WELL 1E-114(A-SAND)1E-1141_1(B-SAND)1E-114L2(D-SAND) SLEEVE;7,4570 i1 1 2/16/2011 NOTE:View Schematic w/Alaska Schematic9.0REV WINDOW L2,7,465.0-7,477 0 1� PRODUCTION;26.94,736.0 �e [it' 7/27/2012 NOTE:PROFILE MODIFICATION-PUMPED 1320 LBS(4MM)CRYSTAL SEAL @ 4200'TARGETING'B'MBE D LINER LEM;7,414.1-7,783.2 fa - 1 4.' -4 1 :--- i i 11 j t 4 i ; i -} 4I 4 1 ) -t SLOTS;7,490.0-11,738.0 1 I ll 4 L 11- _ 1 i. --H- i - 1 t 4- 4 I- 1 I ii i mi LINER 1_2;7,463.2-11,809.6 Ri KUP a 1E-114 GOn©coPhMips a Well Attribut711. Max Angla TD A! Ska,Inc Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Conoco6Ylghps 500292322300 WEST SAK INJ 95.10 9,632.41 12,607.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-114,5/2412017714.56 AM SSSV:NIPPLE Last WO: 31.52 10/26/2004 Verncal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,2z.z Last Tag: Rev Reason:SET ISO SLV,PULLED pproven 12/5/2016 �1. DIVERTER ir iI Casing Strings •LL'••••'•SPLA'•• "•' A•"••'•A' 0,116 19111 '. surf Descnption OD(in) •ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread CONDUCTOR _ 20. 19.124 31.0 108.0 108.0 94.00 K-55 WELDED Casing Description OD(in) LID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • SURFACE 103/4 10.050 29.9 4,197.7 2,296.4 40.50 L-80 BTC -"-/ wwDwUCwOw 3w0w0w0 1 .--Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE;522.3 WINDOW L1 7.65 6.625 7,778.0 7,790.0 3,559.4 29.70 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread O WINDOW L2 75/8 6.625 7,465.0 7,477.0 3,492.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade 'Top Thread I PRODUCTION 75/8 6.875 26.9 8,736.0 3,725.2 29.70 L-80 BTCM SURFACE;29.9-4,197.7 Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) -Set Depth(TVD)...'Wt/Len g...Grade 'Top Thread D LINER LEM 41/2 3.958 7,414.1 7,763.2 3,554.0 12.60 L-80 IBT GAS LIFT;4,476.9 • Liner Details Nominal ID GAS LIFT;70699 Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) AL 7,414.1 3,478.5 77.13 PACKER ZXP LINER TOP PACKER 4.960 IMO SLEEVE-C;7,3700 7,433.1 . 3,482.7 77.29 SBE 109-47 SEAL BORE RECEPTICLE 4.750 Nil 7,451.9 3,486.8 77.45 XO BUSHING CROSSOVER BUSHING 3.930 7,457.1 3,488.0 77.50 HANGER LEM ABOVE HOOK HANGER 3.930 LOCATOR;7,418.0 . 7,463.2 3,489.3 77.50 HANGER LEM INSIDE HOOK HANGER 3.688 SEAL ASSY;7,419.7 �_ 7,760.0 3,553.3 78.04 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread B LINER LEM I 4 1/21 3.9581 7,732.4 8,617.91 3,705.11 12.601 L-80 IBT SLEEVE;7,4570` ..171 if Liner Details WINDOW L2;7,465.0-7,4770 'ht LINER L2;7,483.2-11,809.61 (I� '1 Nominal ID '.` L. Top(ftKB) Top(TVD)(ftKB) Top Incl CI Item Des Com (in) �1 7,732.4 3,547.5 77.68 PACKER ZXP LINER TOP PACKER 4.960 7,751.4 3,551.5 77.90 SBE '109-47 SEAL BORE RECEPTICLE 4.750 7,770.3 3,555.5 78.21 XO BUSHING 'CROSSOVER BUSHING 3.930 7,771.7 3,555.8 78.23 SWIVEL 'BAKER CASING SWIVEL 3.920 D LINER LEM;7,414.1-7,763.2 .. _ + 7,778.0 3,557.0 78.34 HANGER 1 LEM ABOVE HOOK HANGER 3.930 7,784.1 3,558.3 78.44 HANGER 2 'LEM INSIDE HOOK HANGER 3.688 p?, 7,849.7 3,570.8 79.32 NIPPLE CAMCO DB-6 NIPPLE 3.562 WINDOW LI;7,778.0-7.790.D, 1171 8,614.6 3,704.5 79.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 SLEEVE;7,781.1 I Casing Description LINER 1 OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WULen(I...Grade Top Thread 4 1/21 3.9581 8,569.51 11,856.21 3,788.21 12.601L-80 DWC SLOTS;7,802.011,243.0 ' Liner Details -'- ' Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID LINER LI;7,776.8-11,808,4 I 8,569.5 3,696.6 79.89 PACKER 'HRD ZXP LINER TOP PACKER 5.500 (PERF;8,186.08.193.0 8,588.6 3,699.9 79.90 NIPPLE 'RS PACKOFF SEAL NIPPLE 3.958 FISH;8,281.0 8,591.4 3,700.4 79.89 HANGER 'FLEXLOCK LINER HANGER 5.500 - 8,601.2 3,702.1 L 79.87 SBE '190-47 CASING SEAL BORE EXTENSION 4.750 " 11,822.9 3,784.8 84.28 BUSHING BAKER DRILLABLE PACKOFF BUSHING 3.958 Tubing Strings 1I/I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection B LINER LEM;7,732.4-8,6179 I,.-- TUBING 4 1/2 3.958 22.2 7,446.3 3,485.6 12.60 L-80 IBTM Completion Details Nominal ID PRODUCTION;26.9-8,738.0 i Top(ftKB) Top(ND)(ftKB) Top Incl y) Item Des Com (In) SLOTS;8.781.0-8,903.0 7T 222 222 0.00 HANGER VETCO GRAY TUBING HANGER 3.958 y 522.3 520.9 10.78 NIPPLE CAMCO DB-6 NIPPLE w/NO GO PROFILE 3.875 SLOTS;9,027.09.089.0 7,370.0 3,468.6 76.75 SLEEVE-C BAKER CMU SLIDING SLEEVE-CLOSED 11/1/2004 3.810 7,418.0 3,479.4 77.16 LOCATOR BAKER LOCATOR 3.875 7,419.7 3,479.8 77.18 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 SLOTS,9.1200-9,450.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 1 1 r! Top(ftKB) (ftKTop(ND) Top Incl B) r) Des Com Run Date ID(in) 7,457.0 3,487.9 77.50 SLEEVE TYPE-II ISOLATION SLEEV IN D-SAND LEM 11/29/2016 2.580 SLOTS;9,576.0-9,602.5 i I 7,784.1 3,558.3 78.44 SLEEVE TYPE 1 ISO SLEEVE SET IN B-LEM INSIDE HOOK 11/29/2013 2.750 HANGER sl-oTS,9,909.0-10,160.°--- ,9o9.a1o,lso.D i , _ 8,261.0 3,642.8 80.17 FISH 3"BAKER IBP @ 8261'CTMD IN B-LATERAL 10/1/2010 0.000 SLOTS;10.191.010,358.0 -I} Perforations Slots _ Shot ~ SLOTS;10,482.010,524.0 Dens Top(ND) Btm(ND) (shots/ SLOTS;10,555.0-10,597.0-.41 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,188.0 8,193.0 3,630.4 3,631.3 WS A4,1E- '7/23/2012 (PERF Perforations to inject 114L1 Crystal Seal in B LINER SLOTS;10,627.0-10,669.41 FAILED! 8,781.0 8,903.0 3,731.4 3,743.8 WS A2,1E- 10/8/2004 40.0 SLOTS Alternating solid/slotted SLOTS;10,700.0.10,742.0 L 114 pipe-0.125'x2.5"@ 4 circumferential adjacent rows,3"centers SLOTS;10.805.011,095.0 4 Ir staggered 18 deg,3'non -slotted ends 9,027.0 9,089.0 3,753.0 3,756.2 WS A2,1E- 10/8/2004 40.0 SLOTS 114 9,120.0 9,450.0 3,757.0 3,751.1 WS A2,1E- 10/8/2004 40.0 SLOTS SLOTS;11,321.0-11,6549-1� r 114 1 r9,576.0 9,660.0 3,741.3 3,734.2 WS A2,1E- 10/8/2004 40.0 SLOTS 11i 4 SLOTS;117169-11,789.0 1r" 9,909.0 10,160.0 3,735.8 3,752.0 WS A2,1E- 10/8/2004 40.0 SLOTS 114 IM LINER;8,569.5-11,856.2- 1 1 • go& KUP III 1E-114 .Conoc©Phillips Alaska.ino, C OCCPhINcps ...•• 1 E-114,5/24/2017 7:14:56 AM Vertical echemac(actual) HANGER,22.2 =.�,,,•:!:■ SII IlL Perforations&Slots ai r Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (MB) (RKB) Zone Date R) Type Com '^'�CONDUCTOR;31.0-108.0 III 10,191.0 10,358.0 3,754.0 3,762.8 WS A2,1E- 10/8/2004 40.0 SLOTS NIPPLE;522.3 ! 114 10,482.0 10,524.0 3,768.3 3,769.3 WS A2,1E- 10/8/2004 40.0 SLOTS 114 I 10,555.0 10,597.0 3,769.6 3,769.3 WS A2,1E- 10/8/2004 40.0 SLOTS SURFACE;29.94,197.7 114 10,627.0 10,669.0 3,769.0 3,768.5 WS A2,1E- 10/8/2004 40.0 SLOTS GAS LIFT;4,476.9 114 ak 10,700.0 10,742.0 3,767.9 3,766.7 WS A2,1E- 10/8/2004 40.0 SLOTS ME GAS LIFT;7,089.9 ii ; 114 10,805.0 11,095.0 3,763.9 3,746.6 WS A2,1E- 10/8/2004 40.0 SLOTS 114 SLEEVE-C;7,370.0 1 11,321.0 11,654.0 3,748.1 3,769.7 WS A2,1E- 10/8/2004 40.0 SLOTS 114 LOCATOR;7,418.0 8imiii. 11,716.0 11,789.0 3,774.6 3,781.5 WS A2,1E- 10/8/2004 40.0 SLOTS SEAL ASSY;7,419.7 114 a Mandrel Inserts St ah SLEEVE;7,457.0` 11 i on Top(TVD) Valve Latch Port Site TRO Run WINDOW L2;7,465.07,477.0 III ( N LINER L2;7,483.2-11,809.6 �'ITop(RKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com ` i • • 0.000 11 11 12 7,069.9 3,389 6 CAMCO • 0.000 11 11 Notes:General&Safety _ _ End Date Annotation ?EMI 1 11• • • • • D LINER LEM;7,414.1-7,783.2 -- 2/16/2011 NOTE:View Schematic w/Alaska Schematic9.0REV ¢¢ / • PROFILE •• • • 1 11 'TARGETING'B'MBE ft WINDOW L1;7,778 0-7,790.0, 4.1 ( SLEEVE;7,784.1 SII SLOTS;7,802.0-11,243.0 LINER LI;7,776.8-11,808.4 `t 1 (PERF;8,188.08,193.0 FISH;8,261 0 I � B LINER LEM;7,732.4-8,617.9 4 I 4 PRODUCTION;26.9-0,738.0 SLOTS;8,781.0-0,903.0 SLOTS;9,027.0-9,089.0 4 1- SLOTS;9,120.09,450.0 3 1 SLOTS;9,576.09,660.0 j Li I SLOTS; -1' r SLOTS;10,191.010,358.0 SLOTS;10,482.0-10,524.0 SLOTS;10,555.0-10,597.0 r- 4- SLOTS; 4- SLOTS;10,627.0-10,689.0 SLOTS;10,700.0-10.742.0 1. E SLOTS;10,805.011,095.0 4 ] .-..... SLOTS,11,321 0-11,054 0 r SLOTS;11,716.0-11,789.0 LINER;8,559.5-11,858.2 • • Proposal 1E-114L2 to 1E-168L2 D MBE Treatment with MARCIT Gel 1 E-114 tri-lateral injector is completed in West Sak A, B, and D sands. This well has 4-1/2", L-80 tubing and 1E-114L2 lateral contains 4-1/2" L-80 slotted liner. A Matrix Bypass Event (MBE) occurred December 2013 in 1E-114 while the B lateral was isolated with an Iso-Sly. An (PROF was run 5/12/15, that indicated the B lateral was isolated. Thus, it was suspected that a D MBE must have existed. On 7/9/15, a D Diverter was set and a D lateral IPROF was logged, which indicated that a D MBE existed at -7475' RKB just below the D LEM. On 11/29/16, the D Diverter was pulled and a D Iso-Sly was set to return 1D-114 BOI to A sand only. On 1/30/17, a Water Flow log was run which verified that 100% of PWI was entereing the A sand lateral. No other wellwork has been performed since this log run. It is now proposed that a fullbore MARCIT Gel job be pumped to seal off 1E-114L2 D MBE at 7475' RKB. A similar MARCIT MBE treatment of 10/13/16 on 1J-102 continues to be successful. Proposed Procedure: Coil Tubing: 1) RIH & pull D Iso-Sly from D LEM at 7472' RKB. 2) RIH & pull B Iso-Sly from B LEM at 7770' RKB. 3) RIH & set DB Plug in 3.562" DB Nipple at 7850' RKB. 4) RIH & set B Iso-Sly across B LEM at 7770' RKB. 5) RIH & set D Diverter in D LEM at 7472' RKB. Fullbore Pumping: 6) MIRU MARCIT Gel pumping equipment to perform a fullbore MARCIT Gel job down 4.5" Tubing to the D MBE assuming that the MBE volume is -50 bbls in volume while monitoring the treating pressure response in 1E-168 producer. This treatment assumes the D MBE is 1500' OAL x 6" diameter (-50 bbls), and that near perfect displacement of the Crosslinked Accelerated MARCIT Gel is possible to the MBE. Pump the job as follows: Inject -20 bbls Uncrosslinked Linear Gel (Pre-Flush), followed by -50 bbls of Crosslinked Accelerated Viscosity MARCIT, followed by 20 bbls Linear Gel displacement, followed by 26 bbls Seawater, followed by 68 bbls Diesel to FP to 2400' TVD, followed by Shutdown to complete the full displacement of all Accelerated MARCIT Gel into the D MBE. Leave the well SI for at least 5 days to let the treatment cure. Coil Tubing: 7) RIH with Jet Swirl Nozzle to jet through excess MARCIT Gel left in the D lateral liner to as deep as possible jetting Seawater. POOH & FP with Diesel. RD. 8) Run a post-MBE treatment memory IPROF in D lateral to verify D MBE is sealed. Return 1 E-114L2 to PWI service to D sand only to evaluate results of the D MBE treatment prior to treating the B lateral MBE or reopening the A lateral to PWI. JWP 6/5/2017 Zo it 3 2...G011WELL LOG TRANSMIT AL PROACTIVE DIAGNOSTIC SERVICES, INC. DATA LOGGED %/5/2015 K BENDER To: AOGCC Makana Bender R E C:E ` ( P 333 West 7th Avenue Suite 100 AUG 0 4 220113 Anchorage, Alaska 99501 (907) 793-1225 AOGCC RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 icAEV 1) Injection Profile 09-Jul-15 1E-114 L2 Color Log /CD 50-029-23223-61 2) Signed : / 2'424TJ' '5 �� Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(aMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Ach,ves\MasterTemplateFdes\Templates\Distribution\TransmdtalSheets\ConocoPhdhps_Transmit docx · . 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 file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O 4- - 1 7-.3 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: to 1 (Count does ;nctude cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date: 1I/30/Db Organizing (done) D Two-sided 1111111111111111111 REj-CAN \Ø" Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: Date ~ 1/ 3D / 0 b BY: ~ Project Proofing Date 11/30/D0 bl x 30 = (p 0 + Date 1//30/0 ftJ BY: ~ Scanning Preparation BY: C Maria) BY: Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed II 11111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: mP 151 11111111I11111 "III 151 VV1P <Q = TOTAL PAGES fo 7f (Count does not include cover sheet) '^ J\ P 151 I V . 11I11111111111 "III 151 NO Mf YES NO 151 111111/1111I111111I 11111111111111 "III 151 Quality Checked 111111111111 1111111 1016/2005 Well History File Cover Page.doc • • .lntiP.3`:5. a ~. :~~~ "' MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc ;< ~ IU\,¡ J ~~Á DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041730 Well Name/No. KUPARUK RIV U WSAK 1E-114L2 Operator CONOCOPHILLlPS ALASKA INC )f/({¿ 19ót~'f API No. 50-029-23223-61-00 MD 11833 ....... TVD 3539..........· Completion Date 10/26/2004 .,...--. Completion Status 1-01L Current Status 1WINJ ~ REQUIRED INFORMATION Name Interval Start Stop Samples No Directional surve~ (data taken from Logs Portion of Master Well Data Maint . Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 7465 11833 Open 11115/2004 25 Slu 108 11833 Open 5/1812005 RWD, MULTIPLE PROPAGATION RESISTIVITY, GR 25 Slu 108 11833 Open 5/18/2005 RWD, MULTIPLE PROPAGATION RESISTIVITY, GR 25 108 11833 Open 5/1812005 RWD, MULTIPLE PROPAGATION RESISTIVITY, GR 108 11833 Open 5/18/2005 RWD, MULTIPLE PROPAGATION RESISTIVITY, GR Sample . Set Sent Received Number Comments Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: Logl Data Type Rpt Á Electr Digital Dataset Med/Frmt Number Name Directional Survey Induction/Resistivity 13121 ~g 13121 Induction/Resistivity 4" 13121 LIS Verification ~ C ....;:f L..I ~ 13121 Induction/Resistivity Well CoreslSamples Information: ADDITIONAL INFORMATION Well Cored? e Chips Received? Y /1\1 - Daily History Received? ØN ð/N Formation Tops Analysis Received? ::t.J.J;V- Comments: Permit to Drill 2041730 MD 11833 TVD 3539 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Well NamelNo. KUPARUK RIV U WSAK 1E-114L2 Operator CONOCOPHILLIPS ALASKA INC Completion Date 10/26/2004 Completion Status 1-01L Current Status 1WINJ ~ Date: API No. 50-029-23223-61-00 UIC Y '8 ~Ov ~ð~ \ø . . UPDATE: LPP Variance for West Sak injection welllE-114 (PTD... . . Subject: UPDATE: LPP Variance for West Sak injection welllE-114 (PTD 2041710) From: NSK Problem Well Supv <nI617@conocophillips.com> ~. è>C'-\ -\"'\ J.- Date: Mon, 27 Jun 200506:46:56 -0800 .;>o~ - \'""- ~ To: Thomas Maunder <tom_maunder@admin.state.akus>, James Regg <jim_regg@admin.state.akus> CC: AOGCC North Slope Office <aogccyrudhoe_bay@admin.state.akus> Tom & Jim, 1E-114 West Sak injector has built sufficient wellhead pressure to set a LPP. The LPP was place back in service last week. Please let me know if you have any questions. Marie McConnell ConocoPhi 11 ips Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Wednesday, May 18, 2005 5:30 AM To: 'Thomas Maunder'; Dethlefs, Jerry C; 'James Regg' Cc: AOGCC North Slope Office; NSK Problem Well Supv Subject: RE: FW: LPP Variance for West Sak injection well 1E-114 (PTD 2041710) Tom, 1E-114 (PTD 2041710) was brought on line May 7th and passed the initial MITIA yesterday, witnessed by State Inspector, Jeff Jones. The well is still in the process of "fill up" and tubing continues to operate on a vacuum. The variance to gag the LPP expires on 5-20-05. ConocoPhillips requests approval to extend the gagged pilot approval for an additional 30 days to expire on 6/20/05 or when the surface pressure increase to a level that a LPP can be put in service. Please let us know if this is acceptable. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, April 20, 2005 10:43 AM To: Dethlefs, Jerry C Cc: AOGCC North Slope Office Subject: Re: FW: LPP Variance for West Sak injection well 1E-114 (PTD 2041710) Jerry, Given the low surface injection pressure, it is acceptable to "gag" the LPP on 1E-114. Please make sure your operators have a copy of this message. Tom Maunder, PE AOGCC Dethlefs, Jerry C wrote: Tom: West Sak injector 1E-114 will be ready for injection later today--can I assume you approve the variance for having the LPP gagged for up to 30 days? The other issues we discussed can wait, but the 10f5 6/27/20058:37 AM UPDATE: LPP Variance for West Sak injection welllE-114 (PTD... . 20f5 . well is almost ready to put on line. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] *Sent:* Wednesday, April 20, 2005 7:27 AM *To:* Dethlefs, Jerry C *Cc:* jim regg@aàmin.state.ak.us; NSK Problem Well Supv *Subject:* Re: FW: LPP Variance for West Sak injection well 1E-114 (PTD 2041710) Good reasoning as to needing something "on paper". Lets talk later today. Tom Dethlefs, Jerry C wrote: Tom: Yes, the subject wells at West Sak are all water injectors--and you are right, we do not perform a State SVS test on these wells. However, we have found it prudent to strive to meet all the regulatory requirements that apply to our areas of operations, especially these days when we are under sufficient scrutiny that we could be found doing something wrong somewhere at anyone particular point in time. The issue here is that the pool rules (Conservation Order #406B, Rule 6, section b) state we either need dual check valves or a single check and fail safe SSV. We do not have dual checks, but do have a single check and fail safe SSV. If the LPP is gagged we have defeated the SSV and so will be out of compliance. We are not going to risk an NOV for lack of approval to gag the LPP. The requests we have been making are for an exemption from the Pool Rules I mentioned above. This is why I suggested we could specify some conditions for a mutually agreeable plan so we can just manage these situations as they come up rather than having to bother you each time on a well by well basis. We need to have something documented in our hand that shows we can deviate (with approval) from the Pool Rules should certain conditions exist (like insufficient wellhead pressure). Let me know your thoughts on this. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] *Sent:* Tuesday, April 19, 2005 4:08 PM *To:* NSK Problem Well Supv *Subject:* Re: LPP Variance for West Sak injection well 1E-114 (PTD 2041710) Jerry, I thought I sent a response back regarding the settings at Alpine. These WS wells are water injectors aren't they?? I am not sure how all of this works, but to my memory we don't test SSVs on water injectors do we?? MI for sure, but not water and in WS there are only a few wells approved for MI and they are on 1C and 1D. Let me know your thoughts on this and I will talk to Jim as well, but this may be something we don't need to be looking at. Just my thought for now, subject to change after discussion. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: 6/27/20058:37 AM UPDATE: LPP Variance for West Sak injection welllE-114 (PTD ... . service. 30f5 . Tom: The following is a request from Operations to operate West Sak injection well 1E-114 with a gagged low pressure pilot. The request is for a period not to exceed 30 days. This is similar to the previous approvals we have requested for the startup of West Sak injectors recently. The Production Engineers believe the reservoir will charge up over time and that these wells will eventually behave with sufficiently high tubing pressure to return to normal LPP protected service. Please let me know if you concur with our plan. Secondly, the previous email is from a discussion we started last week. Rather than ask for approval for these various situations each time they occur, is it feasible to agree on a set of rules so that the concerns of your agency and our company are met without approval on a well by well basis? CPAI could submit a written document with a proposal on how to manage these issues, and if the AOGCC concurs we could be in business. Let me know your thoughts on this approach as well. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 We are requesting a temporary variance for 1E-114 (PTD 2041710) from Conservation Order #406B, Rule 6, section b which requires a SSVs for water injection well to operate. A temporary variance to operate 1E-114 water injection wells with a defeated SSV pilot and without a 24 hr man watch for a maximum of 30 days is requested. Based on previously pre-produced West Sak injectors, this well will be injecting on a vacuum and the SSV low pressure pilot will not be placed in service at this time. This will be the initial injection for 1E-114 and once an established tubing pressure of 300 psi has been reached the SSV pilot will be placed back in working Thanks, *Peter Nezaticky* / Marie McConnell ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 -----Original Message----- *From:* NSK Problem Well Supv *Sent:* Wednesday, April 13, 2005 4:32 PM *To:* 'Thomas Maunder' *Cc:* NSK Problem Well Supv; jim reg9@admin.state.ak.us *Subject:* RE: LPP Settings for Alpine and West Sak Tom: It would be nice to have a "general rule" or exemption that would apply to all of Alpine when we have this problem. For that matter, it would be nice for West Sak too, for these new injectors with low reservoir pressure. The problem is that not long ago we received approval from your agency to establish 1800 psi as the benchmark LPP setting for gas injectors at Alpine. This has worked out OK until the situation with CD1-06 and 14 (see injection pressure below). These wells are expected to eventually pressure up until they are similar to the others on the pad, however they are not high enough now to use 1800 psi or they will shut-in. Rather than risk another NOV for gagging the LPP we have instead asked for approval to set lower than the 1800 psi guideline. We could make it easier on us both if we agreed on a process to adjust these as needed until they have reached full injection pressure. I don't have a good feeling how 6/27/20058:37 AM UPDATE: LPP Variance for West Sak injection we11IE-114 (PTD... . 40f5 . long that may be--it could be weeks or months. These pilots are easy to change and set since it is largely a software issue, so they can be changed up as needed. If you are willing, I could propose that we just manage this internally until a well reaches it's maximum pressure at which time the standard 1800 psi would apply. For instance, we could say that the LPP must not be set lower than 200 psi below the average daily injection pressure until the injection pressure has reached the mature state. Of course we could document each well that has this problem so that the records could be provided to the Inspector when needed. That would allow us to keep these wells in service without nuisance trips and still provide protection in the case of a release. Should you agree to this type of approval we can formalize it in a letter to your agency. I mentioned earlier the problem with West Sak injectors--our new wells have very low injection pressure and cannot operate with our standard LPP in place of about 700 psi. The injection pressure can be as low as 100 psi on injection and will be vacuum if shut-in. That is the reason for the couple requests recently for a variance to run gagged. We have another (lE-114) that will be on soon that is expected to be near vacuum. I remember years ago when I was at Prudhoe EOA that the water injectors would go on vacuum when shut-in so they were always operated with the LPP gagged. How is that handled with your agency? Is it possible we can do what I proposed above for these cases too? The expectation is with time the injection pressure will increase and a LPP can be used, but initially it is not possible. I am very interested on your opinion on this and if my proposal is something you will consider. As long as we have an agreement in place on how to handle these situations, we can manage it without asking for your approval on a well by well basis. Drop me a line when you have time to review this. I go out tomorrow and MJ will be here, but she can carryon with the issue. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- *From:* Thomas Maunder :tom maunder@admin.state.ak.us] *Sent:* Wednesday, April 13, 2005 3:40 PM *To:* NSK Problem Well Supv *Cc:* jim regg@admin.state.ak.us *Subject:* Re: LPP Setting for Alpine CD1-06 Jerry, Jim and I have discussed this matter. Does it make more sense have you all request a low pressure trip pressure for each pad rather than addressing it on a well by well basis? We are in agreement to have a setting to avoid the nuisance trips. Is this only something encountered when a pattern has low pressure?? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom: Alpine Operations has asked me to seek approval to temporarily reduce the LPP set point from 1800 psi to 1600 psi on MI injection well CD1-06. The injection pressure has been averaging just barely over 1800 psi, so any bobbles may shut-in the well. The following note is from the Alpine Lead Operator with more explanation: Now that we have put all the gas down CD1-06 instead of splitting it with CDl-14, the tubing pressure of 6/27/20058:37 AM UPDATE: LPP Variance for West Sak injection welllE-114 (PTD... . . CD1-06 is coming back up slowly. We would like to lower this trip point to 1600 # until we get some room. Do you think we can do this and then we can raise it in 6 months if the formation pressures back up. This well is also our black start Fuel Gas supply well. If we need to operate off this well for very long we would have the Low pressure trip by-passed with a setting of 1800 # that it has now. At 1600 # setting the by-pass would not be used. Rick Alexander 4220 With your approval we will reduce the LPP set point until such time that the tubing pressure increases to a point it can be reset at 1800 psi without nuisance trips. Thanks for your attention on this. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 50f5 6/27/20058:37 AM . . î:- l:: STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI0N83}it1 .J"U·N (fì, "'" ·znOI1 tL ~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKS 95' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 5. Permit to Drill Number: 204-173 6. API Number: 50-029-23223-61 9. Well Name and Number: 1 E-114l2 10. Field/Pool(s): Kuparuk River Field I West Sak Oil Pool Total Depth measured 11833' feet true vertical 3539' feet Effective Depth measured 11771 feet true vertical 6276' feet Casing Length Size MD Structural CONDUCTOR 108' 20" 108' SURFACE (45.5 ( 4102' 10-314" 4197' INTERMEDIATE 8641' 7-5/8" 8736' WINDOW 12' 7-5/8" 7477' LINER D-SAND 4346' 4-1/2" 11809' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2295' 3725' 3492' Perforation depth: Measured depth: 7490-11738 true vertical depth: 3494-3542 Tubing (size, grade. and measured depth) 4-1/2" , L-80, 7446' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIPPLE SSSV= 522' Form 10-404 Revised 04/2004 Submit Original Only Date Event Summary . . 1E-114L2 DESCRIPTION OF WORK COMPLETED SUMMARY 4/20/200SCommenced Water Injection . . R'" v' .\ f- ,';Z:~j' (.'\~,!",{, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATfðft§l ¿fi JUN 03' 2005 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 95' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 5. Permit to Drill Number: 204-173 6. API Number: 50-029-23223-61 9. Well Name and Number: 1E-114L2 10. FieldlPool(s): Kuparuk River Field I West Sak Oil Pool Total Depth measured 11833' feet true vertical 3539' feet Effective Depth measured 11771 feet true vertical 6276' feet Casing Length Size MD Structural CONDUCTOR 108' 20" 108' SURFACE (45.5 ( 4102' 10-3/4" 4197' INTERMEDIATE 8641' 7-5/8" 8736' WINDOW 12' 7-5/8" 7477' LINER D-SAND 4346' 4-1/2" 11809' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2295' 3725' 3492' Perforation depth: Measured depth: 7490-11738 RBDMS SF' .., . ~" ,U¡V 0 (; 200S true vertical depth: 3494-3542 Tubing (size, grade, and measured depth) 4-1/2' , L-80, 7446' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIPPLE SSSV= 522' Form 10-404 Revised 04/2004 '~ I L Submit Original Only . 1E-114L2 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 4/20/200SCommenced Wtaer Injection Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28',88' AMSL 8. Property Designation: ALK 25651, ADL 469 11. Present Well Condition Summary: .~- 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE INTERMEDIATE LINER - A SAND Perforation depth: . STATE OF ALASKA . RECEIVED ALASKA OILAND GAS CONSERVATION COMMISSION APR 1 3 Z005 REPORT OF SUNDRY WELL OPERATIONS Ala5ka Oil ~~6Cb C(¡n6r.--\t '~ljnlll:¡:¡ltU!lt. Ö er ~ Convert 0 nector nChOr8f;19---, Time Extension ~ U Abandon D Alter Casing D Repair Well D Pull Tubing D Opera!. ShutdownD Re-enter Suspended Well D Plug Perforations D Perforate New Pool D Stimulate D Waiver D Perforate D 4. Current Well Status: Development D Stratigraphic D Exploratory Service D o 5. Permit to Drill Number: 204-1731305-013 6. API Number: 50-029-23223-61 9. Well Name and Number: 1 E-114L2 10. FieldIPool(s): Kuparuk River Field / West Sak Oil Pool measured 11833' feet true vertical 3539' feet measured 11771 ' feet true vertical 3541' feet Length Size MD 108' 20" 108' 4169' 10-3/4 " 4198' 8708' 7-518" 8736' 4347' 4-1/2" 11810' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2295' 3725' 3540' Measured depth: slotted liner true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7446' MD. Packers & SSSV (type & measured depth) pkr @ 8570' SSSV= Landing Nipple 522' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation Pre-produced Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD Gas D WAG D GINJ D WINJ 0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Gary Targac @ 265-6586 Printed Name Randy Thomas Signature ~~ Form 10-404 Rev;"" 0412004 R/9fl1rj /2 J Title Phone Kuparuk Drilling Team Leader Phone: 265-6830 Date ..../~t ~~o.s Preoared bv Sharon AI/suo-Drake 263-4612 C; II\J A L Submit Original Only . .- .. . . 1E-114 Well Events Summary . Date Summary 04/01/05 GAUGED TBG TO 2087' SLM WITH 3.8" GAUGE RING. ENCOUNTERED HYDRATES. IN PROGRESS. [Hydrates-Ice] 04/02/05 CLEAR HYDRATES WITH METHANOL, BRUSH, & G/R. GAUGED TBG TO 3.83" TO 7370' RKB. SET 3.812" DB PLUG (NO PACKING) @ 7370' RKB. PULLED DV @ 7070' RKB. IN PROGRESS. [GLV] 04/03/05 SET DV @ 4477' RKB. LOADED IA WITH INHIBITED SW & DSL CAP. SET DV @ 7070' RKB. MITIA 3000 PSI, PASSED. PULLED PLUG. [MIT] 04/05/05 MEASURED BHP @ 7843' MD: 1098 PSI. [Pressure Data] RECEIVED APR '3 2005 Alaska Oil & Gas Cons. Commission Anchorage .," rm~· I. iUr II Þ. ¡ @iJ I· I FRANK H. MURKOWSK/, GOVERNOR I J ¡ ¡ ¡ / ~D r¡ ~ /7 'þ A ",.4..4i1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Kuparuk IE-114L2 Sundry Number: 305-013 Dear Mr. Thomas: Enclosed is the approved Applica~ion for Sundry Approval relating to the above referenced well. Please note the coné.itions of approval set out in the enclosed form. Please provide at least twenty-fou (24) hours notice for a representative of the Commission to witness any require test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 0 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an applic tion for rehearing. A request for rehearing is considered timely if it is received by :30 PM on the 23rd day following the date of this letter, or the next working day if the 3rd day falls on a holiday or weekend. A person may not appeal a Commission decis on to S erior Court unless rehearing has been requested. DATED thiS~ay of February, 2005 Encl. STATE OF ALASKA 1J)r-3 AtAA OIL AN GAS CONSERVATION COMMI~ ¿¡/~ APPL~ATION FOR SUNDRY AP~VAL 20 AAC 25.280 1. Type of Request: Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: ConocoPhil/ips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28', 88' AMSL 8. Property Designation: ALK 25651, ADl 469 11. Total depth MD (ft): 11833' Casing Suspend 0 Repair well 0 Pull Tubing 0 Total Depth TVD (ft): Effective Depth MD (ft): 3539' 11771' Length Size CONDUCTOR 108' 20" SURFACE 4169' 10-3/4" INTERMEDIATE 8708' 7-5/8" LINER - A SAND 4347' 4-112" Perforation Depth TVD (ft): January 21, 2005 Date: \ Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development _ 0 Stratigraphic 0 Perforate 0 Stimulate 0 Waiver Time Extension Re-enter Suspended Well fi1~~ o o o Annular Disp. 0 Other 0 Pre-produce Exploratory 0 Service 0 5. Permit to Drill Number; 204-173 6. API Number; 50-029-23223-61 9. Well Name and Number: 1E-114L2 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured); 3541' MD TVD Burst 108' 108' 4198' 8736' 11810' 2295' 3725' 3540' Perforation Depth MD (ft): slotted liner Packers and SSSV Type: pkr @ 8570' SSSV= Landing Nipple 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Ope rat 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. _____--.C.ol1tact......-__---Gar.v-Iargac-@..265Æ~--.- Printed Name RandY Thomas Title; Kuparuk Drilling Team Leader Signature ~~ Phone: 265-6830 Date$\l(OS- Commission Use Only Tubing Size: 4-1/2" Tubing Grade: L-BO Packers and SSSV MD (ft) 522' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Plugged 0 WINJ 0 Collapse Tubing MD (ft): 7446' Service 0 Abandoned 0 WDSPl 0 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3v':;;--O/3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ~<L~ S()Ç -00'-1 \ t-.\\'-\ ~l\_\~$ -brR~0\\~'V-(J,~E RBDMS 8Fl rEa 1 5 2005 J At\ --- (\ Ci JcßLNAL BY ORDER OF THE COMMISSION D'~'~/oŠ INSTRUCTIONS ON REVERSE Submit in Duplicate . . ::?UD DA::::: OPER & FIELD c704- \~ \ ~l") -\~3 (y~ 1: ~lt-S\ Sc..l. \ \::- \ \ L.\_ L\- - L~ . \. \ HECHANICAL INTEGRITY REPORT· " :~IG REL,S;..S ~: . WELL NUHBER :rl~LL DAT.t.. TD : Jill.. TVD j :?BTD: MD TVD Ca.sing: ~5('6 Shoe: <¿;~()q;: MD "3>'\),ÇTVD¡ DV: \.J~ 'MD . DiD .:....:':ïe:- : f\,) ~ Shoe: HD TVD í :OP: HD ;:'VD :·...¡oi.:1£: l-.\\b Packer ~'ìOHD TVD¡ See ê-~ 'lL\4b ::ole Size ~'"l/V;. ê-nci j Perfs ~ O\+t:o \o.\-tr~$; "'o-k $Qc...\.c.1\'\~ ð€"Q~I\-.\k", -\-~b\"~ ðu~ \c CtLl::.\_\,l Q:~~l~M..~","\- ~C?~.NIC;'..l. INTEGRITY - PART /1 Annulus Press Test: îP ; 15 m~n ; 30 min Com:o.ents: ...- KECHÞ_"tI1ICÞ..L INTEGRITY - PART /2 Cement: Volumes:' þ...mt. Liner ~~ ; Csgd-O(; bbh,; DV \:J ~ C¡¡¡t -"01 to cover perI S <6% bb \ s. 0 \. c.<é. t'-1..E' \I\.. \ .\à<"i)()((" .\c\ ~ o~ \N ":::. ~ <... 'ì qs'ì \ -- SI::JJ( cA \0\9..:\ \"", ~ o? <::> 'f..s. ¡ Theoretical TOe Ú\~~"\\f''J šb¿c '.¡.. ~ -\-~~ V'c.o'\ \O<:,·~ '-~~O \ "IÙ/'"'\ -04 ...J Cement Bond Log (Yes or No) "JV::... 5> ; In AOGCC File . \~ - . ·..\-\...\O.;;S\..... S(:([ t\~'\ t ,. . ~ i . ··'l.JI. . CBL .:.va.luat~ont z.Qne a.~è'-f-e~~~\- t'-iQ(? ~ ~Üih:'-CDb\E (~t"\\\G\ ð·t~K'rCc.u,f"\~\"~\i'~~~, ~~t ~\C('...~"\:\e'ð ~"tc~~'~'.\-.ðt..~.ð~. KV l \ Q~) \"À \-~ r- KÇ7CT'"~. r % \<:Ì\-"fò." \\ \æ l.. { I ~·Jt- c..t' IV:!: \t'.."~~ ~ Proåuc.tion Log: Type Evaluation tu (\<t\ \-k- \' . ~~ orW~\.-\t1 < 'I CONCLUSIONS: ? ar t f 1 : ? ar;: : Z : h'¡::-~ \;~~\I ~; ." ?M ;;.-./ . r<, ..~ , u. --U--=> - .. \ , . Tom, L ð... Here is the well orientation plot for the 1320 requested on lE·U4. Also, included are the cementing reports for each one of these wells. Six wells were seen to intersect the 1320 plot: . lE-168 v ~JÒ~- :)()C) f\ lE-123./ JÙ~-O'ì. \ ...-2!Jo\oc.~\l!J <¿;J~·-O~ ID-116·/ \<\~;- \ ''l J ID-l13v· '~'i5 - \''\. ~ lD-1l2 ~ \<;..~_. \'6~ \'. c 1 D-103 . ,;)0 ?> - 0<:;' (... - <è ~\ -.:\ <4:-\x~ 1./1 s -0 L\ All the wells had good cementing operations with the exception of lD-103. This was the well drilled two years ago and failed to get returns to surface. The bond log was suspect and we went ahead and perfonned a squeeze. The squeeze only took 9 bbls with fairly high squeeze pressures which told me that the cement was there but I think we may have run the bond log way to soon after the cementing operation (+/-48 hours, SLB recommends 72 hours). If you have any questions give me a call. Steve 263-4620 ·T~"\> ~ðCÙ~C"'\- ~GL? ~'\.\ C)\ -\ ~ fA-C\4£\ ~~?S'è.~~Ci:.~· ~e\" \-'\-¡.~ \I: .~\ \t::-\\~ l-L~~.