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206-046
„~,1. .~ ~,'~ ~~ rr ,~~ t i, .~~' MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE. C:\templTemporary Internet Files\OLK9\Microfilm_Marker.doc r~ ~ ~' J DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060460 Well Name/No. COLVILLE RIV FIORD CD3-307 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20529-00-00 MD 13030 TVD 7044 Completion Date 4/28/2006 Completion Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATI ON Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Date Digital Dataset Tyke Med/Frmt Number Name ' D D Asc Directional Survey ~' 13967 LIS Verification ~ C Asc 13967 LIS Verification V.!! vED C Lis 13697 Induction/Resistivity (~ED C Las 14477 Csa..y.~r1~.. ~I.og Induction/Resistivity Log Induction/Resistivity 1ED C 16121 S N ee otes Well Cores/Sampl es Information: Current Status P&A UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Scale Media Run No Interval Start Stop OH / CH Received Comments 36 13030 Open 6/27/2006 ~ 3 6069 13030 6/27/2006 i LISTPE 22-Jun-2006 3 6069 13030 6!27!2006 3080 12988 Open 6/27/2006 GR, NPHI, NWRO, DRO, RHOB,ROP 10768 11718 Open 2/14/2007 Jewerly Log in LAS form, w/Graphics 25 Col 114 13030 Open 4/21/2008 MD ROP, DGR, EWR, ALD, CTN 22-Apr-2006 25 Col 114 7043 Open 4/21/2008 TVD DGR, EWR, ALD, CTN 22-Apr-2006 0 0 Open 4/21/2008 TVD and MD logs in CGM, EMF and PDF grphics Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y l~ Daily History Received? ~/ N Chips Received? ~7'M1t" Formation Tops ~./ N Analysis ~'T~1 Received? __ Samples No Comments: DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060460 Well Name/No. COLVILLE RIV FIORD CD3-307 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20529-00-00 MD 13030 TVD 7044 Completion Date 4/28/2006 Completion Status 1-OIL Current Status P&A UIC N -- - -_ - - --- -- ---3 -- Compliance Reviewed By: _ Date ~ A-jj • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-307 • April 17, 2008 AK-MW-433275 CD3-307: 2" x 5" MD TC Logs: 1 Color Logs 50-103-20529-00 2" x 5" TVD TC Logs: 1 Color Logs 50-103-20529-00 Digital Log Images: 1 CD Rom 50-103-20529-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~' >,~ .~ Date: '~~`~ ;~,,J- Si ed: i • CD3-107 Current Well Completion 16" Conductor to 114' f+ 3 ~~~~~~ ~.;-~,~~ 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 3093' MD / 2479' TVD 3-1/2" 9.3 ppf L-80 EUE M cemented to surface tubing run with Jet Lube Run'n'Seal pipe dope Completion MD Tubing Hanger 32' 4-%2' 12.6 #/ft IBT-Mod Tubing (2) Crossover 3'/2" 9.3#/ft EUE -Mod Tubing Camco TRMAXX-5E SSSV (2.812") 2236' 3-'/" 9.3#/ft EUE -Mod Tubing Camco KBMG GLM (2.867" ID) 4804' 3-'/2" 9.3#/ft EUE -Mod Tubing Camco KBMG GLM (2.867" ID) 8769' 3-'/" 9.3#/ft EUE -Mod Tubing Camco KBMG GLM (2.867" ID) 10714' 3-'/" 9.3#Jft EUE -Mod Tubing (1) HES 2.813" X Profile 10763' 3-%" Tubing Joints EUE-Mod (1) 3-'/" Baker Gauge Mandrel 10805' 3-%" Tubing Joints EUE-Mod (1) Baker Premier Packer 10856' 3-%:" 9.3#/ft EUE -Mod Tubing (1) HES XN (2.75" NoGo) 10902' 3-%2' 10' pup joint WLEG 10914' Calc TOC +500' above top of Kuparuk C Interval Proposed Kuparuk ' Interval Perforations: 10944-10970'MD Top of Nechelik 11763' MD/ 7075' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 11874' MD / 7077 TVD @ 84° Collasped area above Nechelik .:::;: 13,200-13,500' MD_____-------------------~-~ ; - --- Well TD at 18,315' MD Proposed low side sidetrack point at 12,900' MD • ~ Page 1 of 2 ~~ ~~ ~,o Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday, March 07, 2008 5:35 PM To: 'Galiunas, Elizabeth C'; Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA) Subject: RE: Naming Question on CD3-107 Liz, There is no clean answer to this one. Since the Kuparuk and Nechelik sandstones are in pressure communication within the Fiord Field, AOGCC assigns them to a single oil pool, the Fiord Oil Pool. The 300 series numbers denote Fiord wells within the Kuparuk sandstone, and 100 series numbers denote Fiord wells within the Nechelik sandstone. This well was originally a Kuparuk well C,~, C~3-307,+PTD 206-046, API 50-103-20529-00-00) that was subsequently deepened to the Nechelik. Deepening the well required a new permit to drill (number 206-189), and since the well was being redrilled to the Nechelik, the well was renamed CD3-107 and given a new API number of 50-103-20529-01-00. We couldn't call the deepening CD3-307A, because it was being drilled to the Nechelik. In retrospect, maybe we should have named the deepened wellbore CD3-107A, but at the time I thought that name would cause too much confusion. I# seemed like CD3-107 was the best name for the deepened wellbore. Now, I'm assuming that ConocoPhillips will plug and abandon the pay zones within CD3-107, before redrilling to a new target in the Nechelik. So long as nothing is left open in the existing CD3-107 wellbore, the best approach is to name the new wellbore CD3-107A and give it an API number of API 50-103-20529-02-00. AOGCC wi(I assign this new wellbore a new permit to drill number. In the future, people will be confused by what appears to be a mistake in naming or numbering, but I think it would be more confusing to give the new wellbore the name CD3-1076. Then people would just wonder why there wasn't a "CD3- 107A" wellbore. Copies of this email will be placed in the CD3-307. CD3-107 and CD3-107A well history files to help clear up any confusion. Thanks, Steve Davies AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Friday, March 07, 2008 12:07 PM To: Davies, Stephen F (DOA) Subject: Naming Question on CD3-107 Hi, Steve, We are getting ready to submit a sundry and a new permit to drill for CD3-107. Here is a brief description for the sundry and the new permit to drill . I need some guidance on naming. ConocoPhillips Alaska drilled CD3-107 (PTDs#: 206-189 & 206-046 API 50-103- 20529-00/01). After drilling the first thousand feet of the lateral, the Nechelik sand was exited into the shale above (between 13200' MD-13500'MD). After 13500'MD the lateral continued in the Nechelik sand to a TD of 18315' MD. Once the well was handed over to production, the shale section collapsed and the Nechelik horizontal 3/7/2008 Page 2 of 2 would not produce. It is~ielieved that the basal Nuiquist co~psed, filling the lateral, preventing any production from the Nechelik. The well was perforated in the Kuparuk sand above the Nechelik, and has been producing out of a short section of perforations for around a year. The asset would like to return to this well, decomplete it, sidetrack off the existing lateral at 12,900' MD, and redrill the Nechelik lateral to a TD of 19306' MD. Since returning to the well is a re-entry, planned sidetrack/re-drill the well should take on a letter (I.e.CD3-107A?), but since this well was also CD3-307 (API 50-103-20529- 00) I am not sure what the API or name would be for the re-drilled section since -01 is taken already. Would we name it B and -02? I attached a schematic to help visualize the currentwell and proposed work. I do not have Jim Regg's information to send this to him also since Tom is out of the office. Regards, 3/7/2008 ConocoPhilli S Casing Detail 9 5/8" Surface Casin_g ~-I~, ~'"~ 7-' Well: CD3-307 Date: 4/16/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS ~ © a b~ Doyon 19 RKB to Landing Ring 36.82 FMC Gen V Hanger 2.16 36.82 Jts 3 to 79 77 Jts 9-5/8" 40# L-80 BTC Csg 2974.88 38.98 Halliburton Float Collar ?j 1.51 3013.86 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 75.34 3015.37 Ray Oil Tools "Silver Bullet" Float Shoe 2.20 3090.71 3092.91 TD 12 1/4" Surface Hole 3102.91 12-1/4" Hole @ 3103' MD / 2484' TVD 9-5/8" Shoe @ 3093' MD / 2479' TVD RUN TOTAL 44 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8~ 2 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68, 70, 72, 74, 76 88 joints in the pipe shed. Run 79 joints - 9 joints stay out Use Best-o-Life 2000 pi a do e MU torgue - 9000 ft/Ibs Remarks: Up Wt - 160k Dn Wt- 148k Block Wt - 75k Supervisor: D. Burley/L. Hill r r~ ~ Cement Detail Report CD3-307 Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL & INITIAL COMPLETION DRILLING 10107072 4/13/2006 4/13/2006 4/27/2006 Cement-Details - - - _ _ -- Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 4/16/2006 17:00 4/16/2006 18:57 CD3-307 Comment - -- !CementSYages - __ - - --- _ _ -- -- _ - - - --- - -_ - -- jStage # 1 Description Objective Top (ftK6) Bottom (ftK6) Full Retum? Cmnt Rtm (... Top Plug? Btm Plug? Surtace Casing Cement 36.8 3,093.0 Yes 88.3 Yes Yes 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 6 560.0 1,150.0 Yes 2 0.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cement Fluids & Additives - - -- --- _ - _ - Fluid Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Surface Cement 0.0 2,340.0 385 G 305.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 12.45 10.70 Additives Additive Type Concentration Conc Unit label - - - Fluid - - Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,340.0 3,093.0 230 G 48.0 Yietd (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.40 15.80 Additives Additive Type Concentration Conc Unit label "~~ T , ~ ~~~ Page 1/18 Report Printed: 12/28/2006 r Security Level: Development Daily Drilling Report CD3-307 Report Number: 4 . .. Rig: DOYON 19 Report Date: 4/16/2006 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD3-307 Development FIORD KUPARUK 4/13/2006 3.06 3,103.0 3,103.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10107072 6,465.82 39,125.14 421,839.82 976,423.14 6,314,754.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) 9 5/8" Surface, 3,092.9ftK6 Ops and Depth @ Morning Report 24hr Forecast Setting wear bushing. Test BOP. PU and stand back DP. PU BHA and RIH. Last 24hr Summary Laid down BHA. Rigged up and ran 79 Jts 9 5/8" casin g to 3,093'. Circulated. Cemented casing. Tested casing. ND riser. NU BOP. General Remarks Weather Head Count -14 Wind NW @ 8 MPH 48.0 Time Log St ~ E~~~ ~ ~.:~ '. T~~r e ~ Trr ~ Tree h rsi Phase 'p Code QpSub C:; I'-N-T Trbl Coda lib/ Cass Depth St:ad depth End I {ftKB) (ftKB) Cor~ma'OF;~~i:ancn 00:00 04:30 4.50 COND1 DRILL TRIP P 3,103.0 167.0 Flow check we{I, static -POOH w! pump from 3,069' to 2,594' -attempt to pull without pump -swabbing -POOH with pump from 2,594' to 1,168' - 3.5 bpm / 430 psi - hole taking proper fill -flow checked well @ 610' static. 04:30 07:00 2.50 COND1 DRILL PULD P 167.0 0.0 Lay down jars, DC's, UBHO -down load MWD -pull pulsor -lay down TM - HCIM -DM -stab - FS -motor and bit -clear tools from rig floor 07:00 08:45 1.75 COND1 CASING RURD P 0.0 0.0 RU to run 9 5/8" casing 08:45 09:00 0.25 COND1 CASING SFTY P 0.0 0.0 Held Pre job safety and Opts meeting with crew. 09:00 11:45 2.75 COND1 CASING RNCS P 0.0 1,552.0 Run 9 5/8" 40# BTC csg as follows: FS(Silver bullet) 2 jts. csg - FC (Weatherford) 2 jts. csg (fill pipe & check floats -first 4 connections made up w/ BakerLoc) 36 jts. csg. for 40 total to 1,552' 11:45 12:15 0.50 COND1 CASING CIRC P 1,552.0 1,552.0 Establish circ at 3.8 bpm / 210 psi -staged pumps up to 6 bpm and CBU -FCP =290 psi - PUW 130K SOW 124K 12:15 14:30 2.25 COND1 CASING RNCS P 1,552.0 3,093.0 Continue running 9 5/8" 40# BTC csg. f/ 1,552' to 3,053'. Total jts. run 79 - MU FMC fluted hanger and LJ - Landed casing w/ shoe @ 3,093' & FC @ 3,014' 14:30 15:00 0.50 COND1 CASING RURD P 3,093.0 3,093.0 Lay don fill-up tool -blow down top drive - MU cement head 15:00 16:45 1.75 COND1 CEMENT CIRC P 3,093.0 3,093.0 Establish circ with 2 bpm / 250 psi -staged pumps up 7 bpm -circulate and condition mud for cementing -FCP 280 psi Held PJSM with Dowell and rig crew 16:45 19:00 2.25 SURFAC CEMENT DISP P 3,093.0 0.0 Cement 9 5/8" casing as follows: Pumped 40 bbls. biozan water w/ nut plug - 6 bpm @ 250 psi w/ rig pump -Switch to Dowell -Pumped 3 bbls water -test cement lines to 3000 psi -Dropped btm plug -Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.7 bpm @ 320 psi - Mixed & pumped 305 bbls of lead slurry (ASL "G" w/ 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1% D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.4 bpm @ 220 psi -switched to tail slurry 48 Bbls ("G" w/ 0.2% D46, 0.3% D65, 2% S001) @ 15.8 ppg - 5.6 bpm @ 205 psi Dropped top plug & pumped 20 bbls water w/ Dowell - Switch to rig pumps -Displaced w/ 10.1 ppg mud @ 7 bpm 340 to 560 psi for first 205 bbls -slowed to 4 bpm @ 460 psi for last 4 bbls. -Bumped plug t/ 1150 psi - CIP @ 1857 hrs, floats helds. Full returns during job w/ 88.3 bbls cement returns to surface - recripcated pipe until 305 Bbls of lead slurry away, landed hanger on landing ring. Latest BOP Test Data t n~, -- ' (.ornment Page 1/2 Report Printed: 72/28/2006 Daily Drilling Report CD3-307 Security Level: Development Report Number: 4 tig: DOYON 19 Report Date: 4/16/2006 -- - !Time Lo __ __ .,._~, End Dur l r ~ir -- - -. C pJ-~ Sb, D-ix~'~ G i i'r~c Time (hrs) Pr~~ar: (r.~ Co 1. )e5,.~: ~'-N i 1-t: ! c7e liL t_ ,,.,., ~` Y.F,1 ifrhh; r irmr~hrerafion 19:00 20:00 1.00 SURFAC CASING DHEQ P 0.0 0.0 Rigged up and tested casing to 2,500 psi for 1/2 hour. 20:00 21:00 1.00 SURFAC CASING RURD P 0.0 0.0 Rigged down cement head, bales, casing slips and evelators. 22:45 ~ 00:00 ~ 1.25 Mud Check Data ~- --- i f' Cal, i~el (10s} Gef (10m) Gel (3( ~~ ~ it CHI F-~ ---- - ~~~ Dar. Tr nr r,', f. :.o~i I Type Depth (ftKB) Usr., ,,,,, yu j ' U s ,t ~ ' f V Car_ ~,r;p Water 3,103.0 10.10 68 20.0 I~' ' .;i1 '. ,f~nl100ft') (tbtllODft') {Ibf190( _ ~ g;~, r,L,~~;~ ~ 17.000 3.000 14.000 38.000 30.0 L , ri^. i ~ H I 1 8.9 11.0 Based Mud Injection Fluid -- C'.:id S ~r~ r, .-. ~ - From Lease (bbl) U ~ i,~~:_n 1 _ _ Note -- - --- Diesel I - _.. _ - 15.0 _.. _.- - - - - ----- Same ---- Recycled mud 665.0 ~ CD3-307 to 109 Drill Strin s: BHA No. 1 - Steerable<i Sit Run No. 1 - - 12 1/4in, Hu hes Christensen, MXL-1, 5092249 Depth In (ftKB) Depth Out (ftKB) TFA (loci Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001bf) WOB (rnax) (100... WOB (min) (1000... 114.0 3,103.0 0.75 18/12116/16 3-4-WT-A-E-1-NO-TD 44 33 0 Drill String Components J Ham Description 00 (ln} ID ;ni ' io~~ Conn Sz (in) Top Thre_,d Cur Len !rr~ _ ---_- -- Motorwith Stabilizer 8 4.947 6 5/8 H 90 30.10 Float Sub 7 7/8 3.000 6 5/8 H 90 32.04 Stabilizer 8 2.875 6 5/8 H 90 37.57 XO Sub 8 2.900 6 5/8 Reg 40.08 MWD (DM) 7.99 3.000 6 5/8 Reg 49.21 MWD (HCIM) 7.98 1.920 6 5/8 Reg 57.62 MWD (TM) 8.02 3.250 6 5/8 H 90 67.53 UBHO 8 3.500 6 5/8 H 90 70.47 NMDC 7 1/2 2.813 6 5/8 H 90 101.51 NMDC 7 3/4 2.813 6 5/8 H 90 132.52 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF 166.82 24 HWDP 5 3.000 41/2 IF 886.59 Drilling Parameters _ ~K Ilan-ih ~`.Cun CF h;tt Tii~ Start (ftkC41 Li ,•, imi 1~ {, ~ ~I ~~ _ R.vj PPr~.4 -- PU HI ~ P~~HI CF ~C B ;.t ~~) 3PP iP$~) (1 QODI_r~ 1 Irf. -.. __ ~~ (1 ~ ~ P.I rr f~ ~~ ... ---- Dull I~ _ ~ cac 9 0 ~ 3,1 ~~_0 3.103 0 2 ~~~ 00 0 0 0 0 0 0 0.0 10. ~ ~ ~~ U 150 ~~ IWellbores - _- -- - - -- Wellbore Name Wellbore APIIUWI ~ GD3-307 5010 32052900 Section ~',i? ~;i~.~~ AG Top (ftKB) Act Btm (ftKB) S c-t Oate F^d Oafi COND1 24 0.0 114A 4/1/2006 4/1/2006 SURFAC 12 1/4 114.0 3,103.0 4/13/2006 4/18/2006 INTRM1 8 3/4 3,103.0 13,030.0 4/18/2006 4/22/2006 Casing Strings - --- - - ~ - _ - Ca~~na C7 ~°-p' on Run ©ata CAD l'J: "I ~ ,r~d~~ , •i De: t i:K(31 c.-wren: ~9 5/8" Surface 4!16/2006 9 5/8 40.00 L-80 3,092.9 - -- ~Cement ___ - - __ Surface Casio Cement -Started 4/16/2006 Type Wellbore String Cement Evaluation Results casing CD3-307 9 5/8" Surface, 3,092.9ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.8 3,093.0 4 560.0 r ~_~_f ~ Mass Amount (sacks) ', V (bbl) DensRy (Ihlgaq Yieltl (fi' _ m:k) Est Top (ftKBJ - ~ Fst Btm (ftKB) Surface Cement G 385 305.0 10.70 4.45 0.0 2,340.0 Tail Cement G 230 48.0 15.80 1.17 2,340.0 3,093.0 Page 2/2 Report Printed: 12/28/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 307 Rig: Doyon 19 Date: 4/16/2006 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Burley/Hill Pump used: #2 Mud Pump ~ strokes • 0.1005 ~ Bbis/strk ~ I' 7.OI~ strk/min ~ Type of Test: OpenholeTest LOT/FIT ~ Pumping down annulus and DP. ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 36.8 Ft 3,093 Ft-MD 2,479 Ft-TVD 3,123 Ft-MD 2,494 Ft-TVD Strks si Min si Strks si Min si Casing Size and Description: 9-5/s" 4o#/Ft L-so BTC ~ 0 0 0 2525 0 0 0 1060 Casin Test Pressure Int e rit Test 2 100 1 2525 2 100 0.25 1040 Mud Weight: 10.1 ppg Mud Weight: 9.8 ppg 4 400 2 2525 4 200 0.5 1000 Mud 10 min Gel: 3.0 Lb/100 Ft2 Mud 10 min Gel: 3.0 Lb/100 Ft2 6 650 3 2525 6 350 1 960 Test Pressure: 2,500 psi Rotating Weight: 135,000 Lbs 8 850 4 2525 8 500 1.5 92 Rotating Weight: 150,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 1050 5 2525 10 640 2 88 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 1250 6 2525 12 740 2.5 850 Estimates for Test: 1.9 bbls Estimates for Test: 1057 si 0.8 bbls 14 1425 7 2520 14 800 3 810 ~ ~ 16 1620 8 2520 16 850 3.5 790 EMW =Leak-off Pressure + Mud Weight = 1080 PIT 15 Second 18 1820 9 2520 18 900 4 780 + 9 8 0.052 x TVD 0.052 x 2479 Shut-in Pressure, si 20 2020 10 2520 20 950 4.5 765 EMW at 3093 Ft-MD (2479 Ft-TVD) = 18.2 1040 22 2220 15 2520 22 1000 5 740 300o L t 5 i rin d h test eld 24 2420 20 2520 24 1050 5 5 705 os ps g u , . 99.8% of t est pre ssure . 25 2530 25 2520 25 1080 6 700 30 2520 6 5 700 .. ... .----~ ~ ~ ~-_ ~ : ~ . zsoo . 7 690 7.5 675 8 650 2000 8 5 640 w . ~ 9 635 9.5 625 N ~soo w 10 62 a: a - 1000 s00 0 0 0 0 5 1 0 1 5 2 0 2 5 3 0 0 5 1 0 1 5 2 0 2 5 30 . ~~CA . . SING TEST . Barrel s -~-L . EAK-OFF TE . ST . Shut-I O P n tim IT Poin e, M t inute s Volume PUm ed Volume Bled Back Vol Pu ume m ed Vol Bled ume Back s s s s Comments: ConocoPhilli s p Casing Detail 7" Casing C] Well: CD3-107 Date: 2/17/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.45 FMC Gen V Hanger 2.32 34.45 Jts 3 to 276 274 Jts 7" 26# L-80 BTCM Csg 11749.00 36.77 Weatherford Float Collar 1.26 11785.77 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 85.09 11787.03 Ray Oil Tools "Silver Bullet" Float Shoe 2.13 11872.12 11874.25 TD 8 3/4" Hole 11886.00 8-3/4" Hole TD @ 11,886' MD / 7,077.41' TVD 7" Shoe @ 11,874.25' MD / 7,075.87' TVD Total Centralizers: 50 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt jts. 206,207,208 Straight blade centralizer one per jt on every other joint from #'s 210 thru 274 Top Nechelik - 11,763' MD 7,060' TVD 286 joints in shed - total 276 jts. to run Last 10 jts. out Jts. 181-241 2603' used -laid down F/ CD3-307 Use Run 8~ Seal i e do e MU torque - 7800 ft/Ibs Remarks: Up Wt - 315 k Dn Wt-165k Block Wt - 75k Supervisor. D.Burley/L. Hill - - -- Cement Detail Report CD3-107 Intermediate Casing Cement ' _ _ - _ Cement Details -- -- - ----- Description Cementing Start Date ,Cementing End Date Wellbore Name Intermediate Casing Cement 2/17/2007 18:31 2/17/2007 20:20 CD3-107 --- -- - - - Comment ~~_ ... - _ _ _ --_ -------- -..__ _ - ~I Cement Sta es _ Stage # 1 g _.__ _ - -_-- - ~ - ... To Plu v Btm Plu ~ ~I lDescription Objective Top (ftKB) Bottom (ftKB) Full Return . Cmnt Rtrn ( p g . g . 'Intermediate Casing 10,389.0 11,874.0 Yes 0.0 Yes Yes (Cement O (start) (bbl min) O (end) (bbllmin) O (avg) (bbl/min) ',P (final) (psi) P (bump) (psi) Recip? Stroke (ft) .Rotated? ,Pipe RPM (rpm) 5 5 4 570.0 1,200.0 Yes 20.00 No --- -- -- - Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement 7" casing as follows: Pumped 5 bbls CW-100 -Test lines to 4000 psi -Pumped 15 bbls CW-100 -Mixed 8 pumped 30 bbls 12 ppg Mud Push @ 3.2 BPM @ 330 psi - Dropped btm plug -Mixed & pumped 57 bbls (277 sxs Class G w/additives) @ 15.8 ppg tail slurry @ 5.2 BPM @ 500 psi -Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps ~ displaced cmt w/ 431 bbls 10 ppg mud @ 7 BPM -Slowed pumps to 4 BPM for last 3 bbls of dispalcement -Bumped plug w/ 1200 psi (pre bump pressure 570 psi) CIP @ 2020 hrs. -Check floats (held OK) Full circulation throughout job. 'Cement Fluids & Additives - - -- Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class '.Volume Pumped (bbl) (Tail Cement 10,440.0 11,874.0 277 G 57.0 i ----- _ __ -- - ----- `,Yield (fN/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 15.80 - __ - - Additives --- - _ _ _ ' Additive Type Concentration IConc Unit label ' i Page 1/1 Report Printed: 12/11/2007 I-- Security Level: Development Daily Drilling Report CD3-107 Report Number: 15 tig: DOYON 19 Report Date: 2/17/2007 AFE Type NetworkllD # "~ Total AFE+Sup '. 10159991 7,100, 002.00 Wellbore Well Type Field Name DFS (days) DOL .Depth Progress (ft) jDepth Start (ftKB) Depth End (ftKB) CD3-107 Development 'FIORD KUPARUK 14.25 15.0 0.00 ' 11,886.0 11,886.0 - - -- Daily Mud Cost .Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,068.91 344,527.93 481,913.91 3,276,470.93 ' Actual Start Date ,Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/3/2007 ' 4/13/2006 25.00 ~ast Casing String ,Next Casing OD (in) Next Casing Set Depth (ftKB) -J l~ermediate, 11,874.OftKB -__ Ops and Depth @ Morning Report ' Testing BOP. - - - -- - Last 24hr Summary Ran and cemented 276 jts 7" casing. Tested casing. Set and tested packoff. - - - - General Remarks L_.. Supervisor_ . ---- - -. IDa e Eurley, Rig Supervisor Larr~~ Hill, Rig Supervisor Time Log tart End Dur --~ lime Time ~ (Y~rsi Fbas~ Op Code '.. OpSub Code OO:OOr02:15 225 INTP1~12 CASINGRNCS 02:1503:30 1.25~~INTRM2 CASING RNCS 103:30 04:45 1.25 INTRM2 CASING I r04t45 05:30', 0.75 INTRM2 'CASING --- _ __ 24hrForecast Test BOP. Lay down 5" DP PU and RIH BHA. Drill shoe track. -- Weather (Head Count -29 wind S @ 2 mph. 48.0 Title --- Rig Supervisor Rig Supervisor I - - ~ -- ~ U •pth Start i Depth End - t' N a ' Trbl_Cdde ~ Trt>I Class } tnKB} (ftKB) ', Operation ,' X I 732.01, 3,147.OContinue running 7" csg f/ 732'to X147' ' ' (74 jts. total) XT 'Hole Weight ~, 3,147.0+ 3,176.0'.Casing stopped at 3147 -staged pumps Conditions Transfer/d... ~l up to 6.5 bpm -worked through tight hole ~, ,from 3147 to 3157 (kick of point) 'circulated joint # 74 down to 3176' - - - - - RNCS X 3,176.0 4,504.0 Run 7" csg f/ 3176'to 4504' (105jts. '~ total) ~~' - - -- -- CIRC X 4,504.0 4,504.0 Stage pumps up to 5 bpm -circulate and ~, ', condition mud -FCP= 370 psi PUW ', I 160K SOW 135K 0 ~ -- - ~ S ~' ~ - - 4,504.Oi Run 7" csg f/ 4504' to 7508' (175 jts. 7,508.0 ~ ~~ total) 08:4 5~09:45 ~ 1.00 INTRM2 CASING C RC X ', ~ 7 508.0 Establish circulation - 3.5 bpm / 500 psi - 7 508.1) I stage pumps up to 6 bpm -circulate and ' condition mud -FCP= 570 psi PUW ', 210K SOW 146K 09:45 12:45 3.00 INTRM2 CASING RNCS 'X 7,508.0 10,284.0 Run 7" csg f/ 7508'to 10,284' (240jts. ' total) - - -- - ',12:45 14:00 1.25 INTRM2 CASING iCIRC X i 10,284.0 Establish circulation - 3.6 bpm / 530 psi - 10,284.0 i ~, stage pumps up to 6 bpm -circulate and ', I I ', '.condition mud -FCP= 580 psi PUW 1 i 280K SOW 165K 14:00 116:00 2.OO~,INTRM2 CASING -- -- RNCS - _ X _ - _ I ' 10,284.0 - ~-- 11,874.0'Run 7" csg f/ 10,284'to 11,833' (276jts. I 'total) - PU FMC fluted hanger & landing '~ jt. -Land 7" csg w/ FS @ 11,874.49' FC ' @ 11,785.77 ! .16:00 16:30 0.501NTRM2 ! .CASING OTHR ~X ' 11,874.0'1, Lay down fill up tool -blow down top 11,874.0 I I 1- ~ drive - MU cement head and lines -- -- -- i- 16:30 18:30 2.00 INTRM2 - -- CEMENT CIRC X i 11,874.01 11,874.0 Establish circulation - 2.1 bpm / 330 psi - ', ~ 11 stage pumps up to 6.5 bpm -circulate ' !and condition mud -FCP= 550 psi PUW ' ' --' I 325 K SOW 160 K '- . Latest BOP Test Data Date Comment 2/5/2007 Set test plug and test BOPE: Hydril to 250 & 3500 psi Ppe rams, Choke ma_ nrfold,_choke & kill line_vlaves, Pipe rams,bl_ind rams, - - - Page 1/3 Report Pnnted: 12/11/20071 -- - __ - - Security Level: Development Daily Drilling Report CD3-107 Report Number: 15 tig: DOYON 19 Report Date: 2/17/2007 - _- --- Time L~_ _ __ ' -Stall ~ End Cw Tiir~e i, Deptl, Start:;, Depth E{~~ '. Time Time i ihrs~ s Phase Gp Cooe OpSup-code ~ 'd-~ ~ Trti Code Trbl Class. '. (ftt .5) {RKBj Cox-aaiign ', 18:30 20:30 2.00 INTRM2 'CEMENT DISP X ', 11,8 74.0 O.U Cemt~nt 7" casing as follows: Pumped 5 ', ' bbls CW -100 -Test lines to 4000 psi - ', Pumped 15 bbls CW-100 -Mixed & pumped 30 bbls 12 ppg Mud Push @ 3.2 BPM @ 330 psi - Dropped btm plug - Mixed & pumped 57 bbls (277 sxs Class ' G w/additives) @ 15.8 ppg tail slurry @ ' I 5.2 BPM @ 500 psi -Dropped top plug I I w/ 20 bbls water f/ Dowell -Switched to ', I rig pumps ~ displaced cmt w/ 431 bbls ', ', 10 ppg mud @ 7 BPM -Slowed pumps ~I ~', to 4 BPM for last 3 bbls of dispalcement -Bumped plug w/ 1200 psi (pre bump ' ~I pressure 570 psi) CIP @ 2020 hrs. - i I j ~ I Check floats (held OK) Full circulation ~i, ' ~ ', I i1 ~ ', throughout job. I ' 21:30 i 1.00 INTRM2 CASING DHEO 20:30, I X I I 0.0 Rigged up and tested casing to 3500 psi '~ 0.0 ,for 30 min. -_ _ ~ I 21:30 22:15 ~ 0.75 INTRM2 (CASING RURD ___ - X _ - 0.0 0.0',Rigged down cement head and laid . ' down landing jt. 1.75 INTRM2 .CASING OTHR .22:15 00:00 - X 0.0 0.0!Pulled thin wear ring and ran packoff. - ~ Would not test. Pulled packoff and found it was not in place. Ran and tested ' 'packoff. r- ------ - - Mud Check Data -------.. _ _ --__ _ ' IF (~s -- l GcI i~L;i Gel (1Qm) t li3~n __ _ HTHP Fitt Densfy TFrrp Ii i;, Corr. Tm~ I ~ V. vas 'siytj uenn 1 -, ~ ~ t ~ _~ t PV ~,alc{W) ~ ' < I ~ ~ rlhr ~~,~ r31, Ibt~toort~) {t.,r' ( ~ ~ (mu3ornr~ti vF ~ (°F) (%) ) _ guar t~b18 < 90 0 o86.0 1 0 O 01 36, 1 LSND ) 6.0 ~ 0 000 000 5 . 5.0 i 1 0 'injection Fiuid '' -- ---- _._---_- -_- _ _. __: Fluid ! Sovrce t roir~ Lease (bbt) I ~c_tination Note Water Based Mud 28G.uli;D i-1 9 ,From CD3-107 I Drill Strings: BHA No. 1 - 7" Mud Mtr 718 6.0 / Bit Run No. 1 - 8 3/4in, Hughes Christensen, HG M 5062, 7114472 __~ Depth In (ftKB) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (/32") I ', (ADC Bit Dull '.String Wt (10001bt) 3,093.0 11,886.0 ~ 1.06 ___ _ -- li 15/16/15/15/15/15 1-2-WT-G_X_O-ER-TD 35 Drill String Components _ -- _ -- _ , Item Descx~pfion _. _. Jts 3 (m) j IQ _ O D ~ {an ~TOp Conn Sz (in) :. Top Thre_ad_ _ __Cum_ Len (ft) '~.. ~ -_ _ _ _ 1'Motorwith Stabilizer _ _ _ ~ 7, 26.23 4.000 4 1/2 NC 50 1 ', NM Float Sub 6 3/4', 2.880 4 1/2 NC 50 28.72 ', 1',Stabilizer (Non Mag) ! 6 3/4 3.000'.. 4 1/2 NC 50 33.45 ', 1 MWD (Directional) ! 6 3/4'1 1.9201 4 1/2 NC 50 42.11 I 1 MWD GR/RES/PWD 6 3/4I 1.9201 4 1/2 NC 50 69.92 1 MWD TM HOC I 6 3/4', 1.920' 4 1/2 NC 50 ~ 79.97 1 NMFIexDC ' 6 3/4' 2.813 4 1/2,NC 50 I 110.86 '~ 1 NMFIexDC 6 3/4 2.813' 4 1(21,NC 50 141.99, 1 NMFIexDC 6 3/4 2.813 4 1/21,NC 50 172.86, 3 HWDP 5 3.000 4 1/2'NC 50 262.99' 1 Drilling Jars -Mechanical 6 1/4 ( 2.250 4 1/2 NC 50 295.69 5__ 3.000 4 1/2 NC 50 716.55 .Drilling Param tern I W i ', ; Sliding I~:Gm) 12PM11 ~'I PU Str 'vVt iinll '.,:r e5': 80 Str W: ~I Start (RKBj End rf1RRi Cum ~c;rlh ilir Curn Dnll IiRr: ihr>) iT+me (hr, ~;Pml !~,~ (Ih{1 `rpm/ SFP.(psi) '. (100{llhf~ (1 u)IbI; 11~.701bf1 O`f Stir TG fJiill iq ' 11,886.0 11,886.0 ~,t.)3-00 82.82 630'( 20.0 90 3,540.0 250 200, 1701 15,000.0 15,500.0 I Wellbores 'Wellbore Name Wellbore APIIUWI ' CD3-107 501032052901 - - _ - - ___ Re ort Printed: 12/11/20071 -- Page 2/3 p ---- __ __ Security Level: Development Daily Drilling Report CD3-107 Report Number: 15 tig: DOYON 19 Report Date: 2/17/2007 Section Si ,in;; ,;:~t ~ r iYlBl _ActBtm(ftKB) StartDate End Date COND1 36 36.0 114.0 3/15/2006 3/15/2006 SURFAC 12 1/4 114.0'. 3,103.0 4/13/2006 4/15/2006 INTRM1 8 3/4 3.103.0 13,030.0 4/18/2006 4/22/2006 INTRM2 8 3/4 3,143.0 11,886.0 2/9/2007 2/15/2007 PROD1 6 18 11,874.0 18,315.0 2/15/2007 2~23i2007 ':Casing Strings.. __ -- _ ___ _-.__ _ _ _ _. __ --- -- Casing Description RanDatc CiD(in~ ' .Ntilh~~ft~ Gra ms SetDeptM{ftY,B) Comirent _ Intermediate - - - 2.1;;2007 7 2i;.00 L-~;) 11,~;~4.0 - _-- 'Cement _ - Intermediate Casing Cement -Started @ 2/17/2007 _ Type Wellbore iCemented String Cement Cvaluation Results casing .CD3-107 I7" Intermediate, 13,020.3ftKB - - -- Stg No. .Description Top (ftKB)'Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 '.Intermediate Casing Cement 10,389.0 ' 11,874.0 5 570.0 Fluid ', ( I Class - AmaunF {sacks} ' V {bbl) Densriy (tbJgal) Yield,(ft /sack) _. Est Top {ftKB) _ _ Est Btm (ftKB) Tail Cement i G 277, 57.0 15.80', 1.16 10,440.0 11,874.0 Page 3/3 Report Printed: 12/11/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: GD3-107 Rig: Doyon 19 Date: 2!1812007 volume Input Pump Rate: Drilling Supervisor: D. Burley / L. Hill Pump used: cement unit ~ Barrels ~ Bbls/Strk ~ 0•$ Bbl/min ~ P i d Type Of TESt: Annulus Leak Off Test for Disposal Adequacy ~ ump ng own annulus. ~ asin Tesi Pressure In te rit Test Hole Size: 8-3/4" ~ Casing Shoe Depth Hole Depth Pumpin Shut-in Pumping Shut-in RKB-CHF: 34.5 Ft 3,093 Ft-MD 2,479 Ft-TVD 10,440 Ft-MD 6,494 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 0 475 Chan es for Annul ar Ade u ac Tes Pressure Int e rit Tes t 1 1 76 0.25 475 outer casing shoe test result: in comments Mud Weight: 10.0 ppg 2 2 152 0.5 464 Description references oute casing string Inner casing OD 7.0 In. 3 3 217 1 449 ize is that drilled below oute casing. 4 4 283 1.5 444 timated TOC for Hole Depth. 5 5 343 2 43 Enter inner casing OD at righ Desired PIT EMW: 15.5 ppg 6 6 404 2.5 429 Estimates for Test: 709 si 0.8 bbls 7 7 464 3 424 ~ ~ 8 8 525 3.5 419 EMW =Leak-off Pressure + Mud Weight = 682 PIT 15 Second 9 9 581 4 419 + 10 0.052 x TVD 0.052 x 2479 Shut-in Pressure, psi 10 10 631 4.5 414 ~ EMW at 3093 Ft-MD (2479 Ft-TVD) = 15.3 ~ ~~" 475 15 10.5 661 5 414 20 11 682 5 5 409 loo0 . 