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Home My WebLink About211-024ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 CD3-198 50103206370000 2110240 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 2 2019 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑�AiQfutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ After Casing ❑ Change Approved Program ❑ Plug for Redrill 13erforate New Pool El Repair Well 10 Re-enter Susp Well El Other: El2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 211-024-0 3. Address: P. O. Box 100360, Anchorage, Alaska Stratigraphic❑ Service 0 6. API Number: 99510 50-103-20637-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372104, ADL 372105 CRU CD3 -198 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,228 feel Plugs measured None feet true vertical 7,038 feet Junk measured None feet Effective Depth measured 13,224 feet Packer measured 8057, 8137 feet true vertical 7,038 feet true vertical 6816, 6852 feet Casing Length size MD TVD Burst Collapse CONDUCTOR 80 feet 16 108' MD 108' TVD SURFACE 2,591 feet 9 5/8 " 2,619' MD 2455' TVD INTERMEDIATE 8,704 feet 7 8,729' MD 7004' TVD LOTTED LINER 4,972 feet 4 1/2 " 13,224' MD 7038' TVD Perforation depth: Measured depth: 8761-9241, 9521-13220 feet True vertical depth: 7007-7014. 7015-7038 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 8,257' MD 6,902' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- BAKER PREMIER PACKER 8,057' MD 6,816' TVD PACKER- BAKER PREMIER PRODUCTION PACKER 8,137'MD 6,852'TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: - e - 1120 3900 Subsequent to operation: - 750 - 825 3900 14. Attachments (required per 20 rwc 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development ❑ Service [D Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 21 GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-583 Contact Name: Kyle Hampton Authorized Name: Kyle Hampton Contact Email: kyle.hampton@cop.com Authorized Title: Sr. Drillipa Engineer Contact Phone: (907) 263-4027 Authorized Si nature: Date: oun iu-vuw Revised w/zov VT`s 41311-1 �Wp6Ds■Sli!�VAPR 0 3 2019 Submit Original Only WNS INJ WELLNAME CD3 -198 WELLBORE CD3 -198 ConocoPhlU(ps Well Attributes D Max Angle & MTD Alaska, Ir W. IuG Nama Welleum ARVIIWI W¢IIM,ea luS cl Cl MnInNB) BIm IXKB) FIORD NECHELIK 501032063]00 IND 126 9,205.02 1},22n eammenl 12S (pp.) naR Annotation Ertl Oath KB G141n1 Rip Ross -Date SS6V'. WROP Last W0; 22812019 4/6/2011 CD118A WIM92: 16: 55 PM Last Tag Vaeli:Y w.Mmetic tenths) Annotation pepminxB) End Dale she,Lane. By Last Tag: CD3 -198 1hromr Last Rev Reason Nmi Annaba- End Date WmWre Leat Macey Rev Reason. Post RWO if itinkatinstut Cuing Strings cssmeoeacliWbn oplml IDdd Top MKN set Depen than set aepin lTvpl._wuL.r n._Graae rap Tnread CONDUCTOR 16 15.06 280 1080 108.0 62.50 WELDED cases punhidi t Off (in) ID (in) Top ) S Dafth(XRBI "0epm rovId- anden0 Me Top TmeY ild SURFACE 9518 883 27.9 2,6183 2,455.3 4000 L40 BTCM GSRq pescrIF Op(Inl ID IMI Top peal Bet DeWklllKal get OeMx (TVD)... Wtll.en p... Gnde Top Th"od INTERMEDIATE ] 6.28 24.6 8,]28] ],003.6 2680 L-80 STC -m CxlnO Ossunlptbn Rohn, IDB., TOP 91X8) BM Dean therm ass pepm(Turn MltlLm(L.. Grace Tcp -- 4112 3.96 5,2513 13.224.0 >,038A 12.60 L-� SLHT Liner Liner Details Details wxoDcroR:mo-loeo NonIsAID Top MLe) Top Man IXKB) rop mdl'1 IMm Dn Coen (In) aver Ren-Di.a',xs 82517 6,899.5 6]03 SLEEVE BAKER 'HRD'SETTING SLEEVE 4.380 22mo:2mrdlta 8.263.8 6,904.3 6].4fi NIPPLE BAKER' RSNIPPLE 4.250 8,266.5 S. 67.55 MANGER BAKER DG FLEX LOCK LINER HAN ER 5.0 8,2756 6,908.7 6]8] XO BU RING BAKERCR 8 VERBUSHING 1950 Tubing Strings khaki Tvome Dmcnpllon stamp Ma_, ID 9nl Top IXNBI sal DBpm ln.. BN oeprll (1VD1 (... Wt91Afl1 Grade Top conn6ton TUBING W02019 4112 3.96 21S 8,110.5 Q8402 12 fi0 L-80 TSH Blue Completion Details TOPDVOI I Top andR.Win, Top Innes (I cl Immin com D9n1 21S 21.5 0.00 Hanger FMC Horizontal Gen 11 Tubing Hanger 3.900 2,138] 2,0341 29.32 Nipple -X HES 3.813'X Moore 3.813 8058.5 ,815.] 624] Baker Premier Baker ]'x 45"Premier Packer 3958 Packer SURFACE', 21.92619 T� - ii 6,829.E 63.12 Nipple -X HES 3.813" X Landing Nipple 3.813 8,103.3 6,83]0 83.47 Poor nor Baker Paul Over Shot 6.52' of swallow Spaced l'o9 NOGo 4.620 Overshot Tualnp Deubation sting Me...IDlinl TGPMKB) sat Depth ln.sx depth ITVDI f. Wt9up GMe top ConnecXon TUBING -ORIGINAL 4112 3.96 8,105.0 8,25].9 6,902.0 12.60 L-80 III Amba Fwd-Bna.. Completion Details 2,2:008,I311I:2T/A1B Top OVD) Top mn NI"I'MIL) MKBI 1'1 11em Des com 10 (in) 8,137.2 6,851.9 64.22 PA KER BAKER PREMIER PRODUCTION PACKER(41?TGil box - pin) 3870 8,196.1 Q8]].0 65.21 NIPPLE HES "XN' NIPPLE"PXNPWGINSTALLED 3325 MudrN: e,cm.3 8,24].2 6,89]8 66.8] FLU SHEAR PIN FLUTED NO GO UB 3.]25 SUB 8,256.9 6,901.6 6].21 WLEG WIRELINE ENTRY GUIDE 3,970 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Sn"Pemv PxW;6.neen Top INDI Topmn Top deal dean (I Des Com Run path, I In (in) I "I Xl dome 2,136.] 2834.1 oB.1 MCX VALVE N VALVE (SIN: - I i. 31152019 Inn". BEAN) I 8,11 6,8317 63.51 TUBINGCUTTUBINGCUT�lo81WRKB 2/12019 1 3958 TUMNG cul;dlmo Perforations & Slots Pcw Bay pwNg1; 8,10.3 Shat Dora Top (TVD) Bonlrvol andWh TOP( ) BM 91Y.Bs "Um UnkM Zone Dab I Type Cam PAcxERl LISF2 8]610 9,241.0 7,006.9 ],014.2 4132011 320 SLOTS mating BWnk Pipe ids 118x2.25', 8 slotalo.,, 4 roWslft; no slots 3' frmn bowpin NIPPLE: 8,1m1 9, 1.0 13,220.0 ], 15. ],038.4 N32011 32.0 SLOTS Aner Blank Pipet lots 25', 118x2.25",8ots 3- i4 rows/h; on sloes 3' from FLUTED xpfi08uB: 9,222Lbxlpin e Mandrel Inserts 9t WLEG: dime H Top(MII Latch askRun TPp IXXBs 9 ) Make MWN OB 9n) dery T.P. C9n) Red Run path Com 8,0303 6.503.d Camco KBG2 DMY BK 3It52019 Notes: General & Safety End mh Annobi 41162011 NOTE: View Schematic wl Alaska BChemaosan TV2015 NOTE: Waivered for Water Inlecuort Only. T x IA Communication on Gas, INTEflMFDmTE:24.SB,"Rdo� SLOTS: Sort Da.2N O� SLOTS: 8, 831.D1"Us BRIFTEDLINER:a".7"o J l 13,2N0 Operations Summary (with Timelog Depths) CD3-198 Rig: NORDIC 1 Job: RECOMPLETION Time Log BtartTme EM Time Dur(hr)Phase Op Code Activity Coee Time P-T-X Operation ar(IIKBp� End Depth (flKB) 2/21/2019 2/22/2019 17.00 MIRU MOVE MOB P Remove fluid from pits, break down 07:00 00:00 berming. Pull of the well and stage on CD4. Remove winterizing tarps from cellar. Clean up around the well. Move from C04 to CD3 2/22/2019 2/23/2019 24.00 MIRU MOVE MOB P Move sub and camp from CD4 to 0.0 0.0 00:00 00:00 CD3. Stage sub on CD4. Spread herculite and sets mats for sub and camp. Install winterizing tarps around cellar. Change out speed head on stack. Install new accumulator manifold and test. 2/23/2019 2/23/2019 10.50 MIRU MOVE RURD P Spot cuttings box. Berm dg in. Spot 0.0 0.0 00:00 10:30 sign in shack. Install temporary landing on tree. Perform rig acceptance check list. RIG ACCEPTED at 10:30 2/23/2019 2/23/2019 0.50 MIRU MOVE RURD P RU bleed trailer to IA. Attempt to 0.0 0.0 10:30 11:00 bleed 250 PSI off of IA. Fluid seen at bleed trailer. Shut back in pressure did not bleed off. 2/23/2019 2/23/2019 1.50 MIRU WELCTL MPSP P RU lubricator and pull BPV. 200 PSI 0.0 0.0 11:00 12:30 on tubing. 250 PSI on IA. RD lubricator. 2123/2019 2/23/2019 3.50 MIRU WELCTL RURD P RU circulating equipment to pump 0.0 0.0 12:30 16:00 down tubing and take returns to tiger tank out of the IA. Pressure lest hard line to tiger tank. Take on 8.5 PPG seawater. 2/23/2019 2/23/2019 2.00 MIRU WELCTL KLWL P Pump 350 Bbis of 8.5 PPG seawater 0.0 0.0 16:00 18:00 around down tubing at 5 BPM holding 100 PSI back pressure at choke house. 2/23/2019 2/23/2019 1.50 MIRU WELCTL RURD P Blow down lines R/D circulating 0.0 0.0 18:00 19:30 equipment 2/23/2019 2/23/2019 1.00 MIRU WHDBOP MPSP P Set BPV, R/U and test U 1000 psi in 0.0 0.0 19:30 20:30 direction of flow f/ 10 min R/D Test equipment 2/23/2019 2/23/2019 2.00 MIRU WHDBOP NUND P Nipple down tree and adaptor install 0.0 0.0 20:30 22:30 1 1 blanking plug 2123/2019 2/24/2019 1.50 MIRU WHDBOP NUND P Nipple up BOP stack and riser install 0.0 0.0 22:30 00:00 turnbuckles 2/24/2019 2/24/2019 6.00 MIRU WHDBOP NUND P Continue N/U BOP's 0.0 0.0 00:00 06:00 2/24/2019 2/24/2019 3.50 MIRU WHDBOP RURD P R/U to test BOP'S M/U test it fill stack 0.0 0.0 06:00 09:30 and lines with water. 2124/2019 2/24/2019 8.50 MIRU WHDBOP BOPE P Test BOP's w/ 4.5" Test it t/ 250/3800 0.0 0.0 09:30 18:00 psi f/ 5 min test Upper lower amd blinds, TIW and Dart, Demco, CMV 1- 17 HCR & Man choke and kill ( Dart Failed retest new dart Passed) lest gas sensors and PVT Test Annular t/ 250/2500 psi f/ 5 min test Super and Man chokes, Stale Inspector Matt Herrera waived Witness of test 2/24/2019 2/24/2019 2.00 MIRU WHDBOP RURD P R/D test equipment blow down Hines 0.0 0.0 18:00 20:00 pull test it and blanking plug 2/24/2019 2/24/2019 1.00 MIRU WHDBOP MPSP P R/U and pull BPV install Landing it 0.0 0.0 20:00 21:00 BOLDS 2/24/2019 2/24/2019 1.00 COMPZN RPCOMP PULL P Pull hanger off seat w/ 83k hook load, 8,105.0 8,079.0 21:00 22:00 pull Ufloor 2124/2019 2/24/2019 0.50 COMPZN RPCOMP OWFF P Observe well for flow well static, R/U 8,079.0 8,079.0 22:00 22:30 Tubing handling equip Page 113 Report Printed: 31612019 Summary (with Timelog Depths) AIMOperations CD3-198 qW Rig: NORDIC 1 Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Op Cotle ACLvity Code Time P-T-X Operation Start Depth (flKB) End Depth (ftKB) 2/24/2019 2/25/2019 1.50 COMPZN RPCOMP PULL P POOH f/ 8079'U 7652' UD4.5" 8,079.0 7,652.0 22:30 00:00 Completion 2/25/2019 2/25/2019 17.00 COMPZN RPCOMP PULL P Cont. POOH layng down 4 1/2", 7,652.0 0.0 00:00 17:00 12.6#, L-80, IBTM completion. Pulled 200 joints, 1 nipple, 1 mandrel and 16.43' cut joint. 2/25/2019 2/25/2019 4.00 COMPZN RPC 0 MMP CLEN P Clean and clear floor, finish strapping 0.0 0.0 17:00 21:00 tubuars empty p y pipe shed, bring in new jewelry and strap bring up new hanger 2/25/2019 2/26/2019 3.00 COMPZN WELLPR OTHR P load shed and process tubulars drift 0.0 0.0 21:00 00:00 strap and tally 4.5" completion tubing and jewelry 2/26/2019 2/26/2019 7.50 COMPZN WELLPR OTHR P Continue processing pipe in shed, R/U 0.0 0.0 00:00 07:30 tubing equipment on the floor 2/26/2019 2/26/2019 13.50 COMPZN RPCOMP PUTS P Run 4.5" TS Blue Completion as per 0.0 8,080.0 07:30 21:00 ✓ detail torque turning g pipe as per weatherford f/ surface t/ 8080' 2/26/2019 2/26/2019 2.00 COMPZN RPCOMP i0SO P Slack off observe pins shear on 8,080.0 8,088.0 21:00 2300 overshot at 10k SOW on tubing stub, slack off and Togo, UD two jts P/U space out pups and 1 jt of tubing, M/U Hanger and landing jt 2/26/2019 2/27/2019 1.00 COMPZN RPCOMP CRIH TiR/U and displace well t/ corroision 8,088.0 8,088.0 23:00 0000 1 1inhibited sea water 2/27/2019 2/27/2019 2.75 COMPZN RPCOMP CRIH P Circulate in corrsion inhibited 8,088.0 8,088.0 00:00 0245 seawater with Concor303A 2/27/2019 2/27/2019 0.25 COMPZN RPCOMP THOR P Land tubing hanger and RILDS to 450 8,088.0 8,110.0 02:45 0300 FT/LBS. 2/27/2019 2/27/2019 3.00 COMPZN RPCOMP RURD P Drop ball and rod. RU to set and test 8,110.0 8,110.0 03:00 06:00 packer. 2/27/2019 2/27/2019 1.00 COMPZN RPCOMP RURD TiLine up to set and test packer verify 8,110.0 8,110.0 06:00 0700 line-up 2/27/2019 2/27/2019 2.00 COMPZN RPCOMP PRTS T Attempt to set packer and pressure 8,110.0 8,110.0 07:00 0900 test. Tubing and IA tracking, bleed off IA. Verify line up and cement manifold and standpipe manifold. Re-attempt to set packer and pressure test tubing. TxIA still in communication, Bleed off IA. Isolate cement manifold from IA and tubing verified no surface comminication. Re-attempt to set packer and test TxIA still in communication Bleed off IA call engineer and mobilize Slickline. 2/27/2019 2/27/2019 6.00 COMPZN RPCOMP RURD T Start breaking down tubing bundles for 8,110.0 8,110.0 09:00 15:00 CD3-114, suck out pits and cutting tank, remove stairs from rig for Slickline access, Iaydown Weatherford elevators and dart valve replace with Nordic dart valve and elevators. NO 13-5/8" Speed Head from Nordic 13- 5/8" x 11"spool, 2/27/2019 2/27/2019 1.00 COMPZN RPCOMP SLKL T Spot in slickline and move slickline 8,110.0 8,110.0 15:00 16:00 tools to rig floor. 2/27/2019 2/27/2019 0.50 COMPZN RPCOMP SFTY T Pre job safety meeting with rig crew 8,110.0 8,110.0 16:00 1630 and Halliburton Slickline. 2/27/2019 2/27/2019 5.00 COMPZN RPCOMP ET—KL T RIH and retrieve ball and rod from 8,110.0 8,110.0 16:30 21:30 RHC plug body at 8086' KB. Pick up DPU and ISO plug set timer for 2:15 RIH set 5' above RHC, set ISO Plug POOH, Set wireline to side R/D Running jt Page 2/3 Report Printed: 3/6/2019 Operations Summary (with Timelog Depths) CD3 -198 Rig: NORDIC 1 Job: RECOMPLETION Time Log rtTime End Time Our (hr) Phase Op Code Activity Cone Time P -T -X Operation Stan Depth (0KB) End Depth QlKB) 1.50 COMPZN RPCOMP PRTS T Install landing jt antl R/U and attept t/ 8,110.0 81100 23:00 test tubing to 4200 psi, still has ;-f/27/2019 r22,7 communication to IA, R/D test equipment, R/U Wireline running jt 2/28/2019 1.00 COMPZN RPCOMP SLKL T RIH and Pull SOV f/ Station @ 8030' 8,110.0 8,110.0 00:00 -o POOH 019 2/28/2019 50 COMPZN RPCOMP SLKL T Attempt to set SOV unable to leave in 8,110.0 00:00 00:30 mandrel continue to POOH with valve 2/28/2019 2/28/2019 1.50 COMPZN RPCOMP SLKL T MU and tin with catcher iunable to 00:30 0200 pass 7900' MD POOH with catcher. 2/28/2019 2/28/2019 6.00 COMPZN RPCOMP SLKL T Run 3: MU fool string and RIH with 02:00 0800 SOV unable to leave set valve in mandrel inspite of being fully "No- Go'd" POOH with SOV. Run 4: MU new SOV with bottom latch top sub and RIH leave SOV set in mandrel. LD and standby Slickline for Packer setting 019 2/28/2019 0.50 COMPZN RPCOMP SFTY T PJSM to set packer 08:00 08:00 08:30 2/28/2019 2/28/2019 0.50 COMPZN RPCOMP RURD T RU to test packer verify line up at floor 08:30 09:00 and cellar. 2/28/2019 2/28/2019 1.50 COMPZN RPCOMP PRTS T Set and test packer -t,4200 psi for 30 0.0 0.0 09:00 10:30 minutes, bleed tubing to 2000 psi pressure test IA to 3500 psi for 30 minutes. 2/28/2019 2/28/2019 1.50 COMPZN RPCOMP SLKL T RU and RIH with slickline and retrieve 0.0 0.0 10:30 12:00 sov from mandrel. RD S/L 2/28/2019 2/28/2019 0.50 COMPZN RPCOMP ROU RD P RD Test equipment and clear floor RD 0.0 0.0 1200 12:30 cellar lines. 2/28/2019 2/28/2019 0.50 COMPZN RPCOMP SFTY P PJSM with LRS to pump FP to IA. 0.0 0.0 12:30 1300 2/28/2019 2/28/2019 -1 00 COMPZN RPCOMP FRZP P LRS Pressure test lines open to IA 0.0 0.0 13:00 1400 and pump 75 BBLS diesel to IA. at 2 BPM. RD and release LRS. 019 2/28/2019 0.50 COMPZN RPCOMP MPSP P Set 4" HPBPV on dry rod from floor 0.0 0.0 14:00 14:00 1430 2/28/2019 2/28/2019 0.50 COMPZN WHDBOP SFTY P PJSM to ND BOPE and NU tree and 0.0 0.0 14:30 15:00 adapter. 2/28/2019 2/28/2019 3.00 COMPZN WHDBOP FUND P Drain stack and ND HRC choke and 0.0 0.0 15:00 18:00 kill lines pull pitcher nipple install lifting cap on annular. clean pits and empty cuttings tank. crew C/O 2/28/2019 2/28/2019 5.00 COMPZN WHDBOP NUND P N/D Stack, clean groove set test dart, 0.0 0.0 18:00 23:00 N/U Adaptor and tree 2/28/2019 3/1/2019 -1 o0 COMPZN WHDBOP MPSP P Test tree void t/ 5000 psi f/ 10 min, fill 0.0 0.0 23:00 00:00 tree w/ diesel Test tree / 250/5000 psi f/ 5 min, R/D Test equipment 3/1/2019 3/1/2019 -0 50 COMPZN WHDBOP MPSP P Pull BPV and test dart 0.0 0.0 00:00 0030 3/1/2019 3/1/2019 2.00 COMPZN WHDBOP FRZP P R/U and put tubing and IA in 0.0 0.0 00:30 0230 communication allow diesel freeze protect to U -Tube f/ 1 hr, R/D Lines Drain Diesel 3/1/2019 3/1/2019 -0 50 COMPZN WHDBOP MPSP 5 Install BPV w/ dry rod 0.0 0.0 0230 0300 3/1/2 019 3/1/2019 1.50 DEMOB MOVE P Secure wellhead, Release rig @0430 0.0 0.0 03:00 04:30 Page 3/3 Report Printed: 3/6/2019 MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim Regg2_ P.I. Supervisor (� DATE: Tuesday, April 30, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPs ALASKA, INC. 15 Min CD3-198 FROM: Jeff Jones COLVILLE RIV FIORD CD3-198 Petroleum Inspector a • TVD Ste: Inspector Tubing Reviewed By: 3918 ' P.I. Supry JEP— F3918 NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3 -198 API Well Number 50-103-20637-00-00 Inspector Name: Jeff Jones Permit Number: 211-024-0 Inspection Date: 4/1/2019 - Insp Num: mitJ1190424101539 Rel Insp Num: Interval L- INITAL IP/F P Notes: Initial MITIA post rig workover Sundry # 318-583. 1 well inspected, no exceptions noted. Tuesday, April 30, 2019 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3 -198 Type IneTyp lne j a • TVD e852 Tubing 3919 3918 ' 3919 F3918 PTD 211oz�o Type Test SPT Test psi nl3 IA Slo 2015 980 980 BBL Pumped• BBL Returned 0.9 OA 330 450 440 445 ' Interval L- INITAL IP/F P Notes: Initial MITIA post rig workover Sundry # 318-583. 1 well inspected, no exceptions noted. Tuesday, April 30, 2019 Page I of 1 p -p 2 11 — DZ -4 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, March 19, 2019 6:48 AM To: 'Hampton, Kyle' Subject: RE: [EXTERNAL]RE: CD3 -198 and CD3 -123 Well Status Post RWO Yes, adjust the 10-404 to WAG and hand change the 10-403 to WAG. I will adjust in our files Thanx, Victoria From: Hampton, Kyle <Kyle.Hampton @conocophillips.com> Sent: Thursday, March 14, 2019 2:06 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: CD3 -198 and CD3 -123 Well Status Post RWO It looks like we have not submitted them yet. Can we make the adjustment on that form? From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Sent: Thursday, March 14, 2019 2:03 PM To: Hampton, Kyle <KVIe Hampton@conocophillips.com> Subject: [EXTERNAL]RE: CD3 -198 and CD3 -123 Well Status Post RWO Have the 10-404s been filed yet? From: Hampton, Kyle <KVIe Ha mpton@conocophillips.com> Sent: Thursday, March 14, 2019 1:05 PM To: Loepp, Victoria T (DOA) <victoria loepp@alaska.eov> Subject: RE: CD3 -198 and CD3 -123 Well Status Post RWO Victoria, I wanted to follow up and see if you had a moment to look at the Well Status Change for CD3 -123 (PTD 210-031) and CD3 -198 (PTD 211-024). 1 was wondering what is required to change the status from GINJ to WAG; I misunderstood the intentions for the production team when the application was submitted. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 KVIe.HamptonCa@cop.com From: Hampton, Kyle Sent: Wednesday, March 6, 2019 3:12 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Subject: CD3 -198 and CD3 -123 Well Status Post RWO Victoria, I filled out the form for the 10-403 on these wells incorrectly for the post-RWO status. I just found out that the production engineering team would like to use these wells for water and gas injection, but I only checked the box for gas injection. Is there something I can do to change the injection status of these two wells? Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle. Ham pton(cDcon com C P4 C63- IgI3 PT-6 zl fob Regg, James B (DOA) From: Regg, James B (DOA)I/ Sent: Monday, March 11, 2019 2:28 PM &fq 3l it { (� To: NSK Well Integrity Supv CPF3 and WNS Cc: Brooks, Phoebe L (DOA) Subject: RE: CRU CD4-26 (PTD# 209-049) Request to Cancel Area Injection Order 18C.013 AOGCC has received 2 recent MITs for cancellation of AIO admin approvals that show only pressures imposed in the tested tubing or annulus: - CD4 -26 (PTD 2090490) - C133-198 (PTD 2110240) CPAI is reminded that to be a valid MIT for a regulatory decision AOGCC requires the Tubing, Inner Annulus, and Outer Annulus pressures to be documented for the 30 minute test. Please correct this for future MITs. Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or jim.regg@alaska.zov. From: Brooks, Phoebe L (DOA) Sent: Monday, February 25, 2019 10:02 AM To: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com>; Wallace, Chris D (DOA) <chris.wa (lace @a la ska.gov> Cc: Regg, James B (DOA) <jim.regg@alaska.gov> Subject: RE: CRU C134-26 (PTD# 209-049) Request to Cancel Area Injection Order 18C.013 Attached is a revised report changing the interval to "O" and adding the verbiage from the AOGCC Rep field to the remarks (this field should only include an inspector's name, if witnessed) . Please update your copy. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains infonnation from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential mid/or Privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC + ATTN: Natural Resources Technician II 1 Alaska Oil &Gas Conservation Commision 333 W. 7th Ave, Suite 100 yi Anchorage, AK 99501 2 110 24 TRANSMITTALDATE TRANSMITTAL #' SERVICE ORDER WELL NAME API # # 50-103-20617-00 .� ��i 50-103-20 ®50-103-20792-00 SERVICE FIELD NAME DESCRIPTION DELIVERABLE . Z4 kyj 21 DESCRIPTION DATA TYPE Color DATE LOGGED Prints CD's ___ Transmittal Receipt signature confirms that a package (box' e- / envelope, etc.) has been received and the contents of the X—"I package have been verified to match the media noted above. Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this courier or sign/scan and email a copy o chlumberger and CPA]. point. P7-0 z11- 024- Loepp, Victoria T (DOA) From: Hampton, Kyle <Kyle.Hampton @conocophiIIips.com> Sent: Monday, January 28, 2019 12:15 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]CRU CD3-198(PTD 211-024, Sundry 318-583) WO Attachments: BOP -Choke Schematic.pdf Follow Up Flag: follow up Flag Status: Flagged Victoria, We'll be using Nordic 1 for this workover (schematics attached). We'll be putting these wells on GINJ. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle. Hampton@cop.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Monday, January 28, 2019 9:13 AM To: Hampton, Kyle <Kyle. Ham pton@conocophillips.com> Subject: [EXTERNAL]CRU CD3-198(PTD 211-024, Sundry 318-583) WO Kyle, Please provide rig, BOP stack schematic, BOP ram sizes and configuration. Is the well status after proposed work GINJ or is it WAG? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeOp(QD.alaska. go CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or Vic to a. Loeooe'alaska.aov THE STATE °fALASKA. GOVERNOR MIKE DUNLEAVY Kyle Hampton Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CRU CD3 -198 Permit to Drill Number: 211-024 Sundry Number: 318-583 Dear Mr. Hampton: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, lcvz� Daniel T. Seamount, Jr. Commissioner DATED this3 day of January, 2019. RBDMS '��fEB 0 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 - 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well v❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 4r�( Stratigraphic ElLJ Service 211-024 3. Address: 6. API Number: P.O. Box 100360, Anchorage, AK 99510 , ,�t, n/' 50-103-20637-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a CRU FIORD CD3 -198 Will planned perforations require a spacing exception? Yes ❑ No ❑Q 9. Property Designation (Lease Number): 10. Field/Pool(s): I ADL0372104 / ADLO372105 COLVILLE RIVER / FIORD OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13224 7038 13210 7034 3,492 none none Casing Length Size MD TVD Buret Collapse Structural Conductor 78 16" 114 114 Surface 2797 9-5/8" 2833 2462 Intermediate Production 11008 7" 11041 6952 Liner 4972 3-1/2" 13224 7038 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8761'-9241', 9521'-13220' 7007'-7014', 7015'-7038' 4-1/2" L-80 8258' Packers and SSSV Type: Packer (Baker Premier) Packers and SSSV MD (ft) and TVD (ft): Packer (8137' MD / 6852' TVD) SSSV (A-1) SSV (2093' MD / 1996' TVD) 12. Attachments: Proposal Summary L2J Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/10/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Kyle Hampton Contact Name: Kyle Hampton Authorized Title: Sr. Wells Engineer Contact Email: k le.harTton e0 .Com Contact Phone: 2634627 12 Authorized Signature: ' Date: ern It 2 V-2 comf4fissON USE ONLY Conditions of approval: 4otify Commission so that a representative may witness Sundry Number: 11 Plug Integrity ❑ BOP Test Mechanical Integrity Test 211" Location Clearance ❑ Other: BaP tCSt �0 3800 ,us�g Eg 0 12019 ♦z ` 7'-cS 7' tD Z5Uo/�s 5 RBDMS�J Post Initial Injection MIT Req'd? Yes [RN, ❑ Spacing Exception Required? Yes ❑ No [9/ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ` Z4��o �Ak ' / L l /�/l / /�� ^ //�� AA'' ^A � ,/ Submit Form and `,Form 10-403 Revised 4/2017 Approved applic$igr p�18�Qfq J2 HW1t from the date of approval/,'� DAftachments in Du licale V U •'fTi` w ��,��, ��111111 llliii 111�� 1L... c�- eI IZ�� ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 26 December 2018 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7's Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Alpine Injector CD3 - 198 (PTD# 211-024). Well C133-198 was drilled and completed in February 2011 as a Nechelik injector well. In July 2015, IA pressure fluctuations were observed; the well was waivered to water injection. In water, MITIA passed to 3,300 psi. In August 2018, MI was tested but continued to leak; the well was returned to water only. In October 2018, the well passed MITIA to 3000 psi, IC POT, IC PPPOT, T POT, and T PPPOT. The objective of this rig workover is to pull and replace the production tubing. We will be performing a pre -rig cut at 8,125' MD and stacking a packer with a non -sealing overshot. We are requesting a waiver to place the packer 665' MD above the top perf. If you have any questions or require any further information, please contact me at 263-4627. Sincerely, Kyle Hampton Senior Wells Engineer CPAI Drilling and Wells CD3 -198 RWO Procedure Nechelik Injector PTD #211-024 Current Status: The well is currently injecting water. In October 2018, the well passed MITIA to 3000 psi, IC POT, IC PPPOT, T POT, and T PPPOT. A new SBHP will be captured before rig up; currently there is an ice plug that requires coiled tubing to drill out. Scope of Work: Pull 3-1/2" tubing from pre -rig cut at 8,125' RKB. Pull the tubing out of the hole, laying down the tubing. Run in the hole with new completion string (non -sealing overshot, X nipple, packer, and GLM) and overshoot the tubing stub. General Well info: MPSP: 3,492 psi (using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Nechelik — 4,180 psi / 6,877' TVD (11.7 ppg EMW) 12.0 ppg KWF Wellhead type/pressure rating: FMC Horizontal, 3 1/8" SM BOP Config: Annular / Variable Pipe Ram / Blind Ram / Variable Pipe Ram MIT results: MIT -IA — Passed to 3,300 psig/Opsig on 10/28/2018 Well Type: Injector Estimated Start Date: February 10, 2018 Production Engineers: Mark Shulman (263-3782 / Mark.Shulman@conocophillips.com) Workover Engineer: Kyle Hampton (263-4627 / Kyle.Hampton@conocophiIlips.com) Remaining Pre -Rig Work 1. Drill out ice plug. 2. Set plug in XN nipple at 8196'. 3. Pull lower GLV. 4. Cut tubing at 8125'. S. Swap to dry hole tree configuration for RU. 6. Set isolation sleeve in SSSV. 7. Install BPV. Rig Work MIRU 1. MIRU on well location. 2. Pull BPV and pump seawater from surface to surface. Record shut-in pressures on the T UA. If there is pressure, bleed off IA and/or tubing pressure, and weight up fluid as necessary. Complete 30 -minute NFT. Verify well is dead. 3. Set BPV, ND Tree, NU BOPE (Configuration B) and test to 250/3,800 psi. Test annular 250/3,800 psi. a. Notify AOGCC of BOP test 24 hours prior to nipple up and every 7 days thereafter or when the stack is broken. Retrieve Tubing 4. Pull BPV and MU landing joint. 5. Pull 4-1/2" tubing and lay down the tubing. Install 4-'/:" Tubing Page 1 of 2 CD3 -198 RWO Procedure Nechelik Injector PTD #211-024 6. MU 4 %" completion with non -sealing overshot, packer, and tubing. RIH and place the packer above the existing packer. Set packer with ball and rod. 7. Pressure test tubing to 4,200 psi for 5 minutes. 8. Pressure test inner annulus to 2,500 psi for 30 minutes on chart. ND BOP, NU Tree 9. Confirm pressure tests, then shear out SOV with pressure differential. 10. Install BPV. 11. ND BOPE. NU dry hole tree. 12. Freeze protect well. 13. RDMO. Page 2 of 2 Well CD3 -198 API 5010320637 PTD 211-024 Rig (RKB) Nordic 1 Max DIS 6.5°/i GDR Q 1,661' RKB Max Pad H2S EUEM Well Category Category3 ConocoPhillips PROPOSED RWO COMPLETION Network 8 (Drilling) Network If (Wells) AFE Cos[ AFE Time Max Angle 64.1° @ 8,135' RKB Max Well HIS H2S Radius of Exposure Wellhead IFMC Gen IV Production Tree Tubing Hanger Tubing Head Tbg Head Adapter WELL OBJECTIVE Pull 3-1/2" tubing from pre -rig cut at 8,135' RKB. Pull the tubing out of the hole, laying down the tubing. Run in the hole with new completion string (non -sealing overshot, X nipple, packer, and GLM) and overshoot the tubing stub. WELL HISTORY Drilled and completed in February 2011 as a Nechelik injector well. In July 2015, IA pressure fluctuations were observed; the well was waivered to water injection. In water, MITIA passed to 3,300 psi. In August 2018, MI was tested but continued to leak; the well was returned to water only. In October 2018, the well passed MITIA to 3000 psi, IC POT, IC PPPOT, T POT, and T PPPOT. HSE CONSIDERATIONS CASING INFO MD (ft RKB) TVD OD ID (ft RKB) (in) (in) Weight (Ib/ft) Grade Thread (top) Thread (btm) Conductor 108' 108' 16" 62.5 H-00 Welded EUEM Surface 2,619' 2,455' 9-5/8" 40 L-80 BTCM BTCM Production 8,729' 7,004' 7" 26 L-80 BTCM BTCM Liner 13,224' 7,038' 4-1/2" 12.6 L-80 SLHT SLHT Tubing (Previous) 8,258' 6,902' 4-1/2" 12.6 L-80 EUEM EUEM Tubing (Proposed) 8,100' 6,825' 4-1/2" 12.6 L-80 HYD563 HYD563 Top Perf Bottom Perf PERFORATIONS (RKB) (RKB) Nechelik 8,761' 9,241' Nechelik 9,521' 13,220' 8,125' EUEM EUEM 4-1/2" X Nipple 8,110' EUEM PRESSURE CALCULATIONS IMP4,180 psi 6,877'TVD 4/8/2014 EMW 11.7 ppg Gas Column 688 psi ( MPSP 3,492 psi COMPLETION EQUIPMENT MD TVD (ft RKB) (ft RKB) OD ID (in) (in) Thread (top) Thread (btm) Comments Poor -Boy Overshot 8,125' EUEM EUEM 4-1/2" X Nipple 8,110' EUEM EUEM 4-1/2" x 7" Premier Packer 8,095'1 HYD563 JEUEM Gas Lift Mandrel 8,050.1 HYD563 IHYD563 FLUIDS Weight Comments/Additives Prima Workover Fluid 8.4 Seawater since plugwill be set Back-up Workover Fluid 12.0 pp Drillingmud as back up fluid Corrosion Inhibitor 12.0 ppg Inhibited brine w/ 1%CRW-132 Freeze Protection Diesel WNS INA) r' CD3 -198 ConoeoPhdk)ps Alaska. Angle Well Attributes MaxAngle&MD TD _ Well ttribu Flaw xame swnlwre ams nal l°I Am s,b MKsl SOt0320fi37D0 FIORD NECHELIK INJ 912fi 9.20502 13,2280 UD... Enanon, Hill(n) Rig Peleaae Oeb L00,W0: LN2011 COmmen, H351ppm1 Dab SSSV. WEDS OWt99..1DrA16 IFS, sz AM Mndatlan CepN (KK91 EntlDW Deal Tag Annobtlon Llel Motl By Ena Dare Rev Reason: NOTE UPDATE 1en5111 9/10/2015 .NDEP.1]e- CONDO R: ESD10Sp SPPLE. 2,ba VALVE. Star. suRPAce z7az6,e7- GAS LILT SGGS PACKED: B.1 S>] SPIE,s1B3.1 FLUTED NO-GO suslsN7z WLEG'.a SPERMEO.TE:z468,7287- SLOTS: 876169241 O SLOTS', 9=z 13.=O - GLUTTED DI£R',1 .511 La -ng ngs lrvDl... en S._GISA TGo So Caemg o.xnpYon oD girl ID pro Top Inks) semepelnl(a) sir DePL CONDUCTOR I6 15062 200 108.0 108.0 62.50 WELDED Cary Daae,lptlon OD n') IDllnl Tap ISKIN .e DNdFUVD S. pe P. IND).,. Will ll_. Gratle Top Tref SURFACE 9518 8.835 279 2.618] 2,4553 4000 L-80 BTCM . np De0GappOn On bnl ID INI Tap lslLsl SN -P.'""' $el OepN IND1... VMLen 11... Gbae op:..O INTERMEDIATE 1 62]6 246 8,]28.) 7.0036 2600 LA0 BTGm Cealnp Dexca pron OD llnl IDIM) Tap lslLs) 8e1 D¢p.1n"i" s¢, Dep. IND'.....Len 11..."7 TopT- SLOTTEDLINER 4112 3958 8251.) 13,224.0 7,038.4 1260 LA0 SLHT Liner Details Ninne.lD Top taker 1,LUDIInKB) Topincl Pl Its. Dir Co. girl 8,251] 6899.5 6]03 SLEEVE BAKER'HRDSETTING SLEEVE 4.300 8.2639 6906.3 6746 NIPPLE BAKER IRS' NIPPLE 4,250 8265.5 6905.2 67.55 HANGER BAKER DG FLEX LOCK LINER HANGER 5000 82756 69087 67,87 %O BUSHING BAKER CROSSOVER BUSHING 3950 Tubing Strings Turnp Damen tlon I string IS ID (lnl Tap IKKSI Sof We Lo 8H Dep.1 I... Wl(IO12 L-8ae Top ConneetlOn TUBING 4112 3.958 176 8,25].9 6.9020 1260 L-80 IBT-M Completion Details all ID Topfaso TopINo1IMS) Top )nal Pl Earn Des Co. (in) Ga 17.6 aN HANGER FMC 4-12° x 1 V TUBING HANGER U 0.88 OD) 3.958 2.092.9 1.9958 29.01 NIPPLE CAMCO 'DB" LANDING NIPPLE 3813 8,137.2 6851.9 64,22 PACKER BAKER PREM HER PRODUCTION PACKER(710TC1l 3,870 box - pin) 8.196.1 6,8770 6527 NIPPLE HES-%N' NIPPLE 3.725 8.247.2 Dal 66.87 FLUTED NO- SHEAR PIN FLUTED NO GO SUB 3.725 GO SUB 8256.9 6.9016 6721 WILES WIRELINE ENTRY GUIDE 3.970 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tn""' iop Top lkksl (11N81 Incl 1°) Oaa Cam Run Dab IF lin) 2.092.9 1,9958 29.01 VALVE A-11NJECTION VALVE(SIN. HR0308) 612 14 Pertoraffons & Slots Tap8761 Bim Top (ge (nKB' Bim(NU) 1117,0' Zane Data anD, o a Isbobll p Cam H,Ifi1.0 ,241 9,2610 ],D089 ],Ota2 61312011 32.0 SLUTS SLOTS Alternbts Hank SMSAI , HAMVAE G8 4 rowan: no slotslT from dols 3' from bpxryin 9,5210 13,220.0 ],015.3 7,038.4 40011 320 SLOTS Alternating Blank Piped 1/8x2.25',8 0IOES., 4I..M;n0 31010 3' Imm box Nn Mandrel Inserts s, on N TopIND1 TOPHIKES (WED Make Madel OD(In) 8¢ry blw Type Doi Type Ponslae Ilnl TRO Run Ips)) Ron Odh Com 1 8.0328 6,8046 CAMCO NBG-2 1 GAS LIFT DMY BK 0000 00 6/272014 Notes: General &'Safety Enawle annalnlon a O 4116/201. NOTE'. View Sch.rFxbrw/AleSke SchematK90 9/3/2015 NOTE'. Welvele4 fol WatOl lnleCliOn Only.T%IA COmmenIC811Dn On G85. 1 Loepp, Victoria T (DOA) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Monday, January 28, 2019 12:15 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]CRU CD3-198(PTD 211-024, Sundry 318-583) WO Attachments: BOP -Choke Schematic.pdf Victoria, We'll be using Nordic 1 for this workover (schematics attached). We'll be putting these wells on GINJ. Thanks, Kyle Hampton Senior Wells Engineer ( Office. 907-263-4627 1 Cell. 832-421-1506 1 Ky1e.Hampton(c@cop.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Monday, January 28, 2019 9:13 AM To: Hampton, Kyle <Kyle.Hampton @conocophillips.com> Subject: [EXTERNAL]CRU CD3-198(PTD 211-024, Sundry 318-583) WO Kyle, Please provide rig, BOP stack schematic, BOP ram sizes and configuration. Is the well status after proposed work GINJ or is it WAG? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppaalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loepp@alaskaaaov • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,February 20,2018 P.I.Supervisor `S ? CI 7:711 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD3-198 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-198 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv.. 6.2—' NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-198 API Well Number 50-103-20637-00-00 Inspector Name: Lou Laubenstein Permit Number: 211-024-0 Inspection Date: 2/10/2018 ✓ Insp Num: mitLOL180212123329 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well r CD3-198 'Type IIID W'JTVD 6852 I Tubing 2394 2394 2394 . 1 2394 ' PTD 2110240 (Type Test SPT Test psi 3000 IA 1060 3380 - 3320 • 3310 OA 579 825 - i 818 814 'I LP Returned: 1 Interval REQVAR P/F P BBL Pumped: 2 BBL Ret Notes: MITIA per AIO 30.006 to maximum anticipated injection pressure .--- SCANNED i 1? Tuesday,February 20,2018 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,February 10,2017 P.I.Supervisor �� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-198 FROM: Lou Grimaldi COLVILLE RIV FIORD CD3-198 Petroleum Inspector Src: Inspector Reviewed Bp P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-198 API Well Number 50-103-20637-00-00 Inspector Name: Lou Grimaldi Permit Number: 211-024-0 Inspection Date: 1/28/2017 Insp Num: mitLG170129103126 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-198 Type Inj W- TVD 6852 ' Tubing 2157 i 2157 - 2157 - 2157 PTD 2110240 Type Test SPT Test psi 1713 " IA 680 3300 - 3200 • 3180 - BBL Pumped: 2.2 BBL Returned: 2.6 OA 396 679 - 667 657 - Interval REQVAR P/F P ✓ Notes: Passing test required by A.A.variance An 30.006 on this well.Good test.50 degree diesel pumped by Little Red. SCANNED APR 2 7 2017 Friday,February 10,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, February 23, 2016 1:10 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: CRU CD3-198 (211-024) Report of intent to perform diagnostics Attachments: CD3-198.pdf; CD3-198 90 day TIO trend 2-23-16.JPG Chris, CRU injection well CD3-198 (PTD 211-024) is waivered for water injection only(A10 30.006)due to historical TxIA communication while on miscible injection. ConocoPhillips intends to perform diagnostics on the well to determine the feasibility of regaining miscible injection capabilities to the well. The plan is as follows; Circulate out well bore with clean fluids. Bring well online, on miscible injection for a 30 day monitor period. If there are no indications of TxIA communication while on miscible injection a request for cancelation of the current AA will be submitted. If there are indications of TxIA communication while on miscible injection the wellbore will be flushed out with water and then diagnostic logging will be performed in attempt to locate the leak and evaluate potential repair options. Upon conclusion of the diagnostics and/or monitor period ConocoPhillips will provide a follow up email with the plan forward and submit any required paperwork for corrective action or continued injection. Attached is a 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with the plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 SCANNED MAR 1 5 2016 Pager(907) 659-7000 pgr. 123 WELLS TEAM ConocoPholltps1 • • C) Cs o 0 0 a o*t ( pp pp __ p 6f, M fV 6 � d til5 IX? fes+ u,r�, .,, I I I I I i t_ i . I • o 'L' ,r CI) C k' ''' ; IN MOn 1,0 t, 11 IL, r r' t 7 COIIIC O R CD m V a .0 EL, Ul 6 O ....... , t=, 11J U () a) 3 p C11 C • Q / 1 4J UJ 6 , CO LPCO r O) O Q , N O N t[i e e-,-.) 0 `I N V N +��tt o G v, m UJ u I ► I1 co U, v O O C3 LJ Li CJ C) Ci() I I I. 1 I i l d U.1 O U, CJ UJ C) U, '. 1.3 z_,.. CI IlN V co m ra ry :Y i, , '�, 3 i V el N ` p Q ad 1B '0>1M SV) CDw 1Sd • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, August 31, 2015 4:53 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: FW: CRU CD3-198 (PTD 211-024) Report of IA pressure Anomaly Attachments: CD3-198 90 Day TIO plot.JPG; CD3-198 AA justification packet.pdf Chris- Alpine injector CRU CD3-198 (PTD 211-024) is nearing the end of the AOGCC approved 30 day monitor period. As previously reported, the diagnostic MIT-IA and tubing and inner casing packoff tests all passed. The IA has not shown any indications of TxIA communication while on water injection and therefore CPAI intends to apply for administrative approval for continued water injection only due to TxIA communication while on gas injection. It is CPAI's intentions to leave the well on water injection while the AA in in process. Please let us know if you have any questions or disagree with the plan. Attached are a current 90 day TIO plot and an electronic copy of the AA packet for reference. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 WELLS TEAM ConocoPhillips SCANNED AUG 0 4 201 From: Problem Well Supv Sent: Friday July 31, 2015 9:11 AM To: Wallace, C D (DOA) Cc: Senden, R. Tyle Subject: RE: CRU CD3- 8 (PTD 211-024) Report of IA pressure Anomaly N Chris- Alpine's injector CRU CD3-198 (P1-13'h1.-924) initial diagnostics have been completed. The tubing and inner casing pack off tests all passed,the MIT-IA passed, ho er the IA DDT failed. The well will be WAG'd to water injection and an IA bleed will be performed at the first available op tunity for a 30 day diagnostic monitor period with intent to apply for an AA if integrity is proven during water injection. I IA continues to show pressure build up further diagnostics will be scheduled at that time. Please let me know if you have y questions or disagree with this plan. Attached is a current 90 day TIO plot and MIT-form for the diagnostt 1IT. Cheers, y Dusty Freeborn /Jan Byrne `., Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, July 31, 2015 9:11 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: CRU CD3-198 (PTD 211-024) Report of IA pressure Anomaly Attachments: CD3-198 90 Day TIO plot.JPG; CD3-198 Diagnostic MIT-IA.xls Chris- Alpine's injector CRU CD3-198 (PTD 211-024) initial diagnostics have been completed. The tubing and inner casing pack off tests all passed, the MIT-IA passed, however the IA DDT failed. The well will be WAG'd to water injection and an IA bleed will be performed at the first available opportunity for a 30 day diagnostic monitor period with intent to apply for an AA if integrity is proven during water injection. If the IA continues to show pressure build up further diagnostics will be scheduled at that time. Please let me know if you have any questions or disagree with this plan. Attached is a current 90 day TIO plot and MIT-form for the diagnostic MIT. Cheers, Dusty Freeborn I Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907)943-0450 WELLS TEAM SCANNED JUL 3 12015 ca,«oPhar From: NSK Problem Well Supv Sent: Monday, July 27, 2015 2:05 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: CRU CD3-198 (PTD 211-024) Report of IA pressure Anomaly Chris, CRU CD3-198 (PTD 211-024) is being reported for a suspect IA pressure anomaly. Operations bled the IA pressure down on the 24th of July 2015, but the IA has repressurized to the pre-bleed pressure. At this point it is uncertain whether the IA pressure increase is rate and thermal related or if there is a pressure communication issue. CPAI intends to leave the well on miscible injection while mobilizing DHD to CD3 to perform initial diagnostic testing to include an MIT-IA, tubing and inner casing pack off tests and an IA draw down test. If the IA passes diagnostic testing the well will be left on miscible injection for a 30 day monitor. If the IA exhibits indications of pressure communication during testing or while on miscible injection the well will be WAG'd to water for a 30 day monitor. If the well exhibits indications of pressure communication while on water injection the well will be shut in as soon as sufficient sweep of MI has taken place so that wireline services may enter the wellbore for secure and diagnostic purposes. Attached is a wellbore schematic and 90 day TIO trend. 