~- L)~ ll·& \\~'\ ,,\;~~~ \ ~\" \\!.CD'~~ ~ '-> \.,U_C'- If \ot~ ¿j\ "--\-~ Ws.poc-\-\~o ,ç\ \ ~.... ~. ì \ \J~\\> \)'-JC\ctc¿)Q \<:r"ì,~\r!:oJ ..\.c') \"()..'-' L 0-Uf:p\-ù.. tD \<£ \ \"-.:\e:c_{{ ~ ' ß~~~ ,~ i9-.., ~ C~ 0 ...:> ,~ / / :; / ;' I! / / / / / / ""'- , , c¡,' I Kuparuk lEPad, lE-il~J lE-114l ,':J' "" o."c¡,'Î '!r ", ~c¡, ~ In , "\.1), H ..... J ,('þ , II ~788 1'Î'b ,.,',',1,,1, 3778' :ï\'b !ij '? 6':J'" \ IJ·J \'1!.~'b ~~ 3538 //11 Kuparuk lE Pad, lE-168, lE-168Ll ~3 r f~' In >--- I Kuparuk !D Pad, !D-1l3, !D-I13 V2 t .C ,r. ii/ , ,ii !h i ' i / ~ 3718 t Kuparuk !D Pad, !D-II6, !D-II6 v2l !~ :::: " ) ~ Kuparuk IE Paq, l!j Kuparuk IE Pad, IE-33, IE-33 V2 III 34' I ,,' ~_ ~ ~ ", I Kuparuk I ~ad, lE-24, lE-24A " , I I I I I f', I I I I I I I ì 3000 4000 5000 6000 7000 -- v ï i I. I Kul Kuparuk lE Pad, lE-123, lE-123 V2 I 7000- CQOOCóPhillips 6000- 5000- 4000- '2 :.€ 0 0 0 - 3000- ~ +' € 0 ~ i r:tJ 2000- ;..'~' ,/' j'~ if ," ,; .", ,,> J; <¡)'/" fr" ,:ß'YY 'j"ß' ",.owM;-·' ~ '" ~"'- .''''' 3718 1 000- 3718 --:3478 0-, ~ 0\ IV) ~ -2000- =-1-'_1 ''-'V-!!5UM c.... .....NG ""Vtc.. W est( - )/East( +) [I OOOftlin] ~ "\u....·..,,.~ ,.".....,.. " ../ I Kuparuk !D Pad, !D-103, !D-103 VI j ANTI-COLLISION SE1i1NGS Interpolation Method:TVD Interva): 1.006 Depth Range From: 3478.000 To: 3788.250 Maximum Range: 1376.200 Reference: DeflØiUve Survey Circles of 1320' Radius I 8000 · STATE OF ALASKA _ ALA OIL AND GAS CONSERVATION COM~ION W~LL COMPLETION OR RECOMPLETION REPOR:rr Áö¡t40G Oil ~ Gas U Plugged 0 Abandoned 0 Suspended 0 ~ 1b. Well Clas$: 20AAC 25.105 20AAC 25.110 - \ Development 0 Exploratory 0 WINJ 0 WDSPL 0 No. of Completions _ Other _X Pre-Produced Injector Service 0 Stratigraphic Test 0 12. Permit to Drill Number: 1a. Well Status: GINJ 0 2. Operator Name: . ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: At Top Productive Horizon: 5. Date Comp., Susp., or Aband.: October 26,2004 204-173 6. Date Spudded:O c..fol:.e...r If ( t..Þt:>'¡ 13. API Number: $.r.ptørnbor 25, 2004'¿Þ 50-029-23223-61 7. Date TD Reached: II·Z'lof 14. Well Name and Number: 1E-114L2 91' FSL, 227' FEL, Sec. 16, T11N, R10E, UM 319' FNL, 86' FEL, Sec. 15, T11 N, R1OE, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550301 y- TPI: x- 555615 y- Total Depth: x- 555678 y- 18. Directional Survey: Yes [;2] NoU Zone-4 Zone- 4 Zone-4 October 21, 2004 8. KB Elevation (ft): 28' RKB I 88' AMSL 9. Plug Back Depth (MD + TVD): 11771' MD 13541' TVD 10. Total Depth (MD + TVD): , 11833' MD I 3539' TVD 595' FSL, 187' FEL, Sec. 15, T11N, R10E, UM Total Depth: 21. Logs Run: GR/Res 22. CASING SIZE WT. PER FT. 62.58# 45.5# 29.7# 12.6# GRADE H-40 L-80 L-80 L-80 20" 10.75" 7.625" 4.5" 5959681 5960222 5964588 11. Depth where SSSV set: Landing Nipple @ 522' 19. Water Depth, if Offshore: N/A CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 4198' 28' 2295' 28' 8736' 28' 3725' 7463' 11810' 3489' 3540' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slots in liner from 7490'-11738' 120 joints total wI a slot every other joint 26. Date First Production November 13, 2004 Date of Test Hours Tested 11/17/2004 Flow Tubing press. 398 psi 27. 7 hours Casing Pressure 1366 24. SIZE 4.5" 15. FieldlPool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ALK 25651 17. Land Use Permit: ADL 469 20. Thickness of feet MSL Permafrost: 5765' MD "'774J~-w '"1¥'6S"/.;n.ö .4þ 3. t..hD ""tvh II· 21./-61 13.5" 9.875" 6.75" HOLE SIZE AMOUNT PULLED 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". CEMENTING RECORD 42" 335 sx AS I 730 sx AS Lite, 207 sx DeepCrete 515 sx DeepCrete slotted liner TUBING RECORD DEPTH SET (MD) 7446' PACKER SET 8570' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a Test Period --> Calculated 24-Hour Rate -> RBDMS 8FL NOV 2 6 2004 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Pre-produced Injector - shared production with 1E-114 and 1 E-114L1 Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 368 166 5 45 Bean OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 1222 611 18 n/a CORE DATA Form 10-407 Revised 12/2003 NONE CONTINUED ON REVERSE GAS-OIL RATIO 517 r'o.;'":;,";,:'~: . . ~~~~~-M1 1 V::W":Fn· ¡ , ''-. 2(2Q:,..:1 (,f GEOLOGIC MARKERS . 29. . FORMATION TESTS 28. 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". 1E-114L2 West Sak D 7461' 3489' N/A 30. LIST OF A IT ACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263·4620 Printed Na~ Ra~2Y Thomas Title: Signature \ ~~hone Kuparuk Drilling Team Leader ""2.6 ç 6 is' "3 0 Date 'l (\cr (0" Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 . . Tear out & rig down for rig move. Move rig from 1E-166 to 1E-114, Rig up & Connect all Air, Mud, Steam, Water & Pump Jines. Accept rig @ 08:00 hrs 9/25/04, Nipple up Diverter system, Mix Spud mud, Load pipe shed w/ 5" drill pipe & HWDP. Change out all surface equip., Iron Roughneck & Top drive saver sub from 4" to 5". Pick up 34 stands 5" drill pipe, 29 jts 5" HWDP & Jars and stand back in derrick. Function test Diverter system- OK, Test waived by AOGCC Jeff Jones. Make up BHA #1, Pick up 3 NMDC's, RIH & tag btm of conductor @ 108'. Fill conductor & check for leaks- OK. Note; Rig back on High line power at 21 :30 hrs 9/25/04. Spud well @ 22:00 hrs 9/25/04, Drill 13-1/2" hole f/108' to 220', ART= 1.6 hrs, 5/15K WOB, 60 RPM, 550 gpm @ 500 psi, UP 50K, DN 50K, ROT 50K, Torque on btm 2000 ftllb, Off btm 1000 fUlb. Drill 13-1/2" hole f/220' to 279' (59'), ART= 0.6 hrs, 5/20K WOB, 60165 RPM, 550 gpm @ 600 psi, UP 50K, DN 50K, ROT 50K, Torque on btm 2000 ftllb, Off btm 1000 fUlb. POOH, Pick up Motor w/1.8 AKO & MWD for BHA #2, Orient same, RIH to 279'. Directional Drill 13-1/2" hole fl 279' to 1,848' (1,569'), Ran 3 Gyro Surveys, ART= 0.5 hrs, AST= 8.9 hrs, WOB 10/20, RPM 70, 550 gpm @ 1900 psi, UP 92K, DN 76K, ROT None. PUMP out of hole to HWDP, POOH (No tight spots - Hole in good shape), Lay down Motor & clean rig floor. Pick up Motor w/1.3 AKO, Make up BHA #3, Orient same & RIH to 1,848', No problems going in hole. Directional Drill 13-1/2" hole f/1 ,848' to 2,040' MD /1,588' TVD (192'), ART= 0.8 hrs, AST= 0.6 hrs, WOB 10/20, RPM 80, 590 gpm @ 2100 psi, UP 90K, DN 77K, ROT None, Torque 4/5000 fUlb on btm, 5000 fUlb off btm. Note; Camp off High line power from 09:30 hrs to 14:00 hrs due to CPF 1 Frame 6 maintainance. 16.50 DRILL DRLG SURFAC Drill 13-1/2" hole f/2,040' to 4,205' MD /2,298' TVD (2,165') (10-3/4" casing point), ART= 7.7 hrs, AST= 3.7 hrs, WOB 10/20, RPM 100,700 gpm @ 2500 psi, UP 135K, DN 60K, ROT 88K, Torque 12K ftllb on btm, 12K ftllb off btm, Max gas 841 units. 1.50 DRILL CIRC SURFAC Pump Hi-vis weighted sweep & circ hole clean. 5.50 DRILL TRIP SURFAC Observe well, Backream out of hole 4,205' to 960' at drilling rate of 590 gpm @ 2300 to 1700 psi, RPM 100, Pulling pipe at rate of 40/45 fUmin., Had to slow down from 3,560' to 3530' & 3,360' to 3,330' due to torque and mild packing off, worked thru spots and cleaned up same, Lay down Ghost reamer. POOH on elevators & stand back HWDP. LD BHA #3, LD 3- 6 3/4" Flex DC's, MWD and Motor RU Doyons 103/4" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running casing MU 103/4" float shoe, 2 jts 10 3/4" 45.5# L-80, BTC csg, fit collar, thread locked conn below FC and circ thru shoe track, RIH with 103/4" csg to 2,072' (52 Jts) Circ btms up at 2,072', staged pump rate up to 6 bpm at 325 psi, st wt Legal Well Name: 1E-114 Common Well Name: 1E-114 Event Name: ROT - DRILLING Contractor Name: n 1334@ppco.com Rig Name: Doyon 141 ""OI,ll'S 9125/2004 00:00 - 02:00 2.00 MOVE RURD MOVE 02:00 - 08:00 6.00 MOVE MOVE MOVE 08:00 - 13:00 5.00 WELCTL NUND RIGUP 13:00 -16:00 3.00 DRILL RIRD SURFAC 16:00 - 20:00 4.00 DRILL PULD SURFAC 20:00 - 20:30 0.50 WELCTL BOPE SURFAC 20:30 - 21 :30 1.00 DRILL PULD SURFAC 21 :30 - 22:00 0.50 DRILL CIRC SURFAC 22:00 - 00:00 2.00 DRILL DRLG SURFAC 9126/2004 00:00 - 00:45 0.75 DRILL DRLG SURFAC 00:45 - 03:30 2.75 DRILL TRIP SURFAC 03:30 - 17:30 14.00 DRILL DRLG SURFAC 17:30 - 20:00 2.50 DRILL TRIP SURFAC 20:00 - 22:00 2.00 DRILL TRIP SURFAC 22:00 - 00:00 2.00 DRILL DRLG SURFAC 9/27/2004 00:00 -16:30 16:30 - 18:00 18:00 - 23:30 23:30 - 00:00 0.50 DRILL TRIP SURFAC 9/28/2004 00:00 - 02:00 2.00 DRILL PULD SURFAC 02:00 - 03:15 1.25 CASE RURD SURFAC 03:15 - 03:30 0.25 CASE SFTY SURFAC 03:30 - 07:00 3.50 CASE RUNC SURFAC 07:00 - 08:30 1.50 CASE CIRC SURFAC Start: Rig Release: Rig Number: Spud Date: 9/25/2004 End: 10/26/2004 Group: 9/25/2004 10/26/2004 Printed: 11/12/2004 11:23:10AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Date Description of 0 . From· To 9/28/2004 07:00 - 08:30 08:30 - 09;15 09;15 - 13;00 1.50 CASE 0.75 CASE 3.75 CASE CIRC SURFAC OTHR SURFAC RUNC SURFAC 13;00 - 14;00 1.00 CEMENT CIRC SURFAC 14:00 - 14:30 14:30 -16:00 0.50 CEMENT RURD SURFAC 1.50 CEMENT CIRC SURFAC 16;00 -18:15 2.25 CEMENT PUMP SURFAC 18:15 -19:15 1.00 CEMENT DISP SURFAC 19:15 - 20:00 0.75 CASE DEQT SURFAC 20;00 - 21 ;30 1.50 CEMENT RURD SURFAC 21 :30 - 00:00 2.50 WELCTL NUND SURFAC 9/29/2004 00:00 - 01 :15 1.25 WELCTL NUND SURFAC 01;15 -03:00 1.75 WELCTL NUND SURFAC 03;00 - 05;00 2.00 WELCTL NUND SURFAC 05;00 - 10:30 5.50 WELCTL BOPE SURFAC 10:30 - 11:00 0.50 DRILL OTHR SURFAC 11 :00 - 13;00 2.00 DRILL RIRD SURFAC 13;00 -18:30 5.50 DRILL PULD SURFAC 18:30 - 20:30 2.00 DRILL PULD SURFAC 20;30 - 23:15 2.75 DRILL TRIP SURFAC 23:15 - 23:30 0.25 DRILL SFTY SURFAC 23:30 - 00:00 0.50 RIGMNT RSRV SURFAC 9/30/2004 00:00 - 01 ;00 1.00 RIGMNT RSRV SURFAC 01 :00 - 06:45 5.75 CEMENT DSHO SURFAC Start: Rig Release: Rlig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: up 96K, dn wt 65K Changed out rubber elements on Franks fill up tool Cant RIH with 103/4" csg, MU hanger and landed csg with float shoe at 4,198' MDI 2,295' TVD, float collar at 4,112', no problems RIH, Ran a total of 79 jts (3,130') of 40.5# L-80, BTC csg above shoe track and a total 25 jts (1,032') of 45.5#, L-80, BTC csg including shoe track, total float equip, csg and hanger, 4,168', ran 15 bow spring centralizers and 1 stop ring per well plan Circ btms up thru Franks fill up tool, staged pump rate up to 7 bpm at 600 psi, st wt up 190K, dn wt 65K RD Franks fill up tool and MU Dowell's cement head Fin circ and conditioning mud for cementing, final MW in & out, 9.3 ppg, 39 vis, 13 PVand 11 YP, circ at 7 bpm at 400 psi, st wt up 190K dn wt 70K, held PJSM with Dowell, APC vac truck drivers and rig crew on cementing operations while circ. Cemented 103/4" csg, Dowell pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 42 bbls of 10.5 ppg mudpush, began mixing and pumping Arcticset lead slurry, pumped 591 bbJs (730 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 7 bpm at 180 psi, followed with 92 bbls (207 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.46 yield with add., ave 7 bpm at 300 psi, reciprocated csg till 17:45 hrs with 129 bbls lead cement out of shoe and had full returns, shut down and dropped top plug Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 381 bbls of 9.3 ppg mud, displaced cmt at 7 bpm, initial circ pressure 550 psi, max pressure 725 psi, slowed rate to 3.5 bprn and bumped plug on calc displacement, pressured up to 1,300 psi, chE~cked floats and held, CIP @ 19:15 hrs, had full returns during job anal had 180 bbls of 10.7 ppg cmt back to surface Tested 103/4" csg to 3,000 psi for 30 min, good test RD Dowell cement head and LD landing jt ND 16" diverter line and began NO 21 1/4" diverter and spool Fin ND diverter and starting head, used crane to set out diverter and set in wellhead equipment NU Vetco Gray 13 3/8" 5M MB 222 wellhead, tested seals to 5,000 psi for 15 min, installed test plug NU BOP stack RU and tested BOPE, choke manifold, 4" and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 2,800 psi high, Jeff Jones with AOGCC waived witnessing of test Installed wear bushing Changed over top drive to 4" XT-39 DP, changed out saver sub, grabbers and pipe guide PU and stood back 159 jts (53 stds) of 4" XT-39 DP MU 9 7IB" BHA #4 with AutoTrak tool, initialized Autotrak and RIH to 1,077' with BHA #4, HWDP, jars and MU ghost reamer RIH from 1,077' to 4,048' with BHA #4 on 5" DP Discussed stripping drill procedure with crew on rig floor Began to slip and cut 100' of drlg line Fin slip and cut 100' of drlg line, serviced top drive and blocks RIH from 4,048', tagged plugs above float collar at 4,111', drilled out Printed: 11/12/2004 11 :23:10 AM . . 5.75 CEMENT DSHO SURFAC plugs, float collar at 4,112', shoe track, float shoe at 4,198' and cleaned out to btm at 4,205', drilled 20' of new formation to 4,225' MD/2,307' TVD, 5-30K wob, 60-120 rpms, 500-600 gpm, 1,300 psi to 2,100 psi, rot wt 85K, up wt 140K, dn wt 55K Displaced out spud mud with clean 9.0 ppg LSND mud, evening MW in and out at 9.0 ppg, circ at 510 gpm, 1,700 psi and 30 rpm's RU and performed LOT to 12.8 ppg EMW, 450 psi, 2,295' TVO with 9.0 ppg MW Drilled 9 7/8" hole with AutoTrak tool per directional plan from 4,225' to 6,250' MD/3,049' TVD (2,025'), AOT 10.0 hrs, 3-15K wob, 130 rpm's, 600 gpm, off btm pressure 2,700 psi, on btm 2,800 psi, off btm torque 9K ft-Ibs, on btm 9K ft-Ibs with 2% lubricants, rot wt 93K, up wt 120K, dn wt 73K, clean hole ECO with 9.0 ppg MW at 500 gpm was 9.7 ppg, raised MW from 9.0 to 9.3 ppg at 6,000' per well plan, ECD with 9.0 ppg mud ave 10.1 ppg, ECD with 9.3 ppg MWave 10.6 ppg, BGG with 9.0 ppg mud ave 175 units, max gas/conn gas ave 1,100 units, BGG with 9.3 ppg mud ave 100 units, max gas/conn gas ave 350 units 12.00 DRILL ORLG INTRM1 Drilled 9 7/8" Hole with AutoTrak tool per directional plan from 6,250' to 7,692' MD/ 3,539' TVO, (1,442') ADT 6.7 hrs, 5-15K wob, 130 rpm's, 600 gpm, off btm pressure 3,450 psi, on btm 3,500 psi, off btm torque 15K fHbs, on btm 13K, rot wt 99K, up wt 165K, dn wt 65K, 9.3 ppg MW, ave ECO 10.8 ppg. Top of Ugnu "C" at 5,760' MOl 2,847' TVD, Top of West Sak "0" at 7,457' MD/ 3,488' TVD, ave BGG 100 units, max gas 1,200 units 9.00 DRILL DRLG INTRM1 Drilled 9 718" Hole from 7,692' to 8,741' MOl 3,727' TVD, (1,049') (7 5/8" Csg pt) ADT 5.2 hrs, 5-15K wob, 130 rpm's, 600 gpm, off btm pressure 3,600 psi, on btm 3,675 psi, off btm torque 17K ft-Ibs, on btm 13K, rot wt 97K, up wt 176K, dn wt 62K, 9.3 ppg MW, ave ECD 11.0 ppg, pumped weighted hi vis sweep with no increase in cuttings back Top of West Sak "B" at 7,777' MD/3,577' TVD, ave BGG 350 units, max gas 1,270 units Circ to clear BHA and downlink AutoTrak to ribs off Backream out of hole from 8,741' to 6,947', backreaming out at 130 rpm's, 600 gpm, 3,500 psi with no problems Backreamed out from 6,974' to 5,265' at 130 rpm's, 600 gpm at 2,400 psi, pumped out of hole from 5,256' to 103/4" csg shoe at 4,198' Pumped weighted hi vis sweep and circ hole clean, circ at 600 gpm, 2,350 psi, had 10% increase in cuttings back from sweep, circ add. btms up and clean at shakers, rot wt 89K, up wt 145K, dn wt 58K Monitored well at shoe-static POOH from 4,198' to 4,048', hole taking proper fill, pumped dry job POOH LD 5" DP from 4,048' to 1,077' to BHA, LD 96 jts of 5" DP Monitored well at BHA-static Serviced top drive and blocks Repaired pipe skate POOH LD 29 jts 5" HWDP and jars, cont to LD BHA #4, downloaded Autotrak tool and LD same, cleared rig floor and pulled wear bushing RU Doyon's 7 5/8" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running of 7 518" csg RIH with 7518",29.7#, L-80, BTC-M csg to 2,098', MU 7518" Float shoe, 3 jts csg and float collar, thread locked btm 4 conn's and circ thru float equip and ck ok, RIH with 46 add. jts along with pup jts for spacing out to 2,098' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 d Sub P Co . e Code hase 9/30/2004 01 :00 - 06:45 06:45 - 07:30 0.75 DRILL CIRC SURFAC 07:30 - 08:15 0.75 DRILL LOT SURFAC 08:15 - 00:00 15.75 DRILL DRLG INTRM1 10/112004 00:00 - 12:00 12:00 -21:00 21:00-21:15 0.25 DRILL CIRC INTRM1 21 :15 - 00:00 2.75 DRILL REAM INTRM1 10/2/2004 00:00 - 03:15 3.25 DRILL REAM INTRM1 03:15 - 04:15 1.00 DRILL CIRC INTRM1 04:15 - 04:30 0.25 DRILL OBSV INTRM1 04:30 - 05:00 0.50 DRILL TRIP INTRM1 05:00 - 07:45 2.75 DRILL PULD INTRM1 07:45 - 08:00 0.25 DRILL OBSV INTRM1 08:00 - 08:30 0.50 RIGMNT RSRV INTRM1 08:30 - 09:00 0.50 RIGMNT RGRP INTRM1 09:00 - 11 :30 2.50 DRILL PULD INTRM1 11 :30 -13:30 2.00 CASE RURD INTRM1 13:30 - 14:00 0.50 CASE SFTY INTRM1 14:00 - 17:30 3.50 CASE RUNC INTRM1 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Printed: 11/12/2004 11 :23: 1 0 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 d Sub Hours Co e Code Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Description 0 10/2/2004 17:30 - 18:30 1.00 CASE CIRC INTRM1 18:30 - 20:30 2.00 CASE RUNe INTRM1 20:30 - 21:30 1.00 CASE CIRC INTRM1 21 :30 - 00:00 2.50 CASE RUNC INTRM1 10/3/2004 1.25 CASE RUNC INTRM1 0.75 CASE CIRC INTRM1 00:00-01:15 01 :15 - 02:00 02:00 - 08:45 6.75 CASE RUNC INTRM1 08:45 - 10:15 1.50 CEMENT CIRC INTRM1 10:15-10:30 10:30-11:15 0.25 CEMENT RURD INTRM1 0.75 CEMENT CIRC INTRM1 11:15 -12:45 1.50 CEMENT PUMP INTRM1 12:45 -14:15 1.50 CEMENT DISP INTRM1 14:15 - 15:00 0.75 CASE DEQT INTRM1 15:00 - 16:30 1.50 CASE RURD INTRM1 16:30 -18:00 1.50 WELCTL EQRP INTRM1 18:00 - 19:00 1.00 DRILL PULD INTRM1 19:00 - 20:30 1.50 DRILL PULD INTRM1 20:30 - 23:00 2.50 DRILL PULD INTRM1 23:00 - 23:15 0.25 DRILL DEQT INTRM1 23: 15 - 00:00 0.75 DRILL PULD INTRM1 10/412004 00:00 - 04:45 4.75 DRILL PULD INTRM1 04:45 - 05:45 1.00 DRILL TRIP INTRM1 05:45 - 07:30 1.75 RIGMNT RSRV INTRM1 07:30 - 08:45 1.25 CEMENT DSHO INTRM1 Circ a csg cap at 2,098', staged pump rate up to 4 bpm at 350 psi, st wt up 103K, dn wt 48K RIH with 7518" csg from 2,098' to 4,126' Circ a csg capacity at 10 3/4" shoe, staged pump rate up to 4 bpm at 350 psi, st wt up 142K, dn wt 50K RIH with 7 5/8" csg from 