25 11.5 676 6 409 30 12 641 6.5 409 12.5 626 7 409 11, ~b 13 616 7.5 404 13 5 616 8 404 . w 14 616 8.5 404 ~ 14.5 591 9 404 ~ 15 545 9.5 404 N soo w 10 4 a 0 0 2 a s s 1 0 1 z 14 1 6 0 e , o , a s o z 5 so ~~~ CASING T EST Barrel s -~ -LEAK-O FF TEST Shut- O In tim PIT Poi e, M nt inut es Volume PUm ed Volume Bled Back Vol PU ume m ed Volume Bled Back S S S S Comments: 9 5/8" casing shoe F T = 18.2 ppg (4/16/06 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION C~rv~D I~AR 1 4.2007 WELL COMPLETION OR RECOMPLETION REPOF~~~dhl~1~®~ commission 1a. Well Status: Oil ~ Gas Plugged Q .Abandoned ~ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: f1C 01'88 ~,: . Development Q ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: February 9, 2007 / 12. Permit to Drill Number: 206-046 / 306-405 / 307-028 / 307-042 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 13, 2006 13. API Number: 50-103-20529-00 4a. Location of Well (Governmental Section): Surface: ~ 3926' FNL, 79T FEL, Sec. 5, T12N, R5E, UM ' 7. Date TD Reached: April 22, 2006 14. Well Name and Number: CD3-307 ' At Top Productive Horizon: 635' FSL, 657' FEL, Sec. 33, T13N, R5E, UM 8. KB Elevation (ft): 50' BPMSL 15. Field/Pool(s): Colville River Field Total Depth: 842' FSL, 721' FEL, Sec. 33, T13N, R5E, UM 9. Plug Back Depth (MD + TVD): 3250' MD / 2556' TVD Fiord Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388247 ' y- 6003847 ~ Zone- 4 10. Total Depth (MD + TVD): 13030' MD / 7044' ND ' 16. Property Designation: ADL 372104, 372105, 364471 "~ TPI: x- 396362 y- 6008291 Zone- 4 Total Depth: x- 396301 - 6008499 Zone- 4 11. Depth where SSSV set: not applicable 17. Land Use Permit: LAS21122 18. Directional Survey: Yes ^ No Q 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1268' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 3T 114' 3T 114' 24" 10 cu yds Portland Type III 9-5/8" 40# L-80 37' 3093' 37' 2479' 12.25" 3s5 sx Class G, 230 sx Class G 7" 26# L-80 37' 13020' 37' 7043' 8.75" 34o sx Class G 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET none none no perfs open to production 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug from 2893'-3250' 146 sx 17.0 ppg Class G 26. PRODUCTION TEST Date First Production pgp, Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested not available Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27_ CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~~~'~ '~ r NONE t/ _ r„ 4 G't~ ~~~ "s t Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE ~ ~•/6-,b~ MAR ~ 2007 ~3 ,~~~j (f ~~ +• 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD3-307 K-1 11518' 6640' Kuparuk C 11735' 6735' Nechelik 12813' 7032' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name Chip Alvord Title: Alpine Area Drilling Team Leader Signature Phone ~~ , ~ ~Z~ Date ~ ~~~ Z-° °? INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). . Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple comp-etion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~~ Time Logs - -- _ _ - - - _ _ -- _ _ --- Date From To Dur____ S Depth E. De nth Pha_s_e Code Subcode T COM 04/15/2006 00:00 12:00 12.00 1,739 2,879 COND1 DRILL DDRL P Drill from 1,739' to 2,879' MD 2373' TVD PUW 135k SOW 120k RotWt 130 650 gpm / 2400 psi 150 rpm Torque on/off btm 9500/7500 fUlbs ADT- 7.38 hrs ART 5.85 hrs AST 1.53 hrs 12:00 13:45 1.75 2,879 3,103 COND1 DRILL DDRL P Drill from 2,879' to 3103' MD 2485' TVD PUW 135k SOW 123k RotWt 130 650 gpm / 2500 psi / 50 rpm Torque on/off btm 10000/7000 ft/Ibs ADT 1.72 hrs ART 1.1 hrs AST 0.62 hrs. 13:45 16:00 2.25 3,103 3,069 COND1 DRILL CIRC P Circ 2 x BU - 650 gpm / 2400 psi / 70 rpm -set back one stand to 3069' - flow check well -observed intermittent rollling in annulus - no flow observed - circand condition mud -increase mud wt. from 10.0 to 10.2 16:00 19:45 3.75 3,069 886 SURFA DRILL WPRT P Monitor well, static for 10 min. -Wipe hole from 3069' to 886'. Backreamed with 50 RPM and 550 GPM. 19:45 21:00 1.25 886 3,103 SURFA DRILL WPRT P Checked for flow. Blew down Top drive and RIH from 886' to 3,103'. 21:00 22:30 1.50 3,103 2,879 SURFA DRILL CIRC P Circulated and conditioned mud to run casin . 22:30 23:00 0.50 2,879 3,103 SURFA DRILL TRIP P Blew down Top Drive. Flow checked well. POOH on TT 1 stand gained 1/2 Bbl. RIH to 3103'. 23:00 00:00 1.00 3,103 3,103 SURFA DRILL CIRC P CBU to check BU. Nothing observed. Flow check well dead. 04/16/2006 00:00 04:30 4.50 3,103 167 COND1 DRILL TRIP P Flow check well, static - POOH w/ pump from 3,069' to 2,594' -attempt to pull without pump -swabbing -POOH with pump from 2,594' to 1,168' - 3.5 bpm / 430 psi -hole taking proper fill - flow checked well 610' static. 04:30 07:00 2.50 167 0 COND1 DRILL PULD P Lay down jars, DC's, UBHO -down load MWD -pull pulsor -lay down TM - HCIM -DM -stab - FS -motor and bit - clear tools from ri floor 07:00 08:45 1.75 0 0 COND1 CASINC RURD P RU to run 9 5/8" casing 08:45 09:00 0.25 0 0 COND1 CASINC SFTY P Held Pre-job safety and Opts meeting with crew. 09:00 11:45 2.75 0 1,552 COND1 CASIN RNCS P Run 9 5/8" 40# BTC csg as follows: FS(Silver bullet) 2 jts. csg - FC (Weatherford) 2 jts. csg (fill pipe & check floats -first 4 connections made up w/ BakerLoc) 36 jts. csg. for 40 total to 1,552' 11:45 12:15 0.50 1,552 1,552 COND1 CASINC CIRC P Establish Circ at 3.8 bpm / 210 psi - staged pumps up to 6 bpm and CBU - FCP =290 psi -PUW 130K SOW 124K ~ _ F~~ ~~ ~ ~,,t ~ ~ _ a :~ C~ Time Logs _ Date From To Dur S Depth E bepth_~hase Gode Subcode T COM 04/16/2006 12:15 14:30 2.25 1,552 3,093 COND1 CASINC RNCS P Continue running 9 5/8" 40# BTC csg. f/ 1,552' to 3,053'. Total jts. run 79 - MU FMC fluted hanger and LJ - Landed casing w/shoe @ 3,093' & FC 3,014' 14:30 15:00 0.50 3,093 3,093 COND1 CASINC RURD P Lay don fill-up tool -blow down top drive - MU cement head 15:00 16:45 1.75 3,093 3,093 COND1 CEME~ CIRC P Establish circ with 2 bpm / 250 psi - staged pumps up 7 bpm -circulate and condition mud for cementing - FCP 280 psi Held PJSM with Dowell and ri crew 16:45 19:00 2.25 3,093 0 SURFA CEME DISP P Cement 9 5/8" casing as follows: Pumped 40 bbls. biozan water w/nut plug - 6 bpm @ 250 psi w/ rig pump - Switch to Dowell -Pumped 3 bbls water -test cement lines to 3000 psi - Dropped btm plug -Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.7 bpm @ 320 psi - Mixed & pumped 305 bbls of lead slurry CASE "G" w/ 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1% D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.4 bpm @ 220 psi -switched to tail slurry 48 Bbls "G" w! 0.2% D46, 0.3% D65, 2% S001) @ 15.8 ppg - 5.6 bpm @ 205 psi Dropped top plug & pumped 20 bbls water w/ Dowell -Switch to rig pumps - Displaced w/ 10.1 ppg mud @ 7 bpm 340 to 560 psi for first 205 bbls - slowed to 4 bpm @ 460 psi for last 4 bbls. -Bumped plug t/ 1150 psi - CIP @ 1857 hrs, floats helds. Full returns during job w/ 88.3 bbls cement returns to surface - recripcated pipe until 305 Bbls of lead slurry away, landed hanger on landing rin . 19:00 20:00 1.00 0 0 SURFA CASINC DHEO P Rigged up and tested casing to 2,500 si for 1/2 hour. 20:00 21:00 1.00 0 0 SURFA CASINC RURD P Rigged down cement head, bales, casin sli sand evelators. 21:00 22:45 1.75 0 0 SURFA CASINC NUND P Nippled down flowline and riser. 22:45 00:00 1.25 0 0 SURFA CASINC NUND P Installed Speed head and tested seals. Ni le u BOP. 04/17/2006 00:00 01:15 1.25 0 0 SURFA WELCT NUND P Land and NU BOP stack -install bell ni le, flowline and turn buckles ~..e ~ .._.~ ~ ~_~~ ~ ~ ~ ~~~~~ ~ -;f ~~ \ J i Time Logs Date - From - - To Dur - S. De th__ E De th Phase Code Subcod_e T - - COM _ 04/17/2006 _ 01:15 _ 06:30 5.25 0 _ 0 SURFA WELCT _ BOPE P Set test plug and test BOPE: Hydril to 250 & 3500 psi - Pipe rams, Choke manifold, choke & kill line vlaves, Pipe rams,blind rams, choke manifold valves, floor safety & dart valves 250 & 5000 psi Performed accumulator closure test -John Spaulding (AOGCC) waived witnessing tests - Pull test plug and install wear bushin - blow down lines 06:30 07:00 0.50 0 0 SURFA DRILL PULD P Install drilling bails and 5"elevators - s of Geo-S an skid on ri floor 07:00 10:45 3.75 0 0 SURFA DRILL PULD P RIH -Pick up 84 joints of drill -POOH stand back i e 10:45 13:45 3.00 0 1,035 SURFA DRILL PULD P RIH -Pick up 84 joints of drill -POOH stand back 11 stands 13:45 15:30 1.75 1,035 0 SURFA RIGMN RGRP T Repair air line on Top Drive grabber s stem 15:30 20:00 4.50 0 0 SURFA DRILL PULD P Picked up and stood back 5" DP. 20:00 00:00 4.00 0 106 SURFA DRILL PULD P Picked up and made up BHA. Loaded Nukes. Pulse tested MWD. 04/18/2006 00:00 01:00 1.00 106 740 COND1 DRILL PULD P Finsh MU BHA #2. Test Geospan unit to 3000 psi. PJSM. Install sources. RIH w/ BHA to 740'. 01:00 03:15 2.25 740 2,843 COND1 DRILL PULD P PU and RIH w/ 66 jts 5" DP to 2843'. 03:15 04:45 1.50 2,843 2,843 COND1 RIGMN SVRG P PJSM. Slip and cut drilling line. Service to drive. 04:45 05:15 0.50 2,843 2,990 COND1 DRILL OTHR P Wash from 2843' to TOC at 2990'. 05:15 08:45 3.50 2,990 3,123 SURFA CEMEt~ COCF P Drill out cement, float equipment and 20' new formation to 3123'. 08:45 09:15 0.50 3,123 3,123 SURFA CEME~ CIRC P Circulate and condition mud for FIT. 09:15 10:00 0.75 3,123 3,123 SURFA CEME~ FIT P Performed 18 ppg FIT. 10:00 12:00 2.00 3,123 3,319 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 3123'to 3319' MD 2591' TVD ADT - 1.36 hrs WOB 5/10 k RPM 100 /120 GPM 550 @ 1230 psi String wt. PU 150 SO 115 Rot 130 Torque on/off btm. - 9500/9000 ft. Ibs ECD-10.3/10.9 12:00 00:00 12.00 3,319 4,745 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 3319' to 4745' MD 3327' TVD ADT - 8.26 hrs WOB 5/14 k RPM 100 /120 GPM 600 @ 1900 psi String wt. PU 160 SO 125 Rot 135 Torque on/off btm. - 11000/8000 ft. lbs. ECD-10.8/11.2 i ~ ~ ®®~ r a~~ ~ e~f ~ ~~ Time Logs Date From To ur D S. De th E. De th Phase Code Subcode 7 COM _ 04/19/2006 00:00 12:00 _ 12.00 4,745 6,200 INTRM1 DRILL DDRL P _____ Drill 8 3/4" hole w/ GP f/ 4745' to 6200' MD 4031' TVD ADT - 7.35 hrs WOB 8/15 k RPM 150 GPM 650 @ 2280 psi String wt. PU 180 SO 130 Rot 155 Torque on/off btm. -12000/11500 ft. lbs. ECD-10.9/11.2 12:00 00:00 12.00 6,200 7,840 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 6200' to 7840' MD 4814' TVD ADT - 7.8 hrs WOB 8/18 k RPM 150 GPM 650 @ 2500 psi String wt. PU 198 SO 135 Rot 162 Torque on/off btm. - 14000/12000 ft. lbs. ECD-11 /11.2 04/20/2006 00:00 12:00 12.00 7,840 9,314 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 7840' to 9314' MD 5528' TVD ADT - 7.35 hrs WOB 15/23 k RPM 150 GPM 650 @ 2530 psi String wt. PU 215 SO 150 Rot 183 Torque on/off btm. - 16500/16000 ft. lbs. ECD-11/11.2 12:00 00:00 12.00 9,314 10,742 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 9314' to 10742' MD 6257' TVD ADT - 8.93 hrs WOB 15/23 k RPM 150 GPM 650 @ 2520 psi String wt. PU 280 SO 150 Rot 195 Torque on/off btm. - 20000/19000 ft. lbs. ECD-11/11.2 04/21/2006 00:00 11:30 11.50 10,742 11,694 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 10,742' to 11,694' MD 6718' TVD ADT - 8.08 hrs WOB 18/26 k RPM 150/80 GPM 650/473 @ 2520/1580 psi String wt. PU 250 SO 165 Rot 205 Torque on/off btm. - 19,000!18,500 ft. lbs. ECD-10.6/11.1 11:30 12:00 0.50 11,694 11,694 INTRM1 RIGMN SVRG P Service rig. 12:00 00:00 12.00 11,694 12,530 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 11,694' to 12,530' MD 6987' TVD ADT - 9.58 hrs WOB 20/26 k RPM 80 GPM 473 @ 1690 psi String wt. PU 265 SO 165 Rot 207 Torque on/off btm. - 20,000/17,500 ft. lbs. ECD-10.4/11 .~ _~~ e ~ m ~~c~~ ~ of Time Logs Date From To Dur S Depth E [7~t_h__Ph_ase__ Code Subcode_T_ COM - - _ _ _ _ - 04/24/2006 02:30 03:45 1.25 7,037 7,037 INTRM1 CASIN( CIRC P CBU. Stage pumps up to 5 bpm at 410 si. 03:45 07:30 3.75 7,037 10,887 INTRM1 CASIN RNCS P RIH w/ 7" csg from 7037' to 10,887'. 07:30 09:30 2.00 10,887 10,887 INTRM1 CASINC CIRC P CBU. Stage pumps up to 4.5 bpm at 450 si. 09:30 12:30 3.00 10,887 13,020 INTRM1 CASINC RNCS P RIH w/ 7" csg from 10,887' to 12,980'. MU hanger and landing jt. Land csg at 13,020'. 12:30 13:00 0.50 13,020 13,020 INTRM1 CASIN( RURD P RD Franks fill up tool. Install cement head. 13:00 15:30 2.50 13,020 13,020 INTRM1 CEME~ CIRC P Circ and condition mud. Stage pump from 2/4.5 b mat 15:30 18:00 2.50 13,020 0 INTRM1 CEME~ DISP P Cement 7" casing as follows: Pumped 5 bbls CW-100 -Test lines to 3600 psi -Pumped 20 bbls CW-100 -Mixed & pumped 30 bbls 10.5 ppg MudPush @ 5.2 BPM @ 530 psi - Dropped btm plug -Mixed & pumped 70 bbls (340 sxs Class G w/additives) @ 15.8 ppg tail slurry @ 5.2 BPM @ 500 psi - Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced cmt w/ 475 bbls 9.6 ppg Brine @ 7 BPM -Slowed pumps to 3.5 BPM for last 9 bbls of dispalcement -Bumped plug w/ 1080 psi (pre bump pressure 550 psi) CIP @ 1741 hrs. -Check floats (held OK) Full circulation throw hout'ob. 18:00 19:00 1.00 0 0 INTRM1 CASINC DHEQ P Rigged up and tested casing to 3500 si for 30 minutes. OK. 19:00 19:30 0.50 0 0 INTRM1 CASINC RURD P Laid down landing and cement head. 19:30 20:30 1.00 0 0 INTRM1 CASINC DHEQ P Ran and tested packoff. Laid down landin ~t . 20:30 22:30 2.00 0 0 INTRM1 WELCT BOPE P Changed 7" rams to VBR and tested rams. 22:30 00:00 1.50 0 118 INTRM1 RPCOh RCST P PJSM. Picked up TCP guns a ran com letion to 118'. 04/25!2006 00:00 09:00 9.00 118 9,492 INTRM1 RPCOh RCST P Continue RIH w/ 3 1/2" completion equipment from118' to 9492'. Total of 304 'ts. 09:00 10:00 1.00 9,492 9,492 INTRM1 RPCOh PULD P MU Camco SSSV. Attach control line and test to 5000 si. 10:00 12:30 2.50 9,492 10,769 INTRM1 RPCO RCST P RIH w/ 40 jts 3 1/2" tbg to 10,769' attaching control line bands. Lost ressure on control line. 12:30 15:30 3.00 10,769 9,529 INTRM1 RPCOb RCST T PJSM. RU and POH with 40 jts 3 1/2" tbg to 9529'. Located hole in control line 3 'ts above SSSV. 15:30 17:00 1.50 9,529 9,529 INTRM1 RPCOh OTHR T PJSM. Change out control spools. Test line to 5000 si. Function valve. 17:00 18:30 1.50 9,529 10,769 INTRM1 RPCOb RCST T RIH w/ 3 1/2" tbg from derrick from 9529' to 10,769'. ~. _~e_ ~ €~age ? cif 3 I ~~ Time Logs _ Date From To Dur 5 De th E. De th Phase Code Subcode T COM -_ _ _ _ _-- 04/25/2006 18:30 20:00 1.50 10, 769 11,606 INTRM1 RPCOh RCST P RIH w/ 3 1/2" tbg from pipe shed from 10,769'to 11,606'. Attach 1 control line band er't. 20:00 20:30 0.50 11,606 11,606 INTRM1 RPCOR RURD P RD tbg equipment. Clear floor for wire line. 20:30 20:45 0.25 11,606 11,606 INTRM1 EVAL1/1~ SFTY P PJSM on run WL log. 20:45 23:00 2.25 11,606 11,606 INTRM1 EVALVb ELOG P RU and RIH w/ 1 11/16" GR tool. Run correlation log from 11,400' to 10,800'. POH. RD WL. 23:00 00:00 1.00 11,606 11,727 INTRM1 RPCOh RCST P RU tbg equipment. RIH w/ 1 jt 3 1/2" tb , xo, 2' u and 2 'ts of 4 1/2" tb . 04/26/2006 00:00 01:00 1.00 11,762 11,800 INTRM1 RPCO RCST P MU FMC tbg hanger -Attach control line through hanger & test connections to 5000 psi -Land completion string w/ tbg tail @ 11,799.85' - pert guns f/ 11,799.85' to 11,742.42' - XN @ 11,678.70' -packer @ 11,631.83' - RA tag @ 11,561.02' -X nipple @ 11,559.91' -GLM @ 11,482.09' -GLM 6931.85' - SSSV 2249.19' 01:00 01:45 0.75 11,800 11,800 INTRM1 RPCO DHEQ P RI lock downs -Install TWC - LD landing jt A - MU landing jt. B -Test tbg hanger seals to 5000 psi - LD landin ~t B 01:45 02:15 0.50 11,800 11,800 INTRM1 RPCO OTHR P LD tbg running equipment & clean up ri floor 02:15 03:45 1.50 11,800 11,800 INTRM1 RPCO NUND P ND -flow line -bell nipple -BOP stack 03:45 05:00 1.25 11,780 11,800 INTRM1 RPCOh OTHR P Termiate control line through wellhead & test line 05:00 07:00 2.00 11,800 11,800 INTRM1 RPCOh NUND P NU tree & test to 5000 psi - RU & test FMC lubricator & test to 5000 si 07:00 07:30 0.50 11,800 11,800 INTRM1 RPCOh OTHR P Pull TWC & LD lubricator 07:30 10:45 3.25 11,800 11,800 INTRM1 RPCOh CIRC P RU hard lines to wellhead & squeeze maniflod on floor for displacement - Held PJSM -Pumped 5 bbls water - testlines to 200 psi -pumped 235 bbl 9.4 ppg inhibited brine followed by 143 bbls diesel 10:45 14:00 3.25 11 „800 11,800 INTRM1 RPCOti PACK P RU lubricator & drop packer setting rod/ball assembly -Retest lines to 5000 psi -Pressure up tbg to 4900 psi to set packer & test tbg for 30 mins.- bleed off tbg to 600 psi -Pressure up on annulus to 3500 pis & test for 30 mins. -bleed off annulus & tbg to 0 psi -shut in well -blow down lines & RD lines & s ueeze manifold 14:00 14:30 0.50 11,800 11,800 INTRM1 RPCOh OTHR P Remove outside annulus valves - Secure well 14:30 16:30 2.00 11,800 11,800 INTRM1 RPCOh OTHR P PJSM -Install mouse hole - LD 5"drill i e f/derrick via mouse hole 16:30 17:00 0.50 11,800 11,800 INTRM1 RIGMN SVRG P Rig service 1 ~~ ConocoPhiips Time Log Summary WeJ7view Web Re-PO~ttng Well Name: CD3-107 Job Type: DRILLING RE-ENTRY - - _ -- - --_ -- Time Logs j Date From To Dur S. De th E Depth Phase Code Subcode T COM _ _ __ 01/07/2007 00:00 11:00 11.00 MIRU MOVE DMOB P Pere rig for move - Air up tires -Run through per move check list -cover choke manifold -shovel snow off sub base -Prep pumps & pits -Finish welding in pit #3 - repair teflon on rig floor skid rails -Blow down water lines -disconnect high line power -Move ball mill awa from ri 11:00 00:00 13.00 MIRU MOVE MOB P Move rig camp -sewer plant & truck shop f/CD4 - 214 to CD3-107 -Spot & set u cam -sewer lant & sho 01/08/2007 00:00 00:00 24.00 MIRU MOVE MOB P Continue rig move with Sub and Pit com lex from CD4-CD3. 01/09/2007 00:00 00:00 24.00 MIRU MOVE MOB P Continue moving f/CD4 to CD3 - Moved pump/pit complex to CD3 - Moving Sub & ball mill to CD3 -Rig broke through ice road just off CD2 access road -Replace hydralic motor (No spill) made ice road by-pass around problem area (as per ice road engineer)- Continue moving w/sub & ball mill to CD3 -Sub base broke through ice road 1.5 miles f/ Tamayayak channel crossing - Double matted bad spot - as per ice road en ineer 01/10/2007 00:00 12:00 12.00 MIRU MOVE MOB P Finish moving sub base & ball mill to location 12:00 21:30 9.50 MIRU MOVE RURD P Spot rig -skid floor -spot pits & motors complexes -Hook up service lines Rig on high line power @ 1945 hrs - Accept rig @ 2000 hrs. S of ball mill & i e shed 21:30 22:30 1.00 INTRM1 DRILL OTHR P PU FMC lubricator -test to 1500 psi - Pull BPV - RD 22:30 00:00 1.50 COMPZ RPCO OTHR P PU to kill well 01/11/2007 00:00 01:30 1.50 0 0 COMPZ RPCO NUND P RU surface lines and manifold for well kill o erations 01:30 01:45 0.25 0 0 COMPZ RPCOh SFTY P Held PJSM with crew on well kill rocedures 01:45 03:15 1.50 0 0 COMPZ RPCO CIRC P Displace tubing with 100 bbls of 9.2 ppg brine taking returns through choke to an open top tank - shut in well and check pressures -Tubing 0 -casing 640 si -_ ~® _ _ _ F~~~ 1 ~f 9 r~ _Time Logs _ _ Date From To Dur S Depth E. Depth Phase Code Subcode T COM _ _ _ _____ 01/11/2007 _ 03:15 08:30 _ 5.25 0 0 COMPZ RPCO CIRC P _ Continue to kill well -Pumping 9.2 ppg brine down tubing @ 1.5 bpm ! 200 psi taking returns through choke to outside open top tank -total displacement 430 bbls pumped. Shut in well 08:30 10:00 1.50 0 0 COMPZ RPCOh OWFF P Monitor well 30 minutes- tubing 0 psi - casing pressure 50 psi -rig up to take returns back to rig mud tanks - increased brine wt. in its to 9.4 10:00 13:00 3.00 0 0 COMPZ RPCOh CIRC P Continue circulating through full open choke taking returns to pits - 3.0 bpm / 450 psi -increased brine wt. while circulating to 9.4 ppg -total volume um ed 420 bbls 13:00 14:00 1.00 0 0 COMPZ RPCOh NUND P Shut down and monitor returns -well static - RD circulating hoses and manifold. Hook up to annulus to monitor well on TT -Hole taking 4 bbls/hr 14:00 14:15 0.25 0 0 COMPZ RPCOh OTHR P PJSM with Schlumberger E-line crew 14:15 00:00 9.75 0 0 COMPZ RPCOb OTHR P RU Schlumberger - RIH w/Chemical cutter & CCL - Corrilate to get on depth -Shot chemical cutter @ 11,635.81' -Work tool loose & POOH 01/12/2007 00:00 02:30 2.50 0 0 COMPZ RPCO OTHR P POOH with Sclumberger E-line tools - PJSM on laying down tools -Lay down wireline tool string - RD Schlumber er 02:30 03:30 1.00 0 0 COMPZ RPCO NUND P Install BPV - ND tree -install blanking lu into han er 03:30 06:15 2.75 0 0 COMPZ WELCT NUND P NU BOPE -Fill stack with water and check for leaks 06:15 10:00 3.75 0 0 COMPZ WELCT BOPE P Test Blind rams 250/ 5000 psi -install test joint onto blanking plug -test Annular Preventor 250/ 3500 psi attempt to test top pipe rams - observed leak on stack 10:00 12:00 2.00 0 0 COMPZ WELC EQRP T Tighten bolts on mud cross /top pipe rams flan e 12:00 14:00 2.00 0 0 COMPZ WELCT EQRP T Continue to test ROPE -high pressure tests had slight bleed of with several equipment configurations - no surface leaks observed -replaced sending unit for chart recorder and purge lines with new fluid - no improvement -suspect blanking plug assembly leaking - tested lower pipe rams 250 / 3500 psi, ok. Contacted Team Leader and recieved dispensation to test remaining stack componets to 3500 si. _~ ~°~°~ _ ~ 3~~r~e 2 ~f ~ 1.. J Time Logs Date From To Dur S. De th_E. De th Phase Code Subco_d_e___ T __ COM 01/12/2007 14:00 00:00 10.00 0 COMPZ WELCT BOPE P Test top and bottom pipe rams, choke and kill HCR and manual valves 250/3500 psi -Perform Accumulator test Changed check valve, 1"ball valve & discharge hose on test pump - Finish testing choke manifold, floor safety valves and top drive ibop to 250/5000 s 01/13/2007 00:00 01:00 1.00 0 0 COMPZ WELCT BOPE P Test floor safety valves and top drive ibo valve - 250/5000 si 01:00 02:00 1.00 0 0 COMPZ RPCOh OTHR P Attempt to pull BPV, unable to engage valve - RU and circulate to flush out runnin threads -Pull BPV 02:00 04:30 2.50 0 0 COMPZ RPCO OTHR P Engage hanger with LJa -BOLDS - Attempt to pull Completion string - worked pipe numerous times to 205K (55K over PUW) - no good -land hanger and run in 4 LDS -laid down landin ~oint 04:30 06:00 1.50 0 0 COMPZ RPCOti PULD P Move tubing tongs ,slips and elevators to rig floor -monitor well - 4.5 b h loss 06:00 08:00 2.00 0 0 COMPZ RPCO OTHR T MU LJa -BOLDS -work string to 235K (85k over string wt.) -made numerous attempts with 230-235K, no good -land hanger and RILDS (4) - LD LJa 08:00 11:30 3.50 0 0 COMPZ RPCOh OTHR P RU and pick up 4" drill pipe -stood back 60 'ts. in derrick 11:30 13:00 1.50 0 0 COMPZ RPCOh OTHR T MU LJa in hanger - LD top xo - BOLDS -pull string up to 160K (10K over PUW) set slips in table - LD pup joint off of LDa - MU xo's for Schumberger pressure control e ui ment - 13:00 13:15 0.25 0 0 COMPZ RPCOh OTHR T PJSM with Schlumberger on running chemical cutter o ts. 13:15 15:45 2.50 COMPZ RPCOh OTHR T RU Schlumber E-line equipment - MU tools .15:45 20:45 5.00 COMPZ RPCOti OTHR T RIH w/ chemical cutter -correlate & fire cutter @ 11,636' -POOH w/ tools cutter fired 20:45 21:30 0.75 COMPZ RPCOh OTHR T RD Schlumberger 21:30 22:45 1.25 COMPZ RPCOh OTHR T Attempt to pull completion string - work string up to 236 k (80 k over strip wt. unable to ull strip 22:45 00:00 1.25 COMPZ RPCO OTHR T RU Schlumberger to run jet cutter to cut string in pup jt. above packer Note- Lost 366 bbls brine to hole to date 01/14/2007 00:00 00:15 0.25 0 0 COMPZ RPCO OTHR T PJSM with Schlumberger E-line crew .~~~~ a _ __ ~~u~ 3 ~f ~ r. Time Logs Date From To D_ur S De th E. De th Phase Code Suhcode T COM 01/14/2007 00:15 04:45 4.50 0 0 COMPZ RPCOh OTHR T RU Schlumberger - RIH with jet cutter - shoot 3 1/2" tubing @ 11,626' (5.8' above top of packer) - POOH w/ wireline - RD Schlumber er 04:45 07:30 2.75 0 0 COMPZ RPCOb CIRC P MU top drive to landing joint - PU and confirm pipe is cut -Circulate well @ 4 bpm / 400 psi -observed 2% flow increase with 410 bbls pumped (surface /surface volume) observed well -annulus boiling -shut annular preventor and monitor pressure 10 minutes - DP - 20 psi on gauge / casing pressure 0 -circulated well through full open choke for 40 bbls - 3 bpm / 320 psi -shut down and observe well, well static -Break out and blow down top drive (Rigged up to lay down tubin while circulatn 07:30 18:00 10.50 11,626 0 COMPZ RPCOti PULD P PJSM -Pull and LD hanger and LJ - POOH with 3 1/2" completion equipment (stand back tubing in derrick) -spool SSSV control line -cut bands off tubing -Lay down SSSV -all bands and saddles present (75) - Continue to POOH standing back tubing (total of 360 joints in derrick) laid down remainder of completion string to pup jt cut -off (3.82') f/ top of acker - To of fish 11,626.59' 18:00 18:45 0.75 0 COMPZ RPCOh OTHR P LD 3 1/2" handling equipment 18:45 20:30 1.75 COMPZ WELCT BOPE P Test top pipe rams to 250 & 5000 psi w/ 4" test jt.- unable to get test on bottom i e rams 20:30 22:30 2.00 COMPZ WELCT OTHR T Prep to change btm pipe rams - LD test plug - attempt to set tbg hanger - Unable to get tbg hanger down - LD tbg hanger -Install test plug checked out test pump While working with hanger & found bad sensor - re laced sensor 22:30 23:30 1.00 COMPZ WELCT BOPE P Tested lower pipe rams to 250 & 5000 psi - RU test equipment -Install wear bushin 23:30 00:00 0.50 COMPZ RPCO OTHR P Clear floor & bring milling assembly tools to ri floor 01/15/2007 00:00 00:45 0.75 0 0 COMPZ RPCOh OTHR T Move BHA componets onto rig floor 00:45 03:15 2.50 0 683 COMPZ RPCOti PACK T MU packer milling assembly #1 - Packer mill, (2) 4 3/4" Boot Baskets, bit sub, Pump-out sub, bumper sub, oil jar, (8) 4 3/4" DC's, Intensifier, xo, 13 'ts 4" hwd ® ~ _ se____~ _~aq~ ~ cif ~ i Time Logs Dat_z _____ From To Dur S. Dew, th E, Dgpth Phase Code Subcode T COM - -- --- -- 01/15/2007 03:15 14:15 11.00 683 11,574 COMPZ RPCO TRIP T RIH with Milling assembly picking up 4"drill pipe from shed (345 jts total) - Circulate down -tag top of fish @ 11,574' drill i e measurements 14:15 23:00 8.75 11,574 11,579 COMPZ RPCOh OTHR T Mill f/ 11,574'to 11,579' WOM 3 / 20 RPM 60/80 GPM 252 @ 1560 psi String wt. PU 210 SO 150 Rot 175 Torque 11,500 ft/Ibs Pump pressure increasing f/ 11,574' to 11,577' f/ 1560 psi to 1920 psi Work mill unable to mill beyond 11,579' -Hole packing off -unable to work pipe back to 11,579' several times -when back on btm unable to make any progress due to hole packing off Tried various parameters & dry milling - Pumped several hi vis sweeps - No metal cuttings to surface Hole still taking fluid -total losses to date - 692 bbls 23:00 00:00 1.00 11,579 11,579 COMPZ RPCOb CIRC T Mix & pump hi vis sweep 01!16/2007 00:00 01:00 1.00 11,579 11,579 COMPZ RPCOh CIRC T Circulate high vis sweep around @ 6.5 bpm / 1600 psi 60 rpm w/ 12K torque - monitorwell 10 minutes, static 01:00 10:00 9.00 11,579 683 COMPZ RPCOh TRIP T POOH on trip tank from 11,579' to 683' - monitor well, static 10:00 12:00 2.00 683 0 COMPZ RPCO TRIP T POOH with hwdp and drill collars, break off mill assembly and lay down and empty boot baskets -found pieces of unidetifiable junk on packer mill guide and in boot baskets- determined drill pipe count off one joint long -adjust TOF depth 31.5' to 11,610.5' 12:00 13:00 1.00 0 0 COMPZ RPCOh OTHR T Service top drive and drawworks 13:00 14:30 1.50 0 0 COMPZ RPCOh WOOR T Work plan forward with Baker Oil tools, drilling engineers and other interested arties. 14:30 17:00 2.50 0 0 COMPZ RPCO OTHR P Pick up and stand back 4" drill pipe. 17:00 19:00 2.00 0 701 COMPZ FISH PULD T Picked up Reverse basket and wash over shoe BHA and RIH to 701'. 19:00 00:00 5.00 701 11,570 COMPZ FISH TRIP T RIH with BHA to 11,570'. 01/17/2007 00:00 01:30 1.50 11,570 11,611 COMPZ FISH WASH T Filled pipe and washed down to top of fish @ 11,611'. Dropped ball and worked reverse circulating junk basket wirh0-9BPM30RPMand5-15K weight on Mill Shoe. Torque was steady on bottom 12,000 to 13,000 Ft Lbs de endin on wei ht. 01:30 07:45 6.25 11,611 701 COMPZ FISH TRIP T POOH on trip tank from 11,611' to 701'. v.®A-m®.®~m®®.mw m _ ._ _e _~ ~~ ~ Pa~~ csf 9 CI Time Logs i-- - -- _ - ---- Date From To __ _Our __.S_Depth_ E,_Depth Phase_ ___Co1e Subcode T CO_M 01/17/2007 07:45 10:15 2.50 701 0 COMPZ FISH PULD T POOH with BHA and laid down junk baskets. Recovered mete) scale and debris. 10:15 12:00 1.75 0 701 COMPZ FISH PULD T Made up BHA with Mill Shoe and RIH to 701'. 12:00 16:15 4.25 701 11,611 COMPZ FISH TRIP T RIH and tagged fish @ 11,611'. 16:15 00:00 7.75 11,611 11,611 COMPZ FISH MILL T Milled on fish @ 11,611' with no progress. WOM 5 - 15 K. 50 RPM pumping 0 - 8 BPM. 1635 psi @ 8 BPM. Torque steady 12,000 to 13,500 Ft Lbs de endin on WOM.. 01/18/2007 00:00 04:00 4.00 11,611 11,611 COMPZ FISH MILL T Milling @ 11,611' - 4-8 bpm / 440-1780 psi / 50 rpm 10 K ft/Is off/ 13k fUlbs on btm 10-15 K wt. on mill -pumped 30 bbls nut plug sweep and 25 bb-s of high vis w/ fiber sweep -monitor well, static 04:00 09:00 5.00 11,611 701 COMPZ FISH TRIP T POOH from 11,611' to 701' -flow chech well, static 09:00 10:00 1.00 701 93 COMPZ FISH TRIP T stand back hwdp and DC's 10:00 11:00 1.00 93 65 COMPZ FISH PULD T Lay down mill, wash pipe extensions and boot basket -mill in near new condition -recovered Humerus small pieces ofjunk and small cutting chips -clear tools from floor 11:00 13:00 2.00 65 65 COMPZ RIGMN SVRG T Service Top Drive, Drawworks and Crown - ad~usted drawworks brakes 13:00 14:30 1.50 65 65 COMPZ RIGMN SVRG T Slip and cut drilling line 14:30 15:00 0.50 65 0 COMPZ FISH PULD T Lay down jars,bumper sub and (1) DC 15:00 16:15 1.25 0 0 COMPZ FISH SLKL T Spot up Halliburton slickline unit - PJSM - RU Halliburton 16:15 20:30 4.25 0 0 COMPZ FISH SLKL T RIH with 6" OD fishing magnet to 11,599' WLM. POOH and cleaned off magnet. Recovered about 1/2 to 2/3 of a cu consistin of slivers and chi s. 20:30 00:00 3.50 0 5,000 COMPZ FISH SLKL T RIH with 6" OD fishing magnet Run # 2 to 5,000' WLM. 01/19/2007 00:00 00:45 0.75 5,000 0 COMPZ FISH SLKL T RIH to 11,615' (wlm) work 6" magnet - POOHwith 6" magnet on slickline - cleaned magnet of 3/4" to 1"chips 1/3 cu full 00:45 03:00 2.25 0 0 COMPZ FISH SLKL T RIH with 5.5" LIB on slickline to 11,611' -POOH -partial IB stamp consistant with 3 1/2" tubin 03:00 04:30 1.50 0 0 COMPZ FISH SLKL T RIH with 1 3/4" bailer and 3.6" nogo to 11,613' -POOH with slickline - operator suggests that the bailor had entered the tubing stub ~ 30 inches to no o - RD slickline ~~ ~ ~~~ ~ ~t 9 ~ ~~ _ ~ ~~ i i Time Logs Date From To Dur S D e th E. De th Phase Code Subcode T COM ~ 01/19/2007 04:30 07:00 2.50 _ _ _ 0 678 COMPZ FISH PULD T Clear tools from rig floor - LD boot baskets - MU fishing asst' #4 -Spear, spear ext., xo-stop sub, pump-Out sub, Bumper sub, jars, (8) 4 3/4" DC's, Intensifier, Xo, 13 'ts 4" hwd 07:00 10:30 3.50 678 11,614 COMPZ FISH TRIP T RIH from 678' to 11,548' -establish circulation above fish 2.1 bpm / 790 psi -RIH -appeared to enter TOF @ 11,611' - took wt. 11,613.5' 10:30 13:30 3.00 11,614 11,614 COMPZ FISH JAR T Jar on fish -Free PUW 225K -jar with 300-320K pulling to 385K - no movement 13:30 14:00 0.50 11,614 11,548 COMPZ FISH OTHR T Attempt to release from fish -while working right hand torque into pipe to release grapple -observed pump pressure drop from 780 psi to 130 psi - pipe moved freely up - no recognised loss of PUW 14:00 14:15 0.25 11,548 11,548 COMPZ WELCT OWFF T Blow down top drive -monitor well, static 14:15 20:30 6.25 11,548 678 COMPZ FISH TRIP T POOH from 11,543' to 678'. 