1 Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 EftWELLS TEAM conocoPhalips 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regqealaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov chns.wallace@alaska.gov OPERATOR: ConocoPhillips Alaska,Inc FIELD I UNIT I PAD: Alpine/CRU/ Pad DATE: 07/30/15 OPERATOR REP: ManjarrezlDuffy AOGCC REP: N/A Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3-198 Type Inj. G TVD 6,852' Tubing 4,035 4,030 4,030 4,030 Interval 0 P.T.D.211-024-0 Type test P Test psi 1713 Casing 860 2,880 2,840 2,830 P/F P Notes: Diagnostic MIT-IA OA 390 545 535 530 Well Type In]. TVD Tubing Interval P.T.D. Type test Test psi- Casing P/F Notes: OA Well Type In]. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In]. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Dnlling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) CD3-198 Diagnostic MIT-IA xls W Ii W 0 µaa a a a a a aC Ce 1 W r; W w uJ w w _ C) V C. --7, O = 0 = 0 0 0 N W CC o N •) U. u, 0 0 IL, _W I'...I u, V La- (3 C, V) W V oo aacoo' G .EX , lUC o I. D) 1-...-CIf 1 co a, w E ' W IT o N p) u, o u, o, cb r, o r) P. Q `4' rJ ry a .� t~ c' I-- u.')N u, W u, u, W u. uy u', w o CJ o 0 o O O O 4 rJ [J N f_J Els.' [J NI +' V O) o uui 'T it. � rJ rJ �- rJ N U. N r- r- t- r- t)^ ti. [f u) 0 [i) co Cl; u) co co co co —) )r) C1) CC) ci) b) or o) at J J r. F- r, r) r) r) c), rel LU u U U C.3 C) O C] Cl U C ✓ a C. U) CJ C) (.3 C) 0 0 0 0 0 0 0 --�d6ap - � CO 0 w' in 1 1 4 1 1 I 1 4 I 1 �, _ -d 41) i j � v C '* / -0li 0) c')' VI 1 C 0 a C a = i w oo U ...CC 1 6.11 a) = 4 o C , ........ _i° C 1 a Q 03 a 454. i CO LC: Cl? G414 N O N O rpt rn M 0. � a 0a l 14 a I I I I I � � Y s, [. o Co 1 1 1 n oCI � W RS V3 Iii C] U. O U, O , VTR. NI z CD 0 am war a) m 0:3 -0 isd N o w Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, July 27, 2015 2:05 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: CRU CD3-198 (PTD 211-024) Report of IA pressure Anomaly Attachments: CD3-198 wellbore schematic.jpg; CD3-198 90 day TIO trend 7-27-15.JPG Chris, CRU CD3-198 (PTD 211-024) is being reported for a suspect IA pressure anomaly. Operations bled the IA pressure down on the 24th of July 2015, but the IA has repressurized to the pre-bleed pressure. At this point it is uncertain whether the IA pressure increase is rate and thermal related or if there is a pressure communication issue. CPAI intends to leave the well on miscible injection while mobilizing DHD to CD3 to perform initial diagnostic testing to include an MIT-IA, tubing and inner casing pack off tests and an IA draw down test. If the IA passes diagnostic testing the well will be left on miscible injection for a 30 day monitor. If the IA exhibits indications of pressure communication during testing or while on miscible injection the well will be WAG'd to water for a 30 day monitor. If the well exhibits indications of pressure communication while on water injection the well will be shut in as soon as sufficient sweep of MI has taken place so that wireline services may enter the wellbore for secure and diagnostic purposes. Attached is a wellbore schematic and 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. SUMO JUL 2 8 2015 Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 WELLS TEAM corwcoPhalips 1 cu U • OAC 00U) 0) Utu) U) `ref - 2c_. 2- 2GzL aaoc � cr a (Z/ w w w W w w w i_ g D Z D D Z D D U 0 - 0 _ 0 0 0 N .n O N Q .n u) O O WC)7 M CO p CD N I C") Cl.ffCO N CO .? u. O ', c y.r) CD C, C) 0 C) .n CO N u! ., O O (n <J CO O > Kcn 0) f+ CD CD un S d z a d : y us Cil N O O N V u7 u) CO W C"1 C') CO 0) 0 O r+ N CY CO In Co M O) M f+ CD CI: N N N K I- (0) +n 4) ul Qr. u) .C) .n .n 0 0 0 0 0 0 0 0 uJ N N N N N CV N CV p CV N .- .- CV N CV n n N- (Z.: CD Zia un; CCO CO CO CO CO co CO CO —1 61 0) 0) on Q) Q) O) G) J _I en f"') C") C") C') C') C`") C"') w�++ 00000000 - 00000000 a o a AB op v N d C3 0 m n H o y.! 1 1 1 1 I 1 1 a -- ___ _ ur N 3 1 1 CU 75/5) C.) C '''' .. c. y N C O i7 ui lB C IsZ I .O o r a 71 414 c C C au' F Q A in An oo r r co M d) ti2 ;i : # o 0 tt fti a ^ r Z C 4 s CV G 47 i I I ; Irk kr, tD tv 0 0 0 o 0 0 0 0 0 o a$ % " x 0 N V o M M N N .r O yr I> Rte) T ^ Cid 1B III DR A !Sd c w t WNS INJ CD3-198 ConocoPhillips ; Well Attributes Max Angle&MD TO Alaskains" WYIbon.APVWA Reid Name WNlbore StatusIntl I') MD initial Act8tm l05Bt (nraartetelkp, 501032063700 FIORD NECHELIK INJ 81.21 9,205.02 2,228.0 ... Comment H29 Ippm) Date Annotation End Date KB-Ord IR) Rig Release Date 703.198,al23/20I5321.25 PM SSSV.WHOPLast WO. 4912011 -At//al Schematic(actual) Annotation Depth(MEI) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:SET INJ'ITV 1=_hall) 4:2312015 Casing Strings Casing Deecnption OD(In) D(In) Top(MB) Set Depth MB) Set Depth(ND)...Wt'Len(I...Grade Top Thread CONDUCTOR 16 15.062 28.0 108.0 108.0 62,50 WELDED HANGER.176- F. Casing Omcnptlon OD(in) D On) Top iftKB) Set Depth(IIKB) Set Depth(ND)...Wt'Len(I...Grade Top Thread SURFACE 95/8 8.835 27.3 2,618.7 2,455.3 40.00 L-80 BTCM Casing Dacnptlon ,.� OD On) D(In) Top(19)8) Set Depth((the) Sat Depth)TVD)...wtLen(I...Grade Top Thread l INTERMEDIATE 7 6.276 24.6 8,728.7 7,003.6 26.00 1-80 ETC-ill I Casing Dedcnption OD(In) D(In) Top(18<9) Set Depth(MB) Set Depth(ND),..WULen(I...Grade Top Thread ' 07 SLOTTED LINER 4 112 3.958 8,251.7 13 224.0 7,038.4 12.60 L-80 SLHT • 7 i Liner Details Nominal ID 7%.} I Tap lttKB) Top(TVD)104e) Tip Intl(•) Ite n Des Coin (In) 8,251.7' 8,899.5 67.03 SLEEVE BAKER'HRD'SETTING SLEEVE 4.380 8,263.9 6,904.3 67.46 NIPPLE BAKER'RS'NIPPLE 4.250 8„266.5 0,005.2 67.55 HANGER 'BAKER DG FLEX LOCK LINER HANGER 5.000 8,275.6 6,908.7 67.67 XO BUSHING BAKER CROSSOVER BUSHING 3.950 caNDucTOR;zealae9_. Tubing Strings Tubing Deterlption String Nh.,.10 pn) Top&YtSe) Sat Depth(ft..Set Depth(11/011...lift(Mt) Grade Top Connection I TUBING 41'2 3.258 17.0 8,257.9 6,202.0 ''2.601-82 151-14" Completion Details Seminal ID NIPPLE;2492.9 Top(fthB) Top((NO)41KB) Top Mot(') Item Des Colt (in) VALVE,2p929 17.6 17.6 0.00 HANGER PMC 4-112"x 11'TUBING HANGER(10.85 OD) .,.^o59 2,092.9 1,995.8' 29.01 NIPPLE CAMCO"D8"LANDING NIPPLE 3.6 2 8,137.2 6,851.9 64.22 PACKER BAKER PREMIER PRODUCTION PACKER(4.112"TCII 3871 box-pin) 8,196.1 6,877.0 65.27 NIPPLE HES'TCN'NIPPLE 7.75 8,247.2 6,897.8' 66.87 FLUTED NO- SMEAR PIN FLUTED NO GO SUB ..,__ GO SUB 8,256.9 6,901.6 67.21 WLEG WIRELINE ENTRY GUIDE 3.272 SURFACE;279.281g7--(A 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Intl Top(1048) (RKB) (') Dee Com Rin Date ID(In) 2,092.9 1,995,8 29,01 VALVE A-1 INJEC11DN VALVE(SIN:HRS-308) 6272014 a Perforations&Slots 71 Shot Dens OAS LIFT;9032. Si Top(TVD) elm(TVD) (cFro6,f Top(ftl(8) Bbn(10(6) (4548) (hKB) Zone Date t) Type Com 8,/6'.0 9,241.0 1,006.9 7,01.4.?. "4,112011 32.0 SLOTS ARernabng Blank Ptpe/Slots 118x225",8 slots/row,4 rows/ft;no slots 3'from box/pin 9.521.0 13,220.0 7,015.3 7,038.4' '4/312011 27.0 SLOTS Alternating Blank F5pe7Sloe 1/8x2.25",8 l5:I4=R;8,137 2 - slots/row,4 rows/ft;no .......... slots 3'from box/pin Mandrel Inserts _ St NIPPLE;9,1961 atI on Top IND) Valve! Latch Port Size TRO Run N, Tap MB) (MS) mew Model OD(In) Sery Type Type (m) (ps1) Run Date Corn 1 8,032.8 6,804.6 CAMCO KRG-2 1 GAS I IFI DMY BK 0.000 0.0 5/2117,001a. • Notes:General&Safety End Date Annotation FLUTED NO-GO 9J8;8.247 2 41160011 NOTE:yew Schen tate:w/Alaska Schemata-9.0 WIG;825E9 LI I U I INTERMEDIATE;248.8728.7- SLOTS,8.791 0}9241.0 ..... [ SLOTS 9,5210.13,2200 211 — 6244 a3 - t`Ts) '11-v RECEIVED ConocoPhillips APR 272015 Alaska AOGcc P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 23, 2015 SCANNED MIA" 0 . . a15 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. A s per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, ,/(//y/1,-- MJ foveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10404) Alpine Field Date 4/23/2015 CD3 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal _ CD3-121 50103206150000 2100220 32" NA 32" NA 29.7 3/12/2015 CD3-122 50103206090000 2091530 74" NA 74" NA 49.3 3/12/2015 CD3-130 50103206770000 2131600 38" NA 38" NA 20.4 3/12/2015 CD3-198 50103206370000 2110240 28" NA 15" NA 2.5 3/24/2015 CD3-316 50103205590300 2140180 9" NA 26" NA 14 4/20/2015 CD3-320 50103206670000 2130060 6" NA 6" NA 1.7 3/24/2015 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg IC� ` Z DATE: Wednesday,April 15,2015 P.I.Supervisor \ ( 4(Z l"a SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-198 FROM: John Crisp COLVILLE RIV FIORD CD3-198 Petroleum Inspector Src: Inspector Reviewed By: P.I. NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-198 API Well Number 50-103-20637-00-00 Inspector Name: John Crisp Permit Number: 211-024-0 Inspection Date: 4/12/2015 Insp Num: mitJCr150413043515 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-198 Type In,j W TVD 6852 _I Tubing i 2673 = 2650 ' 2646 2641 - PTD1 2110240 TestLSPT Test psi 1713 , IA 1165 2061 - 2027 - — 2019 - Intervall4YRTST - P/F P OA 508 584. 575 567 Notes: 6 bbl pumped for test - SCANNED MAY 0 4 2015 Wednesday,April 15,2015 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning 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. cD, I L - Oa L- Well History File Identifier Organizing (done) Two-sided 11111111 III IIIII ❑ Rescan Needed II 1111111 1111111 ' RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ D' kettes, No. n f ❑ Maps: reyscale Items: GOther, No/Type:G `�® P r ' Other Items Scannble by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: C Maria Date: (o/c #3//4i. /s/ (viP __P Project Proofing 11111111111 IIIII BY: Maria) Date: (2/A8//q. /s/ rYti) Scanning Preparation x 30 = JV + a I = TOTAL PAGES 117/ BY: de" Date: `(_j. (Count does not include cover sheeill � /s/ Production Scanning I IIIIIIIIIIIIIII Stage 1 Page Count from Scanned File: (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: (19/ / ` /s/ to Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 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Box 100360 Anchorage, AK 99510 Re: Colville River Field, CD3-198 Sundry Number: 313-004 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy . Foerster Chair DATED this/ day of January, 2012 Encl. • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 0 $ 2013 _ ANNULAR DISPOSAL APPLICATION / / v 13 D /� o�cc 20 AAC 25.080 / 1.Operator 3.Permit rill Name: 211-024 ConocoPhillips Alaska 4.API Number: 50-103-20637-00-00 • 2.Address: • 5.Well P.O. Box 100360,Anchorage,Alaska CD3-198• 6.Field: • Colville River Field 7.Publicly recorded wells • 8.Stratigraphic description: a)All wells within one-quarter mile: a)Interval exposed to open annulus: CD3-108, CD3-109, CD3-110, CD3-111, CD3-112, CD3-107, • CD3-302, CD3-113, CD3-301, CD3-316A, CD3-106, CD3-121, Torok and Seabee formation,shale,siltstone and sandstone CD3-119. b)Waste receiving zone: b)water wells within one mile: .Sand layers below the C30 marker in the Seabee formation None c)Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower baffler 9. Depth to base of permafrost: 10.Hydrocarbon zones above waste receiving zone: approximately 1234'MD/1224'TVD ' None 11.Previous volume disposed in annulus and date: 12.Estimated slurry density: 13.Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2311 14. Estimated volume to be disposed with this request: 15.Fluids to be disposed: 35,000 bbls.- Types of waste may be drilling mud, drilling cuttings, reserve pit fluids,cement- contaminated drilling mud, completion fluids, diesel,formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash-fluids, cement rinsate, domestic waste water,any 21-Jan-13 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other . substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17.Attachments: Well Schematic(Include MD and TVD) 2• Cement Bond Log(if required) ElFIT Records w/LOT Graph Q Surf.Casing Cementing Data Other L previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: �f �J� Title: `�` l Printed Phone Name: Chip Alvord • Number: 265-6120 Date: ! (L 12',3 Commission Use Only , / Conditions of approval: LOT review and approval: ` C�1N 17-30-L3 Subsequent form required: 1V— 4 2 3 Approval number: �'✓ 9 / • APPROVED BY Approved by:ALA, COMM ISS THE COMMISSION Date: J._ x-13 �1 Li 6 I L 7�. /2004 INSTRUCTIONS ON REVM S SAN 2 $ 201 mit in Duplicate -0�\°\�. ' , � ConocoPhillips Alaska,Inc. Post Office Box 100360 • • Anchorage,Alaska 99510-0360 ConocoPhiHips Telephone 907-276-1215 January 2, 2013 RECEIVED Alaska Oil and Gas Conservation Commission JAN 0 8 2013 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 AOGCC Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3-198 AOGCC Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3-198 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD3-198 approximately January21, 2013. • Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Plan View of Adjacent Wells 4. Surface Casing Description 5. Surface Casing Cementing Report&Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report(LOT at surface casing shoe). 7. Intermediate Casing Description - 8. Intermediate Casing Cementing Report&Daily Drilling Report during cement job 9. Formation LOT on 9-5/8"x 7" casing annulus 10. List of wells on CD3 pad and the lateral distance from the surface casing shoe 11. Information regarding wells within '/4 mile radius at AOGCC: CD3-108, CD3-109, CD3-110, CD3-111, CD3-112, CD3-107, CD3-302, CD3-113, CD3-301, CD3-316A, CD3-106, CD3-121, CD3-199. 12. Information regarding remaining wells within 1/4 mile radius included in sundry package: CD3-119 13. Copy of previous authorization (CD 1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT(15.9 ppg)occurred at a lower equivalent mud weight than the casing shoe FIT(18.1 ppg). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT. If you have any questions or require further information, please contact Nina Anderson at 265-6403 or Chip Alvord can also be reached by calling 265-6120. Sinceil . -- r /1 p Nina ti‘ on Drilligineer cc: . CD3-198 Well File Chip Alvord ATO-1570 Sharon Allsup-Drake ATO-1530 ORIGINAL Annulus Disposal Transmittal Form - Well CD3-198 AOGCC Regulations,20 AAC 25.080(b) 1 Designation of the well or wells to receive drilling wastes: CD3-198 2 The depth to the base of freshwater aquifers and permafrost,if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost= 1600' TVD(RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission fording that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref.AOGCC Conservation Order No.443, March 15. 1999) 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud,drilling cuttings,reserve disposed of and the estimated density of the waste slurry. pit fluids,cement-contaminated drilling mud,completion fluids,diesel,formation fluids associated with the act of drilling a well,drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate,mud plant rinse fluid generated by rinsing waste under(h)(3)of this section. tanks and equipment after producing drilling/completion fluid (see included note from CD 1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2311 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports,LOT/FIT reports and base of any freshwater aquifer and permafrost,if present,and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones,if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation,not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations,the volumes of waste disposed of,and the wells where the drilling waste was generated. 14 The well(s)where the drilling waste to be disposed of was or CD3-320,CD3-316B,CD3-127 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in(d)of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Va ion 2.0-lan'13 Well CD3-198 Assumptions Date 1/15/2013 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg f 9 Pore pressure at the 9 5/8"casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure(for wells on gas lift) 1,000 psi Maximum Fluid Density to avoid Burst of Surface Casing Pburst85%=PHydrostatic+PApplied-PFormation 4,888 =( 2,455* 0.052 * M W,nax )+ 1500 - ( 0.4337 * 2,455 ) r. .v cam: MWmax = 34.9 ppg 2.455 TVD Surface Casing String Size 9.625 in — TOC Est.@ 3,581' M) Weight 40 ppf 3,288' TV t Grade L 80 S �^ I'burst100% 5,750 Ps' T 'Mi) Pburst85% 4,888 psi Depth of Shoe 2,455 ft FIT/LOT @ Shoe 18.1 ppg or 2,311 psi FIT/LOT for Annulus 15.9 ppg E* Max Surf.Pressure 1,500 psi I- 'N TOC Est.@ 6,835' MD 5,962' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85%=PHydrostatic+PApplied-PGasGradient-PHeader 4,599 =( 5,962* 0.052 * M Wmax )+ 1,500 - ( 0.0700 * 5,962 ) - 1,000 Z Z MWmax = 14.6 ppg 45 I-ubing 2nd Casing String Size 7 in 7.0n4 1VD Weight 26 ppf Grade L 80 1'collapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 5,962 ft Gas Gradient 0.07 psi/ft Max Surf.Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable=Shoe TVD Depth* .052* Shoe FIT/LOT Pmax allowable= ( 2,455 *.052* 18.1 ) Pmax allowable= 2,311 psi This is the value for the Injection Permit"Maximum Anticipated Pressure at Shoe". • -,Sciws,JO 91g2.oi Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 1.0-Jan'05 Well CD3-198 Assumptions Date 1/3/2012 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 pp Pore pressure at the 9 5/8"casing shoe is 0.434 psi/' Gas/Fluid Gradient in tubing/casing annulus 0.07 p ft iiiii Header Pressure(for wells on gas lift) 1,000 psi ai '::;�::; Maximum Fluid Density to avoid Burst of Su ace Casing :': Pburst85%=PHydrostatic+PApplied-PFormation c 4,888 =( 2,455* 0.052 *MWmax )+ 1500 - ( 0.4337 * 2,455) N oN::: MW„. = 34.9 ppg 2,455 TVD Surface Casing Strin Size 9.62 in . Weight ppf Grade - L 80 • yV rburstl00% 5,750 psi .y Pburst85% 4,888 psi C3 Depth of Shoe 2,455 ft FIT/LOT @ Shoe • 18.1 ppg or 2,311 psi - FIT/LOT for Annulus 15.9 ppg o Max Surf.Pres 're 1,500 psi 0 ` TOC Est.@ 4,558' MD _ 4,080' TVD Maximum Fl "Density avoid Collapse of 2nd Casing String Pcollapse85%=PHydrostatic+PAppfied-PGasGradient-PHeader 4,599 =( ,080* 0.052 *MWmax )+ 1,500 - ( 0.0700 * 4,080) - 1,000 Mwmax = 20.7 ppg 4.5 "Tubing 2nd Casing String Size 7 in 7,004 TVD • Weight 26 ppf , Grade L 80 I'collapse100% 5,410 psi Pcollapse85% 4,599 psi / Top of Cement 4,080 ft Gas Gradient 0.07 psi/ft Max Surf.Pressure 1,500 psi • / Header Press 1,000 psi • Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable=Shoe TVD ' epth* .052 * Shoe FIT/LOT Pmax allowable= ( ,455 *.052* 18.1 ) Pmax allowable= • 2,311 psi This is the value for a Injection Permit"Maximum Anticipated Pressure at Shoe". F, c 0p . 0 • d �C_C_C_C_C_ O Q maaaaao- ,^ CO O 0NtO0O - u, 00 O c4 ,yN NN ON� rCa r� \ NN X22 o,sssros cootowco <n t�n ver aov w oN Nr,non �' z000000 Z000000 3 wv”,§ 7r U '2','22 ,g8 �c`ggo!o NN N 1 \ N zciai�ro2 N }NNOI I�N J NNCINNN F w (/)000000 rO ,000000 �++ Om mm ONn (;f NO O(OOnOr Or CC CC Li, 7f 1.0 MI 1� - cc) J w 4.14110144§ ` I-- IT m d O N \ _2=F-F- ma000 �' Ta 411111111SiL\ 3NNNN k I 0999 �0 N\ o Z 0 U000 0o 0 0 0 t` \ O VF T ,o T O r ,A Alighi V _ N _. O 0 NV 1-0 (13 c) z 1 r4.4N C) `� �� / a CO /,_ i ce_ fo O N MIK CI CD r ._ 41i Iii I 2 , O CD CD 1 1. aS M , fv/ i , li/ - 1, IIIIO -fir _� !®d _ o ® T • d 0 N — �I` CO o l 1 . 1 1 , I I t° O O O O O O c O Ln O co N CD T LC) f N T- (U1AI o ) (+MaoN/(-)u1noS r K.,_,,,.,‘ _ .. .. . , . . - ) CD3-198 9-5/8" Surface Casing Well: CD3-198 pr1 L-60 c-rn aria Clti a-51,-1C Date: 3115/2011 CohotoPhillips . Rig: Lloyon Rig 141 11 ,L*0111C. „ „ „, Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 RKB tQ top of lding ring 27 87' RKB to Top of Landing Ring 27.87 jii11,11111111111,11101110111111 FMC 9 5/8" Casing Hanger .22 27.87 9-5/8" Pup in the hanger pin x pin 2.15 28.09 Jts 29 to 62 34 Jts 9 5/8", 40.0#, L-80, BTC-m Casing 1409.11 30.24 Jts 4 to 28 25 Jts 9 5/8", 36.0#, J-55, BTC Casing 1055.11 1439.35 Jts 3 to 3 1 Jts 9 5/8", 40.0#, L-80, BTC-m Casing 41.34 2494.46 HES 9 5/8" Sure Seal II Float Collar 1.21 2535.80 Jts 1 to 2 2 Jts 9 5/8", 40.0#, L-80, BTC-m Casing 79.43 2537.01 Ray Oil Tools 9 518" Silver Bullet Float Shoe 2.24 2616.44 Shoe depth 2618.68 - 2618.68 Baker Lock 1st 3 joints and pin on 4th joint 2618.68, 2618.68 1 Bowspring Centralizer on stop collar 10' above the top of shoe. 2618.68 1 Bowspring Centralizer on stop collar 10' below the box of joint # 2 2618.68 2618.68 Bowspring centralizers on joints #4 -#13. Then run Bowspring 2618.68 centralizer every other joint#15 to #61. 2618.68 2618.68 Centralizer placement highlighted in yellow on tally sheet. 2618.68 38 total centralizers, 2 stop rings 2618.68 2618.68 11 Joints of 9-5/8" casing remain in shed 2618.68 10 jts of 36 ppf J-55 BTC 2618.68 1 jts of 40 ppf L-80 BTC-m 2618.68 2618.68 TO @ 2630' MD ( 2465.2' TVD) 2618.68 Shoe @ 2618.68' MD (2455.11' TVD) 2618.68 Rat hole 11.32'. 2618.68 2618.68 2618.68 2618.68 2618.68 2618.68 2618.68 Remarks: Drifted w/8.775"teflon drift Up Wt 123 K Used Jet Lube Run-N-Seal dope. Dn Wt 95 K Torqued 40 ppf L-80 to 10,000 Ft lbs of torque, 36 ppf J-55 to 8000 ft lbs Block Wt 35 K Supervisors: Fred Herbert/Granville Rizek .qq V 5 �� r7 , Cement Detail Report , . CD3-198 . Kai s €CoalocoPhuUi . String: Surface Casing Cement • Job: DRILLING ORIGINAL,.3/11/2011 15:00 Ce entDetails S - Description Cementing Start Date Cementing End Date . Wellbore Name ' - Surface Casing Cement .• 3/15/2011 15:00 3/15/2011 17:52 • CD3-198 Comment • Cement Stages c:a "'-_ r : --x M `N r -.- t*A As .'M ;,rie' Ana Rx.'n..n 3`ps a; Stage#1 gf :.; . .... ,al;: IMMMMEN,I ' a ` ';.::' .r I- Description Objective • . Top(ftKB) Bottom(ftKB) Full Return? Cmnt Rtrn(... Top Plug? Btm Plug? • Surface Casing Cement Cement surface casing 27.9 2,630.0 • Yes 114.0 Yes . Yes Q(start)(bbl/min) Q(end)(bbl/min) Q.(avg)(bbUmin) P(final)(psi) P(bump)(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 3 5 600.0 .1,400.0 . Yes 11.00 - No Depth tagged(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 90 bbls of 10.0 ppg mud with nut plug marker(7.5 ppb)at 7 bpm with 450.psi. Next pumped 24 bbls of 8.34 ppg Biozan preflush with nut plug marker (5.7 ppb)at 7 bpm with 450 psi. Reciprocated 15'to 20'. P/U 123k lbs and S/0 95k lbs. Dowell pump 5 bbls water and pressure test lines to 3500 psi,good. Bleed off pressure and drop bottom.plug.Mix and pump 40 bbls Mud Push II spacer(10.9 ppg),pump at 4.5 bpm w/400 psi. Mix and pump 276 bbls(755 sx) AS LiteCrete lead cement(11 ppg,2.05 cuft/sx,7.344 gal water/sx),pump at 4.8 bpm with 644 psi.Mix and pump 49 bbls(238 sx)Alpine tail cement(15.8 ppg, 1.16 cuft/sx,5.105 gal water/sx),pump at 4.5 bpm with 600 psi. Shut down and drop top plug. Dowell kick out top plug w/20 bbls water, pump at 5 bpm with 55 psi. Rig displace cement with mud pump#2 and 10.0 ppg mud.Pump at 7 bpm with initial circulating pressure of 300 psi.After pumping 170 bbls at 7 bpm,slowed rate to 3 bpm,with a FCP of 600 psi.Bump plug at 1727 strokes, 173.56 bbls(calculated displacement of 1735 strokes with 0.1005 bbls/stroke) and pressured.up to 1400 psi.Held pressure for 5 minutes.CIP @ 1752 hrs 3/15/2011. Note:Reciprocated until 500 strokes into mud displacement.Landed at 500 strokes into displacement which was 9.5 bbls before cement returns.Circulated 114 bbls of good 11 ppg cement to surface. Cairri lws addtive'1. 3, enggi --- " y . 7i - gniaa srsi° : y - a r : FU1c emnima ` rex • tgi sm Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud w/nut plug 90.0 Yield(ft'lsack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 10.00 Additives • Additive . Type - Concentration Conc Unit label Fluid r air s SI ..NIM SM ~ t ea 7s a gi Y. s .,. 'luid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl)`` Biozan Pre Flush 24.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 8.34 Additives additive Type • Concentration Conc Unit label •1UId 4s _ K.. • :luid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Vlud Push 40.0 (ield(ft/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 10.90 kdditives - kdditive Type • Concentration Conc Unit label luid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class • Volume Pumped(bbl) \S Lite-Lead 26.5 • 2,016.4 755 • 276.0 geld(W/sack) Mix H2O Ratio(gaUsa... Free Water(%) Density(Ib/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) ' 2.05 7.34 1.1.00 `,dditives- 1dditive • Type Concentration Conc Unit label 4. I & .,ems_"ara�.�:�Mg». aaft _.g_. AWrtaV•� ..�`� ''�;�'.s ' szTa ��s` �±��-�.�-3'� luid Type • Fluid Description -Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) 3-Tail 2,016:4 • 2,673.0 238 • G • 49.0 field(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) • 1.16 5.11 . 15.80 . 54.9 4.32 • • Page 1/2 • Report Printed: 1/2/2013 4,` y a. Cement Detail Report CD3-198 • cc}n4C:Phillips v String: Surface Casing Cement Job: DRILLING ORIGINAL,3/11/2011 15:00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) S002 0.8 %BWOC • • Page 2/2 Report Printed: 1/2/2013 • Security Level: AK Development • Daily Drilling Report (No Costs) gA • • X CD3-198 Ctietj� t�>at�r[ y Report Number: 5 • Rig: DOYON 141 Report Date: 3/15/2011 Wellbore Well Type .. , Field Name DFS(days) DOL Depth Progress(ft). Depth Start(ftKB) Depth End(ftKB) CD3-198 Development FIORD NECH.ELIK 3.19 - 5.0 • 0.00. • .2,630.0 2,630.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date • 3/11/2011 3/12/2011 25.49 23.36 2.13 4/3/2011 Last Casing String • Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE,2,618.7ftKB . . • • Ops and Depth @ Morning Report - 24hr Forecast Test BOPE,witness waived by AOGCC insp Jeff Jones NU BOPE, RU/Test BOPE,.PU/stand back 5"dp,MU BHA#3, . single in to FC,test casing,cleanout cement,drill 20'new hole, • peform FIT/LOT,drill 8-3/4"intermediate. Last 24hr Summary POOH UD BHA to 83',download MWD,con't to UD BHA,clean floor,UD tools f/floor,PJSM,RU to run 9-5/8"casing,PJSM,Run 9-5/8"40 ppf L-80 BTC-m casing shoe track to 105',circ through float equipment,con't to run 9-5/8"36 ppf J-55 casing to 1175',then con't to run 40 ppf L-80 BTC-m casing to 2505',circ 68 bbl during crew change,con't to run last two joints at#62 in the hole), MU FMC hanger,RIH land©2618.68'.R/D Frank's tool,RU.Dowell cement head and lines.Break circ,stage up to.7 bpm while conditioning mud f/cement job while reciprocating 11'.Reduced PV/YP to 50/21 w/10 ppg mud weight. PJSM. Pump 90 bbls of 10 ppg mud w/7.5 ppb nut plug,follow w/ 24 bbls biozan preflush w/5.7 ppb nut plug.Switch over to Dowell and pump 5 bbls of water,press test lines to 3500 psi. Drop bottom plug and pump 40 bbls of MudPush II spacer @ 10.9 ppg. Pump 276 bbls of LiteCrete lead cement followed by 49 bbls Alpine tail cement. Drop top plug and kick out w/20 bbls of water using Dowell..Displace cement w/rig mud pump#2 and 10 ppg mud. Bumped plug @ 1727 strokes(173.56 bbls)and pressure up to 1400 psi. Hold pressure f/5 minutes.CIP @ 1752 hrs 3/15/2011.Landed hanger on landing ring 9.5 bbls before good 11 ppg cement was to surface.Circulated 114 bbls of good 11 ppg cement to surface.Blled off pressure,check floats-good. PJSM, R/D cementing and casing running equipment.PJSM,then nipple down riser and FMC adapter,flush annular of cement.Clear a line of sight to align wellhead to mark on VSM. Nipple up FMC Gen II wellhead,torque lock down screws to 450 ftlbs.Test metal to metal seals to 1000 f/10 minutes.Witness of test by rig supervisor.Obtain RKB measurements to lockdown screws. • • General Remarks • Weather Hoad Count No Incidents, No Accidents. Rig and Camp on Hi-line. -9°Wind W @ 12 MPH,WC-28° 47.0 v:.liMMISAMMTMUMWMCCiaiNt Guy Whitlock, Rig Supervisor Rig Supervisor Fred Herbert, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor • Ryan Robertson, Drilling Engineer Drilling Engineer tat Ehd�; Durf' i T me llepth Start:Dep to Erid a -i Cim S�i*S 60 Phases :Qp ode AtLnfyCode PTX Trbl Code T bl Class n( oNZi etR ., � r*Uor zos* 00:00 01:00 1.00 SURFAC DRILL PULD P 738.0 83.0 POOH UD 6 jts of 5"HWDP,jars,2 NM flex drill collars,UBHO and float sub V 738'to 83'. . 01:00 01:30 0.50 SURFAC DRILL- OTHR P 83.0 83.0 Download Sperry Sun MWD. . 01:30 02:30 1.00 SURFAC DRILL PULD P 83.0 0.0 Continue to UD BHA f/83'.Break bit and drain motor.Calc fill f/trip 30 bbls,actual 39 bbls. 02:30 03:00 0.50 SURFAC DRILL PULP P Clean floor. • 03:00 03:15 0.25 SURFAC DRILL PULD P Lay down Sperry Sun tools from the floor. 03:15 03:30 0.25 SURFAC CASING SFTY P . Pre job safety meeting on rigging up to run 9-5/8"casing. 03:30 04:45 1.25 SURFAC CASING •RURD P Rig up casing running tools for 9-5/8" casing. 04:45 05:00 0.25 SURFAC• CASING SFTY P Pre job safety meeting on running 9-5/8" • • 40 ppf L-80 BTC-m and 36 ppf J-55 BTC casing. 05:00 05:45 0.75 SURFAC CASING RNCS P • 0.0 105.0 Run 9-5/8"casing:.MU 9-5/8"casing shoe track as per detail:Rays Oil tool - float shoe joint,.thread lock joint,HES . Sure Seal II float collar joint.All Baker • Locked. • • • • _atest BOP Test Data • Page 1/5 Report Printed: 1/2/2013 Security Level: AK Development - : y Daily Drilling Report (No Costs) It t- $ ' CD3-198 v, � = Report Number: 5 - � tea Con a oPtmttl,; ` Rig: DOYON 141 - Report Date: 3/15/2011 Time Log : 'SSr SMOia Y + MaxL s--h, `'*:.'A'' ` Mitaiga �-,n'�t�.�� OMii r 'g Start End: Dur itapoom �t r s Time yr^ MS"' Depth Srarr�Depth End ttr.V. .... h,,,sr zr PTX "Trbl Code'` Trbr 01:14-'.-It?!� . r(ffK&jz "x sK ,.0 Opecatron Yt .,.<nr slime. Time: (hrs) � Phase':: �-�OµCode_ st„,.ActiuiryCode - AR 05:45 06:00 0.25 SURFAC CASING CIRC P 105.0 120.0 Circulate through float equipment using • Frank's fillup tool w/'9-5/8"shoe above . conductor shoe @ 108'.Circulate 3 bpm- 150 psi-40%Totco flow,4 bpm-200 psi-46%Totco flow,5 bpm-250 psi-48% • Totco flow and 6 bpm-300 psi-49%Totco flow. • 06:00 08:45 2.75 SURFAC CASING RNCS P 120.0 1,422.0 Continue running casing to 1422'(JT# • 34 in the hole).Baker locked the 4th jt pin end.MU torque 10,000 ft lbs f/40 ppf L-80 and 8000 f/36 ppf J-55.The first 3 jts were 40 ppf L-80,#4-#28 were 36 ppf J-55.All pipe after jt#28 was 40 ppf L-80. Installed centralizers per plan: 10' , above shoe over a stop ring,collar of jt - #1, 10'below box of jt#2 over a stop ring.Every collar to jt#13,then every odd joint.to jt#61.Used Run-N-Seal dope on the threads. • 08:45 09:45 1.00 SURFAC CASING CIRC P 1,422.0 1,465.0 Circulate 200 bbls(surf-surf),reciprocate f/1422'to 1465'(JT#35 in the hole). Initial PU wt 90K SO wt 61k.After .circulating PU wt 85k,SO wt 75k.Step rate up f/3.5 bpm w/300 psi.After pumping 70 bbls,increase to 4 bpm w/ • 250 psi.After pumping 90 bbls, increase rate to 5 bpm w/300 psi.After pumping 120 bbls,increase rate to 6 bpm w/400 . psi. Pumped a total of 200 bbls.. 09:45 11:30 1.75 SURFAC CASING RNCS P 1,465.0 2,468.0 Continue to run 9-5/8"casing f/1465'to 2468'(jt#60 in the hole). 11:30 12:00 0.50 SURFAC CASING CIRC P 2,468.0 2,505.0 Circulate 68 bbls on jt#60 during crew change. Reciprocate f/2475'to 2505'. • Pumping 3 bpm w/300 psi. PU wt 127k, • SO wt 94k.Calculated displacement to 2468'was 29.9 bbls,actual was 20 bbls. • 12:00 12:15 0.25 SURFAC CASING RNCS P 2,505.0 2,618.0 Continue to run 9-5/8"•casing f/2505'to 2585'(jt#62 in the hole).Make up FMC hanger and landing joint.Run in the hole, land on hanger w/shoe @2618.68'.SO wt 93k.PU wt 123k. 12:15 12:30 0.25 SURFAC CASING RURD P 2,618.0 2,618.0 Rig down Frank's fillup tool. Blow down the top drive. . 12:30 12:45 0.25 SURFAC CEMENT CMNT P 2,618.0 2,618.0 Rig up Dowell cement head.and lines. 12:45 14:45 2.00 SURFAC • CEMENT. CIRC P 2,618.0 2,618.0 Circulate and condition mud.Stage pumps up f/2 bpm w/250 psi to 7 bpm w/450 psi. Final mud properties:.10 ppg, PV/YP 50/21,Gels:10 second=4, , 10 min=11,30 min=16.Initial PU wt . - .123k,SO wt 95k.After circulating,PU wt • 120k,SOwt 104k. Pre job safety meeting f/cementing while circulating. • • • i I Page 2/5 Report Printed: 1/2/2013 Security Level: AK Development aIii Daily Drilling Report (No Costs) CD3-198 •c>mecsalaEa1[Gp4Report Number: 5 Rig: DOYON 141 • Report Date: 3/15/2011 • tiiiigcdevitagiassontianakirteninttlittlialehbaiitagiagtOmagaMillieStagalgig411kgAi otoripi RAoifp I-Time. irk SIMM SV,# .tart Depth End kR .z aia s; lr�.F�4 O,A L_KV Ti7n Time; (hrs) ,phase by Code AcbS1t code "P TX ,,:tiotode- T.ctrt C7ass�; IftKB mt lupi s � p < a ; 14:45 15:00 0.25 SURFAC CEMENT CIRC P 2;618.0 2,618.0 Pump 90 bbls 10 ppg mud w/nut plug • marker(7.5 ppb)@ 7 bpm w/450 psi. • • Next pumped'24 bbls of 8.34 ppg Biozan • • • preflush w/nut plug marker(5.7 ppb)@ • • 7 bpm w/450 psi:Reciprocated 15'to 20'.PU wt 123k,SO wt 95k. 15:00 17:15 2.25 SURFAC CEMENT CMNT P 2,618.0 2,618.0 Dowell pump 5 bbls of water and pressure test lines to 3500 psi,good. • Bleed off pressure and drop bottom plug. ✓ Mix and pump 40 bbls of Mud Push II spacer(10.9 ppg),pump @ 4.5 bpm w/ 400 psi.Mix and pump 276 bbls(755 sx) Lite Crete cement(11 ppg,2.05 cuft/sx, 7.344 gal/sx water), pump @ 4.8 bprn w/ • • final 644 psi.Mix and pump 49 bbls(238 sx)Alpine tail cement(15.8 ppg, 1.16 • - cuft/sx,5.105-galisx),pump @ 4.5 bpm w/640 psi.Shut down and drop top plug. • • 17:15 18:00 0.75 SURFAC CEMENT DISP P 2,618.0 2,618.0 Dowell kick out plug w/20 bbls of water, pump @ 5 bpm w/55 psi. Rig displace cement with mud pump#2 and 10 ppg mud.Pump @ 7 bpm w/initial circulating pressure of 300 psi.After pumping 170 - bbls,slowed rate to 3 bpm w/600 psi.. • Bump plug at 1727 strokes,pressure to 1400 psi.Hold 5 miri.Bled off pressure to check floats.Floats are holding.CIP @ 1752 hrs 3/15/2011. Note:Reciprocated until 500 strokes into mud displacement.Landed hanger on landing ring 9.5 bbls before good • cement returns to surface. Final SO wt 95k.Circulated 114 bbls of good 11 ppg cement to surface. 18:00 18:15 0:25 SURFAC CEMENT SFTY P 2,618.0 2,618.0.Pre job safety meeting on rigging down cementing equipment. 18:15 21:00 2.75 SURFAC CEMENT RURD P _ 2,618.0 - 0.0 Blow down cemeting lines.Rig down Dowell cement head,rig down hoses. Back out and lay down FMC landing joint. Rig down casing tools.Clear floor of casing tools and cementing • equipment. • 21:00 21:15 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on nipple down. 21:15 22:15 1.00 SURFAC WHDBOP NUND P 0.0 0.0 Nipple down riser and FMC adapter/starter head.Flush annular • element of cement.Clear area in the line • of sight to align wellhead to the mark on the VSM.Pepare hanger f/wellhead • installation. • • • • • • • • • • • • Page 3/5 Report Printed: 1/2/2013 Security Level: AK Development Daily Drilling Report (No Costs) ar =1 CD3-198 Report Number: 5 Co ocot'ftlllFp� .Rig: DOYON 141 Report Date: 3/15/2011 $tari End= Dui 4-.tro. i o - ,'`�"-;�c s.-v"r 9 moot oe w Depttot6it_ Depth o Time Time: (hrsj.; .Phases :Op Code .A 6.1f Cod J-alu TrbFCgd-e TEfit.-ctas5 r;;)loom 22:15 00:00 1.75 SURFAC WHDBOP NUND P - 0.0 0.0 Nipple up FMC Gen II wellhead:Tighten lockdown screws to 450 ft lbs of torque. Aligned wellhead outlet with scribe line on the VSM.Test the metal to metal seals to 1000 psi f/10 minutes.Witness of test by rig supervisor.Obtain RKB to. lockdown screw measurements.Rig floor to upper LD screws 21.53',lower LDS . 24.57',top of starting head 27.87'. Mud Check Data ;. :".: y. # ,y � Densitytkemp Solids,Corr:, AokiType Depth;(ftKB) D'ens(Ibt a(S._Js sfgt), Pt7Calc EcpJ (Ibf/100R) (lbf1.100ft) (Ibfifjpcm)'; (Ibf/100ft) MBT:(Ib/bbl (mtl30mm} pH" (F)'� -`{"h).,..,. SPUD MUD 2,630.0 10.00 57.0 100.0 110.000 30.0 . 8.7 75.0 SPUD MUD 2,630.0 10.00 8.0 26.0 29.000 32.0 8.6 61.0 • 7 ' `` .x:.. .zr mss x..rc; i s.-:x .� �3V. s . € I t. .V rrectton.Flutd� ,.. � .�x�'. ,�r� ��r,�k.-� ''„ .:,�«_ ?-�k a ;'� .;�� ..�rf3"s.`,%'�"u.. ��..v.s�-:<.b €'.�€,_ s- � � "" '�'�. Ktmource,.�Fi Erom Lease(bbl).)_ Dessnatron . C. Vendor 3 ::. ,�, ,,MenfestNumberoe_ ., 'Note ,4. x :. Cementing Fluids CD3-S198 290.0 CD3-124 AES 348802 Cementing Fluids CD3-198 275.0 CD3-124 AES 348804 Cuttings . CD3-198 10.0 CD3-124 AES 348898 Cuttings CD3-198 10.0 CD3-124 AES 348899 •Drilling Mud WBM CD3-198 290.0 CD3-124 AES 348897 Drilling Mud WBM CD3-198 290.0 CD3-124 AES 348803 Drilling Mud WBM CD3-198 275.0 CD3-124 AES 348801 Drilling Mud WBM . CD3-198 225.0 CD3-124 AES 348900 Wellbore Name Wellbore API/UWI • CD3-198 501032063700 .Section ?Size(rn) .' x..fir ,Km ActTop:(ftKB) . _ :Act Btm(ftKBjd # L.,).'tt `::Start Date'. 5 .,, CONDI 18 0.0` 108.0 3/12/2011 SURFAC 12 1/4 108.0 2,630.0 3/12/2011 3/14/2011 INTRM1 8 3/4 2,630.0 8,738.0 3/17/2011 _ 3/30/2011 PROD1 6 1/8 8,738.0 13,228.0 3/30/2011 • Page 4/5 Report Printed: 1/2/2013 • Security Level: AK Development Daily Drilling Report (No Costs) L" t f CD3-198 anocQPhillips :._r, Report Number: 5 CRig: DOYON 141 Report Date: 3/15/2011 Casing Strings String OD String Wt Casing Description Run Date (in) (lbs/ft) String Grade Set Depth(ftKB) Comment SURFACE 3/15/2011 9 5/8 40.00 L-80 2,618.7 Pre job safety meeting on running 9-5/8"40 ppf L-80 BTC-m and 36 ppf J-55 BTC casing. Run 9-5/8"casing:MU 9-5/8"casing shoe track as per detail: Rays Oil tool float shoe joint,thread lock joint, HES Sure Seal II float collar joint.All Baker Locked.Circulate through float equipment using Frank's fillup tool w/9-5/8"shoe above conductor shoe @ 108'. Circulate 3 bpm-150 psi-40%Totco flow,4 bpm-20 psi-46%Totco flow,5 bpm-250 psi-48%Totco flow and 6 bpm-300 psi-49%Totco flow. Continue running casing to 1422'(JT#34 in the hole). Baker locked the 4th jt pin end. MU torque 10,000 ft lbs f/40 ppf L-80 and 8000 f/36 ppf J-55.The first 3 jts were 40 ppf L-80,#4-#28 were 36 ppf J-55.All pipe after jt#28 was 40 ppf L-80. Installed centralizers per plan: 10'above shoe over a stop ring,collar of jt#1, 10'below box of jt#2 over a stop ring. Every collar to jt#13,then every odd joint to jt#61. Used Run-N-Seal dope on the threads.Circulate 200 bbls(surf-surf), reciprocate f/1422'to 1465'(JT#35 in the hole). Initial PU wt 90K SO wt 61k.After circulating PU wt 85k,SO wt 75k.Step rate up f/3.5 bpm w/300 psi. After pumping 70 bbls, increase to 4 bpm w/250 psi.After pumping 90 bbls,increase rate to 5 bpm w/300 psi.After pumping 120 bbls, increase rate to 6 bpm w/400 psi. Pumped a total of 200 bbls. Continue to run 9-5/8"casing f/1465'to 2468'(jt# 60 in the hole).Circulate 68 bbls on jt#60 during crew change. Reciprocate f/2475'to 2505'. Pumping 3 bpm w/300 psi. PU wt 127k,SO wt 94k. Calculated displacement to 2468'was 29.9 bbls, actual was 20 bbls.Continue to run 9-5/8" casing f/2505'to 2585'(jt#62 in the hole). Make up FMC hanger and landing joint. Run in the hole to 2618.68'. SO wt 93k. Rig down Frank's fillup tool. Blow down the top drive. Cement Surface Casing Cement-Started @ 3/15/2011 Type Wellbore Cemented String Cement Evaluation Results casing CD3-198 SURFACE,2,618.7ftKB Stg No. Description Top(ftKB) Bottom(ftKB) Q(end)(bbl/... P(final)(psi) 1 Surface Casing Cement 27.9 2,630.0 3 600.0 Fluid Class Amount(sacks) V(bbl) Density(lb/gal) Yield(ft'/sack) Est Top(ftKB) - Est Btm(ftKB) Mud w/nut plug 90.0 10.00 Biozan Pre Flush 24.0 8.34 Mud Push 40.0 10.90 AS Lite-Lead 755 276.0 11.00 2.05 26.5 2,016.4 0-Tail G 238 49.0 15.80 1.16 2,016.4 2,673.0 Page 5/5 Report Printed: 1/2/2013 k 1 r 14) v) 4) C. .D CD 4) CD U) ca CD CD U) CD CD v) U) CD CD , OD OD CO CO ,- CD N 1.40N v- CD 00 h., 40 C') N O4 ',- 0 C., 'a- c, o CD CD6 C) CD 0) 0) 0) 01 a) co co 00 co co co so co co 06 -Ne . 0 a) ta 4 .. c _ -,...• -,.....- .,.... v..• •,...- ..,..... .,...• 0 • -.J-7, co c ._ 4= CD 41 CD CD CD CD CD CD C3 CD 0 CD CD CD CD CD CD CD CD CD CD CD - E 0 1:3 N ._ cv ce E - -• U) a c) c\i tr) c) tr) c) in o in c) 10 0 Lo c) Lo c) L.0 c) 1.1" c) L.r) c) > —-..--- F) E a. ;?' 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Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 Top'iof String orTop. f Flange RCB to Casing Flange (Load shoulder.75 below LLDS')) (LCDs 24.57 ) 24.57 affiil :::..::::: :.:.,;: FMC 7" Mandrel hanger to the lower lock down screws 1.00 24.57 7", 26#, L-80, BTC-m Casing Pup jt Pin x Pin 2.23 25.57 Jts 89 to 213 125 Jts 7 ", 26#, L-80, BTC-m Casing 5095.08 27.80 HES 7" Stage Collar 2.42 5122.88 Jts 4 to 88 85 Jts 7", 26#, L-80, BTC-m Casing 3475.12 5125.30 HES Shut-off Baffle Collar 1.04 8600.42 Jts 3 to 3 1 Jts 7", 26#, L-80, BTC-m Casing 41.27 8601.46 HES Sure Seal II Float Collar w/By-Pass Baffle Adapter 1.01 8642.73 Jts 1 to 2 2 Jts 7", 26#, L-80, BTC-m Casing 82.79 8643.74 Ray Oil Tools " Silver Bullet" Float Shoe 2.16 8726.53 Bottom of shoe >>> 8728.69 8-3/4" Hole TD © 8738.00' MD/ 7005' TVD, Hole angle 83° 8728.69 7" Shoe © 8728.69' MD/ 7003.83' TVD/ Hole angle 83° 8728.69 8728.69 Qannik © 4563' MD (4083' TVD) 8728.69 8728.69 8728.69 Total of 114 Hydraform centralizers (7" x 8-1/2") 8728.69 1 Hydroform w/ stop 10' above shoe - Jt. #1 8728.69 1 HydrOform w/ stop ring 10' below Float Collar Jt. #2 8728.69 1 Hydroform w/ stop collar 10' below Baffle Adaptor- Jt. #3 8728.69 Hydraform centralizer 1 per jt on jts # 4-4114 floating 8728.69 8728.69 1 Rigid straight blade centralizer on 3 jts Across 9-5/8" Shoe jts # 149-151 8728.69 1 Rigid straight blade centralier every other from jt# 153 to # 163 8728.69 8728.69 Planned: 220 jts in pipe shed /213 jts to run. 9 jts on location. 