4,126' to 5,072', RIH to 4,710', pumped down from 4,710' to 4,770', had to push csg down from 4,770' to 5,072', pushed 2 jts and would pump 3rd one down, 51 wt up 170K, dn 35K, (block wt 35K) Total of 119 of 204 jts in hole RIH slow with 7 5/8" csg from 5,072' to 5,295' Circ btms up at 5,295', staged pump rate up to 5.5 bpm, 400 psi, st wt up 180K, dn wt 45K Fin RIH with 75/8" csg, RIH to btm slow due to excessive drag, MU hanger and landed 7 5/8" csg at 8,736' MD/ 3,725' TVD with float collar at 8,607', ran a total of 204 jts 7 5/8", 29.7#, L-80 BTC-M csg with 4-pup jts and hanger (Total 8,709'), ran 20 tandem rise cent, 40 bow spring and 24 straight blade centralizers per well plan, 1 every 30' Circ btms up thru Franks fill up tool conditioning mud for cementing, staged pump rate up to 6 bpm at 675 psi LD Franks fill up tool and MU Dowell cement head Cont to circ and cond mud for cementing, circ at 6 bpm at 700 psi, st wt up 275K, dn 50K, initial MW out, 9.8 ppg, 156 vis, PV 31, YP 29, conditioned mud to final MW out of 9.3 ppg, 43 vis, 17 YP and 18 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ Dowell pumped 10 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped 40 add. bbls of CW 100, pumped 50 bbls of MudPush at 10.5 ppg, dropped btm plug then pumped 210 bbls, (515 sxs) of DeepCrete cmt at 12.5 ppg, 2.24 yield with additives, ave 6 bpm at 250 psi, reciprocated pipe with full returns, shut down, washed up and dropped btm plug Rig displaced cement with 9.3 ppg OBM, bumped plug on calc displacement after pumping 395 bbls OBM (95% pump eff.) ave 6 bpm while displacing cmt, max pressure 990 psi, slowed pump rate to 3 bpm with 30 bbls left to pump and bumped plug to 1,500 psi, ck floats and held CIP at 14:00 hrs, reciprocated pipe until CW 100 was out of shoe when hole began getting tight and stopped reciprocating, Calc TOe @ 5,500' Tested 7 518" csg to 3,000 psi for 30 min LD landing jt and RD csg equipment Installed 75/8" pack-off and tested seals to 5,000 psi for 15 min, installed wear bushing Changed out elevator bales and PU 6 3/4" BHA to rig floor PU and stood back in derrick 9 stds of 4" Hybrid push pipe MU 6 3/4" BHA #5,43/4" mud motor with 1.2 deg bend, MWD, LWD and PWD, oriented and uploaded MWD, RIH with BHA #5 to 283' Shallow tested MWD at 283', circ at 178 gpm at 550 psi, tool ck ok RIH with BHA #5 PU 4" XT-39 DP singles from pipe shed, RIH to 1032' Cont RIH with 63/4" BHA #5 PU 4" XT 39 DP from Pipe shed to 6,235', PU a total of 195 jts of 4" XT 39 DP RIH from 6,235' to 8,567' with 4" DP from derrick Slip and cut 65' of drlg line, serviced top drive and blocks RIH from 8,567' and tagged plugs above float collar at 8,606', drilled out Printed: 11/12/2004 11:23:10AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: From - To Hours 1.25 CEMENT DSHO INTRM1 float collar at 8,607', shoe trak and float collar at 8,736', drilled 20' of new formation from 8,741' to 8,761' MD/3,729' TVD, drilled with 0-15K wob, 50 rpm's, 236 gpm at 1,900 psi, rot wt 85K, up wt 140K, dn wt 55K Circ hole clean for LOT, 9.35 ppg MW in and out, circ at 296 gpm, 2,600 psi and 50 rpm's RU and performed LOT to 14.7 ppg EMW, 1,030 psi, 3,729' TVD with 9.35 ppg MW RU on 75/8" x 10 3/4" annulus with rig pump, pressured up to 3,500 psi and attempted to break down annulus with no success, Note: on 10/3/04 had pumped 6 bbls down annulus 7 hrs after CIP, At 16:00 hrs RU little Red and attempted to pump down annulus, after 2 hrs was able to pump 1 bbl into annulus, after next 2 1/2 hrs was only able to pump 0.8 bbl, shut down Little Red at 20:30 hrs 6.50 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 8,761' to 9,321' MD/3, 755' (560') ART 2.6 hrs, AST 1.2 hrs, 2-5K wob, 80-120 rpm's, 75 spm, 318 gpm, off btm pressure 2,900 psi, on btm 3,000 psi, off btm torque 6K, on btm 5.5K ft-Ibs, rot wt 85K, up wt 136K, dn wt 63K, clean hole ECD with 9.35 ppg OBM was 11.4 ppg, ECD while drlg with 9.35 OBM ave 11.5 ppg, ave BGG 250 units, max gas 517 units, Est top of West Sak A2 sand 8,769' MD/3,730' TVD 1.75 DRILL DEQT PROD Trouble shoot MWD due to poor decoding, adjusted flow rates and surged pipe and after surging pipe several times, tool began to pulse, no sweeps had been pumped when problem occured, earlier had bad decoding but was able to drill ahead 4.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 9,321' to 9,605' MDI 3,738' (284') ART 1 hr, AST 1.1 hrs, 2-5K wOb, 100-120 rpm's, 75 spm, 318 gpm, off btm pressure 2,900 psi, on btm 3,000 psi, off btm torque 6K, on btm 5.5K ft-Ibs, rot wt 84K, up wt 142K, dn wt 57K, 9.3 ppg OBM, ave ECD 11.4 ppg, ave BGG 250 units 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" "A" sand lateral from 9,605' to 10,475' MDI 3,769' TVD (870'), ART 4.3 hrs, AST 2.6 hrs, 2-10K wOb, 120 rpm's, 75 spm, 318 gpm's, off btm pressure 2,900 psi, on btm 3,100 psi, off btm torque 6K ft-Ibs, on btm 5.5K ft-Ibs, rot wt 85K, up wt 150K, dn wt 50K, 9.3 ppg OBM, ave ECD 11.45 ppg, ave BGG, 275-300 units 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" "A" sand lateral from 10,475' to 11,323' MDI 3,748' TVD (848'), ART 3.3 hrs, AST 3.4 hrs, 2-15K wOb, 120 rpm's, 75 spm, 318 gpm's, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 170K, dn wt 48K, 9.3 ppg OBM, ave ECD 11.8 ppg, ave BGG, 275-300 units, max gas 425, began running push pipe at 11,274' 7.00 DRILL DRLG PROD Directionally drilled 6 3/4" "A" sand lateral from 11,323' to 11,857' MDI 3,788' TVD (534'), ART 3.8 hrs, AST.6 hrs, 2-15K wob, 120 rpm's, 75 spm, 318 gpm's, off btm pressure 3,500 psi, on btm 3,600 psi, off btm torque 7K ft-Ibs, on btm 6.5K ft-Ibs, rot wt 98K, up wt 182K, dn wt 58K, 9.3 ppg OBM, ave ECD 11.9 ppg, ave BGG, 275 units, began running push pipe at 11,274' Pumped weighted hi vis sweep and circ hole clean, circ at 318 gpm, 3,600 psi and 120 rpm's, had no increase in cuttings from sweep Monitored well-static Backreamed out of hole at drlg rate from 11,857' to 8,730' to 7 518" csg shoe with no problems, 120 rpm's, 320 gpm, 2,900 psi Pumped weighted hi vis sweep and circ hole clean, circ at 320 gpm, 2,800 psi and 80 rpm's, had no increase in cuttings from sweep, circ 3X 10/4/2004 07:30 - 08:45 08:45 - 10:00 1.25 DRILL CIRC INTRM1 10:00 - 10:45 0.75 DRILL LOT INTRM1 10:45 - 11 :45 1.00 DRILL OTHR INTRM1 11 :45 - 18:15 18:15 - 20:00 20:00 - 00:00 10/5/2004 00:00 - 12:00 12:00 - 00:00 101612004 00:00 - 07:00 07:00 - 08:45 1.75 DRILL CIRC PROD 08:45 - 09:00 0.25 DRILL OBSV PROD 09:00 - 13:30 4.50 DRILL REAM PROD 13:30 - 15:00 1.50 DRILL CIRC PROD Printed: 11/12/2004 11:23:10AM . . Legal Well Name: 1 E-114 Common Well Name: 1E-114 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Dáte P'rOJ'\"\"To Houl'S 1016/2004 13:30 - 15:00 1.50 DRILL CIRC PROD 15:00 - 15:15 0.25 DRILL OBSV PROD 15:15 - 20:00 4.75 DRILL TRIP PROD 20:00 - 22:00 2.00 DRILL PULD PROD 22:00 - 23:15 1.25 RIGMNT RSRV CMPL TN 23:15 - 00:00 0.75 WAlTON EQIP CMPL TN 10/7/2004 00:00 - 02:30 2.50 LOG RURD CMPL TN 02:30 - 07:00 4.50 LOG ELOG CMPL TN 07:00 - 09:00 2.00 LOG RURD CMPL TN 09:00 - 09:30 0.50 DRILL PULD CMPL TN 09:30 - 13:00 3.50 DRILL TRIP CMPL TN 13:00 - 15:00 2.00 DRILL TRIP CMPL TN 15:00 - 16:00 1.00 DRILL CIRC CMPL TN 16:00 - 17:45 1.75 DRILL CIRC CMPL TN 17:45 -20:15 2.50 DRILL TRIP CMPL TN 20: 15 - 20:30 0.25 DRILL OBSV CMPL TN 20:30 - 23:30 3.00 DRILL TRIP CMPL TN 23:30 - 00:00 0.50 DRILL PULD CMPL TN 10/812004 00:00 - 01 :15 1.25 DRILL PULD CMPL TN 01:15-02:00 0.75 CASE RURD CMPL TN 02:00 - 05:00 3.00 CASE PULR CMPL TN Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: btms up and clean at shakers, st up wt 140K, dn wt 65K Monitored well-static POOH from 8,730' to BHA #5 at 252', SLM no corr Stood back std of HWDP, jars and Flex DC's, download MWD and LD MWD/LWD and motor, cleared rig floor Serviced top drive and drawworks while waiting on Schlumberger wireline, wireline unit was stuck behind rig move at KUP river bridge Waited on Schlumberger wireline unit, rig crew changed out air boot on riser, wireline unit arrived location at 00:00 hrs RU Schlumberger Wireline, MU USIT logging tool with Welltec's tractor tool, Held PJSM with SWS and rig crew RIH with USIT bond log, RIH to 8,630' without having to turn tractor tool on, logged up to 3,000' and POOH, had exceptable bond, est TOe @ 3,250' LD logging tools and RD Schlumberger, cleared rig floor MU BHA #6, 6 1/8" hole opener and RIH to 141' RIH from 141' to 8,730' to csg shoe, est circ to fill pipe, 300 gpm, 2,000 psi, rot wt 84K, up wt 128K, dn wt 60K, 80 rpm's with 6.5K ft-Ibs torque NOTE: Rig and Camp off highline from 09:45 to 11 :30 hrs TlH from 8,730' to 11,857', no problems RIH to btm Circ hole clean with 9.3 ppg OBM, circ at 300 gpm, 3,000 psi, 120 rpm's, 6K ft-Ibs torque, rot wt 99K, up wt 160K, dn wt 60K Changed hole over from 9.3 ppg OBM to 9.3 ppg solids free OBM, circ at 318 gpm, 2,850 psi, monitored well-static POOH from 11,857' to 8,668', no problems or swabbing Monitored well at shoe-static, dropped 1 3/4" rabbit on a wire POOH from 8,668' to BHA #6 to 141' POOH, LD 2 jts of HT-38 HWDP and jars, LD 61/8" hole opener, calc fill on trip out 75 bbls, actual fill 86 bbls PU and stood back 9 jts of 4" XT-39 HWDP and cleared rig floor RU to run 4 1/2" liner and held PJSM with rig crew PU and ran 4 1/2" liner per well program, ran 4 112" ROT silver bullet guide shoe with no float, 92 jts w/1-pup jt, (3,225') of 41/2" 12.6#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 51 jts (1,591 ') of blank liner and 41 jts (1,634') of slotted liner, ran 1- 4 1/2" x 6 114" spiralglide centralizer 1/jt to csg shoe (86 total) ran 9 restrictor packers with 18 spacer rings placed on blank liner to isolate shale sections per geology. 1.00 CASE PULR CMPL TN MU Baker 190-47 csg seal bore ext, 5 1/2" x 7 518" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 3,298' 6.00 CASE RUNL CMPL TN RIH with liner assembly to 8,719', (csg shoe) est circ at 4 bpm, 550 psi, then rotated liner at 10 rpm's with 5.5K ft-Ibs torque, rot wt 80K, up wt 115K, dn wt 62K, having to screw into each std to keep mud from running over 3.00 CASE RUNL CMPL TN Cant to run 4 1/2" liner in open hole, RIH from 8,719' and tagged btm at 11,857' with no problems, PU to 11,856', st wt up 163K, dn wt 70K 1.00 CASE OTHR CMPL TN Dropped 1 7/16" ball and pumped down to seat, pump at 4 bpm at 975 psi, with ball on seat pressured up to 2,000 psi to set Flexlock hanger, bled off the pressure, cont to set packer, pressured up to 4,200 psi and set ZXP packer, no problems setting hangerlpacker, set "A" sand liner with TOL @ 8,569' MDI 3,696' ND and shoe at 11,856', st wt up after setting liner 145K, lost 18K wt 05:00 - 06:00 06:00 - 12:00 12:00 - 15:00 15:00 - 16:00 Description Printed: 11/12/2004 11:23:10AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n 1334@ppco.com Doyon 141 Hours Code Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: RU & tested 7 5/8" csg and ZXP packer to 1,000 psi for 5 min, good test PU out of SBE 33' and circ btms up, circ at 7.5 bpm at 2,500 psi Monitored well-static POOH wet and LD Baker setting tool, SLM out, no corr, calc fill on trip out 59 bbls, actual fill 67 bbls, cleared rig floor Began MU whipstock assembly, PU whipstock and broke out btm trip anchor and LD whipstock, MU milling assembly and LD same, PU seal assembly, locator sub, 3 1/2" DP pup jt, unloader sub, then PU 10 jts 3 1/2" DP RIH to 327' with seal assembly 2.50 WINDOWPULD CMPL TN Fin MU whipstock BHA #7, RIH from 327', PU a total of 24 jts of 31/2" DP for space out, 7 5/8" btm trip whipstock, milling assembly with MWD, oriented MWD and RIH with 3 stds 4" HWDP and 9 stds of 4" push pipe to 1,158' Shallow tested MWD and tool ck ok RIH with whipstock from 1,158' to 7,820' Made MADD pass from 6,970' to 7,000' (sensor depth) and correlated MWD to K-13 sand RIH with whipstock from 7,850' to 8,520' Oriented whipstock to 13 deg left of high side, RIH, tagged TOL at 8,569', set whipstock and sheared off from same, st wt up 137K dn wt 64K Displaced out 9.3 ppg solids free OBM with used 9.3 ppg OBM Milled window in 75/8" csg, top of window at 7,778', btm of window at 7,790', drilled 6 3/4" hole to 7,809' MD (31'), 2-6K wob, 80-120 rpm's, 270-310 gpm, 2,800 psi, rot wt 85K, up wt 137K, dn wt 65K, 6-8K ft-Ibs torque Circ hi vis sweep and circ hole clean, circ at 310 gpm at 2,800 psi, worked mills thru window with no problem Monitored well-static, pumped dry job POOH from 7,809' to BHA #7 at 1,189', monitored well-static LD 3 jts of 4" HWDP, stood back 2 stds HWDP and 9 stds push pipe, LD MWD and milling assembly, upper mill was in gauge, cleared rig floor Pulled wear bushing and flushed out stack RU and began testing BOPE, testing valves, manifold and rams to 250 psi low and 3,500 psi high, tested annular to 250 psi low and 2,800 psi high. NOTE: John Crisp with AOGCC waived witnessing of test Fin. testing BOPE, valves, manifold and rams to 250 psi low and 3,500 psi high, Note John Crisp W/AOGCC waived witnessing of test Installed wear bushing Changed out 4" Xt-39 saver sub on top drive MU 6 3/4" BHA #8 with Autotrak tool and uploaded, PU std of flex DC's and MU std of XT 39 HWDP with jars RIH to 240' RIH with BHA #8 from 240' to 7,714', shalllow tested MWD at 2,295' and ck ok Slip and cut 75' of drlg line, serviced top drive and drawworks RIH from 7,714', washed down from top of window at 7,778' to btm at 7,809', no problems going thru window Drilled 6 3/4" hole with AutoTrak tool in "B" Sand lateral from 7,809' to 9,000' MD/3,581' TVD, (1,191 '), ADT 8.4 Hrs, 5-15K wob, 120-150 rpm's, 75 spm, 318 gpm, off btm pressure 3,250 psi, on btm 3,325, off btm torque, 7.5K ft-Ibs, on btm 6.5K ft-Ibs, rot wt 83K , up wt 137K , dn wt 59K, 9.3 ppg OBM in hole, (clean hole ECD =11.4 ppg) ave ECD 11.7 ppg, ave BGG 260 units, max gas 482 units 10/8/2004 16:00 - 16:15 0.25 CASE DEQT CMPL TN 16:15 -17:15 1.00 DRILL CIRC CMPL TN 17:15-17:30 0.25 DRILL OBSV CMPL TN 17:30-22:15 4.75 DRILL TRIP CMPL TN 22:15 - 00:00 1.75 WINDOWPULD CMPL TN 10/9/2004 00:00 - 02:30 02:30 - 03:00 0.50 WINDOWOTHR CMPL TN 03:00 - 07:30 4.50 WINDOWTRIP CMPL TN 07:30 - 08:15 0.75 WINDOWOTHR CMPL TN 08: 15 - 09:00 0.75 WINDOWTRIP CMPL TN 09:00 - 10:00 1.00 WINDOWSElW CMPLTN 10:00 - 10:30 0.50 WINDOWCIRC CMPL TN 10:30 -15:15 4.75 WINDOWSlWP CMPL TN 15:15 -16:00 0.75 WINDOWCIRC CMPL TN 16:00 - 16:15 0.25 WINDOWOTHR CMPL TN 16:15 - 18:30 2.25 WINDOWTRIP CMPL TN 18:30 - 20:30 2.00 WINDOWPULD CMPL TN 20:30 - 21 :30 1.00 WELCTL OTHR CMPL TN 21 :30 - 00:00 2.50 WELCTL BOPE CMPL TN 1011012004 00:00 - 01 :30 1.50 WELCTL BOPE CMPL TN 01 :30 - 02:00 0.50 DRILL OTHR CMPL TN 02:00 - 03:00 1.00 RIGMNT RSRV CMPL TN 03:00 - 06:00 3.00 DRILL PULD PROD2 06:00 - 09:15 3.25 DRILL TRIP PROD2 09:15 - 10:15 1.00 RIGMNT RSRV PROD2 10:15 -11:00 0.75 DRILL REAM PROD2 11 :00 - 00:00 13.00 DRILL DRLG PROD2 Printed: 11/12/2004 11:23:10AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 9/25/2004 End: 10/26/2004 Group: 9/25/2004 10/26/2004 From ~ To Hours Description of Operations 10111/2004 00:00 - 01 :15 1.25 DRILL DRLG PROD2 01 :15 - 02:15 1.00 DRILL DEQT PROD2 02:15 - 03:15 1.00 DRILL DRLG PROD2 03:15 - 03:45 0.50 DRILL CIRC PROD2 03:45 - 06:00 2.25 DRILL REAM PROD2 06:00 - 07:00 1.00 DRILL CIRC PROD2 07:00 - 07:15 0.25 DRILL OBSV PROD2 07:15 -10:15 3.00 DRILL TRIP PROD2 10:15 -11:15 1.00 DRILL PULD PROD2 11 : 15 - 13:00 1.75 DRILL PULD PROD2 13:00 - 18:00 5.00 DRILL TRIP PROD2 18:00 - 21 :15 3.25 DRILL DRLG PROD2 21 :15 - 22:30 1.25 DRILL DEQT PROD2 22:30 - 00:00 1.50 DRILL DRLG PROD2 10/12/2004 00:00 - 00:30 0.50 DRILL DEQT PROD2 00:30 - 01 :30 1.00 DRILL REAM PROD2 01 :30 - 03:00 1.50 DRILL TRIP PROD2 03:00 - 04:00 1.00 DRILL CIRC PROD2 04:00 - 07:30 3.50 DRILL TRIP PROD2 07:30 - 08:15 0.75 DRILL PULD PROD2 08:15 - 09:15 1.00 DRILL PULD PROD2 09:15 -10:15 1.00 DRILL PULD PROD2 10:15 - 12:00 1.75 DRILL TRIP PROD2 12:00 - 13:45 1.75 DRILL TRIP PROD2 13:45 - 14:30 0.75 DRILL REAM PROD2 14:30 - 16:30 2.00 DRILL REAM PROD2 Drilled 6 3/4" hole with AutoTrak tool from 9,000' to 9,113' MD/3,582' TVD, ADT .5 hrs Trouble shoot AutoTrak tool, unable to get pressure to ribs, to attempt to drill ahead in hold mode Drill from 9,113' to 9,206' MD/3,583' TVD (93') ADT 1 hr, 5-15K wob, 150 rpm's, 318 gpm, on btm pressure 3,300 psi, off btm 3,300 psi, off btg torque 8K ft-Ibs, on btm 8K, rot wt 82K, up wt 136K, dn wt 63K, determined hydraulic seal on ribs of AutoTrak tool failed Downliked autoTrak to ribs off, got SPR's, monitored well-static Backreamed out from 9,206' to 7,714', backreamed out to above window at 7,778' at 120 rpm's, 318 gpm at 3,000 psi Circ hole clean at 318 gpm at 2,800 psi, 90 rpm's Monitored well-static POOH from 7,714' to 48' to AutoTrak tool, stood back HWDP, jars and flex Dc's, Downloaded AutoTrak tool and LD same MU BHA #9 with new AutoTrak tool, uploaded tool and RIH to 240' with flex dc's, jars and HWDP RIH from 240' to 9,116', washed 90' to btm at 9,206' with no problems RIH or going thru window Drilled from 9,206' to 9,580' MD/3,589' TVD (374') ADT 1.7 hrs Trouble shoot the ontrak survey package of AutoTrak tool, found the X-axis of the MAG package was bad, decided to drill ahead and survey eliminating X-axis Drilled from 9,580' to 9,673' MDI 3,590' TVD, (93') ADT 1.1 hrs, 5-15K wob, 150 rpm's, 318 gpm, off btm pressure 3,300 psi, on btm 3,300 psi, off btm torque 6.