20:30 21:30 1.00 678 0 COMPZ FISH PULD T Laid down intensiferjar. Pulled BHA left Spear in hole. Laid down oil jar and bum er sub. 21:30 23:15 1.75 0 685 COMPZ FISH PULD T Picked up Packer mill and new BHA. RIH to 685'. 23:15 00:00 0.75 685 2,114 COMPZ FISH TRIP T RIH from 685' to 2,114'. 01!20/2007 00:00 03:30 3.50 2,114 11,555 COMPZ FISH TRIP T RIH w/ Packer milling assembly from 2114' to 11,555' -establish circulation 6 bpm / 1100 psi / 60 rpm @ 9K ft/Ibs PUW 212K SOW 150K RotWt. 150K 03:30 09:45 6.25 11,555 11,611 COMPZ FISH MILL T Locate TOF @ 11,611' -pump pressure spiking with guide inside fish and mill on top of fish -reduce pump rate to 1.2 bpm / 850 - 1500 psi -mill on fish -swept hole whith 20 bbls viscosified brine w/Super Sweep added -varied wt. on mill 10 - 20 K / 60 - 80 r m - no measurable ro ress 09:45 10:45 1.00 11,611 11,611 COMPZ FISH CIRC T Pumped 30 bbls viscosified brine with .25 ppb of Super Sweep -circulate sweep around 8.0 bpm / 1830 psi / 80 rpm - no mill cuttings observed with sweep back 225 bbls of 9.4 ppg brine lost to hole while millin and circulatin 10:45 11:00 0.25 11,611 11,555 COMPZ FISH OTHR T Monitor well, observed slight breathing -well static in 10 minutes -blow down to drive set back 1st stand 11:00 16:30 5.50 11,555 685 COMPZ FISH TRIP T POOH on trip tank from 11,555' to 685'. 16:30 17:30 1.00 685 0 COMPZ FISH PULD T Laid down packer mill and cleaned boot baskits. Recovered about 10 Lbs of metal cuttin s. • I Time Logs _ I Date From To Dur S. Depth E, De~th_P_hase Code Subcode T COM __ __ _ _ ___ 01/20/2007 17:30 19:00 1.50 0 662 COMPZ FISH PULD T Picked up Junk Mill and stabilizer BHA and RIH to 662'. 19:00 23:00 4.00 662 11,532 COMPZ FISH TRIP T RIH from 662' to 11,532'. 23:00 23:15 0.25 11,532 11,611 COMPZ FISH WASH T Washed to TOF @ 11,611'. 23:15 00:00 0.75 11,611 11,611 COMPZ FISH MILL T Milling on fish @ 11,611'. 8 BPM @ 1810 si. WOM 5/10 K. RPM 60. 01/21/2007 00:00 04:15 4.25 11,611 11,611 COMPZ FISH MILL T Milled on fish @ 11,611' without progress. 8 BPM 1830 psi. 60/80 RPM. 5/25 K WOM. 04:15 06:15 2.00 11,611 11,611 COMPZ FISH MILL T Blew down top drive and dry milled with 5/25 K WOM 60/80 RPM. 06:15 15:00 8.75 11,611 11,611 COMPZ FISH MILL T Milled on fish @ 11,611' without progress. 8 BPM 1830 psi. 60/80 RPM. 5/25 K WOM. 15:00 16:30 1.50 11,611 11,580 COMPZ FISH CIRC T Pumped sweep hi vis with super sweep. 8 BPM 1830 psi 80 RPM. Observed well and laid down sin le. 16:30 22:30 6.00 11,580 663 COMPZ FISH TRIP T Checked well and POOH on TT from 11,611' to 662'. 22:30 00:00 1.50 663 50 COMPZ FISH PULD T Laid down BHA. 01/22/2007 00:00 01:15 1.25 50 0 COMPZ FISH TRIP T Lay down BHA and Baker fishing tools - Mill showed wear pattern on outer 1/4" of face -Very slight recovery from boot basket. 01:15 07:15 6.00 0 11,541 COMPZ PLUG OTHR X MU baker K-1 cement retainer -RIH with retainer to 11,541' 07:15 09:30 2.25 11,541 11,534 COMPZ PLUG MPSP X Establish circulation -Made several passes from 11,541'to 11,530' pumping 3 bpm / 320 psi -Set retainer with Top @ 11,534' -Blow down top drive - Ru cement lines -test lines to 2500 psi -close pipe rams and test retainer to 1000 si for 10 minutes 09:30 10:00 0.50 11,534 11,534 COMPZ PLUG OTHR X Sting into retainer -establish Injection rates - 1.0 bpm - 1380 psi / 1.5 bpm - 1780 psi / 2.0 bpm 2140 psi -pumped a total of 20 bbls of brine 10:00 10:15 0.25 11,534 11,534 COMPZ PLUG SFTY X Pre job safety and opts meeting with Dowell and ri crew 10:15 11:15 1.00 11,534 11,524 COMPZ CEME~ SOEZ X Line up to Dowell -pumped 5 bbls of fresh water -test lines to 3000 psi - pumped 5 bbls fresh water -mix and pump 90 sxs of 15.8 ppg G cement (18.5 bbls) -displaced cement to stinger and stab into retainer - squeezed 14.5 bbls of cement below retainer -final rate 1.7 bpm @ 2500 psi -pick up 10' and displace remaining cement to equalization - RD cement lines - CIP @ 100 hrs - ETOC 11,434' ~ _ ~~m ~s ~_._~_~..___~~__._ ~'~~ k~ of 9 r1 .~ Time Lo~s Date _ _ From To _ __ Dur S. De th E. De th Phase Code Subcode T _ COM 01/22/200 7 1 11 5 12:15 1.00 11,524 __ 11,064 COMPZ CEME~ CIRC X Pull up 5 stands to 11,064' -circulate to clean drill pipe - 10 bpm / 2020 psi for 100 bbls -blow down cement and Kill lines 12:15 14:45 2.50 11,064 8,392 COMPZ CEME~ TRIP X POOH laying down 4" DP 84 Jts. from 11,064' to 8,392'. 14:45 17:45 3.00 8,392 0 COMPZ CEME~ TRIP X Continue POOH from 8,392' to 0' standing back in derrick. Laid down runnin tool. 17:45 19:00 1.25 0 0 COMPZ DRILL RURD X Cleared floor and rigged up to run tubin . 19:00 23:15 4.25 0 9,260 COMPZ DRILL TRIP X RIH with 99 stands of 3 1/2" tubing from derrick. 23:15 00:00 0.75 9,260 9,260 COMPZ DRILL RURD X Rig up to lay down tubing. 01/23/2007 00:00 07:30 7.50 9,260 3,500 COMPZ DRILL PULD X Changed out power tongs and continued to lay down 3.5" tubing from 9,260' to 3,500'. 07:30 09:00 1.50 3,500 3,500 COMPZ DRILL CIRC X PJSM. Circulated 9.2 PPG clean brine into hole. 09:00 13:00 4.00 3,500 0 COMPZ DRILL PULD X Continued laying down tubing from 3,500' to 0'. 13:00 14:15 1.25 0 0 COMPZ DRILL RURD X Pull Wear Ring. RU to RIH with 3-1/2" Tb . 14:15 15:15 1.00 0 1,963 COMPZ RPCOI~ RCST X RIH with 21 stands of 9.3# L-80 3-1/2" tbg, tbg hanger, and mule shoe to 2003' RKB. 15:15 16:15 1.00 0 0 COMPZ RPCO PULD X Land tubing and Install 2 way check. MU and install han er. 16:15 16:30 0.25 COMPZ RPCOh RURD X Test hanger seals to 5000 psi. LD Tbg e ui ment, clear ri floor. 16:30 19:30 3.00 COMPZ RPCOh NUND X ND BOPE. NU Tree and test to 5000 si. Pull 2 wa check. 19:30 21:00 1.50 COMPZ RPCOh CIRC X PJSM for Diesel displace. RU to pump down the tbg taking returns out the 3-1/2" x 7" annulus to the pits. Fluid pack lines and PT. Displace brine with a total of 65 BBLS diesel to freeze rotect tb and annulus to 1800'. 21:00 22:00 1.00 COMPZ RPCOM1 OTHR X Blow down lines. FMC set BPV using lubricator. RD displacement lines. Secure Well. Final Pressures T/I/O = 0/0/750 si. Pre Ri to Move. 22:00 00:00 2.00 COMPZ RPCOh OTHR X Rig released at 2359 hrs. e_- s ~~~ ~f ~~ ~~ ---_~ • ~onocv-Phillips Time Log Summary WefN72sv Web ReDo~'tiAg i Well Name: CD3-107 Job Type: DRILLING RE-ENTRY ------ Time Loc,~s ! Date Fror7i To Dur S De th E De th Fhase Code Subcode T COM 02/03/2007 18:00 20:15 2.25 MIRU MOVE DMOB P Prep Rig for move from CD3-113 20:15 20:30 0.25 MIRU MOVE SFTY P PJSM 20:30 00:00 3.50 MIRU MOVE MOB P Ball mill rear hydraulics shut down. Mechanic fixed -Moved Ball mill away from ri .Continue with ri move. 02/04/2007 00:00 04:00 4.00 MIRU MOVE MOB P Cont. Rig move -Moved Sub over CD3-107 -Spot pit & motor complexes - RU services lines -Spot ball mill & pipe shed ACCEPT ri 0400 hrs. 04:00 05:00 1.00 INTRM2 RPCOh OTHR P Prep tree scaffolding -install double valve to annulus -take on 9.6 ppg brine 05:00 06:15 1.25 INTRM2 RPCOh OTHR P Pull BPV - RU lines for displacment 06:15 07:00 0.75 INTRM2 RPCOh OTHR P Change elevators to 4" -move 4 stds 4" DP f/ off driller's side to driller's side - Chanh a elevators to 5" 07:00 08:00 1.00 INTRM2 RPCOti OTHR P RU choke & flare lines 08:00 08:30 0.50 INTRM2 RPCOti OTHR P Spot for displacment & RU line f/ annulus to tank 08:30 08:45 0.25 INTRM2 RPCOh SFTY P Held pre job meeting -displacing well 08:45 09:15 0.50 INTRM2 RPCOti CIRC P Test lines to 1000 psi -Displace freeze protect diesel w/ 9.6 ppg brine f/ 2003' 09:15 09:45 0.50 INTRM2 RPCOh OTHR P Blow down lines - RD lines 09:45 10:00 0.25 INTRM2 RPCOti OTHR P Set BPV 10:00 12:30 2.50 INTRM2 RPCOh OTHR P ND tree - NU BOPE 12:30 14:00 1.50 INTRM2 RPCOh OTHR P Cut drilling line 14:00 17:30 3.50 INTRM2 RPCOh OTHR P PU and SB 5" DP using the mousehole 17:30 18:00 0.50 INTRM2 RPCOh OTHR P Service the rig. 18:00 00:00 6.00 INTRM2 RPCOh OTHR P Cont PU & SB 5" DP. 02/05/2007 00:00 03:30 3.50 INTRM2 DRILL PULD P Finish picking up 5" DP 03:30 04:00 0.50 INTRM2 DRILL OTHR P Pull BPV _~_ ~ ~ _~_ ~~~ ~ oaf 1r ~ ~ l J l J Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 02/05/2007 04:00 04:45 0.75 INTRM2 DRILL OTHR P RU & test 7" csg to 3500 psi for 15 mins. 04:45 06:45 2.00 INTRM2 RPCOti OTHR P Clean top of hanger - MU landing jt. - Back out lock downs -Pull hanger to rig floor - LD landing jt. - LD hanger - chan a elevators to 3 1/2" 06:45 09:00 2.25 INTRM2 RPCOh OTHR P PJSM -Pull & std back 10 stds 3 1/2" tb - LD 33 ~ts tb kill strin f/ well 09:00 09:30 0.50 INTRM2 RPCOh OTHR P RU tongs & clear floor of tools & e ui ment 09:30 10:30 1.00 INTRM2 WELCT BOPE P MU 5" test jt -Fill stack & choke water - MU TIW & Dart valves 10:30 18:30 8.00 INTRM2 WELCT BOPE P Begin testing BOPE -Tested annulars to 250/3500 psi -Test Top Rams, choke valves, TIW 250/3000 psi -Test Btm rams, blinds, choke, 1-16 HCR & manual choke, Kill auto, and man IBOP dart, Upper rams w/ 4" to 250/4000 psi. Annular w/4" to 250/3500 psi. Blow down Spool and AI ine uni-head. 18:30 19:00 0.50 INTRM2 RPCOh OTHR P Install thin wall wear ring. 19:00 21:30 2.50 0 3,250 INTRM2 RPCOh OTHR P MU & RIH with Baker Bridge Plug (2.09') to setting depth of 3250'. Up Wt = 111#, Dwn Wt = 109#. 21:30 23:00 1.50 3,250 3,250 INTRM2 RPCOh CIRC P Establish circulation @ 4 bpm, 210 psi. Drop ball -work pressure up to 1600 si. Set BP 3250'. 23:00 00:00 1.00 3,250 3,240 INTRM2 RPCOh DHEQ P PU to 3240' and establish circulation - Wt up and displace well to 9.6 ppg brine. RU and test Bridge plug to 3500 si for 30 minutes. 02/06/2007 00:00 00:30 0.50 3,240 3,240 INTRM2 RPCOh OTHR P Finish testing bridge plug to 3500 psi for 30 mins. -Bleed off & blow down TD 00:30 01:30 1.00 3,240 0 INTRM2 RPCOh TRIP P POOH w/ setting tool & 4" DP PU wt 110 SO wt. 105 01:30 02:15 0.75 0 103 INTRM2 RPCO PULD P LD setting tool for bridge plug - MU casing cutter assembly - PU 1 std 4 3/4" DC 02:15 03:30 1.25 103 3,193 INTRM2 FISH TRIP P RIH w/ csg cutter & locate csg collar @3202'-Pull up to 3193'-Open 7'x 9 5/8" annulus - 800 psi -Bleed off ressure too en to tank 0 si 03:30 05:00 1.50 3,193 3,193 INTRM2 FISH CPBO P Cut 7" csg @ 3193' -String wt. PU 112 S0110-torque4k-4/5 bbls/min @ 620 psi Observed pressure drop -Checked ressure on 7' x 9 5/8" annulus 0 si 05:00 05:30 0.50 3,193 3,193 INTRM2 FISH CIRC P Close hydril -pressure up to 500 psi w/ no returns f/ 7" x 9 5/8" annulus 05:30 06:15 0.75 3,193 3,193 INTRM2 FISH CIRC P Open Hydril and attempt to circ btms up on 4" x 7" annulus -lost approx. 15 bbls -shut down & monitor well on TT -Observed sli ht flow ~ _m.m®~ ~. ~ ~_ ~ ~ ~<~~~~ ~ of 1~ ~.~. I, J l J Time Logs _ _ Date From To Dur S De th E. De th Ph se Code Subcode T COM 02/06/2007 06:15 06:30 0.25 3,193 3,026 INTRM2 FISH TRIP P Pull out f/ 3193' to 3026' 06:30 06:45 0.25 3,026 3,026 INTRM2 FISH OTHR P Locate csg collar @ 3036' -Pull up to 3026' to make 2nd cut in 7" csg - Checked 7" x 9 5/8" annulus - Observed 240 si 06:45 14:00 7.25 3,026 3,026 INTRM2 FISH CIRC P Open 7" x 9 5/8" annulus to open top tank -fluid to tank @ 140 psi - Observed fluid level dropping in 4" x 7" annulus -Closed Hydril &circ out diesel f/ 7" x 9 5/8" annulus w/ 9.6 ppg brine -Observed 9.6 ppg brine to tank -Shut down .pump - 7" x 9 5/8" annulus still flowing to tank -Open Hydril -fluid level dropping in 4" x 7" annulus -Closed 7" x 9 5/8" annulus to tank -Observed 140 psi -Monitor 4" x 7" annulus -Observed flow - Open 7" x 9 5/8" annulus to tank -close Hydril & begin circ btms up while getting LSND mud weighted up to 9.8 ppg to change well over to mud - w/ 62 bbls pumped -Shut down pump & check for flow to tank -Well flowing f/ 7" x 9 5/8" annulus -Brought pump back on & switched over to 9.8 ppg LSND mud to displace 7" x 9 5/8" annulus -Final rate 2 bpm / 190 psi on drill pipe -observed gas cut mud back too en to tank 14:00 15:30 1.50 3,026 3,026 INTRM2 FISH CIRC T RU lines to circulate 9 5/8" X 7" annulus taking returns through choke manifold to pits -Monitor well, annulus @ 40 psi -drill pipe 30 psi -circulate through choke @ 3 bpm / 600 psi circulate with 9.8 ppg mud - 190 psi back pressure through full open choke - full returns to its ~____ ~-_ ____-----_ ~ag~ ~ of 1~~ I • Time Logs __ -_. Date __ From_ To Dur S. De th E. De th Phase _._ Code Subcode T COM _ --- ---- 02/06/2007 15:30 20:00 4.50 3,026 _ 3,026 INTRM2 FISH OTHR T Shut down pumps and monitored returns from gasbuster -well flowing - shut in well. Blow down top drive installed 600 psi gauge on drill pipe and checked pressures - (30 minutes after shut in) SIDPP- 85 psi / SICP- 140 psi begin weighting up mud in pits - decided to displace inner annulus to mud before continuing with outer annulus kill -opened choke line on stack to check inner annulus pressure -SIDPP dropped to 50 psi - 9 5/8' x 7" annulus pressure dropped to 100 psi - Inner annulus pressure 40 psi - monitored we1130 minutes with no change in shut in pressures -bled off outer annulus in stages to 0 psi - SIDPPdropped to 1 psi - (1820 hrs)continue to monitor shut in pressures while increasing mud weight in pits -Shut in pressures increased to 50 psi on drill pipe and 100 psi on outer annulus in 30 minutes (1910 hrs) Shut in pressures stable for next 50 minutes while increasing mud weight in pits to 10.7 ppg -SIDPP - 50 psi / 9 5/8" x 7' annulus - 100 psi / 7" x 4" annulus - 40 si 20:00 22:00 2.00 3,026 3,026 INTRM2 FISH CIRC T Displace 9.6 ppg brine f/ 7" x 4" annulus to 10.6 ppg LSND mud - follow kill schedule - 2 bbls/min @ 3000 si FCP 22:00 00:00 2.00 3,026 3,026 INTRM2 FISH CIRC T Displaced 9 5/8" x 7" annulus f! 9.8 ppg to 10.6 ppg LSND mud -follow ki{I schedule - 2 bbls/min @ 390 psi FCP -Shut down pump -Blow down TD & kill & choke lines & choke manifold - Pre to monitor well 02/07/2007 00:00 06:00 6.00 3,026 3,026 INTRM2 WELC7 KLWL T Monitor well - SIDDP 15 psi - Inner annulus 0 -Outer annulus 0 -Monitor well for 45 mins - DP 40 psi Outer annulus 40 psi -Inner annulus 60 psi w/ 10.6 ppg mud -Well stablized for 1 hr. DP 35 psi Inner annulus 60 psi Outer annulus 40 psi -Bleed off DP, OA, & IA to 0 psi (No fluid f/ OA & DP -Some fluid f/ IA -Monitor well for 1 1/2 hrs. - No pressure on DP, OA, & IA for 30 mins. -pressure began to build final stablized pressure DP 15 psi OA 30 psi IA 40 psi -Bleed off pressures to 0 -Monitor well for 1 1/2 hrs.- No pressure for first 20 mins - Stablized pressure DP 0 psi OA 10 si IA 20 si 06:00 07:00 1.00 3,026 3,026 INTRM2 WELL KLWL T Finish weighting up mud in pits to 11.0 ppg - stablized pressure DP 0 psi OA 10 psi IA 20 si I~~C,ja^ .~ O~ 1~ J ~1 Time Los _ _ _ ~ -- - -- Date From To Dur S. De th E. De th Phase Code Subcod e T COM 02/07/2007 07:00 08:15 1.25 3,026 3,026 INTRM2 ___ WELC _ _ KLWL T Circ through choke -displace drill pipe and inner annulus to 11..0 ppg mud 2.5 bpm - 340 / 400 psi - no gas cut mud observed in returns -shut in inner annulus DP 20 psi IA 20 psi OA 90 si 08:15 10:00 1.75 3,026 3,026 INTRM2 WELCT KLWL T Line up to circulate OA through choke - Displaced OA to 11.0 ppg mud - 2.0 bpm - 380 psi - 130/100 psi back pressure with choke full open - observed 10.6 ppg mud gas cut to 9.0 ppg -continued to circulate until) mud wt. in and out at 10.8 ppg /balance scale and 11.0 ppg pressure scale - shut down pumps and monitored returns from gas buster -opened inner annulus to choke and monitor returns - opened annular preventor and monitor well, observed sli ht flow 10:00 11:00 1.00 3,026 3,026 INTRM2 WELCT OWFF T Installed jumper hose across upper and lower annuli -monitor well -well static -blow down top drive -monitor well 45 minutes static 11:00 15:00 4.00 3,026 0 INTRM2 FISH TRIP P POOH on trip tank -well taking proper fill, flow check well @ 2045', 1150', 197' all static. POOH lay down casing cutter assembly -observed good wear indications on knives 15:00 15:30 0.50 0 0 INTRM2 FISH PULD P Monitor well -static -move casing s ear assembl tools to ri floor 15:30 16:30 1.00 0 0 INTRM2 FISH OTHR P Pull thin wall wear bushing and casing ackoff from wellhead 16:30 19:30 3.00 0 0 INTRM2 WELCT BOPE P Change top pipe rams to 7" -Test rams 250/5000 psi -change test joint to 4" and test Annular Preventor 250/3500 psi -set thin wall wear bushin 19:30 20:30 1.00 0 35 INTRM2 FISH PULD P MU spear assembly - RIH & engage 7" casing -pull up to 170 k - no movement 20:30 22:00 1.50. 35 35 INTRM2 FISH CIRC P Establish Circ & circ btms up + pipe volume - 3 bbls/min @ 110 psi - Observed slight gas cut mud @ 10.8 ppg @ btms up -shut down w/ 11.1 ppg mud returns -Flow ckeck well static 22:00 22:30 0.50 35 0 INTRM2 FISH PULL P Pull on 7" casing -came free @ 220 k - Pull csg hanger to rig floor - Up wt. 140 k -Observed slight swabbing & then dro in fluid level 22:30 23:30 1.00 0 0 INTRM2 FISH CIRC P Flow check well (static) -Circ btms up -Observed no gas cut mud -release s ear 23:30 00:00 0.50 0 0 INTRM2 FISH PULD P LD spear assembly 02/08/2007 00:00 00:30 0.50 3,154 3,154 INTRM2 FISH RURD P Rig up to lay down 7" casing -Monitor well, static ~® ~® ~ ~ Pa~~e a ~;t ~1~ • Time Logs Date .From To Dur S. De tfi_ E_, Depth Phase Code Subcode T COM ______ _ 02/08/2007 00:30 08:00 7.50 3,154 0 INTRM2 FISH PULL P POOH -laid down 73 full joints and 1 cutoff joint (33.73') Hole took proper fill -flow check 595' -static. 08:00 08:30 0.50 0 0 INTRM2 FISH RURD P Rig down casing equipment -Monitor well, static 08:30 11:30 3.00 0 0 INTRM2 WELCT OTHR P PJSM -Change top pipe rams to 3 1/2" x 6" VBR's -Pull wear bushing and set test plug -Fill stack with water and test pipe rams to 250/5000 psi - RD test equipment -pull test plug and install Ion wear bushin 11:30 12:00 0.50 0 0 INTRM2 STK OTHR P Rig up to run 3 1/2" tubing 12:00 15:15 3.25 0 3,250 INTRM2 STK TRIP P RIH with 662' of 3 1/2" tubing - change running tools to 4" -RIH with 4"drill pipe from 662' ,tagged bridge lu 3250' 15:15 16:30 1.25 3,250 3,250 INTRM2 STK CIRC P Stage pumps up to 6.1 bpm / 250 psi - circulate and condition mud for cementing -bottoms up mud wt. 10.5 ppg balance scale - 11.0 ppg pressure scale PJSM 16:30 17:30 1.00 3,248 3,248 INTRM2 STK OTHR P Blow down top drive -Rig up cement lines -Plug back 7" casing / 8 3/4" open hole and 9158" casing from 3250' -Pumped 5 bbls of water ahead -test lines to 2500 psi -pumped 5 bbls of fresh water - 25 bbls of 11.2 ppg Mudpush - 146 sxs 17.0 ppg G cement (26 bbls) -displaced cement to equalization - ETOC @ 2893' - CIP 1720 hrs - Rd cement lines 17:30 18:00 0.50 3,248 2,758 INTRM2 STK TRIP P Laid pup jnt. -pull 5 stands of drill pipe to 2758' 18:00 19:30 1.50 2,758 2,758 INTRM2 STK CIRC P Circulate - 4 bpm / 100 psi 19:30 20:30 1.00 2,758 662 INTRM2 STK TRIP P POOH on TT f/ 2760' to 662' (top 3 1/2" cmt stin er -Flow ck Static 20:30 23:30 3.00 662 0 INTRM2 STK TRIP P PJSM - RIH w/ 3 sts 3 1/2" tbg f/ derrick -POOH & LD 30 jts 3 1/2" tbg - LD 1 std 4 3/4" DC's f/derrick 23:30 00:00 0.50 0 0 INTRM2 STK OTHR P Change TD saver sub f/ XT-39 to 4 1/2" IF 02/09/2007 00:00 00:30 0.50 0 0 INTRM2 STK OTHR P Change saver sub to 4 1/2" IF 00:30 02:00 1.50 0 0 INTRM2 STK OTHR P RD circulating equipment from wellhead -Change mud bucket rubbers and dies in iron roughneck to 5" clear tools from floor -move bha com onents to ri floor 02:00 04:30 2.50 0 80 INTRM2 STK PULD P PJSM - MU BHA #1 -Bit /motor / NMFS /IBS ! DM HON / PWD / TM HOC - lu in and initialize tools 04:30 05:00 0.50 80 250 INTRM2 STK TRIP P RIH to 250' and shallow test tools 05:00 07:00 2.00 250 2,710 INTRM2 STK TRIP P RIH from 250' to 2710' (SLM DP) __ I _ ~ _ I ~~~e 6 of'[3 ~ ~~~ • • Time Lois ~~ Date _ _ From To__ Our S. De th E. De th Phase _Code Subcode_ T COM 02/09/2007 07:00 08:15 1.25 2,710 2,995 INTRM2 STK CIRC P Wash and ream from 2710' to 2995' - 3 b m / 260 si 30 r m 08:15 10:15 2.00 2,995 2,995 INTRM2 STK CIRC P Circulate and condition mud - 8 bpm / 670 psi -observed lots of real soft cement at shakers 10:15 12:30 2.25 2,995 2,995 INTRM2 STK OTHR P WOC. -Monitor well, static 12:30 14:15 1.75 2,995 3,098 INTRM2 STK OTHR P Drill out hard cement from 2996' to 3098' - 10 b m / 1160 si / 40 r m 14:15 18:30 4.25 3,098 3,122 INTRM2 STK KOST P Time drill off of cement plug from 3098' to 3122' MD WOB 2/5 GPM 600 1680 si 18:30 20:30 2.00 3,122 3,122 INTRM2 STK CIRC P Circ & condition thick mud -displaced hole with clean 10.7 LSND mud 20:30 00:00 3.50 3,122 3,135 INTRM2 STK KOST P Time drill f/ 3122' to 3135' MD - 2499' ~~ TVD ~ ADT- 7.14 hrs AST - 7.14 hrs -ECD _- 11.09 ppg WOB 2/5 k GPM 600 @ 1680 psi Strin wt. PU 135 SO 115 02/10/2007 00:00 01:00 1.00 3,135 3,151 INTRM2 STK OTHR P Time driil f/ 3135' to 3151' MD - 2508' TVD WOB 7/12 GPM 600 @ 1700 psi AST - 1.52 hrs 01:00 12:00 11.00 3,151 4,048 INTRM2 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 3151' to 4048' MD 3310' TVD ADT - 8.86 hrs =ART 5.24 hrs AST 3.62 hrs -ECD 11.2 ppg WOB - 10/15 k RPM 100 GPM 650 @ 2250 psi String wt. PU 150 SO 120 Rot 135 Tor ue on/off btm. - 9000/8000 ft/Ibs 12:00 00:00 12.00 4,048 5,232 INTRM2 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 4048' to 5232' MD 3664' TVD ADT - 6.7 hrs. =ART 5.59 hrs AST - 1.11 hrs. ECD 11.8 ppg WOB 8/12 k RPM 90 GPM 600 @ 2630 psi String Wt. PU 165 SO 125 Rot 140 Tor ue on/off tbm. - 9500/9000 ft/Ibs 02/11/2007 00:00 12:00 12.00 5,232 6,138 INTRM2 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 5232' to 6138' MD 4151' TVD ADT - 8.77 hrs. =ART 8.7 hrs AST - .07 hrs. ECD 11.8 - 11.5 ppg WOB 12/20 k RPM 90 GPM 640 @ 2747 psi String Wt. PU 185 SO 130 Rot 155 Torque on/off tbm. - 10,500/10,000 fUlbs ~~ ® ~ l~~~ct~a T caf ~ 8~ • SELL Q ____ _ T °~~4/1lSl f~l SAL ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Howard Okland 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hale/Mechanical Logs and /or Tubing Inspection(Caliper / MTTJ The technics{ data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907j 245-8952 1 j 1 EDE CD3 - 307 2) 3) 4J 5) 20~ ' 0`~( 6) 7) Signed Print Name Jewelry Log ~ /~/~/~ ~ y ~~ iS ~~,o alp llg,~,~ 22-0ct-06 '~ ~~~-~ ~ ~;~~ i ~ ~~a l t ~~~,y,.~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AFC 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL : ?®S~NCHOR:~69ECp7NiE~®R°fLCC.E34~ WEBSITE : LA1V~I~Pi.~AEsM®RYLCGaCO647 D:\11~iaster_Copy_00_PDSANC-20ax\Z_Word\Distribution\Transmittal_Sheets\Transmit Original.doc FW: Doyon 19 well kill • • Subject: FW: Doyon 19 well kill From: "Galiunas, Elizabeth C" <Elizabeth.C.Galitinas@conocophillips.com> Date: Wed, 07 Feb ?007 10:58:13 -0900 'I'o: Thoi~r~ Maunder ~~tom maundcr(~i;admin.state.ak.us? Torn, call with questions. I will send you ono#her update today once we know more in an hour. Currently we have 11 ppg mud all the way around and are watching the we{I to be sure it is killed. Regards, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 c~O~ -l7~(P -----Original Message----- From: Doyon 19 Company Man Sent: Tuesday, February 06, 2007 10:55 PM To: 'jeffjones@admin.state.ak.us' Cc: Galiunas, Elizabeth C; Johnson, Vern Subject: Doyon 19 well kill 'Content-Description: AOGCC Notification 020607.doc 'AOGCC Notification 020607.doc'. Content-Type: application/msword Content-Encoding: base64 1 of 1 2/7/2007 2:06 PM [Fwd: [Fwd: Doyon 19 well kill]] • • Subject: [Fwd: [Fwd: Doyon 19 well kill]] From: James Regg <jim_rebb@admin.state.ak.us> Date: Wed, 07 Feb 2007 09:51:58 -0900 'Co: Tom ,1~1aun<ler ~ "to~11 ~Tiaurnicn,~r aci~nin.s~ait.ak.us; CC: Catherine P F~ocrster ~~cathv focr5tc;r'a,:ad~l~in.stale.ak.us=- -------- Original Message -------- Subject:[Fwd: Doyon 19 well kill] Date:Wed, 07 Feb 2007 06:05:02 -0900 From:Jeff Jones <jefl' jone~aadnlin.state.ak.us--~ To:James Regg <jirn re~;~~adnlin.state.ak.us> ~~~-o~c~ Hello Jim, attached is the CD3-107 well control incident summary from Dave Burley, CPAI Co. Rep. on Doyon 19 at Alpine. Thanks, Jeff (Doyon 19 well kill.eml Content-Type: message/rfc822 i Content-Encoding: 7bit 1 of 1 2/7/2007 2:06 PM Doyon 19 216/07 ~ ~~-~~~ Mr. Jeff Jones, This note is an attempt to summarize our phone conversation earlier this evening. The rig is beginning re-drill operations on CD3-107. A bridge plug was set in the 7" casing @ 3240' followed by a pressure test to 3500 psi for 30 minutes. The well was displaced to 9.6 kcl brine from this depth to surface. Ran in hole with casing cutter to 3193', 800 psi on 9 5/8" x 7" annulus was bled off to an open top tank - 0 psi, annulus static. The 7' casing was cut @ 3193'MD / 2528' TVD (100" below 9 5/8" casing shoe) pressure on 9 5/8" annulus still 0 psi. Closed annular preventor and attempted to circulate up annulus, lost 15 bbls to hole with no returns on 9 5/8" x 7" annulus. Pulled up to 3026' planning a second cut. Prior to cut, 240 psi observed on 9 5/8" x 7" annulus at wellhead. Closed annular preventor and opened up annulus to open top tank. Displaced annulus with 9.6 ppg brine. The 9 5/8" x 7" annulus was closed and pressure built to 140 psi, Opened annular preventor and observed slight flow up 7" x 4" annulus. Closed annular preventor and displaced drill pipe and 9 5/8" x 7" annulus with 9.8 ppg mud taking returns to open top tank. Mud returns to open top tank were gas cut to 8.8 ppg. Well was shut in and circulating lines rigged up from 9 5!8" x 7" annulus to the rig's choke manifold. Pressure on 9 5/8" x 7" annulus was 40 psi, drill pipe 20 psi. Circulated out gas cut mud through choke, shut in well and monitored pressure -pressures stabilized at 50 psi on the drill pipe and 100 psi on the 9 5/8 X 7" annulus, 40 psi on the 7" x 4" annulus. The rig is currently performing well kill operations with 10.7 ppg mud. Please contact me if you have any further questions. David P. Burley ConocoPhillips Drilling Supervisor Doyon 19 670-4300 Office 670-4350 Rig floor SARAH PALlN, GOVERNOR 4~7~ Ouj ~ a7r.~7 333 W. 7th AVENUE, SUITE 100 C011T5ER`i~'ATI011T COM11TI55I011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-307 and CD3-107 API Numbers: 50-103-20529-00 and 50-103-20529-01 Sundry Number: 307-042 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Following item 11 in the enclosed Program Outline, the well will be remaned and all subsequent operations and data shall be clearly differentiated in well name (CD3-107), API number (50-103-20529-01) and permit to drill number (206-189) When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907} 659-3607 (pager). 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. DATED this day of January, 2007 Encl. • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 25, 2007 ~A!v 2 ~ 2Q07 Alaska Oil and Gas Conservation Commission glaska Oi! ~ Gas Cons. G~mmissinn 333 West 7th Avenue, Suite 100 anchorage Anchorage, Alaska 99501 Re: Sundry Permit: Changed to approved program and re-enter the suspended well CD3-307 (permit number 206-046) / Ca3- ~o'~ ~Zb6'/89 ~ , ~•Z4 ~~? Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit for change to the approved program and to re-enter CD3-307 which was suspended. -' After the failed fishing attempts on the packer in CD3-307, Doyon 19 moved off 1/23/07 and to another CD3. The plan is to return to CD3-307 on february 2th, 2007, to cut and pull the intermediate casing, re-drill the intermediate ..section and continue on with completing the well as a horizontal Nechelik producer. The kick off point is below the surface casing shoe to the same permitted TD location. One difference from the previous permit to drill 401, is since there are no longer any perforations in the Kuparuk interval, one packer will be run. In the previous permit to drill the well was to be completed with two packers straddling the perforations. Once }~l~e kicked off, the well will be nam CD3-907 and the operations will be under original permit for CD3-107, number 206-189. _---__. Please find attached: 1. Form 10-403 2. A proposed drilling program 3. Abandonment of CD3-307 diagram. 4. Proposed completion schematic. 