8728.69 7 joints left in the shed = 16 jts left over 8728.69 8728.69 8728.69 8728.69 8728.69 8728.69 8728.69 Remarks: Top 2000 ft of 7" run slick to reduce BSM effect and increase maximum allowable pull Drifted w/6.151" plastic rabbit Up Wt 215 K Average MU torque=7800 Ft lbs Dn Wt 150 K Used Run-N-Seal dope Block Wt 35 K Supervisors:Fred Herbert/Mark Brouillet "4 • Y A j„ 6 t 0 1 r Cement Detail Report :g i ' `°' CD3-198 el,, ..rte 1 ConnocoPhillips 1 String: Intermediate Casing Cement Job: DRILLING ORIGINAL,3/11/2011 15:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 3/26/2011 11:15 3/26/2011 17:30 CD3-198 Comment Cement Stages Stage#1 Description Objective Top(ftKB) Bottom(ftKB) Full Return? Cmnt Rtrn(... Top Plug? Btm Plug? Intermediate Casing Cement 500'above and 6,835.0 8,738.0 No 0.0 Yes Yes Cement Below Qannik Q(start)(bbl/min) Q(end)(bbl/min) Q(avg)(bbl/min) P(final)(psi) P(bump)(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 370.0 1,967.0 No No Depth tagged(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 8,598.0 Drill Bit 8,758.0 6 1/8 Comment Cement per program, Pump 5 bbl's water pressure test cement lines to 3,500 psi. Drop top plug and load bottom plug. Pump 30.2 bbl's CW100, Pump 30.4 bbl's mudpush, Batch and pump 55.9 bbl's 15.8 ppg type"G"tail cement at 4.4 bpm. Chase with 5 bbl's water.Turn over to rig for displacement. Displace cement at 5 bpm-350 psi slow rate to 3 bpm prior to bumping plug. Bump plug at 3,050 strokes. Pressure up to 1,200 psi. Pressure held 5 minutes and recorded on chart.Bleed off pressure and check floats. Floats good verified by rig supervisor. Load plug into cement head. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 6,686.0 8,738.0 260 G 31.4 Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 1.16 5.08 15.80 107.0 6.37 Additives Additive Type Concentration Conc Unit label Retarder B155 0.11 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Stage#2 Description Objective Top(ftKB) Bottom(ftKB) Full Return? Cmnt Rtrn(... Top Plug? Btm Plug? Intermediate Casing Cement from TD to Top 3,581.0 5,124.6 No 0.0 Yes No Cement Kup C Q(start)(bbl/min) Q(end)(bbl/min) Q(avg)(bbl/min) P(final)(psi) P(bump)(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 4 4 452.0 1,235.0 Yes 8.00 No Depth tagged(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 5,122.0 Drill Bit 8,547.0 6 1/8 Comment Pump 2nd stage cement job per program. Pump 30 bbl's CW100, Pump 29.6 bbl's Mudpush, Batch and pump 42.1 bbl's 15.8 ppg type"G"tail cement at 5 bpm rate.Shut down Drop top plug chase with 20 bbl's water.Turn over to rig for displacement. Displace cement at 5 bpm and bump plug at 1,735 strokes. Increase pressure to 1,600 psi to close stage collar, Increase pressure to 1,950 psi for 5 minutes. Bleed off pressure verify stage collar closed.Witnessed by rig supervisor. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 3,581.0 5,122.0 200 G 23.4 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 1.16 5.08 15.80 107.0 6.37 Additives Additive Type Concentration Conc Unit label Retarder B155 0.11 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Page 1/1 Report Printed: 1/2/2013 • . , C Security Level: AK Development - • ,. 1 , " Daily Drilling Report (No Costs) ►ate t , - ►.6 ' �a �5 CD3-198 • • Report Number:••16 • • Conoco°hillips, � - • Rig: DOYON 141 Report Date:, 3/26/2011 Wellbore Well Type .• Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD3-198 . 'Development FIORD NECHELIK 14. 9 16.0 • 0.00 8,738.0 .• 8,738.0 Actual Start Date Original Spud Date - AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 3/11/2011 3/12/2011 • . 25.49 • 26.43 -0.93 4/7/2011 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) INTERMEDIATE,8,728.7ftKB Ops and Depth @ Morning Report 24hr Forecast Laying down 5"Drillpipe from derrick Pick up dumb iron drill out assembly Last 24hr Summary .. Ran casing to bottom,Circulated and conditioned.Perfromed 1st stage cement job.Opened stage collar,Circulated and conditioned dropping mud weight from 11.0 ppg to 10.5 ppg.Performed 2nd stage cement job.Rigged down from cement job.Set and tested packoff.Changed top pipe.rams,Saver sub,grabber and bell guide. General Remarks Weather Head Count No Incidents, No Accidents. Rig and Camp on Hi-line.• -1°Wind Southeast @ 3 MPH,No windchill _ '48.0 n'i`t:=z INIK .. ;;;Stiperyisor _::°" `�°O`z _ a _ :,,M i "` - sst.P. '. ��` ---.*be'fjtWA; "5t-M., ','.s_O tVOR_MV Fred Herbert,Rig Supervisor Rig Supervisor Mark Brouillet, Rig Supervisor Rig Supervisor Ryan Robertson, Drilling Engineer • Drilling Engineer 'd x End.--` Dur: .s _ re FAism Y o z� 6.gtyth sot polo Ends ise �, tm„ Time_ �' tis ` s �� 3 x n e , (rfo hase „.x oa< od ` sgwoode .,. P iini#7 0600 , mairClass:i .(1006 ftliBj ._�. Peration 6v v6 m 00:00 03:15 3.25 INTRM1. CASING RNCS P 4,978.0 7,232.0 Run 7"casing per detail F/4,978'MD- T/7,232'MD.Obtain pick up and slack • off weights every 10 joints.Good displacement with np hole problems . encountered. :03:15 04:30 1.25 INTRM1 CASING CIRC P 7,232.0 7,232.0 Circulate @ 7,232'MD Stage pumps up slowly to 3 bpm,Step pumps up in 1/2 bbl increments to final circulating rate @ • 5 bpm-570 psi.Circulated bottoms up with mud weight coming back 11.2 ppg. Continued circulating until mud • properties to spec and mud weight 11.0 ppg in and out.Very minimal cuttings • • . seen at shakers. 04:30 06:45 2.25 INTRM1 CASING RNCS P 7,232.0 8,700.0 Run casing per detail F/7,232'MD- . T/8,700'MD.Capture up and down weight every 1.0 joints.No visible hole • problems. 06:45 07:00 0.25 INTRMI CASING RNCS P 8,700.0 8,728.0 Pick up hanger and landing joint. Land casing on hanger. 07:00 07:45 0.75 INTRM1 CEMENT RURD P • 8,728.0 8,728.0 Blow down topdrive,Lay down Franks fill up tool.Make up cement head. 07:45 11:15 3.50 INTRM1 CEMENT CIRC P 8,728.0 8,728.0 Break Circulation stage pump up to 5 . bpm-700 psi.Circulate and condition mud for cement job.final circulating • pressure at 5 bpm-500 psi. ' • • t Latest BOP Test Data • • • .:Date : axe �„ w, ,: ,.... s. �,.:?...:din sry ., .�.....�., Comment,;.. -z a s akm - ' 3/16/2011 Witness of test waived by AOGCC inspector Jeff Jones. • Page 1/3 • Report Printed: 1/2/2013 �, � Security Level: AK Development `� • Daily Drilling Report (No Costs) mow ..rte CD3-198 • W; % • Report Number: 16 csaPutrg • • " ` Report Date: 3/26/2011 • Rig: DOYON 141 Tune Log Starf End Dur Time l Depth Start Depth End ,,x ,.. ` s Tina 'Gme, (hrst?,_ _ phase Op Code , Activity Code PTX T bl Gode TrbI Class, _? �ft l... �RKB) q� ;Operet on " 11:15 13:30 2.25 INTRMI CEMENT CMNT P 8,728.0 8,728.0 Cement per program,Pump 5 bbl's water pressure test cement lines to 3,500 psi. Drop top plug andload bottom plug. • Pump 30.2 bbl's CW100,Pump 30.4 bbl's mudpush,Batch and pump 55.9 bbl's 15.8 ppg type"G"tail cement at 4.4 bpm.Chase with 5.bbl's water.Turn over to rig for displacement.Displace cement at 5 bpm-350 psi slow rate to 3 bpm, prior to bumping plug. Bump plug at 3,050 strokes.Pressure up to 1,200 psi. Pressure held 5 minutes and recorded on chart.Bleed off pressure and check • floats. Floats good verified by rig supervisor.Load plug into cement head. tv Top of cement calculated=6,835'MD. • 13:30 16:00 2.50 INTRMI CEMENT CIRC P 8,728.0 .8,728.0 Circulate down casing increase pressure to 3,350 psi to open stage collar. Circulate and condition mud reducing • mud weight from 11.0 ppg to 10.5 ppg for 2nd stage cement job. 16:00 17:30 1.50 INTRM1 CEMENT CMNT P 8,728.0 8,728.0 Pump 2nd stage cement job per program. Pump 30 bbl's CW100,Pump . 29.6.bbl's Mudpush,Batch and pump - 42.1 bbl's 15.8 ppg type"G"tail cement at 5 bpm rate.Shut down Drop top plug • chase with 20 bbl's water.Turn over to rig for displacement.Displace cement at 5 bpm and bump plug at 1,735 strokes. Increase pressure to 1,600 psi to close stage collar, Increase pressure to 1,950 psi for 5 minutes.Bleed off pressure verify stage collar closed.Witnessed by . rig supervisor. 17:30 19:30 2.00 INTRMI CEMENT RURD P 0.0 0.0 Rig down cement head and casing • - • equipment.Clear and clean rig floor 19:30 20:30 1.00 INTRM1 WHDBOP NUND P 0.0 0.0 Pull casing running wear bushing. Set . and test.7"packoff to 5,000 psi for 10 minutes.(Test verified and witnessed by • . rig supervisor) 20:30 21:00 0.50 INTRM1 WHDBOP SFTY P 0.0 0.0 Held Safety stand up with rig crew and service personnel.Complimented crews . on working safely.(Discussed paying close attention to all details breaking down tasks examining possible hazards and mitigating out)" • 21:00 00:00 3.00 INTRMI WHDBOP NUND P 0.0 0.0 Change upper pipe rams F/7"-T/3-1/2" X 6"Variables,Sim-ops change out • saver sub,Grabbers and bell guide- Stage BHA components in pipe shed. • �? �"F. 4�' X A bet^ T; � ie ...,y e� ry�,'a.`+�xY£ a�"S" iRe'� .g;N ^.- ,y " .n =`.sth.Ktat ce ..atk. ' .'�33. `''�e�s a.A�'��$Q 4F. AT #.+" lVtud check.Data�:� �~.��.�,.� • j ._ ",,GeF{3Qm) . �, �..Desslry'Temp+ :otids Corr_ Si -: t aitm tI .` s WO 00ft t mL 30[rn _ '` : . Ype� m,.DegtttFt[GCB)� bens€Ib/ga�'�i3�{sT4t��2Y;Calc(cP): ) �bf{1nllf2�� pbf/100H:j +�IbfLtOOtt:)�._MBTjIb bb`lj_::f_,,,.��pH`�.-= "��.":>>�E�;s '�'��' GLYDRIL 8,738.0 10.50 38 9.0 15.0 4.0 5.0 5.000 11.2 6:0 9.2 76.0 LSND• • ' • • • • • Page 2/3 • Report Printed: 1/2/2013 , Security Level: AK Development Daily Drilling Report (No Costs) .4 CD3-198 comocvPhllt� C Report Number: 16 Rig: DOYON 141 Report Date: 3/26/2011 Mud Check Data YP Calc Gel(10s)" Gel(10m) Gel(30m) - HTHP Flit- Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cp) (Ibf/100ft') .(Ibf/100ft') (Ibf/100ft') (Ibf/100ft') MBT(Ib/bbl) (mLl30min) pH -(CF) (%) GLYDRIL 8,738.0 11.00 41 12.0 19.0 8.0 9.0 10.000 15.0 6.0 9.3 82.0 LSND Injection Fluid Fluid Source From Lease(bbl) Destination Vendor - Manifest Number Note Cement Rinsate CD3-198 150.0 CD1-19 AES • 340663 Cuttings CD3-198 10.0 CD3-124 AES 340659 Drilling Mud WBM CD3-198 290.0 CD1-19 AES 340660 Drilling Mud WBM CD3-198 285.0 CD1-19 AES 340667 Drilling Mud WBM CD3-198 285.0 CD1-19 AES 340666 Drilling Mud WBM CD3-198 280.0 CD1-19 AES 340661 Drilling Mud WBM CD3-198 280.0 CD1-19 AES 340658 Drilling Mud WBM CD3-198 280.0 CD1-19 AES 340662 Well bores Wellbore Name Wellbore API/UWI CD3-198 501032063700 Section Size(in) - Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 18 0.0 108.0 3/12/2011 SURFAC 12 1/4 108.0 • 2,630.0 3/12/2011 3/14/2011 INTRM1 8 3/4 2,630.0 8,738.0 3/17/2011 3/30/2011 PROD1 61/8 8,738.0 13,228.0 3/30/2011 Casing Strings String OD String Wt Casing Description - - Run Date (in) (lbs/ft) String Grade Set Depth(ftKB) Comment INTERMEDIATE 3/26/2011 7 26.00 L-80 8,728.7 Cement Intermediate Casing Cement-Started @ 3/26/2011 Type Wellbore Cemented String Cement Evaluation Results casing CD3-198 INTERMEDIATE,8,728.7ftKB Stg No. Description Top(ftKB) Bottom(ftKB) Q(end)(bbl/... P(final)(psi) 1 Intermediate Casing Cement 6,835.0 8,738.0 5 370.0 Fluid Class Amount(sacks) V(bbl) Density(Ib/gal) Yield(ft'/sack) Est Top(ftKB) Est Btm(ftKB) Tail Cement G 260 31.4 15.80 1.16 6,686.0 8,738.0 Stg No. Description Top(ftKB) Bottom(ftKB) Q(end)(bbl/... P(final)(psi) 2 Intermediate Casing Cement 3,581.0 5,124.6 4 452.0 i. Fluid Class Amount(sacks) V(bbl) Density(lb/gal) Yield(ft'/sack) Est Top(ftKB) ;'Est Btm(ftKB) Tail Cement G 200 23.4 15.80 1.16 3,581.0 5,122.0 `Leak Off and Formation Integrity Tests Leak : Dens Fluid LO Eq.Fluid Den off? Last Casing String Run Depth(ftKB) (lb/gal) Fluid -.P(Surf)(psi) (lb/gal) P(LO)(psi) Yes INTERMEDIATE,8,728.7ftKB 3,581.0 10.50 WBM 773.0 15.03 2,566.3 Page 3/3 Report Printed: 1/2/2013 N m OO� C C Ua) N .O O LL O C N a. 1 X X o 0 n N W E To 135 E o a m O DCa a m m m rn a)E. m o O w 0 CU = ❑ ° 0 m d a m a) a) a) 0000 c N N a Or N N > N N N y C U C U U O U U U U — mc -o t C m ad tm tm - m m m m o m t t t t o y v 0Y ' lo w =On 'O 0 0 0 0)-o U o U N i3 03 O >12C O N O X O O m O O O O CO t m C W J - Q t6 W J J 0 J J J J 0 (n 0 O 0 m co ,- co O co)N.- 0) 0)1---0 0 0 0 0 0 0 0 0 0 0 0 0 0 tT r co N CO O CO CO N c0 N I--m IN. 30 m` O. co (o 4 v 6n- ui C()v n- ui n-ui ▪ LL - r r V c'i N V cci V 7 Iri d'CO 10.-s-oa G 1 ao ❑ V O) 01 0 0) O �LC)CO CO CO m N r c0 N to m N m N 10 r C)CO CU CO4 C1 CO - m N 0 r m0) r mm1.rr-I-I.--N CO CON-t0 t0 c0 c0 c0 LO v a s v v V LO V a v v V v V V V V V V V V V V V V V V ''S _N N N N N N N CO N N CO N N N N N N N N CO N N CO N N N N CV C N U F — O r to 0 N 0 O a N 0 0(D 0 000)00 C)r,O 10 0).--m Q)O °-r m m N m W m m CO c0 m m CO m cD m c0 r 00 c0 co C)CO c0 m m r r J .- s 0 C f N V N r co m m 0) '-m 6 0 O CO 0 0 M 0 C0 m o r C)V CO 10 CO C)C)CO Ol m O CO O N Cl) 0 O m 6 000 m CO 0)O N 0)6 m m N N r N 6 V O N O m m N m V CO O m V O N LU U1 O N m m N r C)V V r 0 V C) U O a7 r r r CO CO to 0)N LL') 0I 0 V )0 N C)V 01 CO m 0 6 co m r CO y 0 ' V V V V V to V1 C)10 C) C)C0 C)C)Ch C],Cr V'7 V CO Cl C)V V C0 CO N O 0 0 0 " 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 p >-' O' 0 O 0 0 0 0 0 O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 t 0 CO 0 CO CO 0 CO CO 0 CO CO O COCOCO 0( CO 0 CD CO CO 0(0 0 0 0 CD 0 0 0 5 0 N m C) co I- co. m m V r r I- N O ccO V O a V 6 CO co N N O 6 co co m IN CO 8 00 O N 4 m r C0 CO Ni CO 6 a Non r C0 m N O r r O(O c0 CO NI- O X ,i O m N -co N CO N V CO m C0 V N CO r V CO CO CO r r CO r 0 N 0 C) m C0 0 V 0 m m 0 C0 m 0 V CO r V V V N m 0 0)0 C0 CO r CO C) O O' CO CO r r 0 CO Nr-00 m 0 000 0 0 0 m N N O.m(O C°0 N 0 0 0 N o m m m CO MOO 0 m m m m 0)m 0>m O)m m m m m N m m m m m m 0) CO C) C)CO C) CO CO C) CO CO CO CO CO CO CO CO CO CO CO C)CO CO CO CO CO CO 0 CO CO C) (n 0 ` k N 0 V . m CW - r O m m Vm V O CNmCV0 in m V mO V V -O N fN O O co r O N ‘-r-C33 O O N N 00 N N`•-7 O.N 0 N r N N N o o .r0 O CO O O O O O N- M w „ o o o 0 o O O o 0 0 O TO N N N N N N N N,t(7 N r >„V O V O (O •` O (O N N N Z.7. 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L: 4-3 -i,"-) _ u> . ‘.., 4.) oo ,_ .I .— ..,=, a3 i— ...., 0 -'= — .U) I"' = 0) ' a) R 0 ....I iii 31 — c as t-, u) SSaeld E :— a) wOin :1f1E 6 0 c) x III c.) ,,,,,, - • • TOM and Shannbn, . .You have • . , requeSted tp dispose of "new-product° clern bp fluids from:the. routine. mixincl Of .retud and cement•at Alpine as well ac the clean up fluids resulting frOm • cicaning out the tanksat the mud lant in preparation for using .oil base mud, • The Commission had preViouSly aPPrOved dispoSing Of the 'new productcleat up • • fluidS via annular dispOSal at CD 1 pad. Due: to the geological setting at Alpine, Class 1 and Class 2 disposal options are: . • • predeCessor, P....RC& had established the limitation of 4P.P.PpOl. optibnato the Cot Satis!.faCtion and_annblardiSbasalwas'apProved as - • the prat:deal and environmental alternative. In these requests the waste fluids are no dit:terent thanpreviously approved and. . _ . are the result of the ongoing deVelobMent actiVities at Alpine. • The COmMisSioners have authoriZed Inc to send you. this meethage, By copy of this • email, Phillips is authorized to dispose of "clean up fluids -as described in • your email. Please call with any questIons. Tom Maunder, PE Sr. Petroleum Engineer • AOGCC ALP 'EnV Coord wrote; • :,. Dear Mr, kaundex, • > As noted in the -attached email, Tom Manson previously requested > authorization tc .diSposeyDf new-product clean uo fluids such. as cement > rinsate, and mud.. .and:brine pit rinseS EroMmiXing operations via annular . > injection in perittsells at the Apin CD2 Drill site. AS rioted below, > AOGCC anpreved such disposal at the Drill Site in. 1999, based on the • integral relationship of the mud mixing facility and the on-site drilling > operation. Phillips would like to Continuing Pursbing this request. Signifidant olon • out of tanks at 1-1' mud mxing facility Must OcCutHih.preparationfor th'01. temporary use of, oil lased mud products at Alpine in the- coming months'. > The availability of annular disposal as- an option for tankrinse fluids and > similar wastes would grcatlyfacilitate this process. (Typically, routine • rinses are beneficially, reUsed however, there is a concern about the potential qbantUy of fluid that 'cbuld. begendrated during this large sCale • clean up process. ) > tanks tt the mud mixing facility may-contain either new and used mud > products. Though rinsea in contact with used products may be injected in the permitted class Ji disposal well (C1519A) , rinees ,Of new products would > potentially be r.opt.dd. to the. olas*. I. dispoSal: well (T4D-..02 , where there is > a:diffiCultymanaging solids COntent. The' class I Well is a critical . . . > lifeline for facility iliftotructtre, being the. disposal location or all > doMeStic effluent;,: and it is a priority' tOprevent any compromise to this > diSposal facility. Annular disposal presents a preferred waste management > alternative in this- Case. • • • ( Thank you very much for your aanaide'ratiori of this,request. Please do not • > hesitate to contact sin or ray' a1Le nate Viaemail or shone at (907) 670-4200 > if you have questions or need ecldi.tional information. > Soanr_cn Donnelly ! ' > alpine Field• EiiVironmental Coordinator • (907) 670- 1200 Forwarded by' ALP Env Coord/PPLO on. 11/02/01 •.1250 PM! ----- • ---- > ALP Env Cotard 08/3l/O1 12:45 PM TO: . L'c7., r��under�zc9mi:n.,�t�t;�,ak.ua GC: • Subject: RectueSt to ]_niece Cement Ri.neace at CD2 • > D'car Mr Maunder,. > injection of ceMent rinsate eu d .c(ean-til? fluids frtmt mud and brine mixing operations •al' me Alpine' mud plant facility into approved annular disposal > operations was g anted by. the Alaska 011 And Gan Conservation Commission • > (AOGCC). in the March l7,• 1999 letter from AOGCC to.Doug ''Chester oi; ARCA > Al.aaka, Ino., now Phillipa Alaska, MG.. {PA,1) . ,The approval was granted. to • PAI specifically• •for ;lpj,ne Drill •Sit CDl and tiuthorized'irolumes up to . > 35,000 barrels through the annular' space. > > PAT request that this approval be.extended to drilling. operations at .Alpine. ( > Drill Site 02. Cement mixing operations; for setting surface conductors > will be taking place:at the Grind.and Inject facility which. is ctlrrehtly > attached to ;the drilling rig at .CD2', Upon corrtnJ c i,on of the cementing in • >• of the conductors, the I rnes and milting tank will have .t`ci be rinsed and the . > rinsate disposed of. PAI request approval to inject this' sins te, and other clean-up from tkae mud anal brine. mi Ang operations, into the annual • space of approved'well: locatedat Drill Site CD2. :. 2.[ yOu have arty sliest ions please contact me at G70-4200, > Tors% Manson. • > Alpine Field Environmental Compliance • tom_17tauneler.vai CD3-119 Annular Disposal Details CD3-119 surface casing Well: 003-119 =314 45.5-. -Pin: P. - > =a-__rr, Date: 31212012 Conor liIIlps Rig: °opt-3n 19 Al ki;lnc Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 RKB to Landing Ring 36.53°,,1.11114111111111111111111 FMC 10 3/4" Casing Hanger .22 36.53 10 3/4", 45.5 #, L-80, BTC Casing Pup jt- P x P 2.19 36.75 Jts 69 to 86 18 Jts 10 3/4", 45.5#, L-80, BTCM Casing 751.81 38.94 10 3/4" Tam Port Collar 2.91 790.75 Jts 3 to 68 66 Jts 10 3/4", 45.5 #, L-80, BTCM Casing 2780.93 793.66 10 3/4" Hallibutron Super Seal Float Collar lit, 1.20 3574.59 Jts 1 to 2 2 Jts 10 3/4", 45.5 #, L-80, BTCM Casing72.31 3575.79 10 3/4" Ray Oil Tools Float Shoe(Silver Bul _1 ; ; ',: ;::: 2.25 3648.10 3650.35 10 3/4" Casing shoe @ 3650.35' MD /2483' TVD 3650.35 13 1/2" hole TD. 3661' MD 12488' TVD 3650.35 10.65' of 13-1/2" Rat hole 3650.35 3650.35 3650.35 RAN 49 BOWSPRING CENTRALIZERS - CPAI Part# 11445737 3650.35 1 per jt on Jt#1 - #13 (stop ring on Jt#1 & 2 ) 3650.35 1 perjtonJt#15 - #16 3650.35 Every other jt from jts #18 thru #68 3650.35 Every other jt from jts #69 thru #83 3650.35 1 Hydroform w/ stop ring under on Jt. #85 10' up. 3650.35 Centralizer on Jt#68 on stop ring 10' down. 3650.35 3650.35 3650.35 Leave 14 joints in the shed. 3650.35 3650.35 3650.35 3650.35 3650.35 3650.35 3650.35 3650.35 3650.35 3650.35 3650.35 Remarks: Drifted w/9.875"OD teflon drift Up WI 240 K Torqued to l l k Ft lbs of torque Dn Wt 125 K Used Jet Lube Run-N-Seal dope Block Wt 75 K Supervisors:Dave Burley/Granville Rizek/Ken Harding - :08 ` Cement Detail Report •.. n xis - ah CD3-119 String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/23/2012§1 6:00 Cement Details= a, '��-�:,�"._,t ��. _ _ ,. Description - Cementing Start Date • Cementing End Date Wellbore Name ' _ . Surface Casing Cement 3/2/2012 15:15 3/2/2012 18:45 • . CD3-119. Comment • Circulate and condition mud and hole for cement job.Reciprocate pipe f/3650'to 3637'(13'). Initial pump rate 7 bpm w/440 psi;23%Totco flow out.Total of 1050 bbls pumped. Final mud properties:MW 9.9 ppg,PV/YP in 20/22, 72 funnel vis.. Held PJSM f/cementing while circulating.Con't to circ&cond mud and hole for cement job. • Rig mixed&pump 121 bbls of 9.9 ppg mud w/nut plug marker(5ppb),followed w/33 bbls of viscosified biozan water w/nut plug(5ppb).Pump @ 7 bpm w/ 290 psi.PU wt 215k,SO wt 135k. Dowell pumped 3 bbls water and press test to 2500 psi.Drop bottom plug.Dowell pump 44 bbls of MudPush II(10.5 ppg). Pump 4 bpm w/final press of 175 psi.-Dowell mixed and pumped a total of 485 bbls(1111 sx)of 10.7 ppg ArcticSet Lite cement(Yield 2.45 cuft/sx)(11.53 gal/sx mix water).Avg pump rate of 7 bpm w/initial press of 280 and final of 123 psi.Dowell mixed&pumped 53.3 bbls(258 sx)of 15.8 ppg class"G" tail cement(Yield 1.16 cuft/sx)(5.1 gal/sx mix water).Avg pumping rate of 4.8 bpm w/final of 98 psi. Drop top plug.Dowell displace and wash up through.the • tub, pumping 20 bbls of water.Reciprocate pipe f/3650'to 3637'(13'). Rig displaced cement w/9.9 ppg mud. Pumping the first 310 bbls @ 8 bpm w/370-psi initial and 790 psi final,then slowed rate for the last 14 bbls to 2 bpm w/480 psi. Bumped plugs w/500 psi over-1100 psi @ 18:45 hrs 3/2/2012, held f/5 • minutes. Note:Reciprocated pipe f/3650'to 3637'(13').while.displacing cement,set on hanger 173 bbls prior to bumping plug.Had 62 bbls(142 sx)of good 10.7 ppg cement to surface.Full returns throughout job.SO wt 125k.PU wt 240k. Note:Cement in place @ 18:47 hrs 3-2-2012.Bled off pressure to check floats,floats held.PJSM,rig down cement and casing equip. Cement:Stages h } Stage#1.x:... ..._'> i. ti3 ::. `vr.Lr? s .. ofi . ., smoi. tsemmovesigiumutipx Description Objective Top(ftKB)` Bottom(ftKB) Full Return? Cmnt Rtrn(... Top Plug? Btm Plug? Surface Casing Cement Cement surface casing 36.0 . 3,661.0 Yes 62.0 • Yes Yes (start)(bbl/min) Q(end)(bbl/min)• Q(avg)(bbl/min) P(final)(psi) P(bump)(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 2 . 8 480.0 1,100.0 Yes 13.00 No Depth tagged(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 3,570.0 Drill Bit • 3,661.0 9 7/8 comment circulate and condition mud and hole for cement job.Reciprocate pipe f/3650'to 3637'(13'). Initial pump rate 7 bpm w/440 psi,23%Totco flow out.Total of 1050 bbls pumped.PV/YP in 20/22, 72 funnel vis. Held PJSM f/cementing while circulating.Con't to circ&cond mud and hole for cement job. • Rig mixed&pump 121 bbls of 9.9 ppg mud w/nut plug marker(5ppb),followed w/33 bbls of viscosified biozan water w/nut plug(5ppb).Pump @ 7 bpm w/ ' 290 psi.PU wt 215k,SO wt 135k. Dowell pumped 3 bbls water and press test to 2500 psi.Drop bottom plug.Dowell pump 44 bbls of MudPush II(10.5 ppg). • 'ump 4 bpm w/final press of 175 psi.Dowell mixed and pumped a total of 485 bbls(1111 sx)of 10.7 ppg ArcticSet Lite cement(Yield 2.45 cuft/sx)(11.53 3al/sx mix water).Avg pump rate of 7 bpm w/initial press of 280 and final of 123 psi.Dowell mixed&pumped 53.3 bbls(258 sx)of 15.8 ppg class"G" tail ;ement(Yield 1.16 cuft/sx)(5.1 gal/sx mix water).Avg pumping rate of 4.8 bpm w/final of 98 psi. Drop top plug.Dowell displace and wash up through the ub, pumping 20 bbls of water.Reciprocate pipe f/3650'to 3637'(13'). Rig displaced cement w/9.9 ppg mud.Pumping the first 310 bbls @ 8 bpm w/370 psi nitial and 790 psi final,then slowed rate for the last 14 bbls to 2 bpm w/480 psi. Bumped plugs w/500 psi over-1100 psi @ 18:45 hrs 3/2/2012, held f/5 ninutes. Note: Reciprocated pipe f/3650'to 3637'(13').while displacing cement,set on hanger 173 bbls prior to bumping plug.Had 62 bbls of good 10.7 ppg cement o surface. Full returns throughout job.SO wt 125k. PU wt 240k. Note:Cement in place @ 18:47 hrs 3-2-2012.Bled off pressure to check floats,floats held.PJSM,rig down cement and casing equip. :emerit Fluids.&:Additives ': •: i;.; � = �; ::: 'Mid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) /lud with 5 ppg 121.0 iutplug "ield (ft/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 9.90 additives ,dditive Type Concentration Conc Unit label luid luid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) liozan water with 5 • 33.0 • pb nut plug ield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) . - 8.40 i ,dditives dditive Type Concentration Conc Unit label • Page 1/2 Report Printed: 1/2/2013 Cement Detail Report ` ,`. CD3-119 Win__=jam String: Surface Casing Cement Job: DRILLING ORIGINAL,2/23/2012 16:00 Cement Fluids &Additives 1; Fluid ^ z_ r _S5 a OION` a ' , 'a Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) • Mud Push II 44.0 Yield(ff/sack) • Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid . Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) ASL cement 36.0 , 3,175.0 1,111 485.0 Yield(ft/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) . Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 2.45 11.53 10.70 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail cement 3,175.0 . -• 3,175.0 • • 258 • G with add 53.3 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) . Thickening Time(hrs) CmprStr 1(psi) • 1.16 5.10 15.80 • Additives Additive Type • Concentration• Conc Unit label S002 accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label D46 antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label • D65 dispersant 0.3 %BWOC Page 2/2 Report Printed: 1/2/2013 Security Level: AK Development Daily Drilling Report CD3-119 Report Number: 9 oacaMillip . • • Rig: DOYON 19 Report Date: 3/2/2012 AFEType.,.;:' ' NeMrorIJID# Total"AFE SuP ;::..: 10329832 16,000,000.00 Wellbore Well Type Field Name • DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD3-119 Development .• FIORD NECHELIK 5.83 9.0 0.00 ,3,661.0 3,661.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 9,095.17 124,319.25 744,197.82 3,406,431.90 ;Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 2/23/2012 2/26/2012 45.00 48.29 -3.29 4/11/2012 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE,3,650.4ftKB Ops and Depth @ Morning Report 24hr Forecast Testing 13-5/8"BOPE Nipple down, NU,test FMC wellhead to 1000 psi, NU BOPE • equipment,RU,test BOPE,R/D,PJSM,PU/Standback 5"dp f/ intermediate hole. Last 24hr Summary Finish running 10-3/4"45.5 ppf L-80 BTC-m surface casing f/1750'to 3650.35'(Circ in the hole),MU Dowell cement head,circ and condition mud, PJSM, perform surface cement job w/62 bbls of cement returned to surface(142 sx,yield 2.45 cuft/sx)(100%returns). Bumped plug,checked floats-OK,R/D cement head,UD landing joint, nipple down surface riser and adapter. General Remarks Weather Head Count No Accidents/No Spills -40°/-65°we/WSW 9 mph/Vis.5 mi 52.0 Rig and camp on hi-line power Supervisor ::z. Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor • Rig Supervisor Ken Harding, Rig Supervisor Rig Supervisor Ryan Robertson, Rig Engineer Rig Engineer • John Samuell, Drilling Engineer Drilling Engineer Time Log Stai t End.-- Dur Time Depth Start _-Depth End- Trne .Time;: (hrs.) Phase Op Code Activity Code P-T-X �Trbl Code=i. Trbl Class (ftKB)' (ftKB) _ Operation` _ 00:00 03:00 3.00 SURFAC CASING RNCS P 1,750.0 1,837.0 Working casing down while circulating at 4 bpm at 220 psi to 8 bpm at 500 psi. from 1750'to 1837'. 165K up, 120K down. 03:00 06:15 3.25 SURFAC CASING , RNCS P 1,837.0 1,963.0 Work casing down more aggressively from 1837'to 1963'while circulating at 8 bpm 500 psi. 175K up, 125K down 06:15 11:45 5.50 SURFAC CASING RNCS P 1,963.0 3,611.0 Wash casing down with 10-25K drag and work as needed from 1963'to 3611'. Reduced flow rate from 8 bpm to 6.bpm at 400 psi. 180K up, 130K down 11:45 12:45 1.00 SURFAC CASING RNCS P 3,611.0 3,650.0 MU Hanger/landing joint and land casing at 3650'.RD Franks tool,Blow down top drive,MU Cement head. 12:45 15:15 2.50 SURFAC CEMENT CIRC P 3,650.0 3,650.0 Circulate and condition mud.Staging pump rate up to 7 bpm 440 psi. 215K up, 135K down. Casing collar hanging up on conductor 2'off-bottom,stayed above this while circ and condition.Rig up Dowell cement head,connect lines. Circulate-and condition mud and hole for cement job.Reciprocate pipe f/3650'to 3637'(13').Initial pump rate 7 bpm w/ " 440 psi,23%Totco flow out.Total of 1050 bbls pumped. Final mud properties: MW 9.9 ppg, PV/YP in 20/22,.72 funnel • vis. - Held PJSM f/cementing while circulating.Con't to-circ&cond mud and hole'for cement job. Latest BOP Test Data Date Comment Page 1/3 Report Printed: 1/2/2013 Security Level: AK Development 71 T -rr Daily Drilling Report .re X13 r Ii! - zq fz CD3-119 Report Number: 9 �Piv�GI Ft • • • DOYON 19 Report Date: 3/212012 -441;;.--1','_,,„4.P:1-4' Rig: Time Log • :. Start End Dur. Time t Depth Start. Depth End --- - _ Time Time (hrs) _ Phase. Op Code Activity Code 'P T X I Trbl Trbtblass- (ftKB) (ftl E) Operation , 15:15 18:45 3.50 SURFAC CEMENT CMNT P 3,650.0 3,650.0 Rig mixed&pump 121 bbls of 9.9 ppg mud w/nut plug marker(5ppb),followed w/33 bbls of viscosified biozan water w/ nut plug(5ppb).Pump @ 7 bpm w/290 psi. PU wt 215k,SO wt 135k.Dowell pumped 3 bbls water and press test to • 2500 psi.Drop bottom plug.Dowell pump 44 bbls of MudPush II(10.5 ppg). Pump 4 bpm w/final press of 175 psi. Dowell mixed and pumped a total of 485 • bbls(1111 sx)of 10.7 ppg ArcticSet Lite cement(Yield 2.45 cufUsx)(11.53 gal/sx mix water).Avg pump rate of 7,bpm w/ initial press of 280 and final of 123 psi. Dowell mixed&pumped 53.3 bbls(258 sx)of 15.8 ppg class"G" tail cement Yield 1.16 cuft/sx)(5.1 gal/sx mix water). Avg pumping rate of 4.8 bpm w/final of 98 psi.Drop top plug. Dowell displace and wash up through the tub,pumping 20 bbls of water. Reciprocate pipe f/ 3650'to 3637'(13'). Rig displaced cement w/9.9 ppg mud. Pumping the first 310 bbls @ 8 bpm w/.370 psi initial and 790.psi final,then slowed rate for the last 14 bbls to 2 bpm w/480 psi. Bumped plugs w/500 psi over-1100 psi @ 18:45 hrs 3/2/2012, held f/5 minutes. • Note: Reciprocated pipe f/3650'to 3637'(13').while displacing cement,set on hanger 173 bbls prior to bumping plug.Had 62 bbls(142 sx)of good 10.7 ppg cement to surface. Full returns throughout job.SO wt 125k.PU wt 240k. Note:Cement in place©18:47 hrs 3-2-2012.Bled off pressure to check floats,floats held. PJSM,rig down cement and casing equip. • • 18:45 19:00 0.25 SURFAC CEMENT OTHR P 3,650.0 3,650.0 Bleed off pressure.Check floats-OK. • 19:00 21:15 2.25 SURFAC CEMENT RURD P 3,650.0 0.0 Flush riser w/black water. Blow down lines. Rig down cementing head.Lay down the 10-3/4" landing joint. 21:15 21:30 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on nippling down riser and FMC adapter. 21:30 00:00 2.50 SURFAC WHDBOP NUND P 0.0 0.0 Lay down mouse hole. Nipple down surface riser.Nipple down FMC 16" surface adapter. Mud Check Data YP Calc Gel(10s) - Gel(10m) Gel(30m) NTHP Fitt Density Temp Solids Corr Type Depth MKS) Dens(lb/gal) Vis(s/qt) PV Calc(cp).'. (Ibf/100ft'). (Ibf000ft=) .(Ibf/100?) :_ (Ibf/100ft') MBT{Ib/bbl) ;-::(mU3Omin).:,: pH ` _a(°F) CA) SPUD MUD 3,661.0 9.90 72 20.0 22.0 4.0 5.0 9.000 38.5 8.7 63.0 SPUD MUD 3,661.0 • 9.90 72 20.0 • 22.0 4.0 5.0 9.000 38.5 8.7 63.0 • • • Page 2/3 • Report Printed: 1/2/2013 Security Level: AK Development ..,...tife;;; =.7,±7 ,. • - Daily Drilling Report CD3-119 _ Report Number: 9 •:•. • Rig: DOYON 19 . Report Date: 3/2/2012 Injection Fluid E'E. - •Fluid Source: ; = - Source From Lease(bbl) -:ieDestination . Vendor Manifest NumberNote Diesel 5.0 CD3-122 2"hard line 2"hard line Water 150.0 CD3-122 2"hard line 2".hard line "•" Water Based Mud CD3-119 1962.0 CD3-122 2"hard line 2"hard line Wellbore Name Wellbore API/UWI CD3-119 . 501032065300 Sectjon Size(in) Act Top(5KB) Act Btm(ftKB) .; •Start Date .; . • End,Date 19,375.0 CONDI 16 37.0 116.0 2/26/2011 2/26/2011 SURFAC 131/2 • ., 116.0 3,661.0 2/26/2012 2/29/2012 INTRM2 9 7/8 3,700.0 • 15,258.0 3/24/2012 4/1/2012 • PROD1 6 3/4 15,258.0 19,375.0 4/9/2012 4/15/2012 daing Stringsr.•- •E.: -E EEEE -.40:giarge!ISSA, - String OD String Wtee: Casing Description String Grade Sat:Depth.(ftl<B)..".' • SURFACE 3/2/2012 10 3/4 45.50 L-80 3,650.4 PJSM. RIH with 10 3/4"45.5 ppf L-80 BTCM casing to 1330',began seeing some drag,circulate 54 bbls total at 4 bpm,220 psi. 125K up, 112K down.Continue RIH with 10 3/4"45.5 ppf L-80 E • BTCM casing to 1650',taking weight.Wash • mainly/work casing down from 1630'to 1750',with 4 bpm,220 psi increasing to 6 bpm 320 psi; 150K " up, 110K down.Working casing down while • circulating at 4 bpm at 220 psi to 8 bpm at 500 psi. from 1750'to 1837'. 165K up;120K down.Work • • - casing down more aggressively from 1837'to 1963'while circulating at 8 bpm 500 psi. 175K up, 125K down.Wash casing down with 10-25K drag and work as needed from 1963'to 3611'. Reduced • flow rate from 8 bpm to 6 bpm at 2300',400 psi. 180K up, 130K down.MU Hanger/landing joint and land casing at 3650'.RD Franks tool,Blow down top drive,MU Cement head.Circulate and condition mud.Staging pump rate up to 7 bpm 440 psi. 215K up, 135K down.Casing collar hanging up on conductor 2'off bottom,stayed above this while circ and condition. Rig up Dowell cement head,connect lines.Circulate and condition mud and hole for cement job. Reciprocate pipe f/3650' to 3637'(13'). Initial pump rate 7 bpm w/440 psi, • 23%Totco flow out.Total of 1050 bbls pumped. PV/YP in 20/22, 72 funnel vis. Held PJSM f/cementing while circulating.Con't to circ&cond mud and hole for cement job.240K • PUW, 125K SOW.Full returns throughout job. • Cement - • : EE Surface Casing Cement-Started @ 3/2/2012 Type . Wellbore Cemented String Cement Evaluation Results casing CD3-119 SURFACE, 3,650.4ftKB Stg No.. Description Top(ftKB) Bottom(ftKB) Q(end)(bbl/... P(final)(psi) 1 Surface Casing Cement" 36.0 3,661.0 2 480.0 Fluidyr, !•••:'.Amount(aecke)50 .Dene4:(Thrgel).,ii4,s(ield(fritatK): . ;:.;:r.• Eat Togi(ftKe)*.14.1.e.iii'f4ig BtrrE(ffKB)e,:f,;14, :j Mud with 5 ppg nutplug 121.0 9.90 Biozan water with 5 ppb nut plug 33.0 8.40 - Mud Push II 44.0 10.50 SL cement 1,111 485.0 . • 10.70 2.45 36.0 3,175.0 tail cement G with add 258 53.3 15.80 1.16 3,175.0 3,175.0 . Page 3/3 • - Report Printed: 1/2/2013 • • h. L . . P CD CD C) in D CD CD CD CD CD CD UD ca 1.0-0 Ul U1 4.0 It) 4.. (0 CD 1.0 N- - 0) CO P-- (0 VD NI- 04 04 7.- 7- CD C) CD 0 C.. . .1.5 CD CD 0) aD aD (0 N-. N,-. N.- P-.... N- N- N.... N- 1--.... N.- N... N.- N- N... r- r-- . 0 • E (1-ci ›, co •Ec) co c) co co c) C) co c) co c) co co CD CD CD 0 0 CD CD CD CD 1- .cC Q L . ' w c c) c\I in c:, Lo c) Lo c) io 6 up 6 in 6 In 6 in 6 in cp in cD g '). II ...-• --CA • E . . 'c 0 CD 6 Y: ,- (NI (N C') CO 4 - - 6 6 (0 6 N N.: CO CO C) C) 0 U.I 7.D .,.. 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Doyon 19 RKB to Lower lock down 3 .31 FMC Hanger (7-5/8" Pup 2.22') 3.21 34.31 Jts 164 to 358 195 Jts 7 5/8" 29.7# L-80 BTCM Casing 8289.86 37.52 Halliburton Stage Collar 2.39 8327.38 Jts 4 to 163 160 Jts 7 5/8" 29.7# L-80 BTCM Casing 6779.77 8329.77 Halliburton Baffle Collar 1.40 15109.54 Jts 3 to 3 1 Jts 7 5/8" 29.7* L-80 BTCM Casing 43.18 15110.94 Halliburton Float Collar WI bypass baffle on top 1.00 15154.12 Jts 1 to 2 2 Jts 7 5/8" 29.7# L-80 BTCM Casing 85.46 15155.12 Silver Bullet Shoe 2.11 15240.58 7 5/8" Shoe @ 15242.69 9 7/8" Hole TD @ 15258' MD/6747' TVD 15242.69 7 5/8" Shoe @ 15242' MD/ 6744' TVD 15242.69 15242.69 Top of Qannik at 7804' MD 4136TVD 15242.69 15242.69 (1) 9-1/8" Straight blade Centralizer on Jt#1 15242.69 9-3/8" Hydroform Centralizers; 15242.69 (71) One per Jt on Jts #2 thru #72 15242.69 (18) One per Jt on Jts #171 thru #188(200' below to 500' above K2) 15242.69 (3) One per Jt on Jts#274 thru #276 (Across 10-3/4" Shoe) 15242.69 (40) One per 2 Jts on Jts#278 thru #356 15242.69 Total 15242.69 (1) Straight Blade centralizer 15242.69 (132) Hydroform centralizers 15242.69 (2) Stop collars 15242.69 15242.69 15242.69 Stop collar on Jt#1 10' up from shoe, with centralizer floating below 15242.69 Stop collar on Jt#2 10' down from collar, with centralizer floating above 15242.69 15242.69 15242.69 380 joints in shed - 358 total jts. to run 15242.69 Last 22 jts. out 15242.69 15242.69 Remarks: Use Run and Seal pipe dope Up Wt ??? K Average MU tq = Dn Wt ?? K Block Wt 72 K Supervisors:DaveBurley/Don Mickey 3 Cement Detail Report ter.; CD3-119 ConocoPhillips String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 4/5/2012 15:30 4/6/2012 01:00 CD3-119 Comment Line up to Cementers-Pump 1st Stage Cement as Follows: Pump 3 bbls CW 100-Pressure Test Surface Lines t/3500 psi-Pump 40 bbls 8.4 PPG CW 100 @ 5 BPM/451 Psi-Pump 36 Bbls 12.5 PPG Mud Push @ 5.6 BPM/611 Psi-Dropped bottom plug with last 2 bbls of MudPush(38 bbls total) Bled off lines -floats holding-Load top plug in cement head-Pump 47.7 BBIs(230 sxs) 15.8 PPG Class G Cement w/Additives-—6.3 bpm/657 psi-Dropped top plug- Cementers pumped 10 bbls of fresh water-full returns throughout Switch to rig pumps-Displaced cement with 11.0 ppg mud @ 7 bpm f/510 to 650 psi-slowed pumps @ 667 bbls away to 3.5 bbls/min @ 350 psi for last 21 bbls of displacement-total displacement 688 bbls-didn't bump plug-Shut in cement head-CIP @ 1815 hrs.-Full returns through out job-Continued to reciprocate until last 20 bbls of displacement PU wt 310 SO wt 155 Pumped 2nd stage cement job as follows: Pumped 30 bbls CW-100 @ 5 bbls/min @ 200 psi-Mixed&pumped 30 bbls-12.5 ppg MudPush @ 4 bbls/min @ 300 psi-Mixed&pumped 57 bbls(280 sks) 15.8 ppg Class G cement w/additives @ 4.5 bbls/min @ 250 psi-Dropped closing plug w/10 bbls water f/Dowell Cement Stages Stage#1 Description Objective Top(ftKB) Bottom(ftKB) Full Return? Cmnt Rtrn(... Top Plug? Btm Plug? Intermediate Casing 14,629.0 15,242.0 No Yes Yes Cement Q(start)(bbl/min) Q(end)(bbl/min) Q(avg)(bbl/min) P(final)(psi) P(bump)(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 4 7 350.0 0.0 No No Depth tagged(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Didn't bump plug-waited on cmt 5 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 14,550.0 15,242.0 230 G 47.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 1.16 5.08 15.80 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top(ftKB) Bottom(ftKB) Full Return? Cmnt Rtrn(... Top Plug? Btm Plug? Intermediate Casing 7,277.0 8,327.0 No Yes No Q(start)(bbl/min) Q(end)(bbl/min) Q(avg)(bbl/min) P(final)(psi) P(bump)(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 4 7 260.0 750.0 No No Depth tagged(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pressure up on casing to 3310 psi to open stage collar Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 7,277.0 8,327.0 280 G 57.0 Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 1.16 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/2/2013 Security Level: AK Development � £� �.� (;,£ Daily Drilling Report CD3-119 .��= Report Number: 43 • Rig:: DOYON 19 . . Report Date: 4/5/2012 AFE:TYpe Netedrk/ID#:;; .. Total AFE+SUp 10329832 . 16,000,000.00 Wellbore Well Type Field Name • DES(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD3-119 . Development - FIORD NECHELIK 39.83 43.0 0.00 15,258.0 15,258.0 Daily Mud Cost Cumulative Mud Cost . Daily Cost Total •Cumulative Cost 3,896.63 2,006,280.16 • 862,087.63 13,813,027.61 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 2/23/2012 2/26/2012 45.00 61.75 -16.75 4/25/2012 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) . INTERMEDIATE, 15,242.7ftKB - Ops and Depth @ Morning Report 24hr Forecast LD 5"DP Finish 2nd stage cmt job-LD 5"DP-Test BOPE Last 24hr Summary Circ&condition mud @ 13045'-Cont. RIH w/7 5/8"casing f/13,045'to 14,835'-.washed casing down f/14,835'to 15,242'-RD csg equip./RU cmt head-Circ for cmt job-Pumped 1 st stage cmt job-WOC-Opened stage collar-Pumped 2nd stage cmt job General Remarks Weather Head Count No Accidents/No Spills -4°/-31°we%NE @ 21 mph/Vis. 2 mi. 52.0 Supervisor Title Dave Burley, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor John Samuell, Drilling Engineer Drilling Engineer Time Log ::Start End' Dur Time Depth Start: Depth End Time • Time (hrs)• Phase; �Op Code i Activity•Code PTX ;Trbl Code-- Trbl-Class (ftKB) (ftKB) - Operation .. ,,, 00:00 02:45 2.75 INTRM2 CASING CIRC P 13,045.0 13,045.0 Continue to Circulate and condition mud - FCP 6.0 bpm/480 psi Pumps on PUW 315 SOW 165K Mud wt.in/out 11.0 ppg/11.15 ppg 02:45 07:00 4.25 INTRM2 CASING RNCS P 13,045.0 14,835.0 Ran 7-5/8"29.7#L-80 BTCM casing from 13045'to 14835'(350 jts total in hole) SOW 160K-encountered tight spot at 14835'-lost 25K SOW 07:00 11:00 4.00 INTRM2 CASING RNCS P 14,835.0 15,205.0 Establish circulation 3.0 bpm/460 psi- Worked pipe and washed down through tight hole from 14,835'to 15205'-free pipe SOW 150/155K-washing to bottom SOW intermittent at 125-100K- PUW_350K-once hole was wiper SOW stayed—150K-increased pump rate to 4 bpm/500 psi from 14,950' 11:00 11:30 0.50 INTRM2 CASING RNCS P 15,205.0 15,242.0 MU FMC fluted hanger and landing joint- wash down from 15,205'to 15242'-4.0 bpm/550 psi-land hanger in wellhead 11:30 12:15 0.75 INTRM2 CEMENT RURD P 15,242.0 15,242.0 Lay down fill up tool-blow down top drive MU cement head and lines 12:15 16:00 3.75 INTRM2 CEMENT CIRC P • 15,242.0 15,242.0 Establish circulation-Staged pumps up to 6 bpm-Reciprocate casing-condition mud for cementing-PUW 305K SOW 165K-Mud wt. in 11.0 ppg Mud wt.out 11.7-11.25 ppg-FCP 6.1 bpm/580 psi • -total volume pumped 1060 bbls-Held - PJSM with Rig Team-had full returns while circulating • • Latest BOP Test Data. Date •- ':`Comment 3/30/2012 Witness of test waived by AOGCC inspector Matt Herrera. Next test due 4/13/2012. Page 1/3 • Report Printed: 1/2/2013 Security Level: AK Development • , Daily Drilling Report CD3-119 fh Report Number: 43 • Rig: DOYON. 