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 82K, up wt 135K, dn wt 56K, 9.3 ppg OBM, ave ECD 12.1 ppg, ave BGG 275 units, max gas 459 units. Note: Decision was made after taking survey that too much time would be required to get good survey, preparing to POOH and PU mud motor to drill lateral Trouble shoot the Ontrak survey package of the AutoTrak tool. Down link, ribs off. Take Slow pump rates, monitor well. Back ream out from 9,673' - 9,206' at 120 RPM and 315 GPM. POOH on elevators from 9,206' to 7,714' (pass thru window wlo problems). Circulate btms up at 75 SPM, 2,800 psi. Monitor well, pump dry job. POOH on elevators to 56', lay down stabilizer and float sub. Download MWD data, break bit, make service breaks, lay down AutoTrak and MWD. PU and MU Motor assembly, set AKO at 1.2 deg. Check connection torque on MWD/LWD and motor. Plug in and upload MWD. RIH to 2,584', shallow test MWD at 75 stks 1,759 psi, continue RIH to 3,892'. RIH to 7,723', orient toolface and pass thru window wlo problems. RIH to 8,564'. Wash and Ream from 8,564' - 8,844' at 60 SPM, 2000 psi, 40 rpm, 6,000 ft-Ib. Wash and Ream from 8,844' - 9,673' at 80 SPM, 2150 psi, 80 rpm, 7,000 ft-Ib. Took survey check shots at 9,218', 9,311',9,405',9,498', 9,592'. Printed: 11/12/2004 11 :23:10 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Date From· To Hours Code Sub Code 7.50 DRILL DRLH PROD2 Drill horizontal B-Lateral section fl 9,673' to 10,420' MD - 3,597' TVD ADT - 3.8 hrs. = ART - 3.2 hrs. AST - 0.6 hrs. WOB 2-8 RPM 120 GPM 318 w175 spm @ 3,125 psi String wt. PU 137 SO 56 Rot 82 Torque on/off btm - 8,000 I 7,500 ft-Ib 12.00 DRILL DRLH PROD2 Drill horizontal B-Lateral section f! 10,420' to 11,460' MD - 3,592' TVD ADT - 6.2 hrs. = ART - 4.3 hrs. AST - 1.9 hrs. WOB 2-7 RPM 120 GPM 315 wI 75 spm @ 3,350 psi String wt. PU 165 SO 35 Rot 83 Torque on/off btm - 8,000 18,000 ft-Ib 2.25 DRILL DRLH PROD2 Drill horizontal B-Lateral section f/11 ,460' to 11,570' MD WOB 2-9 RPM 110-120 GPM 315 wI 75 spm @ 3,425 psi String wt. PU 166 SO 57 Rot 86 Torque on/off btm - 8,000 I 8,500 ft-Ib Downlink MWD/LWD. Decoding problem. Bump up mud pump dampner pressure to 1,000 psi. Drill ahead 11,570' - 11,630'. MWD was not decoding properly. Reduced dampner pressure to 750 psi and had no success. Reduced dampner pressure to 450 psi and down linked MWD. Drill horizontal B-Lateral section f/11 ,460' to 11,841' MD - 3,611' TVD ADT - 2.9 hrs. = ART - 2.0 hrs. AST - 0.9 hrs (for tower). WOB 2-9 RPM 120 GPM 315 wI 75 spm @ 3,425 psi String wt. PU 158 SO 60 Rot 92 Torque on/off btm - 9,000 19,000 ft-Ib Pump weighted HI-VIS sweep and circ out at 74 spm and 3,700 psi, 10 rpm. Monitor well - static. BROOH from 11,841' to 10,340' at drilling rate wlo probs. BROOH from 10,340' - 8,003', at drilling rate, wlo probs. Pull 25K over at the hard spot 41' outside of the window. Oriented to 13L of high side and pulled 1 0-15K over thru hard spot. Worked up and down from 7,831 '-7,816' wlo pumps and pulled into the 7-5/8" csg. Pump 30 bbl weighted Hi-Vis sweep and circ clean at 75 spm and 2,300 psi. Orient to high side and monitor well. Trip in hole to 9,200' wlo problems. Wash and ream thru tight spots, and work thru 3 additional times. Cont. RIH to 11,841' TD wlo probs. CBU at 11,841' at 70 spm and 3,450 psi. Swap over to solids free OBM at 70 spm and 3,350 psi. Take slow pump rates, monitor well, POOH on elevators to 11,180'. POOH from 11,180' - 7,680' wlo probs. Monitor well above window - static. POOH on elevators from 7,680'-248'. Monitor well - static, Rack back HWDP, Jars, and NMCSDP. Download MWD. Break bit, LD Motor/MWD. PU whipstock retrieving tools, 1 jt 3-1/2" HWDP, FIS, Bumper sub and Oil Jars + 11 DCs. RIH to 7,790'. Wash whipstk slot and attempt to hook, turn 90 deg and wash, make several attempts. Hook whipstock, shear trip anchor, pull 80K over. Circulate btms up 1.5x at 50 spm and 1,200 psi. Monitor well, blow down Top Drive and POOH to 430'. Monitor well. 10112/2004 16:30 - 00:00 10/13/2004 00:00 - 12:00 12:00 -14:15 14:15 -15:15 1.00 DRILL DEQT PROD2 15:15 -16:15 1.00 DRILL DRLH PROD2 16:15 -17:30 1.25 DRILL DEQT PROD2 17:30 - 20:00 2.50 DRILL DRLH PROD2 20:00 - 21:45 1.75 DRILL CIRC PROD2 21 :45 - 00:00 2.25 DRILL REAM PROD2 10/14/2004 00:00 - 03:45 3.75 DRILL REAM PROD2 03:45 - 04:15 0.50 DRILL TRIP PROD2 04:15 - 05:30 1.25 DRILL CIRC PROD2 05:30 - 05:45 0.25 DRILL OBSV PROD2 05:45 - 08:30 2.75 DRILL TRIP PROD2 08:30 - 09:30 1.00 DRILL CIRC PROD2 09:30 - 11 :00 1.50 DRILL CIRC PROD2 11 :00 - 12:00 1.00 DRILL OBSV PROD2 12:00 - 14:15 2.25 DRILL TRIP PROD2 14:15-17:00 2.75 DRILL TRIP PROD2 17:00 - 18:30 1.50 DRILL OTHR PROD2 18:30 - 20:30 2.00 CMPL TN PULD CMPL T2 20:30 - 23:00 2.50 CMPL TN TRIP CMPL T2 23:00 - 00:00 1.00 CMPL TN OTHR CMPL T2 10/15/2004 00:00 - 00:30 0.50 CMPL TN OTHR CMPL T2 00:30 - 02:00 1.50 CMPL TN CIRC CMPL T2 02:00 - 07:00 5.00 CMPL TN TRIP CMPL T2 Printed: 11/12/2004 11:23:10AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Date Sub Code Code From· To Hours 10/1512004 07:00 - 08:30 1.50 CMPL TN PULD CMPL T2 08:30 - 09:45 1.25 CASE PULR CMPL T2 09:45 - 10:00 0.25 CASE SFTY CMPL T2 10:00 -12:00 2.00 CASE RUNL CMPL T2 12:00 - 13:15 1.25 CASE RUNL CMPL T2 13:15 -13:45 0.50 CASE RUNL CMPL T2 13:45 - 16:30 2.75 CASE RUNL CMPL T2 16:30 - 21 :30 5.00 CASE RUNL CMPL T2 21 :30 - 00:00 2.50 CASE RUNL CMPL T2 10/1612004 00:00 - 00:30 0.50 CASE RUNL CMPL T2 00:30 - 02:00 1.50 CASE RUNL CMPL T2 02:00 - 06:00 4.00 DRILL TRIP CMPL T2 06:00 - 10:00 4.00 RIGMNT RGRP CMPL T2 10:00 - 10:45 0.75 CASE PUTB CMPL T2 10:45 - 11 :00 0.25 CASE SFTY CMPL T2 11 :00 - 12:00 1.00 CMPL TN PULD CMPL T2 12:00 - 13:00 1.00 CASE PULR CMPL T2 13:00 - 17:30 4.50 CASE RUNL CMPL T2 17:30 - 20:00 2.50 CASE RUNL CMPL T2 20:00 - 00:00 4.00 CASE OTHR CMPL T2 10/17/2004 00:00 - 02:45 2.75 CASE OTHR CMPL T2 02:45 - 04:30 1.75 CASE RURD CMPL T2 04:30 - 05:00 0.50 CASE RURD CMPL T2 05:00 - 06:00 1.00 CASE RURD CMPL T2 06:00 - 08:00 2.00 RIGMNT RSRV CMPL T2 08:00 - 12:00 4.00 WELCTL BOPE CMPL T2 12:00 - 12:30 12:30 -14:30 0.50 WELCTL BOPE CMPL T2 2.00 CASE RURD CMPL T2 LD Jars, Bumper sub, Retrieving tool, whipstock, 9x 3-1/2" DP, Trip anchor, 13 x 3-1/2" space out DP, seal assembly. Clean rig floor, LD Baker tools, PU casing tools and RU to run liner. PJSM wI Company Rep, rig crew, csg hand for running 4-1/2" liner. PUIMU bent 3-1/2" bent joint with Baker guide shoe, packoff bushing. RIH wI 2,522' of 4-1/2", 12.6 Ib/ft, L-80, DWC blank I slotted liner with 32x 2.5" x 0.125 slots/ft with 4 circumfrential adjacent rows, staggered 18 degrees. Restrictor packers at 11,516' and 11,255', with blank liner joints between. Spiraglider centralizers (4-1/2" x 6-114"), free floating - 1 per joint, on joints #3 - #126. Average MU torque for liner was 6,300 ft-Ib. Run a total of 128 liner joints, MU Baker 7-5/8" x 4-1/2", Model 81 Flanged Hook Hanger, with hanger running tool. RD casing equipment. MU liner hanger and RD casing equipment RIH on DP to top of window at 7,778'. Orient and make 5 attempts to get bent joint through the window. PU and rotate on each pass. RIH to 11,771' and prep to hook the hook hanger. UP=155K, DWN=75K. RIH to 11,803', pass thru window and RIH an additional 1 0'. PU and hook hanger. Unhook and rehook to verify. Drop ball and pump down at 4 BPM and 1,000 psi. Seat ball and pressure up to 3,000 psi to release. PU to verify, was not released. Re-hook hanger and pressure up to 4,000 psi. PU to verify, not released. Re-hook hanger. RU test pump, and pressure up to 4,600 psi - released from hanger. Note: pinned for 2,500 psi. Blow down TD, POOH, make service breaks, LD liner running tool. Change out upper IBOP valve on Top Drive, test to 3,500 psi. RU casing equipment, clear rig floor. PJSM for running 4-1/2" liner. PU Baker seal assembly. RIH with 10 jts 4-1/2:, 12.6Ib/ft, L-80 tbg. Continue to MU LEM assembly. RIH with LEM assembly on DP to 8,602' Attempt to stab into seal bore receptacle without success. Work pipe setting down 25K, and PU without any drag. POOH with LEM assembly. Continue POOH with LEM assembly. LD LEM, rack back 7 stds of 4-1/2" tbg in the derrick. RD casing equipment, clean rig floor, PU Baker Fishing tools, double stacked tubing tongs. MU Baker reverse circulating basket with 3-3/4" shoe. Cease RU fishing assembly after receiving confirmation of toollD restriction in the profile of the ZXP packer. Make service breaks, RD Baker fishing tools and power tongs. PJSM, Slip and Cut 97' of drill line. Service Top Drive and drawwork brakes. Pull Wear Bushing. RU and tested BOPE, choke manifold, 4" and 5" floor valves, rams excluding btm 7-518" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 3,500 psi high. Tested rig alarm system. Jeff Jones with AOGCC waived witnessing of test Install WB. PJSM and MU LEM assembly. Printed: 11/12/2004 11 :23: 1 0 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Hours Code Sub Phase Code 4.50 CASE RURD CMPL T2 RIH with new space out joint and seal assembly +LEM I ZXP pkr assembly, on DP to 8,610'. UWT= 145K, DWT=85K. 0.50 CMPL TN PCKR CMPL T2 Drop 1-3/4" ball, and pump down at 4 BPM. Set 40K Ib down and pressure up to 3,500 psi and pressure bled back to +1- 2,000 psi, bumped pressure back up to 3,500 psi setting down 40K. The drill string moved down +1- 3'. Set packer. Close Annular preventor, test and chart liner top pkr to 1,000 psi for 5 min. - okay. Bleed off. Circ btms up at 7,625' and monitor well. POOH to 310'. Finish POOH, LD LEM running tools (no damage seen). Clean rig floor. PU Baker milling assembly. MU mill assembly, whipstock, seal assembly, 3 joints 3-112" HWOP, trip anchor, MWD, Bumper Sub, Oil Jar. Orient whipstock to MWD. RIH, PU 3 joints of 4" HWDP, to 1,824'. Shallow test MWD. Cant. RIH to 7,289', Log K-13 sands 7,289' - 7,309'. RIH to 7,709', orient whipstock 10L deg of high side. UWT=135K, OWT= 63K Set whipstock, shear off. Displace solids free OBM to treated 9.3 ppg drilling OBM fluid. Mill window from 7,465' ROT=80K, Torque on = 5-8,000 ft-Ib. Continue milling window to 7,489' Note: TOW=7,465', BOW=7,479'. Pump Hi-Vis sweep, circ hole clean, monitor well. POOH. Wash out stack and clean rig floor. PUIMU bit, 1.2 deg motor and MWO. Upload MWD and orient. RIH with 6-3/4" motor + MWD drilling assembly to 3,708'. Continue RIH f/3,708' to 7,445'. Orient thru window @ 7,465' to 7,477', Wash & Ream down to 7,489' Drill 6-314" Lateral '0' Section f/7,489' to 8,230' MD 3,513' TVD (741'), ART 3.8 hrs, AST 1.8 hrs, UP 120K, DN 60K, Rot 80K, 315 gpm @ 2450 psi, 2J15K WOB, 120 RPM, Arrived clean hole ECD's from PWD 11.3 ppg, Ave ECD's 11.4 ppg, Max gas 234 units. 12.00 DRILL DRLH PROD3 Drill 6-3/4" Lateral 'D' Section ff 8,230' to 9,357' MD 3,538' TVD (1,127'), ART 6.7 hrs, AST 1.4 hrs, UP 135K, DN 55K, Rot 80K, 315 gpm @ 2550 psi, 5115K WOB, 90/120 RPM, Ave ECD's 11.5 ppg, Max gas 285 units. 12.00 DRILL DRLG PROD3 OriIl6-3J4" Lateral 'D' Section f/9,357' to 10,432' MD, 3536' TVD (1075'), ART 5.4 hrs, AST 2.1 hrs, UP 140K, ON 49K, Rot 80K, 315 gpm @ 2800 psi, 5/15K WOB, 120 RPM, Torq on bUm 8 k I off 8.5 k ,Arrived clean hole ECD's from PWD 11.3 ppg, Ave ECD's 11.5 ppg, Max gas 306 units. 12.00 DRILL DRLG PROD3 Drill 6-314" Lateral 'D' Section f/1 0,432' to 11619' MD, 3550' TVD (1187'), ART 6.9 hrs, AST 1.3 hrs, UP 157K, DN 53K, Rot 90K, 315 gpm @ 2950 psi, 2/1 OK WOB, 120 RPM, Torq on bttm 10 k I off bUm 10 k ,Arrived clean hole ECD's from PWD 11.3 ppg, Ave ECD's 11.6 ppg, Max gas 286 units. 3.00 DRILL DRLH PROD3 Drill 6-3/4" Lateral 'D' Section f/11 ,619' to 11,833' MD, 3539' TVD (214'), ART 1.5 hrs, AST 0.4 hrs, UP 170K, ON 50K, Rot 95K, 315 gpm @ 3500 psi, 2/14K WOB, 120 RPM, Torq on bttm 1 OK I off bttm 10K, Ave ECO's 12.0 ppg, Max gas 393 units, Pump weighted Hi-vis sweep 10/17/2004 14:30 -19:00 10/1812004 10/19/2004 19:00 - 19:30 19:30 - 20:00 0.50 CMPL TN DEQT CMPL T2 20:00 - 21 :00 1.00 CMPLTN CIRC CMPL T2 21 :00 - 00:00 3.00 CMPL TN TRIP CMPL T2 00:00 - 01 :00 1.00 CMPL TN PULD CMPL T2 01 :00 - 02:30 1.50 WINDOWPULD CMPL T2 02:30 - 03:00 0.50 WINDOWTRIP CMPL T2 03:00 - 04:15 1.25 WINDOWTRIP CMPL T2 04:15 - 08:30 4.25 WINDOWTRIP CMPL T2 08:30 - 09:30 1.00 WINDOWTRIP CMPL T2 09:30 - 09:45 0.25 WINDOWSETW CMPL T2 09:45 - 10:30 0.75 WINDOWCIRC CMPL T2 10:30 -12:00 1.50 WINDOWSCML CMPL T2 12:00 - 15:00 3.00 WINDOWSCML CMPL T2 15:00 - 16:00 1.00 WINDOWCIRC CMPL T2 16:00 - 20:00 4.00 WINDOWTRIP CMPL T2 20:00 - 20:30 0.50 WINDOWOTHR CMPL T2 20:30 - 21 :00 0.50 DRILL PULD PROD3 21 :00 - 22:00 1.00 DRILL DEQT PROD3 22:00 - 00:00 2.00 DRILL TRIP PROD3 00:00 - 01 :30 1.50 DRILL TRIP PROD3 01 :30 - 02:15 0.75 DRILL REAM PROD3 02:15 - 12:00 9.75 DRILL DRLH PROO3 12:00 - 00:00 10/20/2004 00:00 - 12:00 12:00 - 00:00 10/2112004 00:00 - 03:00 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Printed: 11/12/2004 11:23:10AM . . Legal Well Name: 1 E-114 Common Well Name: 1E-114 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Data F'rom~1?o HöUI"$ Code Sub Code 10/2112004 00:00 - 03:00 3.00 DRILL DRLH PROD3 03:00 - 04:15 1.25 DRILL CIRC PROD3 04:15 - 04:30 0.25 DRILL OBSV PROD3 04:30 - 10:30 6.00 DRILL TRIP PROD3 10:30 - 12:00 1.50 DRILL CIRC PROD3 12:00 - 15:00 3.00 DRILL TRIP PROD3 15:00 - 17:00 2.00 DRILL CIRC PROD3 17:00 - 20:30 3.50 DRILL TRIP PROD3 20:30 - 20:45 0.25 DRILL OBSV PROD3 20:45 - 00:00 3.25 DRILL TRIP PROD3 10122/2004 00:00 - 02:00 2.00 DRILL PULD PROD3 02:00 - 03:00 1.00 WINDOWPULD CMPL T3 03:00 - 06:00 3.00 WINDOWTRIP CMPL T3 06:00 - 06:30 0.50 WINDOWOTHR CMPL T3 06:30 - 07:30 1.00 WINDOWCIRC CMPL T3 07:30 - 13:00 5.50 WINDOWTRIP CMPL T3 13:00 - 15:00 2.00 WINDOWPULD CMPL T3 15:00 - 16:00 1.00 CASE RURD CMPL T3 16:00 -19:30 3.50 CASE PULR CMPL T3 Start: Rig Release: Rig Number: Spud Date: 9/25/2004 End: 10/26/2004 Group: 9/25/2004 1 0/26/2004 19:30 - 21 :30 2.00 CASE RUNL CMPL T3 21 :30 - 21:45 0.25 CASE RUNL CMPL T3 10/23/2004 21 :45 - 00:00 00:00 - 00:30 00:30 - 01:00 RUNL CMPL T3 RUNL CMPL T3 RUNL CMPL T3 2.25 CASE 0.50 CASE 0.50 CASE 01 :00 - 01 :30 0.50 CASE CIRC CMPL T3 01:30-02:15 0.75 CASE CIRC CMPL T3 02:15 - 06:30 4.25 CASE OTHR CMPL T3 06:30 - 08:15 1.75 CMPL TN RUNT CMPL T3 08:15 - 13:00 4.75 CMPLTN RUNT CMPL T3 13:00 - 14:30 1.50 CMPL TN RUNT CMPL T3 14:30 - 18:30 4.00 CMPL TN PULL CMPL T3 18:30 - 20:30 2.00 CMPL TN PULL CMPL T3 20:30 - 22:00 1.50 CMPL TN RUNT CMPL T3 Description of Operations on last connection. Finish pumping out Hi-vis sweep (Increase in cuttings 20%). Survey, Record slow pump rates, Monitor well. Back Ream out of hole at drilling rate to 7,725', Pulling speed 45 to 55 fUmin., Pull thru window with no problems. Pump weighted Hi-vis sweep, Circ hole clean at 315 gpm @ 2350 psi. RIH f/ 7,725' to 11,800', Wash f/11 ,800' to 11,833'. Circ at rate of 315 gpm @ 3400 psi, Change over to Solids free MOBM. Monitor well, POOH on elevators to 7,725', No problems Monitor well- OK. POOH to BHA @ 251 '. Lay down 2 jts. HWDP & Jars, 1 stand NMDC's., Down load MWD tools, Lay down MWD tools, Motor & Bit. Make up Baker whipstock retrieving tools, RIH wI 4-3/4" DC's. RIH to 7,403', Record UP 137K, DN 80K, Break circ. Hook whipstock on 2nd attempt on depth @ 7,471', Pull 60K over and unseat trip anchor, Pull up to 7,403'. Circ btm's up at rate of 8 bpm @ 2750 psi. POOH to BHA. Lay down whipstock retrieving tools, whipstock and space out pipe. Clean rig floor, Rig to run 4-1/2" Slotted liner. Run 3-1/2" Shoe & Bent joint, XIO's, Total of 61 joints Blank (1,891.52') and every other joint Slotted with total of 59 joints (2,387.58'), Last 2 joints Blank, Ran total of 120 joints, Ran total of 118 6-1/2" x 4-1/2" Spiralgliders 1 per joint for 118 joints. Make up Baker Model B1 Flanged Hook Hanger, RIH w. liner to top of window @ 7,465'. Break eire, Record UP wt of 97K, DN 60K, Torque at 10 RPM 3500 fUlb, Attempt to rotate at 10 RPM while lowering down past window, RIH & tag down on lower liner at 7,764' (On depth), Pick back up to 10' above window, Rotate 4 rounds and release torque, RIH and enter window on 2nd try. Continue RIH wI liner to 11,160' with no problems. Continue RIH with 4-112" liner to 11,808'. Ran past bottom of window @ 7,477' to 7,487'- 6 times turning Hook 3/4 turn each time until Hooked wI 35K (Found bottom of window 2.26' low), Top of liner @ 7,462.43', Shoe @ 11,808.89', Rehook wI 35K, Unhook - turn 1/2 turn and run past window 10', Turn 3/4 turn 2 more times and rehook wI 35K to confirm at same depth. Drop ball, Pump down at 3 bpm @ 600 psi, Pressure up to 3200 psi & Release from hanger. Circ btm's up at 8 bpm @ 2700 psi. POOH, Lay down liner running tool. PJSM, Rig & Ran LEM assembly as per detail. RIH wI LEM on drill pipe to 7,477' (Unable to work past 7,477'). Attempt to work thru hook hanger @ 7,477' - Tried all combinations of orientaions and slow rotation. Mule shoe would not penitrate hook hanger port to main well bore. POOH to LEM Assembly. Rig, POOH & Lay down LEM assembly, Lay down swivel,Stand back tubing in derrick, Lay down Seal Aseembly. Make up new Seal Assembly on bent joint, Run tubing from derrick, Make up LEM Assembly. Printed: 11/12/2004 11 :23:10 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: From - To Hours 10123/2004 10/24/2004 22:00 - 00:00 00:00 - 01 :30 01 :30 - 06:00 2.00 CMPL TN RUNT CMPL T3 1.50 CMPL TN TRIP CMPL T3 4.50 CMPL TN TRIP CMPL T3 06:00 - 09:15 09:15 -11:30 3.25 CMPL TN TRIP CMPL T3 2.25 CMPL TN PULD CMPL T3 11 :30 - 12:00 0.50 CMPL TN PULD CMPL T3 12:00 - 15:30 3.50 CMPL TN TRIP CMPL T3 15:30 - 16:00 0.50 CMPL TN TRIP CMPL T3 16:00 - 16:45 0.75 CMPLTN CIRC CMPL T3 16:45 - 20:00 3.25 CMPL TN TRIP CMPL T3 20:00 - 21 :00 1.00 CMPL TN PULD CMPLT3 21 :00 - 23:30 2.50 CMPL TN PULD CMPL T3 23:30 - 00:00 0.50 FISH FISH CMPL T3 10125/2004 00:00 - 01:00 1.00 FISH FISH CMPL T3 01 :00 - 02:30 1.50 FISH FISH CMPL T3 02:30 - 06:15 3.75 FISH FISH CMPL T3 06: 15 - 06:45 0.50 FISH PULD CMPL T3 06:45 - 12:00 5.25 FISH TRIP CMPL T3 12:00 - 13:00 1.00 FISH TRIP CMPL T3 13:00 - 13:30 0.50 FISH TRIP CMPL T3 13:30 - 14:00 0.50 FISH TRIP CMPL T3 14:00 - 14:30 0.50 CMPL TN PCKR CMPL T3 14:30 - 15:00 15:00 - 19:30 0.50 CMPL TN DEQT CMPL T3 4.50 CMPL TN PULD CMPL T3 RIH wI LEM Assembly on drill pipe to 4,750'. Cant TIH to 7468' Work Tight spot @ 7468' - Up wt 135k, Dn wt 85k - Worked past to 7513' stopped - Unable to work past 7513' - Tried several orientation multiple times wI up to 30k dn wt max. No results. After a conference with the town engineers workes several orientataions and set 50 k down wt on string. NO results. Could not get past 7513' TOH RIU & UD LEM assy - Clean rig floor of tools - Confer with engineers in town. Decision was made to attempt to run the LEM only to see if it would clear and Latch in. PIU bent jt wI seal assy on bttm and LEM only - XO to DP TlH to 7733' -( Top of "B" lat. ZXP @ 7732' ) Did not see ANY obstructions of any kind) It appears the Liner and Hook hanger are out the window - Up wt 138k, Dn wt 85k TOH to 7410' to be above window. CBU - Monitor well - Static- MOBM 9.3 ppg, Vis 86 out & in, PP 1200, PR 60 spm, 255 gpm - Small show of oil on BU - Gas<50 units. TOH UD LEM and clear & clean rig floor - Discuss options with town - The decision was made to attempt to fish the Hook Hanger& liner and attempt to re-hook hanger. MU Baker liner running tool wI bent jt of 2 7/8" under tool with circu sub and bull nose. TIH to 7450' MU top drive and attempt to orient out window. Orient bent joint thru window- Work torque in 1/2 turn per attempt - Total of 9 attempts and ran retreiving tool out window. Latched up running tool @ 7503' (Top of hook would be @ 7488'). PU Hook and Liner and work back thru window - No over pull, Liner free. Up wt 156K, Dn wt 65k. Orient and set hook hanger wI 30k dn, repeat release and hook 3 times to assure proper hook. Final hook all at same depth mark on DP w/35k dn wI.. Top of liner 7463.17' Drop 29132" ball and pump down - Last 5 bbls slow to PR 1.5 BPM, PP 300- Ball on seat - Pressure up to 3400 psi to release tooL- PU - tool free Monitor well - Static - TOH Make all service breaks and UD Baker running tool. Clear all tools from rig floor - RIU & PIU LEM assy per well plan. Seals will be run on bentjt. 