5. Revised cementing program for the intermediate 6. Proposed New directional plan If you have any questions or require further information, please contact Liz Galiunas 265-6247. Sincerely, Liz Galiunas Drilling Engineer Attachments cc: CD3-307 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation ConocoP~, STATE OF ALASKA I'~ ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~NI~ '~ ~ LUt~~ APPLICATION FOR SUNDRY APPROVALIsko 111 & Cas Cons. Commssljrt ~n AA(, ~s ~~n ~~~~~nrane 1. Type of Request: gbandon Sus nd ^ ^ pe O erational shutdown p ^ Perforate Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ~ Stimulate ^ Time Extension ^ Change approved program 0 Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well Q r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ - Exploratory ^ 206-046 zQ~- 3. Address: Stratigraphic [] Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20529-00 ~~ 7. KB Elevation (ft): 9. Well Name and Number: 55.1 ft BPMSL CD3-307 ~3 "/~7 ~t9- 8. Property Designation: 10. Field/Pools(s): Fie r ~ /•sy o7 372104, 372105, 364471 ' N e ik Oil Pool PRESENT WELL CONDIT ION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 11 411' 6927' 11 441' cement 6927' 11 541' Retainer 11611' Fish Casing Length Size MD ND Burst Collapse Structural Conductor 114 16" 114' 114' Surface 3019 9.625" 3093 2479 3520 2020 Intermediate 12983 7" 12004 7039 4599 5410 Production 1963 3.5" 2000 1800 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,762'-11,799' 6746'-6761' 3.5 L-80 2000 Packers and SSSV Type: Packers and SSSV MD (ft): 11,632' Premier Packer left in hole 6691' 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 1 Well Stat aft_e4ilproposed work: _ Commencing Operations: 2/2/2007 Oil 9'W ( Gas ^ Plugged ^ Abandoned 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas Printed Name , AIVOrd Alpine Drilling Team Leader Signature _~ Phone 265-6120 Date:1/25/07 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,~/-, Plug Integrity BOP Test p~ I Mechanical Integrity Test ^ Location Clearance ^ Other: ~S~O ~S~\ r~~ ~~ ~V 1~-l ~ '~ST i Subsequent Form Required: l..fj~ roved b A : COMMISSIONER APPROVED BY THE COMMISSION / ~ r Date: 0 pp y s') b, •'~ b'~ ~7 v -- ~ (.tt~~l Form 10-403 Revised 7/ZI305~ ~ ~ ~ SUBMIT IN DUPLICATE • ~ Alaine: CD3-307: Program outline 1. Set BPV. 2. Move Doyon 19 onto the well, dewater cellar as needed. Rig up over well. 3. Pull BPV and displace well to 9.4 ppg brine, taking returns to an open top tank. There is diesel in the tubing and +/-2000' MD in the annulus for freeze protection. 4. Install two-way-check & nipple down tree. 5. Nipple up and test BOPEs. 6. PuHttyo-way-check. 7. Pull and lay down 3.5" freeze protect string and hanger. 8. RIH with bridge plug and set at +/- 3370' MD (9 5/8" shoe at 3093' MD). Test bridge plug at 3500 psi for 30 mins. 9. MU casing cutter and cut casing at 3240' MD (+/- 150' below the surface shoe). 10. Ensure the 7" casing is free and circulate the annulus with LSND mud. Pull out of the hole with the 7" casing and lay down. ,~, C~ ~ p~G' 11. RIH with cement stinger and tag top bridge plug. Set 17 ppg cement plug from bridge plug to 2893' (+!- ~ 200' inside the surface casing). G~D.3' !D? 12. Make up 8 3/" assembly and polish off the cement plug. Kick off and drill into the Nechelik sand. ~!O ~ !~/ 13. Run and cement 7" casing per program. Carry out a leak off test down the 9 5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect the annulus and casing. 14. Make up and run 6-1/8" drilling assembly. Displace well to 9.2 ppg Flo-Pro. 01' ~'~ ( 15. Drill 6-1/8" horizontal section in the Nechelik sand to TD at 18421' MD / 6969' TVD. !~' 16. Circulate hole clean and pull out of the hole. 17. Run 3-%", 9.3#, L-80 tubing, SSSV, gas lift mandrels, packer, and XN nipple. Space out and land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 22. Set BPV and secure well. Move rig off. Plug back schematic for CD3-307 16" Conductor to 114' 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 3093' MD / 2479' TVD 477' ~~~1 (~ ~:. ~, 3240' ~i ~~Pr~~ Cut 7 30' 3370' Bridge Plug KOP at +/- 3300' MD. Cement above Cement Retainer : +/-100' above Bridge Plug_aC~ 11,441', 15.8 gpg 11,541' MD Cem nt Retainer 1 Kuparuk Perforations 11,762-11,799'MD ~1i. Top Kuparuk C 11735' MD / y~, 6573' TVD ~/' Top Nechelik at 12812' MD / 7032' TVD Updated 1/19/07 Sperry Sun Directional Plan WP06 7" 26 ppf L-80 BTC Mod Production Casing @ 13020' MD / 7044' TVD @ 89° • Completion Schematic for CD3-107 16" Conductor to 114' 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing 3093' MD / 2479' TVD cemented to surface TOC @ +/- 5790' MD / 3947' TVD Qannik at +J- 6290' MD / 4223' TVD TAM Stage cementing tool +/- 6752' M D / 4480' TVD Updated 1/19/07 Sperry Sun Directional Plan WP06 3-1 /2" 9.3 ppf L-80 EUE M tubing run with Jet Lube Run'n'Seal pipe dope Completion MD T D IN Tubing Hanger 32' 32' 4-'/~' 12.6 #!ft IBT-Mod Tubing (2) Crossover 3 '/2" 9.3#/ft EUE -Mod Tubing Camco TRMAXX-5E SSSV (2.812") 2210' 2000' 46.4° 3'/2" 9.3#/ft EUE -Mod Tubing Camco KBMG GLM (2.867" ID) 4804' 3400' 60.35 3 '/" 9.3#/ft EUE -Mod Tubing Camco KBMG GLM (2.867" ID) 8771' 5600' 60.3° 3 '/" 9.3#/ft EUE -Mod Tubing Camco KBMG GLM (2.867" ID) 10766' 6675' 63° 3'/z" 9.3#/ft EUE -Mod Tubing (1) Baker Premier Packer 10806' 6693' 63° 3'/" 9.3#/ft EUE -Mod Tubing (1) HES XN (2.75" NoGo) 10846' 6711' 64° 3 '/" 10' pup joint WLEG 11854' 7020' 81° Calc TOC @ ~~. +1- 10,406' MD i 6500' TVD +500' above top of Kuparuk C Well TD at 18,421' MD / 6969' TVD Top Kuparuk C 10,906' MD 16737' TVD Top Nechelik at 12,001' MD / 7039' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 12004' MD / 7039' TVD @ 84° Cementing Requirements • 7" Intermediate Casing run to 12004' MD 17039' ND Cemented in two stases First Stage: Cement from 12004' MD to 10,406' MD {500' above the Kuparuk C) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Lead: (12004' -10406') X 0.1503 ft3/ft X 1.4 (40% excess) = 336.3 ft3 annular volume 80' X 0.2148 ft3lft = 17.2 ft3 shoe joint volume Total volume = 336.3 + 17.2 = 353.5 ft3 => 305 Sx @ 1.16 ft3/sk System: 305 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. Assume 40% excess annular volume Lead: (6752'-5790') X 0.1503 ft3/ft X 1.4 (40% excess) = 202.4 ft3 annular vol. Total Volume = 202.4 ft3 => 173 Sk @ 1.17 ft3/sk System: 173 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1!19/2007 Time:' 11:07:46 Pager I Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD3-30T,?rue North Site: Alpine CD3 Vertical (TVD) Reference: CD3-307: 49.6 Well: CD3-307 Section (VS) Reference: Well (O.OON,O.OOE;323.OOAzi) Wellpath: Plan: CD3-107 Survey Calculation Method: Minimum Curvature Db: Orate Plan: CD3-107wp06 Date Composed: 1/19/2007 sidetrack below surf csg Version: 3 Principal: Yes Tied-to: From: Definitive Path Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: WeII Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Alpine CD3 Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Easting: 388488.10 ft Longitude: 150 54 30.391 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.86 deg Well: CD3-307 Slot Name: Alpine CD3-107 Well Position: +N/-S -43.21 ft Northing: 6003847.19 ft Latitude: 70 25 10.056 N +E/-W -240.49 ft Easting : 388247.02 ft Longitude: 150 54 37.443 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD3-107 Drilled From: CD3-307 Tie-on Depth: 3300.00 ft Current Datum: CD3-307: Height 49.55 ft Above System Datum: Mean Sea Level Magnetic Data: 1/24/2007 -"' Declination: 23.00 deg Field Strength: 57570 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.25 0.00 0.00 323.00 Survey Program for Definitive Wellpath Date: 1/19/2007 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information MD Inc! Azim TVD +N/-S +E/ W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 3300.00 60.01 66.99 2581.27 490.99 1539.85 0.00 0.00 0.00 0.00 3500.00 57.15 73.17 2685.60 549.22 1700.13 3.00 -1.43 3.09 120.00 3850.00 57.77 85.61 2874.39 603.25 1989.26 3.00 0.18 3.55 90.00 4295.10 56.32 69.78 3117.62 682.02 2352.38 3.00 -0.33 -3.56 -100.52 10007.63 56.32 69.78 6285.74 2325.07 6812.91 0.00 0.00 0.00 0.00 12004.14 84.00 0.00 7039.55 3791.41 7705.91 3.50 1.39 -3.50 -83.66 CD3-107wp06 T1 12576.18 91.00 350.00 7064.55 4359.65 7656.07 2.13 1.22 -1.75 304.71 13076.18 91.63 337.51 7053.05 4838.61 7516.52 2.50 0.13 -2.50 -87.00 13657.73 90.70 323.00 7041.19 5342.07 7228.83 2.50 -0.16 -2.50 266.52 18421.56 91.02 322.85 6969.60 9142.49 4357.29 0.01 0.01 0.00 -24.73 CD3-107wp06 Toe WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot CD3-307 -43.21 -240.49 6003847.19 388247.02 70°25'10.056N 150°54'37.443W N/A WELLPA'fH DETAILS Plan: CD3-107 T Parent Wellpath: CD3-307 M Azimuths to True Nor Tie on MD: 3300.00 Magnetic North: 23.01 Rig: D-19 Magnetic Fie Ref. Datum: CD3-307: 49.SSft Strength: 57570r Dip Angle: 80.7' V.Section Origin Origin Starting Date:1/24/20( Angle +N/-S +E/-W From TVD Model: bggm20( 323.00° 0.00 0.00 36.25 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 3300.00 18421.56 Planned: CD3-107wp06 V3 MWD+IFR-AK-CAZ-SC 1500 1250 1000 750 a +^ 500 ~v ,~ 250 -250 -500 CD3-107 06 II I ^~~ I I - I - - - + ___ ~ _. 000 --- - I o t o ~ o o o~ I °o ~ o _ - I ~_ -5000 -2500 0 2500 5000 7500 10000 12500 1 West(-)/Eazt(+) ISOOOtVinl _ ---- a ° 5~~0 ~ 400 f > [- i S6° 0 rn 0 0 0 2000 Vertical Section at 323.00° 12000R/inJ PLAN DETAILS CD3-107wp06 sidetrack below surf csg Version 3 1/19/2007 Start Point MD Inc Azi TVD +N/-S +E/-W 3300.00 60.01 66.99 2581.27 490.99 1539.85 HALLIBURTON_ COI'lOC PhIIIIpS SpeRy Drilling Services ~~ REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: CD3-307, True North Vertical (TVD) Reference: CD3-307: 49.55 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: CD3-307: 49.55 Calculation Method: Minimmn Curvature • ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska lnc. Date: 1!1912007 ' Time: 11 :07:46. Page: 2 Field: Colville Rive r Unit Co-ordiuate(NE) Referenee: Well: CD3-307, True North Site: Alpine CD3 Vertica l (TVD)Reference: C D3-307:49.6` Well: CD3-307 See tion (VS) Reference; We{I {O.OON,O.OOE,323.OOAzi) Wellpatb: Plan: CD3-1 07 Survey Calculafion Method: Minimum Curvature Db: Orate Survey MD Inc! Aziim TVD Sys TVD N/S E/W MapN M~pE DLS VS Comme t ft deg deg ft ft ft ft ft ft degl100ft ft 3092 .91 60. 78 65 .79 2478 .92 2429 .37 419 .20 1374 .77 6004245 .73 389627 .79 0.00 -492 .57 9 5/8" 3300 .00 60. 01 66 .99 2581 .27 2531 .72 490 .99 1539 .85 6004315. 04 389793 .92 0.63 -534 .58 KOP; 3 DLS, 33 0 3400 .00 58. 54 70 .03 2632 .37 2582 .82 522 .49 1619 .82 6004345. 33 389874 .33 3.00 -557 .55 _ 3500 .00 57. 15 73 .17 2685 .60 2636 .05 549 .22 1700 .13 6004370. 85 389955 .03 3.00 -584 .53 steer 3600 .00 57. 20 76 .74 2739 .82 2690 .27 571 .03 1781 .26 6004391. 44 390036 .47 3.00 -615 .95 3700 .00 57. 35 80 .30 2793 .89 2744 .34 587 .76 1863 .69 6004406. 93 390119 .13 3.00 -652 .19 3800 .00 57. 60 83 .85 2847 .66 2798 .11 599 .37 1947 .18 6004417. 30 390202 .78 3.00 -693 .16 3850 .00 57. 77 85 .61 2874 .39 2824. 84 603 .25 1989 .26 6004420. 54 390244 .91 3.00 -715 .39 steer 3900 .00 57. 51 83 .87 2901 .16 2851. 61 607 .12 2031 .31 6004423. 79 390287 .01 3.00 -737 .60 4000 .00 57. 06 80 .34 2955 .22 2905. 67 618 .67 2114 .62 6004434. 09 390370 .48 3.00 -778 .52 4100 .00 56. 71 76 .78 3009 .87 2960. 32 635 .27 2196 .69 6004449. 45 390452. 79 3.00 -814 .65 4200 .00 56. 46 73 .20 3064. 96 3015. 41 656 .88 2277 .29 6004469. 85 390533. 69 3.00 -845 .90 4295 .10 56. 32 69 .78 3117 .62 3068 .07 682 .02 2352 .38 6004493. 86 390609 .14 3.00 -871 .02 Sail; 56.32° for 5 4300 .00 56. 32 69 .78 3120 .33 3070 .78 683 .42 2356 .20 6004495. 21 390612 .98 0.00 -872 .19 4400 .00 56. 32 69 .78 3175 .79 3126. 24 712 .19 2434 .29 6004522. 80 390691 .48 0.00 -896 .21 4500 .00 56. 32 69 .78 3231 .25 3181. 70 740 .95 2512 .37 6004550. 38 390769 .98 0.00 -920 .23 4600 .00 56. 32 69 .78 3286 .71 3237. 16 769 .71 2590 .45 6004577. 97 390848 .48 0.00 -944 .26 4700 .00 56. 32 69 .78 3342 .17 3292. 62 798 .47 2668 .54 6004605. 56 390926. 98 0.00 -968 .28 4800 .00 56. 32 69 .78 3397 .63 3348. 08 827 .24 2746 .62 6004633. 15 391005. 48 0.00 -992 .30 4900 .00 56. 32 69 .78 3453. 09 3403. 54 856 .00 2824 .70 6004660. 74 391083. 97 0.00 -1016 .32 5000 .00 56. 32 69 .78 3508. 55 3459. 00 884 .76 2902 .79 6004688. 32 391162. 47 0.00 -1040 .34 5100 .00 56. 32 69 .78 3564. 01 3514. 46 913 .52 2980 .87 6004715. 91 391240. 97 0.00 -1064 .36 5200 .00 56. 32 69 .78 3619. 47 3569. 92 942 .29 3058 .95 6004743. 50 391319. 47 0.00 -1088 .38 5300 .00 56. 32 69 .78 3674. 93 3625. 38 971 .05 3137 .04 6004771. 09 391397. 97 0.00 -1112 .40 5400 .00 56. 32 69 .78 3730. 39 3680. 84 999 .81 3215 .12 6004798. 67 391476. 47 0.00 -1136 .42 5500 .00 56. 32 69 .78 3785. 84 3736. 29 1028 .57 3293. 20 6004826. 26 391554. 96 0.00 -1160 .45 5600 .00 56. 32 69 .78 3841. 30 3791. 75 1057 .33 3371. 29 6004853. 85 391633. 46 0.00 -1184 .47 5700 .00 56. 32 69 .78 3896. 76 3847. 21 1086 .10 3449. 37 6004881. 44 391711. 96 0.00 -1208 .49 5800 .00 56. 32 69 .78 3952. 22 3902. 67 1114 .86 3527. 45 6004909. 03 391790. 46 0.00 -1232 .51 5900 .00 56. 32 69 .78 4007. 68 3958. 13 1143 .62 3605 .54 6004936. 61 391868. 96 0.00 -1256 .53 6000 .00 56. 32 69 .78 4063. 14 4013. 59 1172 .38 3683 .62 6004964. 20 391947. 46 0.00 -1280 .55 6100 .00 56. 32 69 .78 4118. 60 4069. 05 1201 .15 3761 .70 6004991. 79 392025. 96 0.00 -1304 .57 6200 .00 56. 32 69 .78 4174. 06 4124. 51 1229 .91 3839 .79 6005019. 38 392104. 45 0.00 -1328 .59 6300 .00 56. 32 69 .78 4229. 52 4179. 97 1258 .67 3917 .87 6005046. 96 392182. 95 0.00 -1352 .61 6400 .00 56. 32 69 .78 4284. 98 4235. 43 1287 .43 3995. 95 6005074. 55 392261. 45 0.00 -1376 .63 6500 .00 56. 32 69. 78 4340. 44 4290. 89 1316 .20 4074. 04 6005102. 14 392339. 95 0.00 -1400 .66 6600 .00 56. 32 69. 78 4395. 90 4346. 35 1344 .96 4152. 12 6005129. 73 392418. 45 0.00 -1424 .68 6700 .00 56. 32 69. 78 4451. 36 4401. 81 1373. 72 4230. 20 6005157. 32 392496. 95 0.00 -1448 .70 6800 .00 56. 32 69. 78 4506. 81 4457. 26 1402 .48 4308. 29 6005184. 90 392575. 44 0.00 -1472 .72 6900 .00 56. 32 69. 78 4562. 27 4512. 72 1431. 25 4386. 37 6005212. 49 392653. 94 0.00 -1496 .74 7000. 00 56. 32 69. 78 4617. 73 4568. 18 1460. 01 4464. 45 6005240. 08 392732. 44 0.00 -1520 .76 7100. 00 56. 32 69. 78 4673. 19 4623. 64 1488. 77 4542. 54 6005267. 67 392810. 94 0.00 -1544 .78 7200. 00 56. 32 69. 78 4728. 65 4679. 10 1517. 53 4620. 62 6005295. 26 392889. 44 0.00 -1568 .80 7300. 00 56. 32 69. 78 4784. 11 4734. 56 1546. 29 4698. 70 6005322. 84 392967. 94 0.00 -1592. 82 7400. 00 56. 32 69. 78 4839. 57 4790. 02 1575. 06 4776. 79 6005350. 43 393046. 43 0.00 -1616. 85 7500. 00 56. 32 69. 78 4895. 03 4845. 48 1603 .82 4854. 87 6005378. 02 393124. 93 0.00 -1640 .87 7600 .00 56. 32 69. 78 4950. 49 4900. 94 1632 .58 4932. 95 6005405. 61 393203. 43 0.00 -1664 .89 7700 .00 56. 32 69. 78 5005. 95 4956. 40 1661. 34 5011. 04 6005433. 19 393281. 93 0.00 -1688 .91 7800 .00 56. 32 69. 78 5061. 41 5011. 86 1690. 11 5089. 12 6005460. 78 393360. 43 0.00 -1712 .93 7900. 00 56. 32 69. 78 5116. 87 5067. 32 1718. 87 5167. 20 6005488. 37 393438. 93 0.00 -1736 .95 8000. 00 56. 32 69. 78 5172. 33 5122. 78 1747. 63 5245. 29 6005515. 96 393517. 42 0.00 -1760 .97 8100. 00 56. 32 69. 78 5227. 78 5178. 23 1776. 39 5323. 37 6005543. 55 393595. 92 0.00 -1784 .99 8200. 00 56. 32 69. 78 5283. 24 5233. 69 1805. 16 5401. 45 6005571. 13 393674. 42 0.00 -1809 .01 MD • ConocoPhillips Alaska, Inc. CPAI Report Company: ConoooPhillips Alaska Ina Date: 1/19/2007 Time: 11 `.07:46 Page: 3 Field: Colville River Un it Co-ordinate(NE) Re ference: Well: CD3-307, True North Site: Alpine CD3 Vertica l (TVD) Reference: C D3-307: 49:6 ' Well: CD3-307 Sec tion (VS) Reference: Well (O.OON,O.OOE,323.OOAzi) Wellpath: Plan: C D3-1 07 Survey Calcnlatiou Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N!S E/W MapN MapE DLS VS Comme t ft deg. deg ft ft ft ft ft °' ft deg/100ft ft 8300 .00 56. 32 69 .78 5338 .70 5289. 15 1833 .92 5479 .54 6005598. 72 393752 .92 0.00 -1833 .03 8400 .00 56. 32 69 .78 5394 .16 5344 .61 1862 .68 5557 .62 6005626. 31 393831 .42 0.00 -1857 .06 8500 .00 56. 32 69 .78 5449 .62 5400 .07 1891 .44 5635 .70 6005653. 90 393909 .92 0.00 -1881 .08 8600 .00 56. 32 69 .78 5505 .08 5455. 53 1920 .21 5713 .79 6005681. 49 393988 .41 0.00 -1905 .10 8700 .00 56. 32 69 .78 5560 .54 5510. 99 1948 .97 5791 .87 6005709. 07 394066 .91 0.00 -1929 .12 8800 .00 56. 32 69 .78 5616. 00 5566. 45 1977 .73 5869 .95 6005736. 66 394145. 41 0.00 -1953 .14 8900 .00 56. 32 69 .78 5671. 46 5621. 91 2006 .49 5948 .04 6005764. 25 394223. 91 0.00 -1977 .16 9000 .00 56. 32 69 .78 5726 .92 5677. 37 2035 .26 6026 .12 6005791. 84 394302 .41 0.00 -2001 .18 9100 .00 56. 32 69 .78 5782 .38 5732. 83 2064 .02 6104 .20 6005819. 42 394380 .91 0.00 -2025 .20 9200 .00 56. 32 69 .78 5837. 84 5788. 29 2092 .78 6182 .29 6005847. 01 394459. 41 0.00 -2049 .22 9300 .00 56. 32 69 .78 5893. 30 5843. 75 2121 .54 6260 .37 6005874. 60 394537. 90 0.00 -2073 .25 9400 .00 56. 32 69 .78 5948. 75 5899. 20 2150 .30 6338 .45 6005902. 19 394616. 40 0.00 -2097 .27 9500 .00 56. 32 69 .78 6004 .21 5954. 66 2179 .07 6416 .54 6005929. 78 394694 .90 0.00 -2121 .29 9600 .00 56. 32 69 .78 6059. 67 6010. 12 2207 .83 6494 .62 6005957. 36 394773. 40 0.00 -2145 .31 9700 .00 56. 32 69 .78 6115. 13 6065. 58 2236 .59 6572 .70 6005984. 95 394851. 90 0.00 -2169 .33 9800 .00 56. 32 69 .78 6170. 59 6121. 04 2265 .35 6650 .79 6006012. 54 394930. 40 0.00 -2193 .35 9900 .00 56. 32 69 .78 6226. 05 6176. 50 2294 .12 6728 .87 6006040. 13 395008. 89 0.00 -2217 .37 10000 .00 56. 32 69 .78 6281 .51 6231. 96 2322 .88 6806 .95 6006067. 71 395087 .39 0.00 -2241 .39 10007 .63 56. 32 69 .78 6285. 74 6236. 19 2325 .07 6812 .91 6006069. 82 395093. 38 0.00 -2243 .22 Build; 3.5 DLS 10100 .00 56. 73 65 .93 6336. 70 6287. 15 2354 .11 6884 .25 6006097. 78 395165. 14 3.50 -2262 .97 10200 .00 57. 32 61 .82 6391. 15 6341. 60 2391 .05 6959 .54 6006133. 58 395240. 97 3.50 -2278 .78 10300 .00 58. 03 57 .77 6444. 63 6395. 08 2433 .56 7032 .54 6006174. 99 395314. 59 3.50 -2288 .76 10400 .00 58. 87 53 .78 6496. 97 6447. 42 2481 .49 7102 .97 6006221. 86 395385 .73 3.50 -2292 .87 10500 .00 59. 84 49 .87 6547. 96 6498. 41 2534 .66 7170 .57 6006274. 01 395454. 11 3.50 -2291 .09 10600 .00 60. 91 46 .04 6597. 40 6547. 85 2592 .87 7235 .09 6006331. 25 395519. 49 3.50 -2283 .43 10700 .00 62. 09 42 .29 6645. 13 6595. 58 2655 .91 7296 .29 6006393. 36 395581. 62 3.50 -2269 .91 10800 .00 63. 38 38 .62 6690. 95 6641. 40 2723 .55 7353. 94 6006460. 11 395640. 27 3.50 -2250 .59 10900 .00 64. 75 35. 04 6734. 70 6685. 15 2795 .51 7407. 82 6006531. 26 395695. 22 3.50 -2225 .54 11000 .00 66. 21 31 .54 6776. 21 6726. 66 2871 .55 7457 .74 6006606. 54 395746. 27 3.50 -2194 .86 11100 .00 67. 74 28 .13 6815. 33 6765. 78 2951 .38 7503. 51 6006685. 66 395793. 22 3.50 -2158 .65 11200 .00 69. 35 24 .78 6851. 92 6802. 37 3034 .69 7544. 95 6006768. 34 395835. 90 3.50 -2117 .05 11300 .00 71. 01 21. 51 6885. 83 6836. 28 3121 .18 7581. 91 6006854. 26 395874. 15 3.50 -2070 .22 11400 .00 72. 74 18. 31 6916. 94 6867. 39 3210. 53 7614. 26 6006943. 10 395907. 83 3.50 -2018 .33 11500 .00 74. 51 15. 16 6945. 14 6895. 59 3302 .39 7641. 87 6007034. 54 395936. 81 3.50 -1961 .58 11600 .00 76. 33 12 .07 6970. 32 6920. 77 3396 .44 7664. 64 6007128. 22 395960. 98 3.50 -1900 .18 11700 .00 78. 18 9. 03 6992. 38 6942. 83 3492 .31 7682. 49 6007223. 81 395980. 26 3.50 -1834 .35 11800 .00 80. 07 6. 03 7011. 25 6961. 70 3589 .65 7695. 34 6007320. 94 395994. 57 3.50 -1764 .35 11900 .00 81. 99 3. 06 7026. 84 6977. 29 3688. 10 7703. 16 6007419. 25 396003. 86 3.50 -1690 .43 12000 .00 83. 92 0. 12 7039. 11 6989. 56 3787. 29 7705. 91 6007518. 38 396008. 09 3.50 -1612 .87 12004 .14 84. 00 0 .00 7039. 55 6990. 00 3791 .41 7705. 91 6007522. 50 396008. 16 3.50 -1609 .58 CD3-107wp06 T 12100 .00 85. 17 358 .31 7048. 60 6999. 05 3886 .83 7704. 51 6007617. 92 396008. 18 2.13 -1532 .53 12200 .00 86. 39 356. 56 7055. 97 7006. 42 3986 .45 7700. 05 6007717. 59 396005. 22 2.13 -1450 .29 12300 .00 87. 61 354. 81 7061. 20 7011. 65 4086. 02 7692. 54 6007817. 26 395999. 20 2.13 -1366 .24 12400 .00 88. 84 353. 07 7064. 30 7014. 75 4185. 41 7682. 00 6007916. 78 395990. 14 2.13 -1280 .52 12494. 72 90. 00 351. 42 7065. 26 7015. 71 4279. 26 7669. 22 6008010. 80 395978. 77 2.13 -1197 .88 Deep pt; 12494' 12500 .00 90. 06 351. 33 7065. 26 7015. 71 4284 .48 7668. 42 6008016. 03 395978. 06 2.13 -1193 .24 12576 .18 91. 00 350. 00 7064. 55 7015. 00 4359 .65 7656. 07 6008091. 37 395966. 83 2.13 -1125 .77 12600 .00 91. 03 349. 41 7064. 13 7014. 58 4383. 07 7651. 81 6008114. 86 395962. 92 2.50 -1104 .50 12700. 00 91. 16 346. 91 7062. 22 7012. 67 4480. 92 7631. 29 6008212. 99 395943. 87 2.50 -1014 .00 12800. 00 91. 29 344. 41 7060. 08 7010. 53 4577. 77 7606. 53 6008310. 20 395920. 57 2.50 -921 .75 12900 .00 91. 41 341. 91 7057. 72 7008. 17 4673 .45 7577. 58 6008406. 29 395893. 05 2.50 -827 .91 13000 .00 91. 53 339. 42 7055. 15 7005. 60 4767. 77 7544. 48 6008501. 09 395861. 37 2.50 -732 .67 • ConocoPhilhps Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/19/2007 Time: 11:07:46 Pager 4 Field: Colville River Un it Co-ordinate(NE) Re ference:- Well: CD3-307, True North Site: Al pine CD3 Vertica l (TVD) Reference: C D3-307: 49.6 We1L• `CD3-307 See tion (VS) Reference: WeN {O.OON,O.OOE,323.OOAzi) Wellpatb: Plan: C D3-1 07 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N!S E/W MapN MapE DLS VS Comme t ft deg ..deg ft ft ft ft ft ft degH00ft ft 13076 .18 91. 63 337 .51 7053 .05 7003. 50 4838 .61 7516 .52 6008572. 33 395834 .48 2.50 -659 .27 13100 .00 91. 59 336 .92 7052 .38 7002. 83 4860 .56 7507 .30 6008594. 41 395825 .59 2.50 -636 .19 13200 .00 91. 44 334 .42 7049. 74 7000. 19 4951 .64 7466 .12 6008686. 09 395785 .78 2.50 -538 .67 13300 .00 91. 28 331 .93 7047. 37 6997. 82 5040 .84 7421 .01 6008775. 95 395742. 01 2.50 -440 .28 13400 .00 91. 12 329 .43 7045. 28 6995. 73 5128 .01 7372 .05 6008863. 83 395694. 37 2.50 -341 .21 13500 .00 90. 96 326 .94 7043 .47 6993. 92 5212 .96 7319 .34 6008949. 55 395642 .95 2.50 -241 .64 13600 .00 90. 79 324 .44 7041 .94 6992. 39 5295 .54 7262 .99 6009032. 96 395587 .83 2.50 -141 .77 13657 .73 90. 70 323 .00 7041 .19 6991. 64 5342 .07 7228 .83 6009079. 99 395554 .38 2.50 -84 .05 on wp03 13700 .00 90. 70 323 .00 7040. 67 6991. 12 5375 .83 7203 .39 6009114. 13 395529. 45 0.01 -41 .78 13800 .00 90. 71 323 .00 7039. 44 6989. 89 5455 .68 7143 .21 6009194. 87 395470. 48 0.01 58 .21 13900 .00 90. 72 322 .99 7038. 19 6988. 64 5535 .53 7083 .03 6009275. 60 395411. 50 0.01 158 .20 14000 .00 90. 72 322 .99 7036 .94 6987. 39 5615 .38 7022 .84 6009356. 33 395352 .52 0.01 258 .19 14100 .00 90. 73 322 .99 7035 .67 6986. 12 5695 .23 6962 .64 6009437. 06 395293 .53 0.01 358 .19 14200 .00 90. 74 322 .98 7034. 39 6984. 84 5775 .07 6902 .44 6009517. 79 395234 .54 0.01 458 .18 14300 .00 90. 74 322 .98 7033. 10 6983. 55 5854 .90 6842 .24 6009598. 51 395175. 55 0.01 558 .17 14400 .00 90. 75 322 .98 7031. 79 6982. 24 5934 .74 6782 .04 6009679. 23 395116. 55 0.01 658 .16 14500 .00 90. 76 322 .97 7030. 48 6980. 93 6014 .57 6721 .82 6009759. 95 395057. 54 0.01 758 .15 14600 .00 90. 76 322 .97 7029. 15 6979. 60 6094 .40 6661 .61 6009840. 66 394998 .54 0.01 858 .14 14700 .00 90. 77 322 .97 7027. 81 6978. 26 6174 .22 6601 .39 6009921. 37 394939. 52 0.01 958 .14 14800 .00 90. 78 322 .96 7026. 46 6976. 91 6254 .04 6541 .17 6010002. 08 394880. 51 0.01 1058 .13 14900 .00 90. 78 322 .96 7025. 10 6975. 55 6333 .86 6480 .94 6010082. 78 394821. 49 0.01 1158 .12 15000 .00 90. 79 322. 96 7023. 73 6974. 18 6413 .67 6420. 71 6010163. 48 394762. 46 0.01 1258 .11 15100 .00 90. 80 322. 96 7022. 34 6972. 79 6493 .48 6360. 47 6010244. 18 394703. 43 0.01 1358 .10 15200 .00 90. 80 322. 95 7020. 94 6971. 39 6573 .29 6300. 23 6010324. 87 394644. 40 0.01 1458 .09 15300 .00 90. 81 322 .95 7019. 53 6969. 98 6653 .09 6239 .99 6010405. 56 394585. 36 0.01 1558 .08 15400 .00 90. 82 322 .95 7018. 11 6968. 56 6732 .89 6179. 74 6010486. 24 394526. 32 0.01 1658 .07 15500 .00 90. 82 322. 94 7016. 68 6967. 13 6812 .69 6119. 48 6010566. 93 394467. 27 0.01 1758 .06 15600 .00 90. 83 322. 94 7015. 23 6965. 68 6892 .48 6059. 23 6010647. 61 394408. 22 0.01 1858 .05 15700 .00 90. 84 322. 94 7013. 78 6964. 23 6972 .27 5998. 97 6010728. 28 394349. 16 0.01 1958 .04 15800 .00 90. 84 322. 93 7012. 31 6962. 76 7052 .06 5938. 70 6010808. 96 394290. 10 0.01 2058 .03 15900 .00 90. 85 322 .93 7010. 83 6961. 28 7131 .84 5878 .43 6010889. 63 394231. 04 0.01 2158 .01 16000 .00 90. 86 322 .93 7009. 33 6959. 78 7211 .62 5818. 16 6010970. 29 394171. 97 0.01 2258 .00 16100 .00 90. 87 322. 92 7007. 83 6958. 28 7291 .40 5757. 88 6011050. 95 394112. 90 0.01 2357 .99 16200 .00 90. 87 322. 92 7006. 31 6956. 76 7371 .17 5697. 59 6011131. 61 394053. 82 0.01 2457 .98 16300 .00 90. 88 322. 92 7004. 79 6955. 24 7450 .94 5637. 31 6011212. 27 393994. 74 0.01 2557 .97 16400 .00 90. 89 322. 91 7003. 25 6953. 70 7530. 71 5577. 02 6011292. 92 393935. 66 0.01 2657 .96 16500 .00 90. 89 322 .91 7001. 70 6952. 15 7610 .47 5516. 72 6011373. 57 393876. 57 0.01 2757 .94 16600 .00 90. 90 322. 91 7000. 13 6950. 58 7690 .23 5456. 42 6011454. 22 393817. 47 0.01 2857 .93 16700 .00 90. 91 322. 91 6998. 56 6949. 01 7769 .98 5396. 12 6011534. 86 393758. 38 0.01 2957 .92 16800 .00 90. 91 322. 90 6996. 97 6947. 42 7849 .74 5335. 81 6011615. 50 393699. 27 0.01 3057 .91 16900. 00 90. 92 322. 90 6995. 37 6945. 82 7929. 48 5275. 50 6011696. 14 393640. 17 0.01 3157. 89 17000. 00 90. 93 322. 90 6993. 76 6944. 21 8009. 23 5215. 18 6011776. 77 393581. 06 0.01 3257. 88 17100 .00 90. 93 322. 89 6992. 14 6942. 59 8088 .97 5154. 86 6011857. 40 393521. 94 0.01 3357 .87 17200 .00 90. 94 322. 89 6990. 51 6940. 96 8168 .71 5094. 53 6011938. 02 393462. 82 0.01 3457 .85 17300 .00 90. 95 322. 89 6988. 86 6939. 31 8248. 44 5034. 21 6012018. 64 393403. 70 0.01 3557 .84 17400. 00 90. 95 322. 88 6987. 21 6937. 66 8328. 18 4973. 87 6012099. 26 393344. 57 0.01 3657. 83 17500. 00 90. 96 322. 88 6985. 54 6935. 99 8407. 90 4913. 53 6012179. 88 393285. 44 0.01 3757. 81 17600. 00 90. 97 322. 88 6983. 86 6934. 31 8487. 63 4853. 19 6012260. 49 393226. 30 0.01 3857. 80 17700. 00 90. 97 322. 87 6982. 16 6932. 61 8567. 35 4792. 85 6012341. 10 393167. 16 0.01 3957 .78 17800 .00 90. 98 322. 87 6980. 46 6930. 91 8647. 07 4732. 50 6012421. 71 393108. 02 0.01 4057 .77 17900. 00 90. 99 322. 87 6978. 74 6929. 19 8726. 78 4672. 14 6012502. 31 393048. 87 0.01 4157. 75 18000. 00 90. 99 322. 86 6977. 01 6927. 46 8806. 49 4611. 78 6012582. 91 392989. 71 0.01 4257. 74 18100. 00 91. 00 322. 86 6975. 27 6925. 72 8886. 20 4551. 42 6012663. 50 392930. 56 0.01 4357. 72 ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/19/2007 Time: 11:07:46 Page: 5 Field: Colville River Unit. Co-ordinate(NE) Reference: Well: CD3-307, True North Site: Alpine CD3 Vertical (TVD) Reference: CD3-307: 49.6 Well: CD3-307 Section (VS) Reference: Well (O.OON,tI:E)OE,323.OOAzi) Wellpath: Plan: CD3-1 07 Survey Calculafion Method: Minimum CuNature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ff ft 18200.00 91.01 322.86 6973.52 6923.97 8965.91 4491.05 6012744.09 392871.39 0.01 4457.71 18300.00 91.01 322.86 6971.76 6922.21 9045.61 4430.68 6012824.68 39281223 0.01 4557.69 18400.00 91.02 322.85 6969.98 6920.43 9125.30 4370.31 6012905.27 392753.06 0.01 4657.68 18421.56 91.02 322.85 6969.60 6920.05 9142.49 4357.29 6012922.64 392740.30 0.01 4679.23 CD3-107wp06 T Targets Map Map <---- Latitude ----> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec. Deg Min Sec Dip. Din ft ft ft ft ft CD3-107wp06 Toe 6969.60 9142.49 4357.29 6012922.64 392740.30 70 26 39.958 N 150 52 29.514 W CD3-107wp06 T1 7039.55 3791.41 7705.91 6007522.50 396008.16 70 25 47.304 N 150 50 51.362 W Annotation MD TVD ft ft 3300.00 2581.27 KOP; 3 DLS, 3300' MD 3500.00 2685.60 steer 3850.00 2874.39 steer 4295.10 3117.62 Sail; 56.32° for 5712' 10007.63 6285.74 Build; 3.5 DLS 12004.14 7039.55 7" csg; 12004' MD, 7039' TVD 12494.72 7065.26 Deep pt; 12494' MD, 7064' TVD 13657.73 7041.19 on wp03 18421.55 6969.60 TD Casing Points MD TVD Diameter Hole Size Name ft ft in in 3092.91 2478.92 9.625 12.250 9 5/8" 12004.14 7039.55 7.000 8.750 7" 18421.56 6969.60 6.125 6.125 6 1/8" OH Formations MD TVD Formations Lithology Dip Angte Dlp Direction . • ConocoPhilhps Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 1!19/2007 Time: 10:50:39 Page: - 1 Field: Colville River Unit Reference Site: Alpine CD3 Co-ordinate(NE) Reference: Well: CD3-307, True North Reference Well: CD3-307 Vertical (TVI)) Reference: CD3-307: 49.6 Reference Wellpath: Plan: CD3-107 Db: OraGe GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD3-107wp06 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 3300.00 to 18421.56 ft Scan Method: Trav Cylinder North Maximum Radius: 2038.53 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 3092.91 2478.92 9.625 12.250 9 5/8" 12004.14 7039.55 7.000 8.750 7" 18421.56 6969.60 6.125 6.125 6 1 J8" OH Plan: CD3-107wp06 Date Composed: 1! 19!2007 sidetrack below surf csg Version: 3 Principal: Yes Tied-to: From: Definitive Path Summary <_.___________~_r Offset Wellpath ----------------> Reference Offset Ctr-Ctr Nato Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD3 CD3-108 CD3-108 V14 3300.00 3350.00 892.20 74.10 818.10 Pass: Major Risk Alpine CD3 CD3-302 Plan: CD3-302 VO Plan: 16124.26 13370.29 455.09 144.94 310.16 Pass: Major Risk Alpine CD3 CD3-307 CD3-307 V4 3349.99 3350.00 0.68 74.43 -73.76 FAIL: Major Risk Alpine CD3 CD3-307 Redundant: CD3-107wp038391.15 18475.00 0.20 231.56 -231.37 FAIL: Major Risk Alpine CD3 CD3-307 Redundant: CD3-107wpOS8298.39 18650.00 0.95 199.06 -198.12 FAIL: Major Risk Alpine CD3 Plan: CD3-106 Plan: CD3-106 V2 Plan: 3300.00 3225.00 866.68 76.96 789.72 Pass: Major Risk Alpine CD3 Plan: CD3-301 Plan: CD3-301 V2 Plan: Out of range Alpine Satellites Fjord 5 Fjord 5 PB1 V1 Out of range Alpine Satellites Fjord 5 Fjord 5 V1 Out of range GRAM • ConocoPhillips Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 1/19/2007 ` Time: 10:53:11 Page: 8 Field: Colville Rive r Unit Reference Site: Alpine CD3 Co-ord inate(NE) Refe rence: Well : CD3-307 , True North Reference Well: CD3-307 Vertical (TVD) Reference: CD3-307: 49.6 Reference Wellpath: Plan: C D3-107 Db:- Oracle Site: Alpine C D3 Well: CD3- 307 Rule Assigned: Major Risk Wellpath: CD3-307 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD 11ZD TVD Ref Offset TFO+AZI TFO-HS Casing/Fi~istance Area Dev iation Warning ft ft ft ft ft ft deg deg in ft ft ft 3300.00 2581 .27 3300 .00 2581 .27 8 .78 8 .72 66.99 0. 00 7.000 0 .00 63. 82 -63 .82 FAIL 3325.00 2593 .83 3325 .00 2593 .75 8 .89 8 .83 12.79 305. 05 7.000 0 .17 73. 67 -73 .51 FAIL 3349.99 2606 .54 3350 .00 2606 .21 9 .00 8 .94 13.17 304. 67 7.000 0 .68 74. 43 -73 .76 FAIL 3374.96 2619 .37 3375 .00 2618 .63 9 .12 9 .04 13.54 304. 