19 Report Date: 4/5/2012 Time Log Stat End Dur : Time 4 Depth Start Depth End'' Time Time (his) Phase Op icode Activity Code P-T-X' Operation 16:00 16:30 0.50 INTRM2 CEMENT PUCM P 15,242.0 15,242.0 Line up to Cementers_Pump 1st Stage • Cement as Follows: Pump 3 bbls CW 100-Pressure Test Surface Lines t/ . 3500 psi-Pump 40 bbls 8.4 PPG CW 100 @ 5 BPM/451 Psi-Pump 36 Bbls 12.5 PPG Mud Push @ 5.6 BPM/611 Psi-Dropped bottom plug with last 2 bbls of MudPush(38 bbls total)Bled off lines-floats holding-Load top plug in • cement head-Pump 47.7 BBIs(230 sxs) 15.8 PPG Class G Cement w/Additives- -6.3 bpm/657 psi-Dropped top plug- Cementers pumped 10 bbls of fresh water-full returns throughout 16:30 18:15 1.75 INTRM2 CEMENT DISP P 15,242.0 15,242.0 Switch to rig pumps-Displaced cement with 11.0 ppg mud @ 7 bpm f/510 to 650 psi-slowed pumps @ 667 bbls • away to 3.5 bbls/min @ 350 psi for last 21 bbls of displacement-total displacement 688 bbls-didn't bump plug-Shut in cement head-CIP @ 1815 hrs.-Full returns through out job- Continued to reciprocate until last 20 bbls of displacement PU wt 310 SO wt 155 18:15 22:30 4.25 INTRM2 CEMENT WOC T Cement- Other 15,242.0 15,242.0 Wait on cement-To pressure up to open Primary • stage collar 22:30 22:45 0.25 INTRM2 CEMENT OTHR P 15,242.0 15,242.0 Open valve on cement head-bleed-off pressure<100 psi-Load closing plug for 2nd stage-Pressure up on casing to 3310 psi-opened stage collar 22:45 23:15 0.50 INTRM2 CEMENT CIRC P 15,242.0 15,242.0 Circ btms up from 8327'(stage collar)@ 7 bbls/min @ 420 psi-Mud wt 11.0 ppg in&out Held pre job for 2nd stage cmt job • 23:15 00:00 0.75 INTRM2 CEMENT PUCM P 15,242.0 15,242.0 Pumped 2nd stage cement job as follows:Pumped 30 bbls CW-100 @ 5 bbls/min @ 200 psi-Mixed&pumped 30 bbls-12.5 ppg MudPush @ 4 bbls/min @ 300 psi-Mixed&pumped 57 bbls(280 sks)15.8 ppg Class G cement w/additives @ 4.5 bbls/min @ 250 psi-Dropped closing plug w/10 bbls water.f/Dowell Mud Check-Data •YP Calc Gel(;i op) . :Gel(10m) Gel(30m) f 1THP F It : Density,Temp Solids Cor Depth(ftKB) Dens(lb/gal) Vis(s/qt)_ PV Caic"(cp)', (Ibf/1 (Ibf/100/f) MBTTIb/bbl) ,(mU30mm) pH <y,, CF) (%) 31ydril 15,258.0 11.00 48 15.0 19.0 7.0 8.0 9.000 22.5 5.6 9.2 31ydril 15,258.0 11.00 48 17.0 19.0 7.0 10.0 11.000 21.3 9.2 • njection Fluid ":Source -,FromLease.(bbl) : Destination '_ Vendor;;; ManifestNumbeY;; .,_K.., Note: Drilling Mud WBM CD3-119 560.0 CD1-19 . ASRC 362231,362232 Page 2/3 Report Printed: 112120t3 Security Level: AK Development Daily Drilling Report • 41'51., •11_4 3-:-11.1. CD3-119 • Report Number: 43 • • Rig: DOYON 19 . . Report Date: 4/5/2012 ArgfibbiaguigetRg=;: RMMOTORNingiTgginiggniNVi:-ii:VRAIRMareteliaatiZteannin6ligNg:igintiR-MRlenikiginilalignitgainita Wellbore Name • Wellbore APUUWI • CD3-119 501032065300 f -Section Size(in) r Act Start Date End Date 19,375.0 CONDI • - 16 • 37.0 - . 116.0 2/26/2011 • . 2/26/2011 SURFAC • 13 1/2 116.0 3,661.0 2/26/2012 2/29/2012. INTRM2 • • 9 7/8 3,700.0 15,258.0 3/24/2012 " 4/1/2012 PROD1 6 3/4 15,258.0 19,375.0 4/9/2012 4/15/2012 Casing Sfhngs .:--,: ...... .,„:...--: , ....., . . : String OD Stnng Wt - . " Casing Description7.Run:Date•Mit String Grade i!--- INTERMEDIATE 4/5/2012 7 5/8 29.70 L-80 • 15,242.7 Ran 7-5/8"29.7#L-80 BTCM casing as follows: Float shoe(Ray Oil Tools silver bullet)2 jts csg Float collar(Halliburton Super Seal w/bypass baffle)-1 jt.csg-Baffle collar(Halliburton)1 jt..csg to 176'(shoe track made up w/BakerLoc-fill pipe &circulated to check floats)-86 jts csg to 3819' (90 jts total in hole)-Installed centralizers on first 72 jts.(1 straight blade on shoe jt&71 Hydroform) PU wt. 142 SO wt. 126 Circ &cond @ 3819' • • Ran 7-5/8"29.7#L-80 BTCM casing from 3819'to .. • 7001'(165 jts total in hole) SOW 158K Installed Halliburton Stage tool on top of jt.#163 Ciro&cond @ 7001' Ran 7-5/8"29.7#L-80 BTCM casing from 7001'to 10025'(236 jts total in hole) SOW 155K Ciro&cond:10,025' • Ran 7-5/8"29.7#L-80 BTCM casing from 10025' to 13045'(307 jts total in hole) SOW 165K Circ&cond.@ 13,045' . Ran 7-5/8"29.7#L-80.BTCM casing from 13045' to 14835'(350 its total in hole) SOW 160K- — . encountered tight spot at 14835'-lost 25K SOW . Establish circulation 3.0 bpm/460 psi-Worked pipe and washed down through tight hole from • 14,835'to 15205'-free pipe SOW 150/155K washing to bottom SOW intermittent at 125-100K • -PUW-350K-once hole was wiper SOW stayed -150K-increased pump rate to 4 bpm/500 psi from 14,950' MU FMC fluted hanger and landing joint-wash down from 15,205'to 15242'-4.0 bpm/550 psi- land hanger in wellhead Cement Intermediate Casing Cement-Started @ 4/5/2012 Type Wellbore . Cemented String Cement Evaluation Results casing _ . CD3-119 • INTERMEDIATE, 15,242.7ftKB Stg No. Description • • Top(ftKB) Bottom(ftKB) Q(end)(bbi/... P(final)(psi) - 1 Intermediate Casing Cement 14,629.0 15,242.0 4 350.0 Fluidviyp•;4;-pa#s4;!;:iRmi:-;ii!•-•;;;:ArodiiibtfsotkwfiV(bbt) Density(lb/gal) Yield(ft/saclç) EstTop(ftKB)C "" Est Btm(5KB) Intermediate Cement G 230 47.7 15.80 1.16 14,550.0 15,242.0 Stg No. Description Top(ftKB) Bottom(ftKB) • Q(end)(bb1/... P(final)(psi) 2 Intermediate Casing • - 7,277.0 • 8,327.0 4 • 260.0 4‘.-Agt.MielMtigEgiretni*V-AW4ii,V4-; :-.A17114;rNiQl.ap§ MATioPit(#0150.11i MaiMpolyo*-*4 mDensity.gilgamirOa:-.%1•00.mg46km poikrcemstA Intermediate Cement G . 280 . 57.0 ' 15.80 1.16 • 7,277.0 8,327.0 • • • Page 3/3 • Report.Printed: 1/2/2013 • Security Level: AK Development Daily Drilling Report CD3-119 • �'- Report Number: 44 atrtocoPlvll ; a Rig: DOYON 19 Report Date:. 4/6/2012 10329832 • 16,000,000.00 Wellbore Well Type • Field Name DFS(days) DOL Depth Progress(ft). Depth Start(ftKB) Depth End(ftKB) CD3-119 Development FIORD NECHELIK 40.83 • 44.0 • 0.00 • 15,258.0 • 15,258.0 Daily Mud Cost • .. Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,500.00 2,008,780.16 229,562.00 • 14,042,589.61 . Actual Start Date Original Spud Date . AFE Dur Total(days). •Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 2/23/2012 : • • 2/26/2012- .45.00 • .61.75 • -16.75 4/25/2012 Last Casing String . . Next Casing OD(in) • Next Casing Set Depth(ftKB) INTERMEDIATE, 15,242.7ftKB • • Ops and Depth @ Morning Report 24hr Forecast - Testing BOPE • Test BOPE-Make C/O run to SC-MU BHA-RIH Last 24hr Summary • Displace cmt on 2nd stage cmt job-Closed stage collar-RD casing&cmt.equipment-RU&LD 5"DP f/derrick-Change top pipe rams-Change saver sub in TD-Set test p[ug .General Remarks Weather Head Count No Accidents/No Spills -6°/-25°we/NE @ 12 mph/Vis. 12 mi. 53.0 Dave Burley, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor • • . • • .Rig Supervisor John Samuel!,Drilling Engineer Drilling Engineer . lfSfart. End Dur Time Depth Start.Depth End: .00:14;1 Time c_fratio5 { Phase" O Code Activi Code PTX Trtil Code V Trbl Glass (ftKB ;_ ftKB£`, 00:00 01:15 1.25 INTRM2 CEMENT DISP P 15,242.0 15,242.0 Displaced cement w/378.8 bbls of 11.0 ppg LSND mud @ 7 bbls/min @ 340 psi -Slowed pumps to 3.5 bbls/min @ 240 psi for.last 26.8 bbls..-Bumped plug w/ 750 psi-Held pressur for 2 mins.- pressured up to 1600 psi to close stage collar--Held pressure for 2 mins.-Bleed off pressure-opened bleeder valve on cement head to confirm stage collar was closed-OK-CIP @ 0056 hrs.-Full retunrs throught out'job 01:15 01:45 0.50 INTRM2 CEMENT RURD P 0.0 0.0 PJSM-Blow down lines-RD spider& elevators-RD cement head-'LD landing jt. 01:45 02:30 0.75 INTRM2 . CEMENT OTHR P 0.0 0.0 PJSM-Pulled thin wall wearb ushing (top of wear bushing damaged barley able to get J'ed into w/pulling tool)Set 7 . • 5/8"pack-off&test to 5000 psi,for 10 , mins. - 02:30 03:00 0.50 INTRM2 CEMENT OTHR P 0.0 0.0 Clean&clear rig floor of equipment . • (casing spider&elevators)Removed long bails f/top drive and sent down f/rig floor 33:00 03:30 0.50 INTRM2 CEMENT OTHR P 0.0 0.0 PJSM-Install drilling bails&PU 5"drill • • • pipe elevators 33:30 05:15 1.75 INTRM2 CEMENT PULD P 0.0 0.0 PJSM-LD 5"drill pipe f/derrick via mouse hole -Laid down 12 stds HWDP &5stds 5"DP )5:15 05:45 0.50 INTRM2 CEMENT • SVRG P 0.0 0.0 Service rig )5:45 12:00 6.25 INTRM2 CEMENT PULD P 0.0 0.0 Cont.to LD 5"DP f/derrick via mouse hole-laid down 57stds • 12:00 21:15 9.25 INTRM2 CEMENT PULD P 0.0 0.0 PJSM-Cont.LD 5"drill pipe f/derrick via mouse hole ?1:15 23:30 2.25 INTRM2 WHDBOP . OTHR P 0.0 0.0 PJSM-Change top rams f/75/8"to 3 ' 1/2"x 6"VBR-Chnage out TD saver sub f/4 1/2 IF to 4"XT-39 _atest BOP Test Data . s/30/2012 Witness of test waived by AOGCC inspector Matt Herrera. Next test due 4/13/2012. Page 1/2 • Report Printed: 1/2/2013 �,. Security Level: AK Development 4. Daily Drilling Report • CD3-119 " r *I" Report Number: 44 Rig: DOYON 19 Report Date: 4/6/2012 Tlme Log: �s • Depth Start Depth End Trrne Time= {hrs)3` Phase :rOp Code K3Activity Code P7 X Trbt Code Trbl Class (ftKB) (ftKB)_ Operation 23:30 00:00 0.50 INTRM2 WHDBOP • OTHR P 0.0 0.0 PSJM-House keeping on rig floor-Set test plug Mud Cheek Data ��. w �; YP Calc Gel(10s) Gel(10m) Gel)30m) �f HTHP Filt Density Temp Solids Corr �:' TYpe Depth%ftKB) Deris(Ib/gal) .Va-(s/gt)_;PV Calc?(ep) (Ibf/l OOft') (Ibf/_100ft') (Ibf/100ft)_ (Ibf/100ft) MBT(Ib/bbl) ;(mU/30min) Glydril 15,258.0 11.00 54 16.0 21.0 7.0 10.0 15.000 22.0 8.6 70.0 Injection Fluid Fluid ". „„Source. ;`From"Lease(bbly Destination ;Vendor Manifest.Number IJote - . Diesel CD3-119 Freeze Protect Drilling Mud WBM CD3-119 1590.0 CD1-19 ASRC 362233,34,35,36,37... . Drilling Mud WBM CD3-119 •Annular LOT Fresh Water CD3-119 Annular Flush • Wellbore Name Wellbore API/UWI CD3-119 501032065300 ff Section ., i Act_Btm{ftKB)' " ,:Start Date_ End Date;:" "__ 19,375.0 CONDI 16 37.0 " 116.0 2/26/2011 2/26/2011 SURFAC 13 1/2 • 116.0 , 3,661.0 2/26/2012 2/29/2012 INTRM2 9 7/8 3,700.0 • . 15,258.0 3/24/2012- • • 4/1/2012 PROD1 6 3/4 15,258.0 19,375.0 4/9/2012 " 4/15/2012 • • • • • • • • • • Page 2/2 Report Printed: 1/2/2013 . ... ,:--,o,),.tri.r> cr) )tici,:c?,)::-.,:m i,po:err).:::tri..•.,,e.r.).,e.•,7).i'.47)-:co-•:coL LAY)..e.r>:-to:c . ::.,:c.,..):•ro:•17••••4:-csa • ..o.:•!...tt:Ltr::.....7,5r. (-....x;co:L:•:(9::::',..C!).:VO(-0,(N:(N:CSIL(Ni:04'C's4 .,...: Er)...'.ii!47:,V7L75t. '<" . . .-,.17..;!: ....,-.71,.,,!517- ,N. . ..•.,Ft. 747.Nt.., ,t517.7c17.:Ft,. 7,Ft. - E c1.72- 4; = CO Ca .i.., H 1.— m v) ..„, 1= CD U) if) ,-- LO (N LID V) 1.0 -4. Lo Lo Lo co Lo r- Lo OD in CD 11) CD i5 1;,-,.Y.:::•• a .p. 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O. 0 CD :Iasi 'El . C/) (5 oj - I • - c) 0 _ 0i.i. g 6- ., NO ci io. 7,-) c "(I) ----- :.-, _c CC) (/) a) co ° •- = t't ,4 ti.,i"5 - 0) .- LL 7-:c t, a0- ?"' o c cU c CI LO CD GO r- •.--. '-- E .5 r,9 a) a) - • 0 — — — •• 0 0 -gill WF, 13 -0 N-• ° --.' a ti a) co.0 ° (NI e.) -7?° 2 — ._ 1--- 0)= LU }— I 00.• Q. = c C11 0 E E 0 --- •.,,,, 1- 8 .- 0 -a .6.5. — 4— - o = -0 a CL CD = 0 0 c., ZCr> 4. WO — 0 Ce 0 6 h > c co ,..:, LO 0 0 IT 0 Cs11 a ..1-• I- 0U) T— I— II. In U) ..0 W N7 a) 0,t-') op qd• x ii ....2. I- W co L.L. >, -4- 0 .,..., (12.1 ,..... g ., ›.. t.-4- Li- c) CI . o .... u 41 ----. ..., .0 S' o ,7, 6 , < 2 a- -c tri I o LLJ — (1) U) ,-_s d" 2 0 < CI)2 "ii- , 1 cs;', - .4 ri) . co) : 8 (7) i'r 6 ' g to 4,....) _ 0_ •0_ ,, 0 .,_ .1- 1 -`2 Ci (D ...., E 7) . b tr) 64 E c • ...--, ,-,.. in 0) II O „.0 r^) — gg 0 C C .t' CI `.- 1— I•,-' Vi 0 ) U) I— I- 0) P, . La- 'FT) ,-- o CZ n-- _Y '*.' 0 1:3 = 0 A . ,Tt I— G O —1 [''._ 0 C.0 EL- Ci) C. < — j) (n 14. E LLI ca --5 4,0 41) Ca ..1/2 t tu. -_. a) ,..., 4.4 't 6 C) "5 .,-.., ....-. -,-, -,- CD L. LA ,r, 0 711 c ,n .,, c ,I, = = p_or = > ..- .. z u) a •••• c „, o ca.) +, u) i_ Q,rcm ct s- co 0 Ca u) ' < -•- . X 2 L: 4-10 --"' (1) 8 tar; (9 - -4,2 00 2)a. "Lo Lu ,r„ . 1 o — .. (7) p_ . E 15 LL. 0 0 ..2 0 -0 i c g-CW E) 7—C1) O 0a3 o (6 h , cl. 0 a) 0 . ce _I 0 0 E u) , 0 •c7) Lt.,— id I-- E 1 N Z c Q.) •,...- (/) o 6 (Ts . _c .0 II 3 .- 0 -u- 0 0 - 0 a) W * o 'r- to 111ISS3Nd 0 E ' o Lu ° 0 I -5 0 .N E o ••••p • 4 4.4...-4.44.4.4.44.4.-....j Note to File CD3-198 (2110240) Colville River Unit (Fiord Pool) ConocoPhillips Alaska, Inc ConocoPhillips has made application to authorize annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD3-198). -- 9 5/8" Surface casing was cemented to surface successfully. No problems were reported. Approximately 114 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 44% XS of the calculated hole volume. -- On the initial leak off test (LOT) for the surface casing shoe dated 3/17/2011, the pressure slope rises smoothly to -17.0 EMW and continues at a slightly shallower slope to 18.1 EMW. Minimal fluid was pumped in. The pressure declined slightly during the observation period and was steady during bleed back (1.2 bbl bled back of the 1.4 bbl pumped) and over the 10 min SI period to 15.9 ppg EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented with TOC estimated at 6835 ft MT, 5962 ft TVD to TD 8738 ft MD. Good cement job with bumped plug. 2nd stage cement job pumped to lay cement from 3581 ft MD to 5124 ft MD. LOT of 7 inch calculated at 3581 ft MD shows 15.03 ppg EMW. An annulus 9.625 x 7" LOT was performed 3/27/2011 with a calculated depth of the casing shoe of 2618 ft MD, 2455 ft TVD yielded a 15.9 ppg EMW. The test showed pressure rising smoothly to the 15.9 ppg EMW and a maximum of 16.4 ppg. Recalculating for the probable injection zone top of 2700 ft MD, 2540 ft TVD yields 15.7 ppg EMW. This depth equates to below the 9 5/8" casing shoe and above the 2nd stage 7" cement job TOC. --There are multiple (13) wells within 1/4 mile radius of CD3-198. The surface shoe of CD3-110 is closest, about 144' distant. CD3-106 is 163 ft, CD3-302 is 258' and CD3-109 is 393' distant. AD has been approved for multiple wells on CD3, with the latest approval being an extension to 70,000 of CD3-114. Examination of the cementing information and LOT data did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Chris 4.aline.. Sr. Petroleum Engineer AOGCC January 17, 2013 G:\AOGCC\Common\tommaunder\Well Information\By Subject\Annular Disposal\130117_CD3-198.doc Note to File CRU CD3-198 (PTD 2110240) January 17, 2013 Re: ConocoPhillips' Application for Sundry Approval for Additional Annular Disposal of Drilling Wastes within Well CD3-198 Request ConocoPhillips requests approval to inject 35,000 barrels for disposal of waste fluids generated through drilling operations by injection into the 9-5/8" x 7" annulus within well CD3-198. The CD3-198 development well was drilled to the Fiord Oil Pool within CRU. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set in this well at about 2,455' measured depth (-2,276' true vertical depth subsea, or"TVDSS-1, near the base of a 400-foot thick mudstone and siltstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandy siltstone open to the annulus surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining mudstone strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection of 35,000 additional barrels of waste will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular disposal will be limited to a radius of about 100' from the wellbore. Discussion CPAI's application was reviewed along with well logs from Colville River Unit (CRU) wells CD3-106, CD3-301, CD3-108, and the Fiord 1 exploratory well. An index map is provided in Figure 1, below. All footages presented herein represent measured depth, unless otherwise noted. All thickness footages represent stratigraphic thickness,unless otherwise noted. The proposed disposal injection interval (disposal interval) in the well lies in the Seabee Formation within Section 5, Township 12 North, Range 5 East, Umiat Meridian, located more than 2 1/2 miles from the CRU boundary. The annulus open to the disposal interval extends downward from the 9-5/8" surface casing shoe, which is set at about 2,455' (-2,276' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 3,581' (-3,250' TVDSS).' This annulus lies within Section 5 of T12N, R5E,Umiat Meridian(see Figure 1). ' Top of cement estimate from\\DoaancogcfpsO l\Shared\AOGCC\Common\tommaunder\aa2009 0712 Working- Well_Cement_Current.xls,worksheet MIT II,PTD 211-024,column 30%Excess TOC. CD3-198 January 17, 2013 Note to File Page 2 of 6 The disposal interval in the well lies in the Seabee Formation. The most likely portion of the open annulus that will accept injected waste is a 60-foot thick interval containing unconsolidated sandstones interbedded with siltstones that extends from about 2,490' to 2,542' TVDSS. FIDRD-4 — - CD3-109 CD3-106 388 CD3-106L1 CD3-108 C7 ' 27 26 CD3-110 CD3-111 L1 CD3-301 \_ CD3.301A CD3-107L1 Area of Review CD3-107 CD: FIORD 5 364471 CD3-113 (shaded blue) CD3.302A CD3-114 34 35 115 CRU CD3-198 Annulus 2 CD3-303 Most Likely ReceptorCD3.316 O4 flORD 1 372103 Interval (highlighted with red) CD3•16a CD3-199 CD3-198 CPF-3 CD3-304 CD3-121 CD3-198 • Surface casing shoe CD3-122 CD3-306 CD3-123 al Cement top CD3-125 Figure 1. Index Map (The path of the cross-section shown on Figure 3 is highlighted with a red line) The 9-5/8" surface casing shoe lies near the base of a 300-foot thick interval that is dominated by mudstone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 45-foot thick interbedded siltstone-shale interval that is also continuous throughout the area. This interval, which lies between about -2,685' and -2,730' TVDSS, and two similar, thinner, underlying mudstone intervals will provide additional lower confinement for injected wastes. In vicinity of Drill Site CD3, the base of permafrost occurs at about -1,250' TVDSS, which is about 1,200' shallower than the top of the likely receptor interval. CD3-198 January 17, 2013 Note to File Page 3 of 6 Comedian Depth Res* Parody CALI(CALA) <TVD Res D(RPD) RHOS IN 25 r.2 OHM/ 2001.65 G,CC 2f SP(NIA) TV D S S> Res M(RPM) NPOR(NPHI) O 100 •2 OHMM 20060 PU GR TVD ResS(RPS) =RNA) API 240 ..2 OHMM 200170 a Z <MD DTSH(WA) 1000 $and Sett Shale 2400 2;nii Upper 2 500 Confining Strata 2600 2-lOU s ' f< Most Likely . .... . . ..... ... ,Receptor , 1 - 1 Interval for - Disposed -1 Fluids 2800 , I 1- r_ [,n° CIiII If ' 4. 2900 __ Lower . nn 1 - f .. Confining 4. —-' — -=_ Strata 3000 2800 )ll ; 1. 1 . ' r n -- 3100 2900 . Figure 2.CD3-198 Well Log Displaying Affected Intervals Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the proposed affected area. In Fiord 1 exploratory well, methane was first encountered at about 370' MD. On Drill Site CD3, CD3- 114 is the only well that was mud logged. This well encountered methane at about 1,115' (-1,050' TVDSS). So, in the CD3-198 well,the entire proposed disposal zone likely contains some gas. CD3-198 January 17, 2013 Note to File Page 4 of 6 2110240 1911470 SW 501032063700 501032016200 NE 11593 ft CONOCOPHILLIPS ALASKA ARCO CRU CD3-198 FIORD 1 3888 FNL 641 FEL 526 FSL 420 FWL TWP: 12 N - Range: 5 E -Sec. 5 TWP: 12 N - Range: 5 E - Sec. 2 l000 .. Y+ w 2-5 G� .r000 Net , aa0 22 e - `r__ M. 1500 „• .2. _ .1500 wo u. wo 3200 ._ ._ 9-5/8"9-5/8"Casing _ Shoe - ...._. , 13-3/8"Casing ,,,, .. ,— Shoe X000 _ � Upper 2m 1.00 iy. Confining — 00 Strata •- 0` Upper - NConfining Likely _,', 7 Strata _, ''receptor{ „ -2500,._ - t i Interval 2000 •••• ,. Lower 'm° 1 V, - ‘ Confining—' 0'00 .- Open - �.._ . Strata uO0 _ — AnnulusSI 3300 2200 2. a•s 3200 MOO 22.2 .32 3300 t-__: 3200 22.2 3500 "It 22222 ise. 4000 2, 1 3700 .5 TD=15571 TD=10250 Figure 3. Structural Cross-section from Fiord 1 TO CRU CD3-198 CD3-198 January 17, 2013 Note to File Page 5 of 6 The shallowest oil show encountered in the CD3-114 well was observed at 6,050' (-4,413' TVDSS), about 1,800' stratigraphically below the most likely receptor beds for the injected material. This show consisted only of 10%dull yellow sample fluorescence and a slow pale yellow sample cut in solvent, and the mud logging geologist rated this show as being of"trace"quality. This instance is judged to represent only small amounts of residual (non-mobile) oil. So, at Drill Site CD3 the likely disposal interval does not contain potentially commercial quantities of oil or gas. The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD3-198 that will be affected by the proposed annular disposal operations. There are about 18' of porous sandy siltstone and silty sandstone beds within the likely waste receptor interval, according to a count using the gamma ray curve from CD3-198. Neutron and density porosity well logs were run across the proposed disposal interval in nearby well CD3-108. Inspection of these well logs suggests an average porosity of about 28% for the sandy siltstone and silty sandstone within the likely receptor interval. Based on these values, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 100' from the wellbore, as indicated in the chart below. Injected Fluid vs Affected Radial Distance (assumes 20'aggregate injection zone thickness and 28%porosity) 300 - • 250 d o . m 200 E 0 g• 150 _ O & 100 Q, • 50 0 • 0 10,000 20,000 30,000 40,000 50,000 60.000 70,000 Amount of Injected Fluid(barrels) Figure 4.Radial Distance Potentially Impacted by CD3-198 Annular Disposal CD3-198 January 17, 2013 Note to File Page 6 of 6 Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains some gas, is situated beneath about 1,224' of permafrost, and is bounded above and below by continuous confining layers. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath Drill Site CD3. The open annulus that will be used for disposal injection lies inside the CRU, well away from any external property lines, so correlative rights are not a concern. The area most likely affected by the additional proposed waste volume lies within about 100' of the CD3-198 wellbore. I recommend approval of the request for annular disposal of 35,000 barrels of drilling waste. Patricia Bettis �� Senior Petroleum Geologist lopv ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 Lk May 15,2012 — O0.),•1 � Y� Commissioner Dan Seamount levy Alaska Oil& Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU),and the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor,engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404,Report of Sundry Operations. The cement was pumped in the spring of 2012. The corrosion inhibitor/sealant was pumped in the months of April and May 2012. The attached spreadsheet presents the well name,top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement,Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 5/15/2012 WD,CD2,CD3,CD4,PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal WD-02 50103202850000 1982580 2' n/a 2' n/a 13.6 4/11/2012 CD2-77 50103206290000 2101790 SF n/a 17" n/a 2.1 4/13/2012 CD3-128 50103206380000 2110370 21' n/a 21' n/a 90.7 4/13/2012 CD3-198 50103206370000 2110240 28" n/a 28" n/a 47.6 4/13/2012 CD3-199 50103206350000 2110100 SF n/a 11" n/a 2.9 4/13/2012 CD4-03 50103206410000 2111130 29" n/a 29" n/a 9.4 4/11/2012 CD4-298 50103206230000 2101300 28" n/a 28" n/a 28.9 4/11/2012 Halliburton Sperry Drilling 6900 Arctic Blvd Anchorage, AK 99518 August 23, 2011 AOGCC Christine Mahnken 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Sir or Madam: Subject: CD3-198 Definitive Survey Reports Enclosed are two hard copies(NAD83 and NAD27)of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit@Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd Anchorage, AK ••-18 Received by: .� / DIS Date:2Vili A.a it Please contact me at 907.263.4657with questions or concerns. Regards, Avinash Ramjit a l�_ 0atf Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv[n1617@conocophillips.com] Sent: Wednesday, June 15, 2011 12:14 PM To: Regg, James B(DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv; ALP DS Lead and Simops Coord Subject: Alpine Witnessed MITIA report Attachments: MIT CRU CD3-198 Retest 06-12-11.xls All, Attached is a copy of the retest form for CD3-198. The test pressure was chosen by the inspector on location. From: NSK Problem Well Supv Sent: Wednesday,June 08,2011 8:57 PM To: 'Regg,James B(DOA)'; Maunder,Thomas E(DOA);'Brooks,Phoebe L(DOA)'; DOA AOGCC Prudhoe Bay Subject: Kuparuk and Alpine Witnessed MITIA reports All, Attached are the forms for the Kuparuk and Alpine witnessed MIT's that were performed on 06/05/11. Please let me know if you have any questions. « File: MIT KRU 3A-07 06-05-11.xls» « File: KRU 3F Pad 06-05-11.xls» « File: MIT CRU CD1-07 06-05- 11.xls» « File: MIT CRU CD3-124 & 198 06-05-11.xls» « File: MIT CRU WD-02 06-05-11.xls» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Pager(907)659-7000 pgr. 909 8/4/2011 Page 1 of 1 Maunder,Thomas E(DOA) From: NSK Problem Well Supv[n1617@conocophillips.com] Sent: Wednesday,June 08,2011 8:04 PM To: Regg,James B(DOA);Maunder,Thomas E(DOA);Schwartz,Guy L(DOA) Cc: NSK Problem Well Supv;ALP DS Lead and Simops Coord Subject: CD3-198(PTD 211-024-0)Report of failed MITIA Attachments:CD3-198 schematic.pdf Jim,Tom,Guy Alpine injector CD3-198(PTD 211-024-0)was reported to have a failing initial MITIA as witnessed by Jeff Jones on 06/05/11 due to an unstable injection rate during the test. It is ConocoPhillips intention to leave the well on injection to continue to thermally stabilize and a witnessed retest will be rescheduled. Attached is a 30 day TIO plot(the well was 1301 on 05/14/11)and schematic Please let me know if you have any questions. \generalSCADAIWD_TREND WELL TRENDS CD3 198 PRODUCED WATER INJ WD HOUSE_INIT/ TRrUnuLT SCvLE CURRENT VALUE CURRENT VALUE CURRENT VALUE CURRENT VALUE OPERATOR NOTES SET CHOKE CHOKE 26. INJ RATE 3241. WH PRESS 1870. ORIF DP 71.1 INJ TEMP 108. INJ VOL 2737. IGV/OGV FL PRESS 2111. WFLL STATUS 100.00 3000 1 1 I i ' ON 3000. INVERT OPEN/SI 95.00 2700 -- - _ II EVENT AT 3000.0 PICK TIME 3000. 2400 ` _-..iii.i:" 10.00 s,Pi „ow, --r_- 4h- 1 0.4k1014,!'all ..,0 t14l�� Its 41 GENERAL PURPOSE 3000. if#2100 ' V II EVENT AT 3000. PICK TIME AUTOSCALE 1800 1y� CREATE WELL _ • OK NOTE ATWPM I -- i�, -Nlir + All '^ . "111111114 PICK TIME 0 * + - 1500 O l 1 • ORIFICE Q U 1200 1111 FREEZE r • PROTECTION 900 I. CREATE 600 I-Ir JII4 � N SAFETY DEFEAT i UVIEW 0. SAFETY DEFEAT 0.00 300 0.00 0 i L. ir PREY WELL 0.0c Or NEXT WELL 0.00 ER SCALE DESC PICK VALUE LATEST PLOT DURATION ppm CHOKE 26. 26. 720-00HRS OB-: UX For INTEMP 108. 108. 2H 11711.1) , 4Wj8W ANNCOM PROBLEMS X PRESS 1072. 1108. El ) le OF N1 Flags: 111 Pr FL PRESS 2133. 2111. INSTANT Pr ZOOM MINOR TIM] TBG:: / I� INJ RATE 3252. 3241. MINIJT) _ n MAJOR TIM! IA: ORIF-DP 71.6 71.1 oA- I IA PRES 1219. 1219. HOURLY j 00A/Tree: I OA PRES 635. 635. DAILY WICK TIkC OS-JUN Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska,Inc. Desk Phone(907)659-7224 Pager(907)659-7000 pgr.909 8/4/2011 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE:Monday,June 27,2011 Jim Regg P.I.Supervisor K 9((``(( ill j( SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-198 FROM: Jeff Jones COLVILLE RIV FIORD CD3-198 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JL C— NON-CONFIDENTIAL Comm Well Name: COLVILLE RIV FIORD CD3-198 API Well Number: 50-103-20637-00-00 Inspector Name: Jeff Jones Insp Num: mitJJl10606102943 Permit Number: 211-024-0 Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Type CD3-198 Inj. W TVD 6852 IA 1066 i 2118 2132 2144 ,I 2153 - 2148 - 211ozao , P.T.D1 TypeTest SPT Test psi 1713 -I OA I 560 653 } 662 665 670 668 Interval INITAL - pjj' F- - Tubing] 1615 1831 1817 1819 1797 1793 Notes: IA pressure failed to stabilize due to unstable injection rate. 1 BBL diesel pumped. 1 well inspected;no exceptions noted. Monday,June 27,2011 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑., • WDSPL ❑ No.of Completions: Service ❑., • Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., il, 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 2011 • 211-024/ • 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 March 12,2011 50-103-20637-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1392'FSL,642'FEL,Sec.5,T12N, R5E, UM April 2,2011 CD3-198 ' Top of Productive Horizon: 8. KB(ft above MSL): 12.8'RKB 15.Field/Pool(s): 1339'FNL,997'FWL,Sec.4,T12N, R5E,UM GL(ft above MSL): 40'AMSL Colville River Field Total Depth: 9.Plug Back Depth(MD+TVD): 281'FSL, 1592'FEL,Sec.4,T12N, R5E, UM 13224'MD/7038'TVD Fiord Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation:, Surface: x-388402 y- 6003883 Zone-4 • 13228'MD/7038'TVD • ADL 372104,372105 TPI: x-390071 y- 6006408 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-392718 y- 6002709 Zone-4 nipple @ 2082'MD/1985'TVD LAS2112 18.Directional Survey: Yes 0 No E] 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1300'MD/1297'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 28' 108' 28' 108' 24" Pre-installed 9.625" 40# L-80 28' 2619' 28' 2455' 12.25" 755 sx AS Lite,238 sx Class G I 7" 26# L-80 28' 8728' 28' 7004' 8.75" 260 sx Class G,200 sx Class G 4.5" 12.6# L-80 8251' 13224' 6899' 7038' 6.125" slotted liner 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 4.5" 8258' 813716,857.1-143 slotted liner 8761'-9241'MD 7006'-7014'TVD KK """° "� 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9521'-13220'MD 7016-7038'TVD DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED z ) !:',., LIM 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RECEIVED RBrMS APR 2`8 201 4 APk r f ;f Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Qi•1eUa�'k�+adiff:74 Gas cons.tyvfl $final only „`J.// 28. GEOLOGIC MARKERS(List all formations and markers e. ,tered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1300' 1297' needed,and submit detailed test information per 20 AAC 25.071. C-30 2659' 2491' C-20 3103' 2879' K-3 4338' 3903' K-2 4560' 4082' Nanuq 6849' 5974' K-1 7837' 6700' Kuparuk C 7977' 6777' Nechelik 8671' 6997' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Rya obe o @ 265-6318 Printed Name L.Alvord Title: Alaska Drilling Manager Signature Phone 263-4619 Date 0��Z?/// 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. 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,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 pC } I a ConocoPhilli pars(Alaska) Inc. y1 Western North Slope CD3 Fiord Pad CD3-198 501032063700 1: 11: Sperr ► Drilling Definitive Survey Report 04 April, 2011 0. .41 p ta k t HALLIBURTON Sperry Dritlirsg 04 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-198 Project: Western North Slope TVD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Site: CD3 Fiord Pad MD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Well: CD3-198 North Reference: True Wellbore: CD3-198 Survey Calculation Method: Minimum Curvature Design: CD3-198 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3-198 Well Position +N/-S 0.00 ft Northing: 6,003,883.15 ft Latitude: 70°25'10.432 N +E/-W 0.00 ft Easting: 388,402.44 ft Longitude: 150°54'32.901 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50ft Wellbore CD3-198 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 3/15/2011 20.70 80.83 57,604 Design CD3-198 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.59 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (0) 27.59 0.00 0.00 142.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 81.00 1,095.00 CD3-198 Gyro(R200)(CD3-198) CB-GYRO-SS Camera based gyro single shot 3/14/2011 12:C 1,153.06 2,584.59 CD3-198 MWD(R200)(CD3-198) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/14/2011 12:C 2,682.04 7,219.13 CD3-198 MWD(R300)(CD3-198) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/16/2011 12:C 7,311.00 8,696.18 CD3-198 MWD(R400)(CD3-198) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/22/2011 12:C 8,728.58 13,069.81 CD3-198 MWD(R500)(CD3-198) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/30/2011 12:C Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 27.59 0.00 0.00 27.59 -12.50 0.00 0.00 6,003,883.15 388,402.44 0.00 0.00 UNDEFINED 81.00 0.09 117.77 81.00 40.91 -0.02 0.04 6,003,883.13 388,402.48 0.17 0.04 CB-GYRO-SS(1) 173.00 0.17 65.99 173.00 132.91 0.00 0.23 6,003,883.15 388,402.67 0.15 0.14 CB-GYRO-SS(1) 265.00 1.79 39.24 264.98 224.89 1.17 1.26 6,003,884.30 388,403.72 1.78 -0.15 CB-GYRO-SS(1) 357.00 3.32 42.19 356.89 316.80 4.26 3.96 6,003,887.35 388,406.46 1.67 -0.92 CB-GYRO-SS(1) 449.00 4.84 41.50 448.65 408.56 9.14 8.32 6,003,892.17 388,410.89 1.65 -2.08 CB-GYRO-SS(1) 541.00 6.58 54.86 540.20 500.11 15.08 15.20 6,003,898.00 388,417.86 2.37 -2.52 CB-GYRO-SS(1) 634.00 6.94 60.38 632.55 592.46 20.92 24.44 6,003,903.71 388,427.19 0.80 -1.44 CB-GYRO-SS(1) 726.00 6.60 56.56 723.91 683.82 26.58 33.69 6,003,909.23 388,436.52 0.61 -0.21 CB-GYRO-SS(1) 813.00 6.74 54.86 810.32 770.23 32.28 42.03 6,003,914.80 388,444.95 0.28 0.44 CB-GYRO-SS(1) 4/4/2011 9:21:44AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-198 Project: Western North Slope TVD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Site: CD3 Fiord Pad MD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Well: CD3-198 North Reference: True Wellbore: CD3-198 Survey Calculation Method: Minimum Curvature Design: CD3-198 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 875.00 6.94 52.47 871.88 831.79 36.69 47.98 6,003,919.08 388,450.96 0.56 0.66 CB-GYRO-SS(1) 939.00 7.59 46.43 935.37 895.28 41.92 54.11 6,003,924.26 388,457.16 1.57 0.28 CB-GYRO-SS(1) 1,002.00 9.04 38.97 997.71 957.62 48.64 60.24 6,003,930.88 388,463.39 2.86 -1.24 CB-GYRO-SS(1) 1,095.00 11.24 34.98 1,089.25 1,049.16 61.75 70.03 6,003,943.84 388,473.38 2.48 -5.54 CB-GYRO-SS(1) ` 1,153.06 11.17 32.35 1,146.20 1,106.11 71.14 76.28 6,003,953.13 388,479.77 0.89 -9.09 MWD+IFR-AK-CAZ-SC(2) 1,246.20 12.24 33.92 1,237.40 1,197.31 86.95 86.62 6,003,968.79 388,490.34 1.20 -15.19 MWD+IFR-AK-CAZ-SC(2) 1,293.23 14.55 31.42 1,283.15 1,243.06 96.13 92.48 6,003,977.88 388,496.34 5.06 -18.81 MWD+IFR-AK-CAZ-SC(2) 1,338.17 16.94 28.25 1,326.40 1,286.31 106.72 98.52 6,003,988.37 388,502.54 5.65 -23.44 MWD+IFR-AK-CAZ-SC(2) 1,383.23 18.82 24.47 1,369.29 1,329.20 119.12 104.64 6,004,000.68 388,508.84 4.90 -29.44 MWD+IFR-AK-CAZ-SC(2) 1,431.65 20.93 22.64 1,414.82 1,374.73 134.21 111.21 6,004,015.67 388,515.63 4.54 -37.29 MWD+IFR-AK-CAZ-SC(2) 1,522.99 25.20 20.84 1,498.84 1,458.75 167.45 124.41 6,004,048.71 388,529.33 4.74 -55.36 MWD+IFR-AK-CAZ-SC(2) 1,616.40 27.44 18.94 1,582.56 1,542.47 206.40 138.47 6,004,087.44 388,543.97 2.56 -77.39 MWD+IFR-AK-CAZ-SC(2) 1,661.26 29.31 14.26 1,622.04 1,581.95 226.83 144.54 6,004,107.77 388,550.34 6.47 -89.76 MWD+IFR-AK-CAZ-SC(2) 1,709.38 29.75 9.94 1,663.91 1,623.82 250.00 149.50 6,004,130.87 388,555.65 4.52 -104.96 MWD+IFR-AK-CAZ-SC(2) 1,801.13 30.22 3.82 1,743.40 1,703.31 295.47 154.97 6,004,176.25 388,561.79 3.37 -137.43 MWD+IFR-AK-CAZ-SC(2) 1,893.61 31.14 2.01 1,822.94 1,782.85 342.60 157.36 6,004,223.33 388,564.89 1.41 -173.09 MWD+IFR-AK-CAZ-SC(2) 1,985.82 29.74 0.02 1,902.43 1,862.34 389.30 158.20 6,004,270.01 388,566.43 1.87 -209.37 MWD+IFR-AK-CAZ-SC(2) 2,079.55 28.91 0.67 1,984.15 1,944.06 435.20 158.47 6,004,315.90 388,567.39 0.95 -245.38 MWD+IFR-AK-CAZ-SC(2) 2,172.31 29.58 0.95 2,065.09 2,025.00 480.51 159.12 6,004,361.19 388,568.71 0.74 -280.69 MWD+IFR-AK-CAZ-SC(2) 2,264.84 29.03 0.74 2,145.78 2,105.69 525.80 159.78 6,004,406.46 388,570.05 0.60 -315.96 MWD+IFR-AK-CAZ-SC(2) 2,356.84 28.51 1.33 2,226.42 2,186.33 570.07 160.58 6,004,450.71 388,571.51 0.64 -350.36 MWD+IFR-AK-CAZ-SC(2) 2,448.82 29.24 2.93 2,306.97 2,266.88 614.45 162.24 6,004,495.06 388,573.83 1.16 -384.31 MWD+IFR-AK-CAZ-SC(2) 2,542.16 29.15 4.00 2,388.45 2,348.36 659.90 164.99 6,004,540.45 388,577.26 0.57 -418.43 MWD+IFR-AK-CAZ-SC(2) 2,584.59 29.14 4.52 2,425.51 2,385.42 680.50 166.53 6,004,561.03 388,579.11 0.60 -433.72 MWD+IFR-AK-CAZ-SC(2) 2,682.04 28.72 2.27 2,510.80 2,470.71 727.55 169.32 6,004,608.03 388,582.61 1.20 -469.07 MWD+IFR-AK-CAZ-SC(3) 2,772.42 28.46 2.73 2,590.16 2,550.07 770.76 171.21 6,004,651.20 388,585.14 0.38 -501.96 MWD+IFR-AK-CAZ-SC(3) 2,867.59 29.02 3.22 2,673.60 2,633.51 816.46 173.59 6,004,696.86 388,588.20 0.64 -536.51 MWD+IFR-AK-CAZ-SC(3) 2,960.01 28.86 3.14 2,754.48 2,714.39 861.11 176.07 6,004,741.46 388,591.34 0.18 -570.17 MWD+IFR-AK-CAZ-SC(3) 3,052.91 29.63 2.40 2,835.54 2,795.45 906.45 178.26 6,004,786.76 388,594.21 0.92 -604.54 MWD+IFR-AK-CAZ-SC(3) 3,142.90 29.44 2.19 2,913.84 2,873.75 950.77 180.03 6,004,831.05 388,596.65 0.24 -638.38 MWD+IFR-AK-CAZ-SC(3) 3,235.96 28.83 1.33 2,995.12 2,955.03 996.06 181.43 6,004,876.30 388,598.72 0.80 -673.20 MWD+IFR-AK-CAZ-SC(3) 3,325.43 31.01 1.55 3,072.67 3,032.58 1,040.67 182.55 6,004,920.88 388,600.51 2.44 -707.67 MWD+IFR-AK-CAZ-SC(3) 3,421.12 32.41 0.40 3,154.07 3,113.98 1,090.95 183.40 6,004,971.15 388,602.11 1.59 -746.77 MWD+IFR-AK-CAZ-SC(3) 3,514.67 33.29 0.66 3,232.66 3,192.57 1,141.70 183.87 6,005,021.87 388,603.34 0.95 -786.47 MWD+IFR-AK-CAZ-SC(3) 3,607.52 33.94 359.31 3,309.98 3,269.89 1,193.09 183.85 6,005,073.26 388,604.09 1.07 -826.98 MWD+IFR-AK-CAZ-SC(3) i 3,694.15 36.21 359.24 3,380.88 3,340.79 1,242.87 183.22 6,005,123.04 388,604.20 2.62 -866.59 MWD+IFR-AK-CAZ-SC(3) 3,792.63 36.57 358.35 3,460.15 3,420.06 1,301.28 181.99 6,005,181.46 388,603.84 0.65 -913.38 MWD+IFR-AK-CAZ-SC(3) 3,885.63 36.93 358.80 3,534.67 3,494.58 1,356.91 180.61 6,005,237.09 388,603.29 0.48 -958.07 MWD+IFR-AK-CAZ-SC(3) 3,977.87 36.03 357.90 3,608.84 3,568.75 1,411.72 179.03 6,005,291.92 388,602.54 1.14 -1,002.23 MWD+IFR-AK-CAZ-SC(3) 4,070.24 35.50 357.34 3,683.79 3,643.70 1,465.66 176.79 6,005,345.88 388,601.11 0.67 -1,046.11 MWD+IFR-AK-CAZ-SC(3) 4/4/2011 9:21:44AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-198 Project: Western North Slope TVD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Site: CD3 Fiord Pad MD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Well: CD3-198 North Reference: True Wellbore: CD3-198 Survey Calculation Method: Minimum Curvature Design: CD3-198 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,162.54 35.00 357.16 3,759.16 3,719.07 1,518.87 174.24 6,005,399.12 388,599.35 0.55 -1,089 62 MWD+IFR-AK-CAZ-SC(3) 4,255.78 35.43 358.60 3,835.34 3,795.25 1,572.60 172.25 6,005,452.87 388,598.16 1.00 -1,133.18 MWD+IFR-AK-CAZ-SC(3) 4,348.69 34.79 357.90 3,911.35 3,871.26 1,626.01 170.62 6,005,506.29 388,597.33 0.81 -1,176.27 MWD+IFR-AK-CAZ-SC(3) 4,440.98 36.24 357.79 3,986.46 3,946.37 1,679.58 168.61 6,005,559.88 388,596.12 1.57 -1,219.73 MWD+IFR-AK-CAZ-SC(3) 4,531.99 37.00 357.42 4,059.51 4,019.42 1,733.82 166.34 6,005,614.15 388,594.66 0.87 -1,263.87 MWD+IFR-AK-CAZ-SC(3) 4,622.91 36.61 356.40 4,132.31 4,092.22 1,788.21 163.40 6,005,668.57 388,592.54 0.80 -1,308.53 MWD+IFR-AK-CAZ-SC(3) 4,712.90 36.49 357.10 4,204.60 4,164.51 1,841.72 160.36 6,005,722.11 388,590.30 0.48 -1,352.56 MWD+IFR-AK-CAZ-SC(3) 4,809.77 36.30 357.09 4,282.58 4,242.49 1,899.12 157.45 6,005,779.54 388,588.25 0.20 -1,399.59 MWD+IFR-AK-CAZ-SC(3) 4,903.24 36.57 357.85 4,357.78 4,317.69 1,954.58 155.00 6,005,835.03 388,586.63 0.56 -1,444.80 MWD+IFR-AK-CAZ-SC(3) 4,996.15 36.49 358.72 4,432.43 4,392.34 2,009.86 153.34 6,005,890.32 388,585.80 0.56 -1,489.38 MWD+IFR-AK-CAZ-SC(3) 5,089.16 36.58 357.87 4,507.17 4,467.08 2,065.20 151.70 6,005,945.68 388,584.98 0.55 -1,534.01 MWD+IFR-AK-CAZ-SC(3) 5,182.18 36.73 357.73 4,581.79 4,541.70 2,120.69 149.57 6,006,001.19 388,583.68 0.18 -1,579.05 MWD+IFR-AK-CAZ-SC(3) 5,274.58 35.94 357.06 4,656.23 4,616.14 2,175.38 147.08 6,006,055.91 388,582.01 0.96 -1,623.67 MWD+IFR-AK-CAZ-SC(3) 5,365.20 36.13 357.06 4,729.51 4,689.42 2,228.62 144.35 6,006,109.18 388,580.07 0.21 -1,667.31 MWD+IFR-AK-CAZ-SC(3) 5,454.54 36.14 357.53 4,801.66 4,761.57 2,281.24 141.86 6,006,161.83 388,578.37 0.31 -1,710.31 MWD+IFRAK-CAZ-SC(3) 5,549.40 36.36 358.07 4,878.16 4,838.07 2,337.29 139.71 6,006,217.90 388,577.06 0.41 -1,755.80 MWD+IFRAK-CAZ-SC(3) 5,641.79 36.50 357.78 4,952.50 4,912.41 2,392.12 137.72 6,006,272.74 388,575.89 0.24 -1,800.23 MWD+IFRAK-CAZ-SC(3) 5,737.11 35.97 357.60 5,029.38 4,989.29 2,448.42 135.45 6,006,329.07 388,574.46 0.57 -1,845.99 MWD+IFR-AK-CAZ-SC(3) 5,830.27 36.06 357.45 5,104.73 5,064.64 2,503.15 133.08 6,006,383.82 388,572.92 0.14 -1,890.57 MWD+IFR-AK-CAZ-SC(3) 5,926.13 33.92 3.22 5,183.28 5,143.19 2,558.06 133.33 6,006,438.71 388,573.98 4.11 -1,933.69 MWD+IFR-AK-CAZ-SC(3) 6,013.03 33.62 4.58 5,255.52 5,215.43 2,606.25 136.61 6,006,486.84 388,577.99 0.94 -1,969.64 MWD+IFR-AK-CAZ-SC(3) 6,105.93 32.75 8.89 5,333.28 5,293.19 2,656.72 142.55 6,006,537.22 388,584.68 2.71 -2,005.76 MWD+IFR-AK-CAZ-SC(3) 6,196.47 30.92 15.25 5,410.22 