10" bent, 14' up from seals.- TIH Can't TIH to 7460' Orient bent jt thru Hook Hanger @ 7472' into main well bore. Can't TIH to TOP of ZXP - @ 7758' seals became tight wI 25k dn wt - Work seals down to 7763' and latch LEM at proper depth. Pull test LEM to 10k "OK" Drop 29/32" ball and pump down - PR 3 BPM, PP 675. Slow to 1.5 bpm last 5 bbls - Ball on seat - Pressure up to 2900 psi to set packer, wait 5 min - Can't to pressure up to 3500 psi to neutralize tool. When tool neutralize it showed release.-P/U 2' free. Close annular and test packer to 1000 psi f/10 min ·OK" TOH - UD HWDP & DCs - UD Hybred SWDCs Printed: 11/12/2004 11:23:10AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Cd Sub o e Code Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 10/25/2004 15:00 - 19:30 4.50 CMPL TN PULD CMPL T3 ***Note*** MUD DOG not cleaning MOBM out of inside of DP. We will stand back DP in derrick and let it drain. (Will have 111 stds 4" DP in derrick - All else has been laid down. All HWOP, Hybred stands and Des) TOH standing back 4" DP in derrick Make service breaks and UD running tool. 19:30 - 21 :30 2.00 CMPL TN TRIP CMPL T3 21 :30 - 22:30 1.00 CMPL TN PULD CMPL T3 22:30 - 23:00 0.50 CMPL TN RURD CMPL T3 23:00 - 00:00 1.00 CMPL TN PULD CMPL T3 10/26/2004 00:00 - 00:15 0.25 CMPL TN SFTY CMPL T3 00:15 - 07:00 6.75 CMPL TN RUNT CMPL T3 07:00 - 09:45 2.75 CMPL TN RUNT CMPL T3 09:45 - 10:15 0.50 WELCTL OTHR CMPL T3 10:15 - 13:00 2.75 WELCTL NUND CMPL T3 13:00 - 15:00 2.00 WELCTL NUND CMPL T3 15:00 - 16:00 1.00 CMPL TN RURD CMPL T3 16:00 - 18:00 2.00 CMPL TN PULD CMPL T3 18:00 -19:00 1.00 WELCTL EQRP CMPL T3 19:00 - 23:30 4.50 CMPL TN PULD CMPL T3 23:30 - 00:00 0.50 CMPL TN OTHR CMPL T3 RlU and pull wear bushing Remove all un-needed tools, subs, eel. from rig floor - Clean working area of MOBM - RIU 4 1/2" tbg running tools and power tongs. Held PJSM on running 4 1/2" completion Ran 41/2" 12.6#, L-80 IBTM tbg with completion assembly to 7,400', ran a total of 235 jts 41/2" tbg Spaced out completion string, MU tbg hanger and landed tbg at 7,446' RILDS, landed tbg with open CMU sliding sleeve at 7,370' and DB-6 nipple at 522', st wt up 90K, down wt 57K, block wt 34K , tested hanger seals to 5,000 psi for 10 min, installed TWC Flushed out BOP stack NO BOP stack and set off NU Vetco Gray adapter spool and tree, tested void and tree to 5,000 psi for 10 min, pulled TWC RU to freeze protect well, clear cellar area and RU scaffolding Began LD 4" DP from derrick, freeze protected well while LD OP, displaced out 9.3 ppg OBM with diesel thru open CMU sliding sleeve at 7,370', displaced hole with 300 bbls of diesel at 6 bpm at 900 psi Installed BPV using lubricator Fin LD 4" Dp from derrick, LD a total of 112 stds Cleared rig floor and secured well RELEASED RIG @ 24:00 hrs 10/26/04, rig to move to 1 E-168 Printed: 11/12/2004 11:23:10AM '. Conoc;p.,illips Well bore Name 114 L2 Well Name 114 Slot Name Slot #114 lrtstaIIation NaTIe Pad 1 E Field Na'ne Kuoaruk River Unit ConocoPhillips Alas~c.,Slot #114 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wellbo.14 L2 Well path: MWD w/Mag-Sag-IIFR<7477 . 11833'> Date Printed: 8-Nov-2004 ,&¡. BAKER HUGHES INTEQ I Created 20-0ct-2004 I Last Revised 27 -Oct-2004 I Govemment ID 50-029-23223-00 I Last Revised 5-0ct-2004 I Grid NorthillQ 5959681.0000 I North 91 A3N lEast 226.61W I Grid Eastin!:! 550301.0000 I Latitude N70 18 2.2151 I LOllQitude W149 35 33.3755 I Eastina I Northina I Coord Svstem Name INorth Alianment 550528.194 5959591.109 AK-4 on NORTH AMERICAN DATUM 1927 datum True I Eastina 487754.6208 I Coord Svstem Name I North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True I Northina 5948985.8206 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7280.16 Feet on azimuth 48.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ;¿ 0 v( -/73 ¥ ConocoPhillips ConocoPhillips Alas~c.,Slot #114 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wellbo.14 L2 Well path: MWD w/Mag-Sag-IIFR<7477 - 11833'> Date Printed: 8-Nov-2004 r&i. BAKER IIUGIIES INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Section[ftl 7465.00 77.50 358.50 3489.68 509.52N 5318.19E 0.00 721.62 555615.14 5960276.06 7477.44 79.09 358.50 3492.20 521.70N 5317.88E 12.79 733.77 555614.74 5960238.23 7576.44 87.74 358.50 3503.54 619.92N 5315.30E 8.74 831.81 555611.51 5960336.42 7669.48 90.35 359.68 3505.09 712.92N 5313.83E 3.08 924.68 555609.41 5960429.41 7762.93 89.34 1.04 3505.35 806.37N 5314.41 E 1.81 1018.07 555609.37 596052?84 7855.61 88.91 0.24 3506.76 899.03N 5315.45E 0.98 1110.70 555609.78 5960615.50 7949.30 87.99 359.70 3509.30 992.68N 5315.40E 1.14 1204.28 555609.11 5960709.14 8043.88 89.86 359.86 3511.07 1087.24N 5315.04E 1.98 1298.75 555608.11 5960803.69 8136.52 89.74 3.22 3511.39 1179.84N 5317.53E 3.63 1391.37 555609.98 5960896.29 8230.10 89.25 3.62 3512.22 1273.25N 5323.11E 0.68 1484.93 555614.94 5960989.72 8323.95 88.30 3.66 3514.23 1366.88N 5329.06E 1.01 1578.73 555620.27 5961083.39 8417.52 89.03 4.24 3516.41 1460.20N 5335.51 E 1.00 1672.23 555626.09 5961176.74 8510.92 89.65 3.40 3517.48 1553.39N 5341.73E 1.12 1765.59 555631.68 5961269.96 8603.87 88.57 1.61 3518.93 1646.23N 5345.79E 2.25 1858.52 555635.12 5961362.82 8697.92 88.05 1.46 3521.70 1740.21N 5348.31E 0.58 1952.52 555637.01 5961456.80 8790.58 87.56 359.38 3525.25 1832.79N 5348.99E 2.30 2045.06 555637.07 5961549.38 8883.82 87.87 0.85 3528.97 1925.96N 5349.18E 1.61 2138.16 555636.64 5961642.53 8977.62 89.13 0.78 3531.42 2019.71N 5350.51E 1.35 2231.89 555637.34 5961736.28 9071.95 90.23 1.46 3531.95 2114.02N 5352.35E 1.37 2326.20 555638.55 5961830.59 9164.75 88.42 3.28 3533.04 2?06.73N 5356.19E 2.77 2418.99 555641.77 5961923.31 9257.75 88.54 1.53 3535.51 2299.61 N 5360.09E 1.89 2511.95 555645.05 5962016.21 9349.86 88.42 0.13 3537.95 2391.68N 5361.43E 1.52 2603.99 555645.77 5962108.27 9443.05 88.73 357.50 3540.27 2484.81N 5359.50E 2.84 2696.98 555643.22 5962201.38 9537.43 90.97 357.64 3540.52 2579.10N 5355.50E 2.38 2791.03 555638.58 5962295.63 9632.46 90.32 357.01 3539.45 2674.02N 5351.06E 0.95 2885.70 555633.51 5962390.51 9726.05 92.44 359.30 3537.19 2767.52N 5348.05E 3.33 2979.00 555629.88 5962483.98 9819.37 91.00 359.01 3534.39 2860.78N 5346.68E 1.57 3072.14 555627.88 5962577.23 9912.14 90.84 357.76 3532.90 2953.50N 5344.06E 1.36 3164.68 555624.64 5962669.92 10004.31 90.91 358.12 3531.49 3045.60N 5340.75E 0.40 3256.57 555620.71 5962761.98 10098.38 89.40 358.20 3531.24 3139.62N 5337.73E 1.61 3350.40 555617.06 5962855.97 10193.69 89.31 358.87 3532.31 3234.90N 5335.29E 0.71 3445.50 555613.99 5962951.21 10285.40 89.25 2.05 3533.47 3326.58N 5336.03E 3.47 3537.14 555614.11 5963042.90 10378.49 89.31 3.03 3534.64 3419.57N 5340.15E 1.05 3630.22 555617.61 5963135.90 10473.07 88.79 3.21 3536.20 3514.00N 5345.30E 0.58 3724.78 55562? .13 5963230.35 10565.98 88.33 1.89 3538.54 3606.79N 5349.43E 1.50 3817.65 555625.64 5963323.15 10659.86 88.67 1.57 3541.00 3700.59N 5352.27E 0.50 3911.50 555627.84 5963416.97 10750.97 89.50 2.06 3542.45 3791.64N 5355.15E 1.06 4002.59 555630.12 5963508.03 10840.96 89.65 3.09 3543.12 3881.54N 5359.19E 1.16 4092.58 555633.56 5963597.94 10931.93 89.37 2.66 3543.90 3972.39N 5363.76E 0.56 4183.54 555637.51 5963688.81 11022.67 88.76 1.44 3545.38 4063.06N 5367.00E 1.50 4274.26 555640.15 5963779.49 11111.82 90.69 3.33 3545.81 4152.12N 5370.71E 3.03 4363.40 555643.27 5963868.57 11203.00 88.97 3.35 3546.08 4243.14N 5376.02E 1.89 4454.57 555647.97 5963959.61 11295.04 87.34 1.29 3549.04 4335.05N 5379.75E 2.85 4546.55 555651.08 5964051.53 11384.55 89.40 1.79 3551.59 4424.49N 5382.15E 2.37 4636.01 555652.88 5964140.97 11474.04 90.45 2.03 3551.70 4513.93N 5385.13E 1.20 4725.50 555655.27 5964230.42 11564.51 92.01 3.50 3549.76 4604.26N 5389.50E 2.37 4815.94 555659.02 5964320.78 11654.81 92.81 4.27 3545.96 4694.28N 5395.61 E 1.23 4906.12 555664.53 5964410.82 11745.76 92.04 4.52 3542.11 4784.88N 5402.57E 0.89 4996.93 555670.89 5964501.46 11779.62 92.32 4.88 3540.83 4818.60N 5405.35E 1.35 5030.73 555673.43 5964535.19 11833.00 92.32 4.88 3538.67 4871.74N 5409.88E 0.00 5084.02 555677.62 5964588.36 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7280.16 Feet on azimuth 48.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated >/jI I. Conc>cdít,¡llips ConocoPhill;ps A,as,!C.,SIOI #114 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wellbor.4 L2 Wellpath: MWD w/Mag-Sag-IIFR<7477 - 11833'> Date Printed: 8-Nov-2004 r&ií. BAKER HUGHES INTEQ Comments MDrftl TVDrftl Northrftl Eastrftl Comment 7477.44 3492.20 521.70N 5317.88E Interpolated Azimuth 7576.44 3503.54 619.92N 5315.30E Interoolated Azimuth 11833.00 3538.67 4871.74N 5409.88E Proiected Data - NO SURVEY Hole Sections Diameter Start Start Start Start End End End Start Wellbore finl MDrftl TVDrftl Northrftl Eastrftl MDrftl TVDrftl Northrftl Eastrftl 24.000 0.00 0.00 O.OON O.OOE 108.00 108.00 O.OON O.OOE 114 131/2 108.00 108.00 O.OON O.OOE 4205.00 2299.28 480.21S 2981.79E 114 97/8 4205.00 2299.28 480.21S 2981.79E 8741.00 3725.90 1783.26N 5349.05E 114 6314 7465.00 3489.68 509.52N 5318.19E 11833.00 3538.67 4871.74N 5409.88E. 114 L2 Casinas Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MDfftl TVDrftl Northrftl Eastrftl MDfftl TVDrftl Northrftl Eastrftl ~O" Conductor 0.00 0.00 O.OON O.OOE 108.00 108.00 O.OON O.OOE 114 103/4" CasinQ 0.00 0.00 O.OON O.OOE 4198.00 2296.55 479.01S 2975.45E 114 7 518" Casino 0.00 0.00 O.OON O.OOE 8736.00 3725.17 1757.33N 5351.02E 114 4 112" Liner 7462.43 3489.12 507.01N 5318.26E 11808.89 3539.64 4847.74N 5407.83E 114 I ? All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 95.00 above mean sea level) Vertical Section is from O.ooN O.OOE on azimuth 2.29 degrees Bottom hole distance is 7280.16 Feet on azimuth 48.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · ~~!Æ~! aD F fÆlfÆ~~~fÆ Jt"~~1iA OIL AND GAS CONSERVATION COMMISSION / ~. FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-114L2 ConocoPhillips Alaska, Inc. Permit No: 204-173 Surface Location: 5188' FNL, 116' FEL, SEC. 16, T11N, RIOE, UM Bottomhole Location: 319' FNL, 29' FEL, SEC. 15, T11N, RIOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU lE-114, Permit No. 204-171, API 50-029-23223-00. Production should continue to be reported as a function ofthe original API number stated above. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907 659-3 (pager). Si BY ORDER 0.l.. THE COMMISSION DATED this~day of October, 2004 cc: Department ofFish & Game, Habitat Section w/o enc1. Department of Environmental Conservation w/o enc1. ~ ConocoPhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com September 8,2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Injector, 1E-114 l2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production well bore, the upper lateral wellbore of a multilateral horizontal well, in the West Sak "0" sand. /The main bore of this well will be designated 1E-1l2 and has been permitted under a separate application, submitted on September 8,2004. This application is for the upper lateral of that well, to be designated 1E-1l4L2. The expected date that operations will begin on 1E-1l4L2 is October 22,2004. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. Under separate cover, ConocoPhillips is applying for a spacing exception for this well bore, under the terms of 20 MC 25.055 Please contact Steve Shultz at 263-4620 if more information is needed to issue a Permt to Drill for 1E- 114L2. Sincerely, ~~ Randy Thomas GKA Drilling Team Leader OR\G\NAl 1a. Type of Work: Drill0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . ~/iÍ RedrillU 11b. Current Well Class: Stratigraphic Test 0 4668' FNL, 229' FEL, Sec. 15, T11N, R1OE, UM Total Depth: 319' FNL, 29' FEL, Sec. 15, T11 N, R10E, UM ./ 4b. Location of Well (State Base Plane Coordinates): STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 y- 5959681 ./ It. Maximum Hole Angle: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 5188' FNL, 226' FEL, Sec. 16, T11 N, R10E, UM ./ Top of Productive Horizon: Surface: x- 550301 v 16. Deviated wells: Kickoff depth: 7528 18. Casing Program Size Hole Driven 13.5" 9-7/8" 6.75" Casing 20" 10.75" 7-5/8" 4.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (It): 20. Attachments: Filing Fee Property Plat Weight 94# 45.5# 29.7# 12.6# Specifications Grade Coupling K-55 Welded L-80 BTC L-80 BTCM L-80 DWC ./ ../ Zone- 92° Length 80' 4154' 8752' 4357' PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Length Size (.J L- t BOP SketchD o Diverter Sketch 0 21. Verbal Approval: Commission Representative: ExploratoryU Development Oil U Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-114l2 6. Proposed Depth: 12. Field/Pool(s): MD: 11849' TVD: 3574' Kuparuk River Field 7. Property Designation: .I West Sak Pool ./ ALK 25651 8. Land Use Permit: 13. Approximate Spud Date: 10/22/2004 ADL 469 9. Acres in Property: 2560 14. Distance to Nearest Property: 5051' 10. KB Elevation 15. Distance to Nearest 4 1D-103 @ 650' . Well within Pool: (Height above GL): 28 feet 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 1673 psig I Max. Surface Pressure: 1246 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 108' 260 cf ArcticCrete 2295' 718 sx ASLite, 189 sx DeepCrete 3733' 508 sx DeepCrete 3574' slotted liner Top MD TVD 28' 28' 28' 3494' MD 108' 4182' 8780' 11849' 28' 28' 28' 7492' (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD I Perforation Depth TVD (It): Drilling Program0 Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randy Thomas Signature ~ ~ Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone "UØS- 6tJ ~o Date -;..{ 7 (0 '1 PreDared bv Sharon Al/suD-Drake Commission Use Only I API Number: I Permit Approval 50-ðZJ¡- 232.2 3--t?! Date: /p/~/t7 r Samples required 0 Yes ..g'"NO Mud log required 0 Yes ~ No Hydrogen sulfide measures 0 Yes 8 No Directional survey required ~Yes 0 No t4'.'io'\A..'-3l1-\. ~~~")\-. \3,0\'~~\-\ V".~{"O \ ~ \l.\.~o..·'C~ , ~\Q:.~,,-, C~~"'--~~o..\~'-l \.0 ~ o^'- ~~~~,. COW'SSIONER :~~~:~:'ON O.æ /-f fbf Number: Permit to Drill ;2Ot/-/73 Conditions of approval : Form 10-401 Revised 3/2003 . Isee cover letter for other requirements / ORIGINAL Submit in duplicate · APPliceor Permit to Drill, Well 1 E-114 L2 Revision No.O September 2, 2004 Permit It - West Sak Well #1 E-114 L2 ("D" Sand) Application for Permit to Drill Document M~xïr'r'liZE Well Vgll,J~ Table of Contents 1. Well Name..................................................................................................................... 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................2 2. Locati on Su m mary....................................................................................................... 2 Requirements of 20 AAC 25.005(c){2) ................................................................................................2 Requirements of 20 AAC 25.050(b) ....................................................................................................3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(c){3) ........ ......... ..... ....... ....... ..... ........ ....... ........... ....... ............... ....... 3 4. Drilli ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c){4) ...............................................................................................3 5. Procedure for Conducting Formation Integrity Tests.............................................3 Requirements of 20 AAC 25.005 (c){5) ...............................................................................................3 6. Casi ng and Ceme nting Prog ram................................................................................ 4 Requirements of 20 AAC 25.005(c){6) ... ....... ....... ...... ........ ........ .... ..... ........ .............. ..... ..................... 4 7. Diverter System Information ............... ...................................................... ......... ........4 Requirements of 20 AAC 25.005(c){7) ... ..... .......... ..... ....... ........ ..... ........ ....... .... ....... .......... .......... ....... 4 8. Dri II i ng Flu id Program................................................................................................. 5 Requirements of 20 AAC 25.005(c){8) ................................................................................................ 5 Lateral Mud Program (MI FloPro NT) .................................................................................................. 5 9. Abnormally Pressured Formation Information ........................................................5 Requirements of 20 AAC 25.005 (c){9) ...............................................................................................5 1 O. Seism ic Analysis.......................................................................................................... 5 Requirements of 20 AAC 25.005 (c){i0) .............................................................................................5 11. Seabed Condition Analysis.. ........................................................................... ........... 5 Requirements of 20 AAC 25.005 (c){i1) .............................................................................................5 12. Evidence of Bonding ............................ ............. .......................................................... 6 Requirements of 20 AAC 25.005 (c){i2) ............................................................................................. 6 OR\G\NAL L2 PERMIT IT (Injector) RevO.doc Page 10f7 Printed: September 2, 2004 · APPliceor Permit to Drill, Well 1 E-114 L2 Revision No.O September 2, 2004 13. Proposed Drilling Program ............. ............................................... ........................ ..... 6 Requirements of 20 AAC 25.005 (c)(13) .............................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6 Requirements of 20 AAC 25.005 (c)(14) .............................................................................................6 15. Attach ments........................................."........................................................................ 7 Attachment 1 Directional Plan ........... ............. ...... ...... ........ ........ ... ....... ....... ............ ...... ..... ......... ........ 7 Attachment 2 Drilling Hazards Summary...... ......... ... ......... ....... ............ ....... ..... ...... ...... ...... ........ ...... .... 7 Attachment 3 Well Schematic.. ...... ............. ...... ...... ........ ...... ............ ...... ... ... ...... ....... ...... ..... ........ ..... 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1 E-114 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dríll must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 5,959,681 Eastings: 550,301 FNL:5188', FEL:226', See 16, T11NjRlOE, UM RKB Elevation I 94.5' AMSL Pad Elevation 66.5' AMSL ../ Location at Top of Productive Interval (West Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,960,239 Eastings: 555,573 FNL:4668', FEL:229, See 15, T11NjRlOE, UM / Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7492' 3494' 3414.0' Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,964,589 Eastings: 555,735 FNL:319', FEL:29', See 15, T11NjRlOE, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 11849' 3574' 3479.0' and (D) other information required by 20 MC 25.050(b); L2 PERMIT IT (Injector) RevO.doc Page 2 of 7 Printed: September 2, 2004 ORIGINAL · APPliC.or Permit to Drill, Well 1 E-114 L2 Revision No.O September 8, 2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a pla~ drawn to a suitable scale, showing the path of the proposed wel/bore, including all adjacent wellbores within 200 feet of any portion of the proposed well,· Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record~ and show that each named operator has been furnished a copy of the application by certified mail,· or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a PermIt to Drill must be accompanied by each of the following itemf;,~ except for an item already on file wIth the commission and identified in the application: (3) a diagram and description ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 AAC 25.03~ or 20 MC 25.031., as applicable/ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-114 L2. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by ei'lch of the following item~ except for an item already on file with the commission and identified in the application: (4) information on drilling hazard~ including (A) the maximum downhole pressure that may be encountered, criteria used to determine it and maximum potential surface ;.Î pressure based on a methane gradient/ ..L> ,,¡.{ý.c> The expected reservoir pressures in the West Sak sands in the 1E-114 L2 area vary from ~0.44 to '0.47 .... psi/ft, or 8.6 to 9.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1,422 psi, calculated thusly: MPSP =(3560 ft)(0.47 - 0.11 psi/ft) = 1245.66 psi ... (B) data on potential ga5' zones/ The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strat4 lost circulation zone~ and zones that have a propensity for differential sticking/ Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25. 030(f)/ The parent wellbore,lE-114, will be completed with 75/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance OR'G\NAL L2 PERMIT IT (Injector) RevO.doc Page 3 of 7 Printed: September 8, 2004 · APPIiCefor Permit to Drill. Well 1 E-114 L2 Revision No.O September 2, 2004 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a PermIt to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25. 030, and a description of any slotted liner; pre- perforated liner; or screen to be installed/ 4 1/2 6 3/4" "A" slotted Lateral (lE- 114) 4 1/2 6 3/4" slotted "B" Lateral (s......... (lE-114 Ll) 4 1~ 6 3/4 -----r2.6 slotted "0" Lateral (lE-114 L2) ---- 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applicatIon for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2)/ 7784/3560 11854/3633 Slotted- no 7492/3494 1184913574 s::n:¿ cement ....-----...... --- ~. Casing and Cementing Program See also Attachment 3, APO for lE-114: Cement Summary Csg/Tbg OD (in) 20 X 34 Hole Size (in) 42 8tm MD/TVD (fl) 108 / 108 Weight (Iblft) 94 Grade K55 Connection Welded Length (fl) 80 Top MD/TVD (fl) 28 / 28 10 3/4 28 / 28 4182 /2295 13 1/2 L-80 45.5 BTC 4154 7 5/8 28 / 28 8780 / 3733 9 7/8 29.7 L-80 BTCM 8752 12.6 8780/3733 11870/3808 L-80 OWC 3090 12.6 L-80 OWC 4070 L-80 ---- OWC 4357 ------- -. No diverter system will be utilized during operations on lE-l14 L2 Cement Program Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 718 sx ASLite Lead, 189 sx OeepCRETE Tail Cement Top planned @ 5500' MO / 2750' TVO. Cemented w/ 508 sx OeepCRETE Slotted- no cement ...~ ORIGINAL L2 PERMIT IT (Injector) RevO.doc Page 4 of 7 Printed: September 2, 2004 · APPlic.or Permit to Drill. Well 1 E-114 L2 Revision No.O September 2, 2004 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c){8) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (8) a drilling fluid program including a diagram and description of the drilling flUId system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) ¡/'. Properties Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Electric Stability Chlorides (mgll) pH API filtrate (cc 130 min) **HTHP filtrate (cc 130 min) MBT (Ib 1 gal) ./ 18-28 650-900 40000 N/A <4 <10 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.03J(t}; Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c){10) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test we/~ a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform mobile bottom-founded structure, jack-up rig, or floating drilling vesse~ an analysis of seabed conditions as required by 20 AAC 25.061(b}; Not applicable: Application is not for an offshore well. ORIGINAL L2 PERMIT IT (Injector) RevO.doc Page 50f7 Printed: September 2, 2004 · APPIiC.or Permit to Drill, Well 1 E-114 L2 Revision No.O September 2, 2004 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met· Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program for 1E-114 L2 is listed below. (Note: Previous operations are covered under the 1E-114 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 7492' MD 3494'1VD, the top of the D sand. 2. Mill 63/4/1 window. POOH. / 3. Pick up 63/4/1 drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D/I sand lateral at 11849' MD / 3574'1VD, as per directional plan. ,/ 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4 1/2/1 slotted liner. ~ 1 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. Displace liner annulus and liner to 9.3 ppg weighted brine. 10. POOH, if the well is to be an injector then pick up a lateral entry module (LEM), RIH and set into the "D/I sand hook hanger, release from LEM. 11. POOH and lay down drill pipe 12. MU completion equipment for injection well and RIH 13. Locate top of PBR on the hook hanger, space out and stab seal assembly into PBR 14. Install BVP, and ND BOPE, NU X-mas tree, Shear out gas lift mandrel and freeze protect well. 15. Secure well, rig down move out 16. RU wireline, replace shea rout valve on GLM with dummy valve 17. RD wireline and place well on 180 days of pre-production through gas lift prior to injection service. /"' 13. Discussion of Mud and Cutting; Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. 080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1E Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1E Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved 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. ORIGINAL L2 PERMIT IT (Injector) RevO.doc Page 6 ofl Printed: September 2, 2004 · 14. Attach ments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL APPlicefor Permit to Drill, Well 1 E-114 L2 Revision No.O September 2, 2004 L2 PERMIT IT (Injector) RevO.doc Page 70fl Printed: September 2, 2004 . . c:onoa*hillips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 1 Wellbore: 114L2 Well path: 114L2 Verso #2 Date Printed: 9-Aug-2004 -II: INTEQ Wellbore ·~1a~~~=====~~-_.-- ·_-=-~==·~····_==~·-J~~:~~~QQi~-=___=·-=--_···_····_----_..====JL9~:;~;~e4~___=~__~~~====-__·~~==-===__=__= ~-_.__.-..,.--.-...--.~-----~-~---~--, "'-'~--~~-~---""---------~"""""""-~-~--'-~"'"--- -~--~- wen Name .11L_____ ......._._ __.._. .~. -IGoverQITlen..t__IId_-...._......._-..._ lL stR d .. ..__ ..... __ -1__________==._____ .<!~Fe:;~~_ ---~ -------_._-~--- Slot Name Slot #114 I Grid Northino 5959681.0000 I Grid Eastino I Latitude 550301.00.illL__ N70 18 2.2151__ I Lonoítude W149 35 33.3755 I North 91.43N lEast 226.61W <./ ~-~~._.-~- Installation Name Pad 1 E I EastinolNorthino . 550528.1946 . 5959591.1090 I Coord System Name I North Alionment AK-4 on NQFITH AMERICAN DATUM 1927 datu~ _ True Field NalTlé Kuparuk River Unit I EastinQ .. . 487754.6208 Northino 5948985.8206 ~ J Coord SvstemNarne .. . NorthAliQnrnenf I AK-4 onNORTH AMERICAN DATUM 1927 datu .. .... True ---- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . r___~·U· '-.uI1UUJl"'"111 Ips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Well bore: 114L2 Wellpath: 114L2 Verso #2 Date Printed: 9-Aug-2004 -II: INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [degf10 Section[f _ North) East) ~ .OftL__tL.__ _._ 7491.81 75.00 ..£.~.._~Aª-4.0Q..~~j). 00 522. 75l'L_.9216cJ4.E_.Q9602..3MQ._QQ55nillL_ 0.OL333.15 Top Whipstoc!srn.~e~Ti!LO!l....-_~___. 7503.81 76.91 2.29 3496.91 3401.91 534.38N 5276.60E 5960250.64 555573.39 15.90 744.79 End of Build 7508.31 76.91 2.29 3497.93 3402.93 538.76N 5276. Z.ß~_5960255 02 555573.5~_..Q,00 ....149.W_J;!ase Whipstoj:j< FacEL__._ 7521.81 76.91 2.29 3500.99 3405.99 551.90N 5277.30E 5960268.16 555573.97 0.00 762.33 End of Hold 7528.31 77.30 2.29 3502.44 3407.44 558.23N 5277.56E 5960274.49 555574.18 6.00 768.66 End Milled Openhole. KOP 7621.81 82.91 2.29 3518.51 3423.50 650.23N_ 52ª-.j.23.E_. 5960366.50 ....Q.55577.23 6.00 860.73 ~--,._~~-~ 7721.81 88.91 2.29 _ 3525.64 3430.64 749.85N 5285.20E 5960466J4 555580.54 6.00_ 960A~.__ 7726.71 89.20 2.29 3525.72 3430. 72 ~4. 75N 5285.40E 5960471.03 555580.70 .6.00 965.33 End of Build 7826.71 92.20 2.29 3524.49 3429.49 854.65N 5289.38E 5960570.95 555584.02 3.00 1065.31 End of Build 7900.00 92.20 2.29 3521.68 3426.68 927.~N 5292.30E 5960644.14 Q.Q9..986.45 0.00 1138.55 7984.51 92.20 2.29 3518.43 3423.43 1012.20N 5295.67E _ 59ß..0728.53 _555589.25 0.00 _122:tQQ....End of Hold 8084.50 89.20 2.29 3517.20 3422.20 1112.10N 5299.66E 5960828.43 555592.57 3.00 1322.97 SIC Kick off Point 8100.00 89.20 2.29 3517.42 3422.42 1127.Q1.3N 5300.27E 5960843.~2_555593.08 0.00 1338.41___ 8200.00 89.~2.29 3518.81 3423.81-. 1227.49N 5304.26E 5960943.85 _.555596.40 0.00 1438.46 8300.00 89.20 2.29 3520.21 3425.21_ 1327.40N 5308.25E 5961043.77 555599.72 0.00 1538.45 8400.00 89.20 2.29 3521.60 3426.60 1427.32N 5312.23E 5961143.70 555603.03 0.00 1638.44 8500.00 89.20 2.29 3522.99 3427.99 1527.22N 5316.22E 5961243.62 555606.35 0.00 1738.43 8600.00 89.20 2.29 3524.39 3429.39 1627.14N 5320.21E 5961343.5!L...J5.§5609.67 0.00 1838.42 8700.00 89.20 2.29 3525.78 3430.78 1727.05N 5324.19E 5961443.47 555612.99 0.00 1938.41 8800.00 89.20 2.29 3527.17 3432.17 1826.96N 5328.18E 5961543.40 555616.30 0.00 2038.40 8900.00 89.20 2.29 3528.56 3433.56 1926.87N 5332.17E 5961643.33 555619.62 0.00 2138.39 9000.00 89.20 2.29 3529.96 3434.96 2026.78N 5336.15E 5.1361743.25 555622.94 0.00 2238.38 9100.00 89.20 2.29 3531.35 3436.35 2126.69N 5340.14E 5961843.18 555626.25 0.00 2338.37 9200.00 89.20 2.29 3532.74 3437.74 2226.60N 5344.12E 5961943.10 555629.57 0.00 2438.36 9300.00 89.20 2.29 3534.14 3439.14 2326§jN 5348.11E....J5962043.03 555632.89 0.00 2538.35 9400.00 89.20 2.29 3535.53 3440.53 2426.42N 5352.10E 5962142.95 555636.21 0.00 2638.34 9500.00 89.20 2.29 3536.92 3441.92 2526.33N 5356.08E . 5962.242.88 555639.52 0.00 2738.33 9600.00 89.20_ 2.29 3538.31 3443.31 2626.24N 5360.07E 5962342.80 555642.84 0.00 2838.32 9700.00 89.20 2.29 3539.71 3444.71 2726.16N 5364.06E 5962442.73 555646.16 0.00 2938.31 9800.00 89.20 2.29 3541.10 3446.10 2826.07N 5368.04E 5962542.65 555649.47 0.00 3038.30 9900.00 89.20 2.29 3542.49 3447.49 2925.98N 5372.03E 5962642.58 555652.79 0.00 3138.29 9936.45 89.20 2.28 3543.00 3448.00 2962.39N 5373.48E 5962679.00 555654.00 0.00 3174.74 WS 1E C6 D-MDPT#1 RVSD080304. End of Hold 9954.63 89.07 2.81 3543.27 3448.27 2980.55N 5374.29E 5962697.16 555654.69 3.00 3192.92 SIC Kick off Point 10000.00 89.07 2.81 3544.01 3449.01 3025.86N 5376.52E 5962742.48 555656.61 O.O-º-. 3238.28 10100.00 89.07 2.81 3545.63 3450.63 3125.73N 5381.43E 5962842.37 555660.85 0.00 3338.26 10200.00 89.07 2.81 3547.26 3452.26 3225.60N 5386.34..E 5962942.26 555665.09 0.00 3438.24 10300.00 89.07 2.81 3548.88 3453.88 3325.46N 5391.24E 5963042.14 555669.33 0.00 3538.23 10400.00 89.07 2.81 3550.50 3455.50 3425.33N 5396.15E 5963142.03 555673.57 0.00 3638.21 10500.00 89.07 2.81 3552.13 3457.12 3525.20N 5401.06E 5963241.92 555677.81 0.00 3738.19 10600.00 89.07 2.81 3553.75 3458.75 3625.06N 5405.97E 5963341.81 555682.05 0.00 3838.17 10700.00 89.07 2.81 3555.37 3460.37 3724.93N 5410.88£_ 5963441.69 555686.29 0.00 3938.16 10800.00 89.07 2.81 3556.99 3461.99 382479N 5415.79E 5963541.58 555690.53 0.00 4038.14 10900.00 89.07 2.81 3558.61 3463.61 392466N 5420.70E 5963641.47 555694.77 0.00 4138.12 11000.00 89.07 2.81 3560.24 3465.24 4024"53N 5425.61 E_Q.~637 41.35 555699.01 0.00 4238.11 11100.00 89.07 2.81 3561.86 3466.86 4124.39N 5430.52E 5963841.24 555703.25 000 4338.09 11200.00 -ªª",º7 2.81 3563.48 3468.48 4424.26N 5435.43E 5963941.13 555707.49 0.00 4438.07 -~ 11300.00 89.07 2.81 3565.10 3470.10 4324.13N 5440.34E 5964041.01 555711.73 0.00 4538.05 11400.00 89.07 2.81 3566.72 3471.73 4423.99N 5445.25E 5964140.90 555715.97 0.0~L._4638.04 11500.00 89.07 2.81 3568.35 3473.35 4523.86N 5450.16E 59642401.!L 555720.22 0.00 4738.02 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~illips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 3 Wellbore: 114L2 Well path: 114L2 Verso #2 Date Printed: 9-Aug-2004 .Jr: INTEQ 11600.00 11700.00 .J 1800.00 11848.61 Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[f ___~~_~_ . No[t.hL___~_.Eastl.~_ Oft1 t1 _ 89.QL._...2Jll 3569.97 34 74.97.__4623. 721\!-ºL\55. 0?.E~ªº.4JAº--Q!L~2ºnAA.Q__9. 00 _4..&':i§JllL~..______._. ____.. __.m_~__ 89.07 2.81 3571.59 3476.59 4723.59N 5459.98E 5964440.56 555728.70 0.00 4937.98 8¡¡JL~~2J~1.~Z:uL..~78.21.._.Aª29A6N 546489E _.Q964540.4p_ __555Z.~~._ 0.00 5037.9L-. 89.07 2.81 3574.00 3479.00 4872.00N 5467.27E 5964589.00 555735.00 0.00 5086.56 TO, 5 1/2in Uner, WS 1 E C6 0 TOE RVSD080304, 4 112in Casing, End of ...,. _euildlTurn _______~ ----~-----~--~-------_._-----------~--------~--------- All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Datum #1 95.Oft above mean sea level) Vertical Section is from O.OON O.OOE on azirnuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~illips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 4 Wellbore: 114L2 Wellpath: 114L2 Verso #2 Date Printed: 9-Aug-2004 øtI: INTEQ Comments MDrftl TVDfftl __~ Eastfftl Northrftl _ Co.mment_._..~___~._._____.______~___ 7491.81.____3494.0Q..~~liL1.4E__ __ 522.z.QI'L_~I.Q¡;LWhi~tocKf<lce__. _ .u_________...__._.____.._~.._.