28 7.000 1 .52 75. 18 -73 .66 FAIL 3399.90 2632 .32 3400 .00 2631 .02 9 .23 9 .17 14.12 304. 09 7.000 2 .71 75. 90 -73. 19 FAIL 3424.81 2645 .38 3425 .00 2643 .32 9 .32 9 .30 15.31 304. 50 7.000 4 .28 76. 35 -72 .07 FAIL 3449.66 2658 .55 3450 .00 2655 .52 9 .40 9 .44 16.54 304. 96 7.000 6 .24 76. 76 -70 .52 FAIL 3474.46 2671 .81 3475 .00 2667 .63 9 .49 9 .57 17.67 305. 31 7.000 8 .58 77. 19 -68 .61 FAIL 3499.19 2685 .16 3500 .00 2679 .68 9 .58 9 .68 18.53 305. 38 7.000 11 .25 77. 67 -66. 42 FAIL 3523.89 2698 .56 3525 .00 2691 .82 9 .67 9 .77 18.66 304. 64 7.000 14 .11 78. 46 -64. 35 FAIL 3548.54 2711 .93 3550 .00 2704 .04 9 .76 9 .87 18.16 303. 26 7.000 17 .11 79. 50 -62 .39 FAIL 3573.14 2725 .26 3575 .00 2716 .35 9 .86 9 .97 17.33 301. 54 7.000 20 .26 80. 68 -60. 41 FAIL 3597.68 2738 .56 3600 .00 2728 .77 9 .95 10 .03 16.28 299. 62 7.000 23 .57 81. 86 -58. 29 FAIL 3622.15 2751 .81 3625 .00 2741 .30 10. 05 10 .09 15.09 297. 56 7.000 27 .01 83. 09 -56. 07 FAIL 3646.55 2765 .01 3650 .00 2753 .96 10. 14 10 .15 13.82 295. 42 7.000 30. 62 84. 32 -53. 69 FAIL 3670.88 2778 .16 3675 .00 2766 .74 10 .24 10 .21 12.52 293. 25 7.000 34 .40 85. 53 -51 .13 FAIL 3695.10 2791 .25 3700 .00 2779 .49 10 .34 10 .30 11.39 291. 26 7.000 38 .50 86. 71 -48. 21 FAIL 3719.21 2804 .25 3725 .00 2792 .14 10. 43 10 .38 10.52 289. 53 7.000 42 .99 87. 79 -44. 79 FAIL 3743.19 2817 .16 3750 .00 2804 .68 10. 52 10 .46 9.85 288. 01 7.000 47. 88 88. 77 -40. 89 FAIL 3767.03 2829 .98 3775 .00 2817 .12 10. 61 10 .54 9.36 286. 67 7.000 53. 14 89. 69 -36. 54 FAIL 3790.76 2842 .71 3800 .00 2829 .60 10. 70 10 .61 8.88 285. 35 7.000 58. 67 90. 59 -31. 92 FAIL 3814.36 2855 .35 3825 .00 2842 .16 10 .79 10 .68 8.38 284. 02 7.000 64 .41 91. 47 -27. 06 FAIL 3837.83 2867 .90 3850 .00 2854 .82 10. 88 10 .76 7.89 282. 70 7.000 70. 38 92. 33 -21. 96 FAIL 3862.05 2880 .82 3875 .00 2867 .56 10. 99 10 .84 7.03 281. 84 7.000 76. 50 93. 27 -16. 76 FAIL 3887.31 2894 .35 3900 .00 2880 .39 11. 12 10 .94 5.90 281. 59 7.000 82. 35 94. 27 -11. 92 FAIL 3912.74 2908 .01 3925 .00 2893 .31 11. 25 11 .04 4.87 281. 46 7.000 87. 83 95. 22 -7. 39 FAIL 3938.34 2921 .80 3950 .00 2906 .32 11 .37 11 .14 3.94 281. 42 7.000 92 .94 96. 13 -3. 20 FAIL 3964.08 2935 .73 3975 .00 2919 .40 11. 49 11 .24 3.08 281. 47 7.000 97 .67 97. 06 0. 61 Pass 3989.97 2949 .77 4000 .00 2932 .49 11. 61 11 .36 2.34 281. 64 7.000 102. 00 97. 97 4. 04 Pass 4015.99 2963 .92 4025 .00 2945 .58 11. 73 11 .47 1.69 281. 92 7.000 105. 95 98. 84 7. 10 Pass 4042.13 2978 .18 4050 .00 2958 .68 11. 84 11 .58 1.12 282. 28 7.000 109. 49 99. 69 9. 80 Pass 4068.37 2992 .53 4075 .00 2971 .81 11 .96 11 .69 0.61 282. 70 7.000 112 .63 100. 54 12. 09 Pass 4094.71 3006 .97 4100 .00 2985 .00 12. 07 11 .80 0.14 283. 17 7.000 115. 35 101. 39 13. 96 Pass 4121.13 3021 .48 4125 .00 2998 .26 12. 18 11 .91 -0.30 283. 67 7.000 117. 65 102. 20 15. 45 Pass 4147.61 3036 .06 4150 .00 3011 .58 12. 29 12 .02 359.28 284. 20 7.000 119. 54 102. 99 16. 54 Pass 4174.15 3050. 69 4175 .00 3024 .96 12. 39 12 .11 358.89 284. 76 7.000 121. 04 103. 75 17. 28 Pass 4200.72 3065. 36 4200 .00- 3038 .42 12. 50 12 .21 358.52 285. 34 7.000 122. 17 104. 50 17. 67 Pass 4227.32 3080 .07 4225 .00 3051 .94 12. 60 12 .30 358.16 285. 94 7.000 122. 94 105. 22 17. 72 Pass 4253.94 3094 .80 4250 .00 3065 .53 12. 69 12 .38 357.82 286. 56 7.000 123. 35 105. 92 17. 42 Pass 4280.56 3109 .55 4275 .00 3079 .15 12. 79 12 .47 357.52 287. 22 7.000 123. 41 106. 61 16. 81 Pass 4306.44 3123. 91 4300 .00 3092 .81 12. 90 12 .55 357.44 287. 66 7.000 123. 17 107. 29 15. 88 Pass 4331.44 3137. 77 4325 .00 3106 .50 13. 02 12 .63 357.59 287. 81 7.000 122. 87 108. 02 14. 85 Pass 4356.43 3151 .63 4350 .00 3120 .21 13. 14 12 .72 357.73 287. 95 7.000 122. 55 108. 77 13. 78 Pass 4381.43 3165 .49 4375 .00 3133 .88 13. 27 12 .82 357.90 288. 12 7.000 122. 17 109. 53 12. 64 Pass 4406.42 3179 .35 4400 .00 3147 .50 13. 39 12 .92 358.11 288. 33 7.000 121. 72 110. 29 11. 43 Pass 4431.41 3193. 21 4425 .00 3161 .08 13. 51 13 .03 358.36 288. 58 7.000 121. 20 111. 03 10. 17 Pass 4456.40 3207. 07 4450 .00 3174 .60 13. 64 13 .14 358.65 288. 88 7.000 120. 63 111. 80 8. 83 Pass 4481.38 3220 .92 4475 .00 3187 .99 13. 76 13 .26 359.03 289. 25 7.000 120. 02 112. 55 7. 47 Pass 4506.35 3234 .77 4500 .00 3201 .27 13. 88 13 .39 -0.51 289. 71 7.000 119. 40 113. 28 6. 12 Pass 4531.32 3248. 62 4525 .00 3214 .42 14. 01 13 .51 0.03 290. 25 7.000 118. 75 113. 98 4. 77 Pass 4556.28 3262. 46 4550 .00 3227 .47 14. 13 13 .64 0.64 290. 86 7.000 118. 09 114. 65 3. 44 Pass ConocoPhilhps Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska Ina Date: 1/19/2007 Time: - 10:53:11 Page: 9 Field: Colville River Unit Reference Site: Alpine CD3 Co-ordinate(NE) Reference: WeI L• CD3-307, True North Reference Well: CD3-307 Vertical (TVD) Reference: CD3-307 : 49.6 Reference Wellpath: Plan: C D3-1 07 Db: Oracle Site: Alpine CD3 We1L• CD3-307 Rule Assigned: Major Risk Wellpath: CD3-307 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable M D TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSi)istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 4581. 23 3276. 30 4575 .00 3240. 46 14. 25 13 .76 1 .29 291 .52 7.000 117. 43 115 .30 2.14 Pass 4606. 18 3290. 14 4600 .00 3253. 39 14. 38 13 .89 2. 00 292 .22 7.000 116. 77 115 .92 0.86 Pass 4631. 12 3303. 97 4625 .00 3266. 26 14. 50 14 .02 2. 75 292 .97 7.000 116. 11 116 .50 -0.39 FAIL 4656. 07 3317. 81 4650 .00 3279. 11 14. 63 14 .14 3. 53 293 .76 7.000 115. 44 117 .05 -1.61 FAIL 4681. 00 3331. 64 4675. 00 3291. 95 14. 75 14 .26 4. 33 294 .55 7.000 114. 75 117 .57 -2.82 FAIL 4705. 94 3345. 47 4700. 00 3304. 80 14. 88 14 .38 5. 15 295 .37 7.000 114. 04 118 .07 -4.03 FAIL 4730. 88 3359. 29 4725. 00 3317. 65 15. 00 14. 50 5. 98 296 .21 7.000 113. 32 118 .54 -5.22 FAIL 4755. 80 3373. 12 4750 .00 3330. 44 15. 13 14 .63 6. 87 297 .09 7.000 112. 62 118 .97 -6.35 FAIL 4780. 73 3386. 94 4775 .00 3343. 14 15. 25 14 .75 7. 82 298 .04 7.000 111. 98 119 .35 -7.37 FAIL 4805. 64 3400. 76 4800. 00 3355. 74 15. 38 14 .87 8. 83 299 .05 7.000 111. 40 119 .66 -8.27 FAIL 4830. 55 3414. 57 4825. 00 3368. 26 15. 50 14 .99 9. 90 300 .13 7.000 110. 88 119 .93 -9.05 FAIL 4855. 45 3428. 38 4850. 00 3380. 73 15. 63 15 .12 11. 02 301 .24 7.000 110. 44 120 .14 -9.71 FAIL 4880. 35 3442. 19 4875. 00 3393. 14 15. 75 15. 25 12. 16 302 .38 7.000 110. 07 120 .31 -10.24 FAIL 4905. 25 3456. 00 4900. 00 3405. 51 15. 88 15. 38 13. 33 303 .55 7.000 109. 78 120 .42 -10.64 FAIL 4930. 14 3469. 81 4925 .00 3417. 82 16. 00 15 .50 14. 54 304 .76 7.000 109. 58 120 .47 -10.89 FAIL 4955. 03 3483. 61 4950. 00 3430. 03 16. 13 15 .63 15. 78 306 .00 7.000 109. 54 120 .45 -10.92 FAIL 4979. 91 3497. 41 4975. 00 3442. 14 16. 25 15 .75 17. 05 307 .28 7.000 109. 65 120 .37 -10.72 FAIL 5004. 78 3511. 20 5000. 00 3454. 15 16. 38 15 .87 18. 36 308 .58 7.000 109. 93 120 .22 -10.29 FAIL 5029. 65 3524. 99 5025. 00 3466. 04 16. 50 16. 00 19. 69 309 .92 7.000 110. 41 120 .01 -9.59 FAIL 5054. 50 3538. 77 5050. 00 3477. 77 16. 63 16. 12 21. 05 311 .27 7.000 111. 14 119 .54 -8.39 FAIL 5079. 33 3552. 55 5075. 00 3489. 33 16. 76 16. 24 22. 42 312 .65 7.000 112. 13 118 .95 -6.81 FAIL 5104. 16 3566. 31 5100. 00 3500. 74 16. 88 16. 36 23. 80 314 .03 7.000 113. 39 118 .30 -4.91 FAIL 5128. 96 3580. 07 5125. 00 3512. 04 17. 01 16. 48 25. 17 315 .39 7.000 114. 84 117 .62 -2.78 FAIL 5953. 77 3593. 83 5150. 00 3523. 28 17. 13 16 .60 26. 51 316 .73 7.000 116. 42 116 .91 -0.49 FAIL 5178. 56 3607. 58 5175. 00 3534. 48 17. 26 16. 72 27. 82 318 .04 7.000 118. 13 116 .19 1.93 Pass 5203. 36 3621. 33 5200. 00 3545. 63 17. 39 16. 84 29. 10 319 .32 7.000 119. 96 115 .46 4.50 Pass 5228. 14 3635. 08 5225. 00 3556. 74 17. 51 16. 95 30. 31 320 .53 7.000 121. 95 114 .74 7.21 Pass 5252. 93 3648. 82 5250. 00 3567. 82 17. 64 17. 07 31. 44 321 .66 7.000 124. 11 114 .06 10.05 Pass 5277. 72 3662. 57 5275. 00 3578. 87 17. 77 17. 18 32. 48 322 .71 7.000 126. 44 113 .43 13.00 Pass 5302. 50 3676. 31 5300. 00 3589. 89 17. 89 17. 29 33. 45 323 .67 7.000 128. 92 112 .86 16.06 Pass 5327. 28 3690. 06 5325. 00 3600. 87 18. 02 17. 39 34. 32 324 .54 7.000 131. 58 112 .35 19.24 Pass 5352. 05 3703. 79 5350. 00 3611. 81 18. 14 17. 49 35. 09 325 .31 7.000 134. 43 111 .92 22.51 Pass 5376. 82 3717. 53 5375. 00 3622. 71 18. 27 17. 60 35. 77 325 .99 7.000 137. 46 111 .57 25.88 Pass 5401. 58 3731. 26 5400. 00 3633. 59 18. 40 17. 69 36. 37 326 .59 7.000 140. 61 111 .29 29.32 Pass 5426. 34 3744. 99 5425. 00 3644. 52 18. 52 17. 79 36. 92 327 .14 7.000 143. 75 111 .05 32.70 Pass 5451. 12 3758. 73 5450. 00 3655. 52 18. 65 17. 88 37. 42 327. 64 7.000 146. 85 110 .85 36.00 Pass 5475. 90 3772. 48 5475. 00 3666. 58 18. 78 17. 97 37. 87 328. 09 7.000 149. 91 110 .68 39.23 Pass 5500. 69 3786. 23 5500. 00 3677. 73 18. 90 18. 06 38. 28 328. 51 7.000 152. 91 110 .55 42.36 Pass 5525. 51 3799. 99 5525. 00 3689. 02 19. 03 18. 14 38. 64 328 .86 7.000 155. 81 110 .48 45.33 Pass 5550. 34 3813. 76 5550. 00 3700. 45 19. 16 18. 23 38. 94 329 .16 7.000 158. 59 110 .46 48.13 Pass 5575. 18 3827. 54 5575. 00 3712. 02 19. 29 18. 31 39. 20 329 .42 7.000 161. 26 110 .49 50.77 Pass 5600. 05 3841. 33 5600. 00 3723. 72 19. 41 18. 40 39. 41 329 .64 7.000 163. 81 110 .56 53.25 Pass 5624. 92 3855. 12 5625. 00 3735. 53 19. 54 18. 49 39. 61 329. 83 7.000 166. 25 110 .66 55.59 Pass 5649. 81 3868. 93 5650. 00 3747. 45 19. 67 18. 57 39. 78 330. 01 7.000 168. 56 110 .77 57.79 Pass 5674. 71 3882. 74 5675. 00 3759. 49 19. 80 18. 66 39. 94 330. 16 7.000 170. 75 110 .91 59.84 Pass 5699. 62 3896. 55 5700. 00 3771. 61 19. 93 18. 75 40. 08 330. 30 7.000 172. 85 111 .07 61.78 Pass 5724. 53 3910. 37 5725. 00 3783. 80 20. 05 18. 84 40. 20 330 .42 7.000 174. 89 111 .25 63.64 Pass 5749. 45 3924. 19 5750. 00 3796. 06 20. 18 18. 93 40. 31 330. 53 7.000 176. 85 111 .44 65.41 Pass 5774. 38 3938. 01 5775. 00 3808. 40 20. 31 19. 02 40. 41 330. 63 7.000 178. 74 111 .64 67.10 Pass 5799. 31 3951. 84 5800. 00 3820. 85 20. 44 19. 11 40. 45 330. 67 7.000 180. 56 111 .91 68.65 Pass 5824. 25 3965. 67 5825. 00 3833. 43 20. 57 19. 20 40. 44 330. 66 7.000 182. 30 112 .24 70.06 Pass WELL DETAILS AN-riLOLLISION SETTWGS COMPANY DETAILS Nwe +N'-S ~E'-W' Nulling EesOng LerINJ< LungiNde Slur Interlwlatiun MethodMD Interval. 2S.(N) CunxoPhillips Alaska lnc. [kplh Range From. 3700.00 Tn IN421 N, Engixering CD3-3U7 4321 -24(1.49 GOU3847.19 38824702 ]0"25'10 OSbN 150"54'37.343W' NA Ma<nnurn Range. 2038 i3 Rel<r<nce Plan CD3-I07aaPOG 75 50 0 10 U I (1 ua.LPA'm DE'1'nR.s Pon. (V3-lo7 Pu.m udbuh ~v.};m r nn MD. -~oo.W Nib RA. Damn. 0.19 Cll}?Yi: Jv 5511 Mgle rh~ein (hi8m w8 •NiS -E~-N' Fmm RU 3L? W' YOU 0 W ?6.25 n From Colour To DID 0 250 CD3-307 (CD3-3071 250 500 750 1000 1250 1500 1750 2000 16000 16250 16500 16750 18250 18500 18750 19000 25000 Travelling Cylinder Azimuth (TFO+AZ[) [deg] vs Centre to Centre Separation [30ft/in] 75 LEGEND CU3-108 (Cp3-108). Ma3or Risk ~ F)ord S(F3ord5PB1). Major Rmk C'D3-J02 (Plan CD1-302). Major Risk ~ Fjord 5 (Fjord 5), Majm Risk CD3-307 (CD3-if17). Minor Risk ~ Plan CD3-107 Plon..CD3-IOG IPIen.CDI-IOG). Major Risk ~ CD3-1U]xp06 Plan CD3-301 (Plan t'D1-301), Mayor Risk 0 Calculation MerhoJ. Minimum Cnrrarurc Ertor Sasr<m ISCWBA Scan Merhud. frneC5linJcr Nnrrh Error Surfeu h'ILpn<al w C'using W arcing MefioJ. Rules BnseJ From Colour To MD 0 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 16000 16000 16250 6 '" - 16500 - 16750 - 18250 40 - 18500 18750 19000 30 -- 25000 SECTION DF.TAILB S« MU Inc A>, TVD +N'-S .E~-W DLeg TFax VS« 'l argcl 1 3300.00 6001 66.99 258127 490.99 1539.85 000 000 -SW 58 2 3500181 5715 7317 268560 54922 170013 300 12000 -5&153 3 3850 00 5] ]] R5.6I 28]d 39 6U3 25 1989.26 300 9000 -715 39 4 4295.10 56 32 G9 ]8 311] 62 682 02 2352.38 300 -100 52 -871 02 5 10007.61 56.32 6978 fi2R5.74 2)25.U7 6812.91 OOU 000 -224122 6 12004.14 8400 000 ]039.55 3]9141 770591 150 -8366 -140958 CD3-10]avp0G T1 7 1257G.IN •1100 35t1.0U ]064.55 4359.fi5 7656.07 2.13 304]1 -1125"/7 8 130]6.18 91 63 337 51 ]OS3 OS 4818 61 7516 52 2 50 -87 00 -rr59 27 9 13657.]3 NI.7(1 321 UU ]U41.19 5342 U] 722tl N3 2.SU 266.52 -N4.U5 10 18421.56 91 02 322 85 G9G9 60 9142 49 415] 29 0 01 -24 73 4679 21 CD3-107w38W Tx • Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75ft/in] • SARAH PALIN, GOVERNOR oii0-7~A ®~ ~ ~ 333 W. 7th AVENUE, SUITE 100 Co11T5ERVA1'ao11T Cor'II~'II55aolY ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-307 Sundry Number: 307-028 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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. DATED this day of January, 2007 Encl. `"~~~ ~;,.,,.o..o1t, ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 22, 2007 ~,l'g ~~~ ~ `~ 1 ~~~ t Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Alaska Oil & Gas Cons. t~~~~rnissior~ Anchorage, Alaska 99501 A~~l~orage Re: Sundry Permit: Changed to approved program and suspension of CD3-307 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit for change to the approved program and the suspension of CD3-307. Operations for CD3-307 commenced again this winter season after the rig moved to CD3 on January 10th, 2007. Using E-line we made two attempts at cutting the mandrel inside the premier packer to be able to pull the entire completion string out in one run. After not being able to move the completion, we jet cut above the packer and pulled the upper completion out, leaving part of a pup joint of tubing, the packer, XN, and tubing conveyed perforation guns. Multiple milling attempts were performed to try and pull out the fish, none of which resulted in any progress. After seven days of milling, the decision was made to suspend this well and return to it at a later date to finish the well. As of now, since the well was never decompleted it is still known as CD3-307.x/ Please find attached the form 10-403, plan of operations and suspension schematic. If you have any questions or require further information, please contact Liz Galiunas 265-6247. Sincerely, ~~ Liz Galiuna Drilling Engineer Attachments cc: CD3-307 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation ~ 1S 1)z~-~~" ?~~cE~~iED ~ ~ STATE OF ALASKA ~~~ ~ 2 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ~(~ ,' APPLICATION FOR SUNDRY APPROVAL Alaska 0+~ & Gas titans. Carrtmissian 20 AAC 25.280 Anl:horag 1. Type of Request: Abandon ^ Suspend Q Operational shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 206-046 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20529-00 - 7. KB Elevation (ft): 9. Well Name and Number: 55.1 ft BPMSL CD3-307 8. Property Designation: 10. Field/Pools(s): "~ ~~r'j ~~ `~ 372104, 372105, 364471 '~ , ~ I'esb»tik Oil Pool PRESENT WELL CONDIT ION SUMMARY Total Depth M ): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): l 1' r-~ "~~ ~>f~" 11 441' cement 6927 11 541' Retainer 11611' Fish Casing Length ~. 7 Size MD TVD Burst Collapse Structural Conductor 114 16" 114' 114' Surface 3019 9.625" 3093 2479 3520 2020 Intermediate 12983 7" 13020 7044 4599 5410 Production 1963 3.5" 2000 1800 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,762'-11,799' 6746'-6761' 3.5 L-80 2000 Packers and SSSV Type: Packers and SSSV MD (ft): 11,632' Premier Packer left in hole 6691' 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: ~ ~34D~ t~a~ Commencing Operations: 1/21/2007 ~ Oil ^ Gas ^ Plugged ~ Abandoned ^ 16. Verbal Approval: Date: 1/21/07 v WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder f/~}lla 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas Printed Name C. Al v ord Alpine Drilling Team Leader r f Signature ~ ~ °,y~ Phone 265-6120 t~~ Date 1/22/07 - COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Number: Sun d ry ~~ ~~ ``''~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: l.a~~~ APPROVED BY Approved by: OMMIS ONER THE COMMISSION Date: /,. Q Form 10-403 Revised 7/2005 ~ ~ ~ ~ ~ SUBMIT IN DUPLICAT~/l Z .mss D ~• z 3 -°7 ~"' ~l~J Alpine: CD3-307 Suspension of Well -Program outline covered under sundry 1. POOH & lay down junk mill assembly 2. PU cement retainer and set 70' above fish (11,611') at 11,541' MD. ' 3. Pump cement through retainer to 100' below bottom perforations which are at 11,799' MD. Cement to 11,900' MD. 4. Leave 100' cement plug on top of retainer to predicted depth of 11,441' MD. ~ 5. POOH and lay down excess 3.5" tubing that is racked back in the derrick. 6. Run in hole with 2000' MD of 3.5" tubing and land hanger. Test seals. 7. Set two-way-check. 8. ND BOPE. NU and test tree. 9. Pull two-way-check. 10. Displace to freeze protection. 11. Install BPV. 12. LD excess drillpipe. 13. RDMO to CD3-113. C~-307 Suspension Plar~ 16" Conductor to 114' 3-1/2" 9.3 ppf L-80 EUE M tubing kill string 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 3093' MD / 2479' TVD cemented to surface Updated 12/21!06 Sperry Sun Directional Plan WP05 KW Fluid 9.4_„ppg KCI Brine with 1800' TVD diesel cao 1 11,541' MD Ce Retainer Cement above Cement Retainer : +/-100' above Bridge Plugs 11.441', 15.8 ppg Kuparuk Perforations 11,762-11,799'MD t Cement 100' below bottom perforations down to 11,900'. 15.8 pDq Top Kuparuk C 11735' MD / 6573' TVD Top Nechelik at 12812' MD / 7032' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 13020' MD / 7044' ND @ 89° CD3-307 Update • • Subject: CD3-307 Update From: "Galitulas, Elizabeth G" <Elizabeth.C.G~Iiunas@.conocophillips.com> Date: Mon, 22 Jan 2007 08:39:27 -0900 To: Thomas ~~auncier °~-tom maunder~u_admin.~tate.ak.us-::. Tom, Operations for CD3-307 began 1/10/2007 when we accepted the rig. After two failed chemical cuts inside our packer to release the entire completion, we jet cut the tubing above the packer. We proceeded to lay down the upper completion and attempted to mill the tubing pup joint above the packer. After 7 days of milling and no notable progress, the decision was made to suspend the well to be returned to at a later date (probably next winter season). The next well is CD3-113. The rig is currently working to suspend the well and should be moving off CD3-307 some time tomorrow evening. Verbal approval to suspend the well was given 1/21/07 and a sundry is to follow in the next day. Regards, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 1 of 1 1/24/2007 12:49 PM SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Field Oil Pool, CD3-307 Sundry Number: 306-405 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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. DATED thisT day of December, 2006 Encl. ConocoPhillips Alaska, In~ Post Office Box 100360 ~~ Anchorage, Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 December 20, 2006 ~'~ Alaska Oil and Gas Conservation Commission DEC ~ ~ 2006 333 West 7th Avenue, Suite 100 ABasi~a Qil ~ ncs ~~~~ ~'~~m~asro~ Anchorage, Alaska 99501 hQr~ge Re: Application for change to Approved Program- Re-enter suspended well CD3-307 and Re- drill well CD3-107 (permit no. 206-046) Dear Sir or Madam: ConocoPhillips Alaska, Inc. herby applies for a Permit for change to Approved Programs for CD3-307. Last winter CD3-307 began on 4/13/06 with Doyon 19 (permit no. 206-046). This well was drilled through the Kuparuk reservoir and into the Nechelik reservoir, where 7" casing was set and cemented. A completion was run and the Kuparuk interval perforated for a short term flowback and pressure monitoring. Once the ice road is open, the plan is to return to CD3-307 and decomplete the well. The rig will drill out of the 7" casing horizontally into the Nechelik reservoir. The well will be renamed CD3- 107 (the API number changed to 50-103-20529-01) once the well is decompleted and the casing shoe drilled out. CD3-107 will be completed as a Nechelik producer with two packers straddling the Kuparuk perforations. ~ Please find attached the information required by 20 AAC 25.010 and 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 APPLICATION FOR Sundry approval 20 ACC 25.010 (a) W 2. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 3. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 4. A proposed drilling program, including pre-rig work 5. Current completion diagram. 6. Proposed completion diagram. 7. Proposed New directional plan 8. A drilling fluids program summary. 9. Pressure information as required by 20 ACC 25.035 (d)(2). 10. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 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. OR161NAL • If you have any questions or require further information, please contact Liz Galiunas, 265-6247, or Chip Alvord at 265-6120. Sincerely, Liz Galiunas Drilling Engineer Attachments cc: CD3-107 Well File /Sharon Allsup Drake Chip Alvord Vern Johnson Liz Galiunas Jack Walker Lanston Chin ATO 1530 ATO 1700 ATO 1702 ATO 1704 ATO 1740 Kuukpik Corporation ORIGINAL DTs '2,~~ ICU' ~~- STATE OF ALASKA ~~~ SEC ~ ~ Z~~6 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL~`~s~~ ~'~ has ~ns~ Comrnissiolt ~n AAC ~S Aso anchorage 1. Type of Request: Abandon Sus nd ^ pe ^ Operational shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^~ Pull Tubing 0 Perforate New Pool ^ Re-enter Suspended Well ^~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 206-046 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20529-00 • 7. KB Elevation (ft): 9. Well Name and Number: 55.1 ft BPMSL CD3-307 8. Property Designation: 10. Field/Pools(s): 372104, 372105, 364471 Nechelik Oil Pool ` PRESENT WELL CONDIT ION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): Casing Length Size MD ND Burst Collapse Structural Conductor 114 16" 114' 114' Surface 3019 9.625" 3093 2479 3520 2020 Intermediate 12983 7" 13020 7044 4599 5410 Production 11648 3.5" 11680 6711 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11, 762'-11, 799' 6746'-6761' 3.5 L-80 11680 Packers and SSSV Type: Packers and SSSV MD (ft): 11,632' Premier Packer & 2249' TRM4E SCSSSV 669'1 & 2026' 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/8/2006 Oil Q Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas Printed Name ~,~ C. Alvord Alpine Drilling Team Leader Signature `~`~ ~~ ~ ~"~-~3,~_~ Phone 265-6120 Date 12/18/06 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3G ly -' ~U~. _ ra Plug Integrity ^ BOP Test Ix Mechanical Integrity Test ^ Location Clearance ^ other: 3 SC7`~ '~S ti rf._t~~ a.'`v ~"` ~~7 - -~- Subsequent Form Required: ~--,~' ti APPROVED BY Approved by: COM SSIONER THE COMMISSION Date: IZ.L~'i~/ `~ t~ Form 10-403 Revised 7/2005 ORIGINAL ~""~ SUBMIT IN DUPLICATE • • Nechelik : CD3-107 Pre-Riq Work 1) Slickline will change out the GLMs and E-line will chemical cut the Premier Packer once the ice road opens. 2) BPV set in well. Riq Procedure 3) Move on Doyon 19, dewater cellar as needed. 4) Rig up riser. 5) Pull BPV and displace well to 9.2 ppg brine, taking returns to an open top tank. 6) Install two way check, nipple down the tree. 7) Nipple up and test BOPE. 8) Pull two way check. "'~~5 ~~~~v~-~` 9) Attempt to pull tubing hanger to floor. Only pull 40,000 Ibs over on the packer, if not moving then rig up E-~ Line to re-cut the packer. If possible, pull out of hole laying down 3-1/2" tubing. Check pipe for Normally Occurring Radioactive Material (NORM). C 10) M/U drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 11) Displace well to water based, Flo-Pro mud. 12) Drill 6-1/8" horizontal section to well TD. ~ ~~ (~ ~~~\~~~ C~6.. ~~ 13) Circulate hole clean and pull out of the hole. 14) Run 3-'/z", 9.3#, L-80 tubing, SSSV, gas lift mandrels, packers, XN nipple and X nipple. Space out and land hanger. 15) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 16) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 17) Circulate tubing to diesel and install freeze protection in the annulus. 18) Drop ball and rod, set packer and test tubing and annulus to 3500 psi 130 rains. 19) Set BPV and secure well. Move rig off. -~ ~:, '~- =• C • C~3-307 Current-Well Completion 16" Conductor to 114' I ~ 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 3093' MD 12479' TVD cemented to surface 3-1/2" 9.3 ppf L-80 EUE M tubing run with Jet Lube Run'n'Seal pipe dope Baker Packer 11,632'MD ~~' Calc TOC @ +!- 11230' MD 16504' TVD ~~~Z~\ +500' above top of Kuparuk C ~ Top Kuparuk C 11735' MD / 6573' TVD ~` Top Nechelik at 12812' MD / 7032' TVD Updated 12/18/06 Tubing: 102 bbl Diesel Inner Annulus: 307 bbl, 9.4 ppg brine with diesel cap Completion MD TVD Inclination Tubing Hanger 32' 32' 0 degrees 4-''/Z" 12.6 #/ft IBT-Mod Tubing (2) 4-''/z" 12.6# Space out pups Crossover 3-1/2", 9.3#!ft, EUE-Mod Tubing Camco TRM4E SCSSSV 2249' 2026' 48 3-1/2", 9.3#/ft, EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 6932' 4409' 61 3-1/2", 9.3#/ft, EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 11482' 6623' 62.5 3-1/2" tubing joints (2) HES "X" (2.81" ID) Profile 11560' 6659' 63.2 3-1/2" tubing joint (2} Baker Premier Packer 11632' 6691' 64.1 3-1/2" tubing joint (1) HES "XN" (2.75" ID)-64.7° inc 11679' 6711' 64.7 3-1/2" tubing joint (2) Schlumberger TCP gun assembly 11742' 6738' 65.3 Tubing Tail 11799' 6762' 66 Kuparuk Perforations 11, 762-11, 799' M D --!:a 7" 26 ppf L-80 BTC Mod at 13,020' MD / 7044' TVD, 89.3° CD3-307 Nechelik Extension • • Subject: CD3-307 Nechelik Extension From: Thomas Maunder <tom_maunder~c~adulin.state.ak.us> Date: Thu, 21 Dec 2006 10:35:26 -0900 'I'o: Lir Galiut~as "~~aliucc~;~i,conoco~~hillii~s.ci~m=- CC: Vero Johnson <~~~'crn..fohnson crc~~noc~~phillips.e~~m'. Chi}~ \l~i~rd ~-Chip..~Ivordr~r..eonocophillips.r~~m> Steve Davies ~ "stc~-e d~vi~s'uadmin.statc.ak.~~s~ Liz, Probably best that we have a paper trail on this matter. CD3-307 (206-046) has 7" casing set into the Nechelik. The well was perforated in the shallower Kuparuk for testing and monitoring during the "non-drilling" season at CD3. CPAI now intends to pull the completion and drill out of the 7" shoe and drill a horizontal. section in the Nechelik. In the naming convention presently used at Fiord, this new penetration would be CD3-107. The path forward as we understand it will be: 1. CPAI will apply with a 403 to pull the completion and prepare the well to drill out. One item that should be addressed is how the Kuparuk will be isolated. 2. CPAI will submit a new 401 to drill to-the Nechelik BHL. As I understand, the well name will be CD3-107. 3. The API number for CD3-107 should have the -O1 in it since this is considered a sidetrack. 4. When CD3-107 is completed, the Commission will administratively abandon CD3-307. Ca11 or message with any questions. Tom Maunder, PE AOGCC 1 of 1 12/27J2006 8:03 AM ~~~/~. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 June 23, 2006 RE: MWD Formation Evaluation Logs: CD3-307, AK-MW-4332755 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 5 0-103 -20529-00. RECEIVED JUN 2 7 2006 ~~ (3N & Gas Cons. Commission Anchorage • 07-Jun-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD3-307 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.25' MD Window /Kickoff Survey: 12,999.34' MD (if applicable) Projected Survey: 13,030.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 r rr-- a Date? ~~ .Q~ ~D Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) o~,p to " ~`(.~ ConocoPhillips • G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Jug z June 5, 2006 pteiska D~ &. ~s Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Corrected Well Completion Report for CD3-307 (APD 206-046) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD3-307. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~~~. ~~ ~. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RE~ElVEI~ JUN 0 7 2006 WELL COMPLETION OR RECOMPLETION REPOF~~l~dil~~,Qii~ Commission 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: AtiCh0~8g@ Development ^/ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~L~ ~ ~,~ y~, orAband.: April~l, 2006 ~ Permit to Drill Number: 206-046 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 13, 2006 13. API Number: 50-103-20529-00 4a. Location of Well (Governmental Section): Surface: 3926' FNL, 797' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: April 22, 2006 14. Well Name and Number: CD3-307 • At Top Productive Horizon: 635' FSL, 657' FEL, Sec. 33, T13N, R5E, UM 8. KB Elevation (ft): 37' RKB 15. Field/Pool(s): Colville River Field Total Depth: 842' FSL, 721' FEL, Sec. 33, T13N, R5E, UM 9. Plug Back Depth (MD + ND): 13030' MD / 7044' TVD Fiord Kuparuk Oil Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388247 y- 6003847 Zone- 4 10. Total Depth (MD + ND): 13030' MD / 7044' ND 16. Property Designation: ADL 372104, 372105, 364471 TPI: x- 396362 y- 6008291 Zone- 4 Total Depth: x- 396301 ' - 6008499 ' Zone- 4 11. Depth where SSSV set: SSSV @ 2249' 17. Land Use Permit: LAS21122 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1268' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" 10 cu yds Portland Type III 9-5/8" 40# L-80 37' 3093' 37' 2479' 12.25" 385 sx Class G, 23o sx Class G 7" 26# L-80 37' 13020' 37' 7043' 8.75" 34o sx Class G 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" ! 3.5" 82' / 11680' 11632' 11762'-11799' MD 5 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production April 28, 2006 Method of Operation (Flowing, gas lift, etc.) Oil producer Date of Test flowback Hours Tested not available Production for Test Period --> OIL-BBL GAS-MCF 1040 WATER-BBL CHOKE SIZE not available GAS-OIL RATIO not available Flow Tubing press. psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". CY?fi'L~'TON • R~®IVIS ~~. JUN ~ ~ 1006 ~z~a~ ~~ NONE V n;1=9ED .~$ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~~lG~~IAL G r 2a. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD3-307 K-1 11518' 6640' Kuparuk C 11735' 6735' Nechelik 12813' 7032' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name C ' Ivord Title: Alpine Area Drillino Team Leader ~ ~~ > °~ Signature . Phone ~~~ ~~ ~~~ Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Ketly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. if none, state "None". Form 10-407 Revised 12!2003 Conoc Phi1i s ~ Time Lo Summa Wellview We6~ or[ing Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/13/2006 06:00 15:00 9.00 0 0 MIRU MOVE PSIT P Moved and Rigged up. 15:00 16:45 1.75 0 0 MIRU MOVE RURD P Nippled up riser and took on Spud Mud. Ri acce ted 1500 hrs. 16:45 18:15 1.50 0 0 MIRU DRILL PULD P Picked up 5" DP and HWDP from pipe shed and stood back in derrick. 18:15 22:30 4.25 0 114 SURFA DRILL PULD P Picked up BHA and tested MWD. Probe was bad on MWD. Changed robe and u loaded MWD. RIH to 114'. 22:30 00:00 1.50 114 162 SURFA DRILL DRLG P Drilled from 114' to 162' ADT .48 Hrs. ART .48 Hrs. AST 0 Hrs. GPM 400 PP 580 psi. WOB 5 K Up Wt. 95 K Down 95 K Rot 98 K. Torq On/Off Btm 4000/4000 FP. 1 G ro surve 80'. 04/14/2006 00:00 01:00 1.00 162 252 SURFA DRILL DRLG P Drill from 162' to 252' -run Gyro survey - MWD tool uit ulsin 01:00 03:45 2.75 252 252 SURFA DRILL OTHR NP Attempt to POOH -could not break out from Top Drive -laid down 3 singles below top drive -broke saver sub off to drive 03:45 04:00 0.25 252 70 SURFA DRILL TRIP T POOH from 252' to 70' 04:00 06:45 2.75 70 70 SURFA DRILL PULD T Plug in and trouble shoot MWD - change out pulsor and probe -initialize tools -scribe UBHO 06:45 08:00 1.25 70 70 SURFA RIGMN RGRP T Change out grabber dies - mu saver sub -service ri 08:00 08:30 0.50 70 70 SURFA DRILL TRIP T RIH from 70' to 252', no fill. 08:30 12:00 3.50 70 476 SURFA DRILL DRLG P Drill from 252' to 476' MD 476' TVD PUW 107k SOW 100k RotWt 100 450 gpm / 940 psi / 50 rpm Torque on/off btm 5000/3000 ft/Ibs ADT- 2.3 hrs ART .83 hrs AST 2.1 hrs 12:00 00:00 12.00 476 1,739 SURFA DRILL DDRL P Drill from 475' to 1,739' MD 1,680' TVD PUW 126k SOW 123k RotWt 127 650 gpm / 1800 psi / 50 rpm Torque on/off btm 8000/5500 ft/Ibs ADT- 7.69 hrs ART 3.57 hrs AST 4.12 hrs 04/15/2006 00:00 12:00 12.00 1,739 2,879 COND1 DRILL DDRL P Drill from 1,739' to 2,879' MD 2373' TVD PUW 135k SOW 120k RotWt 130 650 gpm / 2400 psi / 50 rpm Torque on/off btm 9500/7500 ft/Ibs ADT- 7.38 hrs ART 5.85 hrs AST 1.53 hrs ~~ e ___. _ F~~c~ ~f 3 ~. _ ,. 4 ._..~ Time Logs Date From To Dur th E. De th Phase Code Subcod~ OM 04/15/2006 12:00 13:45 1.75 2,879 3,103 COND1 DRILL DDRL P Drill from 2,879' to 3103' MD 2485' TVD PUW 135k SOW 123k RotWt 130 650 gpm / 2500 psi / 50 rpm Torque on/off btm 10000/7000 ft/Ibs ADT 1.72 hrs ART 1.1 hrs AST 0.62 hrs. 13:45 16:00 2.25 3,103 3,069 COND1 DRILL CIRC P Circ 2 x BU - 650 gpm / 2400 psi / 70 rpm -set back one stand to 3069' - flow check well -observed intermittent rollling in annulus - no flow observed - circ and condition mud -increase mud wt. from 10.0 to 10.2 16:00 19:45 3.75 3,069 886 SURFA DRILL WPRT P Monitor well, static for 10 min. -Wipe hole from 3069' to 886'. Backreamed with 50 RPM and 550 GPM. 19:45 21:00 1.25 886 3,103 SURFA DRILL WPRT P Checked for flow. Blew down Top drive and RIH from 886' to 3,103'. 21:00 22:30 1.50 3,103 2,879 SURFA DRILL CIRC P Circulated and conditioned mud to run casin . 22:30 23:00 0.50 2,879 3,103 SURFA DRILL TRIP P Blew down Top Drive. Flow checked well. POOH on TT 1 stand gained 1/2 Bbl. RIH to 3103'. 23:00 00:00 1.00 3,103 3,103 SURFA DRILL CIRC P CBU to check BU. Nothing observed. Flow check well dead. 04/16/2006 00:00 04:30 4.50 3,103 167 COND1 DRILL TRIP P Flow check well, static -POOH w/ pump from 3,069' to 2,594' -attempt to pull without pump -swabbing -POOH with pump from 2,594' to 1,168' - 3.5 bpm / 430 psi -hole taking proper fill - flow checked well 610' static. 04:30 07:00 2.50 167 0 COND1 DRILL PULD P Lay down jars, DC's, UBHO -down load MWD -pull pulsor -lay down TM - HCIM -DM -stab - FS -motor and bit - cleartools from ri floor 07:00 08:45 1.75 0 0 COND1 CASIN( RURD P RU to run 9 5/8" casing 08:45 09:00 0.25 0 0 COND1 CASIN( SFTY P Held Pre-job safety and Opts meeting with crew. 09:00 11:45 2.75 0 1,552 COND1 CASIN( RNCS P Run 9 5/8" 40# BTC csg as follows: FS(Silver bullet) 2 jts. csg - FC (Weatherford) 2 jts. csg (fill pipe & check floats -first 4 connections made up w/ BakerLoc) 36 jts. csg. for 40 total to 1,552' 11:45 12:15 0.50 1,552 1,552 COND1 CASIN( CIRC P Establish circ at 3.8 bpm / 210 psi - staged pumps up to 6 bpm and CBU - FCP =290 psi -PUW 130K SOW 124K 12:15 14:30 2.25 1,552 3,093 COND1 CASIN( RNCS P Continue running 9 5/8" 40# BTC csg. f/ 1,552' to 3,053'. Total jts. run 79 - MU FMC fluted hanger and LJ - Landed casing w/ shoe @ 3,093' & FC 3,014' 14:30 15:00 0.50 3,093 3,093 COND1 CASIN( RURD P Lay don fill-up tool -blow down top drive - MU cement head e®~_~ ~_ ~ ®_~_ ~__ ~.~ '~~e ~ ~~ ~ a _m~ Time Logs _ Date From To Dur th E. De th Phase Code Subcode OM 04/16/2006 15:00 16:45 1.75 3,093 3,093 COND1 CEMEI~ CIRC P Establish circ with 2 bpm / 250 psi - staged pumps up 7 bpm -circulate and condition mud for cementing - FCP 280 psi Held PJSM with Dowell and ri crew 16:45 19:00 2.25 3,093 0 SURFA CEMEf~ DISP P Cement 9 5/8" casing as follows: Pumped 40 bbls. biozan water w/ nut plug - 6 bpm @ 250 psi w/ rig pump - Switch to Dowell -Pumped 3 bbls water -test cement lines to 3000 psi - Dropped btm plug -Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.7 bpm @ 320 psi - Mixed & pumped 305 bbls of lead slurry (ASL "G" w/ 30% D-53, 0.6% DO46, 1.5% DO79, 1.5% SOO1, 43.1% D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.4 bpm @ 220 psi - switched to tail slurry 48 Bbls ("G" w/ 0.2% D46, 0.3% D65, 2% SOO1) @15.8 ppg-5.6bpm@205 psi Dropped top plug & pumped 20 bbls water w/ Dowell -Switch to rig pumps - Displaced w/ 10.1 ppg mud @ 7 bpm 340 to 560 psi for first 205 bbls - slowed to 4 bpm @ 460 psi for last 4 bbls. -Bumped plug t/ 1150 psi - CIP @ 1857 hrs, floats helds. Full returns during job wf 88.3 bbls cement returns t~ - recripcated pipe until 305 Bbls of lead slurry away, Landed ha on landin rin . 19:00 20:00 1.00 0 0 SURFA CASIN( DHEQ P Rigged up and tested casing to 2,500 si for 1/2 hour. 20:00 21:00 1.00 0 0 SURFA CASIN( RURD P Rigged down cement head, bales, casin sli sand evelators. 21:00 22:45 1.75 0 0 SURFA CASIN( NUND P Nippled down flowline and riser. 22:45 00:00 1.25 0 0 SURFA CASIN( NUND P Installed Speed head and tested seals. Ni le u BOP. 04/17/2006 00:00 01:15 1.25 0 0 SURFA WELCT NUND P Land and NU BOP stack -install bell ni le, flowline and turn buckles 01:15 06:30 5.25 0 0 SURFA WELCT BOPE P Set test plug and test BOPE: Hydril to 250 & 3500 psi - Pipe rams, Choke manifold, choke & kill line vlaves, Pipe rams,blind rams, choke manifold valves, floor safety & dart valves 250 & 5000 psi Performed accumulator closure test -John Spaulding (AOGCC) waived witnessing tests - Pull test plug and install wear bushin - blow down lines 06:30 07:00 0.50 0 0 SURFA DRILL PULD P Install drilling bails and 5" elevators - s of Geo-S an skid on ri floor 07:00 10:45 3.75 0 0 SURFA DRILL PULD P RIH -Pick up 84 joints of drill -POOH stand back i e ~~ .~~~. ®_ ~_ F~~e 3 of m~ ~~ Time Logs Date From To Dur th E. De th Phase Code Subcode OM 04/17/2006 10:45 13:45 3.00 0 1,035 SURFA DRILL PULD P RIH -Pick up 84 joints of drill -POOH stand back 11 stands 13:45 15:30 1.75 1,035 0 SURFA RIGMN RGRP T Repair air line on Top Drive grabber s stem 15:30 20:00 4.50 0 0 SURFA DRILL PULD P Picked up and stood back 5" DP. 20:00 00:00 4.00 0 106 SURFA DRILL PULD P Picked up and made up BHA. Loaded Nukes. Pulse tested MWD. 04/18/2006 00:00 01:00 1.00 106 740 COND1 DRILL PULD P Finsh MU BHA #2. Test Geospan unit to 3000 psi. PJSM. Install sources. RIH w/ BHA to 740'. 01:00 03:15 2.25 740 2,843 COND1 DRILL PULD P PU and RIH w/ 66 jts 5" DP to 2843'. 03:15 04:45 1.50 2,843 2,843 COND1 RIGMN SVRG P PJSM. Slip and cut drilling line. Service to drive. 04:45 05:15 0.50 2,843 2,990 COND1 DRILL OTHR P Wash from 2843' to TOC at 2990'. 05:15 08:45 3.50 2,990 3,123 SURFA CEMEI~ COCF P Drill out cement, float equipment and 20' new formation to 3123'. 08:45 09:15 0.50 3,123 3,123 SURFA CEMEf~ CIRC P Circulate and condition mud for FIT. 09:15 10:00 0.75 3,123 3,123 SURFA CEME~ FIT P Performed 18 ppg FIT. 10:00 12:00 2.00 3,123 3,319 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 3123' to 3319' MD 2591' TVD ADT - 1.36 hrs WOB 5/10 k RPM 100 /120 GPM 550 @ 1230 psi String wt. PU 150 SO 115 Rot 130 Torque on/off btm. - 9500/9000 ft. Ibs ECD-10.3/10.9 12:00 00:00 12.00 3,319 4,745 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 3319' to 4745' MD 3327' TVD ADT - 8.26 hrs WOB 5/14 k RPM 100 /120 GPM 600 @ 1900 psi String wt. PU 160 SO 125 Rot 135 Torque on/off btm. - 11000/8000 ft. lbs. ECD-10.8/11.2 04/19/2006 00:00 12:00 12.00 4,745 6,200 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 4745' to 6200' MD 4031' TVD ADT - 7.35 hrs WOB 8/15 k RPM 150 GPM 650 @ 2280 psi String wt. PU 180 SO 130 Rot 155 Torque on/off btm. - 12000/11500 ft. lbs. ECD-10.9/11.2 12:00 00:00 12.00 6,200 7,840 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 6200' to 7840' MD 4814' TVD ADT - 7.8 hrs WOB 8/18 k RPM 150 GPM 650 @ 2500 psi String wt. PU 198 SO 135 Rot 162 Torque on/off btm. - 14000/12000 ft. lbs. ECD-11/11.2 .~.. ~.. ~._._. ~._.. ~ mM._.,. ~~ ~ c~~ ~ Time Los .Date. From To Dur th E. De th Phase Code Subcode IGOM 04/20/2006 00:00 12:00 12.00 7,840 9,314 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 7840' to 9314' MD 5528' TVD ADT - 7.35 hrs WOB 15/23 k RPM 150 GPM 650 @ 2530 psi String wt. PU 215 SO 150 Rot 183 Torque on/off btm. - 16500/16000 ft. lbs. ECD-11/11.2 12:00 00:00 12.00 9,314 10,742 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 9314' to 10742' MD 6257' TVD ADT - 8.93 hrs WOB 15/23 k RPM 150 GPM 650 @ 2520 psi String wt. PU 280 SO 150 Rot 195 Torque on/off btm. - 20000/19000 ft. lbs. ECD-11/11.2 04/21/2006 00:00 11:30 11.50 10,742 11,694 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 10,742' to 11,694' MD 6718' TVD ADT - 8.08 hrs WOB 18/26 k RPM 150/80 GPM 650/473 @ 2520/1580 psi String wt. PU 250 SO 165 Rot 205 Torque on/off btm. - 19,000/18,500 ft. lbs. ECD-10.6/11.1 11:30 12:00 0.50 11,694 11,694 INTRM1 RIGMN SVRG P Service rig. 12:00 00:00 12.00 11,694 12,530 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 11,694' to 12,530' MD 6987' TVD ADT - 9.58 hrs WOB 20/26 k RPM 80 GPM 473 @ 1690 psi String wt. PU 265 SO 165 Rot 207 Torque on/off btm. - 20,000/17,500 ft. lbs. ECD-10.4/11 04/22/2006 00:00 07:45 7.75 12,530 13,030 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 12,530' to 13,030' MD 7044 TVD ADT - 6.5 hrs WOB 20/25 k RPM 80/120 GPM 474 @ 1650 psi String wt. PU 270 SO 150 Rot 205 Torque on/off btm. - 21,500/20,000 ft. lbs. ECD-10.3/10.5 07:45 10:15 2.50 13,030 12,645 INTRM1 DRILL CIRC P Pump sweep. CBU 2X at 550 gpm - 2090 psi - 120 rpms. Stand back 1 std eve 30 min. 10:15 13:30 3.25 12,645 10,932 INTRM1 DRILL WPRT P POH w/ pump from 12,645' to 10,932' at 550 gpm - 1970 psi - 70 rpms. Check flow. OK. 13:30 14:30 1.00 10,932 12,930 INTRM1 DRILL WPRT P RIH w/ 5" DP from 10,932' to 12,930'. No hole roblems. ® ~ ®.~_.. e- ~_ ~~~ __. _ ~ - ~__ ~ _._ _ ~_ ~~ge ~ ~t ~ ..Time Lo s Date From To Dur th E. De th Phase Code Subcode OM _ 04/22/2006 14:30 17:30 3.00 12,930 13,030 INTRM1 DRILL CIRC P Break circ. Wash from 12,930' to 13,030'. Pump sweep. CBU 2X at 550 gpm -2040 psi - 120 rpms. Stand back 1 std eve 30 min. 17:30 20:30 3.00 12,930 10,932 INTRM1 DRILL WPRT P POH w/ pump from 12,645' to 10,932' at 550 gpm - 1970 psi - 70 rpms. Check flow. OK. 20:30 21:30 1.00 10,932 13,030 INTRM1 DRILL WPRT P RIH w/ 5" DP from 10,932' to 12,930'. No hole roblems. 21:30 23:30 2.00 13,030 13,030 INTRM1 DRILL CIRC P Pumped sweep and circulated hole clean. Raised MW to 9.8 PPG. 23:30 00:00 0.50 12,930 12,550 INTRM1 DRILL TRIP P POOH with pump at 3 BPM spotting HSP and casing running pill from 13,026' to 12,550'. 04/23/2006 00:00 01:45 1.75 12,550 11,028 INTRM1 DRILL TRIP P POH spotting tube pill from 12,550' to 11,028' at 3 bpm. Check flow. OK. Blow down to drive. 01:45 03:00 1.25 11,028 10,075 INTRM1 DRILL TRIP P POH on trip tank from 11,028'to 10,075'. 03:00 03:30 0.50 10,075 10,075 INTRM1 DRILL OTHR P Check flow. OK. Pump dry job. Blow down to drive. 03:30 11:15 7.75 10,075 198 INTRMI DRILL TRIP P POH f/ 10,075' to 198'. Flow check at shoe and 740'. OK. 11:15 15:00 3.75 198 0 INTRM1 DRILL PULD P LD BHA #2. Remove sources. Download MWD. LD Geo ilot and bit. 15:00 17:30 2.50 0 0 INTRM1 CASIN( NUND P Cleared floor and changed rams from VBR to 7". Set test plug and tested rams. 17:30 19:00 1.50 0 0 INTRM1 CASIN( RURD P Rigged up casing tools. 19:00 22:30 3.50 0 2,997 INTRM1 CASIN( RNCS P PJSM. Picked up and ran 70 Jts of 7" 26# L 80 BTCM casin to 2,997'. 22:30 23:00 0.50 2,997 2,997 INTRM1 CASIN( CIRC P Broke circulation and circulated one casing volume @ 4 BPM. ICP 250 psi FCP 200 si. 23:00 00:00 1.00 2,997 3,890 INTRM1 CASIN( RNCS P Picked up and ran 22 Jts of 7" 26# L 80 BTCM casin to 3,890'. 04/24/2006 00:00 02:30 2.50 3,890 7,037 INTRM1 CASIN( RNCS P RIH w/ 7" csg from 3890' to 7037'. 02:30 03:45 1.25 7,037 7,037 INTRM1 CASIN( CIRC P CBU. Stage pumps up to 5 bpm at 410 si. 03:45 07:30 3.75 7,037 10,887 INTRM1 CASIN( RNCS P RIH w/ 7" csg from 7037' to 10,887'. 07:30 09:30 2.00 10,887 10,887 INTRM1 CASIN( CIRC P CBU. Stage pumps up to 4.5 bpm at 450 si. 09:30 12:30 3.00 10,887 13,020 INTRM1 CASIN( RNCS P RIH w/ 7" csg from 10,887' to 12,980'. MU hanger and landing jt. Land csg at 13, 020'. 12:30 13:00 0.50 13,020 13,020 INTRM1 CASIN( RURD P RD Franks fill up tool. Install cement head. 13:00 15:30 2.50 13,020 13,020 INTRMI CEME~ CIRC P Circ and condition mud. Stage pump from 2/4.5 b mat ~---- ~ ~_, -~ -~°-- -- _ ~, ~e ~ r ®v. ~~ ~ ?______. .~~_ ~~ Time.. Logs _ Date From To Dur .. pth E. De th Phase Code Subcod~ lCCM 04/24/2006 15:30 18:00 2.50 13,020 0 INTRM1 CEMEf~ DISP P Cement 7" casing as follows: Pumped 5 bbls CW-100 -Test lines to 3600 psi -Pumped 20 bbls CW-100 -Mixed & pumped 30 bbls 10.5 ppg MudPush @ 5.2 BPM @ 530 psi - Dropped btm plug -Mixed & pumped 70 bbls (340 sxs Class G w/additives) @ 15.8 ppg tail slurry @ 5.2 BPM @ 500 psi - Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced cmt w/ 475 bbls 9.6 ppg Brine @ 7 BPM -Slowed pumps to 3.5 BPM for last 9 bbls of dispalcement - Bumped plug w/ 1080 psi (pre bump pressure 550 psi) CIP @ 1741 hrs. - Check floats (held OK) Full circulation throu hout 'ob. 18:00 19:00 1.00 0 0 INTRM1 CASIN( DHEQ P Rigged up and tested casing to 3500 si for 30 minutes. OK. 19:00 19:30 0.50 0 0 INTRM1 CASIN( RURD P Laid down landing and cement head. 19:30 20:30 1.00 0 0 INTRM1 CASIN( DHEQ P Ran and tested packoff. Laid down landin 't . 20:30 22:30 2.00 0 0 INTRM1 WELCT BOPE P Changed 7" rams to VBR and tested rams. 22:30 00:00 1.50 0 118 INTRM1 RPCOh RCST P PJSM. Picked up TCP guns a ran com letion to 118'. 04/25/2006 00:00 09:00 9.00 118 9,492 INTRM1 RPCOh RCST P Continue RIH w/ 3 1/2" completion equipment from118' to 9492'. Total of 304 'ts. 09:00 10:00 1.00 9,492 9,492 INTRM1 RPCOh PULD P MU Camco SSSV. Attach control line and test to 5000 si. 10:00 12:30 2.50 9,492 10,769 INTRM1 RPCOh RCST P RIH w/ 40 jts 3 1/2" tbg to 10,769' attaching control line bands. Lost ressure on control line. 12:30 15:30 3.00 10,769 9,529 INTRM1 RPCOh RCST T PJSM. RU and POH with 40 jts 3 1/2" tbg to 9529'. Located hole in control line 3 'ts above SSSV. 15:30 17:00 1.50 9,529 9,529 INTRM1 RPCOti OTHR T PJSM. Change out control spools. Test line to 5000 si. Function valve. 17:00 18:30 1.50 9,529 10,769 INTRM1 RPCOCV RCST T RIH w/ 3 1/2" tbg from derrick from 9529' to 10,769'. 18:30 20:00 1.50 10,769 11,606 INTRM1 RPCOh RCST P RIH w/ 3 1/2" tbg from pipe shed from 10,769' to 11,606'. Attach 1 control line band er 't. 20:00 20:30 0.50 11,606 11,606 INTRM1 RPCOh RURD P RDtbgequipment.Clearfloorforwire line. 20:30 20:45 0.25 11,606 11,606 INTRM1 EVALVI~ SFTY P PJSM on run WL log. 20:45 23:00 2.25 11,606 11,606 INTRM1 EVALV\ ELOG P RU and RIH w/ 1 11/16" GR tool. Run correlation log from 11,400' to 10,800'. POH. RD WL. 23:00 00:00 1.00 11,606 11,727 INTRM1 RPCOti RCST P RU tbg equipment. RIH w/ 1 jt 3 1/2" tb , xo, 2' u and 2 'ts of 4 1/2" tb . ~~ r_ ®..~ ~ - - ~~ ~' ~f ~ _Time Logs :Date From To Dur th E. De th Phase Code Subcode OM 04/26/2006 00:00 01:00 1.00 11,762 11,800 INTRM1 RPCOh RCST P MU FMC tbg hanger--Attach control line through hanger & test connections to 5000 psi -Land completion string w/ tbg tail @ 11,799.85' -pert guns f/ 11,799.85' to 11,742.42' - XN @ 11,678.70' -packer @ 11,631.83' - RA tag @ 11,561.02' - X nipple @ 11,559.91' -GLM @ 11,482.09' -GLM 6931.85' - SSSV 2249.19' 01:00 01:45 0.75 11,800 11,800 INTRM1 RPCOh DHEQ P RI lock downs -Install TWC - LD landing jt A - MU landing jt. B -Test tbg hanger seals to 5000 psi - LD landin 't B 01:45 02:15 0.50 11,800 11,800 INTRM1 RPCOti OTHR P LD tbg running equipment & clean up ri floor 02:15 03:45 1.50 11,800 11,800 INTRM1 RPCOh NUND P ND -flow line -bell nipple -BOP stack 03:45 05:00 1.25 11,780 11,800 INTRM1 RPCOCV OTHR P Termiate control line through wellhead & test line 05:00 07:00 2.00 11,800 11,800 INTRM1 RPCOh NUND P NU tree & test to 5000 psi - RU & test FMC lubricator & test to 5000 si 07:00 07:30 0.50 11,800 11,800 INTRM1 RPCOh OTHR P Pull TWC & LD lubricator 07:30 10:45 3.25 11,800 11,800 INTRM1 RPCOh CIRC P RU hard lines to wellhead & squeeze maniflod on floor for displacement - Held PJSM -Pumped 5 bbls water - test lines to 200 psi -pumped 235 bbl 9.4 ppg inhibited brine followed by 143 bbls diesel 10:45 14:00 3.25 11,800 11,800 INTRM1 RPCOb PACK P RU lubricator & drop packer setting rod/ball assembly -Retest lines to 5000 psi -Pressure up tbg to 4900 psi to set packer & test tbg for 30 mins.- bleed off tbg to 600 psi -Pressure up on annulus to 3500 pis & test for 30 mins. -bleed off annulus & tbg to 0 psi - shut in well -blow down lines & RD lines & s ueeze manifold 14:00 14:30 0.50 11,800 11,800 INTRM1 RPCOh OTHR P Remove outside annulus valves - Secure well 14:30 16:30 2.00 11,800 11,800 INTRM1 RPCOh OTHR P PJSM -Install mouse hole - LD 5" drill i e f/derrick via mouse hole 16:30 17:00 0.50 11,800 11,800 INTRM1 RIGMN SVRG P Rig service 17:00 20:30 3.50 11,800 11,800 INTRMI RPCOh OTHR P Continue LD 5" DP 20:30 00:00 3.50 11,800 11,800 INTRM1 RIGMN RGRP T Repair pipe skate 04/27/2006 00:00 10:00 10.00 11,800 INTRM1 RPCOh OTHR Finish laying down 5" DP f/derrick - pull mouse hole -Release rig @ 10:00 hrs. ~ ~----- ® _~ r Cage 3 of ~ i .~.~.. ..~~ _ m ~~1 • CD3-307 Daily Operations Summary • DATE Summary Operations 04/27/06 PULL BALL & ROD @ 11678' RKB, PULL RHC PLUG BODY FROM SAME. WELL READY FOR FLOWBACK. 04/28/06 E-Fired 4.5" PJ Omega's 5 SPF 72 degree phased guns in the Kuparuk sands using pressure pulses from the surface. Flowed a total of 90 BBLS to tanks; discontinued flowback once dark wellbore fluids to surface. Freeze protected with 25 bbls diesel. 04/30/06 WELL SECURE, FMC SET BPV • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Uate: 5/17/2006 Time: 08:52:09 Pagc: 1 Field: Goiville River Unit Co-ordinate(NE) Reference: Well: CD3-307, True North - Site: Alpine CD3 Vertical (TVD) Refer ence: CD3-307: 49.6 Well: CD3-307 Section (VS) Reference:. Well (O.OON,O OOE, 59.13Azi) Wellpath: CD3-307 Survc~ C'atculationM ethod: Minimum Curvature ~ Db: Oracle Field: Colville River Unit ~ North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: CD3-307 Slot Name: Alpine CD3-107 Well Position: +N/-S -43.21 ft Northing : 6003847.19 ft ' Latitude: 70 25 10.056 N +E/-W -240.49 ft Easting : 388247.02 ft Longitude: 150 54 37.443 W Position Uncertainty: 0.00 ft Wellpath: CD3-307 Drilled From: Well Ref. Point 501032052900 Tie-on Depth: 36.25 ft Current Datum: CD3-307: Height 49.55 ft Above System Da tum: Mean Sea Level Magnetic Data: 4/13/2006 Declination: 23.46 deg i. Field Strength: 57514 nT Mag Dip Angle: 80.72 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direc tion ft ft ft deg 36.25 0.00 0.00 59.13 Survey Program for Definitive Wellpath Date: 4/22/2006 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name j ft ft 80.00 438.00 CD3-307 gyro (80.00-438.00) CB-GYRO-SS Camera based gyro single shot 475.12 12999.34 CD3-307 (475.12-12999.34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey - MU lncl Azim T'~D . Sys TVD N!S E/VV NIapN A9apE "fool ft deg deg ft ft ft ft __ ft __ ft __ ', _ __' ', 36.25 0.00 0.00 36.25 -13.30 0.00 0.00 6003847.19 388247.02 TIE LINE 80.00 0.60 105.00 80.00 30.45 -0.06 0.22 6003847.13 388247.24 CB-GYRO-SS ~~, 166.00 0.65 118.00 165.99 116.44 -0.40 1.09 6003846.77 388248.10 CB-GYRO-SS 'i 'i 258.00 0.80 139.00 257.99 208.44 -1.13 1.97 6003846.03 388248.97 CB-GYRO-SS '~ 348.00 1.30 120.00 347.97 298.42 -2.12 3.27 6003845.02 388250.25 CB-GYRO-SS ' 438.00 1.75 109.00 437.94 388.39 -3.08 5.45 6003844.03 388252.42 CB-GYRO-SS 475.12 1.82 103.04 475.04 425.49 -3.39 6.56 6003843.70 388253.52 MWD+IFR-AK-CAZ-SC 564.76 3.24 99.39 564.59 515.04 -4.13 10.45 6003842.91 388257.40 MWD+IFR-AK-CAZ-SC 656.84 5.80 104.30 656.38 606.83 -5.70 17.52 6003841.23 388264.45 MWD+IFR-AK-CAZ-SC it 746.72 7.18 105.72 745.68 696.13 -8.35 27.33 6003838.44 388274.22 MWD+IFR-AK-CAZ-SC 'i j 836.60 9.06 103.89 834.66 785.11 -11.57 39.61 6003835.03 388286.44 MWD+IFR-AK-CAZ-SC ~~ ', 931.87 10.61 93.69 928.53 878.98 -13.93 55.64 6003832.43 388302.44 MWD+IFR-AK-CAZ-SC 1027.72 12.77 90.94 1022.39 972.84 -14.68 75.04 6003831.39 388321.83 MWD+IFR-AK-CAZ-SC ~, 1123.01 17.26 87.60 1114.40 1064.85 -14.26 99.71 6003831.44 388346.49 MWD+IFR-AK-CAZ-SC 1216.57 20.95 83.21 1202.80 1153.25 -11.70 130.20 6003833.55 388377.02 MWD+IFR-AK-CAZ-SC i ~I 1311.62 23.33 82.25 1290.83 1241.28 -7.15 165.73 6003837.56 388412.60 MWD+IFR-AK-CAZ-SC ~ 1406.83 29.03 77.18 1376.25 1326.70 0.53 206.97 6003844.62 388453.96 MWD+IFR-AK-CAZ-SC I 1502.50 34.77 74.48 1457.44 1407.89 12.99 255.94 6003856.34 388503.10 MWD+IFR-AK-CAZ-SC i 1597.44 36.98 74.21 1534.37 1484.82 28.00 309.50 6003870.56 388556.88 MWD+IFR-AK-CAZ-SC ii 1693.20 38.65 74.12 1610.01 1560.46 44.03 365.99 6003885.73 388613.59 MWD+IFR-AK-CAZ-SC 1788.29 38.86 75.22 1684.17 1634.62 59.76 423.39 6003900.60 388671.22 MWD+IFR-AK-CAZ-SC ', I 1883.72 39.38 74.20 1758.21 1708.66 75.64 481.47 6003915.61 388729.52 MWD+IFR-AK-CAZ-SC '' 1979.23 40.01 72.87 1831.70 1782.15 92.93 539.97 6003932.02 388788.27 MWD+IFR-AK-CAZ-SC II 2074.78 43.25 68.37 1903.12 1853.57 114.06 599.78 6003952.25 388848.38 MWD+IFR-AK-CAZ-SC 2170.04 44.40 68.74 1971.85 1922.30 138.17 661.17 6003975.44 388910.13 MWD+IFR-AK-CAZ-SC 2265.11 49.04 68.61 2037.01 1987.46 163.34 725.63 6003999.63 388974.95 MWD+IFR-AK-CAZ-SC '. 2359.98 51.97 68.13 2097.34 2047.79 190.33 793.67 6004025.60 389043.38 MWD+IFR-AK-CAZ-SC ', 2455.13 54.76 67.21 2154.11 2104.56 219.34 864.29 6004053.55 389114.42 MWD+IFR-AK-CAZ-SC '', 2549.58 56.39 66.83 2207.51 2157.96 249.76 936.01 6004082.89 389186.58 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 5/17/2006 Time: 08 :52.09 Page: 2 Field: Colville River Unit Co-ord inatc(NE) Reference: Well`. CD3-307; True North Site: Alpi ne CD3 Vertica l (TVD) Reference: CD3-307.49.6 Well: CD3-307 Section (VS) Refere nce: Well (O.OON,O. OOE,59.13Azi) ~Vellpath: CD3 -307 Survey Calculation ~1etP~od: Minimum Curv ature llb: Oracle Survcv hID Incl Azim TVD Sys TVD \/S E/~V NIapN iV[apE 'fool ft deg deg ft ft ft ft ft ft 2644. 62 59. 07 68. 24 2258 .25 2208. 70 280.45 1010.27 6004112 .46 389261. 28 MWD+IFR-AK-CAZ-SC II 2739. 91 60. 50 69. 58 2306 .20 2256. 65 310.07 1087.09 6004140 .93 389338. 54 MWD+IFR-AK-CAZ-SC !i 2834. ! 23 61. 70 71. 75 2351. 79 2302. 24 337.40 1165.01 6004167 .08 389416. 84 MWD+IFR-AK-CAZ-SC I ! 2928. 09 59. 93 69. 99 2397. 56 2348. 01 364.24 1242.42 6004192 .76 389494. 64 MWD+IFR-AK-CAZ-SC ! 3023. 45 60. 59 66. 65 2444. 87 2395. 32 394.83 1319.34 6004222 .19 389572. 01 MWD+IFR-AK-CAZ-SC ! ~, 3057. I 25 60. 61 66. 32 2461. 46 2411. 91 406.58 1346.35 6004233 .54 389599. 18 MWD+IFR-AK-CAZ-SCI ! 3102. 03 60. 83 65. 66 2483. 37 2433. 82 422.47 1382.02 6004248 .89 389635. 09 MWD+IFR-AK-CAZ-SC 3197. 19 60. 35 66. 71 2530. 10 2480. 55 455.95 1457.86 6004281 .22 389711. 41 MWD+IFR-AK-CAZ-SC 3291. 36 59. 98 66. 98 2576. 95 2527. 40 488.07 1532.97 6004312 .21 389786. 99 MWD+IFR-AK-CAZ-SC i 3385. 88 60. 26 67. 06 2624. 03 2574. 48 520.06 1608.42 6004343 .07 389862. 90 MWD+IFR-AK-CAZ-SC 3481. 94 61. 24 67. 11 2670. 97 2621. 42 552.70 1685.62 6004374 .54 389940. 57 MWD+IFR-AK-CAZ-SC 3576. 55 60. 37 67. 86 2717. 12 2667. 57 584.32 1761.91 6004405 .02 390017. 32 MWD+IFR-AK-CAZ-SC 3671. 82 59. 14 68. 62 2765. 11 2715. 56 614.84 1838.34 6004434 .39 390094. 20 MWD+IFR-AK-CAZ-SC 3766. 95 60. 24 68. 20 2813. 12 2763. 57 645.06 1914.71 6004463 .46 390171. 00 MWD+IFR-AK-CAZ-SC 3862. 05 59. 37 68. 59 2860. 95 2811. 40 675.32 1991.13 6004492 .57 390247. 86 MWD+IFR-AK-CAZ-SC 3956. 89 58. 45 69. 05 2909. 92 2860. 37 704.67 2066.86 6004520 .78 390324. 01 MWD+IFR-AK-CAZ-SC '~ 4053. 08 58. 39 69. 93 2960. 29 2910. 74 733.38 2143.61 6004548 .34 390401. 18 MWD+IFR-AK-CAZ-SC ' 4146. 85 57. 74 70. 69 3009. 89 2960. 34 760.19 2218.53 6004574 :02 390476. 48 MWD+IFR-AK-CAZ-SC ~ 4243. 51 57. 03 70. 83 3061. 99 3012. 44 787.02 2295.40 6004599 .70 390553. 74 MWD+IFR-AK-CAZ-SC 4338. 61 56. 72 70. 83 3113. 96 3064. 41 813.18 2370.63 6004624 .72 390629. 35 MWD+IFR-AK-CAZ-SC 4433. 98 57. 22 71. 79 3165. 95 3116. 40 838.79 2446.37 6004649 .20 390705. 45 MWD+IFR-AK-CAZ-SC ' I 4528. 44 58. 47 72. 58 3216. 22 3166. 67 863.26 2522.50 6004672 .52 390781. 94 MWD+IFR-AK-CAZ-SC 4623. 91 59. 09 73. 03 3265. 70 3216. 15 887.39 2600.50 6004695 .48 390860. 28 MWD+IFR-AK-CAZ-SC ~ 4719. 01 59. 06 73. 49 3314. 58 3265. 03 910.89 2678.62 6004717 .80 390938. 74 MWD+IFR-AK-CAZ-SC 4814. 75 59. 98 73. 70 3363. 14 3313. 59 934.19 2757.77 6004739 .92 391018. 22 MWD+IFR-AK-CAZ-SC 4909. 70 60. 46 73. 64 3410. 30 3360. 75 957.36 2836.85 6004761 .90 391097. 64 MWD+IFR-AK-CAZ-SC 5004. 66 61. 48 73. 13 3456. 38 3406. 83 981.11 2916.41 6004784 .45 391177. 54 MWD+IFR-AK-CAZ-SC ii I 5100. 44 63. 07 72. 09 3500. 94 3451. 39 1006.45 2997.32 6004808 .57 391258. 81 MWD+IFR-AK-CAZ-SC 5194. 48 63. 56 71. 77 3543. 17 3493. 62 1032.51 3077.20 6004833 .43 391339. 06 MWD+IFR-AK-CAZ-SC ! 5289. 80 63. 85 70. 35 3585. 40 3535. 85 1060.25 3158.02 6004859 .96 391420. 29 MWD+IFR-AK-CAZ-SC ! 5384. 75 64. 25 68. 37 3626. 95 3577. 40 1090.34 3237.91 6004888 .85 391500. 61 MWD+IFR-AK-CAZ-SC ~ 5480. 02 63. 62 68. 13 3668. 81 3619. 26 1122.06 3317.40 6004919 .37 391580. 56 MWD+IFR-AK-CAZ-SC 5575. 50 62. 25 67. 78 3712. 25 3662. 70 1153.97 3396.21 6004950 .09 391659. 83 MWD+IFR-AK-CAZ-SC 5670. 50 61. 12 67. 98 3757. 31 3707. 76 1185.46 3473.68 6004980 .42 391737. 76 MWD+IFR-AK-CAZ-SC 5765. 96 60. 42 68. 02 3803. 93 3754. 38 1216.67 3550.92 6005010 .46 391815. 45 MWD+IFR-AK-CAZ-SC 5861. 31 59. 14 66. 83 3851. 92 3802. 37 1248.29 3627.00 6005040 .94 391891. 98 MWD+IFR-AK-CAZ-SC ~!, 5956. 48 58. 62 66. 79 3901. 11 3851. 56 1280.37 3701.89 6005071 .89 391967. 34 MWD+IFR-AK-CAZ-SC 6051. ~ 71 57. 91 66. 00 3951. 20 3901. 65 1312.80 3776.10 6005103 .21 392042. 03 MWD+IFR-AK-CAZ-SC I 6146. 74 57. 31 66. 71 4002. 10 3952. 55 1344.99 3849.61 6005134 .28 392116. 00 MWD+IFR-AK-CAZ-SC ! 6241. 81 57. 39 66. 91 4053. 39 4003. 84 1376.51 3923.19 6005164 .70 392190. 04 MWD+IFR-AK-CAZ-SC ! 6337. 40 57. 24 68. 09 4105. 01 4055. 46 1407.29 3997.52 6005194 .37 392264. 81 MWD+IFR-AK-CAZ-SC 6432. 27 57. 09 68. 15 4156. 45 4106. 90 1437.00 4071.49 6005222 .96 392339. 21 MWD+IFR-AK-CAZ-SC ! 6527. 07 57. 48 69. 73 4207. 69 4158. 14 1465.66 4145.92 6005250 .50 392414. 06 MWD+IFR-AK-CAZ-SC 6622. 44 58. 89 69. 46 4257. 97 4208. 42 1493.91 4221.87 6005277 .61 392490. 42 MWD+IFR-AK-CAZ-SC !! 6717. 49 60. 87 68. 02 4305. 67 4256. 12 1523.73 4298.48 6005306 .28 392567. 46 MWD+IFR-AK-CAZ-SC 6812. 76 61. 27 67. 58 4351. 75 4302. 20 1555.24 4375.68 6005336 .62 392645. 11 MWD+IFR-AK-CAZ-SC 6908. 33 60. 93 68. 21 4397. 94 4348. 39 1586.72 4453.20 6005366 .94 392723. 09 MWD+IFR-AK-CAZ-SC 7002. 63 62. 31 68. 15 4442. 76 4393. 21 1617.56 4530.22 6005396 .62 392800. 55 MWD+IFR-AK-CAZ-SC 7098. 21 63. 23 67. 71 4486. 49 4436. 94 1649.49 4608.98 6005427 .37 392879. 78 MWD+IFR-AK-CAZ-SC 7192. 19 63. 43 65. 81 4528. 68 4479. 13 1682.63 4686.14 6005459 .34 392957. 42 MWD+IFR-AK-CAZ-SC 7287. 96 63. 51 64. 65 4571. 46 4521. 91 1718.53 4763.94 6005494 .07 393035. 74 MWD+IFR-AK-CAZ-SC '! !, 7382. 05 63. 90 63. 29 4613. 14 4563. 59 1755.55 4839.74 6005529 .95 393112. 07 MWD+IFR-AK-CAZ-SC 1 Halliburton Company Survey Report ' Company: ConocoPhillips Alaska Inc. llate: 5/17!2006 Time: 08:52:09 Page: 3 Field: Go iville River Unit Co-ordinate(NE) Reference: Well : CD3-307, True North Site: Alpine CD3 Vertical (TVD) Reference: CD3 -307: 49.6 Well: CD3-307 Se ction (V5) Reference: Well (O.OON,O. OOE,59.13Azi) ' «cllpath: CD3-307 Survey Calculation Method: Minimum Curvature Db: Oracle Survey __ __ MD Inc! Azim TVI) Sys TVD N/S E/VV D1apl\ MapE Tool ft deg deg ft ft ft ft ft ft ' 7478.62 63. 98 63. 00 4655 .57 4606. 02 1794. 74 4917.13 6005567. 97 393190. 04 MWD+IFR-AK-CAZ-SC ' 7573.60 64. 06 62. 51 4697 .17 4647. 62 1833. 83 4993.04 6005605. 91 393266. 52 MWD+IFR-AK-CAZ-SC 7668.99 64. 11 62. 50 4738 .86 4689. 31 1873. 44 5069.15 6005644. 37 393343. 20 MWD+IFR-AK-CAZ-SC 7764.62 63. 77 62. 62 4780 .87 4731. 32 1913. 02 5145.39 6005682. 81 393420. 02 MWD+IFR-AK-CAZ-SC 7859.85 62. 59 63. 70 4823 .84 4774. 29 1951. 40 5221.22 6005720. 04 393496. 41 MWD+IFR-AK-CAZ-SC 7955.11 61 .76 64. 83 4868 .31 4818. 76 1987. 98 5297.10 6005755. 48 393572. 83 MWD+IFR-AK-CAZ-SC 8050.19 61 .28 66. 73 4913 .65 4864. 10 2022. 27 5373.31 6005788. 62 393649. 54 MWD+IFR-AK-CAZ-SC 8145.12 61 .03 67. 77 4959 .45 4909. 90 2054. 42 5449.99 6005819. 62 393726. 68 MWD+IFR-AK-CAZ-SC ; ' 8240.42 60 .91 67. 03 5005 .69 4956. 14 2086. 44 5526.92 6005850. 49 393804. 08 MWD+IFR-AK-CAZ-SC 8335.34 60. 70 67. 36 5051 .99 5002. 44 2118. 56 5603.31 6005881. 45 393880. 93 MWD+IFR-AK-CAZ-SC ~ 8430.48 60. 72 69. 68 5098 .54 5048. 99 2148. 94 5680.51 6005910. 67 393958. 57 MWD+IFR-AK-CAZ-SC 8525.82 60. 42 69. 04 5145 .39 5095. 84 2178. 21 5758.22 6005938. 77 394036. 70 MWD+IFR-AK-CAZ-SC 8620.54 60. 70 68. 69 5191 .95 5142. 40 2207. 95 5835.16 6005967. 36 394114. 07 MWD+IFR-AK-CAZ-SC 8715.73 60. 78 69. 09 5238 .47 5188. 92 2237. 86 5912.63 6005996. 10 394191. 97 MWD+IFR-AK-CAZ-SC 8811.09 61. 34 69. 65 5284 .62 5235. 07 2267. 26 5990.73 6006024. 33 394270. 50 MWD+IFR-AK-CAZ-SC 8906.01 61. 55 71. 50 5329 .99 5280. 44 2294. 99 6069.35 6006050. 87 394349. 52 MWD+IFR-AK-CAZ-SC 9001.39 61 .49 70. 55 5375 .48 5325. 93 2322. 25 6148.63 6006076. 94 394429. 20 MWD+IFR-AK-CAZ-SC 9096.42 60 .70 70. 69 5421 .41 5371. 86 2349. 85 6227.11 6006103. 36 394508. 07 MWD+IFR-AK-CAZ-SC 'I 9191.33 60 .52 70. 51 5467 .99 5418. 44 2377. 32 6305.11 6006129. 66 394586. 47 MWD+IFR-AK-CAZ-SC ! . 9286.80 60. 12 70. 38 5515 .26 5465. 71 2405. 08 6383.27 6006156. 25 394665. 03 MWD+IFR-AK-CAZ-SC 9381.93 59. 98 71. 31 5562 .75 5513. 20 2432. 13 6461.13 6006182. 12 394743. 28 MWD+IFR-AK-CAZ-SC I 9476.89 60. 41 73. 62 5609 .96 5560. 41 2456. 95 6539.70 6006205. 76 394822. 20 MWD+IFR-AK-CAZ-SC j 9572.14 60. 55 72. 26 5656 .89 5607. 34 2481. 27 6618.93 6006228. 89 394901. 78 MWD+IFR-AK-CAZ-SC ~ 9667.54 60. 13 70. 92 5704 .10 5654. 55 2507. 44 6697.59 6006253. 88 394980. 81 MWD+IFR-AK-CAZ-SC 9762.94 59. 51 69. 30 5752 .06 5702. 51 2535. 50 6775.13 6006280. 77 .395058. 76 MWD+IFR-AK-CAZ-SC 9858.42 58. 61 68. 68 5801 .15 5751. 60 2564. 86 6851.58 6006308. 98 395135. 63 MWD+IFR-AK-CAZ-SC 9952.71 58 .71 67. 81 5850 .19 5800. 64 2594. 70 6926.38 6006337. 70 395210. 86 MWD+IFR-AK-CAZ-SC 10048.20 57 .88 67. 63 5900 .38 5850. 83 2625. 50 7001.55 6006367. 37 395286. 48 MWD+IFR-AK-CAZ-SC ~I 10143.08 57 .40 67. 52 5951 .16 5901. 61 2656. 08 7075.63 6006396. 82 395361. 01 MWD+IFR-AK-CAZ-SC i 10238.23 57. 16 68. 06 6002 .59 5953. 04 2686. 34 7149.75 6006425. 97 395435. 56 MWD+IFR-AK-CAZ-SC ' ~ 10333.75 57. 90 68. 77 6053 .87 6004. 32 2715. 98 7224.68 6006454. 49 395510. 92 MWD+IFR-AK-CAZ-SC ! . 10428.95 58. 92 66. 75 6103 .75 6054. 20 2746. 68 7299.73 6006484. 05 395586. 42 MWD+IFR-AK-CAZ-SC 10525.16 59. 84 64. 10 6152 .76 6103. 21 2781. 11 7375.01 6006517. 36 395662. 20 MWD+IFR-AK-CAZ-SC j I~ 10620.06 60. 93 60. 56 6199 .66 6150. 11 2819. 43 7448.06 6006554. 57 395735. 80 MWD+IFR-AK-CAZ-SC 'I 10715.44 60. 85 57. 42 6246 .07 6196. 52 2862. 35 7519.46 6006596. 42 395807. 84 MWD+IFR-AK-CAZ-SC 10809.83 60. 21 54. 83 6292 .52 6242. 97 2908. 15 7587.69 6006641. 18 395876. 73 MWD+IFR-AK-CAZ-SC ' 10906.01 59. 40 50. 83 6340 .90 6291. 35 2958. 35 7653.92 6006690. 38 395943. 70 MWD+IFR-AK-CAZ-SC 11001.61 59 .13 47. 74 6389 .77 6340. 22 3011. 93 7716.19 6006743. 02 396006. 76 MWD+IFR-AK-CAZ-SC 11096.71 59 .71 44. 07 6438 .16 6388. 61 3068. 90 7774.97 6006799. 09 396066. 39 MWD+IFR-AK-CAZ-SC ;~ 11191.87 60. 49 41. 06 6485 .61 6436. 06 3129. 65 7830.75 6006859. 00 396123. 07 MWD+IFR-AK-CAZ-SC i !~ 11287.11 62. 02 37. 30 6531 .42 6481. 87 3194. 37 7883.48 6006922. 92 396176. 75 MWD+IFR-AK-CAZ-SC '!, 11382.37 61. 60 32. 53 6576 .44 6526. 89 3263. 19 7931.52 6006991. 00 396225. 81 MWD+IFR-AK-CAZ-SC 11477.85 62. 44 29. 21 6621 .25 6571. 70 3335. 55 7974.76 6007062. 71 396270. 13 MWD+IFR-AK-CAZ-SC ' 11572.42 63. 36 24. 87 6664 .34 6614. 79 3410. 52 8013.01 6007137. 08 396309. 49 MWD+IFR-AK-CAZ-SC !: I~ 11668.05 64. 54 19. 94 6706 .36 6656. 81 3489. 92 8045.73 6007215. 98 396343. 39 MWD+IFR-AK-CAZ-SC 11762.90 65. 56 16. 57 6746 .38 6696. 83 3571. 57 8072.65 6007297. 22 396371. 53 MWD+IFR-AK-CAZ-SC 11858.20 66. 68 11. 60 6784 .98 6735. 43 3656. 06 8093.83 6007381. 37 396393. 97 MWD+IFR-AK-CAZ-SC 11953.49 68. 12 8. 18 6821 .61 6772. 06 3742. 71 8108.92 6007467. 78 396410. 36 MWD+IFR-AK-CAZ-SC 12048.29 69 .74 5. 48 6855 .69 6806. 14 3830. 53 8119.43 6007555. 42 396422. 18 MWD+IFR-AK-CAZ-SC ~ 12142.72 72. 01 2. 49 6886 .63 6837. 08 3919. 52 8125.62 6007644. 30 396429. 70 MWD+IFR-AK-CAZ-SC 12238.06 73. 20 0. 25 6915 .14 6865. 59 4010. 46 8127.78 6007735. 20 396433. 23 MWD+IFR-AK-CAZ-SC 12333.28 74. 63 356. 94 6941 .53 6891. 98 4101. 91 8125.53 6007826. 66 396432. 34 MWD+IFR-AK-CAZ-SC ~ 12428.72 76. 21 353. 94 6965 .56 6916. 01 4193. 97 8118.18 6007918. 81 396426. 37 MWD+IFR-AK-CAZ-SC I. s Halliburton Company Survey Report Company: ConocoPhillips Alaska lne. Date: 5/17/2006 'l'ime: 08:52:09 Page: d ', Field: Colville River Unit Co-ordinate(NE) Refcrence: Well: CD3-307, TrueNorth Site: Alpine CD3 Vertical (T3'n) Reference: CD3-307: 49.6 We11: CD3-307 Section (VS) Reference: Well (O.OON,O.OOE,59.13Azi) We[Ipath: CD3-307 Survey Calculation Method: Minimum Curvature Db: Oracle Survcv D7D Intl Azim TVD Sys TVD N/S E/W MapA h1apE Tool ', ft deg deg ft ft ft ft ft ft ~I 12524.05 77.81 352.27 6986.99 6937.44 4286.18 8107.03 6008011.17 396416.60 MWD+IFR-AK-CAZ-SC 12619.08 80.04 349.44 7005.24 6955.69 4378.24 8092.20 6008103.43 396403.15 MWD+{FR-AK-CAZ-SC 1 12714.24 81.94 347.01 7020.15 6970.60 4470.24 8073.02 6008195.69 396385.35 MWD+IFR-AK-CAZ-SC 12808.90 84.40 344.50 7031.41 6981.86 4561.32 8049.89 6008287.11 396363.59 MWD+IFR-AK-CAZ-SC 12903.99 85.92 342.58 7039.43 6989.88 4652.18 8023.04 6008378.$5 396338.11 MWD+IFR-AK-CAZ-SC 12999.34 89.26 341.93 7043.44 6993.89 4742.90 7994.01 6008469.49 396310.44 MWD+IFR-AK-CAZ-SC 13030.00 89.26 341.93 7043.84 ~ 6994.29 4772.04 7984.50 6008498.77 - 396301.37 • PROJECTED to TD '~ STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to:~ ~-e~~;')adrr:in.state.a>~.us• ao~c~ ~.4d~oe o~:v~ad:~ n.s~tae.ak.us I~~~ :eckenst°:n :tiadr~:i:~.stute.ak us Contractor: Doyon Rig No.: 19 DATE: 4!17/2006 Rig Rep.: Krupa/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Hill Field/Unit & Well No.: Colville Rv CD3-307 PTD # 206-046 Operation: Drlg: x Test: Initial: x Test Pressure: Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Annular Preventer 1 13-5/8 Pipe Rams 1 3-1/2x 6 Lower Pipe Rams 1 3-1/2x 6 Workover: Weekly: Annular: 250/3500 Explor.: Bi-Weekly Valves: 250/5000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P Test Result P P P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3000 P Pressure After Closure 1600 P 200 psi Attained 38 P Full Pressure Attained 3 min 03 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg}: 4@ 2050 psi Number of Failures: 0 Test Time: 5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: iim req„~ tiadrr:i:~.state.ak.us Remarks: Good test. No problems. 24 HOUR NOTICE GIVEN YES X NO Date 04/15/06 Test start Time 7:25am Finish Waived By John Spauldi Witness Lupton/Hill BOP Test (for rigs) BFL 11/09/04 Doyon19 4-17-06 CD3-307.x1s ~'~ I 9 ~ y 7 7 ~ J t 71 '' ~ y.l P, ~~~ M1~ ~ ~ ~®,~ r ~ ~ a~ a ~ ~ ~ ~ ~ ~,~ ,~1, ~A ~ ,Y FRANK H. MURKOWSKI, GOVERNOR ~, v ~' t~~ OI~ ~ lT~-7 333 W. 7T" AVENUE, SUITE 100 COI~TSER'FA'1'IO1Q C011i11'IISSIOI~T 1l ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit, Fiord Kuparuk Oil Pool, CD3-307 ConocoPhillips Alaska, Inc. Permit No: 206-046 Surface Location: 3926' FNL, 797' FEL, SEC. 5, T12N, RSE, UM Bottor~ii~iole Loe~tion: 4499' FNL, 1031' FEL, SEC. 33, T13N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not ~:~ 11 nt1-+Pr rPq_uired permits and authorize conducting drilling operations 'aiiui a~~ ~.~.~..- - 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9C~.7'j~59-3607 (pager). DATED this ~ day of April, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • ConocoPhillips Alaska, Inc. `~ Post Office Box 100360 Anchorage, Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 March 30, 2006 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 MAR 3 ~ 2006 Re: Application for Permit to Drill CD3-307 ~la~a Oai ~`_ ~~G~~ ~. Dear Sir or Madam: ~c~l ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the Fiord CD3 drilling pad. The intended spud date for this well is 4/14/06. It is intended that Doyon Rig 19 be used to drill the well. CD3-307 will be drilled through the Kuparuk reservoir, then penetrate the Nechelik reservoir horizontally. After setting and cementing 7" intermediate casing in the Nechelik, a completion will be run and the f--- Kuparuk interval perforated for a short flowback. Pressure in the Kuparuk reservoir will be monitored periodically for the next +/- 10 months to determine reservoir continuity. When ice roads are available next season, it is planned that the rig will return to CD3-307 to decomplete the well. The rig will then drill out of 7" casing horizontally in the Nechelik, and complete the well as a Nechelik producer. It is planned to rename the well CD3-107 after decompleting CD3-307. A waiver for the diverter requirement is requested. This will be the 7th well on the CD3 Fiord pad and there has been no indication of gas or shallow gas hydrates. 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. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1 ). 3. A proposed drilling program. 4. A proposed completion diagram. 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. 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 is: 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. Riser setup If you have any questions or require further information, please contact Vern Johnson at 265-6081, or Chip Alvord at 265-6120. • Sincerely, ~~-'' ~' ~ ~.- Vern Johnson Drilling Engineer ~~3~~~~' Attachments cc: CD3-307 Well File /Sharon Allsup Drake Chip Alvord Vern Johnson Jack Walker Jordan Wiess Lanston Chin r ATO 1530 ATO 1700 ATO 1702 ATO 1740 ATO-1782 Kuukpik Corporation STATE OF ALASKA AL, OIL AND GAS CONSERVATION COMMI~ PERMIT TO DRILL ~`~~ 20 AAC 25.005 1a. Type of Work: 1b. Current Well Class: Exploratory ^ Development Oil- 0 1c. Specify if well is proposed for: Drill Q Redrill ^ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry [I Multiple Zone ^ Single Zone ~ Shale Gas ^ 2. Operator Name: 5. Bond: Blanket 0 Single Well ^ 11. Well Name and Number: ConocoPhillips Alaska Inc. Bond No. 59-52-180 ' CD3-307 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 129gg ~ TVD: 7049 Colville River Unit 4a. Location of Well (Governmental Section): 7. Property Designation: Fiord Kuparuk Pool ' Surface: 3926' FNL, 797' FEL, Sec 5, T12N, RSE, UM' ADL 372104, 372105, 364471, 3~G47'~ Top of Productive Horizon: 8. Land Use Permit: ,Q`~y Ob yytt 13. Approximate Spud Date:/~ 298' FNL, 3366' FEL Sec 3, T12N, R5E, UM LAS21122 .2714/2006 Total Depth: 9. Acres in Property: 14. Distance to Nearest 4499' FNL, 1031' FEL Sec 33, T13N, RSE, UM ~ 3180 Property: 14893' to CRU bound 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well 4 ~ ~ (Height above GL): 36.7 feet Within Pool: CD3-302 4465' at 11680' ~ 6003847 Zone- Surface: x- 387 385 16. Deviated wells: • ~ Kickoff depth: 350 - feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3190 Surface: 2485 - 18. Casing Program: Specifications Top -Setting Depth -Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 77 37 37 - 114 - 114 Portland Cement 12.25" 9.625" 40# L-80 BTC-Mod 3089 37 37 - 3126 2500 500 sx AS Lite & 230 LiteCrete 8.75" 7" 26# L-80 BTC-Mod 12932 37 37 12969 - 7049 322 sx 15.8 ppg G 3.5" 9.3# L-80 EUE-Mod 11748 32 32 11780 6755 tubing 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner ~°A r'~ Perforation Depth MD (ft): Perforation Depth TVD (ft): =a~-~ ~~'' '+' $~ 20. Attachments: Filing Fee Q BOP Sketch ^ Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketcl^ Seabed Report ^ Drilling Fluid Program^ 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 3/31/2006 22. I hereby certify that the foregoing is true and correct. Contact V. Johnson 907-265-6081 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature ~ _ ~ Phone 265-6120 Date 3/31/2006 Commission Use Only Permit to Drill / ~v '~ ~~ API Number: C-' ~d 3 ~ ~ Zq ~ Permit Approval t D See cover letter for other i t Number: . (p j 50- +-~ a e: remen requ s. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in sh~ Other: Samples req'd: Yes^ No [Y Mud log req'd: Ye~ No HZS measures: Yes^ No Directional svy req'd: Ye~~No ^ ~~5~-~RC ~.~~ivi~~c~~~1~fcC!-LS~C~~~ Y`~\f "lV~ 1 APPROVED BY THE COMMISSION DATE: "' a ,COMMISSIONER ~/ V \ i ~~ Y 5~Q6 Form 10-401 Revised 12/2005 ' ~ ~ ~ ~ ~ n ~ ~ ~ ~it in Du~~e CD3-307 Drilling Hazards Summary (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 Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' ND Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate ~ Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure ~ mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well ~ control ractices mud scaven ers ORIGINAL • • Fiord: CD3-307 Procedure 1. Move on Doyon 19. 2. Rig up riser, dewater cellar as needed. 3. Drill 12-'/<" hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 9-5/8" surface casing. 5. Install and test BOPE to 5000 psi. 6. Pressure test casing to 2500 psi. 7. Drill out 20' of new hole. Perform leak off test. 8. Pick up and run in hole with 8-3/4" drilling BHA. 9. Drill 8-3/4" hole to intermediate casing point in the Nechelik reservoir sand. (LWD Program: GR/RES/PWD) 10. Run and cement 7" casing as per program.' Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. Run 3-%, 9.3#, L-80 EUE Mod tubing with TRM4E SSSV, gas lift mandrels, X nipple, packer XN nipple, and TCP perforating guns. 12. Rig up electric line to log the well for depth control. Space out and land hanger. 13. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 14. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 15. Circulate tubing to diesel and install freeze protection in the annulus. 16. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 17. Set BPV and secure well. Move rig off. ORIGINAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-108 is the nearest well to the CD3-307 plan with 16.3' well to well separation at 500' MD. Drillins~ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of-' lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. 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 Pumpins~ Operations: Incidental fluids developed from drilling operations on well CD3-307 will be injected into the permitted annulus CD3-109 or the class 2 disposal well on CD1 pad. The CD3-307 surtace/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1500' TVD. The only significant hydrocarbon zones are the Nechelik and Kuparuk reservoirs and there will be more than 500' of cement fill above the top of the Kuparuk as per regulations. Upon completion of CD3-307 form 10-403, Application for Sundry Operations -Annular Disposal, will 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 containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no 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. surtace 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. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surtace and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85°l0 of Collapse Burst 85°I° of Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2.992 asi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ~n~~'~~:~d~ • • DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint -12 '/:' Intermediate hole to 7" casing point - 8 %" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg PV 10 - 25 YP 20 - 60 15 - 25 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 minute gels <18 API Filtrate NC -10 cc / 30 min 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 160 PH 8.5-9.0 9.0-10.0 KCL Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at t 200 sec/gt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Nechelik is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. OR161NAL • • Fiord (CD3) Colville River Field CD3-307 Production Well Completion Plan 16" Conductor to 114' ' 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 3126' MD / 2500' TVD cemented to surface 3-1/2" 9.3 ppf L-80 EUE M tubing run with Jet Lube Run'n'Seal pipe dope Baker Premier Packer at +/- 11670' MD Pertorations in the Kuparuk sand TOC (81 +l- 11277' MD / 6524' TVD ~ 500' above top of Kuparuk C Updated 03/31/06 Sperry Sun Directional Plan WP04 Completion IlAQ Tubing Hanger 32' 32' 4 '/z' 12.6 #/ft IBT-Mod Tubing (2) Crossover 3-1/2", 9.3#/ft, EUE-Mod Tubing Camco TRM4E SCSSSV 2187' 2000' 3-1/2", 9.3#/ft, EUE-Mod Tubing Camco KBUG GLM (2.867" ID) 6988' 4400' 3-1/2", 9.3#/ft, EUE-Mod Tubing Camco KBUG GLM (2.867" ID) 11510' 6636' 3-112" tubing joints (2) HES "X" (2.81" ID) Profile 11610' 6682' 3-1/2" tubing joint (2) Baker Premier Packer 11670' 6708' 3-1 /2" tubing joint (1) HES "XN" (2.75" ID)-64.7° inc 11720' 6730' 3-1/2" tubing joint (2) Schlumberger TCP gun assembly 11780' 6755' Top Kuparuk C 11777 MD 16754' TVD 7" 26 ppf L-80 BTC Mod Top Nechelik at 12791' MD / 7035' TVD Production Casing @ 12969' MD 17049' TVD @ 90° OR161NAL • CD3-307 PRESSURE INFORMATION (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: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3126 / 2500 14.5 1131 1635 7" 12969 / 7049 16.0 3190 ~ 2429 NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. 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 Ib/gal 0.052 =Conversion from Ib./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 ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1084 - (0.1 x 2500') = 881 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 2500 = 1635 psi OR ASP =FPP - (0.1 x D) = 3190 - (0.1 x 7049) = 2485 psi OR!r,In!.AL • Cementing Program: • 9 5/8" Surface Casing run to 3125' MD / 2500' TVD. Cement from 3125' MD to 2625' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2625' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1263' MD). Lead slurry: (2625'-1267') X 0.3132 ft3/ft X 1.5 (50% excess) = 638.0 ft3 below permafrost 1267' X 0.3132 ft3/ft X 4 (300% excess) = 1587.3 ft3 above permafrost Total volume = 638.0 + 1587.3 = 2225.3 ft3 => 500 Sx @ 4.45 ft3/sk System: 500 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 12969' MD / 7049' TVD Cement from 12969' MD to 11277' MD (minimum 500' MD above top of Kuparuk C reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (9053' -7759') X 0.1503 ft3/ft X 1.4 (40% excess) = 356.0 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 356.0 + 17.2 = 373.2 ft3 => 322 Sx @ 1.16 ft3/sk System: 322 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant, 0.07% B155 retarder and 0.4% D 167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ®~~~~ ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-307 -Slot 7 Plan: CD3-307 Proposal Report 31 March, 2006 • Sperry I~rillnc~ ~er~rics ,r =x Calculation Method: Minima Elrar System: ISCWSA ConocoPl~illips ScanMetlrotl: Trav.Cyli~tlerNOrth s rt Colville River Unit error e a~e: Euipi Iconic Warning Method: Rules Based OeodehcDatam ~,gz,t~~~o"~s, Mag~wtie Model: BGGM2g05 Alpine CD3 Plan: CD3-307 Plan: CD3-307 ~wm nriwna s~n,~: CD3-307wp04 9000 U - - - - - SHL; 3926' FNL & 79T FEL; Sec05-T12N-ROSE ' Kick-aff Point; 2° DLS, 105° TFO, 350' MD, 350' TVD ~-. Base Permafrost ~ ', ', 10 ~ Begin Dir; 3° DLS, -40.6° TFO, 850' MD, 64T TVD 30 Q C-40 5 0 ' ~ - - 9 5/6' Csg - 12 1/4" Hole B Start Sail; 60 5° INC, 2606' MD 2244' TVD ~" 2500 _ y _ ,l __ ~ ~ 9-5/6" Csg Pt; 3' r ~.. Q C-20 '. ~ 0 K-3 K-3 Basa_I K-2 ' - ~ U K-2 Basal ~ 5000 ._ Albian 97 Albian 96 ~ _ ;_.-: i Top HRZ Base HRZ Top Kuparuk D Top Kuparuk C 7500- I Top Nechelik - - - LCU K-1 -Top Nwqsut t- ~~~~~ ~~~-- -~-- ~~_-- ~~~-~~~~ N i B qsu ase u -7500 -5000 -2500 67 Begin Dir; 4° DLS, -100° TFO, 10425' MD, 6090' TVD - 7" Csg Pt; 12969' MD, 7049' T~DCsg - 8 3/4" Hole Target (TD); 12969' MD,7049' TVD; 4499` FNL & 1031' FEL; Sec33-T13N-R0 -~.- ~o 0 m 0 2500 5000 at ~~~ nn° (2500 ft/in) _ - Sperry Drilling Services :_ ~. ~ .: ' ~onoco P~ill s Planning Report -Geographic . . _ "faSl4a Sperry Drilting Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-307 -Slot 7 Company: ConocoPhillps Alaska Inc. TVD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) '~ Project: Colville River Unit MD Reference: Planned'Doyon 19 @ 49,60ft (Doyon 19{36.3 + 13.3)) '' Site: Alpine CD3 North Reference: True ' Well: Plan: CD3-307 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-307 Design: CD3-307wp04 Project Colville River Unit, North Slope Alaska, United States 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 Plan: CD3-307 -Slot 7 Well Position +N/-S 0.00 ft Northing: 6,003,847.17 ft , Latitude: 70° 25' 10.055" N +E/-W 0.00 ft Easting: 388,247.02 ft ~ Longitude: 150° 54' 37.443" W Position Uncertainty 0.00 ft Wellhead E levation: ft Ground Level: 13.30ft Wellbore Plan CD3-307 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 3/31/2006 23.47 80.72 57,513 - -_ ___ Design CD3-307wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From (TVD) +N/-S +E/-W Directio n (ft) (ft) (ft) (°) ~_ 36.30 0.00 0.00 323.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/.S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°I100ft) (°/100ft) (°) 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 850.00 10.00 105.00 847.47 -11.26 42.04 2.00 2.00 0.00 105.00 2,606.58 60.53 68.52 2,244.37 247.83 967.04 3.00 2.88 -2.08 -40.60 10,425.08 60.53 68.52 6,090.64 2,740.77 7,301.11 0.00 0.00 0.00 0.00 12,969.55 87.00 323.19 7,049.60 4,711.15 7,674.16 4.00 1.04 -4.14 -100.33 3/31/2006 9:32:O6AM Page 2 of 7 !'~~.. COMPASS 2003.11 Build 50 Conacc~Phili~s Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3-307 Welibore: Plan: CD3-307 Design: CD3-307wp04 Planned Survey CD3-307wp04 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: MD Inclination Azimuth TVD SSND +N/-S (ft) (°) (°) (ft) (ft) lft) 36.30 0.00 0.00 36.30 -13.30 0.00 SHL; 3926' FNL & 797' FEL; Sec05-T12N-ROSE 1 C0.00 0.00 0.00 100.00 50.40 0.00 200.00 0.00 0.00 200.00 150.40 0.00 350.00 0.00 0.00 350.00 300.40 0.00 Kick-off Point; 2° DLS , 105° TFO, 350' MD, 350' ND 400.00 1.00 105.00 400.00 350.40 -0.11 500.00 3.00 105.00 499.93 450.33 -1.02 600.00 5.00 105.00 599.68 550.08 -2.82 700.00 7.00 105.00 699.13 649.53 -5.53 800.00 9.00 105.00 798.15 748.55 -9.13 850.00 10.00 105.00 847.47 797.87 -11.26 Begin Dir; 3° DLS, -40 .6° TFO, 850' MD, 847' ND 900.00 11.18 99.96 896.61 847.01 -13.23 1,000.00 13.73 92.58 994.26 944.66 -15.44 1,100.00 16.43 87.52 1,090.81 1,041.21 -15.36 1,200.00 19.21 83.88 1,186.01 1,136.41 -12.99 1,267.75 21.14 81.94 1,249.60 1,200.00 -10.09 Base Permafrost 1,300.00 22.06 81.14 1,279.58 1,229.98 -8.34 1,400.00 24.93 78.99 1,371.28 1,321.68 -1.42 1,500.00 27.83 77.27 1,460.86 1,411.26 7.75 1,600.00 30.75 75.85 1,548.07 1,498.47 19.14 1,700.00 33.68 74.66 1,632.66 1,583.06 32.73 1,800.00 36.62 73.63 1,714.41 1,664.81 48.48 1,900.00 39.57 72.74 1,793.10 1,743.50 66.34 2,000.00 42.53 71.95 1,868.50 1,818.90 86.26 2,100.00 45.49 71.25 1,940.42 1,890.82 108.20 2,200.00 48.45 70.62 2,008.65 1,959.05 132.08 2,300.00 51.42 70.04 2,073.00 2,023.40 157.85 2,400.00 54.39 69.50 2,133.31 2,083.71 185.44 2,51]0.00 57.36 69.01 2,189.40 2,139.80 214.76 2,600.00 60.34 68.55 2,241.12 2,191.52 245.74 2,606.58 60.53 68.52 2,244.37 2,194.77 247.83 Start Sail; 60.5° INC, 2606' MD, 2244' ND 2,700.00 60.53 68.52 2,290.33 2,240.73 277.62 2,785.93 60.53 68.52 2,332.60 2,283.00 305.02 C-40 2,800.00 60.53 68.52 2,339.52 2,289.92 309.51 2,900.00 60.53 68.52 2,388.72 2,339.12 341.39 3,000.00 60.53 68.52 2,437.91 2,388.31 373.28 3,100.00 60.53 68.52 2,487.11 2,437.51 405.16 3,126.21 60.53 68.52 2,500.00 2,450.40 413.52 9-5/8" Csg Pt; 3126' MD, 2500' N D - 9 5/8" Cs g - 12 1/4" Hole 3,131.50 60.53 68.52 2,502.60 2,453.00 415.20 C-30 LJ Sperry Rrilll'rng Service Well Plan: CD3-307 -Slot 7 Planned Doyoh 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Planned Doyon 19 @ 49.60ft (DOyon 19 (36.3 + 13.3)) True Mihimum Curvature Map Map +E!-W Northing Easting DLSEV Vert Section (ft) (ft) (ft) (°/100ft) (ftl 0.00 6,003,847.17 388,247.02 0.00 0.00 0.00 6,003,847.17 388,247.02 0.00 0.00 0.00 6,003,847.17 388,247.02 0.00 0.00 0.00 6,003,847.17 388,247.02 0.00 0.00 0.42 6,003,847.05 388,247.44 2.00 -0.34 3.79 6,003,846.10 388,250.80 2.00 -3.09 10.53 6,003,844.19 388,257.51 2.00 -8.59 20.63 6,003,841.34 388,267.56 2.00 -16.83 34.07 6,003,837.53 388,280.95 2.00 -27.79 42.04 6,003,835.28 388,288.88 2.00 -34.30 51.01 6,003,833.18 388,297.82 3.00 -41.26 72.42 6,003,830.65 388,319.19 3.00 -55.91 98.41 6,003,830.34 388,345.18 3.00 -71.49 128.90 6,003,832.25 388,375.70 3.00 -87.95 152.08 6,003,834.80 388,398.92 3.00 -99.59 163.82 6,003,836.38 388,410.69 3.00 -105.25 203.07 6,003,842.71 388,450.03 3.00 -123.35 246.54 6,003,851.22 388,493.63 3.00 -142.19 294.12 6,003,861.90 388,541.36 3.00 -161.72 345.66 6,003,874.72 388,593.10 3.00 -181.89 401.04 6,003,889.63 388,648.70 3.00 -202.63 460.09 6,003,906.61 388,708.01 3.00 -223.91 522.66 6,003,925.59 388,770.87 3.00 -245.65 588.57 6,003,946.53 388,837.10 3.00 -267.80 657.65 6,003,969.38 388,906.52 3.00 -290.30 729.71 6,003,994.07 388,978.95 3.00 -313.08 804.54 6,004,020.53 389,054.18 3.00 -336.09 881.95 6,004,048.68 389,132.01 3.00 -359.26 961.71 6,004,078.46 389,212.22 3.00 -382.52 967.04 6,004,080.48 389,217.58 3.00 -384.05 1,042.72 6,004,109.13 389,293.69 0.00 -405.81 1,112.34 6,004,135.48 389,363.70 0.00 -425.82 1,123.74 6,004,139.79 389,375.17 0.00 -429.10 1,204.75 6,004,170.46 389,456.64 0.00 -452.39 1,285.76 6,004,201.13 389,538.12 0.00 -475.68 1,366.78 6,004,231.79 389,619.59 0.00 -498.97 1,388.01 6,004,239.83 389,640.95 0.00 -505.08 1,392.29 6,004,241.45 389,645.25 0.00 -506.31 3J31/2006 9:32:06AM Page 3 of 7 COMPASS 2003.11 8urld 50 ORIGINAL Sperry Drilling Services ~ - Cc~nt~~aPhi~ li s Planning Report -Geographic .. ~~_._...... Alaska Sper ry Drilling Services Database: E DM 2003.11 Si ngle User Db Local Co-ordinate Reference: Well Plan: CD 3-307 -Slot 7 Company: C onocoPhillips Alaska Inc. TVD Reference: Planned Doyo n 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Project: C olville River Unit MD Reference: Planned Doyo n 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) ' Site: Alpine CD3 North Reference: True Well: P lan: CD3-307 Su rvey Calculation Method: Minimum Curvature Wellbore: P lan: CD3-307 Design: C D3-307wp04 __ - - Planned Survey CD3-307wp04 i Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) l°) ~ (ftl (ft) 1~) (ft) (ft) (~) (°I100ft) (ft) 3,200.00 60.53 68.52 2,536.30 2,486.70 437.05 1,447.79 6,004,262.46 389,701.07 0.00 -522.26 3,300.00 60.53 68.52 2,585.49 2,535.89 468.93 1,528.81 6,004,293.12 389,782.54 0.00 -545.55 3,400.00 60.53 68.52 2,634.69 2,585.09 500.82 1,609.82 6,004,323.79 389,864.02 0.00 -568.84 3,500.00 60.53 68.52 2,683.88 2,634.28 532.70 1,690.83 6,004,354.46 389,945.49 0.00 -592.13 3,600.00 60.53 68.52 2,733.08 2,683.48 564.59 1,771.85 6,004,385.12 390,026.97 0.00 -615.43 3,700.00 60.53 68.52 2,782.27 2,732.67 596.47 1,852.86 6,004,415.79 390,108.44 0.00 -638.72 3,800.00 60.53 68.52 2,831.47 2,781.87 628.36 1,933.88 6,004,446.45 390,189.92 0.00 -662.01 3,900.00 60.53 68.52 2,880.66 2,831.06 660.24 2,014.89 6,004,477.12 390,271.39 0.00 -685.30 3,918.17 60.53 68.52 2,889.60 2,840.00 666.04 2,029.61 6,004,482.69 390,286.20 0.00 -689.53 C-20 4,000.00 60.53 68.52 2,929.86 2,880.26 692.13 2,095.90 6,004,507.79 390,352.87 0.00 -708.59 4,100.00 60.53 68.52 2,979.05 2,929.45 724.01 2,176.92 6,004,538.45 390,434.34 0.00 -731.88 4,200.00 60.53 68.52 3,028.24 2,978.64 755.90 2,257.93 6,004,569.12 390,515.82 0.00 -755.17 4,300.00 60.53 68.52 3,077.44 3,027.84 787.78 2,338.94 6,004,599.78 390,597.29 0.00 -778.46 4,400.00 60.53 68.52 3,126.63 3,077.03 819.67 2,419.96 6,004,630.45 390,678.77. 0.00 -801.75 4,500.00 60.53 68.52 3,175.83 3,126.23 851.55 2,500.97 6,004,661.12 390,760.24 0.00 -825.04 4,600.00 60.53 68.52 3,225.02 3,175.42 883.44 2,581.99 6,004,691.78 390,841.72 0.00 -848.33 4,700.00 60.53 68.52 3,274.22 3,224.62 915.32 2,663.00 6,004,722.45 390,923.20 0.00 -871.63 4,800.00 60.53 68.52 3,323.41 3,273.81 947.21 2,744.01 6,004,753.11 391,004.67 0.00 -894.92 4,900.00 60.53 68.52 3,372.61 3,323.01 979.09 2,825.03 6,004,783.78 391,086.15 0.00 -918.21 5,000.00 60.53 68.52 3,421.80 3,372.20 1,010.98 2,906.04 6,004,814.45 391,167.62 0.00 -941.50 5,100.00 60.53 68.52 3,470.99 3,421.39 1,042.86 2,987.06 6,004,845.11 391,249.10 0.00 -964.79 5,200.00 60.53 68.52 3,520.19 3,470.59 1,074.75 3,068.07 6,004,875.78 391,330.57 0.00 -988.08 5,300.00 60.53 68.52 3,569.38 3,519.78 1,106.63 3,149.08 6,004,906.44 391,412.05 0.00 -1,011.37 5,400.00 60.53 68.52 3,618.58 3,568.98 1,138.52 3,230.10 6,004,937.11 391,493.52 0.00 -1,034.66 5,500.00 60.53 68.52 3,667.77 3,618.17 1,170.40 3,311.11 6,004,967.78 391,575.00 0.00 -1,057.95 5,600.00 60.53 68.52 3,716.97 3,667.37 1,202.29 3,392.13 6,004,998.44 391,656.47 0.00 -1,081.24 5,700.00 60.53 68.52 3,766.16 3,716.56 1,234.17 3,473.14 6,005,029.11 391,737.95 0.00 -1,104.53 5,800.00 60.53 68.52 3,815.35 3,765.75 1,266.06 3,554.15 6,005,059.77 391,819.42 0.00 -1,127.82 5,900.00 60.53 68.52 3,864.55 3,814.95 1,297.94 3,635.17 6,005,090.44 391,900.90 0.00 -1,151.12 5,991.58 60.53 68.52 3,909.60 3,860.00 1,327.14 3,709.36 6,005,118.52 391,975.51 0.00 -1,172.44 K-3 6,000.00 60.53 68.52 3,913.74 3,864.14 1,329.83 3,716.18 6,005,121.11 391,982.37 0.00 -1,174.41 6,100.00 60.53 68.52 3,962.94 3,913.34 1,361.71 3,797.20 6,005,151.77 392,063.85 0.00 -1,197.70 6,200.00 60.53 68.52 4,012.13 3,962.53 1,393.60 3,878.21 6,005,182.44 392,145.32 0.00 -1,220.99 6,300.00 60.53 68.52 4,061.33 4,011.73 1,425.48 3,959.22 6,005,213.10 392,226.80 0.00 -1,244.28 6,306.65 60.53 68.52 4,064.60 4,015.00 1,427.60 3,964.61 6,005,215.14 392,232.22 0.00 -1,245.83 K-3 Basal 6,377.80 60.53 68.52 4,099.60 4,050.00 1,450.29 4,022.25 6,005,236.96 392,290.19 0.00 -1,262.40 K-2 6,400.00 60.53 68.52 4,110.52 4,060.92 1,457.37 4,040.24 6,005,243.77 392,308.27 0.00 -1,267.57 6,500.00 60.53 68.52 4,159.72 4,110.12 1,489.25 4,121.25 6,005,274.44 392,389.75 0.00 -1,290.86 6,585.14 60.53 68.52 4,201.60 4,152.00 1,516.40 4,190.23 6,005,300.55 392,459.12 0.00 -1,310.69 K-2 Basal 6,600.00 60.53 68.52 4,208.91 4,159.31 1,521.14 4,202.26 6,005,305.10 392,471.22 0.00 -1,314.15 6,700.00 60.53 68.52 4,258.10 4,208.50 1,553.02 4,283.28 6,005,335.77 392,552.70 0.00 -1,337.44 6,800.00 60.53 68.52 4,307.30 4,257.70 1,584.91 4,364.29 6,005,366.43 392,634.17 0.00 -1,360.73 6,900.00 60.53 68.52 4,356.49 4,306.89 1,616.79 4,445.31 6,005,397.10 392,715.65 0.00 -1,384.02 3/31/2006 9:32:O6AM Page 4 of 7 COMPASS 2003.11 Build 50 ORIGINAL Sperry Drilling Services - - ~U1'74CUP~"1(~ ~1~??$ Planning Report -Geographic Al~sl<:~ Sperr y Dttilting Services Database: E DM 2003.11 Si ngle User Db Local Co-ordinate Reference: Well Plan: CD 3-307 -Slot 7 Company: ConocoPhillips Alaska Inc. N D Reference: Planned Doyo n 19 @ 49.60ft (Doyon 19 (36.3+ 13.3)) Project Colville River Unit MD Reference: Planned Doyo n 19 @ 49.60ft {Doyon 19 (36.3 + 13.3)) Site: Alpine CD3 No rth Reference: True Well: P lan: CD3-307 Su rvey Calculation Method: Mihimum Curvature Wellbore: P lani CD3-307 Design: C D3-307wp04 Planned Survey CD3-307wp04 -- Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_V~ Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 7,000.00 60.53 68.52 4,405.69 4,356.09 1,648.68 4,526.32 6,005,427.77 392,797.12 0.00 -1,407.31 7,100.00 60.53 68.52 4,454.88 4,405.28 1,680.56 4,607.33 6,005,458.43 392,878.60 0.00 -1,430.61 7,200.00 60.53 68.52 4,504.08 4,454.48 1,712.45 4,688.35 6,005,489.10 392,960.07 0.00 -1,453.90 7,300.00 60.53 68.52 4,553.27 4,503.67 1,744.33 4,769.36 6,005,519.76 393,041.55 0.00 -1,477.19 7,400.00 60.53 68.52 4,602.47 4,552.87 1,776.22 4,850.38 6,005,550.43 393,123.02 0.00 -1,500.48 7,500.00 60.53 68.52 4,651.66 4,602.06 1,808.10 4,931.39 6,005,581.10 393,204.50 0.00 -1,523.77 7,600.00 60.53 68.52 4,700.85 4,651.25 1,839.99 5,012.40 6,005,611.76 393,285.98 0.00 -1,547.06 7,700.00 60.53 68.52 4,750.05 4,700.45 1,871.87 5,093.42 6,005,642.43 393,367.45 0.00 -1,570.35 7,800.00 60.53 68.52 4,799.24 4,749.64 1,903.76 5,174.43 6,005,673.10 393,448.93 0.00 -1,593.64 7,900.00 60.53 68.52 4,848.44 4,798.84 1,935.64 5,255.45 6,005,703.76 393,530.40 0.00 -1,616.93 8,000.00 60.53 68.52 4,897.63 4,848.03 1,967.53 5,336.46 6,005,734.43 393,611.88 0.00 -1,640.22 8,100.00 60.53 68.52 4,946.83 4,897.23 1,999.41 5,417.47 6,005,765.09 393,693.35 0.00 -1,663.51 8,200.00 60.53 68.52 4,996.02 4,946.42 2,031.30 5,498.49 6,005,795.76 393,774.83 0.00 -1,686.80 8,300.00 60.53 68.52 5,045.21 4,995.61 2,063.18 5,579.50 6,005,826.43 393,856.30 0.00 -1,710.10 8,400.00 60.53 68.52 5,094.41 5,044.81 2,095.07 5,660.52 6,005,857.09 393,937.78 0.00 -1,733.39 8,500.00 60.53 68.52 5,143.60 5,094.00 2,126.95 5,741.53 6,005,887.76 394,019.25 0.00 -1,756.68 8,600.00 60.53 68.52 5,192.80 5,143.20 2,158.84 5,822.54 6,005,918.42 394,100.73 0.00 -1,779.97 8,700.00 60.53 68.52 5,241.99 5,192.39 2,190.72 5,903.56 6,005,949.09 394,182.20 0.00 -1,803.26 8,800.00 60.53 68.52 5,291.19 5,241.59 2,222.61 5,984.57 6,005,979.76 394,263.68 0.00 -1,826.55 8,900.00 60.53 68.52 5,340.38 5,290.78 2,254.49 6,065.58 6,006,010.42 394,345.15 0.00 -1,849.84 9,000.00 60.53 68.52 5,389.58 5,339.98 2,286.38 6,146.60 6,006,041.09 394,426.63 0.00 -1,873.13 9,100.00 60.53 68.52 5,438.77 5,389.17 2,318.26 6,227.61 6,006,071.75 394,508.10 0.00 -1,896.42 9,200.00 60.53 68.52 5,487.96 5,438.36 2,350.15 6,308.63 6,006,102.42 394,589.58 0.00 -1,919.71 9,300.00 60.53 68.52 5,537.16 5,487.56 2,382.03 6,389.64 6,006,133.09 394,671.05 0.00 -1,943.00 9,400.00 60.53 68.52 5,586.35 5,536.75 2,413.92 6,470.65 6,006,163.75 394,752.53 0.00 -1,966.29 9,500.00 60.53 68.52 5,635.55 5,585.95 2,445.80 6,551.67 6,006,194.42 394,834.00 0.00 -1,989.59 9,600.00 60.53 68.52 5,684.74 5,635.14 2,477.69 6,632.68 6,006,225.08 394,915.48 0.00 -2,012.88 9,700.00 60.53 68.52 5,733.94 5,684.34 2,509.58 6,713.70 6,006,255.75 394,996.95 0.00 -2,036.17 9,752.17 60.53 68.52 5,759.60 5,710.00 2,526.21 6,755.96 6,006,271.75 395,039.46 0.00 -2,048.32 Albian 97 9,800.00 60.53 68.52 5,783.13 5,733.53 2,541.46 6,794.71 6,006,286.42 395,078.43 0.00 -2,059.46 9,900.00 60.53 68.52 5,832.33 5,782.73 2,573.35 6,875.72 6,006,317.08 395,159.90 0.00 -2,082.75 10,000.00 60.53 68.52 5,881.52 5,831.92 2,605.23 6,956.74 6,006,347.75 395,241.38 0.00 -2,106.04 10,1C0.00 60.53 68.52 5,930.71 5,881.11 2,637.12 7,037.75 6,006,378.41 395,322.85 0.00 -2,129.33 10,200.00 60.53 68.52 5,979.91 5,930.31 2,669.00 7,118.77 6,006,409.08 395,404.33 0.00 -2,152.62 10,260.36 60.53 68.52 6,009.60 5,960.00 2,688.24 7,167.66 6,006,427.59 395,453.50, 0.00 -2,166.68 Albian 96 10,300.00 60.53 68.52 6,029.10 5,979.50 2,700.89 7,199.78 6,006,439.75 395,485.80 0.00 -2,175.91 10,400.00 60.53 68.52 6,078.30 6,028.70 2,732.77 7,280.79 6,006,470.41 395,567.28 0.00 -2,199.20 10,4;5.08 60.53 68.52 6,090.64 6,041.04 2,740.77 7,301.11 6,006,478.10 395,587.71 0.00 -2,205.04 Begin Dir; 4° DLS, -100° TFO, 10425' MD, 6090' ND 10,500.00 60.04 65.12 6,127.78 6,078.18 2,766.37 7,360.91 6,006,502.81 395,647.89 4.00 -2,220.58 10,600.00 59.52 60.52 6,178.14 6,128.54 2,805.82 7,437.75 6,006,541.10 395,725.30 4.00 -2,235.32 10,700.00 59.16 55.89 6,229.16 6,179.56 2,851.12 7,510.84 6,006,585.29 395,799.05 4.00 -2,243.13 10,800.00 58.96 51.23 6,280.59 6,230.99 2,902.04 7,579.81 6,006,635.17 395,868.77 4.00 -2,243.97 10,900.00 58.94 46.57 6,332.19 6,282.59 2,958.33 7,644.34 6,006,690.49 395,934.13 4.00 -2,237.85 11,000.00 59.08 41.90 6,383.69 6,334.09 3,019.74 7,704.12 6,006,750.98 395,994.81 4.00 -2,224.78 11,100.00 59.39 37.26 6,434.86 6,385.26 3,085.94 7,758.84 6,006,816.36 396,050.52 4..00 -2,204.84 3/31/2006 9:32:O6AM Page 5 of 7 COMPASS 2003.11 Build 50 ORIGINAL ' • ' Sperry Drilling Services _ ~{at'1C1C4~~'1tE ~1~3S Planning Report -Geographic . Alaska Sperry Drilling Services Database: E DM 2003.11 Si ngle User Db Local Co-ordinate Reference: Well Plan: CD 3-307 -Slot 7 Company: C onocoPhillips Alaska Inc. TV D Reference: Planned Doyo n 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) '' Project: C olville River Unit MD Reference: Planned Doyo n 19 @ 49.60ft (Doyon 19 (36:.3 + 13.3)) Site: Alpine CD3 No rth Reference: True Well: P lan: CD3-307 Su rvey Calculation Method: Minimum Curvature Wellbore: P lan: CD3-307 Design: C D3-307wp04 -_ Planned Survey _ _ ___ CD3-307wp04 _ _ __ _ __ -- -_ - , I Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) Ift) (ft) (ft) lft) (ft) (ft) (°/100ft) (ft) 11,109.31 59.43 36.83 6,439.60 6,390.00 3,092.33 7,763.66 6,006,822.68 396,055.44 4.02 -2,202.64 Top HRZ 11,200.00 59.86 32.66 6,485.45 6,435.85 3,156.63 7,808.24 6,006,886.29 396,100.97 4.00 -2,178.12 11,300.00 60.50 28.10 6,535.19 6,485.59 3,231.45 7,852.09 6,006,960.44 396,145.93 4.00 -2,144.76 11,400.00 61.28 23.61 6,583.86 6,534.26 3,310.05 7,890.17 6,007,038.45 396,185.17 4.00 -2,104.90 11,490.11 62.11 19.63 6,626.60 6,577.00 3,383.78 7,919.38 6,007,111.73 396,215.48 4.00 -2,063.60 Base HRZ 11,5C.0.00 62.21 19.20 6,631.22 6,581.62 3,392.03 7,922.29 6,007,119.94 396,218.52 3.98 -2,05$.76 11,585.73 63.12 15.47 6,670.60 6,621.00 3,464.72 7,944.96 6,007,192.27 396,242.27 4.00 -2,014.35 K-1 11,600.00 63.28 14.86 6,677.03 6,627.43 3,477.01 7,948.29 6,007,204.51 396,245.79 3.99 -2,006.54 11,680.42 64.23 11.43 6,712.60 6,663.00 3,547.23 7,964.69 6,007,274.47 396,263.23 4.00 -1,960.32 Top Kuparuk D 11,700.00 64.48 10.61 6,721.08 6,671.48 3,564.56 7,968.06 6,007,291.75 396,266.86 3.99 -1,948.52 11,776.88 65.48 7.40 6,753.60 6,704.00 3,633.35 7,978.95 6,007,360.37 396,278.78 4.00 -1,900.13 Top Kuparuk C 11,800.00 65.79 6.45 6,763.14 6,713.54 3,654.26 7,981.49 6,007,381.23 396,281.63 3.99 -1,884.96 11,813.37 65.98 5.89 6,768.60 6,719.00 3,666.39 7,982.80 6,007,393.34 396,283.13 4.01 -1,876.06 LCU 11,900.00 67.22 2.37 6,803.01 6,753.41 3,745.67 7,988.52 6,007,472.52 396,290.03 4.00 -1,816.18 12,000.00 68.75 358.39 6,840.50 6,790.90 3,838.36 7,989.11 6,007,565.18 396,292.01 4.00 -1,742.52 12,053.73 69.61 356.28 6,859.60 6,810.00 3,888.52 7,986.77 6,007,615.37 396,290.42 4.00 -1,701.05 Top Nuigsut 12,100.00 70.37 354.48 6,875.43 6,825.83 3,931.85 7,983.27 6,007,658.74 396,287.56 4.00 -1,664.33 12,200.00 72.08 350.66 6,907.62 6,858.02 4,025.71 7,971.01 6,007,752.77 396,276.71 4.00 -1,582.00 12,300.00 73.85 346.91 6,936.93 6,887.33 4,119.47 7,952.40 6,007,846.79 396,259.51 4.00 -1,495.92 12,3E~5.95 75.06 344.48 6,954.60 6,905.00 4,181.04 7,936.70 6,007,908.57 396,244.74 4.00 -1,437.30 Base Nuigsut 12,400.00 75.69 343.23 6,963.19 6,913.59 4,212.68 7,927.54 6,007,940.35 396,236.05 3.99 -1,406.51 12,426.37 76.19 342.27 6,969.60 6,920.00 4,237.11 7,919.95 6,007,964.89 396,228.83 4.01 -1,382.44 12,500.00 77.59 339.61 6,986.30 6,936.70 4,304.88 7,896.53 6,008,032.99 396,206.43 4.00 -1,314.22 12,600.00 79.54 336.05 7,006.13 6,956.53 4,395.62 7,859.54 6,008,124.27 396,170.80 4.00 -1,219.49 12,700.00 81.52 332.52 7,022.59 6,972.99 4,484.46 7,816.74 6,008,213.74 396,129.34 4.00 -1,122.78 12,791.23 83.36 329.34 7,034.60 6,985.00 4,563.49 7,772.80 6,008,293.41 396,086.59 4.00 -1,033.22 Top Nechelik 12,800.00 83.53 329.04 7,035.60 6,986.00 4,570.98 7,768.34 6,008,300.96 396,082.24 3.98 -1,024.56 12,900.00 85.57 325.58 7,045.09 6,995.49 4,654.73 7,714.57 6,008,385.50 396,029.74 4.00 -925.31 12,969.55 87.00 323.19 7,049.60 7,000.00 4,711.15 7,674.16 6,008,442.51 395,990.18 4.00 -855.93 7" Csg Pt; 12969' M D, 7049' TVD -Target (TD); 12969' MD, 7049' TVD; 4499' FNL & 10 31' FEL; Sec33-T13N-ROSE - 7" Csg - 8 3/4" Hole -CD3 3/31/20L'6 9:32:06AM Page 6 of 7 COMPASS 2003.11 Buitd 50 ~~~~d'~~ Sperry Drilling Services - ~~~'~~~~~;~~~~~ Planning Report -Geographic ~ - Aiaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-307 -Slot 7 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 49:60ft (Doyon 19 (36:3 + 13.3)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Site: Alpine CD3 North Reference: True Well: Plan: CD3-307 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-307 Designs CD3-307wp04 Gl eologic Targets Plan: CD3-307 TVD (ft) 7,049.60 - Point Prognosed Casing Points +N/-S +E/-W ft ft C1-14 X42 = .. 4,711.15 7,674.16 Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) lft) (") (") 3,126.21 2,500.00 9-518 12-1/4 12,969.54 7,049.60 7 8-3/4 Northing Easting (ft) (ft) 6,008,442.51 395,990.18 Prognosed Formation Intersection Points Measured Vertical Clepth Inclination Azimuth Depth +N/-E +E/-W lft) (°) (°l lft) (ft) (ft) Paz=~~Ft~ 1,267.75 21.14 81.94 1,249.60 -10.09 152.08 Base Permafrost 2,785.93 60.53 68.52 2,332.60 305.02 1,112.34 C-40 3,131.50 60.53 68.52 2,502.60 415.20 1,392.29 C-30 3,918.17 60.53 68.52 2,889.60 666.04 2,029.61 C-20 5,991.58 60.53 68.52 3,909.60 1,327.14 3,709.36 K-3 6,306.65 60.53 68.52 4,064.60 1,427.60 3,964.61 I{-3 Basal 6,377.80 60.53 68.52 4,099.60 1,450.29 4,022.25 K-2 6,585.14 60.53 68.52 4,201.60 1,516.40 4,190.23 K-2 Basal 9,752.17 60.53 68.52 5,759.60 2,526.21 6,755.96 Aibian 97 10,260.36 60.53 68.52 6,009.60 2,688.24 7,167.66 Rlbian 96 11,109.31 59.43 36.83 6,439.60 3,092.33 7,763.66 Top HZ 11,490.11 62.11 19.63 6,626.60 3,383.78 7,919.38 Base HRZ 11,585.73 63.12 15.47 6,670.60 3,464.72 7,944.96 K-1 11,680.42 64.23 11.43 6,712.60 3,547.23 7,964.69 Top Kuparuk D 11,776.88 65.48 7.40 6,753.60 3,633.35 7,978.95 Top Kuparuk C 1'!,813.37 65.98 5.89 6,768.60 3,666.39 7,982.80 LCU 12,053.73 69.61 356.28 6,859.60 3,888.52 7,986.77 Top Nuigsut 12,365.95 75.06 344.48 6,954.60 4,181.04 7,936.70 Bass Nuigsut 12,791.23 83.36 329.34 7,034.60 4,563.49 7,772.80 Top Nechelik 3/31/2006 9:32:06AM Page 7 of 7 COMPASS 2003.11 Buf(d 50 (1R!GW^~ .7 ConocoPhillips Alaska • ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-307 Plan: CD3-307 CD3-307wp04 Anticollision Report 31 March, 2006 Sperry Drilling serv~c~a ORIGIPI!1~ .,.. AR1I~LOWSION SETi1NG5 cex cw. TuMO C©nQCQPhI~(~ ~ co3-307Wg04 IM.rpembnM.a.e Mo Im.rval zssl.nen. m ,. p , ":u„ ' 36.30 Ta 12969.55 GalWlationM.e,ea Mlmm.mGU<Y.N,m MaMmum Range 1493.]251]3999)] E M tl l ISCWSA rmr O e : Sun Menwtl: Trav. CYliMer NoM . r . ~ ,...~ nI Error SUrlaee: EllipBeal Canic Wxmin McMOtl: Rules aazetl _. 3ygfey Dli llirty 5elr~fc ern SItR\'EY PROOR,IM DMt'. 100403-31700:00:00 \'x1i0n1ed: Yer Version: _..._..- - - Deplh Fmm Depth Tn SmveylPlxn Tonle. -,,,,.. _, v.v i~e 3fi.30 1000.00 CD310)wpM CRLYRO-S4 1000.00 129fi9.S5 CD3-l0]wpM Mw'M2FR-AR-CAZ-BC a ~v: CD3-302 ~ CD3-108 ~,~::"a1nw~.~::::. w: o:~,n,.~.,....M CD3-110 CD3-302P81 CD3-301 (wp01) ... n... ,n,,,» ~ I ~ 0'30 ... ~ m a. rom, ~ CD3-109 `>~*, _ 30 / 330 .`1\ 3 _~ _... ., - ~ \ ~ Plan: CD3-106 (wp01) ere \ ~ ' I r 1 1 a \\ I CD3111 -60 / 300 ~ I~ ~ ~ / ~ ~ \\60 I I I z rt/1'~' CD3111L1 _ _ _ ~. 1 ~ , ~ •"~ CD3-111 L1wp05 \~~,\ ICI I .n i0 i^ 1 ~ ~ ~~~ ; . 1 r~ ~ , ~ ~/S„ 1 .~ / cva,,.xaa CD3-112 Rig \~~~ ~x r j - L~. ~ _ i -90 / 270 `~ 1 ~ :90 ~. II _ / Plan: CD3-113 ( 001) j 25. • / ~j~f' - '', ~V 1v ~~ ,~' ~ CD}303PB1wp03 ~y Plen: CD3-114 ( 0011 ~ 1 ~ ~ 50_-'- ~ / - , ~~ \\ ~ ,..- OD3-303wp04 , r , \\ Plan: CD3-115 (wp01) \ 75_,_ - -1201240'. ~ ~ 20 ',,,, ,~ -.....,........ 100.. ~ I \ _ \ A ~~ ~~'~ _ 1_25_ -' ~ , Plan' CD&305 (wpD2) ~ ~ -150 / -1 B0 / 1 BO 950 CD3-304wp06 P I C>=n-. ~~ , aeport 1 r,,, .ire Separ. Critical Issues: -90 / -1 BO 1180 7 Ian: cD>-1na lwpol d0 i 120 SECTION DETAILS Sec AID hIC ,121 T\'D +NI-S +EI-W DLeg TFau VBer Txrgd 1 36.30 U.UU U. W 36.3U U.On U.00 U.nO U.OU U.al z Ssn3w Icon n.Iw 351100 B.en n.no n.ao ann o.al 3 e5o.oo la.oe los.oe B4]-n -u.z6 Jzw z.oo las.ee aJ.w J zfip6_56 6o.a fix5z nJf.3] z4z63 9n).a 3.OD -35.60 aBJ.os 5 IUJ2SU6 W.SI b8.u 609U.N E)3U.]) )31111] U.00 U.UU -n05.UJ fi 12969.55 B].M 323.19 ]039.fi11 3)II.IS )fi]J-Ifi 1.M -]51.33 -85.593 C'D31n)wpn2 Neel • • 3/31 /2006 8:52 AM ConocoPhilli~s • Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Reference Site: Alpine CD3 Site Error: O.OOft Reference Well: Plan: CD3-307 Well Error: O.OOft Reference Wellbore Plan: CD3-307 Reference Design: CD3-307wp04 Sperry Drilling Services Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Sherry Drilling Service& Well Plan: CD3-307 -Slot 7 Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) True Minimum Curvature 1.00 sigma EDM 2003:11 Single User Db Offset Datum __ Reference CD3-307wp04 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referE Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,493.33ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma ~' Survey Tool Program Date 3/31/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 36.30 1,000.00 CD3-307wp04 (Plan: CD3-307) CB-GYRO-SS Camera based gyro single shot 1,000.00 12,969.55 CD3-307wp04 (Plan: CD3-307) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Alpine CD3 CD3.108 -CD3-108 -CD3-108 500.00 500.00 16.26 9.30 6.98 Pass -Major Risk CD3-109 -CD3-109 -CD3-109 743.58 750.00 39.88 15.20 24.82 Pass -Major Risk CD3-110 -CD3-110 -CD3-110 544.93 550.00 57.16 11.27 45.92 Pass -Major Risk CD3-111 -CD3-111 -CD3-111 374.36 375.00 83.45 7.94 75.51 Pass -Major Risk CD3-111 -CD3-111 L1 -CD3-111 L1 374.36 375.00 83.45 7.94 75.51 Pass -Major Risk CD3-111 -CD3-111 L1 -CD3-111 L1wp05 374,36 375.00 83.45 7.94 75.51 Pass -Major Risk CD3-302 -CD3-302 -CD3-302 248.80 250.00 100.42 5.22 95.21 Pass -Major Risk CD3-302 -CD3-302P61 -CD3-302P61 248.80 250.00 100.42 5.22 95.21 Pass -Major Risk Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 (~ 250.99 250.00 20.44 5.19 15.24 Pass -Major Risk Plan: CD3-113 -Plan: CD3-113 -Plan: CD3-113 (~ 400.00 400.00 120.61 7.45 113.15 Pass -Major Risk Plan: CD3-114 -Plan: CD3-114 -Plan: CD3-114 (~ 398.90 400.00 140.60 7.44 133.16 Pass -Major Risk Plan: CD3-115 -Plan: CD3-115 -Plan: CD3-115 (~ 398.61 400.00 160.60 7.43 153.16 Pass -Major Risk Plan: CD3-116 -Plan: CD3-116 -Plan: CD3-116 (~ 226.00 225.00 180.38 4.18 176.20 Pass -Major Risk Plan: CD3-117 -Plan: CD3-117 -Plan: CD3-117 (~ 226.00 225.00 200.35 4.18 196.17 Pass -Major Risk Plan: CD3-301 -Plan: CD3-301 -CD3-301 (wp01) 608.13 600.00 120.41 11.42 109.08 Pass -Major Risk Plan: CD3-303 -Plan: CD3-303 -CD3-303wp04 502.58 500.00 83.19 10.64 72.56 Pass -Major Risk Plan: CD3-303 -Plan: CD3-303P61 -CD3-303P6 503.70 500.00 83.22 10.67 72.56 Pass -Major Risk Plan: CD3-304 -Plan: CD3-304 -CD3-304wp06 604.82 600.00 64.90 12.88 52.05 Pass -Major Risk Plan: CD3-305 -Plan: CD3-305 -Plan: CD3-305 (~ 250.99 250.00 40.29 4.65 35.64 Pass -Major Risk Rig: CD3-112 -Rig: CD3-112 -CD3-112 Rig 324.97 325.00 100.28 6.86 93.42 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/31/2006 8:42:22AM Page 2 of 2 COMPASS 2003.11 Burld 50 ORIGINAL -1067 ..-. _ . ~..._.__._ ~ ~~ ~ ~ > 8 ~ _ Y % \ E _ C 0 m 4. 3 C Q. _ .. _ y - .. O r^ fl ~ ~ _ ~ Q 323 _ _; , ,,,,,.,.°'~ ._ !? ~ ' i f 1323 a,,. ... ... ....... I North (+I / South I I ~ I ~._.. _....... ..._w.,... ... ..._._. .,__..,._...~.. ...... ... .... ___ ._ T _,. 385048 °v o - 0 2323 __ _ -_ __~ __ _ _ .._ __ 386048 _ ~ I 8 ~ ~ ....... ....._ ._ a ..... _ _,.._- -- ~ ,-' __ - 87048 3 N N m ti o F 3323 ~ __ _ w w ~ Q ~ _._ .. 388048 m. 4323 ~ _... ... .. ._. 3 '. .''.. .. ..... ..... ......... .. ..... 389048 5323 ... _. ._ T _ ~. ..__ ! ____. _.. .. 390048 6323 ._..._... .. .. ... _. _. .i .. j _... ~ ', ''.. '. '. _._... ..... .._..... ...... ____..... 39to4s E 9 o i o a ~ u u F 3 .. Y n t ____. ......_ _. 392048 .-. .. „ 3 3 2 < 7323 , _ 4 S "e i o . _ __. . ;__ ....~ ~ _~ ... 393048 .. e 8323 _ - _._ .._ _ ~ I _ - - ~ ' ~ , ..... ..... ... .. 394048 9323 - - ;~ ~ _ _= - -- --° -°-° ~--~-"... - A 395046 ~ ' 1 : t 10323 - ...._ . . _._. ~_ ,. - ~ ..._.._ ._.. ._ _.. 396048 ,, 3 ` 11323 .... - .-. ..... __ .___. €. ___~„... ..... ,.. 397048 . '''.. I I '. a a ~ .a ~ ..._.. ,..... ...._. 398048 ~ ' o ? -, :` .. 12323 _ _... ~.. _ _ r ~ ....~ t ~ ~~ ~ ~ o ar t ' j _ ... ..... _ .. .. _ __ _._ 399048 v 13323 ~ _ W P Q OO O ( J N OO A O V P o 0 o rn o 0 0 O o 0 0 o O o _ ~ to 0 n Cj o O o C J 8 8 0 0 8 S ~' 8 8 ° S o 0 0 • System True Vertical Depih Closest in POOL ~_..~ Closest A roach: Reference Well: CD3-3 07w 04 Plan t3ffst Well: CD3-302 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+))S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. TVD E(+)/W(_) (323°) Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (323°) Comments POOL Min Distance POOL Min Distance (4465.31 ft) in POOL (4465.31 ft) in POOL (6663 - 6719 TVDss) (6663 - 6719 TVDss) to CD3-302 Rig MWD to CD3-307wp04 Plan 4465.31 11680.42 64.23 11.43 6663.211 6007274 396264.1 -1960.679 (6663 - 6719 TVDss) 9300 76.3 58.09 6701.545 6008071 391870.6 1273.735 (6663 - 6719 TVDss) Closest A roach: Reference Well : CD3-3 07w 04 Plan Offset ell: Ford Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W - (323°) Comments Depth Incl. An le TRUE Azi. ND E + /W - (323°) Comments POOL Min Distance POOL Min Distance (6809.48 ft) in POOL (6809.48 ft) in POOL (6663 - 6719 TVDss) (6663 - 6719 TVDss) to Fjord 5 (ATDB) to CD3-307wp04 Plan 6809.48 11800 65.79 6.45 6713.745 6007381 396282.5 -1885.318 (6663 - 6719 TVDss) 6800 1.36 152.54 6675.534 6012648 391966.8 4990.449 (6663 - 6719 TVDss) POOL Summaryl 3/31/2006 9:23 AM • • ~E: CD3-307 C • Subject: f2E: CD ~- till;' From: "Johnson, ~~'rrn" <Vern.Johnson~conocophillips.con~~= llate: Thu, 06 Apr ?OOCi Q9:?3:O6 -0800 To: 7 homas >\~launder <tom maunder(iadmin.state.ak.us=> CC: Steve Davies <ste~~edaviesrc!.achnin.state.ak.us~=, staatsl ~ciprudhoe-bay.oilfield.slb.com, "Smyth, Robin .I." <-fZobin.,1.Smylhrj!ci;:conocop}~illips.com==, "Walker, Jack 1~~~ -Jack.:~.Wall.crlc~.~conocophilli_ps.com~=, "Sch«-artz, Gary L" <Guv.L..Sch~~art~(~i~conocophillips.com-~, "Noel, Brian" =~13rian.Noe](1'conocophillips.com=, Tom, In answer to your questions below: 1. We think the risk of firing the guns while circulating and setting the packer is extremely low. This is an excerpt from an email from Schlumberger: "What Bob Staats is proposing as a firing mechanism is "e-Fire / redundant TCF"... Which in simple terms means a primary firing head which requires a unique firing pressure signature in order to set it off. Normal hydrostatic or an increase to set a packer etc will have no effect on it. Only when a certain set of pre-defined conditions are met ... Like over-pressure 500 psi, hold 5 minutes, drop pressure hold steady for 10 minutes, over pressure 750 psi, hold for 10 minutes, drop pressure hold steady for 5 minutes and over pressure for 500 psi and release.... Wait 30 minutes, guns fire.... The total delay between running in hole this type of firing head and actually firing is limited to 240 Hrs or with special batteries up to 1000 hrs. AS a back up a secondary system includes a Trigger Charge Firing Head, which involves running a contained firing head and downward facing charge, which is landed out using slickline, the SL recovered and then pressure up to fire. This will not be in the hole during packer setting operations and will only be used in the extremely unlikely event of a malfunction of the primary system." Bob Staats can help with any further questions you might have. 2. Shooting and flow testing will happen after the rig moves off the well (provided we see sufficient Kuparuk sands). I spoke with Jack Walker and we agreed that we would handle those details in a sundry permit. 3. Thanks for the feedback, I sent your message to the Sperry directional planner for follow up. Let me know if you have any further questions. Vern -----Original Message----- From: Thomas Maunder [mailta:tom maur_der~admin.state.ak.us] Sent: Wednesday, April 05, 2006 10:40 AM To: Johnson, Vern Cc: Steve Davies Subject: CD3-307 Vern, We are reviewing this application. A couple of questions ... 1. You are running TCP guns as part of the completion. When doing all the circulating and packer setting, is there any risk of firing the 1 of 2 4/6/2006 12:52 PM CD3-307 • • Subject: CD3->07 From: Thomas Maunder ~_tommaundcr(a7admin.state.ak.us=~ Date: \t'cd. 0~ r~pr 2006 1 t?:39:3 -OSt)0 To: ~~'en~ Johnson <Vern.Johnson(cL~.conocophillips.coni CC: Steve Day ics < teve day ies(~i~aiimin.state.ak.us=. Vern, We are reviewing this application. A couple of questions ... 1. You are running TCP guns as part of the completion. when doing all the circulating and packer setting, is there any risk of firing the guns? 2. You show the rig leaving after running the completion. What are the plans for shooting and flowing/testing? Nothing is included to describe those operations. Those plans should be included here or the production people can provide the plans via sundry. 3. The 3-D plots are very informative with regard to the spatial relationship of the wells, thanks for including. One request, could you have the font darkened "closest in pool" plot (well name) and listing (2nd and 3rd columns). Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 4/5/2006 10:46 AM • • SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS f 142 ATO 1530 70o G ST, / ANCHORAGE AK 99501 j ~v~ DATE _ PA v TO THE 56-1551/441 y ORDER OF ! / + / ~ ~ ft L~-~ ' ' p~-C~C CC ~ ~O p oU .~_---_ ~ ~. ~~ W A ~ anChase ~ j ~~,<~au, JPMorgan Chase Bank, N.A. Valid Up To 5000 Dollars Columbus, OH } ~- , MEMO ~. c\- 6~iL~y _ ' ~ - --- 1 ' 0 4 4 1 15 5 i 1 ~: 5 28 ? 4? 19.0 ? 9~ 7 u ------ 'Li42 ~ • • TRANSMITTAL LETTER CHECKLIST WELL NAME L'2GC, C~ 3 ' 3~ ~ PTD# ~~l° ~ O ~~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) 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. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas 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 ro ram. Rev: 1 /25/06 C: \j ody\transmittal_checklist ~ • ^ ^ °' ~ o y m a rnm •- m ° p - 'O • N O ~ c ~ >' ~O ~ ~ C, ~ , ~ ~ ~ ~ ~ Vl' ~ ~ ~ M' ~ ~ ~ ~ ~'~ c O N O N °~ ~, ~ c ~ ~ m, ~ 3 o Y ~ ~, C, p O ~ ~ O p Q ~ Q aao 3 ~ ~: ~, p, s. ~ ~ U ~ N ~ ~ ~ =p L~ o. ~ N ~ ~ ~ o o a~ N Y Z °2J y, . , p, O, N. 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O {0 N U O (O V :~:~ Q ~ ~ ~ ~ ~ ~ O N W O t6 V C V V p '- ~ O N y •= ~ ~ ~ O W o •E D a ~ a w c c~ U ~ ~ ¢ LL a cn ! a~ w a f- ~ acn • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 22 14:31:39 2006 • RECEIVED JUN 2 ~ 2006 Reel Header Service name .............LISTPE Date .....................06/06/22 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/22 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Colville River (Fiord Kuparuk) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JOB NUMBER: MW0004332755 LOGGING ENGINEER: R. KRELL OPERATOR WITNESS: D. LUTRICK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 15T STRING 2ND STRING 3RD STRING PRODUCTION STRING A18Sk30~&C7a6GOn Scientific Technical Services Scientific Technical Services CD3-307 501032052900 ConocoPhillips Alaska, Inc Sperry Drilling Services 22-JUN-06 5 12 5E 3926 797 49.55 13.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 3093.0 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. THIS WELL WAS DRILLED TO THE INTERMEDIATE CASING POINT. IT WILL BE RE- ENTERED AND DRILLED TO THE PLANNED TD NEXT WINTER (2006/2007). 4. MWD RUNS 1 AND 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), ACOUSTIC CALIPER (ACAL), PRESSURE WHILE DRILLING (PWD), AND GEOPILOT ROTARY-STEERABLE BHA (GP). 6. 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 DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1-3 REPRESENT WELL CD3-307 WITH API#: 50-103-20529-00. THIS WELL SECTION REACHED A TOTAL DEPTH (TD) OF 13030'MD/7043'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX) . CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.75" BIT) MUD WEIGHT: 9.6 - 9.8 PPG MUD SALINITY: 450 - 800 PPM CHLORIDES FORMATION WAT~SALINITY: 25000 PPM CHLORIDES. FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/22 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3069.0 12995.5 FET 3080.0 12988.0 NPHI 3080.0 12942.0 PEF 3080.0 12955.5 RPX 3080.0 12988.0 RPM 3080.0 12988.0 GALA 3080.0 12945.0 RPD 3080.0 12988.0 DRHO 3080.0 12955.5 RHOB 3080.0 12955.5 NCNT 3080.0 12942.0 FONT 3080.0 12942.0 RPS 3080.0 12988.0 ROP 3103.5 13030.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3069.0 13030.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN 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 INCH 4 1 68 4 2 ~ • FCNT MWD CNTS 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 RHOB MWD G/CM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD. HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3069 13030 ~ 8049.5 19923 3069 13030 CALA MWD INCH 8.55 10.24 9.11628 19631 3080 12945 FCNT MWD CNTS 608.08 3824 1165.4 19725 3080 12942 NCNT MWD CNTS 114272 204518 146831 19725 3080 12942 RHOB MWD G/CM 0.004 3.363 2.41315 19752 3080 12955.5 DRHO MWD G/CM -2.818 0.267 0.0453267 19752 3080 12955.5 RPD MWD OHMM 0.58 2000 7.10627 19817 3080 12988 RPM MWD OHMM 0.46 87.14 5.52237 19817 3080 12988 RPS MWD OHMM 0.46 44.03 5.24843 19817 3080 12988 RPX MWD OHMM 0.62 44.77 5.09137 19817 3080 12988 FET MWD HOUR 0.14 68.62 0.567468 19817 3080 12988 GR MWD API 40.99 391.23 113.129 19854 3069 12995.5 PEF MWD BARN 1.84 14.09 2.78059 19752 3080 12955.5 ROP MWD FT/H 0.98 393.45 180.95 19854 3103.5 13030 NPHI MWD PU-S 11.82 53.54 31.2719 19725 3080 12942 First Reading For Entire File..........3069 Last Reading For Entire File...........13030 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/22 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name.... Version Number...........1.0.0 Date of Generation.......06/06/22 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # • FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3069.0 PEF 3080.0 RPX 3080.0 FET 3080.0 RPS 3080.0 NPHI 3080.0 RPD 3080.0 DRHO 3080.0 RPM 3080.0 RHOB 3080.0 NCNT 3080.0 FONT 3080.0 CALA 3080.0 ROP 3103.5 s LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12995.5 12955.5 12988.0 12988.0 12988.0 12942.0 12988.0 12955.5 12988.0 12955.5 12942.0 12942.0 12945.0 13030.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den ACAL Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 22-APR-06 Insite 68.18 Memory 13030.0 3103.0 13030.0 56.7 89.3 • TOOL NUMBER 149206 96540 179954 10507555 727422 8.750 3093.0 Polymer 9.70 41.0 8.9 600 3.6 2.820 60.0 1.155 156.2 4.250 60.0 2.180 60.0 REMARKS: • • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GALA MWD030 INCH 4 1 68 4 2 FONT MWD030 CNTS 4 1 68 8 3 NCNT MWD030 CNTS 4 1 68 12 4 RHOB MWD030 G/CM 4 1 68 16 5 DRHO MWD030 G/CM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 RPM MWD030 OHMM 4 1 68 28 8 RPS MWD030 OHMM 4 1 68 32 9 RPX MWD030 OHMM 4 1 68 36 10 FET MWD030 HOUR 4 1 68 40 11 GR MWD030 API 4 1 68 44 12 PEF MWD030 BARN 4 1 68 48 13 ROP MWD030 FT/H 4 1 68 52 14 NPHI MWD030 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3069 13030 8049.5 19923 3069 13030 GALA MWD030 INCH 8.55 10.24 9.11628 19631 3080 12945 FCNT MWD030 CNTS 608.08 3824 1165.4 19725 3080 12942 NCNT MWD030 CNTS 114272 204518 146831 19725 3080 12942 RHOB MWD030 G/CM 0.004 3.363 2.41315 19752 3080 12955.5 DRHO MWD030 G/CM -2.818 0.267 0.0453267 19752 3080 12955.5 RPD MWD030 OHMM 0.58 2000 7.10627 19817 3080 12988 RPM MWD030 OHMM 0.46 87.14 5.52237 19817 3080 12988 RPS MWD030 OHMM 0.46 44.03 5.24843 19817 3080 12988 RPX MWD030 OHMM 0.62 44.77 5.09137 19817 3080 12988 FET MWD030 HOUR 0.14 68.62 0.567468 19817 3080 12988 GR MWD030 API 40.99 391.23 113.129 19854 3069 12995.5 PEF MWD030 BARN 1.84 14.09 2.78059 19752 3080 12955.5 ROP MWD030 FT/H 0.98 393.45 180.95 19854 3103.5 13030 NPHI MWD030 PU-S 11.82 53.54 31.2719 19725 3080 12942 First Reading For Entire File..........3069 Last Reading For Entire File...........13030 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/22 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF • Tape Trailer Service name .............LISTPE Date .....................06/06/22 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................06/06/22 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services End Of LIS File