5,370.13 2,703.38 152.46 6,006,583.71 388,595.28 4.22 -2,036.43 MWD+IFR-AK-CAZ-SC(3) 6,293.61 30.29 20.42 5,493.84 5,453.75 2,750.42 167.57 6,006,630.52 388,611.09 2.79 -2,064.19 MWD+IFR-AK-CAZ-SC(3) 6,382.02 29.88 24.77 5,570.35 5,530.26 2,791.32 184.58 6,006,671.16 388,628.71 2.51 -2,085.95 MWD+IFR-AK-CAZ-SC(3) 6,476.08 29.41 31.47 5,652.12 5,612.03 2,832.30 206.46 6,006,711.81 388,651.20 3.56 -2,104.77 MWD+IFR-AK-CAZ-SC(3) 6,571.79 29.08 38.42 5,735.66 5,695.57 2,870.58 233.19 6,006,749.68 388,678.49 3.56 -2,118.48 MWD+IFR-AK-CAZ-SC(3) 6,664.31 30.14 44.93 5,816.12 5,776.03 2,904.65 263.58 6,006,783.29 388,709.38 3.66 -2,126.62 MWD+IFR-AK-CAZ-SC(3) 6,757.07 31.45 52.79 5,895.83 5,855.74 2,935.78 299.31 6,006,813.88 388,745.58 4.56 -2,129.15 MWD+IFR-AK-CAZ-SC(3) 6,849.41 32.79 60.97 5,974.07 5,933.98 2,962.50 340.38 6,006,839.98 388,787.04 4.92 -2,124.92 MWD+IFR-AK-CAZ-SC(3) 6,940.04 33.22 68.85 6,050.11 6,010.02 2,983.37 385.01 6,006,860.18 388,831.97 4.76 -2,113.89 MWD+IFR-AK-CAZ-SC(3) 7,031.07 35.13 72.58 6,125.43 6,085.34 3,000.22 433.27 6,006,876.30 388,880.47 3.11 -2,097.46 MWD+IFR-AK-CAZ-SC(3) 7,124.58 38.34 77.61 6,200.37 6,160.28 3,014.50 487.29 6,006,889.77 388,934.70 4.70 -2,075.45 MWD+IFR-AK-CAZ-SC(3) 7,219.13 40.15 82.68 6,273.61 6,233.52 3,024.68 546.19 6,006,899.07 388,993.74 3.89 -2,047.21 MWD+IFR-AK-CAZ-SC(3) 7,311.00 42.43 90.32 6,342.68 6,302.59 3,028.28 606.61 6,006,901.77 389,054.19 6.02 -2,012.86 MWD+IFR-AK-CAZ-SC(4) 7,359.82 42.92 94.41 6,378.58 6,338.49 3,026.91 639.66 6,006,899.91 389,087.22 5.77 -1,991.43 MW D+I FR-AK-CAZ-SC(4) 7,406.37 43.05 97.06 6,412.64 6,372.55 3,023.74 671.23 6,006,896.26 389,118.74 3.89 -1,969.49 MWD+IFR-AK-CAZ-SC(4) 7,496.78 44.49 100.99 6,477.94 6,437.85 3,013.91 732.97 6,006,885.51 389,180.31 3.40 -1,923.73 MWD+IFR-AK-CAZ-SC(4) 7,591.92 46.68 101.40 6,544.52 6,504.43 3,000.71 799.62 6,006,871.32 389,246.76 2.32 -1,872.29 MWD+IFR-AK-CAZ-SC(4) 7,683.54 49.66 102.82 6,605.61 6,565.52 2,986.37 866.36 6,006,855.98 389,313.27 3.45 -1,819.91 MWD+IFR-AK-CAZ-SC(4) 4/4/2011 9:21:44AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-198 Project: Western North Slope TVD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Site: CD3 Fiord Pad MD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Well: CD3-198 North Reference: True Wellbore: CD3-198 Survey Calculation Method: Minimum Curvature Design: CD3-198 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,731.86 51.14 104.91 6,636.41 6,596.32 2,977.44 902.50 6,006,846.52 389,349.27 4.53 -1,790.62 MWD+IFR-AK-CAZ-SC(4) 7,773.78 52.26 106.64 6,662.40 6,622.31 2,968.50 934.15 6,006,837.10 389,380.78 4.20 -1,764.08 MWD+IFR-AK-CAZ-SC(4) 7,828.47 53.96 109.65 6,695.23 6,655.14 2,954.86 975.71 6,006,822.85 389,422.12 5.39 -1,727.76 MWD+IFR-AK-CAZ-SC(4) 7,869.27 5529 111.54 6,718.85 6,678.76 2,943.16 1,006.84 6,006,810.68 389,453.08 4.99 -1,699.37 MWD+IFR-AK-CAZ-SC(4) 7,919.19 57.27 113.90 6,746.56 6,706.47 2,927.12 1,045.13 6,006,794.07 389,491.12 5.58 -1,663.15 MWD+IFR-AK-CAZ-SC(4) 7,961.27 58.81 115.04 6,768.84 6,728.75 2,912.33 1,077.62 6,006,778.79 389,523.39 4.32 -1,631.49 MWD+IFR-AK-CAZ-SC(4) 8,011.26 60.43 116.13 6,794.12 6,754.03 2,893.70 1,116.52 6,006,759.59 389,561.99 3.75 -1,592.87 MWD+IFR-AK-CAZ-SC(4) 8,051.11 62.35 116.60 6,813.20 6,773.11 2,878.16 1,147.86 6,006,743.59 389,593.10 4.93 -1,561.33 MWD+IFR-AK-CAZ-SC(4) 8,105.53 63.52 117.37 6,837.96 6,797.87 2,856.17 1,191.04 6,006,720.96 389,635.94 2.49 -1,517.42 MWD+IFR-AK-CAZ-SC(4) 8,145.17 64.40 117.79 6,855.36 6,815.27 2,839.68 1,222.61 6,006,704.00 389,667.26 2.42 -1,484.99 MWD+IFR-AK-CAZ-SC(4) 8,200.81 65.35 118.93 6,878.99 6,838.90 2,815.75 1,266.94 6,006,679.41 389,711.22 2.52 -1,438.84 MWD+IFR-AK-CAZ-SC(4) 8,240.92 66.65 119.76 6,895.30 6,855.21 2,797.80 1,298.88 6,006,660.98 389,742.88 3.75 -1,405.02 MWD+IFR-AK-CAZ-SC(4) 8,291.37 68.43 121.61 6,914.58 6,874.49 2,774.00 1,338.97 6,006,636.59 389,782.61 4.89 -1,361.59 MWD+IFR-AK-CAZ-SC(4) 8,333.51 70.49 123.19 6,929.36 6,889.27 2,752.86 1,372.28 6,006,614.95 389,815.60 6.02 -1,324.42 MWD+IFR-AK-CAZ-SC(4) 8,382.62 73.54 124.22 6,944.52 6,904.43 2,726.94 1,411.13 6,006,588.46 389,854.05 6.52 -1,280.08 MWD+IFR-AK-CAZ-SC(4) 8,425.78 75.77 125.54 6,955.95 6,915.86 2,703.13 1,445.27 6,006,564.15 389,887.83 5.95 -1,240.30 MWD+IFR-AK-CAZ-SC(4) 8,471.69 77.75 126.81 6,966.46 6,926.37 2,676.76 1,481.34 6,006,537.24 389,923.50 5.08 -1,197.31 MWD+IFR-AK-CAZ-SC(4) 8,515.30 79.77 128.05 6,974.96 6,934.87 2,650.76 1,515.30 6,006,510.74 389,957.07 5.41 -1,155.91 MWD+IFR-AK-CAZ-SC(4) 8,564.49 81.95 130.06 6,982.77 6,942.68 2,620.16 1,553.01 6,006,479.58 389,994.31 5.99 -1,108.59 MWD+IFR-AK-CAZ-SC(4) 8,607.96 82.57 131.33 6,988.63 6,948.54 2,592.08 1,585.67 6,006,451.01 390,026.54 3.23 -1,066.35 MWD+IFR-AK-CAZ-SC(4) 8,696.18 82.98 135.09 6,999.73 6,959.64 2,532.16 1,649.44 6,006,390.16 390,089.41 4.25 -979.87 MWD+IFR-AK-CAZ-SC(4) 8,728.58 83.47 134.66 7,003.55 6,963.46 2,509.46 1,672.24 6,006,367.12 390,111.86 2.01 -947.95 MWD+IFR-AK-CAZ-SC(5) 8,824.38 86.75 135.98 7,011.72 6,971.63 2,441.60 1,739.35 6,006,298.27 390,177.94 3.69 -853.16 MWD+IFR-AK-CAZ-SC(5) 8,918.29 89.53 135.79 7,014.76 6,974.67 2,374.22 1,804.68 6,006,229.93 390,242.25 2.97 -759.84 MWD+IFR-AK-CAZ-SC(5) 9,013.36 88.73 137.92 7,016.21 6,976.12 2,304.87 1,869.68 6,006,159.62 390,306.20 2.39 -665.17 MWD+IFR-AK-CAZ-SC(5) 9,109.61 90.82 140.03 7,016.59 6,976.50 2,232.27 1,932.85 6,006,086.08 390,368.27 3.09 -569.07 MWD+IFR-AK-CAZ-SC(5) 9,205.02 91.26 142.51 7,014.85 6,974.76 2,157.85 1,992.53 6,006,010.80 390,426.83 2.64 -473.69 MWD+IFR-AK-CAZ-SC(5) 9,301.43 89.77 142.90 7,013.99 6,973.90 2,081.16 2,050.94 6,005,933.25 390,484.08 1.60 -377.29 MWD+IFR-AK-CAZ-SC(5) 9,394.78 89.34 142.27 7,014.71 6,974.62 2,007.02 2,107.66 6,005,858.27 390,539.68 0.82 -283.95 MWD+IFR-AK-CAZ-SC(5) 9,490.38 90.02 144.06 7,015.25 6,975.16 1,930.51 2,164.97 6,005,780.92 390,595.84 2.00 -188.38 MWD+IFR-AK-CAZ-SC(5) 9,586.35 89.34 148.52 7,015.78 6,975.69 1,850.70 2,218.21 6,005,700.33 390,647.88 4.70 -92.70 MWD+IFR-AK-CAZ-SC(5) 9,681.35 88.11 148.25 7,017.90 6,977.81 1,769.82 2,268.00 6,005,618.72 390,696.45 1.33 1.68 MWD+IFR-AK-CAZ-SC(5) 9,776.78 89.53 147.05 7,019.86 6,979.77 1,689.22 2,319.05 6,005,537.38 390,746.28 1.95 96.62 MWD+IFR-AK-CAZ-SC(5) 9,871.34 89.22 145.40 7,020.89 6,980.80 1,610.63 2,371.61 6,005,458.01 390,797.66 1.78 190.92 MWD+IFR-AK-CAZ-SC(5) 9,963.52 89.10 143.80 7,022.24 6,982.15 1,535.50 2,425.01 6,005,382.10 390,849.92 1.74 282.99 MWD+IFR-AK-CAZ-SC(5) 10,055.79 88.79 141.81 7,023.94 6,983.85 1,462.02 2,480.77 6,005,307.80 390,904.58 2.18 375.23 MWD+IFR-AK-CAZ-SC(5) 10,150.77 90.02 140.55 7,024.93 6,984.84 1,388.02 2,540.31 6,005,232.93 390,962.99 1.85 470.19 MWD+IFR-AK-CAZ-SC(5) 10,246.35 89.90 140.72 7,025.00 6,984.91 1,314.13 2,600.93 6,005,158.14 391,022.50 0.22 565.74 MWD+IFR-AK-CAZ-SC(5) 10,342.21 89.59 141.57 7,025.42 6,985.33 1,239.48 2,661.07 6,005,082.61 391,081.51 0.94 661.59 MWD+IFR-AK-CAZ-SC(5) 10,437.24 89.59 142.89 7,026.10 6,986.01 1,164.37 2,719.27 6,005,006.64 391,138.58 1.39 756.62 MWD+IFR-AK-CAZ-SC(5) 4/4/2011 9:21:44AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-198 Project: Western North Slope TVD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Site: CD3 Fiord Pad ttD Reference: Rig:27.59+12.5 @ 40.09ft(D141) Well: CD3-198 North Reference: True Wellbore: CD3-198 Survey Calculation Method: Minimum Curvature Design: CD3-198 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 10,531.58 90.33 144.07 7,026 17 6,986.08 1,088.55 2,775.41 6,004,930.00 391,193 57 1.48 850.92 MVVD+IFR-AK-CAZ-SC(5) 10,626.28 90.08 145.61 7,025.83 6,985.74 1,011.13 2,829.94 6,004,851.78 391,246.94 1.65 945.50 MWD+IFR-AK-CAZ-SC(5) 10,720.20 89.34 144.30 7,026.31 6,986.22 934.24 2,883.87 6,004,774.10 391,299.71 1.60 1,039.29 MWD+IFR-AK-CAZ-SC(5) 10,815.63 90.39 144.76 7,026.53 6,986.44 856.52 2,939.25 6,004,695.57 391,353.91 1.20 1,134.63 MWD+IFR-AK-CAZ-SC(5) 10,907.56 89.59 147.32 7,026.55 6,986.46 780.28 2,990.59 6,004,618.58 391,404.11 2.92 1,226.32 MWD+IFR-AK-CAZ-SC(5) 11,001.20 89.09 146.57 7,027.63 6,987.54 701.80 3,041.67 6,004,539.35 391,453.99 0.96 1,319.61 MWD+IFR-AK-CAZ-SC(5) 11,096.96 89.28 146.16 7,028.99 6,988.90 622.08 3,094.70 6,004,458.85 391,505.83 0.47 1,415.08 MWD+IFR-AK-CAZ-SC(5) 11,191.54 89.59 143.26 7,029.92 6,989.83 544.90 3,149.33 6,004,380.86 391,559.30 3.08 1,509.54 MWD+IFR-AK-CAZ-SC(5) 11,284.93 89.10 139.97 7,030.99 6,990.90 471.71 3,207.31 6,004,306.82 391,616.17 3.56 1,602.91 MWD+IFR-AK-CAZ-SC(5) 11,378.59 88.85 138.89 7,032.66 6,992.57 400.57 3,268.21 6,004,234.79 391,676.00 1.18 1,696.46 MWD+IFR-AK-CAZ-SC(5) 11,473.72 88.79 139.24 7,034.62 6,994.53 328.72 3,330.53 6,004,162.02 391,737.23 0.37 1,791.44 MWD+IFR-AK-CAZ-SC(5) 11,566.68 89.59 143.47 7,035.94 6,995.85 256.14 3,388.56 6,004,088.59 391,794.16 4.63 1,884.36 MWD+IFR-AK-CAZ-SC(5) 11,660.93 90.27 148.02 7,036.05 6,995.96 178.26 3,441.60 6,004,009.93 391,846.02 4.88 1,978.39 MWD+IFR-AK-CAZ-SC(5) 11,755.83 90.08 147.00 7,035.76 6,995.67 98.22 3,492.58 6,003,929.14 391,895.79 1.09 2,072.85 MWD+IFR-AK-CAZ-SC(5) 11,848.96 89.71 147.53 7,035.93 6,995.84 19.88 3,542.94 6,003,850.07 391,944.97 0.69 2,165.58 MWD+IFR-AK-CAZ-SC(5) 11,943.01 89.96 147.13 7,036.20 6,996.11 -59.29 3,593.70 6,003,770.15 391,994.55 0.50 2,259.23 MWD+IFR-AK-CAZ-SC(5) 12,037.03 89.77 145.61 7,036.43 6,996.34 -137.57 3,645.77 6,003,691.11 392,045.43 1.63 2,352.97 MWD+IFR-AK-CAZ-SC(5) 12,131.96 90.33 145.23 7,036.34 6,996.25 -215.73 3,699.65 6,003,612.16 392,098.13 0.71 2,447.73 MWD+IFR-AK-CAZ-SC(5) 12,224.43 90.33 146.05 7,035.81 6,995.72 -292.06 3,751.84 6,003,535.06 392,149.17 0.89 2,540.01 MWD+IFR-AK-CAZ-SC(5) 12,319.91 90.27 144.42 7,035.31 6,995.22 -370.50 3,806.28 6,003,455.83 392,202.43 1.71 2,635.34 MWD+IFR-AK-CAZ-SC(5) 12,414.14 89.84 140.79 7,035.22 6,995.13 -445.35 3,863.50 6,003,380.14 392,258.51 3.88 2,729.54 MWD+IFR-AK-CAZ-SC(5) 12,508.06 89.03 140.77 7,036.15 6,996.06 -518.11 3,922.88 6,003,306.51 392,316.80 0.86 2,823.44 MWD+IFR-AK-CAZ-SC(5) 12,601.54 89.34 141.58 7,037.48 6,997.39 -590.92 3,981.48 6,003,232.83 392,374.30 0.93 2,916.90 MWD+IFR-AK-CAZ-SC(5) 12,695.03 88.97 143.62 7,038.85 6,998.76 -665.18 4,038.25 6,003,157.74 392,429.95 2.22 3,010.37 MWD+IFR-AK-CAZ-SC(5) 12,791.36 89.71 143.91 7,039.96 6,999.87 -742.88 4,095.19 6,003,079.21 392,485.71 0.83 3,106.64 MWD+IFR-AK-CAZ-SC(5) 12,883.79 90.33 145.74 7,039.93 6,999.84 -818.42 4,148.43 6,003,002.88 392,537.82 2.09 3,198.96 MWD+IFR-AK-CAZ-SC(5) 12,978.18 90.08 147.40 7,039.59 6,999.50 -897.19 4,200.43 6,002,923.35 392,588.63 1.78 3,293.04 MWD+IFR-AK-CAZ-SC(5) 13,069.81 90.33 148.07 7,039.27 6,999.18 -974.68 4,249.35 6,002,845.15 392,636.38 0.78 3,384.21 MWD+IFR-AK-CAZ-SC(5) 13,228.00 90.33 148.07 7,038.36 6,998.27 -1,108.93 4,333.01 6,002,709.67 392,718.02 0.00 3,541.51 PROJECTED to TD 4/4/2011 9:21:44AM Page 6 COMPASS 2003.16 Build 69 WNS CD3 198 ConocoPhiib Well Attributes IMax Angle&MD TD AIBSIiF Inc. '. Wellbore APVUWI Field Name (Wall Stats Intl(') 1MD(RKB) Act Bbn(HKB) wrc.ttNriihsr'-' 5010320637011 HORD SVC 91.26 9,205.02 13,228.0 Comment H2S(ppm) Date Annotation 'End Data KB-Gid(ft) Rig Release Data .•• i5ctlC t1 _QP3,1.9).-412 D11.2:1Pd1PM - SSSV:NIPPLE Last WO: 4/6/2011 —_- ScTatic-Aaatg__ ,� -Annotation Depth(RKB) End Date Annotation Last Mod.. End Date Last Tag: Rev Reason:NEW WELL Imosbor 4/16/2011 ,... tem Casing Strings HANGER,18 Casing Description String 0... String ID...Top(PoCB) Set Depth(f...Sat Depth(ND)...String Wt...String...String Top That '. CONDUCTOR 16 15.062 28.0 108.0 108.0 62.50 WELDED Casing Description String 0... String ID...Top IRKBI Set Depth(L.Set Depth(TVD) -String Wt...String...String Tap Thrd '.- __ SURFACE 9 5/8 8.835 27.9 2618.7 2,455.3 40.00 L-80 BTCM Casing Description String 0... String ID...Top(ft1B) Sat Depth(L..Sat Depth(ND)...String Wt...String...String Top Thrd , Casing INTERMEDIATE 7 6.276 23.9 8,728.0 7,003.5 26.00 L-80 BTC-m : ng_- _._ _..._.. Description String 0... String ID...Top(MB) Set Depth(f...SM Depth(ND) String Wt...String...String Top That SLOTTED LINER 41/2 3.958 8,251.7 13,224.0 7,038.4 1260 L-80 SLHT 11P1 Liner Details Top Depth (TVD) Top Incl Nomi... Top(11KB) (RK81._, C) Item Description Comment ID(in) 8,251.7 6,898.7 66.49 SLEEVE BAKER'HRD'SETTING SLEEVE 4.380 8,263.9 6,903.9 67.09 NIPPLE BAKER'RS'NIPPLE 4.250 CONDUCTOR, __ ,2 28,108 S. 5,266.5 6,904.9 67.21 HANGER BAKER DG FLEX LOCK LINER HANGER 5.000 8,275.6 6,908.6 67.66 XO BUSHING BAKER CROSSOVER BUSHING 3.950 Tubing Strings Tubing Description Siring 0... String ID...Top(HKB) Set Depth(f...Set Depth(ND) String Wt...Str g..String Top That TUBING 4 1/2 3.958 17 6 I 8,257 9 I 6,901 4 12 60 , L-80 L_-_ IBT-M NIPPLE.2.093 41,--• CompletionDetails 1111r,': Top Depth (ND) Top Incl Mond... i.: T,, Bl Ifbce) (9 lam Descri•r.n Comment ID(in) 17.6 176 -0.02 HANGER FMC 4-12"x 11"TUBING HANGER(10.85 OD) 3.958 2,092.9 1,996 4 30.05 NIPPLE CAMCO"DB"LANDING NIPPLE 3.813 8,134-- 6,851 9 6422 PACKER BAKER PREMIER PRODUCTION PACKER(4-1/2"TCII box-pin) 3.870 1;' 8,196.1 6,877.0 65.20 NIPPLE HES"XN"IBT-M NIPPLE 3.725 I ACE I ! • 8,247.2 6,896.8- 66.27 FLUTED SHEAR PIN FLUTED NO GO SUB NO-GO UR3.725 gi S 28F2,8 9 - 7 8,256.9 6,901.0 66.74 WLEG WIRELINE ENTRY GUIDE 3.970 ; Perforations&Slots Shot 'I',; Top Top(TVD) Bhri(TVD) Dens Top MKS)Sim MKS) (HKB) (RKB) Zone Data Oh-_..Type ._... Comment_ Ci 8,761.0 9,241.0 7,006.1 7,014.4 4/32011 32.0 Slots Alternating Blank Pipe/Slots 1/8x2.25",8 slots/row,4 rows/ft;no i slots 3'from box/pin GAS LIFT. - - - 8,033 9,521.0 13,2220.0---7,016.0 7,038.4 4/3/2011 32.0 Sias Alternating Blank Pipe/Slots 1/8x2.25",8 slots/row,4 rows/ft;no U slots 3'from box/pin lir Notes:General&Safety-Z. End Date Annotation 4/16/2011 NOTE View schematic w/Alaska Schematic9.0 PACKER,8,137- _._ __ NIPPLE,8,196-- is, FLUTED ,,i,:,- NO-GO, NO-GO,8,247 ,:, if;. WLEG,8,257---- �. LA , I i Mandrel Details TopDepth Top I Port NTERMEDIATE, (NO) Incl OD Valve Latch SW, TRO Run 24-8,726 Stn Top IRKBI MKS) () Make Model (in) Seer Type Typo (1n) (psi) Run Date Can... 1 8,032.8 6,804.4 61.47 CAMCO KBG-2 1 GAS LIFT OV BK-5 0.250 0.0 4/10/2011 Bl241 8,761-5,211 1 td= 1 I i a Slots, 9,621-13,220 i 1 w SLOTTED LINER.I\ 8,252-13,224 10, -- i-'s TD,13,228 -- i-�� Conoco Phillips Time Log & Summary Weliview Web Reporting Report Well Name: CD3-198 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 3/12/2011 8:00:00 AM Rig Release: 4/6/2011 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/11/2011 24 hr Summary Rig was released f/CD3-199 @ 1500 hrs on 3/11/2011 to move to CD3-198. Move will be 19.47'.Continue to blow down water and steam lines. Peak Oilfield moving pipe shed, rock washer,boilers, motors, pumps and pit complex's. Peak Oilfield moving sub off the hole w/2 cats. Move rig mats from around well/cellar. Pick up herculite secondary containment.SIMOPS:Allow a wellhouse to be installed on well CD3-301. Lay herculite secondary containment around CD3-198,set matting boards for the sub.Spot sub over the hole. Start laying matting boards f/other complex's to be set on. 15:00 16:00 1.00 r MIRU MOVE RURD P Continue to blow down water and steam lines. 16:00 17:30 1.50 MIRU MOVE MOB P Peak Oilfield moving pipe shed, rock washer, boilers, motors, pumps and pit complex's. 17:30 18:00 0.50 MIRU MOVE MOB P Peak Oilfield moving sub off the hole w/2 cats. 18:00 18:45 0.75 MIRU MOVE RURD P Move rig mats from around well/cellar. Pick up herculite secondary containment. 18:45 19:45 1.00 MIRU MOVE OTHR P SIMOPS:Allow a wellhouse to be installed on well CD3-301. 19:45 22:45 3.00 MIRU MOVE PSIT P Lay herculite secondary containment around CD3-198,set matting boards for the sub. 22:45 23:30 0.75 MIRU MOVE PSIT P Spot sub over the hole. 23:30 00:00 0.50 MIRU MOVE PSIT P Start laying matting boards f/other complex's to be set on. 03/12/2011 Con't w/rig move f/CD3-199 to CD3-198(19.47'move). RU. Rig accepted at 0800 hrs 3/12/2011. NU riser and flowline.Transfer mud into pits. Rig on Hi-Line @ 0830 hrs. PU BHA tools to floor, PU/MU/stand back 20 stands of 5"dp&8 stands of 5"HWDP.Clear floor of 4"tools, PU tools f/beaver slide. PJSM. MU cleanout BHA#1 to drill to 230+/-', so as to have room to make up BHA w/MWD tools. RU Sperry Sun Gyro tools. Tag w/BHA @ 106' RKB. Fill hole w/mud, check f/leaks. Pressure test mud lines to 3500 psi-OK. Spud @ 1930 hrs 3/12/2011. Drill w/5k WOB,60 rpm,2k ft lbs of torque. Pumping 443 gpm w/500 psi, motor turning 115 rpm(.26 rev/gal). Drill f/106'to 229'. Run gyro survey @ 80'and 171'. POOH f/229'to 40'to MU BHA#2. ✓ MU BHA#2 f/40'to 85'. 00:00 02:30 2.50 0 0 MIRU MOVE PSIT P Rig move to CD3-198:Shim to level sub. Laying matting boards f/other complex's to be set on. Move and spot pits, pumps, motors,and boiler complex's. 02:30 04:30 2.00 0 0 MIRU MOVE PSIT P Lay down herculite secondary containment.Spot rock washer and pipe sheds. 04:30 06:00 1.50 0 0 MIRU MOVE RURD P Rig up service lines(steam,air, water,glycol, electric service lines). 06:00 08:00 2.00 0 0 MIRU MOVE RURD P Rig up:Working on rig acceptance check list. Rig accepted @ 0800 hrs 3/12/2011. Rig on Hi-Line at 0830 hrs 3/12/2011. Page 1 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:30 1.50 0 0 MIRU WHDBO NUND P Nipple up surface riser and flowline eauipment. Load pipe shed w/5"drill pipe. 09:30 11:30 2.00 0 0 MIRU DRILL RURD P Spot Sperry Sun Gyro unit by the beaver slide.Transfering spud mud into the pits. 11:30 12:00 0.50 0 0 MIRU DRILL PULD P Pick up BHA components to the floor. 12:00 13:45 1.75 0 0 MIRU DRILL PULD P Continue to pick up BHA components to the floor, rig up in the cellar. Rig up to pick up 5"drill pipe. Measure rig floor elevations. 13:45 16:30 2.75 0 0 MIRU DRILL PULD P Pickup/Make up/Stand back 60 jts (20 stands)of 5"dp,and 24 joints of 5"HWDP(8 stands). 16:30 17:00 0.50 0 0 MIRU DRILL PULD P Clear floor of 4"tools,PU tools f/ beaver slide. 17:00 17:15 0.25 0 0 MIRU DRILL SFTY P Pre job safety meeting 17:15 19:00 1.75 0 0 SURFA( DRILL PULD P Make up cleanout BHA#1 to drill to 230+/-',so as to have room to make up BHA w/MWD tools. 19:00 19:15 0.25 0 0 SURFA( DRILL RURD P Rig up Sperry Sun Gyro tools. 19:15 19:30 0.25 0 0 SURFA( DRILL PRTS P Run in and tag w/BHA @ 106'RKB. Fill hole w/mud,check f/leaks. Pressure test mud lines to 3500 psi. 19:30 22:00 2.50 0 229 SURFA( DRILL DDRL P Spud 1930 hrs 3/12/2011. Drill w/ 5k WOB,60 rpm,2k ft lbs of torque. Pumping 443 gpm w/500 psi, motor turning 115 rpm(.26 rev/gal). Drill f/ 106'to 229'. 22:00 22:15 0.25 229 229 SURFA( DRILL SRVY P Blow down the top drive. Run gyro survey's @ 80'and 171'. 22:15 22:45 0.50 229 40 SURFA( DRILL TRIP P POOH w/BHA#1 f/229'to 40'. 22:45 00:00 1.25 40 85 SURFA( DRILL PULD P MU BHA#2 f/40'to 85'. 03/13/2011 Upload Sperry Sun MWD.Con't to MU BHA#2 f/85'to 185'.Attmept to gyro.While installing line wiper,a teflon wiper insert fell into the BHA. LD the jars and(2)NM flex DC's, UBHO sub and float sub. Did not find insert on top of pulsar.MU BHA f/85'to 185'. Rabbit components with a 2.187"drift while PU. MU float sub, UBHO sub,(2)NM flex DC's,jars. Note: Found wire line wiper teflon insert(2-1/2"x 1"x 1/2")when the jars were being picked up from the skate to the rig floor. Rabbit knocked the insert out. Run gyro survey @ 185'. Directional drill 12-1/4"surface hole f/229'to 1475'(1454'TVD)w/gyro surveys. Notified by RTO that we are done w/gyro surveys @ 1373', rigged them down on a connection @ 1382'@ 2230 hrs 3/13/2011. 00:00 00:30 0.50 85 85 SURFA( DRILL PULD P Upload Sperry Sun MWD. 00:30 01:00 0.50 85 185 SURFA( DRILL PULD P Continue to MU BHA#2 f/85'to 185' (Orient sub, (2)NM flex DC's,Jars). 01:00 01:15 0.25 185 185 SURFA( DRILL SRVY P Attmept to gyro.While installing line wiper, a teflon wiper insert fell into the BHA. 01:15 02:00 0.75 185 89 SURFA( DRILL PULD T Laying down BHA to find wiper element. Layed down the jars and(2) NM flex DC's. Page 2 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:00 1.00 89 89 !SURFA( DRILL OTHR P Daylight savings time.Advance clocks ahead 1 hr. 03:00 03:30 0.50 89 85 SURFA( DRILL PULD T Continue laying down BHA to find wiper element. Layed down the UBHO sub and float sub. Did not find insert on top of pulsar. 03:30 04:15 0.75 85 185 SURFA( DRILL PULD T Make up BHA f/85'to 185'. Rabbit components with a 2.187"drift while picking up. Make up float sub, UBHO sub, (2)NM flex DC's,jars. Note: Found wire line wiper teflon insert(2-1/2"x 1"x 1/2")when the jars were being picked up from the skate to the rig floor.The rabbit knocked the teflon insert out. 04:15 04:30 0.25 185 185 SURFA( DRILL SRVY T Run gyro survey @ 185'. 04:30 12:00 7.50 229 642 SURFA( DRILL DDRL P Directional drill 12-1/4"surface hole f/ 229'to 642'(641'TVD),with gyro surveys. KOP 229'.ADT 3.95 hrs, AST 2.68 hrs. Jar hrs 50.61. Drill w/ 15-20 WOB, pumping 490 gpm w/ 1300 psi. Rotating 50 rpm and motor turning 127 rpm. PU wt 70k, SO wt 65k, Rot wt 75k.Torque on 3k ft lbs, torque off 1k ft lbs. 12:00 00:00 12.00 642 1,475 SURFA( DRILL DDRL P Directional drill 12-1/4"surface hole f/ 642'to 1475'(1454'TVD),with gyro surveys.ADT 5.59 hrs,AST 2.56 hrs.Jar hrs 56.2.Drill w/15-25 WOB, pumping 490-506 gpm w/1300-1600 psi. Rotating 50-60 rpm and motor turning 127-131 rpm. PU wt 90k,SO wt 89k, Rot wt 87k.Torque on 3-4k ft lbs,torque off 1-2k ft lbs. Note: RTO notified us we are done w/gyro surveys @ 1373', Rigged down on connection @ 1382'@ 2230 hrs. 03/14/2011 Directional drill 12-1/4"surface hole f/1475'to 2630'(2465'TVD). Circulate BU, backream out f/2630'to 922'. monitor well-static, RIH f/922'to 2607',tagged 23'fill,ream to bottom.Circulate and weight up f/9.8 ppg to 10 ppg, backreaming and setting back stands to 2344'. Blow down the top drive, RIH f/2344'to 2630', monitor well-static, POOH f/2630'to 922'(no problems), monitor well @ the 5"HWDP-static, continue to POOH 6 stands of 5"HWDP to 738'. 00:00 12:00 12.00 1,475 2,507 SURFA( DRILL DDRL P Directional drill 12-1/4"surface hole f/ 1475'to 2507'(2358'TVD).ADT 7.55 hrs,AST 1.5 hrs. Jar hrs 56.2.Drill w/ 15-35 WOB, pumping 506 gpm w/ 1600-1900 psi. Rotating 50-80 rpm and motor turning 131 rpm. PU wt 107-111k,SO wt 97-101k, Rot wt 103-106k.Torque on 4-6k ft lbs, torque off 2-5k ft lbs. Page 3 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:15 1.25 2,507 2,630 SURFA( DRILL DDRL P Directional drill 12-1/4"surface hole f/ 2507'to 2630'(2465'TVD).ADT 1.27 hrs,AST 0 hrs.Jar hrs 65.02. Drill w/ 25-35 WOB, pumping 506 gpm w/ 1900-1950 psi. Rotating 80 rpm and motor turning 131 rpm. PU wt 111k, SO wt 100k, Rot wt 106k.Torque on 5k ft lbs,torque off 3k ft lbs. 13:15 13:45 0.50 2,630 2,630 SURFA( DRILL CIRC P Circulate BU,pumping 600 gpm w/ 2250 psi, rotate 80 rpm w/3k ft lbs of torque. PU wt 95k. 13:45 17:15 3.50 2,630 922 SURFA( DRILL REAM P Back ream out of the hole f/2630'to 922'. From 2630'to 1289': Pumping 600 gpm w/2200 psi, rotating 80 rpm w/3k ft lbs. From 1289'to 922': Pumping 500 gpm w/1450 psi, rotate 80 rpm w/2-3k ft lbs of torque. PU wt 82k,SO wt 80k.Calculated fill 13.5 bbls, actual 15 bbls. No problems encountered. 17:15 17:30 0.25 922 922 SURFA( DRILL OWFF P Blow down the top drive.Monitor well-static. 17:30 18:30 1.00 922 2,630 SURFA( DRILL TRIP P RIH f/922'to 2607',tag 23'fill @ 2607', ream to bottom @ 2630'. Hole took 15k wt @ 1810',2140',2290'. PU wt 105k, SO wt 92k.Calculated displacement 13.5 bbls,actual 13.5 bbls. 18:30 21:30 3.00 2,630 2,344 SURFA( DRILL CIRC P Circulate and weight up f/9.8 to 10 ppg. Stand back a stand every 30-45 min. Rotate 80 rpm w/3k ft lbs of torque.Worked up hole to 2344' while circulating. Blow down the top drive. 21:30 21:45 0.25 2,344 2,630 SURFA( DRILL TRIP P Run in the hole on elevators f/2344' to 2630', no fill. no problems. 21:45 22:00 0.25 2,630 2,630 SURFA( DRILL OWFF P Monitor well f/20 minutes-static. 22:00 23:15 1.25 922 922 SURFA( DRILL TRIP P POOH on elevators to run 9-5/8" casing. Pull f/2630'to 922', no overpull observed. Monitor well @ HWDP-static.Calculated displacement 14 bbls,actual 19.25 bbls. 23:15 00:00 0.75 922 738 SURFA( DRILL TRIP P Continue to trip out.Stand back 6 stands of 5"HWDP. Calculated displacment, 10.02 bbls, actual 10.02 bbls. Page 4 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/15/2011 24 hr Summary POOH UD BHA to 83',download MWD,con't to UD BHA, clean floor, L/D tools f/floor, PJSM, RU to run 9-5/8"casing, PJSM, Run 9-5/8"40 ppf L-80 BTC-m casing shoe track to 105',circ through float equipment, con't to run 9-5/8"36 ppf J-55 casing to 1175',then con't to run 40 ppf L-80 BTC-m casing to 2505',circ 68 bbl during crew change,con't to run last two joints(jt#62 in the hole), MU FMC hanger, RIH land @ 2618.68'. R/D Frank's tool, RU Dowell cement head and lines. Break circ,stage up to 7 bpm while conditioning mud f/ cement job while reciprocating 11'. Reduced PV/YP to 50/21 w/10 ppg mud weight. PJSM. Pump 90 bbls of 10 ppg mud w/7.5 ppb nut plug,follow w/ 24 bbls biozan preflush w/5.7 ppb nut plug.Switch over to Dowell and pump 5 bbls of water, press test lines to 3500 psi. Drop bottom plug and pump 40 bbls of MudPush II spacer @ 10.9 ppg. Pump 276 bbls of LiteCrete lead cement followed by 49 bbls Alpine tail cement. Drop top plug and kick out w/20 bbls of water using Dowell. Displace cement w/rig mud pump#2 and 10 ppg mud. Bumped plug @ 1727 strokes(173.56 bbls)and pressure up to 1400 psi. Hold pressure f/5 minutes. CIP @ 1752 hrs 3/15/2011. Landed hanger on landing ring 9.5 bbls before good 11 ppg cement was to surface. Circulated 114 bbls of good 11 ppq cement to surface. Blled off pressure, check floats-good. PJSM, R/D cementing and casing running equipment. PJSM,then nipple down riser and FMC adapter,flush annular of cement. Clear a line of sight to align wellhead to mark on VSM. Nipple up FMC Gen ll wellhead,torque lock down screws to 450 ftlbs.Test metal to metal seals to 1000 f/10 minutes.Witness of test by rig supervisor. Obtain RKB measurements to lockdown screws. 00:00 01:00 1.00 738 83 SURFA( DRILL PULD P POOH UD 6 jts of 5"HWDP,jars,2 NM flex drill collars, UBHO and float sub f/738'to 83'. 01:00 01:30 0.50 83 83 SURFA( DRILL OTHR P Download Sperry Sun MWD. 01:30 02:30 1.00 83 0 SURFA( DRILL PULD P Continue to L/D BHA f/83'. Break bit and drain motor. Calc fill f/trip 30 bbls,actual 39 bbls. 02:30 03:00 0.50 SURFA( DRILL PULD P Clean floor. 03:00 03:15 0.25 SURFA( DRILL PULD P Lay down Sperry Sun tools from the floor. 03:15 03:30 0.25 SURFA( CASING SFTY P Pre job safety meeting on rigging up to run 9-5/8"casing. 03:30 04:45 1.25 SURFA( CASING RURD P Rig up casing running tools for 9-5/8" casing. 04:45 05:00 0.25 SURFA( CASING SFTY P Pre job safety meeting on running 9-5/8"40 ppf L-80 BTC-m and 36 ppf J-55 BTC casing. 05:00 05:45 0.75 0 105 SURFA( CASING RNCS P Run 9-5/8"casing: MU 9-5/8"casing shoe track as per detail: Rays Oil tool float shoe joint,thread lock joint, HES Sure Seal II float collar joint.All Baker Locked. 05:45 06:00 0.25 105 120 SURFA( CASING CIRC P Circulate through float equipment using Frank's fillup tool w/9-5/8" shoe above conductor shoe @ 108'. Circulate 3 bpm-150 psi-40%Totco flow,4 bpm-200 psi-46%Totco flow, 5 bpm-250 psi-48%Totco flow and 6 bpm-300 psi-49%Totco flow. Page 5 of 33 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:00 08:45 2.75 120 1,422 SURFA( CASING RNCS P Continue running casing to 1422'(JT #34 in the hole). Baker locked the 4th jt pin end.MU torque 10,000 ft lbs f/40 ppf L-80 and 8000 f/36 ppf J-55.The first 3 jts were 40 ppf L-80, #4-#28 were 36 ppf J-55.All pipe after jt#28 was 40 ppf L-80. Installed centralizers per plan: 10' above shoe over a stop ring,collar of jt#1, 10'below box of jt#2 over a stop ring. Every collar to jt#13,then every odd joint to jt#61. Used Run-N-Seal dope on the threads. 08:45 09:45 1.00 1,422 1,465 SURFA( CASING CIRC P Circulate 200 bbls(surf-surf), reciprocate f/1422'to 1465'(JT#35 in the hole). Initial PU wt 90K SO wt 61k.After circulating PU wt 85k,SO wt 75k. Step rate up f/3.5 bpm w/ 300 psi.After pumping 70 bbls, increase to 4 bpm w/250 psi.After pumping 90 bbls, increase rate to 5 bpm w/300 psi.After pumping 120 bbls, increase rate to 6 bpm w/400 psi. Pumped a total of 200 bbls. 09:45 11:30 1.75 1,465 2,468 SURFA( CASING RNCS P Continue to run 9-5/8"casing f/1465' to 2468'(jt#60 in the hole). 11:30 12:00 0.50 2,468 2,505 SURFA( CASING CIRC P Circulate 68 bbls on jt#60 during crew change. Reciprocate f/2475'to 2505'. Pumping 3 bpm w/300 psi. PU wt 127k, SO wt 94k. Calculated displacement to 2468'was 29.9 bbls, actual was 20 bbls. 12:00 12:15 0.25 2,505 2,618 SURFA( CASING RNCS P Continue to run 9-5/8"casing f/2505' to 2585'(jt#62 in the hole). Make up FMC hanger and landing joint. Run in the hole, land on hanger w/ shoe @ 2618.68'. SO wt 93k. PU wt 123k. 12:15 12:30 0.25 2,618 2,618 SURFA( CASING RURD P Rig down Frank's fillup tool. Blow down the top drive. 12:30 12:45 0.25 2,618 2,618 SURFA( CEMEN"CMNT P Rig up Dowell cement head and lines. 12:45 14:45 2.00 2,618 2,618 SURFA( CEMEN"CIRC P Circulate and condition mud. Stage pumps up f/2 bpm w/250 psi to 7 bpm w/450 psi. Final mud properties: 10 ppg, PV/YP 50/21, Gels: 10 second=4, 10 min=11,30 min= 16. Initial PU wt 123k, SO wt 95k.After circulating, PU wt 120k, SOwt 104k. Pre job safety meeting f/cementing while circulating. Page 6 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 15:00 0.25 2,618 2,618 SURFA( CEMEN"CIRC P Pump 90 bbls 10 ppg mud w/nut plug marker(7.5 ppb)@ 7 bpm w/ 450 psi. Next pumped 24 bbls of 8.34 ppg Biozan preflush w/nut plug marker(5.7 ppb)@ 7 bpm w/450 psi. Reciprocated 15'to 20'. PU wt 123k, SO wt 95k. 15:00 17:15 2.25 2,618 2,618 SURFA( CEMEN"CMNT P Dowell pump 5 bbls of water and pressure test lines to 3500 psi,good. Bleed off pressure and drop bottom plug. Mix and pump 40 bbls of Mud Push II spacer(10.9 ppg), pump @ 4.5 bpm w/400 psi. Mix and pump 276 bbls(755 sx)Lite Crete cement (11 ppq,2.05 cuft/sx,7.344 qal/sx water), pump @ 4.8 bpm w/final 644 7" "4 • psi. Mix and pump 49 bbls(238 sx) Alpine tail cement(15.8 ppg, 1.16 7�"" cuft/sx,5.105 gal/sx),pump @ 4.5 bpm w/640 psi. Shut down and drop GJV► top plug. 17:15 18:00 0.75 2,618 2,618 SURFA( CEMEN"DISP P Dowell kick out plug w/20 bbls of water,pump @ 5 bpm w/55 psi. Rig displace cement with mud pump#2 and 10 ppg mud. Pump @ 7 bpm w/ initial circulating pressure of 300 psi. After pumping 170 bbls, slowed rate to 3 bpm w/600 psi. Bump plug at 1727 strokes, pressure to 1400 psi. Hold 5 min. Bled off pressure to check floats. Floats are holding.CIP @ 1752 hrs 3/15/2011. Note: Reciprocated until 500 strokes into mud displacement. Landed hanger on landing ring 9.5 bbls before good cement returns to surface. Final SO wt 95k.Circulated 114 bbls of good 11 ppg cement to surface. 18:00 18:15 0.25 2,618 2,618 SURFA( CEMEN"SFTY P Pre job safety meeting on rigging down cementing equipment. 18:15 21:00 2.75 2,618 0 SURFA( CEMEN"RURD P Blow down cemeting lines. Rig down Dowell cement head, rig down hoses. Back out and lay down FMC landing joint. Rig down casing tools. Clear floor of casing tools and cementing equipment. 21:00 21:15 0.25 0 0 SURFA(WHDBO SFTY P Pre job safety meeting on nipple down. 21:15 22:15 1.00 0 0 SURFA(WHDBO NUND P Nipple down riser and FMC adapter/starter head. Flush annular element of cement. Clear area in the line of sight to align wellhead to the mark on the VSM. Pepare hanger f/ wellhead installation. Page 7 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 00:00 1.75 0 0 SURFA(WHDBO NUND P Nipple up FMC Gen II wellhead. Tighten lockdown screws to 450 ft lbs of torque.Aligned wellhead outlet with scribe line on the VSM.Test the metal to metal seals to 1000 psi f/10 minutes.Witness of test by rig supervisor.Obtain RKB to lockdown screw measurements. Rig floor to upper LD screws 21.53', lower LDS 24.57',top of starting head 27.87'. 03/16/2011 NU BOPE, RU,Test BOPE(witness of test waived by AOGCC inspector Jeff Jones)(upper IBOP on top drive failed test @ 250 psi, all other tests completed), PJSM, Change out IBOP and install actuator,test upper IBOP to 250 psi low and 3500 psi high, Rig down BOPE test equipment, install 9-7/8"ID FMC wear bushing. Install drilling bales on the top drive,clear floor, PU BHA components to floor. Make up BHA#3 to 133', slack off to 66', upload MWD,continue to make up BHA#3 to 164', shallow test MWD, pumping 447 gpm w/ 912 psi, blow down the top drive. _ 00:00 00:15 0.25 0 0 SURFA(WHDBO SFTY P Pre job safety meeting on nippling up BOPE. 00:15 03:00 2.75 0 SURFA(WHDBO NUND P NU 13-5/8"BOPE. 03:00 04:00 1.00 SURFA(WHDBO BOPE P Rig up to test BOPE. 04:00 04:15 0.25 SURFA(WHDBO BOPE P Fill hole. Flood choke manifold and BOP stack w/water.Check f/leaks, OK. 04:15 08:00 3.75 SURFA(WHDBO BOPE P Test BOPE.Witness of test waived by AOGCC inspector Jeff Jones.All tests charted for 5 minutes.Tested annular to 250 psi low and 2500 psi high.Tested al valves in the choke manifold,choke line, kill line,4" demco valve on mud line,floor safety valve, IBOP,top drive automatic and manual IBOP valves, upper pipe rams(6"x 3-1/2"variable bore), blinds, lower pipe rams(5"x 2-7/8" variable bore)to 250 psi low and 3500 psi high. Pipe rams and annular tested w/5"test joint. Performed accumulator test: initial system pressure was 3000?psi, pressure after closure was 1800 psi. Build up 200 psi in 35 seconds and full charge in 2 min 58 seconds. Nitrogen bottles(5)average 2220 psi.Tested PVT and gas alarms. Upper IBOP automatic failed @ low test,wil replace and will re test. 08:00 08:15 0.25 SURFA(WHDBO SFTY P Pull 5"test joint. Pre job safety meeting on changing out upper IBOP valve on the top drive. 08:15 13:15 5.00 SURFA( RIGMNT RGRP T Change out upper IBOP on the top drive.Connect actuator. 13:15 14:15 1.00 SURFA(WHDBO BOPE T Test upper IBOP valve to 250 psi low and 3500 psi high. Chart test. Hold each test f/5 minutes. Page 8 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 15:00 0.75 SURFA(WHDBO RURD P R/D BOPE testing eauioment. Install wear bushing(9-7/8"ID). Install drilling bales to top drive. Rig up to pick up 5"dp via mouse hole. 15:00 15:15 0.25 SURFA( DRILL SFTY P PJSM on picking up dp. 15:15 19:30 4.25 SURFA( DRILL PULD P PU then MU 150 joints(50 stands)of 5"drill pipe, rack back in the derrick. Rabbit to 2-3/4". 19:30 20:30 1.00 SURFA( DRILL PULD P Clear floor, Pick up BHA f/the beaver _slide. Prepare to work BHA. 20:30 22:00 1.50 0 133 SURFA( DRILL PULD P Make up BHA#3: Hughes 8-3/4"bit, 7"SperryDrill mtr w/1.5 deg bend, NM integral blade stab, NM float sub, DM collar, EWR-P4 collar, DGR collar, PWD, HCIM,ALD, CTN, BAT, TM to 133',slack off to 66'. 22:00 23:00 1.00 133 133 SURFA( DRILL PULD P Upload MWD @ 66'. Slack off to _133'. 23:00 23:15 0.25 133 164 SURFA( DRILL PULD P Continue w/BHA#3:Make up a flex NMDC to 164'. 23:15 00:00 0.75 164 164 SURFA( DRILL DHEQ P Shallow pulse test MWD @ 164'. Pumping 447 gpm w/912 psi-41% flow out. Blow down the top drive. 03/17/2011 PJSM, Load RA sources,Con't to MU BHA#3 f/164'to 780'. PJSM, PU/MU single in w/51 jts of 5"dp to 2355, Circulate for casing test. RU/Perform casing test f/30 minutes w/chart recorder.Test to 2585 psi-lost 35 psi-good test. PJSM,then cut 163'of 1-1/4"drilling line. Service rig.Trip in f/2355'to tag wiper rubbers on top of the float collar @ 2535'. Drill cement wiper plugs,float collar(2535'), cement to float shoe bttm @ 2618.65'.Clean out rat hole from 2618.68'to 2630'MD(2465.2'TVD). Drill 8-3/4"f/2630'to 2650'MD. Displace mud f/9.6 ppg to New 9.6 ppg LSND mud. Flow check-static. POOH to 2600', RU/Perform FIT to 18.1 ppg. using 9.6 ppg mud and 1085 psi applied surface pressure. 9-5/8"shoe @ 2618.68'MD(2455.1' TVD). R/D, blow down.trip f/1600'to 2650'. Directional drill 8-3/4"intermediate hole f/2650'to 4018'(3640' TVD). Pumped 35 bbl hi vis sweeps @ 3185', pumped 35 bbl nut plug(10ppb)hi vis sweeps @ 3480'and 3745'. 00:00 00:15 0.25 164 164 SURFA( DRILL SFTY P Pre job safety meeting on loading RA sources.Then load sources. 00:15 01:15 1.00 164 780 SURFA( DRILL PULD P Continue w/BHA#3:Make up 2 more flex NMDC, Run a stand of 5" HWDP, PU/MU Weatherford 6-1/4"x 2-1/4"jars(ser#1622-0445). Run 5 more stands of 5"HWDP f/derrick, lay down a single HWDP. 01:15 01:30 0.25 780 780 SURFA( DRILL SFTY P Pre job safety meeting on picking up/ Make up/single in the hole 5"dp f/ pipe shed. 01:30 02:45 1.25 780 2,355 SURFA( DRILL PULD P PU/MU/single in the hole 51 joints of 5"dp(17 stands)to 2355'. 02:45 03:45 1.00 2,355 2,355 SURFA( DRILL CIRC P Circulate and condition mud for casing test.Circulate 257 bbls. Rot wt 95k. Pump @ 5 bpm w/500 psi-35%Totco flow out, rotate 30 rpm w/4k ft lbs of torque. Reciprocate f/2355'to 2262'. 03:45 04:00 0.25 2,355 2,355 SURFA( DRILL OTHR P Blow down the top drive. 04:00 04:15 0.25 2,355 2,355 SURFA( DRILL RURD P Rig up to test casing. Page 9 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 05:00 0.75 2,355 2,355 SURFA( DRILL PRTS P Test 9-5/8"40 ppf L-80 and 36 ppf J-55 casing to 2585 psi. Pumped 21 strokes(2.1 bbls). Chart test f/30 minutes. Lost 35 psi-good test. Tested lower annulus valve while testing(inside valve shut,outside valve open to atmosphere). 05:00 05:15 0.25 2,355 2,355 SURFA( DRILL RURD P Rig down testing equipment. Blow down lines. 05:15 05:30 0.25 2,355 2,355 SURFA( DRILL SFTY P PJSM on slipping and cutting drilling line. 05:30 06:30 1.00 2,355 2,355 SURFA( RIGMNT SVRG P Hang top drive. Slip and cut 163'of 1-1/4"line. 06:30 07:00 0.50 2,355 2,355 SURFA( RIGMNT SVRG P Service rig. 07:00 07:30 0.50 2,355 2,535 SURFA( DRILL TRIP P Trip in the hole f/2355'-2447'. Make a top drive connection.Wash and ream f/2447',tag the wiper rubbers on top of the float collar @ 2535.8'. Rotate 30 rpm w/4k ft lbs of torque. Pumping 260 gpm w/600 psi. 07:30 09:00 1.50 2,535 2,630 SURFA( CEMEN-DRLG P Drill cement wiper plugs,float collar (2535'),cement to float shoe bottom @ 2618.65'.Clean out rat hole from 2618.68'to 2630'MD(2465.2'TVD). Pumping 504 gpm w/1600 psi. Rotate w/50 rpm w/5k ftlbs of torque. 5-7 WOB, PU wt 110k, SO wt 85k, Rot wt 95k. 09:00 09:15 0.25 2,630 2,650 SURFA( DRILL DRLG P Drill 8-3/4"f/2630'to 2650'MD. Drilling parameters: 50 rpm w/5k ft lbs of torque,504 gpm w/1600 psi, PU wt 110 k, SO wt 85k, Rot wt 95k. ECD's 10.03 ppg, ADT.14 hr,jar hrs 79.93 hrs. 09:15 09:30 0.25 2,650 2,650 SURFA( DRILL OWFF P Monitor well-static. 09:30 10:00 0.50 2,650 2,650 SURFA( DRILL CIRC P Displace mud f/9.6 ppq to New 9.6 ppg LSND mud. Pumping 460 gpm w/900 psi. Rotate 50 rpm w/5k ft lbs of torque.Circulate 220 bbls. 10:00 10:30 0.50 2,650 2,600 SURFA( DRILL TRIP P Flow check-static. Pull out of the hole f/2650'to 2600'(lay down a single). 10:30 11:00 0.50 2,600 2,600 SURFA( DRILL RURD P RU f/FIT/LOT. Fill cement line and kill line with 9.6 ppg mud. 11:00 11:30 0.50 2,600 2,600 SURFA( DRILL FIT P Perform FIT to 18.1 ppq, using 9.6 ppg mud and 1085 psi applied surface pressure. 9-5/8"shoe @ 2618.68'MD(2455.1'TVD).After 10 minutes,the pressure had dropped to 800 psi. Pumped 1.4 bbls, bled back 1.2 bbls. 11:30 11:45 0.25 2,600 2,600 INTRM1 DRILL RURD P Rig down testing equipment. Blow down lines. 11:45 12:00 0.25 2,600 2,650 INTRM1 DRILL TRIP P Trip in the hole f/2600'to 2650'(PU a single). PU wt 115k,SO wt 85k. Page 10 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 2,650 4,018 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate hole f/2650'to 4018'(3640'TVD). ADT 7.93 hrs,ART 6.67 hrs,AST 1.26 hrs, Total bit hours 8.07,total jar hrs 87.86. ECD's 10.03 to 11.16 ppg.WOB 5-15k, Pumping 504 to 618 gpm w/1200 to 1620 psi, rotate 50-80 rpm w/5-4k ft lbs of torque on bottom,4-2k ft lbs off bottom. PU 110-125k, SO wt 85 to 114k, Rot wt 95 to 121k. Lubes in mud 2%. Pumped 35 bbl hi vis sweeps @ 3185'w/15%increase, pumped 35 bbl nut plug(10ppb)hi vis sweeps @ 3480'and 3745'w/10%increase each. 03/18/2011 Backream f/4018'to 3830'to clean up hole/reduce ECD's, RIH to 4018',continue to directional drill 8-3/4" intermediate hole f/4018'to 6056'(5293'TVD). Pumped 35 bbl hi vis sweeps @ 4018',4481',4851', Pumped 35 bbl weighted to 10.6 ppg-nut plug(10ppb)hi vis sweeps @ 5129'and 5592'. Performed a 275 bbl dilution of 9.6 ppg new mud @ 5655'. 00:00 00:45 0.75 4,018 3,830 INTRM1 DRILL REAM P Backream stand twice f/4018'to 3924',then stand back,backream another stand to 3830'.Trying to clean hole and reduce ECD's. Pumping 600 gpm w/1850 psi. Rotate 80 rpm w/3k ft lbs of torque. PU wt 123k. 00:45 01:00 0.25 3,830 4,018 INTRM1 DRILL TRIP P RIH f/3830'to 4018'@ 20-25 fpm. PU wt 123k, SO wt 120k. 01:00 12:00 11.00 4,018 5,036 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate hole f/4018'to 5036'(4465'TVD). ADT 6.59 hrs,ART 5.38 hrs,AST 1.21 hrs, Total bit hours 14.66,total jar hrs 94.45. ECD's 11.4-10.98 ppg. WOB 10-15k, Pumping 600-650 gpm w/1800-2150 psi, rotate 80 rpm w/ 6-7k ft lbs of torque on bottom,3-4k ft lbs off bottom. PU 125-140k,SO wt 114-128k, Rot wt 121-136k. Lubes in mud 2%. Pumped 35 bbl hi vis(flozan 2ppb) sweeps w/nut plug(10 ppb)@ 4018'-15%incr,4481'-10%incr, 4851'-25%incr. Page 11 of 33 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 12:00 00:00 12.00 5,036 6,056 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate hole f/5036'to 6056'(5293'TVD). ADT 7.39 hrs,ART 5.75 hrs,AST 1.64 hrs, Total bit hours 22.05,total jar hrs 101.84. ECD's 10.9 ppg. WOB 10-15k, Pumping 650-643 gpm w/2000-2350 psi, rotate 80 rpm w/ 6-9k ft lbs of torque on bottom,4-7k ft lbs off bottom. PU 144-160k,SO wt 127-143k, Rot wt 137-154k. Lubes in mud 3%@ 2100 hrs. Pumped a weighted(10.6 ppg)hi vis sweep(2ppb Flozan)w/nutplug(10 ppb)@ 5129'-50%incr, 5592'-40% incr Diluted w/275 bbls of new 9.6 ppg mud @ 5655'. 03/19/2011 Continue to directional drill 8-3/4"intermediate hole f/6056'to 7260'(6303.5'TVD).Obtain SPR's. Circulate a 35 bbls hi vis nut plug sweep to surface while backreaming f/ f/7260'to 7166'. Monitor well-static. Back ream out f/7166'to 5204'. Pumped a weighted(10.6 ppg)hi vis sweep(2ppb Flozan)w/nutplug(10 ppb)@ 6095'-15%incr. Pumped a hi vis sweep(2ppb Flozan)w/nutplug(10 ppb)@ 6390'-40%incr. _Diluted w/275 bbls of new 9.6 ppg mud @ 6426'. 00:00 12:00 12.00 6,056 6,797 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate hole f/6056'to 6797'(5930'TVD). ADT 7.78 hrs,ART 2.99 hrs,AST 4.79 hrs, Total bit hours 29.83,total jar hrs 109.62. ECD's 10.8 ppg. WOB 10-15k, Pumping 650 gpm w/ 2200-2250 psi, rotate 80 rpm w/6-9k ft lbs of torque on bottom,5-8k ft lbs off bottom. PU 160-177k,SO wt 143-154k, Rot wt 154-169k. Lubes in mud 3%. Pumped a weighted(10.6 ppg)hi vis sweep(2ppb Flozan)w/nutplug(10 ppb)@ 6095'-15%incr. Pumped a hi vis sweep(2ppb Flozan)w/nutplug(10 ppb)@ 6390'-40%incr. Diluted w/275 bbls of new 9.6 ppg mud @ 6426'. 12:00 19:30 7.50 6,797 7,260 INTRM1 DRILL DDRL P Directional drill 8-3/4"intermediate hole f/6797'to 7260'(6303.5'TVD). ADT 7.78 hrs,ART 2.99 hrs,AST 4.79 hrs, Total bit hours 35.54,total jar hrs 115.33. ECD's 10.66 ppg. WOB 10-15k, Pumping 650-635 gpm w/2250-2325 psi, rotate 80 rpm w/ 7-8k ft lbs of torque on bottom, 5-7k ft lbs off bottom. PU 177-186k, SO wt 154-158k, Rot wt 169-171k. Lubes in mud 2.5-3%. Page 12 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:15 0.75 7,260 7,166 INTRM1 DRILL CIRC P Obtain SPR's. Circulate a 35 bbls hi vis nut plug sweep to surface while backreaming f/ f/7260'to 7166'. 2-3'pm pulling speed. Pumping 650 gpm w/2100 psi. Rotate 80 rpm w/ 6k ft lbs of torque. 20:15 20:30 0.25 7,166 7,166 INTRM1 DRILL OWFF P Monitorwell-static. 20:30 23:30 3.00 7,166 5,225 INTRM1 DRILL REAM P Backream out of the hole from 7166' to 5225'. Pulling speed 17-20 fpm. Rotate 80 rpm w/Obtain PU and SO wt's every 5 stands. 23:30 00:00 0.50 5,225 5,204 INTRM1 DRILL REAM P Backream out f/5225'to 5204 @ midnight. Pumping 650 gpm w/1400 psi. Pulling speed 2-3'/min.Sperry Sun MWD not reading correct average or max values f/ECD's. Pumping a 30 bbl hi-vis nut plug sweep(10 ppb)while pulling f/5225' to 5125'. 03/20/2011 Continue to back ream out f/5204'to 5125', pumping 650 gpm w/1400 psi, rotate 80 rpm w/6k ft lbs of torque, pulling speed 2-3'/min,while pumping a hi vis nut plug sweep to surface w/15%increase in cuttings. Continue to back ream f/5125'to 2620', mostley 20-25'/min pulling speed.At 2990'slowed down to 3'/min f/ ECD's of 10.9 ppg.After last T&D value, RIH to 2723', back ream while pumping a 30 bbl hi vis nut plug sweep to surface. Pull on elevators f/2630'to 2540'. Blow down the top drive, monitor well,service rig, attempt to reset Sperry PWD tool by pumping through it, blow down the top drive. RIH f/2540'to 7170'. Pump a 30 bbls hi vis sweep,follow w/275 bbl new 9.6 ppg LSND,follow with spike fluid Glydril LSND mud ✓ weighing 10 ppg to weight system up to 9.8 ppg. Preacutionary ream f/7170'to 7260'.Make a connection, could not drill-No ROP,250 psi pump pressure increase.Check surface equipment-OK. Monitor well-static. POOH f/7260'to 6244', monitor-static, pump a dry job, POOH f/6244'to surface, monitor well at shoe and HWDP-all static. PJSM on RA sources, remove sources,download MWD, Lay down BHA to 87'. Pull out and observed broke service break, connection 1'below top of SperryDrill motor. Fish in the hole 25'(24'of motor ser#700-033)and Hughes PDC 8-3/4"bit(ser#7124444). Prepare to fish,work on work orders (MP2's). Pumped a hi vis sweep(2ppb Flozan)w/nutplug(10 ppb)@ 5204'-15%incr,2618'-15 to 20%incr. Pumped a hi vis sweep(2ppb Flozan)@ 7170'-. Diluted w/275 bbls of new 9.6 ppg mud @ 7260', and @ 6426'while back reaming,7170'after RIH. 00:00 00:15 0.25 5,204 5,125 INTRM1 DRILL REAM P Backream out f/5204'to 5125'. Pumping 650 gpm w/1400 psi. Pulling speed 2-3'/min. Rotating 80 rpm w/6k ft lbs of torque. While reaming, pumping a 30 bbl hi-vis nut plug sweep(10 ppb)while pulling f/5225'to 5125'-15% increase in cuttings. Note: Sperry Sun MWD not reading correct average or max values f/ ECD's Page 13 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:15 05:15 5.00 5,125 2,620 INTRM1 DRILL REAM P Backream out f/5125 to 2620'. Pumping 650 gpm w/1400-1025 psi. Pulling speed 20-25'/min. Rotating 80 rpm w/6-3k ft lbs of torque.Obtain PU,SO,and Rot wt's every 5 stands. Note: ECD's spiked up to 10.9 ppg while reaming at 2990',slowed down pulling speed to 3'/min to circ clay cuttings out of the hole. Resumed 17'/minute until to the shoe @ 2618'. Note: Sperry Sun MWD not reading correct average or max values f/ECD's. 05:15 06:00 0.75 2,620 2,620 INTRM1 DRILL REAM P After acquiring last T&D value, run in the hole f/2620'to 2723',then back ream 2723'to 2620'while pumping a nut plug( 10 ppb)sweep to surface--15-20%increase in cuttings.Shakers are clean when through pumping. Pumping 650 gpm w/1025 psi. Pulling speed 2-3'/min. Note: Sperry Sun MWD not reading correct average or max values f/ ECD's 06:00 06:15 0.25 2,620 2,540 INTRM1 DRILL TRIP P Pull on elevators f/2630'to 2540'. PU wt 105k,SO wt 93k. Hole taking proper fill. Blow down the top drive. 06:15 06:30 0.25 2,540 2,540 INTRM1 DRILL OWFF P Monitor well-static. 06:30 07:00 0.50 2,540 2,540 INTRM1 RIGMNT SVRG P Service rig,drawworks and top drive. 07:00 07:30 0.50 2,540 2,540 INTRM1 DRILL CIRC P Attempt to reset PWD tool by cycling pumps. Blow down the top drive. 07:30 12:00 4.50 2,540 7,170 INTRM1 DRILL TRIP P Run in the hole f/2540'to 7170'. Fill pipe every 20 stands. PU wt 180k, +/ SO wt 147k. Calculated displacment 35.1 bbls, actual 29 bbls. 12:00 14:00 2.00 7,170 7,170 INTRM1 DRILL CIRC P Pump a 30 bbl hi vis sweep to surface. Pumping 650 gpm w/1600 psi,slowed the rate to 510 gpm to treat mud system.Add 275 bbls of new 9.6 LSND,follow w/Glydril spike fluid of 10 ppg and weight system up to 9.8 ppg. Rotate 80 rpm w/5k ft lbs of torque. PU wt 185k,SO wt 153k, Rot wt 170k. 14:00 14:30 0.50 7,170 7,260 INTRM1 DRILL REAM P Precautionary ream in the hole f/ 7170'to bottom @ 7260'. Make a connection. No ROP-increase of pump pressure by 250 psi.Will pull ,out of the hole to check tools. 14:30 14:45 0.25 7,260 7,260 INTRM1 DRILL PRTS T Pressure test surface equipment to 2500 psi. No Problems found. 14:45 15:00 0.25 7,260 7,260 INTRM1 DRILL OWFF T Monitor well-static/Blow down the to drive. 15:00 15:30 0.50 7,260 6,244 INTRM1 DRILL TRIP T Pull out of the hole on elevators f/ 7260'to 6244'. Page 14 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 15:45 0.25 6,244 6,244 INTRM1 DRILL OWFF T Monitor well-static. 15:45 16:00 0.25 6,244 6,244 INTRM1 DRILL CIRC T Pump a dry job, blow down the top drive. 16:00 17:30 1.50 6,244 2,632 INTRM1 DRILL TRIP T Pull out of the hole on elevators f/ 6244'to 2632'.Shoe is @ 2618'. 17:30 17:45 0.25 2,632 2,632 INTRM1 DRILL OWFF T Monitor well-static. 17:45 18:30 0.75 2,632 780 INTRM1 DRILL TRIP T Pull out of the hole on elevators f/ 2632'to 780'. BHA is 780' 18:30 18:45 0.25 780 780 INTRM1 DRILL OWFF T Monitor well-static. 18:45 19:00 0.25 780 225 INTRM1 DRILL TRIP T Pull out of the hole on elevators f/ 780'to 225'. 19:00 19:15 0.25 225 133 INTRM1 DRILL SFTY T PJSM on removing sources and working BHA. Stand back a stand of 6-1/2"NM flex drill collars. 19:15 19:45 0.50 133 133 INTRM1 DRILL OTHR T Pick up, Remove RA sources. Run back in the hole. 19:45 20:30 0.75 133 133 INTRM1 DRILL OTHR T Pick up to 66'. Download Sperry Sun MWD. 20:30 21:00 0.50 133 87 INTRMI DRILL PULD T Continue to lay down BHA f/133'to 87'.Then PU to surface and observed that the SperryDrill 1.5 deg bend motor was missing.A service break on the motor(ser#700-033) 1'below the top box had broke, leaving 25 of $ fish in the hole including the Hughes 8-3/4"bit ser#7124444. 21:00 21:30 0.50 87 0 INTRM1 DRILL PULD T Run in the hole and finish laying down BHA#3 f/87'. 21:30 22:00 0.50 0 0 INTRM1 DRILL OTHR T Clean floor.Alert Baker Fishing of upcoming fishing job,6-15/16"OD motor. 22:00 00:00 2.00 0 0 INTRM1 FISH OTHR T Put 6 steel spiral drill collars(6-3/4" OD)into the pipe shed. Strap, OD, ID, FN.Work on work orders (MP2's). 03/21/2011 Prepare to fish,work on work orders(MP2's). Pick up Baker tools to the floor, PJSM, PU/MU BHA#4 to 685, RIH f/685'to 2535',fill pipe,blow down,continue trip in hole filling every 20 stands f/2535'to 7025'.Worked through hole drag of 15-20k @ 6940'.Circulate and wash down totop of fish,engage fish top @ 7235',swallow 2.3'of fish,observed increase in pump pressure(good indication-fish on). POOH f/7260'to 6738'w/fish(bit and 24'of motor),drop ball and rod,circ ball down @ 4 bpm w/450 psi, open circ sub w/1500 psi,then circ @ 7 bpm w/450 psi, monitor well-static, POOH f/6738'to shoe, monitor well-static, POOH to top of BHA, monitor well-static, Stand back 5"HWDP, lay down Baker intensifiers, lay down(3)6-1/4"steel drill collars, stand back a stand of 6-1/4"spiral steel drill collars. Pick up and observe fish in the overshot @ 1745 hrs. Lay down Baker oil jars, bumper sub and the float sub. Break bit, lay down motor and overshot, PU Baker jars and bumper sub f/pipe shed, break and lay down. Latch onto a stand of 6-1/4"drill collars, lay down same.Clear rig floor of fishing tools.Staighten up floor. PJSM on PU/MU BHA#5. PU/MU BHA#5 to 133', slack off to 66', upload MWD,shallow pulse test, PJSM on nuke sources. 00:00 01:45 1.75 0 INTRM1 FISH OTHR T Prepare to fish,work on work orders (MP2's). 01:45 02:15 0.50 INTRM1 FISH PULD T Pick up Baker tools to the rig floor. 02:15 02:30 0.25 INTRM1 FISH SFTY T Pre job safety meeting on PU BHA #4(fishing assembly#1). Page 15 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:45 1.25 0 223 INTRM1 FISH PULD T Pick up/make up fishing BHA#1 (BHA#4)to 223':8-3/8"OD guide, 8-1/2"OD overshot w/7"grapple and packoff,float sub,6-1/4" lubricated bumper sub,6-1/4"Oil Jar, Pump out sub,(6)6-1/4"spiral steel drill collars,6-1/4"intensifier. PU wt 45k, SO wt 50k. 03:45 04:00 0.25 223 223 INTRM1 FISH PULD T Move a stand of nm flex drill collars in the derrick. Move a stand of 5" HWDP w/jars in the derrick. 04:00 04:30 0.50 223 685 INTRM1 FISH TRIP T Strap and run in the hole 5 stands of 5"HWDP f/223'to 685'. PU wt 65k, SO wt 68k. 04:30 05:30 1.00 685 2,535 INTRM1 FISH TRIP T Trip in the hole w/fishing BHA on 5" drill pipe f/685'to 2535'. 05:30 06:00 0.50 2,535 2,535 INTRM1 FISH CIRC T Fill pipe. Pumping 358 gpm w/200 psi. Blow down the top drive. 06:00 09:45 3.75 2,535 7,025 INTRM1 FISH TRIP T Continue to trip in the hole f/2535'to 7025'. Fill pipe every 20 stands. Note: Drag of 15-20k @ 6940'. 09:45 10:15 0.50 7,025 7,224 INTRM1 FISH CIRC T Fill pipe at 7025, break circulation, then circulate 295 gpm w/450 psi. Wash down to 7145',tag fish,work over fish and engage @ 7224'. PU wt 185k,SO wt 150k. 10:15 11:15 1.00 7,224 7,224 INTRM1 FISH CIRC T Circulate bottom's up @ 7224'. Pumping 295 gpm w/450 psi. Rotate 15 rpm w/5k ft lbs of torque. Reciprocate pipe f/7224'-7168'. 11:15 12:00 0.75 7,224 7,260 INTRM1 FISH FISH T Slack off w/o rotation,then push fish to bottom.Tag 3 times w/10k weight.Shut down pumping,slack off 20k to 7238'(top of fish 7235')(2.3' swallow). Pick up w/200k,slack off, turn pump on 295 gpm. . Pick up w/ 650 psi to confirm extra pressure (fish on). 12:00 12:30 0.50 7,260 6,738 INTRM1 FISH TRIP T Pull out of the hole w/fish f/7260'to 6738'.(5 stands) 12:30 13:00 0.50 6,738 6,738 INTRM1 FISH CIRC T Drop ball to open circ sub. Circ ball down @ 4 bpm w/450 psi. Open circ sub @ 1500 psi. Circulate 7 bpm w/ 450 psi. 13:00 13:15 0.25 6,738 6,738 INTRM1 FISH OWFF T Monitor well-static. 13:15 15:30 2.25 6,738 2,560 INTRM1 FISH TRIP T Continue to POOH w/fish(Hughes 8-3/4"bit(ser#7124444)&24'of Sperrydrill mtr(ser#700-033)f/ 6738'to 2560' 15:30 15:45 0.25 2,560 2,560 INTRM1 FISH OWFF T Monitor well-static. 15:45 16:30 0.75 6,768 710 INTRM1 FISH TRIP T Continue to POOH w/fish(Hughes 8-3/4"bit(ser#7124444)&24'of Sperrydrill mtr(ser#700-033)f/ 2560'to 710' 16:30 16:45 0.25 710 710 INTRM1 FISH OWFF T Monitor well-static. Page 16 of 33 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 17:00 0.25 710 248 INTRM1 FISH TRIP T Stand back 5 stands of 5"HWDP. 17:00 17:15 0.25 248 236 INTRM1 FISH PULD T Lay down Baker 6-1/4"intensifier. 17:15 17:30 0.25 236 146 INTRM1 FISH PULD T Lay down(3)6-1/4"steel spiral drill collars. 17:30 17:45 0.25 146 53 INTRM1 FISH TRIP T Stand back a stand of 6-1/4"spiral steel drill collars. 17:45 18:00 0.25 53 28 INTRMI FISH PULD T Pick up and observe fish in the overshot @ 1745 hrs. Lay down oil jar, bumper sub and float sub. 18:00 18:30 0.50 28 0 INTRMI FISH PULD T PU/MU lift sub to Baker overshot. Pick up and break off Hughes 8-3/4" HCM605Z bit(ser#712444). Lay down SperryDrill motor(ser# 700-033)with Baker overshot attached. Done @ 18:30 18:45 0.25 0 0 INTRM1 FISH PULD T Clean floor. PU oil jars and bumper sub. Break and lay down. 18:45 19:15 0.50 INTRM1 FISH PULD T Latch a stand of 6-1/4"spiral drill collars. RIH, break and lay down 3 steel drill collars. 19:15 19:30 0.25 INTRM1 FISH PULD T Lay down Baker tools f/rig floor. 19:30 19:45 0.25 INTRM1 FISH PULD T Clean and straighten rig floor. 19:45 20:00 0.25 INTRM1 DRILL SFTY T Pre job safety meeting on PU/MU BHA#5. 20:00 21:45 1.75 0 133 INTRMI DRILL PULD T Pick up/Make up BHA#5:8-3/4" Hughes HCM605Z(ser#7124444), 7"SperryDrill mtr(1.5 deg bend), integral blade stabilizer,float sub, DM collar, EWR-P4 collar, DGR collar, PWD, HCIM collar,ALD collar,CTN collar, BAT collar,TM collar to 166'.Then pull up to 66'. 21:45 23:15 1.50 133 66 INTRM1 DRILL PULD T Upload Sperry Sun MWD @ 66'. 23:15 23:30 0.25 66 133 INTRM1 DRILL PULD T Upload MWD @ 66'.Slack off to 133'. 23:30 23:45 0.25 133 133 INTRM1 DRILL DHEQ T Shallow pulse test MWD @ 133. Pumping 447 gpm w/912 psi-41% flow out. Blow down the top drive. 23:45 00:00 0.25 133 133 INTRM1 DRILL SFTY T Pre job safety meeting on loading RA sources. 03/22/2011 Load nuke sources,finish MU BHA#5 to 781', RIH on 5"dp-filling every 20 stands to stand#60 @ 6338',fill pipe,circulate bottom's up,continue to run in the hole f/6338'to 7,260'. Drill F/7,260'-T/8,071' 00:00 00:30 0.50 133 133 INTRM1 DRILL PULD T Load RA sources. 00:30 01:00 0.50 133 781 INTRM1 DRILL TRIP T Continue w/BHA#3: Make up a stand of flex NMDC, Run 6 stands of 5"HWDP f/derrick, including jars to 781'. 01:00 04:45 3.75 781 6,338 INTRM1 DRILL TRIP T Continue to run in the hole w/BHA #5 on 5"dp f/781'to 6338'. Fill pipe every 20 stands,obtain PU and SO wt's. Note:At the shoe 2618',filled pipe pumping 525 gpm w/1200 psi. Page 17 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 05:15 0.50 6,338 6,338 INTRMI DRILL CIRC T Fill pipe on stand#60 @ 6338'. Circulate bottom's up,pumping 400 gpm w/1100 psi, ECD's 10.77 reduced to 10.66 ppg. MW in 9.9 ppg, MW out 10.1 ppg. Back ream f/ 6338'to 6235', pulling 3-4'/min, rotate 50 rpm w/5-6k ft lbs of torque. 05:15 06:00 0.75 6,338 7,171 INTRM1 DRILL TRIP T Continue to run in the hole w/BHA #5 on 5"dp f/6338'to 7,171'. Fill pipe every 20 stands,obtain PU and SO wt's. 06:00 06:30 0.50 7,171 7,260 INTRM1 DRILL WASH T Wash&Ream F/7,171'MD-T/ 7,220'MD. Stage pumps up to 650 gpm-2,300 psi. Rot 50 rpm,Torque 7,000 ft/lbs. Continue washing and reaming T/7,260'MD.Tagged no fill. 06:30 12:00 5.50 7,260 7,447 INTRM1 DRILL DDRL P Drill F/7,260'MD-T/7,447'MD TVD -6,443'Flow rate 650 gpm-2,450 psi,80 rpm, Bit wt 12k-20k.Torque on 7k off 6k. Mud wt 9.8 ppg. ECD- 10.48. Up 187k,down 155k, rot 173k.ADt 3.63,ART 1.17,AST 2.46. Total bit hrs. 39.21 Total jar hrs 119. Bit and jar hrs for BHA#5 3.63 hrs. SPR's @ 7,295'MD 6,330'ND, Mud wt 9.8 ppg#1 pump 30 spm-280 psi,40 spm 350 psi.#2 pump 30 spm-280 psi,40 spm-370 psi 12:00 00:00 12.00 7,447 8,071 INTRM1 DRILL DDRL P Drill F/7,447'MD-T/8,071'MD TVD -6,824'Flow rate 650 gpm-2,800 psi,80 rpm, Bit wt 10k-25k.Torque on 8koff7k. Mud wt9.8ppg increased to 10.5 ppg from 12:00 hrs -to 17:00 hrs.. ECD-11.38. Up 195k,down 155k, rot 176k.ADT- 8.27,ART-3.11,AST-5.16.Total bit hrs.47.44 Total jar hrs 127.27. Bit and jar hrs for BHA#5 11.90 hrs. SPR's @ 7,908'MD 6,742'ND, Mud wt 10.5 ppg#1 pump 30 spm-320 psi,40 spm 400 psi.#2 pump 30 spm-340 psi,40 spm-440 psi 03/23/2011 Drill F/8,071'-T/8,738'(TD)Circulate bottoms up X 2,500 gpm-1750 psi,50 rpm. Increase parameters to 650 gpm-2,700 psi,80 rpm. Pump Hi-Vis weighted sweep, Backream F/8,738'-T/7,264'. Run in hole on elevators with no evidence of hole problems. Page 18 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 8,071 8,545 INTRM1 DRILL DDRL P Drill F/8,071'MD-T/8,545'MD TVD j-6,979'Flow rate 650 gpm-2,800 psi,80 rpm, Bit wt 15k-20k.Torque on9koff7k. Mud wt10.5ppg ECD- 11.21. Up 197k,down 147k, rot 172k.ADT-9.04,ART-2.60, AST-6.44.Total bit hrs. 56.48 Total jar hrs 136.31. Bit and jar hrs for BHA#5 20.94 hrs. SPR's @ 8,420'MD 6,979'TVD,Mud wt 10.5 ppg#1 pump 30 spm-310 psi,40 spm 380 psi.#2 pump 30 _spm-310 psi,40 spm-400 psi 12:00 16:45 4.75 8,545 8,738 INTRM1 DRILL DDRL P Drill F/8,545'MD-T/8,738'MD TVD -7,005', Flow rate 650 gpm-2,900 psi, 80 rpm, Bit wt 15k-25k.Torque .r on 10k off 7-8k. Mud wt 10.5 ppg ECD-11.28. Up 201k,down 143k, rot 169k.ADT-3.24,ART-1.46, AST-1.78.Total bit hrs. 59.72 Total jar hrs 139.56. Bit and jar hrs for BHA#524.18 hrs. SPR's @ 8,738'MD 7,005'TVD, Mud wt 10.5 ppg#1 pump 30 spm-320 psi,40 spm 410 psi.#2 pump 30 spm-330 psi,40 spm-420 psi 16:45 19:30 2.75 8,738 8,654 INTRM1 DRILL CIRC P Circulate 2 bottoms up rotating and reciprocating string. initial rate 500 gpm-1,750 psi,50 rpm, Increased to 650 gpm-2,700 psi,80 rpm.Torq- 8k, Up 160 down 155(rot).Continue circulating pump Hi-Vis weighted nutplug sweep surface to surface. Minimal increase of cuttings visible upon sweep returning to surface. Circulate final bottoms up with stand racked back.Monitor well 10 minutes-Static 19:30 23:00 3.50 8,654 7,264 INTRM1 DRILL WASH P Backream F/8,654'MD-T/7,264' MD at drilling rate 650 gpm-2,600 psi,80 rpm,8k torque. Final circulating pressure 2,550 psi with torque reduced to 6k.Circulated bottoms up at 7,264'MD with minimal cuttings increase noted at shakers. Monitored well(Static) Blow _down top drive 23:00 00:00 1.00 7,264 8,283 INTRM1 DRILL TRIP P Trip in hole on elevators with no evidence of hole problems F/7,264' MD-T/8,283'MD. Slack of weight 145k. Page 19 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/24/2011 24 hr Summary Weighted up from 10.5 ppg to 11.0 ppg,Tripped out on elevators to 7,989'MD(25k Overpull @ 8,445'MD) Performed MAD pass F/8,000'MD-T/7,250'MD.Tripped back to bottom on elevators without difficulty. Circulated and conditioned mud prior to spotting CRP.Spotted casing running pill to 7,225'MD at 2 bpm with 200 psi.Attempted to trip out on elevators, Improper hole fill, Decision to pump out. Pumped out to next MAD pass point at 4,740'MD. MAD pass F/4,740'MD-T/4,540'MD,350 fph,450 gpm-1,300 psi,25 rpm. Flow rate set higher to circulate bottoms up during mad pass.Attempted to pull on elevators without success !(Swabbing)Pumped out of hole to 3,745'MD. 00:00 00:15 0.25 8,283 8,738 INTRM1 DRILL TRIP P Trip in hole F/8,283'MD-T/8,738' MD.Washed last stand to bottom. No hole problems evident. 00:15 06:45 6.50 8,738 8,738 INTRM1 DRILL CIRC P Circulate and condition while raising mud weight from 10.5 ppg to 11.0 ppg.Added chemicals to enhance mud properties. parameters 600 gpm -2,500 psi,80 rpm,torq 7-8k, ECD 11.8 06:45 08:00 1.25 8,738 7,898 INTRM1 DRILL TRIP P Blow down top drive, Monitor well, Pull out of hole on elevators T/7,898' 10-15k drag 25k overpull at 8,445' MD. (Area worked until satisfied) 08:00 12:15 4.25 7,898 7,250 INTRM1 DRILL DLOG P MAD pass section F/8,000'MD- T/7,250'MD at 300 fph,25 rpm,2 bpm-300 psi,torque 7,000 ft/lbs. 12:15 13:30 1.25 7,250 8,738 INTRM1 DRILL TRIP P Run in hole on elevators,Wash last stand down.Calculated displacement 11.25 bbl's actual displacement 16 bbl's. No hole problems encountered. 13:30 14:45 1.25 8,738 8,738 INTRM1 DRILL CIRC P Circulate and condition mud,600 gpm-2,450 psi,80 rpm,8k torq, Blow down topdrive,Monitor well (Static) 14:45 17:45 3.00 8,738 7,225 INTRM1 DRILL WASH P Pump and spot CRP F/8,738'MD- T/7,225'MD at 2 bpm-200 psi, Overpull of 25k noted at 8,600'MD and 8,030'MD. Initial pick up wt at 8,738'MD was 200k Final up weight at 7,225'MD was 185k 17:45 21:30 3.75 7,225 4,763 INTRM1 DRILL TRIP P Attempted to pull out of hole on elevators, Improper hole fill, (Swabbing)Pump out T/4,763'MD,4 bpm-400 psi, No rotation. Recorded torque and drag info. Calculated hole fill 18.75 bbl's actual hole fill 22 bbl's 21:30 22:45 1.25 4,763 4,540 INTRM1 DRILL DLOG P Mad pass F/4,763'MD-T/4,540' MD,350 fph,25 rpm,4k torque, Flow rate 450 gpm-1,300 psi.(Flow rate set to 450 gpm to circulate bottoms up during mad pass) 22:45 00:00 1.25 4,540 3,736 INTRM1 DRILL TRIP P Attempted to pull on elevators F/ 4,540 MD-T/4,100'MD. Hole fill 1.25 bbl's for 4 stands. Decision made to resume pumping out due to improper hole fill. Pump out of hole F/4,100'MD-T/3,736'at 4 bpm-300 psi. No rotation. Page 20 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/25/2011 24 hr Summary Trip out to 9-5/8"Shoe(2,618')Circulate bottoms up. Slip and cut 69'drill line,Trip out, lay down BHA, Pull wear bushing, Clear and clean floor, Flush stack, Change top pipe rams to 7"test same. Rig up and run 7" casing to 4,978', Circulate bottoms up. 00:00 01:00 1.00 3,736 2,634 INTRM1 DRILL TRIP P Pump out of hole F/3,736'MD-T/ 2,634'MD at 4 bpm-300 psi. No rotation. 01:00 01:30 0.50 2,634 2,643 INTRM1 DRILL CIRC P Circulate bottoms up at 2,643'MD 600 gpm-1,850 psi, 50 rpm. ECD= 11.69 01:30 02:30 1.00 2,643 2,643 INTRMI DRILL SLPC P Slip and Cut 69'of Drill line. 02:30 03:45 1.25 2,643 781 INTRM1 DRILL TRIP P Trip out of hole, Pulled on elevators to BHA @ 781'MD.Calculated fill 27.72 bbl's Actual hole fill 28.25 bbl's. 03:45 04:15 0.50 781 781 INTRM1 DRILL OWFF P Monitor well via Trip Tank. Held Safety Stand Up with rig crew and service hands. (Discussed success of operations and the fact that it did not happen by accident.Continue to focus and apply lessons learned.) 04:15 105:00 0.75 781 135 INTRM1 DRILL TRIP P Trip out of hole racking back 5" HWDP and Jars T/135'MD 05:00 05:45 0.75 135 135 INTRM1 DRILL PULD P Lay down Flex Drill Collars, PJSM- Remove Nuke sources 05:45 07:00 1.25 135 135 INTRM1 DRILL PULD P Download MWD data 07:00 08:00 1.00 135 0 INTRM1 DRILL PULD P Lay down remaining BHA. Gauge and Grade bit. 08:00 09:15 1.25 0 0 INTRM1 DRILL PULD P Pick up stack flushing tool. Remove BHA components from floor, Clear and clear rig floor while flushing BOP stack. Pull Wear bushing. 09:15 10:30 1.25 0 0 INTRM1 WHDBO NUND P Change top set pipe rams to 7" 10:30 12:00 1.50 0 0 INTRM1 WHDBO BOPE P Rig up and test upper pipe rams,250 psi low-3,500 psi high 5 minute per test.Test recorded on chart. Install casing running wear ring. 12:00 13:15 1.25 0 0 INTRM1 CASING RNCS P PJSM-Rig up to run 7"casing. 13:15 23:00 9.75 0 4,978 INTRM1 CASING RNCS P Run 7"casing per detail obtaining pick up and slack off weight every 10 joints. Ran 122 joints to 4,978'MD. Displacement for trip=40.5 bbl's calculated displacement 46.37 bbl's. GS`ti Mud loss of 6.5 bbl's. Up wt 145k down wt 115k. (Started adding water at 14 bbl per hr.) 23:00 00:00 1.00 4,978 4,978 INTRMI CASING CIRC P Circulate and condition mud. Break circulation slowly to 3 bpm 400 psi. Final circulating rate 4 bpm-500 psi. 03/26/2011 Ran casing to bottom,Circulated and conditioned. Perfromed 1st stage cement job.Opened stage collar, Circulated and conditioned dropping mud weight from 11.0 ppg to 10.5 ppg. Performed 2nd stage cement job. Rigged down from cement job.Set and tested packoff.Changed top pipe rams, Saver sub,grabber and bell guide. Page 21 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:15 3.25 4,978 7,232 INTRM1 CASING RNCS P Run 7"casing per detail F/4,978'MD -T/7,232'MD.Obtain pick up and slack off weights every 10 joints. Good displacement with no hole problems encountered. 03:15 04:30 1.25 7,232 7,232 INTRM1 CASING CIRC P Circulate @ 7,232'MD Stage pumps up slowly to 3 bpm, Step pumps up in 1/2 bbl increments to final circulating rate @ 5 bpm-570 psi. Circulated bottoms up with mud weight coming back 11.2 ppg. Continued circulating until mud properties to spec and mud weight 11.0 ppg in and out.Very minimal cuttings seen at shakers. 04:30 06:45 2.25 7,232 8,700 INTRM1 CASING RNCS P Run casing per detail F/7,232'MD- T/8,700'MD. Capture up and down weight every 10 joints. No visible hole problems. 06:45 07:00 0.25 8,700 8,728 INTRM1 CASING RNCS P Pick up hanger and landing joint. Land casing on hanger. 07:00 07:45 0.75 8,728 8,728 INTRM1 CEMEN"RURD P Blow down topdrive, Lay down Franks fill up tool. Make up cement head. 07:45 11:15 3.50 8,728 8,728 INTRM1 CEMEN'CIRC P Break Circulation stage pump up to 5 bpm-700 psi.Circulate and condition mud for cement job.final circulating pressure at 5 bpm-500 psi. 11:15 13:30 2.25 8,728 8,728 INTRM1 CEMEN'CMNT P Cement per program. Pump 5 bbl's water pressure test cement lines to 3,500 psi. Drop top plug and load bottom plug. Pump 30.2 bbl's Sdt'l!� CW100, Pump 30.4 bbl's mudpush, Batch and pump 55.9 bbl's 15.8 ppg type"G"tail cement at 4.4 bpm. Chase with 5 bbl's water.Turn over to rig for displacement. Displace cement at 5 bpm-350 psi slow rate to 3 bpm prior to bumping plug. Bump plug at 3,050 strokes. Pressure up to 1,200 psi. Pressure held 5 minutes and recorded on chart. Bleed off pressure and check floats. Floats good verified by rig supervisor. Load plug into cement head.Top of cement calculated= 6,835'MD. 13:30 16:00 2.50 8,728 8,728 INTRM1 CEMEN"CIRC P Circulate down casing increase pressure to 3,350 psi to open stage collar.Circulate and condition mud reducing mud weight from 11.0 ppg to 10.5 ppg for 2nd stage cement job. Page 22 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:30 1.50 8,728 8,728 INTRM1 CEMEN'CMNT P Pump 2nd stage cement job per ✓ program. Pump 30 bbl's CW100, Pump 29.6 bbl's Mudpush, Batch and pump 42.1 bbl's 15.8 ppg type "G"tail cement at 5 bpm rate.Shut down Drop top plug chase with 20 t3 bbl's water.Turn over to rig for SkaY' displacement. Displace cement at 5 0 bpm and bump plug at 1,735 strokes. Increase pressure to 1,600 psi to close stage collar, Increase pressure to 1,950 psi for 5 minutes. Bleed off pressure verify stage collar closed.Witnessed by rig supervisor. 17:30 19:30 2.00 0 0 INTRM1 CEMEN-RURD P Rig down cement head and casing equipment.Clear and clean rig floor 19:30 20:30 1.00 0 0 INTRM1 WHDBO NUND P Pull casing running wear bushing. Set and test 7"packoff to 5,000 psi for 10 minutes. (Test verified and witnessed by rig supervisor) 20:30 21:00 0.50 0 0 INTRM1 WHDBO SFTY P Held Safety stand up with rig crew and service personnel. Complimented crews on working safely. (Discussed paying close attention to all details breaking down tasks examining possible hazards and mitigating out) 21:00 00:00 3.00 0 0 INTRM1 WHDBO NUND P Change upper pipe rams F/7"-T/ 3-1/2"X 6"Variables,Sim-ops change out saver sub,Grabbers and bell guide-Stage BHA components in pipe shed. 03/27/2011 Tested up rams, Performed injectivity test, Flushed and freeze protected annulus. Layed down all 5"drillpipe. Changed out handling equip.from 5"over to 4"picked up cleanout assembly,Tripped in to 5,092'MD circulated and did 10 min 1,000 psi casing test. Drilled out stage collar at 5,122'MD(tagged on depth)Ran in to 5,316'MD circulated and did 2nd casing test below stage collar 10 min 1,000 psi.Tripped in to 6,005'MD. All tripping in hole done picking up singles of 4"drillpipe from pipeshed. 00:00 01:00 1.00 0 0 INTRM1 DRILL RURD P Complete installation of new saver sub.Adjust height on grabbers. Pick up short bales and 5"elevators 01:00 02:30 1.50 0 0 INTRM1 WHDBO BOPE P Set test plug. Riq up and test top rams 3-1/2"X 6" variable's.250 psi NQS low-3,500 psi high.5 min test recorded and charted. Rig down from test. Pull test plug install 8"ID wear bushing. 02:30 03:00 0.50 0 0 INTRM1 DRILL PULD P Rig up to lay down 5"drillpipe, Install mousehole.Sim-op rig up Dowell and perform injectivity test. 03:00 10:00 7.00 0 0 INTRM1 DRILL PULD P PJSM, Lay down 5"drillpipe. Dowell flushing 9-5/8"X 7"annulus with 300 bbl's water, Freeze protect with 65 bbl's diesel. 10:00 10:30 0.50 0 0 INTRM1 RIGMN1SVRG P Service top drive and draworks Page 23 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 0 0 INTRM1 DRILL PULD P Mobilize cleanout BHA components. Swap out 5"handling equipment for 4"handling equipment. 12:00 18:15 6.25 0 4,940 INTRM1 DRILL TRIP P Pick up cleanout assembly, Bit, NB stabilizer,collars and 4"HWDP with jars.Single in hole with 4"drillpipe from pipeshed to 4,940'(49 stands) Displacement calculated=30.66 bbl's. Displacement actual=29.4 bbl's 18:15 18:45 0.50 4,940 4,940 INTRM1 DRILL CIRC P Circulate bottoms up at 5 bpm-525 psi.50 rpm 18:45 19:30 0.75 4,940 4,940 INTRM1 DRILL PRTS P Rig up and test 7"casing at 4,940' MD above stage collar(5,122'MD). 10 min test 1,000 psi.Test recorded and charted. Rig down from test. 19:30 20:30 1.00 4,940 5,092 INTRM1 DRILL TRIP P Single in hole picking up 4"drillpipe from pipeshed F/4,940'MD-T/5,092' MD. Up wt 105k down 87k. 20:30 22:00 1.50 5,092 5,124 INTRM1 CEMEN"COCF P Wash down to stage collar.tagged on depth at 5,122'MD. Drill out stage collar.Work area until satisfied. 22:00 22:30 0.50 5,124 5,316 INTRM1 DRILL CIRC P Single in hole picking up 4"drillpipe from pipeshed F/5,124'MD-T/5,316" MD. Circulate bottoms up 22:30 23:00 0.50 5,316 5,316 INTRM1 DRILL PRTS P Rig up and test 7"casing at 5,316'MD below stage collar(5,122' MD). 10 min test 1,000 psi.Test recorded and charted. Rig down from test. 23:00 00:00 1.00 5,316 6,005 INTRM1 DRILL TRIP P Single in hole picking up 4"drillpipe from pipeshed F/5,316'MD-T/6,005' MD. 03/28/2011 Single in 4"drillpipe F/6,005'MD-T/8,514'MD.String took 10k wt,Washed down to 8,574'MD 250 gpm-1,200 psi and 70 rpm. Circulated bottoms up. Rigged up and made several attempts to obtain good casing test with no success.Tripped out of hole, Laid down cleanout BHA. Rigged up and tested BOPE. Witness of BOPE test waived by AOGCC representative Bob Noble. Picked up Baker retrieve O'matic packer and tripped in hole to 5,209'Stage collar at 5,122'MD. Set packer tested below stage collar pumping down drillpipe.Test leaked off pressure.Tested from stage collar to surface 3,500 psi test results good.Tripped in hole T/8,502'MD. Prepared to test casing. 00:00 02:15 2.25 6,005 8,514 INTRM1 DRILL TRIP P Trip in hole picking up 4"drillpipe in singles from pipeshed F/6,005'MD- T/8,514'MD.Took weight at 8,514' MD 10k. Up 155k down 95k. 02:15 02:45 0.50 8,514 8,574 INTRM1 CEMEN"WASH P Break circulation,Wash and ream through cement stringers F/8,514' MD-T/8,574'MD. Parameters-250 gpm-1,200 psi, rot 70 rpm with 5-7k torque. 02:45 03:15 0.50 8,574 8,574 INTRM1 CEMEN"CIRC P Circulate bottoms up at 8,574'MD. 250 gpm-1,200 psi,70 rpm,torque 5k. Increrase pump rate to 325 gpm- 1,550 psi. Page 24 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 06:00 2.75 8,574 8,574 INTRM1 DRILL PRTS T Rig uo and attempt to test 7"Casing to 3,500 psi. Pump at 6 spm recording pressure every 2 strokes. Achieved 3,500 psi. Shut in and monitored pressure with pressure dropping off at 100 psi per minute rate. Made 2nd attempt testing casing again using top pipe rams with same results.Attempted 3rd test using hydril test still resulted in pressure loss. Racked back one stand made final attempt at casing test with out success. Decision made to trip out of hole with cleanout assembly. 06:00 07:00 1.00 8,574 8,574 INTRM1 DRILL TRIP T Rig down test eqipment, Run stand in hole pick up single to come out on even stand number. Rack back stand, Instal airslips, monitor well, Pump dry job, Blow down top drive. 07:00 10:00 3.00 8,574 279 INTRM1 DRILL TRIP T Trip out of hole with cleanout assembly T/279'Calculated hole fill 50 bbl's,Actual hole fill 55.75 bbl's. 10:00 10:45 0.75 279 0 INTRM1 DRILL PULD T Rack back 4"HWDP with Jars, Flex collars. Lay down bumper sub, Crossover, Float sub, Near Bit Stabilizer and bit. 10:45 11:15 0.50 0 0 INTRM1 WHDBO BOPE T Pull wear bushing, Set test plug and test joint. 11:15 17:00 5.75 0 0 INTRM1 WHDBO BOPE T Rig up and test BOPE,250 psi low- 3,500 psi high.Annular tested 250 psi low-2,500 psi high.All tests recorded and charted. Rig down from BOPE test, Blow down lines and choke manifold. Set wear bushing. 17:00 21:00 4.00 0 5,209 INTRM1 DRILL TRIP T Make up Baker Retrieve Omatic packer,Trip in hole to 5,209'MD 21:00 22:00 1.00 5,209 5,209 INTRM1 DRILL PRTS T Break circulation pump 5 bbl's at 2.5 bpm-250 psi. Up wt 108k down 85k. G°'° Set packer at 5,209'MD.Test below packer pumping down drillpipe at 6 Stot spm. Pressure at 3,500 psi in 26 strokes. Pressure bled down. Bled off remaining pressure,Closed top pipe rams and pumped through kill line testing from 5,209'MD to surface.6 spm to 3,500 psi. Pressure held for 10 minutes with no loss. (Test good). Both tests recorded and charted. Bled off pressure. 22:00 23:30 1.50 5,209 8,508 INTRM1 DRILL TRIP T Trip in hole F/5,209'MD-T/8,508' MD. Picked up 6 additional joints 4" drillpipe from pipeshed to reach depth. Displacement actual 50.5 bbl's, Calculated displacement 48.6 bbl's Page 25 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 8,508 8,502 INTRM1 DRILL PRTS T Break circulation at 3 bpm-500 psi, pump 15 bbl's. Up wt 170k down wt 100k. Set packer at 8,502'MD. 03/29/2011 Test 7"Casing 3,500 psi-30 min,Trip out of hole, Lay down Baker retrieve-o-matic packer, Pick up Sperry Geo-Pilot BHA.Trip in picking up singles 4"drillpipe T/7,680'MD. MAD pass F/7,680'MD-T/8,563'MD. Wash and ream down to baffle collar.Tagged and drilled out baffle collar on depth 8,600'MD. • 00:00 01:00 1.00 8,502 8,502 INTRM1 DRILL PRTS T Test casing to 3,500 psi. Pump at 6 55V6 spm, Recording pressure every 2 O/Sf strokes. reached 3,500 psi with 28 1 G strokes.Shut down and recorded shut in pressure for 30 minutes. Pressure showed minimal bleed off from 3,510 psi down to 3,430 psi in 30 min. Good test. Bleed off pressure. Release packer. 01:00 06:00 5.00 8,502 0 INTRM1 DRILL TRIP T Trip out of hole with Baker Retrieve-O-matic packer. Lay down packer 06:00 10:30 4.50 406 406 INTRM1 DRILL PULD P Make Up BHA#8,Sperry 5200 Geo-Pilot.Make up bit, Geo-Pilot and MWD tools. Upload MWD data. Make up remaining BHA. Pulse test MWD tools,downlink to Geo-Pilot while rotating at 20 rpm to break in seals on Geo-Pilot. Flow rate 220 gpm-1,050 psi. 10:30 17:30 7.00 406 7,680 INTRM1 DRILL TRIP P Trip in hole with Geo-Pilot assembly picking up single joints of 4"drillpipe from pipeshed T/7,680 MD. 17:30 21:30 4.00 7,680 8,563 INTRM1 DRILL QEVL P MAD pass F/7,680'MD-8,563'MD (Bit depth's)at 300 fpm.Assembly started taking weight at 8,563'MD (10k)Up 155k down 97k 21:30 00:00 2.50 8,563 8,630 INTRM1 CEMEN"COCF P Circulate at 225 gpm-1,800 psi,20 rpm,torque 7k.Wash down to 8,595' MD. Increase rotary speed to 60 rpm.Tag baffle collar plug at 8,597' MD. Drill out baffle collar and continue drilling cement down to 8,630'MD 03/30/2011 Drill out shoe track plus 20'new hole.Circulate and condition, Perform Flt to 12.5 ppg EMW, Displace well to 10.3 ppg flo-thru mud, Establish PWD baseline, Drill ahead F/8,738'MD-T/ 00:00 02:00 2.00 8,630 8,642 INTRM1 CEMEN"COCF P Drill cement F/8,630'MD-T/8,638' MD. Drill out float collar tagged on depth at 8,642'MD. Parameters Bit wt 5-15k 225-gpm-1,850 psi, Rotary 70 rpm Torque 7-8k. 02:00 04:15 2.25 8,642 8,738 INTRM1 CEMEN-COCFP Drill cement F/8,642'MD to 8,726' MD tag top of silver bullet shoe on depth. Drill out shoe and rathole T/8,738'MD. Parameters Bit wt 5-15k 225-gpm-1,880 psi, Rotary 65 rpm Torque 7k. Page 26 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:45 0.50 8,738 8,758 INTRM1 DRILL DDRL P Drill 20'of new hole F/8,738'MD-T/ 8,758'MD,TVD-7,006'Flow rate 225 gpm-1,900 psi,60 rpm, Bit wt 5k.Torque on 9k off 7-8k. Mud wt 10.3 ppg ECD-11.59. Up 155k, down 97k, rot 120k.ADT/ART-.54 Total bit hrs.= .54 Total jar hrs 79.19 04:45 06:00 1.25 8,758 8,758 INTRM1 DRILL CIRC P Circulate and condition for FIT 222 gpm-1,950 psi,60 rpm,torque 8k 06:00 07:00 1.00 8,758 8,758 INTRM1 DRILL FIT P Rack back stand, Rig up and perform FIT to 12.5 ppg EMW, Rig down from test 07:00 08:30 1.50 8,758 8,758 PROD1 DRILL CIRC P PJSM, Displace well over to 10.3 ppg Flo-Thru mud.222 gpm-1,900 psi, 60 rpm,torque 7k, ECD 11.36, Pumped 30 bbl spacer followed with 290 bbl's Flo-Thru mud. 08:30 09:00 0.50 8,758 8,758 PROD1 DRILL CIRC P Establis PWD baseline,Take SPR's, Blow down topdrive, Monitor well, Clean under shakers 09:00 12:00 3.00 8,758 8,863 PROD1 DRILL DDRL P Drill F/8,758'MD-T/8,863'MD,TVD -7,016'Flow rate 222 gpm-1,775 psi,60 rpm, Bit wt 5-10k.Torque on 8k off 6k. Mud wt 10.3 ppg ECD- 11.03. Up 150k,down 120k, Rot 125k.ADT/ART-2.02 Total bit hrs.= 2.56 Total jar hrs 81.21. SPR's#1 pump 20 spm-390 psi 30 spm-670 psi.#2 pump 20 spm-390 psi,30 spm-754 psi 12:00 00:00 12.00 8,863 9,648 PROD1 DRILL DDRL P Drill F/8,863'MD-T/9,648"MD, TVD-7,014'Flow rate 222 gpm- 1,900 psi, 120 rpm, Bit wt 5-8k. Torque on 8k off 7k. Mud wt 10.3 ppg ECD- 11.44. Up 150k,down 104k, Rot 120k.ADT/ART-9.08 Total bit hrs.= 11.64 Total jar hrs 90.29. SPR's#1 pump 20 spm-500 psi 30 spm-740 psi.#2 pump 20 spm-520 psi,30 spm-780 psi. Mud losses for tour 120 bbl's.Added 20 bbl's Dyna Red LCM pill. Losses down to 5 bph. 03/31/2011 Drill F/9,648'MD-T/11,159'MD 7,029'TVD 00:00 12:00 12.00 9,648 10,407 PROD1 DRILL DDRL P Drill F/9,648'MD-T/10,407'MD, TVD-7,025' Flow rate 222 gpm- 1,900 psi, 120 rpm, Bit wt 8-12k. Torque on 8k off 6k. Mud wt 10.3 ppg ECD-11.38. Up 155k,down 105k, Rot 131k.ADT/ART-8.54 Total bit hrs.=20.18 Total jar hrs 98.83. SPR's @ 10,312'MD#1 pump 20 spm-450 psi 30 spm-710 psi.#2 pump 20 spm-470 psi,30 spm- 720 psi. Mud losses for tour 18.5 bbl's Page 27 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 10,407 11,159 PROD1 DRILL DDRL P Drill F/10,407'MD-T/11,159'MD, TVD-7,029' Flow rate 222 gpm- 2,000 psi, 120 rpm, Bit wt 8-12k. Torque on 9k off 6k. Mud wt 10.3 ppg ECD-11.55. Up 158k, Down 102k, Rot 125k.ADT/ART-8.69 Total bit hrs.=28.87 Total jar hrs 107.52. SPR's @ 11,159'MD#1 pump 20 spm-480 psi 30 spm-750 psi.#2 pump 20 spm-520 psi,30 spm- 850 psi. Mud losses for tour 75 bbl's 04/01/2011 Drill F/11,159'MD-T/12,570'MD 7,037'TVD.250 bbl mud dilutions every 500'. Flow check every connection. 00:00 12:00 12.00 11,159 11,818 PROD1 DRILL DDRL P Drill F/11,159'MD-T/11,818'MD, TVD-7,033' Flow rate 220 gpm- 2,100 psi, 120 rpm, Bit wt 6-12k. Torque on 10k off 7k.Mud wt 10.3 ppg ECD-11.62. Up 157k, Down 100k, Rot 129k.ADT/ART-8.5 Total bit hrs.=37.37 Total jar hrs 116.02. SPR's @ 11,818'MD 7,033'TVD#1 pump 20 spm-570 psi 30 spm-870 psi.#2 pump 20 spm-570 psi, 30 spm-870 psi. Mud losses for tour 93 bbl's 12:00 00:00 12.00 11,818 12,570 PROD1 DRILL DDRL P Drill F/11,818'MD-T/12,570'MD, TVD-7,037'Flow rate 220 gpm- 2,150 psi, 120 rpm, Bit wt 10-12k. Torque on 10k off 8k. Mud wt 10.3 ppg ECD-11.64. Up 160k, Down 95k, Rot 130k.ADT/ART-8.98 Total bit hrs.=46.35 Total jar hrs 125.00. SPR's @ 12,666'MD 7,040'TVD#1 pump 20 spm-570 psi 30 spm-870 psi.#2 pump 20 spm-550 psi, 30 spm-820 psi. Mud losses for tour 82 bbl's 04/02/2011 Drilled F/12,570'MD-T/13,228'MD 7,037'TVD.Troubleshoot MWD tool without success. Backream to 7" casing shoe @ 8,728'MD. Circulate 2 X bottoms up. Blow down mud lines and topdrive. Monitor well(Static) Slip and Cut 98'of drill line. Circulate in mud dilution 220 gpm-1,800 psi. 00:00 10:30 10.50 12,570 13,228 PROD1 DRILL DDRL P Drill F/12,570'MD-T/13,228'MD, TVD-7,037'Flow rate 220 gpm- 2,200 psi, 120 rpm, Bit wt 5-10k. Torque on 10k off 8k. Mud wt 10.3 ppg ECD-11.64. Up 162k, Down 97k, Rot 130k.ADT/ART-7.97 Total bit hrs.=54.32 Total jar hrs 132.97. SPR's @ 13,228'MD 7,037'TVD#1 pump 20 spm-570 psi 30 spm 900 psi.#2 pump 20 spm-650 psi, 30 spm-960 psi.Mud losses for tour 102 bbl's Page 28 of 33 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 13,228 13,228 PROD1 DRILL DHEQ T Attempt survey without success at 13,228'MD. Downlink to obtain survey with unsuccessful results. Continue troubleshooting MWD. Final decision-Trip out for tool failure. 12:00 20:00 8.00 13,228 8,695 PROD1 DRILL TRIP T Backream out of hole F/13,228'MD- 8,695'MD.220 gpm-2,000 psi, 100 rpm. Pulling speed 25 fpm. Calculated hole fill 72.66 bbl's Actual hole fill 76 bbl's. 20:00 21:30 1.50 8,695 8,695 PROD1 DRILL CIRC T Circulate 2 bottoms up at 218 gpm- 1,800 psi. 21:30 22:00 0.50 8,695 8,695 PROD1 DRILL OWFF T Blow down topdrive and mud lines. Monitor well-Well taking fluid. 22:00 23:00 1.00 8,695 8,695 PROD1 RIGMNT SLPC P Slip and Cut 98'of drill line,Service top drive and brake linkage.(Well took 3 bbl's during cutting of drill line.) 23:00 00:00 1.00 8,695 8,695 PROD1 DRILL CIRC T Pump 275 bbl 10.3 ppg dilution mud at 218 gpm-1,800 psi.**Note,After cutting drill line driller started circulation of fluid. He then inspected the drill line on the drum and found a bad wrap with several strands showing breaks. Line would be slipped and recut after circulation** 04/03/2011 Complete pumping dilution mud. Make 2nd cut of drill line due to bad wrap found. Monitor well,Trip out on elevators. Lay down BHA. Rig up and run Liner to 12,987'per detail. 00:00 00:30 0.50 8,695 8,695 PROD1 DRILL CIRC T Complete pumping of 275 bbl's 10.3 ppg dilution fluid. Final circulation rate 218 gpm-1,750 psi 00:30 01:00 0.50 8,695 8,695 PROD1 DRILL OWFF T Monitor well for flow-Slight drop in fluid level. 01:00 02:30 1.50 8,695 8,695 PROD1 RIGMNT SLPC P Slip and cut an additional 91'of drill line due to bad condition found on one wrap of drill line on drum. Hole monitored during cut of drill line with 1.5 bbl loss in 1-1/2 hrs. 02:30 07:30 5.00 8,695 406 PROD1 DRILL TRIP T Trip out pulling on elevators F/8,695' MD. Hole taking over calculated fill. Dropped 2"drift. Overpull of 30K at 1,700' (Area worked)At 1,054'20K overpull with string hung up.Worked string free continued pulling out of hole with overpull every 40'of 15- 20k.Continued pulling out to BHA while working string through tight spots to BHA at 406' 07:30 09:00 1.50 406 70 PROD1 DRILL PULD T Monitor well at BHA(Static)Lay down HWDP, Bumper sub,Jar and non mag flex collars. 09:00 10:00 1.00 70 70 PROD1 DRILL PULD T Attempted to download MWD data with out success. Failure to communicate with tool. Page 29 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:00 1.00 70 0 PROD1 DRILL PULD T Lay down remaining BHA. No visible damage upon inspection of BHA components. Found nothing to indicate a reason for overpull every 40' 11:00 12:00 1.00 0 0 PROD1 DRILL RURD P Clear and clean rig floor.Change wear bushing from 8"wear bushing to 9"wear busing. 12:00 12:30 0.50 0 0 COMPZ CASING RURD P Rig up to run 4-1/2"liner per detail. 12:30 18:00 5.50 0 4,986 COMPZ CASING RUNL P Run 4,980'of 4-1/2 Slotted liner and blank liner per comoletion design, Total of 124 joint. Make up liner hanger assembly.Add pal mix,wait 30 minutes for mixture to gel. 18:00 00:00 6.00 4,986 12,987 COMPZ CASING RUNL P Make up crossover from liner to drillpipe. **Note**Backing out topdrive after circulation of pipe volume a 1/2 turn to the left was .• applied to liner. Rotated string to the S right showed 1,200 ft/lbs torque. I�� Shear pins set at 2,300 ft/lbs torque I l� to shear. Pulled hanger to floor inspected per Baker rep. Decision made to trip in hole but not capture torque and drag data as there was no desire to move the string in an upward motion. Decision per Rig Supervisor*** Trip in hole with 4-1/2"completion liner on drillpipe. Circulate pipe volume at shoe at 4 t/ bpm-500 psi. Continue in hole to 12,987'MD. Up 155k Down 103k. Displacement calculated-43.5 bbl's Actual displacement 38.5 bbl's. No hole problems encountered 04/04/2011 Set and release from liner hanger,Trip out of hole lay down liner running tool. Rig up run 4-1/2" 12.6 ppf tubing,Space out, Displace to 10.3 brine. Pull Wear bushing. Land tubing on hanger. Pull landing joint,set TWC. 00:00 00:30 0.50 12,987 13,225 COMPZ CASING RUNL P Trip in hole with liner on drillpipe, F/12,987'MD-T/13,229'MD.Tagged bottom. Up wt 157k Down 105k, Pull up to 13,225'MD Page 30 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:30 1.00 13,225 8,257 COMPZ!CASING RUNL P Drop 29/32"setting ball and pump down @ 4 bpm-800 psi. Pump 50 bbl's decrease flow to 3 bpm-550 psi for 10 bbl's,decrease rate to 2 bpm for 10 bbl's-300 psi. Decrease to final circulating rate of 1 bpm-200 psi until ball seated. Ball on seat with 76 bbl's pumped.Allow pressure to increase to 700 psi and held for 5 min. Increased pressurre to 2,500 psi, Slack off on hanger from 157k to 60k. Increase pressure to 3,500 psi hold for 5 min. Pick up to verify liner hanger set. 140k up weight-Hanger set and released. Liner top 8,257' MD 01:30 02:00 0.50 8,257 8,257 COMPZ CASING OWFF P Rack back stand. Monitor well-No flow with slight drop in fluid level of 1' below flow line in 30 min. 02:00 06:30 4.50 8,257 0 COMPZ DRILL TRIP P Trip out of hole with liner setting tool. Lay down Baker setting tool per Baker rep.Calculated hole fill 47.4 bbl's.Actual hole fill 52.25 bbl's. 06:30 07:00 0.50 0 0 COMPZ RPCOM RCST P Clear and Clear floor, Rig up to run 4-1/2"IBT-M 12.6 L-80 Tubing. 07:00 07:30 0.50 0 0 COMPZ RPCOM SFTY P Hold pre-job safety meeting with rig crew, Baker rep, Doyon casing hand, toolpusher and rig supervisers. Discuss running order. Hazards and mitigation. 07:30 13:00 5.50 0 2,877 COMPZ RPCOM RCST P Make up lower 4-1/2"completion tools per detail. Baker lok connections per detail. Run in hole picking up 4-1/2"IBT-M 12.6 L-80 Tubing T/2,877'MD. Up 57k Down 57k. Calculated displacement 12 bbl's actual displacement 5.5 bbl's 13:00 17:30 4.50 2,877 8,260 COMPZ RPCOM RCST P Run 4-1/2" IBT-M 12.6 L-80 Tubing F/2,877'-T 8,259'MD. Set down 7k to shear brass pins,slacked off 1' and set 15k down on No-Go @ 8,260'MD. Pulled up and layed down 1 joint(#205)Make up crossover for brine displacement. 17:30 20:00 2.50 8,220 8,220 COMPZ RPCOM CIRC P Pump 35 bbl's 10.1 ppg spacer, Pump 10.3 ppg clean up brine 150 bbl's, Pump 10.3 ppg brine 154 bbl's, Pump 30 bbl's 10.3 ppg inhibited brine and chased with 120 bbl's clean brine.Total strokes pumped 4,842 @ 3 bpm-500 psi. 20:00 20:30 0.50 8,220 8,220 COMPZ RPCOM OWFF P Monitor well(Taking fluid) Page 31 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:45 2.25 8,220 0 COMPZ RPCOM THGR P Space out by Laying down 3 joints of 4-1/2"IBT-M 12.6 L-80 Tubing. Pick up 4 pup joints(5.71'-5.82'-7.80'- 9.76' order placed in string)pick up joint#202 and make up wear bushing retreival tool, Pull wear bushing. Run joint#203,make up hanger and land hanger with landing joint. lay down landing joint. 22:45 00:00 1.25 0 0 COMPZ RPCOM PRTS P Set two Way Check,make up crossover to landing joint(B)for hanger seal test. 04/05/2011 Land tubing hanger and test.Test failed, PU new hanger and test ok. Set packer and test tbg&IA. Freeze protect with diesel. ND BOP, NU tree and test ok. Begin to LDDP. 00:00 00:30 0.50 0 0 COMPZ RPCOM PRTS P Make up landing joint in hanger. Rig up to test hanger seals 250 psi low 5,000 psi high.Test charted.Good low test. High test failed. 00:30 01:00 0.50 0 0 COMPZ RPCOM PRTS T Rig down test equipment and landing joint. 01:00 02:00 1.00 0 0 COMPZ RPCOM THGR T Shift poppet on top of 2 way check verify no pressure. Pull 2 way check. well on vacuum stripped lower seal off two way check. Seal down tubing. Make up full open floor safety valves. Prep to pull hanger. 02:00 03:00 1.00 0 0 COMPZ RPCOM THGR T Make up landing joint and back out lockdowns. Unseat hanger and pull to floor. Upon pulling hanger free hole was filled taking 4 bbl's of 10.3 ppg brine. Lay down hanger and make up new elastomer seal hanger on landing joint. Run hanger and land. Run in lock downs. Up wt 120K down 94k. 03:00 03:30 0.50 0 0 COMPZ RPCOM THGR P Pull Landing joint set 2 way check 03:30 04:30 1.00 0 0 COMPZ RPCOM PRTS P Make up landing joint and test equipment.Test upper and lower hanger seals. 250 psi low-5,000 psi high for 5 minutes. (Good test)Rig down test equipment. 04:30 06:30 2.00 0 0 COMPZ RPCOM PRTS P Drop ball and rod. Pres up and set packer with 2700 PSI. Continued to 3500 PSI and test for 30 min. Bleed tubing to 2000 PSI and pres up on 1 PC tbq X annulus to 3500 PSI for 30 min. Bleed tbg to zero and shear DCK-2 valve @ 2500 PSI. Bleed tubing and annulus to zero 06:30 08:00 1.50 0 0 COMPZ DRILL PRTS P Set two way check and test f/below to 2550 psi for 5 min. Bleed off pressure and monitor tbg X IA for 30 min(static) 08:00 09:00 1.00 0 0 COMPZ WHDBO NUND P PJSM. ND BOP. Held spill drill. 09:00 11:00 2.00 0 0 COMPZ WHDBO PRTS P N/U tree and test to 250/5000 PSI for 10 min. Page 32 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:00 2.00 0 0 'COMPZ WHDBO NUND P RD test equip. RU lubricator and pull TWC. RD lubricator. 13:00 15:00 2.00 0 0 COMPZ DRILL FRZP P RU L.R.S.and pump 75 BBL diesel do IA for freeze protect. U-tube from annulus to tubing. 15:00 17:00 2.00 0 0 COMPZ WHDBO NUND P RD L.R.S.,remove secondary annulus valve, install blind flange and guage on OA&IA. 17:00 00:00 7.00 0 0 COMPZ DRILL PULD P PJSM. Begin LDDP. 04/06/2011 LDDP and Release Rig 00:00 03:30 3.50 0 0 COMPZ MOVE PULD P Continue to LD 4"Drillpipe 03:30 08:00 4.50 0 0 COMPZ MOVE DMOB P Clean pits, Rockwasher. Release Rig at 0800,4/6/2011. Page 33 of 33 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday,June 17,2011 TO: Jim Regg P.I.Supervisor Kef7 L(.°1 I1 SUBJECT:Mechanical Integrity Tests , CONOCOPHILLIPS ALASKA INC CD3-198 FROM: Matt Herrera COLVILLE RIV FIORD CD3-198 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv;60,-- NON-CONFIDENTIAL Comm Well Name: COLVILLE RIV FIORD CD3-198 API Well Number: 50-103-20637-00-00 Inspector Name: Matt Herrera Insp Num: mitMFH110617110710 Permit Number: 211-024-0 Inspection Date: 6/12/2011 Rel Insp Num: T Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i CD3-198-Type Inj. w ' TVD 6852 IA 1100 1998 - 1965 11960 r P.T.D 2110240'!ITypeTest SPT Test psi 1713 OA 510 622 625 625 Interval INITAL ' p/F P - Tubing r 1923 1 1924 1925 1 1923 Notes: Friday,June 17,2011 Page 1 of 1 ) Z//-02 'i MECHANICAL INTEGRITY REPORT SPUD DAT:- : 3712-0 OPER & FIELD Cti4-1 — =G RELEASE : ' S-/( WELL NUMBER Gv 3 -19 8 WELL DATA TD : /322$_ .. 7o38 TVD ; =BTD : /322`( MD 703V iTvD 4 Si Shoe: .26r ( MD 9 STVD DV: TVD MD sW-� Casing : a �Ts .r't "Liner : 7a Shoe : '729 1-D 7a0Y TVD ; TOP : 1•0D TVD 11,55" _ lbinE352Y Packer Yf37:-4 $S/ TVD ; Set at � :ole Size ��S „ and ; 3,_r: 77Z-r to 13224 • SLoTTeo LI,VE� 'CTIANICAL INTEGRITY - PART 11 f � Annulus Press Test: Ip3Wv ; 15 min ; 30 min - . Comments : J lC r S 6 S i 21m;i /A- ,- M~'CHANICAL INTEGRITY - PART #2 Cement Volumes Amt. Liner5'(' 66-5 Csg T ; DV Cmt vol to cover perfs 13/34.3• f 307• X S Theoretical IOC -7/ P3 M (� 77o6 'tiero Cement Bond Log (Yes or No) EAT— ; In AOGCC File '' CBL Evaluation, zone above perfs kid( ee ,. �.P D �•► - s �.•/s-ri h yra..e, 7§rS-o (44.- N Der Se-e-h 11 ic? s1pr Q Production Log: Type 6//1- ; Evaluation 7G o0 CONCLUSIONS : /1 Part r 1 : Wi�hesseJ M.Cr--- 1A t u c.re- . Part !2: ja ja.,.4- Vol&-4.- 1 soi c-J 130.--e rs0 ez-. • Cf HALLIBURTON Sperry Drilling WELL LOG TRANSMITTAL To: State of Alaska April 7, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-198 AK-MW-0007896847 CD3-198 50-103-2637-00 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5"TVD TRIPLE COMBO Logs: 1 Color Log 2"x 5" MD BAT SONIC Logs: 1 Color Log 2" x 5"TVD BAT SONIC Logs: 1 Color Log 1" x 5" BAT Cement Log: 1 Color Log Digital Log Images & LWDG-formatted LIS Data w/verification listing: 1 CD Digital Log Images 1" x 5" BAT Cement Log 1 CD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 ,Oi t -02-4/ a p 3 Bryan.Burinda@halliburton.com Date: '.` r r Signed: a5z SlfR\ITE T ALASEA SEAN PARNELL, GOVERNOR 7�T II ALASKA OIL GAS 333 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-198 ConocoPhillips Alaska, Inc. Permit No: 211-024 Surface Location: 3888' FNL, 641' FEL, SEC. 05, T12N, R5E, UM Bottomhole Location: 1608' FNL, 217' FEL, SEC. 09, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. 7( Chair DATED this2.day of February, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) r. STATE OF ALASKA FEB 1 5 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL `, .',7,--"kiat P C,? ,as.C.. ,sion 20 AAC 25.005 11 ii w L:,. ,.aG 1a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone 0. lc.Specify if well is proposed for: Drill Q. Re-drill❑ Stratigraphic Test ❑ Development-Gas/ ❑ Service-Supply ❑ Multiple Zones Coalbed Gas ❑ Gas Hydrates❑ / Re-entry ❑ Exploratory ❑ Service-WAG ❑ 'Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 , CD3-198 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 15571' • TVD: 7047' • Colville River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): 3888'FNL,641'FEL,Sec.5,T12N,R5E,UM ' ADL 372104,372105 Fiord Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1329'FNL,4295'FEL,Sec.4,T12N,R5E,UM LAS2112 3/1/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1608'FNL,217'FEL,Sec.9,T12N,R5E,UM 2560 +/-1.5 miles to ADL 391451 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: . 40.8 feet 15.Distance to Nearest Well Open Surface:x- 388402.4 . y- 6003883.2 Zone- 4 GL Elevation above MSL: . 12.8 feet to Same Pool: CD3-199,2185 16.Deviated wells: Kickoff depth: 232 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 89.84° deg Downhole:3189 psig Surface:2484 psig • 18.Casing Program: Specifications I Top - Setting Depth -$ottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD `VD (including stage data) 24" 16" 62.5 H-40 Welded 71 37 37 108 ,A108 Pre Installed 12.25" 9.625" 40 L-80 BTC 1370 37 37 1407 V1"1388 397 sx AS Lite 3,232 sx 15.8'G' 14- i 12.25" 9.625" 36 J-55 BTC 1200 1407 1388 2607 ' 2450 . Z•ZY•1! 8.75" 7" 26 L-80 BTC-M 6971 37 37 $G 41- 700$ 1st-240 sx 15.8'G' 2nd-186 sx 15.8 G _ 4.5" 12.6 L-80 IBT-M 8268 32 32 8300 6923 Tubing 6.125" 4.5" 12.6 L-80 SLHT 7261 8300 6923 15561 7046 Slotted liner with blanks 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program Time v.Depth Plot❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Ryan Robertson 265-6318 Printed Name Chip Alvord Title Alaska Drilling Manager "46-- Signature 4-1-7- GAe.i 1-4-4%/4-1- F4k Phone 265-6120 Date �-(P /rt-4x0 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 2 l C�%2- C) 50-t, r -(- :>Date: (II/��t�� for other requirements Conditions of approval: If box is checked,well ma not be used to explore for,test,or produce coalbed m ane,gas hydrates,or gas contained in shales: 3 S OD p s c 1:30PsOP f Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No 1161. Other: 042.SDO es,: An,,«,--(--- ( ;S 4..H2S measures: Yes ❑ No .. Directional svy req'd: Yes [ No ❑ n "IF Di1)Gi-•Fcr Loa iUe-Jr iii-GLZA i4AC- 2 c s (h)CZ) 0 #4 l [- i CB L Y e�u.�/ a.1' ,# K if;ft,$44- Orr ;1"h Ib. C pT-Or i Aio 3 Q APPROVED BY THE COMMISSION 2/ZS 7/ DATE: ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid fo 2 nR4 fe,ArI3vaI(20 AAC 25.005(8)) Submit�i p ConocoPhillips Alaska, Inc. `, Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 Feb 6th, 2011 p;71 «ate'_ Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 5 2011 Anchorage, Alaska 99501tie-7 1,4 ar r;ohs.i ,Sper Re: Application for Permit to Drill CD3-198 Ale gc„. Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD3 (Fiord) pad. The intended spud date for this well is March 1st, 2011. It is intended that Doyon Rig 141 be used to drill the well. CD3-198 will penetrate the reservoir horizontally. After setting the 7" intermediate casing, the horizontal section will be drilled and the well completed as a Nechelik inJeor. Once completed, the well will be flowed back to mitigate reservoir damage and then hooked up to begin injection. It is expected that the K2 (Qannik)sand could be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement through the intermediate casing shoe and then open a stage tool and pump a second cement job to isolate the K2 formation with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. This will be C) the 7th winter season of drilling on the Fiord pad and there has not been a significant indication of shallow gas / or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program with request for approval of annular pumping operations 3. A proposed completion diagram 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Ryan Robertson at 265-6318, or Chip Alvord at 265-6247. Sincerely, Ryan Robertson Attachments cc: CD3-198 Well File/Sharon Allsup Drake ATO 1530 Liz Galiunas ATO 1500 Ryan Robertson ATO 1702 Nina Anderson ATO 1706 Lanston Chin Kuukpik Corporation CD3-198 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Employ gyro single shots and traveling cylinder diagrams. Gas Hydrates Low Monitor well at base of permafrost, increase mud weight, decreased mud viscosity, increase circulating times, control drilling rates and low mud temperatures. Running Sands and Gravel Low Maintain planned mud parameters, increase mud weight if needed and use weighted sweeps. Abnormal Pressure in Low Increase mud weight to 9.6—9.8 ppg. Surface Formations • >2000'TVD Lost Circulation Low Reduced pump rates,thin mud rheology, pump LCM pills and use of low density cement slurries. 8-3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills. Mud weight of 9.6 ppg or higher. Flow Surface Formations • checks during connections. Mud weight increase if >2000'TVD needed. Lost circulation Low Reduced pump rates and trip speeds. Real time equivalent circulating density(ECD)monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties. Ensure proper hole fill. Pump out of hole if needed. Monitor real time equivalent circulating density(ECD). Use of weighted sweeps. Abnormal Reservoir Low Well control drills. Increase mud weight. No mapped Pressure • faults occur within 700'of the planned wellbore. Hydrogen Sulfide gas Low H2S drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengers. 6-1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates and trip speeds. Real time equivalent circulating density(ECD)monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds. Pump out to 7"shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density(ECD). Use weighted sweeps. Abnormal Reservoir Medium BOPE drills. Keep mud weight above 8.8 ppg. V Pressure • Check for flow during connections and if needed. Increase mud weight if necessary. Perform well control drills. Hydrogen Sulfide gas Low H2S drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengers. ORIGtNAL Fiord Nechelik : CD3-198 Procedure 1. Move rig onto CD3-198. 2. Rig up riser. - Diver ter Wei;✓c•� 3. Drill 12-1/4"hole to surface casing point as per the directional plan(Directional/GR/RES) 4. Run and cement 9-5/8"surface casing. 5. Install BOPE and test to 3,500 psi high and 250 psi low. 6. Pick up and run in the hole with 8-3/4"drilling BHA. 7. Pressure test casing to 2,500 psi. 8. Drill out 20'of new hole and perform leak off test. 9. Drill 8-3/4" hole to intermediate casing point into the Nechelik reservoir sand(Directional/GR/RES). 10. Run and cement 7" casing as per drilling program. If needed, a second stage cement job will be pumped to isolate the K2(Qannik)formation. J 11. Perform a leak off test down the 9-5/8" x 7" annulus to confirm the fracture pressure referenced to the surface casing shoe. Freeze protect casing annulus to surface. 12. Perform BOPE test to 3,500 psi high and 250 psi low. ✓ 13. Pick up and run 6-1/8"drilling BHA. 14. Drill out HES cementing tool used to isolate the Qannik formation. 15. Pressure test 7" intermediate casing to 3,500 psi. 16. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is =- 11.0 11.0 ppg EMW. 17. Perform MADD pass with BAT Sonic tool while tripping to bottom to ensure first stage cement quality. C&L- 18. Displace well to Flo-Pro mud system. 19. Drill 6-1/8" horizontal section to well TD(LWD Program: GR/RES/DENS/NEUT/PWD) 20. Circulate hole clean and pull out of hole. , 21. Run lower completion-4-1/2", 12.6 ppg, L-80 slotted liner with blanks across shale. • 22. Run upper completion:4-1/2", 12.6 ppf, L-80 tubing with DB Profile,GLM, Premier Packer, and XN nipple. ' 23. Drop ball and rod to set packer. . 24. Install two way check valve and pressure test hanger seals to 5,000 psi. Pull TWC. 25. Test tbg to 3500 psi for 30 minutes. Bleed down tbg to 2000 psi and pressure test annulus to 3500 psi for 30 minutes. Bleed tbg to 0 psi to sheer casing to tbg DCK-2 SOV. Bleed tubing and annulus pressure to zero. 26. Install TWC and pressure test through SOV to 1000 psi in the direction of flow. Nipple down BOP" 27. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 28. Circulate tubing to diesel and install freeze protection in the annulus. 29. Set BPV and secure well. Move rig off CD3-198. ORIGINAL Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following , attachments. CD3-110 is the closest existing well with a clearance factor less than 2.0. Ellipse to ellipse separation is 59.81' @ 7,318' MD. Drilling Area Risks: There are no high risk events anticipated. • No over pressured zones are expected. • Faulting within the Nechelik reservoir is considered to be the most likely cause of lost circulation. Standard LCM • material is expected to be effective in dealing with any drilling fluid losses to the drilled formations. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3-199 will be injected into a permitted annulus on the CD3 pad, or the class 1 disposal well on CD1 pad. The CD3-199 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000'TVD. Significant hydrocarbon zones include the Nechelik reservoir, and potentially the Qannik and Kuparuk reservoir.There will be 500'of cement fill placed above the top of the Kuparuk reservoir, along with 500' of cement above and below the Qannik reservoir as per regulations. Once CD3-199 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containingsignificant hydrocarbons will be isolatedprior to initiatingannularpumping. There will be no 9 Y USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation(C-40). These 450-500'thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure=(12.0 0.052 (Surf. Shoe TVD)+ psi ppg)*( ) 1,500 =(12.0 ppg)*(0.052)*(2450')+ 1,500 psi = 3028 psi Pore Pressure = 1,108 psi Therefore Differential = 3028— 1108= 1920 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength byusingthe 85%collapse and burst ratings listed in the followingtable: 9 P 9 Wt Connection 85%of 85%of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi 2,626 psi 5,750 psi 4,887 psi 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3520 psi 2,992 psi I _ 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi DRILLING FLUID PROGRAM SPUD to 9-5/8" Intermediate hole to 7" Production Hole surface casing point casing point—8 3/4" Section—6 1/8" — 12 1/4" Density 8.7—9.8 ppg 9.6—9.8 ppg 9.0 ppg PV 10— 16 7—12 YP 30-60 13- 16 10-15 Funnel Viscosity 70—300 Initial Gels 8—10 6-9 10 minute gels <20 8- 12 API Filtrate NC— 10 cc/30 min 5—12 cc/30 min (drilling) g HPHT Fluid Loss at 10 cc/30 min 165 8.5-9.0 9.0- 10.0 9.0-9.5 PH KCL 6 % Surface Hole: A standard high viscosity fresh water gel spud mud is planned for the surface interval. Flow line viscosity will be kept at± 300 sec/qt while drilling gravels. Viscosity prior to cementing will be reduced to ± 80-100 sec/qt. Mud weight will be maintained at <9.8 ppg by use of solids control system and dilution where necessary. Using cold make up water will help keep the flow line temperature as low as possible. Intermediate Hole Section: A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists, particularly after the Nechelik reservoir is penetrated. Mud weight will be maintained at or below 9.8 ppg to minimize losses, and lost circulation material will be introduced to the system if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids(by diluting as required)will all be beneficial in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a MI Swaco's Flo-Thru drill-in fluid. The base fluid will consist of 6% KCI, with calcium carbonate bridging material to minimize formation damage. Flowzan Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. Klagard will be used for inhibition. ECD's will be monitored with real time PWD data, and controlled by maintaining fluid rheology and pump rates within specifications. Completion Schematic Colville River Field CD3-198 Nechelik Injector Well Completion J ' 1 16"Conductor to 114' Updated 02/07/2011 • 4-1/2" 12.6 ppf IBT M tubing run with Sperry Drilling Services OJet Lube Run'n'Seal pipe dope CD3-198wp07 3 DB Nipple @ 2093'MD/2000'TVD 9-5/8"40 ppf L-80 BTC-Mod Surface Casing 1,407'MD/1388'TVD 9-5/8"36 ppf J-55 BTC Surface Casing 1407'MD/1388'TVD to 2607'MD/2450'TVD Cemented to surface TOC 4558'MD/ 4080'TVD Qannik interval top+/-4558'MD/4080'TVD • ES Cementer 5083'MD/ 1 0 0 4503'TVD Upper Completion MD TVD 1)Tubing Hanger 32' 32' 2)4-W 12.6#/ft IBT-Mod Tubing 3)Camco DB Landing Nipple(3.813"ID) 2093' 2000' 4)4-W 12.6#/ft IBT-Mod Tubing 5)Camco 41/2"KBG-2 GLM with DV(3.883"ID) 8100' 6843' 6) 4-W 12.6#/ft IBT-Mod Tubing (2 joints) 7) Baker 4.5"X 7"Premier Packer 8200' 6885' 8) 4'/2"12.6#/ft IBT-Mod Tubing (1 joints) 9) HES No-Go"XN"(3.725"min ID)C7 68° 8250' 6905' 10) 4-W 12.6#/ft IBT-Mod Tubing 11) 4-W 12.6#/ft IBT-Mod flutted WLEG 8300' 6923' Lower Completion: Too MD TVD 12) HRD Setting Sleeve w/10'Tie back extension 8300' 6923' 13) Baker 5"x7"Flexlock Liner Hanger w/setting sleeve 8316' 6928' 14) 4'/2"12.6#/ft L-80 SLHT blank&Slotted liner 15)Orange Peel Shoe with 4-W 12.6#L-80 Box Up 15561' 7046' 1°\) . AM TOC Calculated O 14 7464'MD/6460'TVD • 11 • f36 __________-- l Top Kuparuk C at 7964'MD/6776 TVD Top Nechelik at 8662'MD/7008'TVD 6 1/8"Well TD • 7"26 ppf L-80 BTC Mod Casing 8662'/7008'TVD 15571'MD / • 7046'TVD ' ORIGINAL p!. CD3-198 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005( c)(3,4)and as required in 20 ACC 25.035(d)(2)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (lbs./gal) (psi) (psi) 16 114/114 10.9 52 53 9 5/8 2607/2450 14.5 1109 1602 7" 8662/70 16.0 2484 N/A 15771 047 ' 16.0 3189** N/A • NOTE: The Doyon 141 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. • **NOTE: Pore Pressure for production interval is estimated reservoir pressure PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)-0.1]D Where: ASP=Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP= [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1]x 114= 53 psi OR ASP= FPP—(0.1 x D) = 1109—(0.1 x 2450')=864 psi 2. Drilling below surface casing (9 5/8") ASP= [(FG x 0.052 —0.1] D = [(14.5 x 0.052)—0.1]x 2450= 1602 psi OR ASP= FPP—(0.1 x D) = 3171 —(0.1 x 7008')=2470 psi 3. Drilling below intermediate casing(7") ASP= Reservoir Pressure—(0.1 x D) = 3189—(0.1 x 7047')=2484 psi ORIGINAL Cementing Program: 9 5/8" Surface Casing run to 2607' MD/2450' TVD. Cement from 2607' MID to 2107' (500' of fill)with Class G+Adds @ 15.8 PPG, and from 2107' to surface with Arctic Set Lite 3.Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(1234' MD). Lead slurry: (2107'-1234')X 0.3132 ft3/ft X 1.5 (50% excess)=410 ft3 below permafrost (1234' -80')X 0.3132 ft3/ft X 3.5 (250% excess)= 1265 ft3 above permafrost ConductorVolume= 80' X 0.7632 ft3/ft = 61 ft Total volume=410+ 1265 +61 = 1736 ft3 =>387 Sx @ 4.49 ft3/sk System: 387 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.49 ft3/sk Tail slurry: 500' X 0.3132 ft3/ft X 1.5,.(50% excess) =235 ft3 annular volume ✓ 80' X 0.4258 ft3/ft= 34 ft3 shoe joint volume Total volume=235 +34=269 ft3=>232 Sx @ 1.16 ft3/sk System: 232 Sx Class G+ 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.16 ft3/sk 7"Intermediate Casing run to 8662' MD/7008' TVD: Cemented in two stages Cement from 8662' MD to 7464' MD (300' MD above the packer & minimum 500' MD above top of Kuparuk reservoir)with Class G+adds @ 15.8 PPG.Assume 40% excess annular volume. First Stage: Lead: (8662' -7464')X 0.1503 ft3/ft X 1.4 (40% excess) =252 ft3 annular vol. 120' X 0.2148 ft3/ft=26 ft3 shoe joint volume Total volume=252+26=278 ft3=>240 Sx @ 1.16 ft3/sk System: 240 Sx Class G+0.2% D046 antifoamer, 0.25%D065 dispersant, 0.25%D800 retarder and 0.18%D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a stage tool set 500' below the Qannik(K2)interval to +/- 500' above the K2 interval with Class G+additives @ 15.8 ppg. AWsirtne 40% excess annular volume Lead: (5083' -4058')X 0.1503 ft3/ft X 1.4(40% excess)=216 ft3 annular vol. Total Volume=216 ft3=> 186 Sk @ 1.16 ft3/sk System: 186 Sx Class G+0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.16 ft3/sk ORIGINAL I ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3-198 Plan: CD3-198 Plan: CD3-198wp07 a.k.a. 110 South or G Standard Proposal Report permit Pack 18 January, 2011 Very shallow kick- off. High doglegs. Surface Casing REVISED Depth changed. 3:12 pm, Jan 17, 2011 Formation tops and toolcodes updated. HALLIBURTON Sperry Drilling Services ORGNAL 1 4,r Northing (5000 ft/in) r I I I I I I I I 1 I I I t 11111111 1 I I I I , I I I I I 1 1 1 1 1 I I I I 1 I I I I I 1 1 1 1 I 1 I ( 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -4- N _ M M O — U LI- 0p.-- Ln - d o - cn in M M M M — p U U v o I o •co MU o a p 0 N Q ♦ (O h p �� CO O m M U — 0 3 v- . p N 0 p� U C - U 411. ) d • ,'N _ s _ . a _ co M . M - O - O— \_ p N - O O c� p ;AL N. 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N O x— 03 —O M CDOcp _in cn I 1 I I co o i � o co I . co d) O o) N .- (u n 0g6) (+)4poN/(-)umoS N, ORIGINAL 0 0 N. L0dM86 L-£ao > o 1.2.99 1- _ o C r, o O 0009L _ ._ 14•106 V X o C 000t4 _ N —L0 c 000£L 0 0 _0 0 .06 0 Lr) co 000ZL o O N O 000u _o ca C O U a) 0 O 0000E o r O v' N ° p -o r O G "' �p po 0006 _ 0 Om co o 40 000 v co r•-• .— . s 00 r•-• CO x co `C) CD I CI) o -o M CO 0 o O 0 Lo 1- or - 0 0 0 0 0 0 CD 0 CD 0 0 LO o Lc) o , co d o N (u1/14 0091-) yide le3ITJOA en-11 Y, i % s t E L . t +... ConocoPhillips ##, HALLIBURTON Standard Proposal Report T.` Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-198 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) • Project: Western North Slope MD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-198 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-198 Design: CD3-198wp07 Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site CD3 Fiord Pad Site Position: Northing: 469.98ft Latitude: 53°58'43.652 N From: Map Easting: 401.27ft Longitude: 152°19'30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88° Well Plan:CD3-198 Well Position +N/-S 0.00 ft Northing: 6,003,883.15 ft • Latitude: 70°25'10.432 N +E/-W 0.00 ft Easting: 388,402.44 ft - Longitude: 150°54'32.901 W LPosition Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.50ft • Wellbore Plan:CD3-198 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) i BGGM2009 1/17/2011 16.38 79.74 57,376 Design CD3-198wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 142.00 [Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 -12.50 0.00 0.00 0.00 0.00 0.00 0.00 231.70 0.00 0.00 231.70 191.20 0.00 0.00 0.00 0.00 0.00 0.00 1 . 742.85 6.64 60.00 741.70 701.20 14.80 25.64 1.30 1.30 0.00 60.00 894.27 9.04 51.54 891.70 851.20 26.58 42.54 1.75 1.58 -5.59 -30.00 1,291.48 17.51 27.63 1,278.21 1,237.71 99.12 94.82 2.50 2.13 -6.02 -45.00 1,767.83 29.00 4.28 1,716.00 1,675.50 278.73 136.91 3.05 2.41 -4.90 -50.01 3,226.40 29.00 4.28 2,991.70 2,951.20 983.90 189.69 0.00 0.00 0.00 0.00 3,635.69 36.30 357.37 3,336.20 3,295.70 1,204.23 191.54 2.00 1.78 -1.69 -30.00 5,863.56 36.30 357.37 5,131.70 5,091.20 2,521.77 131.10 0.00 0.00 0.00 0.00 7,048.81 35.18 72.00 6,138.04 6,097.54 2,998.78 453.99 3.50 -0.09 6.30 123.00 7,870.81 55.23 109.86 6,724.57 6,684.07 2,956.09 1,012.12 4.00 2.44 4.61 68.22 8,661.71 83.00 134.18 7,007.50 6,967.00 2,559.30 1,618.82 4.51 3.51 3.07 44.51 8,711.71 83.00 134.18 7,013.59 6,973.09 2,524.71 1,654.41 0.00 0.00 0.00 0.00 8,934.55 89.84 134.18 7,027.50 6,987.00 2,369.81 1,813.81 3.07 3.07 0.00 0.00 9,270.35 89.84 144.25 7,028.45 6,987.95 2,115.87 2,032.87 3.00 0.00 3.00 90.04 15,571.45 89.84 144.25 7,046.50 7,006.00 -2,998.17 5,713.92 0.00 0.00 0.00 0.00 1/18/2011 2:59:05PM Page 2 COMPASS 2003.16 Build 69 OR1GNAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-198 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.5©40.50ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-198 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-198 Design: CD3-198wp07 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (°) (ft) ft (ft) (ft) (ft) (ft) -12.50 28.00 0.00 0.00 28.00 -12.50 0.00 0.00 6,003,883.15 388,402.44 0.00 0.00 100.00 0.00 0.00 100.00 59.50 0.00 0.00 6,003,883.15 388,402.44 0.00 0.00 200.00 0.00 0.00 200.00 159.50 0.00 0.00 6,003,883.15 388,402.44 0.00 0.00 231.70 0.00 0.00 231.70 191.20 0.00 0.00 6,003,883.15 388,402.44 0.00 0.00 Start Build 1.30 300.00 0.89 60.00 300.00 259.50 0.26 0.46 6,003,883.41 388,402.90 1.30 0.07 400.00 2.19 60.00 399.96 359.46 1.61 2.78 6,003,884.72 388,405.25 1.30 0.45 500.00 3.49 60.00 499.83 459.33 4.08 7.07 6,003,887.13 388,409.57 1.30 1.14 600.00 4.79 60.00 599.57 559.07 7.69 13.32 6,003,890.64 388,415.87 1.30 2.14 700.00 6.09 60.00 699.12 658.62 12.43 21.53 6,003,895.26 388,424.15 1.30 3.46 742.85 6.64 60.00 741.70 701.20 14.80 25.64 6,003,897.57 388,428.30 1.30 4.12 /; Start DLS 1.75 TFO-30.00 800.00 7.53 56.18 798.42 757.92 18.54 31.61 6,003,901.22 388,434.32 1.75 4.85 894.27 9.04 51.54 891.70 851.20 26.58 42.54 6,003,909.09 388,445.37 1.75 5.24 Start DLS 2.50 TFO-45.00 900.00 9.14 50.90 897.36 856.86 27.15 43.25 6,003,909.65 388,446.08 2.50 5.23 r 1,000.00 11.06 41.75 995.81 955.31 39.32 55.80 6,003,921.63 388,458.82 2.50 3.37 f 1,100.00 13.18 35.40 1,093.58 1,053.08 55.77 68.80 6,003,937.89 388,472.06 2.50 -1.59 1,200.00 15.41 30.81 1,190.48 1,149.98 76.48 82.21 6,003,958.39 388,485.78 2.50 -9.66 1,234.32 16.20 29.53 1,223.50 1,183.00 84.56 86.90 6,003,966.40 388,490.59 2.50 -13.13 Base Permafrost 1,291.48 17.51 27.63 1,278.21 1,237.71 99.12 94.82 6,003,980.84 388,498.73 2.50 -19.73 Start DLS 3.05 TFO-50.01 1,300.00 17.68 26.98 1,286.33 1,245.83 101.41 96.01 6,003,983.11 388,499.94 3.05 -20.81 1,400.00 19.80 20.13 1,381.03 1,340.53 130.85 108.73 6,004,012.36 388,513.10 3.05 -36.18 1,500.00 22.13 14.61 1,474.42 1,433.92 164.99 119.31 6,004,046.33 388,524.19 3.05 -56.56 1,600.00 24.61 10.13 1,566.21 1,525.71 203.72 127.73 6,004,084.92 388,533.19 3.05 -81.90 1,700.00 27.20 6.43 1,656.17 1,615.67 246.93 133.95 6,004,128.04 388,540.05 3.05 -112.12 1,767.83 29.00 4.28 1,716.00 1,675.50 278.73 136.91 6,004,159.79 388,543.49 3.05 -135.35 Start 1458.58 hold at 1767.83 MD 1,800.00 29.00 4.28 1,744.14 1,703.64 294.29 138.08 6,004,175.32 388,544.89 0.00 -146.89 1,900.00 29.00 4.28 1,831.60 1,791.10 342.64 141.70 6,004,223.60 388,549.23 0.00 -182.76 t, 2,000.00 29.00 4.28 1,919.06 1,878.56 390.98 145.31 6,004,271.88 388,553.57 0.00 -218.63 2,100.00 29.00 4.28 2,006.52 1,966.02 439.33 148.93 6,004,320.17 388,557.91 0.00 -254.50 2,200.00 29.00 4.28 2,093.99 2,053.49 487.67 152.55 6,004,368.45 388,562.25 0.00 -290.37 2,300.00 29.00 4.28 2,181.45 2,140.95 536.02 156.17 6,004,416.73 388,566.59 0.00 -326.24 2,400.00 29.00 4.28 2,268.91 2,228.41 584.36 159.79 6,004,465.01 388,570.93 0.00 -362.11 2,453.27 29.00 4.28 2,315.50 2,275.00 610.12 161.71 6,004,490.73 388,573.24 0.00 -381.22 C-40 2,500.00 29.00 4.28 2,356.37 2,315.87 632.71 163.41 6,004,513.29 388,575.27 0.00 -397.98 2,600.00 29.00 4.28 2,443.83 2,403.33 681.06 167.02 6,004,561.58 388,579.61 0.00 -433.85 2,607.05 29.00 4.28 2,450.00 2,409.50 684.46 167.28 6,004,564.98 388,579.92 0.00 -436.38 9-5/8"x 12-1/4" 2,663.65 29.00 4.28 2,499.50 2,459.00 711.83 169.33 6,004,592.31 388,582.37 0.00 -456.68 C-30 1/18/2011 2:59.05PM Page 3 COMPASS 2003.16 Build 69 ORG1NAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-198 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-198 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-198 Design: CD3-198wp07 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/S +E-A! Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,490.80 2,700.00 29.00 4.28 2,531.30 2,490.80 729.40 170.64 6,004,609.86 388,583.95 0.00 -469.72 2,800.00 29.00 4.28 2,618.76 2,578.26 777.75 174.26 6,004,658.14 388,588.29 0.00 -505.59 2,900.00 29.00 4.28 2,706.22 2,665.72 826.09 177.88 6,004,706.42 388,592.63 0.00 -541.46 3,000.00 29.00 4.28 2,793.68 2,753.18 874.44 181.50 6,004,754.71 388,596.97 0.00 -577.33 3,095.83 29.00 4.28 2,877.50 2,837.00 920.77 184.96 6,004,800.98 388,601.13 0.00 -611.70 C-20 3,100.00 29.00 4.28 2,881.14 2,840.64 922.78 185.11 6,004,802.99 388,601.31 0.00 -613.20 3,200.00 29.00 4.28 2,968.61 2,928.11 971.13 188.73 6,004,851.27 388,605.65 0.00 -649.07 3,226.40 29.00 4.28 2,991.70 2,951.20 983.90 189.69 6,004,864.02 388,606.80 0.00 -658.54 Start DLS 2.00 TFO-30.00 3,300.00 30.28 2.82 3,055.66 3,015.16 1,020.22 191.93 6,004,900.30 388,609.58 2.00 -685.78 3,400.00 32.05 1.01 3,141.23 3,100.73 1,071.94 193.64 6,004,951.98 388,612.07 2.00 -725.48 I 3,500.00 33.84 359.37 3,225.15 3,184.65 1,126.31 193.80 6,005,006.35 388,613.04 2.00 -768.23 3,600.00 35.65 357.87 3,307.31 3,266.81 1,183.28 192.41 6,005,063.33 388,612.50 2.00 -813.98 3,635.69 36.30 357.37 3,336.20 3,295.70 1,204.23 191.54 6,005,084.28 388,611.95 2.00 -831.02 Start 2227.87 hold at 3635.69 MD 3,700.00 36.30 357.37 3,388.03 3,347.53 1,242.26 189.80 6,005,122.33 388,610.77 0.00 -862.06 3,800.00 36.30 357.37 3,468.62 3,428.12 1,301.40 187.09 6,005,181.50 388,608.94 0.00 -910.34 3,900.00 36.30 357.37 3,549.21 3,508.71 1,360.54 184.37 6,005,240.67 388,607.11 0.00 -958.61 4,000.00 36.30 357.37 3,629.81 3,589.31 1,419.68 181.66 6,005,299.84 388,605.28 0.00 -1,006.88 4,100.00 36.30 357.37 3,710.40 3,669.90 1,478.82 178.95 6,005,359.00 388,603.46 0.00 -1,055.16 4,200.00 36.30 357.37 3,790.99 3,750.49 1,537.96 176.23 6,005,418.17 388,601.63 0.00 -1,103.43 4,300.00 36.30 357.37 3,871.58 3,831.08 1,597.10 173.52 6,005,477.34 388,599.80 0.00 -1,151.70 I 4,337.12 36.30 357.37 3,901.50 3,861.00 1,619.05 172.51 6,005,499.30 388,599.12 0.00 -1,169.62 K-3 4,400.00 36.30 357.37 3,952.18 3,911.68 1,656.24 170.81 6,005,536.51 388,597.97 0.00 -1,199.97 4,500.00 36.30 357.37 4,032.77 3,992.27 1,715.38 168.09 6,005,595.68 388,596.14 0.00 -1,248.25 4,517.04 36.30 357.37 4,046.50 4,006.00 1,725.45 167.63 6,005,605.76 388,595.83 0.00 -1,256.47 K-3 Basal 4,557.98 36.30 357.37 4,079.50 4,039.00 1,749.67 166.52 6,005,629.98 388,595.08 0.00 -1,276.24 K-2 4,600.00 36.30 357.37 4,113.36 4,072.86 1,774.51 165.38 6,005,654.84 388,594.31 0.00 -1,296.52 4,691.99 36.30 357.37 4,187.50 4,147.00 1,828.92 162.88 6,005,709.27 388,592.63 0.00 -1,340.92 K-2 Basal 4,700.00 36.30 357.37 4,193.96 4,153.46 1,833.65 162.67 6,005,714.01 388,592.48 0.00 -1,344.79 4,800.00 36.30 357.37 4,274.55 4,234.05 1,892.79 159.95 6,005,773.18 388,590.66 0.00 -1,393.06 4,900.00 36.30 357.37 4,355.14 4,314.64 1,951.93 157.24 6,005,832.35 388,588.83 0.00 -1,441.34 5,000.00 36.30 357.37 4,435.73 4,395.23 2,011.07 154.53 6,005,891.52 388,587.00 0.00 -1,489.61 5,100.00 36.30 357.37 4,516.33 4,475.83 2,070.21 151.81 6,005,950.68 388,585.17 0.00 -1,537.88 5,200.00 36.30 357.37 4,596.92 4,556.42 2,129.35 149.10 6,006,009.85 388,583.34 0.00 -1,586.15 5,300.00 36.30 357.37 4,677.51 4,637.01 2,188.49 146.39 6,006,069.02 388,581.51 0.00 -1,634.43 5,400.00 36.30 357.37 4,758.11 4,717.61 2,247.63 143.68 6,006,128.19 388,579.68 0.00 -1,682.70 5,500.00 36.30 357.37 4,838.70 4,798.20 2,306.77 140.96 6,006,187.36 388,577.86 0.00 -1,730.97 5,600.00 36.30 357.37 4,919.29 4,878.79 2,365.91 138.25 6,006,246.52 388,576.03 0.00 -1,779.24 5,700.00 36.30 357.37 4,999.88 4,959.38 2,425.04 135.54 6,006,305.69 388,574.20 0.00 -1,827.52 1/18/2011 2:59:05PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips i HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-198 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-198 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-198 Design: CD3-198wp07 I Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) 5,039.98 5,800.00 36.30 357.37 5,080.48 5,039.98 2,484.18 132.82 6,006,364.86 388,572.37 0.00 -1,875.79 5,863.56 36.30 357.37 5,131.70 5,091.20 2,521.77 131.10 6,006,402.47 388,571.21 0.00 -1,906.47 Start DLS 3.50 TFO 123.00 5,900.00 35.62 359.21 5,161.20 5,120.70 2,543.16 130.46 6,006,423.86 388,570.89 3.50 -1,923.72 6,000.00 33.90 4.56 5,243.37 5,202.87 2,600.10 132.28 6,006,480.76 388,573.56 3.50 -1,967.47 6,100.00 32.44 10.38 5,327.09 5,286.59 2,654.30 139.33 6,006,534.84 388,581.42 3.50 -2,005.83 6,200.00 31.27 16.63 5,412.05 5,371.55 2,705.56 151.59 6,006,585.91 388,594.44 3.50 -2,038.68 6,300.00 30.41 23.25 5,497.94 5,457.44 2,753.70 169.01 6,006,633.78 388,612.58 3.50 -2,065.89 6,400.00 29.91 30.15 5,584.42 5,543.92 2,798.52 191.54 6,006,678.26 388,635.77 3.50 -2,087.35 6,500.00 29.77 37.18 5,671.19 5,630.69 2,839.88 219.07 6,006,719.19 388,663.92 3.50 -2,102.98 6,516.48 29.79 38.34 5,685.50 5,645.00 2,846.35 224.08 6,006,725.59 388,669.03 3.50 -2,104.99 Albian 97 6,600.00 30.01 44.19 5,757.92 5,717.42 2,877.60 251.52 6,006,756.42 388,696.92 3.50 -2,112.73 6,700.00 30.61 51.03 5,844.28 5,803.78 2,911.55 288.75 6,006,789.81 388,734.66 3.50 -2,116.56 I 6,800.00 31.55 57.56 5,929.94 5,889.44 2,941.60 330.64 6,006,819.23 388,776.99 3.50 -2,114.45 6,883.24 32.58 62.70 6,000.50 5,960.00 2,963.57 368.94 6,006,840.62 388,815.61 3.50 -2,108.18 Albian 96 6,900.00 32.81 63.70 6,014.60 5,974.10 2,967.65 377.02 6,006,844.58 388,823.75 3.50 -2,106.42 7,000.00 34.34 69.39 6,097.94 6,057.44 2,989.59 427.72 6,006,865.76 388,874.77 3.50 -2,092.50 7,048.81 35.18 72.00 6,138.04 6,097.54 2,998.78 453.99 6,006,874.56 388,901.16 3.50 -2,083.57 Start DLS 4.00 TFO 68.22 7,100.00 35.98 75.24 6,179.68 6,139.18 3,007.17 482.55 6,006,882.52 388,929.85 4.00 -2,072.59 7,200.00 37.79 81.19 6,259.68 6,219.18 3,019.36 541.26 6,006,893.82 388,988.73 4.00 -2,046.05 7,300.00 39.87 86.64 6,337.60 6,297.10 3,025.93 603.56 6,006,899.47 389,051.11 4.00 -2,012.88 7,400.00 42.18 91.61 6,413.06 6,372.56 3,026.87 669.15 6,006,899.42 389,116.70 4.00 -1,973.24 7,500.00 44.69 96.15 6,485.68 6,445.18 3,022.16 737.70 6,006,893.68 389,185.17 4.00 -1,927.32 7,572.70 46.62 99.19 6,536.50 6,496.00 3,015.20 789.21 6,006,885.96 389,236.57 4.00 -1,890.12 Top HRZ 7,600.00 47.37 100.28 6,555.12 6,514.62 3,011.82 808.88 6,006,882.29 389,256.19 4.00 -1,875.35 7,700.00 50.17 104.07 6,621.04 6,580.54 2,995.91 882.36 6,006,865.28 389,329.41 4.00 -1,817.58 7,748.28 51.57 105.79 6,651.50 6,611.00 2,986.26 918.54 6,006,855.09 389,365.44 4.00 -1,787.70 a Base HRZ 1 7,800.00 53.10 107.55 6,683.11 6,642.61 2,974.51 957.76 6,006,842.76 389,404.47 4.00 -1,754.29 7,825.87 53.87 108.41 6,698.50 6,658.00 2,968.09 977.53 6,006,836.05 389,424.15 4.00 -1,737.06 K-1 7,870.81 55.23 109.86 6,724.57 6,684.07 2,956.09 1,012.12 6,006,823.53 389,458.54 4.00 -1,706.31 Start DLS 4.51 TFO 44.51 7,888.35 55.79 110.53 6,734.50 6,694.00 2,951.10 1,025.68 6,006,818.33 389,472.03 4.51 -1,694.02 Top Kuparuk D 7,900.00 56.17 110.97 6,741.02 6,700.52 2,947.68 1,034.71 6,006,814.78 389,481.01 4.51 -1,685.77 7,963.68 58.26 113.31 6,775.50 6,735.00 2,927.49 1,084.28 6,006,793.86 389,530.27 4.51 -1,639.34 I Top Kuparuk C I 7,982.86 58.90 114.00 6,785.50 6,745.00 2,920.92 1,099.28 6,006,787.07 389,545.16 4.51 -1,624.93 LCU 8,000.00 59A7 114.60 6,794.28 6,753.78 2,914.87 1,112.69 6,006,780.81 389,558.49 4.51 -1,611.90 1/18/2011 2:59.05PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-198 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-198 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-198 Design: CD3-198wp07 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,770.00 8,032.46 60.57 115.72 6,810.50 6,770.00 2,902.91 1,138.14 6,006,768.48 389,583.75 4.51 -1,586.82 Top Nuiqsut 8,100.00 62.87 117.98 6,842.50 6,802.00 2,876.04 1,191.19 6,006,740.82 389,636.39 4.51 -1,532.98 8,200.00 66.34 121.17 6,885.39 6,844.89 2,831.43 1,269.71 6,006,695.04 389,714.23 4.51 -1,449.48 8,293.72 69.66 124.00 6,920.50 6,880.00 2,784.62 1,342.90 6,006,647.15 389,786.70 4.51 -1,367.54 Base Nuiqsut 8,300.00 69.88 124.19 6,922.67 6,882.17 2,781.32 1,347.78 6,006,643.78 389,791.53 4.51 -1,361.94 8,400.00 73.46 127.07 6,954.12 6,913.62 2,726.02 1,424.90 6,006,587.33 389,867.81 4.51 -1,270.88 8,500.00 77.09 129.85 6,979.54 6,939.04 2,665.87 1,500.60 6,006,526.06 389,942.59 4.51 -1,176.87 8,600.00 80.74 132.54 6,998.77 6,958.27 2,601.24 1,574.41 6,006,460.35 390,015.42 4.51 -1,080.50 8,661.71 83.00 134.18 7,007.50 6,967.00 2,559.30 1,618.82 6,006,417.75 390,059.20 4.51 -1,020.11 Start 50.00 hold at 8661.71 MD-Top Nechelik-7"x 8-3/4" 8,700.00 83.00 134.18 7,012.17 6,971.67 2,532.81 1,646.07 6,006,390.86 390,086.05 0.00 -982.46 8,711.71 83.00 134.18 7,013.59 6,973.09 2,524.71 1,654.41 6,006,382.64 390,094.26 0.00 -970.95 Start Build 3.07 8,800.00 85.71 134.18 7,022.28 6,981.78 2,463.49 1,717.41 6,006,320.48 390,156.34 3.07 -883.91 8,900.00 88.78 134.18 7,027.08 6,986.58 2,393.89 1,789.04 6,006,249.82 390,226.91 3.07 -784.97 8,934.55 89.84 134.18 7,027.50 6,987.00 2,369.81 1,813.81 6,006,225.38 390,251.32 3.07 -750.74 Start DLS 3.00 TFO 90.04 9,000.00 89.84 136.14 7,027.68 6,987.18 2,323.40 1,859.96 6,006,178.29 390,296.76 3.00 -685.76 9,100.00 89.84 139.14 7,027.97 6,987.47 2,249.51 1,927.33 6,006,103.41 390,363.01 3.00 -586.06 9,200.00 89.84 142.14 7,028.25 6,987.75 2,172.20 1,990.73 6,006,025.17 390,425.25 3.00 -486.10 9,270.19 89.84 144.25 7,028.45 6,987.95 2,116.00 2,032.78 6,005,968.35 390,466.45 3.00 -415.93 Start 6300.96 hold at 9270.19 MD 9,270.35 89.84 144.25 7,028.45 6,987.95 2,115.87 2,032.87 6,005,968.22 390,466.54 3.00 -415.77 9,300.00 89.84 144.25 7,028.54 6,988.04 2,091.81 2,050.19 6,005,943.90 390,483.50 0.00 -386.14 9,400.00 89.84 144.25 7,028.82 6,988.32 2,010.65 2,108.61 6,005,861.88 390,540.69 0.00 -286.22 9,500.00 89.84 144.25 7,029.11 6,988.61 1,929.49 2,167.03 6,005,779.86 390,597.89 0.00 -186.30 9,600.00 89.84 144.25 7,029.40 6,988.90 1,848.33 2,225.45 6,005,697.85 390,655.08 0.00 -86.38 9,700.00 89.84 144.25 7,029.68 6,989.18 1,767.16 2,283.87 6,005,615.83 390,712.28 0.00 13.55 9,800.00 89.84 144.25 7,029.97 6,989.47 1,686.00 2,342.29 6,005,533.81 390,769.47 0.00 113.47 9,900.00 89.84 144.25 7,030.26 6,989.76 1,604.84 2,400.71 6,005,451.79 390,826.66 0.00 213.39 10,000.00 89.84 144.25 7,030.54 6,990.04 1,523.68 2,459.13 6,005,369.77 390,883.86 0.00 313.31 10,100.00 89.84 144.25 7,030.83 6,990.33 1,442.52 2,517.55 6,005,287.75 390,941.05 0.00 413.24 10,200.00 89.84 144.25 7,031.11 6,990.61 1,361.36 2,575.97 6,005,205.74 390,998.25 0.00 513.16 10,300.00 89.84 144.25 7,031.40 6,990.90 1,280.20 2,634.39 6,005,123.72 391,055.44 0.00 613.08 10,400.00 89.84 144.25 7,031.69 6,991.19 1,199.04 2,692.81 6,005,041.70 391,112.64 0.00 713.00 10,500.00 89.84 144.25 7,031.97 6,991.47 1,117.88 2,751.22 6,004,959.68 391,169.83 0.00 812.92 10,600.00 89.84 144.25 7,032.26 6,991.76 1,036.71 2,809.64 6,004,877.66 391,227.02 0.00 912.85 10,700.00 89.84 144.25 7,032.55 6,992.05 955.55 2,868.06 6,004,795.64 391,284.22 0.00 1,012.77 10,800.00 89.84 144.25 7,032.83 6,992.33 874.39 2,926.48 6,004,713.63 391,341.41 0.00 1,112.69 10,900.00 89.84 144.25 7,033.12 6,992.62 793.23 2,984.90 6,004,631.61 391,398.61 0.00 1,212.61 11,000.00 89.84 144.25 7,033.41 6,992.91 712.07 3,043.32 6,004,549.59 391,455.80 0.00 1,312.54 11,100.00 89.84 144.25 7,033.69 6,993.19 630.91 3,101.74 6,004,467.57 391,513.00 0.00 1,412.46 11,200.00 89.84 144.25 7,033.98 6,993.48 549.75 3,160.16 6,004,385.55 391,570.19 0.00 1,512.38 1/18/2011 2:59.05PM Page 6 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-198 it Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-198 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-198 Design: CD3-198wp07 I Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (*) (ft) ft (ft) (ft) (ft) (ft) 6,993.77 11,300.00 89.84 144.25 7,034.27 6,993.77 468.59 3,218.58 6,004,303.53 391,627.39 0.00 1,612.30 11,400.00 89.84 144.25 7,034.55 6,994.05 387.43 3,277.00 6,004,221.52 391,684.58 0.00 1,712.22 11,500.00 89.84 144.25 7,034.84 6,994.34 306.27 3,335.42 6,004,139.50 391,741.77 0.00 1,812.15 11,600.00 89.84 144.25 7,035.12 6,994.62 225.10 3,393.83 6,004,057.48 391,798.97 0.00 1,912.07 11,700.00 89.84 144.25 7,035.41 6,994.91 143.94 3,452.25 6,003,975.46 391,856.16 0.00 2,011.99 11,800.00 89.84 144.25 7,035.70 6,995.20 62.78 3,510.67 6,003,893.44 391,913.36 0.00 2,111.91 11,900.00 89.84 144.25 7,035.98 6,995.48 -18.38 3,569.09 6,003,811.42 391,970.55 0.00 2,211.84 12,000.00 89.84 144.25 7,036.27 6,995.77 -99.54 3,627.51 6,003,729.41 392,027.75 0.00 2,311.76 12,100.00 89.84 144.25 7,036.56 6,996.06 -180.70 3,685.93 6,003,647.39 392,084.94 0.00 2,411.68 12,200.00 89.84 144.25 7,036.84 6,996.34 -261.86 3,744.35 6,003,565.37 392,142.13 0.00 2,511.60 12,300.00 89.84 144.25 7,037.13 6,996.63 -343.02 3,802.77 6,003,483.35 392,199.33 0.00 2,611.52 12,400.00 89.84 144.25 7,037.42 6,996.92 -424.18 3,861.19 6,003,401.33 392,256.52 0.00 2,711.45 12,500.00 89.84 144.25 7,037.70 6,997.20 -505.35 3,919.61 6,003,319.31 392,313.72 0.00 2,811.37 12,600.00 89.84 144.25 7,037.99 6,997.49 -586.51 3,978.03 6,003,237.30 392,370.91 0.00 2,911.29 12,700.00 89.84 144.25 7,038.28 6,997.78 -667.67 4,036.45 6,003,155.28 392,428.11 0.00 3,011.21 12,800.00 89.84 144.25 7,038.56 6,998.06 -748.83 4,094.86 6,003,073.26 392,485.30 0.00 3,111.14 12,900.00 89.84 144.25 7,038.85 6,998.35 -829.99 4,153.28 6,002,991.24 392,542.49 0.00 3,211.06 13,000.00 89.84 144.25 7,039.13 6,998.63 -911.15 4,211.70 6,002,909.22 392,599.69 0.00 3,310.98 13,100.00 89.84 144.25 7,039.42 6,998.92 -992.31 4,270.12 6,002,827.20 392,656.88 0.00 3,410.90 13,200.00 89.84 144.25 7,039.71 6,999.21 -1,073.47 4,328.54 6,002,745.19 392,714.08 0.00 3,510.82 13,300.00 89.84 144.25 7,039.99 6,999.49 -1,154.63 4,386.96 6,002,663.17 392,771.27 0.00 3,610.75 13,400.00 89.84 144.25 7,040.28 6,999.78 -1,235.80 4,445.38 6,002,581.15 392,828.47 0.00 3,710.67 13,500.00 89.84 144.25 7,040.57 7,000.07 -1,316.96 4,503.80 6,002,499.13 392,885.66 0.00 3,810.59 13,600.00 89.84 144.25 7,040.85 7,000.35 -1,398.12 4,562.22 6,002,417.11 392,942.86 0.00 3,910.51 13,700.00 89.84 144.25 7,041.14 7,000.64 -1,479.28 4,620.64 6,002,335.09 393,000.05 0.00 4,010.44 13,800.00 89.84 144.25 7,041.43 7,000.93 -1,560.44 4,679.06 6,002,253.08 393,057.24 0.00 4,110.36 13,900.00 89.84 144.25 7,041.71 7,001.21 -1,641.60 4,737.47 6,002,171.06 393,114.44 0.00 4,210.28 14,000.00 89.84 144.25 7,042.00 7,001.50 -1,722.76 4,795.89 6,002,089.04 393,171.63 0.00 4,310.20 14,100.00 89.84 144.25 7,042.29 7,001.79 -1,803.92 4,854.31 6,002,007.02 393,228.83 0.00 4,410.12 14,200.00 89.84 144.25 7,042.57 7,002.07 -1,885.08 4,912.73 6,001,925.00 393,286.02 0.00 4,510.05 14,300.00 89.84 144.25 7,042.86 7,002.36 -1,966.25 4,971.15 6,001,842.98 393,343.22 0.00 4,609.97 14,400.00 89.84 144.25 7,043.14 7,002.64 -2,047.41 5,029.57 6,001,760.97 393,400.41 0.00 4,709.89 14,500.00 89.84 144.25 7,043.43 7,002.93 -2,128.57 5,087.99 6,001,678.95 393,457.60 0.00 4,809.81 14,600.00 89.84 144.25 7,043.72 7,003.22 -2,209.73 5,146.41 6,001,596.93 393,514.80 0.00 4,909.74 14,700.00 89.84 144.25 7,044.00 7,003.50 -2,290.89 5,204.83 6,001,514.91 393,571.99 0.00 5,009.66x° 14,800.00 89.84 144.25 7,044.29 7,003.79 -2,372.05 5,263.25 6,001,432.89 393,629.19 0.00 5,109.58 14,900.00 89.84 144.25 7,044.58 7,004.08 -2,453.21 5,321.67 6,001,350.87 393,686.38 0.00 5,209.50 15,000.00 89.84 144.25 7,044.86 7,004.36 -2,534.37 5,380.09 6,001,268.86 393,743.58 0.00 5,309.42 15,100.00 89.84 144.25 7,045.15 7,004.65 -2,615.53 5,438.50 6,001,186.84 393,800.77 0.00 5,409.35 15,200.00 89.84 144.25 7,045.44 7,004.94 -2,696.70 5,496.92 6,001,104.82 393,857.96 0.00 5,509.27 15,300.00 89.84 144.25 7,045.72 7,005.22 -2,777.86 5,555.34 6,001,022.80 393,915.16 0.00 5,609.19 15,400.00 89.84 144.25 7,046.01 7,005.51 -2,859.02 5,613.76 6,000,940.78 393,972.35 0.00 5,709.11 15,500.00 89.84 144.25 7,046.30 7,005.80 -2,940.18 5,672.18 6,000,858.76 394,029.55 0.00 5,809.04 15,571.16 89.84 144.25 7,046.50 7,006.00 -2,997.93 5,713.75 6,000,800.40 394,070.25 0.00 5,880.14 TD at 15571.16-4-1/2"x 6-1/8" 1/18/2011 2:59:05PM Page 7 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HAL LIBURTQN Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-198 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) • Project: Western North Slope MD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) • Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-198 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-198 Design: CD3-198wp07 :. Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 7,006.00 15,571.45 , 89.84 144.25 7,046.50 ' 7,006.00 -2,998.17 5,713.92 6,000,800.16 394,070.41 0.00 5,880.43 CD3-G 25May10 Toe Targets Target Name 1 -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) r) (ft) (ft) (ft) (ft) (ft) CD3-G 25May10 Toe 0.00 0.00 7,046.50 -2,998.17 5,713.92 6,000,800.16 394,070.41 -plan hits target center -Point CD3-G 25May10 Heel 0.00 0.00 7,007.50 2,629.25 1,548.71 6,006,488.73 389,990.15 -plan misses target center by 15.53ft at 8564.59ft MD(6992.68 TVD,2624.61 N, 1548.52 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,607.05 2,450.00 9-5/8"x 12-1/4" 9-5/8 12-1/4 8,661.71 7,007.50 7"x 8-3/4" 7 8-3/4 15,571.16 7,046.50 4-1/2"x 6-1/8" 4-1/2 6-1/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 4,337.12 3,901.50 K-3 7,825.87 6,698.50 K-1 1,234.32 1,223.50 Base Permafrost 7,748.28 6,651.50 Base HRZ 4,517.04 4,046.50 K-3 Basal 4,557.98 4,079.50 K-2 7,888.35 6,734.50 Top Kuparuk D 7,572.70 6,536.50 Top HRZ 2,663.65 2,499.50 C-30 6,883.24 6,000.50 Albian 96 4,691.99 4,187.50 K-2 Basal 8,661.71 7,007.50 Top Nechelik 7,982.86 6,785.50 LCU 8,293.72 6,920.50 Base Nuiqsut 6,516.48 5,685.50 Albian 97 2,453.27 2,315.50 C-40 3,095.83 2,877.50 C-20 7,963.68 6,775.50 Top Kuparuk C 8,032.46 6,810.50 Top Nuiqsut 1/18/2011 2.59.05PM Page 8 __�? COMPASS 2003.16 Build 69 9 E,, •i 1 ConocoPhillips H, 1, LI B U RTD N Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-198 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan:28+12.5 @ 40.50ft(Doyon 141) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-198 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-198 Design: CD3-198wp07 Plan Annotations I Measured Vertical Local Coordinates Depth Depth +N/S +EJ-W (ft) (ft) (ft) (ft) Comment 231.70 231.70 0.00 0.00 Start Build 1.30 742.85 741.70 14.80 25.64 Start DLS 1.75 TFO-30.00 894.27 891.70 26.58 42.54 Start DLS 2.50 TFO-45.00 1,291.48 1,278.21 99.12 94.82 Start DLS 3.05 TFO-50.01 1,767.83 1,716.00 278.73 136.91 Start 1458.58 hold at 1767.83 MD 3,226.40 2,991.70 983.90 189.69 Start DLS 2.00 TFO-30.00 3,635.69 3,336.20 1,204.23 191.54 Start 2227.87 hold at 3635.69 MD 5,863.56 5,131.70 2,521.77 131.10 Start DLS 3.50 TFO 123.00 7,048.81 6,138.04 2,998.78 453.99 Start DLS 4.00 TFO 68.22 7,870.81 6,724.57 2,956.09 1,012.12 Start DLS 4.51 TFO 44.51 8,661.71 7,007.50 2,559.30 1,618.82 Start 50.00 hold at 8661.71 MD 8,711.71 7,013.59 2,524.71 1,654.41 Start Build 3.07 8,934.55 7,027.50 2,369.81 1,813.81 Start DLS 3.00 TFO 90.04 9,270.19 7,028.45 2,116.00 2,032.78 Start 6300.96 hold at 9270.19 MD 15,571.16 7,046.50 -2,997.93 5,713.75 TD at 15571.16 • is 1/18/2011 2:59.05PM Page 9 COMPASS 2003.16 Build 69 QRIGINM- to 2 a 0 I— m oc 3 2 M L J 4 L L m I a Y/ d Z ID =_ W N C ' O ea N U a O N • co.N Cl).10w Ii , v O N U str o L 15 ` I o. 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N > I F co) �tii BAS Q o p (0 c p :1ii"x_ FIR; o m M pas,: ORttINAL co � �� ConocoPhillips CD3-198w 07 HALLIBURTON Alaska Sperry Drilling ANTI-COLLISION SETTINGS 15:16,January 17 2011 Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 15571.16 Results Limited By: Centre Distance: 1754.32 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1200.00 CD3-198wp07(Plan: CD3-198) CB-GYRO-SS 1200.00 2607.05 CD3-198wp07(Plan: CD3-198) MWD+IFR-AK-CAZ-SC 2607.05 8661.71 CD3-198wp07(Plan: CD3-198) MWD+IFR-AK-CAZ-SC 8661.71 15571.16 CD3-198wp07 (Plan: CD3-198) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 2607.05 9-5/8"x 12-1/4" 9-5/8 7007.50 8661.71 7"x 8-3/4" 7 7046.50 15571.16 4-1/2"x 6-1/8" 4-1/2 • mo � 0 60 • • ma U 030 !�'-- Y!! E' O - �I 0 I I I i I I 1 I i r 1 1 i i 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND -0- CD3-106,CD3-106,CD3-106 VO -- CD3-301,CD3-301A,CD3-301A VO -0- CD3-304,CD3-304,CD3-304 VO -X- CD3-106,CD3-106L1,CD3-106L1 VO $- CD3-301,CD3-301APB1,CD3-301APB1 VO CD3-305,CD3-305,CD3-305 VO $- CD3-107,CD3-107,CD3-107 V7 -X-- CD3-301,CD3-301PB1,CD3-301PB1 V1 -%- CD3-305,CD3-305PB1,CD3-305PB1 VO -g- CD3-107,CD3-107L1,CD3-107L1 VO $ CD3-302,CD3-302,CD3-302 V3 - CD3-316,CD3-316,CD3-316 VO - CD3-107,CD3-307,CD3-307 V4 --- CD3-302,CD3-302A,CD3-302A V0 -e-- Plan:CD3-119,Plan:CD3-119,CD3-119wp07 VO $- CD3-108,CD3-108,CD3-108 V14 -X- CD3-302,CD3-302PB1,CD3-302PB1 V11 -e- Plan:CD3-199,Plan:CD3-199,CD3-199wp07 VO CD3-109,CD3-109,CD3-109 V5 -6- CD3-302,CD3-302PB2,CD3-302PB2 V6 $- CD3-198wp07 --- CD3-110,CD3-110,CD3-110 V12 -9- CD3-302,CD3-302PB3,CD3-302PB3 V2 CD3-301,CD3-301,CD3-301 V4 -e- CD3-303,CD3-303,CD3-303 VO OR1G1NM _ CD3-198w s p07ConocoPhillip HALLIBURTON Alaska Sperry Drilling ANTI-COLLISION SETTINGS 15:16,January 172011 Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 15571.16 Results Limited By: Centre Distance: 1754.32 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1200.00 CD3-198wp07(Plan: CD3-198) CB-GYRO-SS 1200.00 2607.05 CD3-198wp07(Plan: CD3-198) MWD+IFR-AK-CAZ-SC 2607.05 8661.71 CD3-198wp07(Plan: CD3-198) MWD+IFR-AK-CAZ-SC 8661.71 15571.16 CD3-198wp07 (Plan: CD3-198) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 1V1' 2450.00 2607.05 9-5/8" x 12-1/4" 9-5/8 7007.50 8661.71 7"x 8-3/4" 7 7046.50 15571.16 4-1/2"x 6-1/8" 4-1/2 A M rT 0 2 U U U °60- Ilp��l 1 . .... ...�� / N Q II 111$111' HI I i /N - o I�IIII!II11l11lk fly i O _ \ IPI i _ 30- 1- 7 -C - >:1/I I 1!I it 11 U - / IiiiiI'I' 0 I 1 I I I I r 1 I I 1 I I I f I I I I I I I I I 1 I I I I I 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND -e- CD3-106,CD3-106,CD3-106 VO -9- CD3-301,CD3-301A,CD3-301A VO -e- CD3-304,CD3-304,CD3-304 VO -X- CD3-106,CD3-106L1,CD3-106L1 VO -A- CD3-301,CD3-301APB1,CD3-301APB1 VO -g- CD3-305,CD3-305,CD3-305 VO - CD3-107,CD3-107,CD3-107 V7 -X- CD3-301,CD3-301PB1,CD3-301PB1 V1 --T-- CD3-305,CD3-305PB1,CD3-305PB1 VO CD3-107,CD3-107L1,CD3-107L1 VO -e- CD3-302,CD3-302,CD3-302 V3 -4- CD3-316,CD3-316,CD3-316 VO CD3-107,CD3-307,CD3-307 V4 -0.- CO3-302,CD3-302A,CD3-302A VO 0 Plan:CD3-119,Plan:CD3-119,CD3-119wp07 VO -0- CD3-108,CD3-108,CD3-108 V14 -X- CD3-302,CD3-302PB1,CD3-302PB1 V11 O Plan:CD3-199,Plan:CD3-199,CD3-199wp07 VO - CD3-109,CD3-109,CD3-109 V5 -A- CD3-302,CD3-302PB2,CD3-302PB2 V6 0 CD3-198wp07 $- CD3-110,CD3-110,CD3-110 V12 -9- CD3302,C03302P83,CD3-302PB3 V2 CD3301,CD3301,CD3301 V4 -e- CD3303,CD3303,CD3-303 VO ORIGiNAL Northing (3000 ft/in) J I I I I I I I I I I I I 1 I I I I I I I I i I I I I I I I I I I 1 I I I I I 1 I I I 1 1 I I I I I I I I I I I I I I I I I l 1 I I I I I I r _ - N - 3 _ 7 M O - r M M 0 - U d M - M M O M � - - M - _ ^ 0 U = _ �j) — i- - ------,iii,GQ'- - _ o. — y Cl1 - - r:. tp 0 - 4:1) 1_. ch — O CO 0 = UC. —, C.) 1 C - — 4111.11M11.0 , co C a N/ M p - C a— N CO O —a r con CO 0 0 - o N- 0 N N 0 N 0 0 Q 0 0 v - Q M O 0 M O d 3 - r) 3 A a U 0 N rn 0 C— O U CR U U M — C as W - 0 0 N iii;\ 0 - W U U o U U V. 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UPDATED PER K100002ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD JCD3-X98 6,003,630.37 1,528,434.35 70' 25' 09.267" 150' 54' 44.278" 1392 642s' 7.3 12.5 J ' CD3-X99 6,003,625.99 1,528,415.38 70' 25' 09.221" 150' 54' 44.833" 1387 661 7.3 12.8 CD3-301 6,003,621.33 1,528,395.58 70' 25' 09.172" 150' 54' 45.411" 1382' 680' 7.3 13.5 CD3-302 6,003,616.72 1,528.376.38 70' 25' 09.124" 150' 54' 45.972" 1377' 700' 7.3 13.2 CD3-303 6,003,612.52 1.528.356.72 70' 25' 09.080" 150' 54' 46.547" 1373' 719' 7.3 13.3 CD3-304 6,003,607.82 1,528,337.04 70' 25' 09.031" 150' 54' 47.122" 1368' 739' 7.3 13.4 CD3-305 6,003,603.48 1,528,317.56 70' 25' 08.985" 150' 54' 47.691" 1363' 758' 7.3 13.6 CD3-106 6,003,599.43 1,528,298.37 70' 25' 08.942" 150' 54' 48.252" 1359' 777' 7.3 13.4 CD3-107 6,003,594.38 1,528,278.93 70' 25' 08.890" 150' 54' 48.820" 1354' 797' 7.3 13.2 CD3-108 6,003,589.85 1,528.259.61 70' 25' 08.842" 150' 54' 49.385" 1349' 816' 7.3 13.1 CD3-109 6,003,585.27 1,528,239.85 70' 25' 08.794" 150' 54' 49.962" 1344' 836' 7.3 13.1 CD3-110 6,003,580.97 1,528,220.32 70' 25' 08.749" 150' 54' 50.533" 1339' 855' 7.3 13.0 CD3-111 6.003,576.13 1,528,201.08 70' 25' 08.699" 150' 54' 51.095" 1334' 874' 7.3 12.9 CD3-112 6,003,572.43 1,528,181.20 70' 25' 08.660" 150' 54' 51.676" 1330' 894' 7.3 13.1 CD3-113 6,003,567.62 1,528,161.38 70' 25' 08.609" 150' 54' 52.255" 1325' 914' 7.3 13.1 CD3-114 6,003,563.04 1,528,142.21 70' 25' 08.561" 150' 54' 52.815" 1320' 933' 7.3 13.3 CD3-115 6,003,558.57 1,528,122.60 70' 25' 08.515" 150' 54' 53.388" 1315' 953' 7.3 13.2 CD3-316A 6,003,554.04 1,528,103.39 70' 25' 08.467" 150' 54' 53.950" 1311' 972' 7.3 13.2 CD3-117 6,003,549.51 1,528,083.99 70' 25' 08.420" 150' 54' 54.516" 1306' 991' 7.3 13.1 CD3-118 6,003,544.88 1,528,064.44 70' 25' 08.372" 150' 54' 55.086" 1301' 1011' 7.3 12.8 CD3-X19 6.003,540.17 1.528,044.86 70' 25' 08.322" 150' 54' 55.660" 1296' 1030' 7.3 12.8 CD3-X20 6,003,535.95 1,528.025.39 70' 25' 08.278" 150' 54' 56.229" 1291' 1050' 7.3 12.6 CD3-X21 6.003,531.41 1.528,006.04 70' 25' 08.230" 150' 54' 56.794" 1286' 1069' 7.3 12.5 CD3-122 6,003,527.00 1,527,986.67 70' 25' 08.184" 150' 54' 57.360" 1282' 1088' 7.3 12.6 CD3-X23 6.003.522.43 1,527,967.12 70' 25' 08.136" 150' 54' 57.932" 1277' 1108' 7.3 12.6 CD3-124 6.003,518.17 1,527,947.59 70' 25' 08.091" 150' 54' 58.502" 1272' 1127' 7.3 12.5 CD3-X25 6.003.513.62 1,527,927.89 70' 25' 08.044" 150' 54' 59.078" 1267' 1147' 7.3 12.6 CD3-X26 6.003,508.97 1,527,908.70 70' 25' 07.995" 150' 54' 59.639" 1263' 1166' 7.3 12.6 CD3-X27 6.003.503.45 1,527.889.34 70' 25' 07.948" 150' 55' 00.204" 1258' 1185' 7.3 12.6 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) ALPINE MODULE:CD30 UNIT: CD C•noc•Phillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1A-2 3-17-05 CE-CD30-111 2 OF 3 9 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME C,)�--lt C. r/E PTD# I ( C Z-4 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: (i)4.1//c - _/ ii'r POOL: r (6) 17-c-4 Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 to D m G) D 3 cn D a m L O I- v Co m a 3 0 O 1 a u) 1 1 - 3 G) co rn " ,. 1 Iii po W W Ca W W W W W CO W N N CJ N N N N N N N - -, (O Co --,1 C) 0) A W CJ - -, ° CO Co J C) C)) A Ca N - 0 CO Co J 0) CT A Ca N -+ 0 CO Co C) CT A Ca N - 0 J 0 n CO W o D D C) n n 0 to n m D n m v O O c CD CD z O 0 CD o to o 0 0 c- O O - °- °- (D n 47 K K K c 0 m - co n) (D o -° D Q c co CD CD 7 v fD ° m a 0 d 3 0- m m m < a -I v a o F = 7 3 0 0 _ _ _ (n 3 0 n0 3. 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O O a O o 0 * O O O O r CD a 0) lOA N (0i») II 7' 7 N W N CD o) 0) CT '� W I- O 7 O 0 J m c n F N CO 0co o -, 0 a c o 0 o - - `�° O � A 03 CD O 03 Cn -a •a r O COm 7 mCO 0 o m 0 0 0 a) N = (n < 5- co O. O N OW 0 a 3 7 0 CD 0 0 N -1 7 N O (C) C)) (,J C (a) W 00 _, cn Ca CO - 0 a W S ° ° y c) -a .x 73 (D = O p) O -O' 7 7' 7 N0 0 7 7 O o 7 N Cr' a o (O Q 0 J V CD - O O O m ° __ v a o N' 0 0 n 0 (n A a) (n .a N N (D -a co 7 W C 3 co O za) FET a C Q (n N o (<D co . CD to m 01 7 co O b -a 7 z c CO N 0) -, 7C O' j n n (O W a) .7. (b (n v D co (o co N Q 0 CD CD v o- 0 s '< n Cn 0. 0 < CD 0 0 N cn cn .0.. 0 -I OW ° Ca = Jo o ca n 0 O 0 00 d = O D Ca N .0. .0.. (7n 0) 7 7 N 7 �p' p (0 D ' 0. *. 3 a co N y 3 I- - m- = � N co a CCo CO O N ( a) -o n Q o o O 3 -a -a '(n 0 C) A 7 (O - co 0m 0 c N 3 N- n 0- X Q co co CD 3 3 o ° 0 O (/O) Cp - 7 c Q m7 c (n v 7 7 0) a 2 o a a q o D N N O j CD N 3 c CS P 1 Well History File APPE. NI1X Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 06 15:37:28 2011 Reel Header Service name LISTPE Date 11/04/06 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/04/06 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: CD3-198 API NUMBER: 501032063700 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 06-APR-11 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: AKMW0000789684 AKMW0000789684 AKMW0000789684 LOGGING ENGINEER: TYLER RITCHE TYLER RITCHE JACK KLEINHA OPERATOR WITNESS: GUY WHITLOCK FRED HERBERT FRED HERBERT MAD RUN 4 MWD RUN 5 JOB NUMBER: AKMW0000789684 AKMW0000789684 LOGGING ENGINEER: JACK KLEINHA JACK KLEINHA OPERATOR WITNESS: FRED HERBERT GUY WHITLOCK SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 3888 FSL: a<< - oay aot43 • FEL: 641 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 40.09 GROUND LEVEL: 12.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 16.000 108.0 2ND STRING 8.750 9. 625 2619.0 3RD STRING 6. 130 7.000 8728 .0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUNS 100 WAS DIRECTIONAL ONLY, ROP DATA FROM RUN MERGED ONTO THE TOP OF MWD RUN 200. 4 . MWD RUN 200 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , AT-BIT INLINATION (ABI)AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 5. MWD RUN 300 AND 400 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AZIMUTHAL LITHO-DENSITY (ALD) ) , BI-MODAL ACOUSTIC TOOL (BAT) , ACOUSTIC CALIPER (ACAL) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 6. DENSITY DATA (ACDL, ADCL, ALRPM) FROM 4651' MD TO 4443' MD ACQUIRED DURING A MEASUREMENT AFTER DRILLING PASS AT THE END OF MWD RUN 400 WHILE PULLIN OUT OF THE HOLE. 7 . A MAD PASS WAS PERFORMED TO ACQUIRE CALIPER DATA WHILE POOH AT THE END OF MWD RUN 400 FROM 7192.5 FT TO 7902 FT (BIT DEPTHS. ) ALL LOGGING DATA AVAILABLE HAS BEEN PRESENTED FOR THIS MAD PASS. NOTE NO SONIC SHEAR DATA (BTSS AND BVPS) DATA ACQUIRED AND THERFORE WAS NOT PRESENTED. MAD PASS DATA HAS BEEN DEPTH CORRECTED TO THE DRILLING DATA DEPTHS. 8. MWD RUN 500 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , DRILLSTRING DYNAMICS SENSOR (DDSr) , AND BI-MODAL ACOUSTIC TOOL (BAT) . BAT RUN IN RECORDED ONLY MODE FOR CEMENT LOGGING, NO OPENHOLE DATA PRESENTED FOR THIS RUN. 9. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 10. MWD RUNS 100 - 500 REPRESENTS WELL CD3-198 WITH API 50-103-20637-00. THIS WELL REACHED A TOTAL DEPTH OF 13,228' MD, 7, 038' TVD. MNEMONIC CURVE DESCRIPTION R09P 9in Phase Resistivity R15P 15in Phase Resistivity R27P 27in Phase Resistivity R39P 39in Phase Resistivity EWXT EWR Formation Exp Time ROPA Avg Rate of Penetration DGRC DGR Combined Gamma Ray APEL ALD LCRB Pe Factor ACDL ALD LCRB Comp Density ADCL ALD LCRB Den Correction TNPS CTN Porosity Sandstone TNFA CTN Far Avg Count Rate TNNA CTN Near Avg Count Rate BTCS BAT Comp Slowness BTSS BAT Comb Shear Slowness BVPS BAT VP/VS Ratio ACHD ACAL Hole Diameter ALRPM ALD RPM PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: ACAL, FALLBACK 9.875" FIXED. MUD WEIGHT: 9. 6 - 10.5 PPG WHOLE MUD CHLORIDES: 550 - 1, 200 PPM CL FORMATION WATER SALINITY: 23, 000 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR GAMMA RAY AND ROP. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. ALL SONIC DATA ARE SMOOTHED WITH A 2.0 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. P PP g DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH ROP 106.0 13228.0 GR 162.0 13179.0 RPX 172.5 13186.0 RPD 172.5 13186.0 RPM 172.5 13186.0 FET 172.5 13186.0 RPS 172.5 13186.0 NCNT 2609.0 8639.0 RHOB 2609.0 8653.0 PEF 2609.0 8653.0 NPHI 2609.0 8639.0 DRHO 2609.0 8653.0 FCNT 2609.0 8639.0 CALN 2609.0 8653.0 DTC 2619.0 8623.0 SCRA 2722.0 8623.0 DTSH 2722.0 8623.0 CALA 3216. 0 8642.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 106.0 2630.0 MWD 3 2563.5 7260.0 MWD 4 7077.5 8738.0 MWD 5 8678.5 13228.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined e Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD IN 4 1 68 4 2 RHOB MWD G/CC 4 1 68 8 3 DRHO MWD G/CC 4 1 68 12 4 CALN MWD IN 4 1 68 16 5 PEF MWD B/E 4 1 68 20 6 DTC MWD USPF 4 1 68 24 7 BOSS MWD USPF 4 1 68 28 8 SCRA MWD NONE 4 1 68 32 9 GR MWD API 4 1 68 36 10 FET MWD HR 4 1 68 40 11 RPX MWD OHMM 4 1 68 44 12 RPS MWD OHMM 4 1 68 48 13 RPM MWD OHMM 4 1 68 52 14 RPD MWD OHMM 4 1 68 56 15 ROP MWD FPH 4 1 68 60 16 FCNT MWD CP30 4 1 68 64 17 NCNT MWD CP30 4 1 68 68 18 NPHI MWD PU 4 1 68 72 19 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 106 13228 6667 26245 106 13228 CALA MWD IN 8. 41 13.2 8. 94644 10854 3216 8642.5 RHOB MWD G/CC 0.251 3.225 2.38978 12089 2609 8653 DRHO MWD G/CC -2.801 0.418 0.0949196 12089 2609 8653 CALN MWD IN 8.25 14.28 8.87711 8104 2609 8653 PEF MWD B/E 2.24 12 4 .06398 12089 2609 8653 DTC MWD USPF 74 .39 160 102.08 12009 2619 8623 BCSS MWD USPF 131. 55 296.74 200.807 11582 2722 8623 SCRA MWD NONE 1.43 2. 94 1. 97219 11582 2722 8623 GR MWD API 10. 18 421.75 89.3555 26035 162 13179 FET MWD HR 0. 19 161.39 1.3969 25898 172. 5 13186 RPX MWD OHMM 0.1 1370.89 7.23388 25898 172.5 13186 RPS MWD OHMM 0.1 204 . 98 9.23733 25898 172.5 13186 RPM MWD OHMM 0. 18 1962.22 13.3981 25898 172. 5 13186 RPD MWD OHMM 0.19 2000 17. 9429 25898 172.5 13186 ROP MWD FPH 0.17 1349.09 124 .877 26245 106 13228 FCNT MWD CP30 359. 6 1727. 62 634 . 969 12061 2609 8639 NCNT MWD CP30 79756. 9 133303 99514 .7 12061 2609 8639 NPHI MWD PU 12.54 74 . 67 34 .5858 12061 2609 8639 First Reading For Entire File 106 Last Reading For Entire File 13228 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH DTC 7077.5 7890.5 FCNT 7093. 5 7902.0 NCNT 7093.5 7902.0 NPHI 7093.5 7902.0 RHOB 7106.0 7902.0 DRHO 7106.0 7902.0 PEF 7106.0 7902.0 CALN 7106.0 7902.0 CALA 7113.5 7902.0 GR 7131.0 7902.0 RPM 7141.0 7902.0 RPD 7141.0 7902.0 RPS 7141.0 7902.0 FET 7141.0 7902. 0 RPX 7141.0 7902.0 RAT 7192.5 7902.0 $ I MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 4 1 7077.5 8738.0 $ REMARKS: MERGED MAD PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . . 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MAD IN 4 1 68 4 2 RHOB MAD G/CC 4 1 68 8 3 DRHO MAD G/CC 4 1 68 12 4 CALN MAD IN 4 1 68 16 5 PEF MAD B/E 4 1 68 20 6 DTC MAD USPF 4 1 68 24 7 GR MAD API 4 1 68 28 8 FET MAD HR 4 1 68 32 9 RPX MAD OHMM 4 1 68 36 10 RPS MAD OHMM 4 1 68 40 11 RPM MAD OHMM 4 1 68 44 12 RPD MAD OHMM 4 1 68 48 13 RAT MAD FPH 4 1 68 52 14 FCNT MAD CP30 4 1 68 56 15 NCNT MAD CP30 4 1 68 60 16 NPHI MAD PU 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7077.5 7902 7489.75 1650 7077.5 7902 CALA MAD IN 8.89 10.84 9. 4284 1089 7113.5 7902 RHOB MAD G/CC 1. 669 3. 108 2. 46158 1593 7106 7902 DRHO MAD G/CC -0. 103 0.204 0. 0480785 1593 7106 7902 CALN MAD IN 8.41 13.87 9.38008 1593 7106 7902 PEF MAD B/E 2.196 10.725 4 . 91079 1593 7106 7902 DTC MAD USPF 79.57 112. 92 95. 9809 1611 7077.5 7890.5 GR MAD API 83. 99 430. 12 180. 951 1543 7131 7902 FET MAD HR 36. 63 114 .54 55.4017 1523 7141 7902 RPX MAD OHMM 1.44 13. 11 3.80997 1523 7141 7902 RPS MAD OHMM 1.48 12.74 4 .00116 1523 7141 7902 RPM MAD OHMM 1.45 12.81 4 . 14441 1523 7141 7902 RPD MAD OHMM 1.51 10.48 4 .25328 1523 7141 7902 RAT MAD FPH 15.75 423.2 251. 119 1420 7192.5 7902 FONT MAD CP30 402.27 1808.55 600.012 1618 7093.5 7902 NCNT MAD CP30 85524. 1 130285 97784 .7 1618 7093.5 7902 NPHI MAD PU 12.03 60.27 35. 9536 1618 7093.5 7902 First Reading For Entire File 7077.5 Last Reading For Entire File 7902 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 ' Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROPA 106.0 2630.0 DGRC 162.0 2563.0 R39P 172.5 2573.0 R27P 172.5 2573.0 R15P 172.5 2573.0 R09P 172.5 2573.0 EWXT 172.5 2573.0 LOG HEADER DATA DATE LOGGED: 14-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88 .2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 2630.0 TOP LOG INTERVAL (FT) : 229.0 BOTTOM LOG INTERVAL (FT) : 2630.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 1. 8 MAXIMUM ANGLE: 31. 1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUALAMMA 7 G RAY 10 18512 EWR4 ELECTROMAG. RESIS. 4 113423 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (FT) : 108.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 8. 90 MUD VISCOSITY (S) : 135. 0 MUD PH: 8. 9 MUD CHLORIDES (PPM) : 1000 FLUID LOSS (C3) : 12.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 3.000 75. 0 MUD AT MAX CIRCULATING TERMPERATURE: 2.576 88.5 MUD FILTRATE AT MT: 2.200 70.0 MUD CAKE AT MT: 2.800 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 FET MWD020 HR 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 106 2630 1368 5049 106 2630 GR MWD020 API 10.18 204 . 96 81.3966 4803 162 2563 FET MWD020 HR 0.19 8. 19 0. 943717 4802 172.5 2573 RPX MWD020 OHMM 0. 9 1370.89 10.7564 4802 172.5 2573 RPS MWD020 OHMM 0.85 204 . 98 18. 6696 4802 172.5 2573 I RPM MWD020 OHMM 0.82 1962.22 35. 9307 4802 172.5 2573 RPD MWD020 OHMM 0.85 2000 50.371 4802 172.5 2573 ROP MWD020 FPH 0.25 1349.09 176.784 5049 106 2630 First Reading For Entire File 106 Last Reading For Entire File 2630 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 2563.5 7201.5 AHSI 2609.0 7177.0 R39P 2609.0 7211.5 EWXT 2609.0 7211.5 R15P 2609.0 7211.5 R09P 2609.0 7211.5 R27P 2609.0 7211.5 TNFA 2609.0 7164 . 5 TNNA 2609.0 7164 .5 APEL 2609.0 7178.5 TNPS 2609.0 7164 . 5 ACDL 2609.0 7178.5 ADCL 2609.0 7178.5 BTCS 2619.0 7148.0 ROPA 2630.5 7260.0 BCSS 2722.0 7148.0 BVPS 2722.0 7148.0 ACHD 3216.0 7168.0 LOG HEADER DATA DATE LOGGED: 19-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88 .2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7260.0 TOP LOG INTERVAL (FT) : 2630.0 BOTTOM LOG INTERVAL (FT) : 7260.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 28 .5 MAXIMUM ANGLE: 40.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 11241795 CTN COMP THERMAL NEUTRON 244601 BAT Bi-modal Acoustic 195179 ALD Azimuthal Litho-Dens 10603721 BOREHOLE AND CASING DATA I OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2619.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 80 MUD VISCOSITY (S) : 39.0 MUD PH: 9.2 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2. 400 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.356 120.2 MUD FILTRATE AT MT: 3.300 65.0 MUD CAKE AT MT: 2. 100 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD030 IN 4 1 68 4 2 RHOB MWD030 G/CC 4 1 68 8 3 DRHO MWD030 G/CC 4 1 68 12 4 CALN MWD030 IN 4 1 68 16 5 PEF MWD030 B/E 4 1 68 20 6 DTC MWD030 USPF 4 1 68 24 7 BCSS MWD030 USPF 4 1 68 28 8 SCRA MWD030 NONE 4 1 68 32 9 GR MWD030 API 4 1 68 36 10 FET MWD030 HR 4 1 68 40 11 RPX MWD030 OHMM 4 1 68 44 12 RPS MWD030 OHMM 4 1 68 48 13 RPM MWD030 OHMM 4 1 68 52 14 RPD MWD030 OHMM 4 1 68 56 15 ROP MWD030 FPH 4 1 68 60 16 FCNT MWD030 CP30 4 1 68 64 17 NCNT MWD030 CP30 4 1 68 68 18 NPHI MWD030 PU 4 1 68 72 19 r First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2563.5 7260 4911.75 9394 2563. 5 7260 CALA MWD030 IN 8 .41 10.35 8.84288 7905 3216 7168 RHOB MWD030 G/CC 0.251 2.736 2.36561 9140 2609 7178.5 DRHO MWD030 G/CC -2.801 0.356 0.0878535 9140 2609 7178.5 CALN MWD030 IN 8.25 14.28 8 .87026 6836 2609 7177 PEF MWD030 B/E 2.24 12 3.59043 9140 2609 7178.5 DTC MWD030 USPF 76. 99 160 106.584 9059 2619 7148 BCSS MWD030 USPF 140.28 296.74 213.002 8853 2722 7148 SCRA MWD030 NONE 1. 43 2. 94 2.01495 8853 2722 7148 GR MWD030 API 48.74 202.02 113.057 9277 2563.5 7201.5 FET MWD030 HR 0.22 70. 62 0. 962678 9206 2609 7211.5 RPX MWD030 OHMM 0.28 17. 65 4 .25645 9206 2609 7211.5 RPS MWD030 OHMM 0.2 14 . 66 4.23689 9206 2609 7211.5 RPM MWD030 OHMM 0. 18 40.31 4 .27217 9206 2609 7211.5 RPD MWD030 OHMM 0. 19 2000 9.76853 9206 2609 7211.5 ROP MWD030 FPH 1. 65 283. 61 151. 613 9260 2630.5 7260 FCNT MWD030 CP30 359. 6 1547.05 609.88 9112 2609 7164 .5 NCNT MWD030 CP30 79756. 9 133003 98851. 1 9112 2609 7164.5 NPHI MWD030 PU 15.82 74 . 67 36.04 9112 2609 7164 .5 First Reading For Entire File 2563.5 Last Reading For Entire File 7260 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH BTCS 7148.5 8623.0 TNNA 7165.0 8639.0 TNPS 7165.0 8639.0 TNFA 7165.0 8639.0 ACHD 7168.5 8642.5 ADCL 7179.0 8653.0 APEL 7179.0 8653.0 ACDL 7179.0 8653.0 DGRC 7202.0 8678.0 AHSI 7209.0 8653.0 EWXT 7212. 0 8688 .0 R15P 7212.0 8688.0 R39P 7212.0 8688 .0 R09P 7212.0 8688 .0 R27P 7212.0 8688.0 BVPS 7259. 0 8623.0 BCSS 7259.0 8623.0 ROPA 7260.5 8738.0 LOG HEADER DATA DATE LOGGED: 24-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88 .2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 8738.0 TOP LOG INTERVAL (FT) : 7260. 0 BOTTOM LOG INTERVAL (FT) : 8738. 0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 42.4 MAXIMUM ANGLE: 83.0 # I TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 279516 EWR4 ELECTROMAG. RESIS. 4 10505932 CTN COMP THERMAL NEUTRON 244601 BAT Bi-modal Acoustic 195179 ALD Azimuthal Litho-Dens 10603721 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2619.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.50 MUD VISCOSITY (S) : 43.0 MUD PH: 9. 4 MUD CHLORIDES (PPM) : 650 FLUID LOSS (C3) : 6. 0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1. 960 65.0 MUD AT MAX CIRCULATING TERMPERATURE: . 906 148 .5 MUD FILTRATE AT MT: 1. 990 65.0 MUD CAKE AT MT: 1.800 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD040 IN 4 1 68 4 2 RHOB MWD040 G/CC 4 1 68 8 3 DRHO MWD040 G/CC 4 1 68 12 4 CALN MWD040 IN 4 1 68 16 5 PEF MWD040 B/E 4 1 68 20 6 DTC MWD040 USPF 4 1 68 24 7 BCSS MWD040 USPF 4 1 68 28 8 SCRA MWD040 NONE 4 1 68 32 9 GR MWD040 API 4 1 68 36 10 FET MWD040 HR 4 1 68 40 11 RPX MWD040 OHMM 4 1 68 44 12 RPS MWD040 OHMM 4 1 68 48 13 RPM MWD040 OHMM 4 1 68 52 14 RPD MWD040 OHMM 4 1 68 56 15 ROP MWD040 FPH 4 1 68 60 16 FCNT MWD040 CP30 4 1 68 64 17 NCNT MWD040 CP30 4 1 68 68 18 s NPHI MWD040 PU 4 1 68 72 19 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7148.5 8738 7943.25 3180 7148.5 8738 CALA MWD040 IN 8.62 13.2 9.22403 2949 7168.5 8642.5 RHOB MWD040 G/CC 1. 679 3.225 2.46468 2949 7179 8653 DRHO MWD040 G/CC -0.097 0.418 0. 11682 2949 7179 8653 CALN MWD040 IN 8.43 13.5 8. 91407 1268 7209 8653 PEF MWD040 B/E 2. 69 11 5.53169 2949 7179 8653 DTC MWD040 USPF 74 .39 107.86 88.2477 2950 7148.5 8623 BCSS MWD040 USPF 131.55 223.3 161.244 2729 7259 8623 SCRA MWD040 NONE 1.5 2.27 1.83348 2729 7259 8623 GR MWD040 API 44 . 62 421.75 137.571 2953 7202 8678 FET MWD040 HR 0. 61 60.51 3.1727 2953 7212 8688 RPX MWD040 OHMM 1.45 25.04 4 .37629 2953 7212 8688 RPS MWD040 OHMM 1.38 23.7 4 .51513 2953 7212 8688 RPM MWD040 OHMM 1.35 24 .21 4 . 9526 2953 7212 8688 RPD MWD040 OHMM 1.44 24 .74 5. 1444 2953 7212 8688 ROP MWD040 FPH 0. 17 193.52 70.3485 2956 7260.5 1 8738 FCNT MWD040 CP30 369.5 1727. 62 712.489 2949 7165 8639 NCNT MWD040 CP30 79851.4 133303 101565 2949 7165 8639 NPHI MWD040 PU 12.54 49.32 30.0927 2949 7165 8639 First Reading For Entire File 7148.5 Last Reading For Entire File 8738 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 • Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 8678.5 13179.0 R27P 8718.0 13186.0 R09P 8718.0 13186.0 EWXT 8718.0 13186.0 R39P 8718.0 13186.0 R15P 8718.0 13186.0 ROPA 8738.5 13228.0 LOG HEADER DATA DATE LOGGED: 02-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 13228.0 TOP LOG INTERVAL (FT) : 8738 .0 BOTTOM LOG INTERVAL (FT) : 13228 .0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 83.5 MAXIMUM ANGLE: 91.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 091360 EWR4 Electromag Resis. 4 11261763 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6. 125 DRILLER'S CASING DEPTH (FT) : 8728 .0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10. 30 MUD VISCOSITY (S) : 45. 0 MUD PH: 9. 0 MUD CHLORIDES (PPM) : 122000 FLUID LOSS (C3) : 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .080 68.0 MUD AT MAX CIRCULATING TERMPERATURE: . 884 173.2 MUD FILTRATE AT MT: .060 70.0 MUD CAKE AT MT: .090 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD050 API 4 1 68 4 2 FET MWD050 HR 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8678. 5 13228 10953.3 9100 8678.5 13228 GR MWD050 API 22. 98 97.89 53.3594 9002 8678.5 13179 FET MWD050 HR 0.41 161.39 1.50092 8937 8718 13186 RPX MWD050 OHMM 0. 1 20. 97 9.35246 8937 8718 13186 RPS MWD050 OHMM 0. 1 92 10. 8805 8937 8718 13186 RPM MWD050 OHMM 2.41 1703.84 13. 4822 8937 8718 13186 RPD MWD050 OHMM 2.77 1899. 97 13.1682 8937 8718 13186 ROP MWD050 FPH 1. 14 129.24 86.071 8980 8738.5 13228 First Reading For Entire File 8678.5 Last Reading For Entire File 13228 File Trailer Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.007 Physical EOF File Header Service name STSLIB.007 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH BTCS 7077 .5 7890.5 TNPS 7093.5 7902.0 TNFA 7093.5 7902.0 TNNA 7093.5 7902.0 ADCL 7106.0 7902.0 AHSI 7106.0 7902.0 ACDL 7106.0 7902.0 APEL 7106.0 7902.0 ACHD 7113.5 7902.0 DGRC 7131.0 7902.0 R39P 7141.0 7902.0 R27P 7141.0 7902.0 EWXT 7141.0 7902.0 R09P 7141.0 7902.0 R15P 7141.0 7902.0 RSPD 7192.5 7902.0 LOG HEADER DATA I DATE LOGGED: 24-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 8738.0 TOP LOG INTERVAL (FT) : 7260.0 BOTTOM LOG INTERVAL (FT) : 8738.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 42.4 MAXIMUM ANGLE: 83.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 279516 EWR4 ELECTROMAG. RESIS. 4 10505932 CTN COMP THERMAL NEUTRON 244601 BAT Bi-modal Acoustic 195179 ALD Azimuthal Litho-Dens 10603721 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (FT) : 2619.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.50 MUD VISCOSITY (S) : 43.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 650 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1. 960 65.0 MUD AT MAX CIRCULATING TERMPERATURE: . 906 148.5 MUD FILTRATE AT MT: 1. 990 65.0 MUD CAKE AT MT: 1.800 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: # I Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MAD041 IN 4 1 68 4 2 RHOB MAD041 G/CC 4 1 68 8 3 DRHO MAD041 G/CC 4 1 68 12 4 CALN MAD041 IN 4 1 68 16 5 PEF MAD041 B/E 4 1 68 20 6 DTC MAD041 USPF 4 1 68 24 7 GR MAD041 API 4 1 68 28 8 FET MAD041 HR 4 1 68 32 9 RPX MAD041 OHMM 4 1 68 36 10 RPS MAD041 OHMM 4 1 68 40 11 RPM MAD041 OHMM 4 1 68 44 12 RPD MAD041 OHMM 4 1 68 48 13 RAT MAD041 FPH 4 1 68 52 14 FCNT MAD041 CP30 4 1 68 56 15 NCNT MAD041 CP30 4 1 68 60 16 NPHI MAD041 PU 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7077.5 7902 7489.75 1650 7077.5 7902 CALA MAD041 IN 8.89 10.84 9.4284 1089 7113.5 7902 RHOB MAD041 G/CC 1. 669 3. 108 2.46158 1593 7106 7902 DRHO MAD041 G/CC -0. 103 0.204 0.0480785 1593 7106 7902 CALN MAD041 IN 8. 41 13.87 9. 38008 1593 7106 7902 PEF MAD041 B/E 2. 196 10.725 4 . 91079 1593 7106 7902 DTC MAD041 USPF 79.57 112. 92 95. 9809 1611 7077.5 7890.5 GR MAD041 API 83. 99 430. 12 180. 951 1543 7131 7902 FET MAD041 HR 36. 63 114 .54 55. 4017 1523 7141 7902 RPX MAD041 OHMM 1. 44 13. 11 3. 80997 1523 7141 7902 RPS MAD041 OHMM 1. 48 12.74 4 .00116 1523 7141 7902 RPM MAD041 OHMM 1.45 12.81 4 . 14441 1523 7141 7902 RPD MAD041 OHMM 1.51 10.48 4 .25328 1523 7141 7902 RAT MAD041 FPH 15.75 423.2 251. 119 1420 7192.5 7902 FCNT MAD041 CP30 402.27 1808.55 600.012 1618 7093.5 7902 NCNT MAD041 CP30 85524 . 1 130285 97784 .7 1618 7093.5 7902 NPHI MAD041 PU 12.03 60.27 35. 9536 1618 7093.5 7902 • First Reading For Entire File 7077.5 Last Reading For Entire File 7902 File Trailer Service name STSLIB.007 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.008 Physical EOF Tape Trailer Service name LISTPE Date 11/04/06 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN p Comments STS LIS Writing Library.. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/04/06 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File 1