___ ~lQQ8.3L_m__ 3497~ª_ª._ __...!:>276. 78E __~_~6.2ºN___ Ba~.YI,lb[¡¿~tocK.f.ª_c~__...____..._. ._um__._______ __________ .. ______ . m_____u ____ _...TI>28.3L__~.._350244 _....._.~277.56E __.~.._ 558.23N ..-.ßlc:LMilled Oº~J]I:1ºJ~, KOP.. .__.________ m _____~_______~____________ 11848.61 3574.00 5467.27E 4872.00N TD. 5 1f2in Liner ~----~- --~-----_.~_.-~-"-----~-~-_.~--~- ~-~~--- Hole Sections Diameter I Start I Start I Start J Start I End I End finl MDfftl TVDfftl Northfftl Eastfftl MDfftl TVDfftl 63/4 7491.81 3494.00 n~4.2]5N_ ___5276.14E 11848.61 3574.00 I End iEnd\nEaStf;!] Wellbore Northfftl 4872.00N 5467.27E 114L2 Casinas Name 1~6iftl .I~fftl. I~~~hfftl I~~~tfftl .I~~:l I~~.. I~~~~rftl .J~:~:ft1 wellbore 7491.81 3494.0~ 522.75N 5276.~184ML1- 357~4872.00N 5467.21E 114L2 4 1f2in Casinq ~~ Taraets -~ Name Northfftl Eastfftl TVDrftl Latitude Lonqitude Eastil1Q NorthinQ WS 1 E C6 D TOE 4872.00N 5467.27E 3574.00 N70 18 50.1112 W149 32 53.8802 555735.00 5964589.00 RVSD080304 WS 1E C6 2962.39N 5373.48E 3543.00 N70 18 31.3311 W149 32 56.6563 555654.00 5962679.00 D-MDPT#1 RVSD080304 WS 1E C6 DTOP 522.75N 5276.14E 3494.00 N70 18 7.3381 W149 32 59.5453 555573.00 5960239.00 RVSD080304 WS 1E C6 2962.73N 5323.48E 3546.00 N70 18 31.3347 W149 32 58.1147 555604.00 5962679.00 D-MDPT#2 RVSD010704 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL <= 0 -800 0 N II E u -400 Q) iii u C/) -0 400 o :::¡') 800 11200 ~1600 rt (1) 2000 > (1) 2 2400 l- I V .. ..... ConocoPhillips Alaska, Inc. 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 Vertical Section (feet) -> Azimuth 2.29 with reference 0.00 N, 0.00 E from Slot #114 (STRONG!) Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E , RKB Elevatlo", 95' KOP 6.00 Bld/Trn 4/100 18.00 Bld/Trn 6/100 32.00 44.00 DLS: 6.00 deg/100ft 2800 EOC Top T-3 Top K-15 10 314" Casing PI. 3200 69.80 Start 200' Pump Tangent Bld/Trn 5/100 65.40 Top Ugnu C 64.31 DLS: 5.00 deg/100ft TOQ.Ug[1.u B 65.76 TOp ugnu A 67.66 70.24 K-13EOC 73.39 Q ·0· s\ S'3\\\ r;:¡O C ---..¿) ,\o~-.¡.Je~~N\\Ò &~~£>¡>.-A¡>.-~ ~ íO~ -.¡.Jes 1 fJ\'Ô' cs9· S'3v..¡>.?-· \!'leS\ íO~ I I 3600 4000 4400 -1200 -800 -400 0 Seale 1 em = 200 ft 400 800 Slcmt #ßpt #114 Well: 114 Wellbore: 114 Conoc~illips Created by: Planner Date plotted: 3-Sep-2004 Plot reference is 114. - Ref wellpath is 114 Vers. #2. Coordinates are in feet reference Slot #114. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 . Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. . . 114L21 " ~~ij '" o '" " E Q " '" S _ 3200 - () .æ - 3360 .c. - Q, () C 3520 <:) ::::t) - G) - z: » r- ¡¡; u :e 3680 () > () ::s I.. l- I V '" o '" " E Q " ~ 3200 - - :ß 3360 ~ .c. 15.. 3520 () C ¡¡; 3680 U :.e () > 3840 () ::s I.. I- 4000 I V ConocoPhillips Alaska, Inc. --...---.-...--- Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E INTEQ ~ ~\'3-cef('3-ceo\e.ý...O? ¡ 73 3 ,,~ 5 :1 ,,\Otge{l'ri O? - . ~OC -.;o~~,,~~~~\eô '¡Sþ¥- f('3-~f('3-~o\e'\<! ~,~~ ~~~~W"~~9~ - It. \) . . . III -.;n\à'lC.f' ô \~)P · 'J'IeS\ s~ 3\^SJ:J CoG -= ,Y/ff ç:JI - . . III III ""\ 09 ~\).~ô € Sø.¥- ~ ~ 'J'IeS\ þ.:ð. ""\09 Yo þ.:3 3840 --4 ~'f! 0· \'\ Î:I0 1 SI'Õ' C"\\Ô ð. S'3-¥-¡X2.· ~e"\ -.;o? 4000 320 480 640 Scale 1 cm = 80 ft 800 960 1120 1280 1440 1600 1760 1920 2080 2240 2400 2560 2720 Vertical Section (feet) -> Azimuth 2.29 with reference 0.00 N, 0.00 E from Slot #114 89.07 .. 189.01 rt'1 Top West Sak A2, 7 5/8" Csg. PI. 11 Yo III ~\Ô ð.\'\ () 't;.oG Curve 3/100 "" EOC 4160 1760 1920 2080 2240 2400 2560 Scale 1 cm = 80 ft Slot: Slot #114 Well: 114 Wellbore: 114 III 't;.OC Conocd)í,illips Created by : Planner Date plotted: 3-8ep.2004 Plot reference is 114. Refwellpath is 114 Verso #2. Coordinates are in feet reference 810t #114 . True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. 89.07 I I 89.01 e Curve1?88° 1t" ~ 2880 3040 3200 3360 3520 3680 3840 89.07 I 189.01 TO,5 112in Liner~ 114L2 TO, 4 1/2in Liner~ ---.; 114L 11 .....LI TD,4 1/2 Liner ~ . 89.07 I 2720 2880 3040 3200 3360 3520 3680 3840 4000 4160 4320 4480 4640 4800 Vertical Section (feet) -> Azimuth 2.29 with reference 0.00 N, 0.00 E from Slot #114 5440 4960 5120 5280 · . lE-114L2 Drillina Hazards Summary 6 3/4" Open Hole / 4 1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low ./ Low Mitigation Strategy Stripping drills, Shut~in drills, Increased mud weight. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out Lost Circulation Hole Swabbing on Trips Moderate Low ORIGINAL 1£-114 Drilling Hazards Summary prepared by Steve Shultz 8/13/2004 4:04 PM Tubing String 4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift KOP: 300', build at 3-5 deg/100' 6-3/4" Hole, 4-1/2" Liner Set @ 11,849' MD, 3,574' TVD illips West Sak 7 -5/8n Injector 1E..114 I Com pletion 13-112" Hole, 10-3/4" Casing, 4,182' MD, 2,295' TVD 'D' Sand Lateral and all laterals are Rotary Steerable. B-sand Casing Exit at 7,784' MD 'B' Sand Lateral 6-3/4" Hole, 4-1/2" Liner Set @ 11,854' MD, 3,633 TVD 'A' Sand Undulatina Lateral 6-3/4" HOle, 4-112" Liner Set @ 11,870' MD, 3,808' TVD Marc Q, Kuck OWgT!1Je; !!¡¡ker Oil Too!. 1E·114· TIÍ~latera¡ Completîon ~ InjfJ:ctor- Date: ¡ 4,000 KRU . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME !Ó2 tL / E~/I t( LZ- PTD# WLf'.- /7-3 Development V Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL v/ (If API num ber last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUE". Tbe permit is for a ,new wen~9resegment of existing well k/Z 1<- 1£ -.11 'f Permit No,µ;x.¡-/7/ API No. 5""t.l bvì -.Z-3¿.Z;S- cO Production. sbould continue to be reponed as a function 'of tbe original API number stated above. BOLE ]n accordance witb 20 AAC 25.005(f), an records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for we)) (name on permit). PJLOT (PH) SPACING EXCEPT] ON DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance witb 20 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to the spacing .exception tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample inter:vals tbrougb target zones. Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 E-114L2 Program SER _ Well bore seg ~ PTD#: 2041730 Company CONOCOPHILLlPS ALASKA INC Initial ClassfType SERIPEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal D Administration '1 P~rmit fee attaçhe~. - - - - - - - .... .NA Multilater.al. wellsegme.nt; fee. waived per .20 MC .25.005( e) - - - - - - - - - - - - - - - - - - - - - 2 .Lease .numberapprQpriate. . . . . . . . . - - - - · . . . . . Y~$ WelJ bQre $e.9m~otJQcated jn.AQL02565.1, . . . . . . . . . - - - - - - - - - - - - - - - - - - 3 .U_niquewell.n.am~.aod oumb.er. . . _ _ . . _ . _ _ _ _ _ _ . . . . . . . . . . . . _ _ . . Y~$ - - - - . - - - - - - - - - - - . - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - ~ 4 WelUQcat~d ¡na defil1e~ ppol. - - - - - · . . . . Y~$ KRU West Sal< .QiI Ppol, goyemed. by.Gonse.~ation Order No, 4Q6A. - - - - - - 5 WeJUQcated proper .distance. from driJling ul1itb.oul1d~ry. · . . . . .Y~$ - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 6 WellJQcat~d PrOper .distance from otber wells _ . . . . . . . . . Y~$ NOllJioal spa.cing with ill the pOQlis.10 .açre$.. - - - - - - - - - - - - - - - - - - - - - - - 7 Suffiçiel1t.açreage.aYail~ble indJil/iog unit. . . . . · . . . . . .Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 Jf.d~viated, js weJlbQre platil1cJu.ded . . - - - - - - - - - - · . .Y.e$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 .Oper.ator ol1l¥ affected party. . . - - - -- - - - - - - · . . . . Y~$ - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - 10 .Oper.ator bas.apprppriate.bond in.force _ . . . . . . . . _ . _ . . . . . . ....___..Y.es - - - - - - - - - - - - - - - - - . . - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - ~ - - - - - - - - 11 p~(I1Jit cao be iS$ued wjtbQut co.nservatiOI1 order. . - - - - - - · . . . . Y~$ - - - -. - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 P~rmit can be iS$ued witbQut admil1istrati\(e.apprpvaJ . Y~$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 9/15/2004 13 Can permit be approved before 15-day wait Yes 14 WeJI JQc~t~d withil1 area and.strata authorized by.lojectipo Order # (put 10# in cpmm~ots) (for. Y~$ Ar~a Injeçtjo.n.Qrd~r No. 2B - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . 15 .AJlwels.withi.n.1l4.llJile.area.ofreYiewid~otified(Fprservjce.we!lOI)I¥)...... _ _...... _ _Y~$ KRU :10-.112, KR[JJP:1.13,.KRU_1Q-11.6, KRU 11;-:ln KR[J.1~~1;13L.1. . _ _ . . . . . . . . . _ . _ . . . . 16 Pre-produced injector; ~uration.of pre-ProductiOl1le$S than:3 mOl1tbs. (for service well Qnly) . . Yes Well will be pre-pro~uced from 2.10 6 mooths.. . . . . . . - - - - - - - - - - - - 17 .A{:MP.F:ïl1djngof ConsLsteocyha$ been.issUed. fortbis Projeçt .. .NA Multilateral weJl.bpre.seglllent drilled frQm all existil1g pad.. . - - - - - - Engineering 18 Cooductor stril1gPJQvided . . . . - - - - - · . . . . . Y~$ Conductor.seUo motherbore,.1.E-1H. - - - - - - - - - - - 19 Surfac~casil)gprQtects all.known USQWs . . - - - - - - - - - - - ..... .NA All aquifers ex~mpt~d,40.CFR1<47.:1021b)(3).. . . . . . . . . . . . . . . . . . . . . - - - - - 20 .CMT. v.ol adeQuateto çirc.u late oncol1d.uçtor. & $u.rf csg . . . - - - - · . Ye$ Surface ca.sLng to.~e.cemel)ted to surfa.CE! inmo.therbore. . - - - - - - - - - - - 21 .CMT. vol adeQl!.ateto tie-i.nJong .striog tosur.f çsg. . . . . . . · . . . . . N.o All hydroçarbQn.zooes.plaJ1oedto be co.vered in.mQtherbore.. . . - - - - - - - - - - - - - - 22 CMT. will coyer.aJll<l1own pro.ductiYe bQri;!:ons. No Slotte.dJioercomplelioo pl~Ol1ed.. - - - - - - - - - - - - - - - - - - - - - - - - - - - 23 .C.asiog designs ad.equa.te fpr C,.l", B.&. perllJafro$t. . . . . . . . . . . . · Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 24 .Adequate.tan.kageoJ reserve pit. - - - - - - - - - - - - - - - - · Y~$ Rig js e.quipped.with steel.pjts.. NQ rese.~er pit planned. . AII.waste.lQ appro.ved an.nulus or.djspos.al wells. 25 Jf.a.re-drilL has.a. 10:403 fQr abandonment be~o apPJQved . NA - - - - - - - - - - - - - - -- - - - - - - - - - - - 26 _Adequatewe!lbore separatjo.npfoposed. . . . . _ _ _ . . . . . . . . . . . . . . . · . . . .. _Y~$ I?rpJ$ìmi.t¥ an~IY$i$ perfored._ Neares.t wellbPre.is 1.1. ": 60~ tvd below.. . . . _ _ _ _ . . . . . . . . _ 27 Jf.djverter Jeq.uired, dQes it .meet reguJa.tiOl)s. - - - - - - - - - - - - - - . . . . NA. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 DJiUiog fluid.prograllJ schematic & e(tuipJist.adequate. . . . . . . Y~$ MaxillJum BHE' 8.6.- 9.0EMW. Plal1ned mud weigbts 9.3ppg. . . . . . . . . . . . . . . . TEM 9128/2004 29 .B.OPEs, do they meet reguJatiol1 . . . . - - - - -- · . . . . . Y~$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Þt,W( 30 BOPE.press ra.liog appropriate; .test to.(pu.t psig iJ1commel1t$) - - - - .. Y~$ CalcuJa.ted.MASF' 12<46 psi. 3500 psi.test preSS.Ure.apprppriate, CPALmay.les.l 5000 psi, . 31 Choke.llJanifold çompJies wIAPIRP-53 (May 84) . . . . . . . . . . . · Yes - - - - - - - - - - - - - - - - - - - - - - 32 WQrk wiJl OCCUr withou!.operatjoJ1sbutdo.wn - - - - - - - - .....Y.e$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence of H2S gas. prob.able . - - - - - - - . . . . N.o. WS.is 1101 known 1Q C0J1tainH2S, Rigis eqìpped wi.th seJ1$Qrs and.alaJms.. . - - - - 34 Meçbanical.cood.ilion pf wells within AOR yeri.fied (for service w~1J on!¥). · Y~$ CellJentiog rePQrtsof AOR wellse1CallJioed,Spme ppera!i.oos 1)0.1 optimal. buUso!ation. i$ likely, Geology 35 P~rmit c.ao be i.ssu.ed wlo. hydrogen. s.ulfide meaS].Jres . · . . . . . Ye$ - - - - - - - - - - - - - - - - - - - -- - - - - - - 36 D.ata.PJeseoted on. pote.ntial pveJpressur~zones. . . . . · Y~$ Expected r.e$e~ojr pre's$l!.re is 8,6 -9,0. ppg EMW; willb.e .drilled wjtb 9.3 ppg mud. Appr Date 37 .S~i.smicaJ1alys.is. Qf sbaJlow gas.zPoes .. .NA - - - - - - - - - - SFD 9114/2004 38 S~abed .conditioo survey.(if off-ShPre) . . · .NA - - - - - - - - - - - - - - - - -- 39 . CQntact l1amelphol1eforweekly progress.report$ [exploratory only]. · .NA Geologic Date: Engineering Date Public Date Commissioner Commissioner ~"., tJ~ 'iIJof<t 7'YtJy e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, infonnation 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 infonnation. **** REEL HEADER **** LDWG 05/05/17 AWS 01 **** TAPE HEADER **** LDWG 05/05/17 01 *** LIS COMMENT RECORD ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! !!!!!!!!!!!!!!!!!! ! TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA . *** . ~J3J;Z1 LDWG File Version 1.000 Extract File: LISTAPE.HED JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 3 C. WONG D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 42.000 13.500 9.875 6.750 lE-114L2 500292322361 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 17-May-05 MWD RUN 4 4 F. WENDLER P. WILSON MWD RUN 10 10 F. WENDLER M. THORNTON 16 11N 10E 98.40 70.40 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 148.0 4198.0 7477.0 11833.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR ~L/--/73 . . TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 18' 2.2151" LONG: W149 DEG 35' 33.3755" LOG MEASURED FROM D. F. AT 98.4 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ runs 1 & 2 utilized an 8" directional only tool to drill from 148 to 4205 feet MD (148 to 2299 feet TVD). 2) Baker Hughes INTEQ run 3 utilized a 6.75" ATK 2.5 with Reservoir Navigation Resistivity (RNT), Gamma Ray, along with Annular Pressure to drill from 4205 to 8741 feet MD (2299 to 3726 feet TVD). 3) Baker Hughes INTEQ run 9 utilized a 4.75" directional tool with Gamma Ray to set a whipsttock and mill a window in the 7 5/8" casing. 4) Baker Hughes INTEQ run 10 utilized a 4.75" directional tool with a Multiple Propagation Resistivity (MPR) , Gamma Ray, along with Annular Pressure to drill from 7489 to 11833 fèet MD (3494 to 3539 feet TVD) . REMARKS : 1) Depth of 10 3/4" Casing Shoe - Driller: 4198 feet MD (2296 feet TVD) . Depth of 10 3/4" Casing Shoe - Logger: 4198 feet MD (2296 feet TVD). 2) Depth of 7 5/8" Casing Window: Top of window: 7465 feet MD (3490 feet .TVD). Bottom of window: 7477 feet MD (3492 feet TVD). 3) Due to the change in resistivity tool type (from RNT in the 9.875" borehole to MPR in the 6.75" borehole) the resistivity presentation goes from 2 curves (RNT: RPD & RPS) to 4 curves (MPR: RPD, RPM, RPS, RPX) at 7477 feet MD (3492 feet TVD). 4) The interval from 11803 to 11833 feet (3540 to 3539 feet TVD) was not logged due to sensor offsets at TD. $ Tape Subfile: 1 83 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 4198.0 STOP DEPTH 11833.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) . . --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 3 10 MERGE TOP 4198.0 7477.0 MERGE BASE 7477.0 11833.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. Note: Due to the change in resistivity tool type (from RNT in the 9.875" borehole to MPR in the 6.75" borehole) the resistivity curves RPM & RPX are null in the 9.875" hole section above 7477' (MWD Run 3). $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT le-114L2 5.xtf 150 - ConocoPhillips Alaska, Inc. lE-114L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN D IMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 . 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 ---...,..--- 28 Total Data Records: 493 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4198.000000 11833.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 539 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 . log header data for each bit run in separate files. 2 .2500 START DEPTH 4150_0 STOP DEPTH 7477.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PRES DIR RNT GRAM $ BOTTOM) TOOL TYPE PRESSURE DIRECTIONAL RES. NAVIG. GAMMA RAY RES. # 01-0CT-04 MSB 18704 6.75 ATK MEMORY 8741. 0 4150.0 7477.0 o 66.5 80.2 TOOL NUMBER 100009727 10035313 1127 1127 . BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 9.625 4198.0 F.W. Spud 9.15 .0 .0 200 .0 .000 .000 .000 .000 108.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 3) . RNT/GR. The bottom of the 7 5/8" casing window was at 7477 feet MD on thi s MWD run. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-114L2.xtf 150 ConocoPhillips Alaska, I 1E-114L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 . . One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 MINS 4 4 ------- 20 Total Data Records: 317 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4150.000000 7477.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 400 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !! !!! !!!!!!! !!!!!!! LDWG File Version 1.000 !!!!!!!!! !!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 4R .2500 START DEPTH 7477.0 STOP DEPTH 11833.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): 21-0CT-04 MSB 18704 4.75 MPR MEMORY 11833.0 7477.0 . BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM PRES $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RES. GAMMA RAY PRESSURE # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 118330 o 79.1 92.4 TOOL NUMBER 1490 6032 5058 10064654 6.750 7477.0 OBM 9.30 .0 .0 60000 .0 .000 .000 .000 .000 105.0 .0 .0 .0 .00 .000 .0 o BIT RUN 4R (MWD Run 10). MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-114L2.xtf 150 ConocoPhillips Alaska, I lE-114L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM 0.0 GRAM . . . RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 563 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7477.000000 11833.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 648 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/05/17 01 **** REEL TRAILER **** LDWG 05/05/17 .. AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes