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210-031
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS rvtCdrCIVr.LJ APR Oil 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 p n 0 ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well O Reenter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic❑ Service ❑+ 210-031-0 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20617-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: CRU CD3 -123 ADL 372105 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17,142 feet Plugs measured None feet true vertical 7,034 feet Junk measured None feet Effective Depth measured 17,142 feet Packer measured 9730, 9795 feet true vertical 7,034 feet true vertical 6621, 6648 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16 114' MD 114' TVD SURFACE 2,797 feet 95181, 2,833' MD 2462' TVD INTERMEDIATE 11,008 feet 7 11,041' MD 6952' TVD LINER 6,314 feet 3 1/2 " 17,140' MD 7034' TVD Perforation depth: Measured depth: SLOTS 11059-13833, 13988-15910. 16287-17071 feet True Vertical depth: SLOTS 6954-6997, 7002-7024. 7030-7037 feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 10,848' MD 6,930' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PACKER TCII 9,730' MD 6,621' TVD PACKER - BAKER PREMIER PACKER 9,795' MD 6,648' TVD SSSV - NONE 2,137' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: - 2000 - 1000 3870 Subsequent to operation: - 1400 - 670 3480 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development ❑ Service O Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct t0 the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-560 Contact Name: Kyle Hampton Authorized Name: Kyle Hampton Contact Email: kyle.hampton@cop.com Authorized Title: Sr. Wells rngineer fI I Contact Phone: (907) 263-4627 Authorized Si "'I nature: Date : Form 10-404 Revised 4/2017 1 M 411011'? / .0 �(�0' RBDMS �E"'APR 0 9 2019 Submit Original Only ConocoPPhillips MARKS. ITS; WNS INJ WELLNAME CD3 -1123 WELLBORE CD3 -123 ' SSSV: TROP I I I Last WO'. 3/1012016 141 70 HORIZONTAL- C0319, 46601913m WPM Last Tag VerhY VJwYc Hemi Annolafion Won (me) End DN Wellbore lu[Motl BY Last Ta,'. CD3 -12 Lnosbor ......................................................................................... Last Rev Reason 1MW.r AS- AnnWlion End Oahe Wtllbore Iasi MM By Rev Reason: Post RWO I I CD3 -123 IDOeforne Casing Strings 10 (n) Top Me) 6eh10 IXHBI Seh,0 (NDI_. 6... GOA.Oescrlprlon 16 HHO WELDEDld CONDUCTOR 24" 16 1525 36.0 1140 114.0 82.50 Hd0 WELDED 6250 InsingIMDriven ,,,,_ B) Sat MKS) BN Oe2M INO1... WVLen 11._HSOones CasSURFDescrlpWn Wit9Sol ,, ,,,,,, _ BTCTopTMm4 8,83 35.7T*P 2,M3.0H SURFACE 9518 8.83 35.7 2,833.0 2,462.2 40.00 LA0 TOPT nature poser,tim on (1") ID6n1 Tap(nX01 6H DepN (nKB) fiel OepM IN01.., WVLen 11... GrWe Top ThreaO INTERMEDIATE J 6.28 33.5 11,041.3 6,952.1 2600 L-80 BTC -m Crtied W.dAtion OD lint IDbm Top(..) abl Won IXnin se+Depth(Tvrn-. WVLen p..Greoe Top Thrxi LINER 3112 2.99 10,8262 17,1400 7,0337 9.30 L-80 SHIFT Liner Details Ke ekbe offTubkol:7p+ overtrain) Topil Top nivouOKB) TIP Incl C) been Oes Com (in) CONDUCTOR N'ln DeMeriafi.anao aarwr nw-ot- 10,826.2 6,927.9 82.9] SLEEVE a er "x7"'HRD"liner Belong Ieeve(5.5"I ) 4 N (5 79 OD' x 434" IDI x,moowlmdeak mB 10,8393 6,929.5 83.07 NIPPLERS Iew collar on top nm 426p ea pp (5.64'' OD x 4260" ID) xkow-x: z4mJ k+ vALve. z.lno 044 10,843.0 6,9299 63.10 HANGER Baker "x 7' lexlopk liner hanger(. x 4420 ID) 10,052.7 6,931.1 83.17 XO BUSHING Crossover Bushing IS 58' x393"ID) 3.930 10.869.0 6,9316 83.30 XO - Retuning Crossover 4-112" SLHT x 3-12" SLHT 2.992 Tubing Strings Thin C11111fion smog soo-)'DomraP MKS) set Depth ln.. seh Cepn inve)I.. In (,bell) Grunt rop Connetion TUBING 4.5"x3.5" 312 2.99 0.6 9,786.3 6644.4 9.30 L-80 Hyd 563 SURFACk WT-zBeo Completion Details TIP(NOI ToPlnch nornme Toppling) Me)(') San Dx Co. to Ont 31.2 31.2 0.00 Hanger FMCHomanlal Gen II11"x4-12" tubinghanger 3.920 MmW RW-rzPPy cl B�Ir�x 2.137.1 2-w2.3 40.66 Nipple -X Camco 3-12'x2.8 Xlancing nipple 2.813 2.SC.7na.0 anBRme 9703.1 7609.0 63.93 L I" Camco 3-12'x 1•KBMG 2.992 KBMG 9729.9 E7620 6453 PACKER Baker 7" x 312" Premier Pecker TCII 2870 SLBi+?nifikk M.1 66325 65.09 Nippie-X Camco 3-12'x .1" X landing nipple %7M8 6641.3 6548 Overshot Baker 7"x 3.Ync sealing Wring stub eversMt 4.60 iuMp %Oihea4r: e./ID.0 Tubing downpoursbiuB Ma.. -ID (in) Top IXa01 a.IMMM ln.4ed Nion IND)(... WHIMtI Grade Toptennedien PAOKeel g7mg Original Packer Ass, 3112 2.99 9,782.1 10,848.6 6,9306 980 LA0 EUE-m rwxoxonviefts.7sa.a Completion Details TOP IND) TOP incl Nominel Nilge-X: B.T1T.8 Top hiIXKB) () nem ors Com IO lin t 95 9.).1 6,648.0 65 JB PACKER Baker -11 "xT Former Packer -Camaro element .4 'tlown / 2.870 hop 1.9 6,667.3 6669 NIPPLE HES 3117'XN" nipple(XXN PLUG INSTALLED) 275) Tud.p XOThvbdu9M2 108231 692].5 82.95 LOCATOR Sheer pinned Fluted NoFGo Su4 above no 90 3000 1=4 6,W7 7 82.96 LOCATOR Sheer pinned Fluted NoGo Sutr hence, nogo 3000 awrsnm. e.nae 10,847.6 6.930.5 83.14 WLEG 3-12'9.3 pp1 L-8018¢ ALLIED -Fluted 112 muleshoe 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top CTD) Top Ina PACKER:.71I rop IXKB) (Xxel p) Des Com Run OaM ID lin) 2.II u 2,002.2 40.65 1i o VALVE e- . 11NJ VALVE i "X -L K ( /N: 5 14-111 4 3/1912019 BEAN) NIPPLE, %ii Perforations & Slob Shot Cents P HTVO1 BtmIND) IsM4M LOCATOR', 10,8231 1,1111KBI BMIXKB) (XKB) (XK01 L1nkMZone Whe 1 Type Com LOCATOR: notar.z 11,059.0 13,8330 6,9537 6,9968 NFFIrchu D- 123 4120/2010 32.0 SLOTS I0u1/ 5', M.1aft v, 4 rowslq no slots T from Boxlvin 13988.0 45.910.0 7.0022 7,0244 Nechelik, D - 4/2072010 320 TOTS lou 197TY, sI.Wrow, 123 4 rowslX, no slots 3' from bOxlpin VILE.. OD SPA 162870 17,0710 7,0302 7,0374 Nechelik,D 420/2010 320 SLOTS St.% IMI 8 so row. 123 4 rowale no slats 3' herrn boxlpin Mandrel Inserts n ab Non Top IND) Tap lfKR) MKS) Make Me4el ODpnl Eery VAN. Type Lath Type Pwl seta (in) TRO Run Bob) Run Dtla Com 1 97031 6.609.0 Camco 1 GAS LIFT DMY BEN 311]2019 Notes: General & Safety End Co. AmroMibn 4/262010 NOTE VIEW SCHEMATIC wIAlaska Scic9 her .0 INTERMEDIATE, 33.5110ai3 SLOTS. ifM I6I%Raao M.: 13WB616,e1g0 6L0T6: learC.f7,%1.0 UNER:IOS282-17,1400- Operations Summary (with Timelog Depths) CD3-123 Rig: DOYON 142 Job: RECOMPLETION Time Log Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth di Entl Depth rite) 3/4/2019 3/5/2019 12.00 MIRU MOVE MOB P Rig down. Pull support mods apart 0.0 0.0 12:00 00:00 and stage on pad. Pull sub off Tinmiaq 10. Move rig towards CD3. Clean location at Tinmiaq 10. 3/5/2019 3/5/2019 12.75 MIRU MOVE MOB P Move rig to CD3. 0.0 0.0 00:00 1245 3/5/2019 3/5/2019 0.75 MIRU MOVE MOB P Lay mats and herculite for 0.0 0.0 12:45 13:30 1 1 substructure. 3/5/2019 3/5/2019 4.50 MIRU MOVE MOB P Spot substructure over CD3-123. Set 0.0 0.0 13:30 18:00 stompers. Remove load hitch. Skid rig to drilling position. 3/5/2019 3/5/2019 1.50 MIRU MOVE MOB P Stage pump room and pits at end of 0.0 0.0 18:00 19:30 well row. Set mats and herculite. Spot pits. 3/5/2019 3/6/2019 4.50 MIRU MOVE MOB P Lay mats and herculite. Spot pump 0.0 0.0 19:30 0000 room, motor room and pipe shed. 3/6/2019 3/6/2019 0.50 MIRU MOVE MOB P Spot rock washer. 0.0 0.0 00:00 0030 3/6/2019 3/6/2019 3.50 MIRU MOVE RURD P Hook up interconnects, rig up pipe 0.0 0.0 00:30 0400 skate and beaver slide. Complete rig acceptence check list. Lay mats for camp and shop. Accept rig at 04:00 hrs 3/6/19 3/6/2019 3/6/2019 3.00 MIRU WELCTL RURD P Rig up circ lines in cellar Sim- 0.0 0.0 04:00 07:00 ops/Move camp off Tinmiaq 10 starting at 04:30 hrs. 3/6/2019 3/6/2019 4.00 MIRU WELCTL WAIT T Wait on seawater. Sim-ops/Repair TO 0.0 0.0 07:00 11:00 energy track. Mobilize speed head adaptor to BOPE deck. 3/6/2019 3/6/2019 3.00 MIRU WELCTL RURD P Take on 580 bbls seawater to mud 0.0 0.0 11:00 14:00 pits. Rig up to take returns to cuttings tank. Blow air through lines. Purge lines for pressure test. Sim-ops/Camp arrived on location at 11:00 hrs. Spot and set camp. 3/6/2019 3/6/2019 2.75 MIRU WELCTL SFTY T Secure well and evacuate rig to 0.0 0.0 14:00 16:45 primary muster area due to emergency response needed for other rig on location. All personnel accounted for. 3/6/2019 3/6/2019 0.75 MIRU WELCTL SEQP P Purge circ lines with seawater and test 0.0 0.0 16:45 17:30 to 3000 psi. Bleed off and blow down lines. 3/6/2019 3/6/2019 0.75 MIRU WELCTL MPSP P Rig up and pull BPV Tubing=0 psi, 0.0 0.0 17:30 18:15 IA=0 psi, 01160 psi 3/6/2019 3/6/2019 1.75 MIRU WELCTL CIRC P Circulate 43 bbls 8.5 ppg seawater 0.0 0.0 18:15 20:00 down IA taking returns up tubing. ICP=330 psi at 3 bpm. FCP=473 psi at 3 bpm. Shut down pump 171 bbls 8.5 ppg seawate down tubing taking returns up IA. ICP=423 psi at 3 bpm, FCP=280 psi at 3 bpm. Total strokes pumped=1906 3/6/2019 3/6/2019 0.50 MIRU WELCTL 01 P Monitor well. Static. 0.0 0.0 20:00 20:30 3/6/2019 3/6/2019 1.00 MIRU WELCTL MPSP P Set Type H BEV. Test to 1000 psi/10 0.0 0.0 20:30 21:30 mins from below. Blow down and rig down circ lines. 3/6/2019 3/6/2019 1.25 MIRU WHDBOP NUND P Nipple down tree. Pull smooth bore 0.0 0.0 21:30 2245 metal seal. Disconnect and secure SSSV control line. Install blanking plug. Page 114 ReportPrinted: 3/11/2019 Operations Summary (with Timelog Depths) �, .. CD3-123 Rig: DOYON 142 Job: RECOMPLETION Time Log StaRTime End Time our(hr) Phase Op Code Activiy Code Time P-T-X Operabon Start Depth dtKB) End Depth ptKB) 3/6/2019 3/7/2019 1.25 MIRU WHDBOP NUND P Nipple up adapter flange and 11"x 13 0.0 0.0 22:45 00:00 5/8" adapter spool. 3/7/2019 3/7/2019 1.50 MIRU WHDBOP NUND P Nipple up BOPS. Re-position FMC 0.0 0.0 00:00 01:30 speed head. 3/7/2019 3/7/2019 3.50 MIRU WHDBOP NUND P Connect choke and kill lines. Install 0.0 0.0 01:30 05:00 bell nipple and riser. Grease choke manifold and BOPE valves. 3/7/2019 3/7/2019 1.00 MIRU WHDBOP BOPE T Install 41/2" test joint. Conduct shelll 0.0 0.0 05:00 0600 test with closed annular preventer, floor kill valve. CV 1, 12, 13,14. 250/2500 psi for 5 mins each. Tighten Oteco clamps on kill and choke lines, 3/7/2019 3/7/2019 1.00 MIRU WHDBOP BOPE T Retorque LDS on tubing spool. 0.0 0.0 06:00 0700 1 3/7/2019 3/7/2019 6.00 MIRU WHDBOP BOPE T Troubleshoot and diagnose leaks. 0.0 0.0 07:00 1300 Isolate and test BOPE/choke valves. Obsrerve flow out of the IA due to blanking plug not holding. Observe DSA leak on flange below lower pipe rams. Tighten spacer spool and choke line connection. Open annular preventer and purge lines and BOPE. 3/7/2019 3/7/2019 6.50 MIRU WHDBOP POPE P Test Upper and lower rams 250 psi 0.0 0.0 13:00 1930 low - 4,500 psi high for 5 min's each using 3 1/2" and 4 1/2" test joints, Test annular 250 psi low-2500 psi high for 5 min's each using 3 1/2" test joint, Test choke Test choke valves 1- 14, Annular, upper pipe rams, lower pipe rams, blind rams, manual/HCR choke & kill lines, 4" floor valves, Test gas alarms, PVT and Flow show. Test hydraulic and manual chokes drawdown. Perform accumulator test. Starting pressure=3000 psi, after function=1700 psi, 200 psi attained=9 sec's, full recovery=73 sec. 6 nitrogen bottles at 2054 psi. Witness waived by AOGCC Inspector Adam Earl 3/7/2019 3/7/2019 0.75 MIRU WHDBOP BOPE P Rig down testing equipment. Blow 0.0 0.0 19:30 2015 down lines. 3/7/2019 3/7/2019 0.25 COMPZN RPCOMP MPSP P Pull blanking plug and BPV. Monitor 0.0 0.0 20:15 2030 well for 10 min's. Static. 3/7/2019 3/7/2019 1.00 COMPZN RPCOMP THGR P PJSM-Make up landing joint and X-O 9,770.0 9,738.0 20:30 21:30 to top drive. BOLDS. Unseat hanger with 117K PU. Pull to 128K to free pipe. 107K free travel PU. wt. Pull hanger to rig floor 3/7/2019 3/8/2019 2.50 COMPZN RPCOMP CIRC P Establish circulation with 8.5 ppg 9,738.0 9,738.0 21:30 0000 seawater at 2 bpm, 60 psi. Stage rate up to 6 bpm, 700 psi, 8% FO. Sim- ops/ Rig up GBR equipment. 3/8/2019 3/8/2019 1.75 COMPZN RPCOMP CIRC P Circulate 8.5 ppg seawater at 6 bpm, 9,738.0 9,738.0 00:00 01:45 675 psi 3/8/2019 3/8/2019 0.75 COMPZN RPCOMP OWFF P Monitor well. Static 9,738.0 9,738.0 01:45 0230 3/8/2019 3/8/2019 0.25 COMPZN RPCOMP RURD P Lay down tubing hanger. Rig up 9,738.0 9,738.0 02:30 0245 control line spooler. Terminate SSSV control line. 3/8/2019 3/8/2019 4.75 COMPZN RPCOMP PULL P POOH laying down 3 1/2" 9.3# L-80 9,738.0 7,642.0 02:45 07:30 EUE 8rd tubing from 9738' MD to 7642' MD. Page 2/4 Report Printed: 3/11/2019 Operations Summary (with Timelog Depths) CD3 -123 Rig: DOYON 142 Job: RECOMPLETION Time Log shut Time End Time Our (M Phase Op Code ActivityCode 7me P -T- X Operation Start Depth rt Ke) End Depth (flKB) 3/8/2019 3/8/2019 0.50 COMPZN RPCOMP RURD P Rig down and clear from floor SLB 7,642.0 7,617.0 07:30 08:00 control line spooler. Lay down SSSV. Recover 69 stainless steel bands. 3/8/2019 3/8/2019 6.25 COMPZN RPCOMP PULL P POOH laying down 3 1/2" 9.3# L-80 7,617.0 2,758.0 08:00 14:15 EUE 8rd tubing from 7617' MD to 2758' MD. PU=64K SO=66K 3/8/2019 3/8/2019 0.75 COMPZN RPCOMP EORP T Troubleshoot and cool down GBR 2,758.0 2,758.0 14:15 15:00 1 hydraulic power unit. 3/8/2019 3/8/2019 0.25 COMPZN RPCOMP PULL P POOH laying down 3 1/2" 9.3# L-80 2,758.0 2,638.0 15:00 15:15 EUE 8rd tubing from 2758' MD to 2638' MD. PU=64K SO=66K 3/8/2019 3/8/2019 0.75 COMPZN RPCOMP RURD T Change out GBR hydraulic power unit. 2,638.0 2,638.0 15:15 16:00 3/8/2019 3/8/2019 3.50 COMPZN RPCOMP PULL P POOH laying down 3 1/2" 9.3# L-80 2,638.0 0.0 16:00 19:30 EUE 8rd tubing from 2638' MD to surface. Recover 2 its 4 1/2" tubing, X- O, 302 its 3 1/2" tubing, 1 cut it at 14.82', 1 SSSV w/ X nipple and 3 GLM's. 69 stainless steel bands recovered. 3/8/2019 3/8/2019 2.50 COMPZN RPCOMP RURD P Change out X -O on floor safety valve, 0.0 0.0 19:30 22:00 Dress GBR tongs for 4 1/2". Load and strap completion jewelry in pipeshed. Mobilize hanger to rig floor. Drift and strap space out pup joints. 3/8/2019 3/9/2019 2.00 COMPZN RPCOMP PUTB P PJSM- Pick up and RIH with 3 1/2" 0.0 1,345.0 22:00 00:00 9.3# L-80 Hyd 563 upper completion as per running order to 1345' MD. Torque connections to 2900 Polbs. 3/9/2019 3/9/2019 12.00 COMPZN RPCOMP PUTB P Pick up and RIH with 3 1/2" 9.3# L-80 1,345.0 9,700.0 00:00 12:00 Hyd 563 upper completion as per running order from 1345' MD to 9791' MD. Torque connections to 2900 ft/Ibs. Tag shear pins at 9788.1' MD. Slack off and shear pins with 1 O down weight. Slack off and no-go at 9791.7' MD. Confirm with 10K down weight. POOH from 9791' MD to 9700' MD. 3/9/2019 3/9/2019 1.00 COMPZN RPCOMP HOSO P Pick up 3 1/2" 9.82' long space out 9,700.0 9,744.0 12:00 13:00 pup, X -O, one joint of 4 1/2" tubing to 9744' MD. 3/9/2019 3/9/2019 0.75 COMPZN RPCOMP THGR P Make up and orient tubing hanger as 9,744.0 9,770.0 13:00 13:45 per FMC. Rig up headpin on landing joint. RIH to 9770' MD. 319/2019 3/9/2019 2.25 COMPZN RPCOMP CRIH P Make up circ hose. Break circulation 9,770.0 9,770.0 13:45 16:00 at 3 bpm, 250 psi, 2% FO. Pump 275 bbls of 8.5 ppg seawater with 1% CRW-132 corrosion inhibitor. Chase with 70 bbls 8.5 ppg seawater. 3 bpm, 250 psi 2% FO. 3/9/2019 3/9/2019 1.00 COMPZN RPCOMP THGR P Land hanger. RILDS. PU=104K 9,770.0 9,786.3 16:00 17:00 SO=94K. WLEG set at 9786.3' MD original RKB. 3/9/2019 3/9/2019 1.50 COMPZN RPCOMP PRTS P Test hanger seals 250 psi low/5 min's. 9,786.3 9,786.3 17:00 18:30 5000 psi high/10 min's. Charted. Sim - ops/ Drop ball/roller rod. Page 3/4 Report Printed: 3/11/2019 MEMORANDUM TO: Jim Regg / P.I. Supervisor FROM: Matt Herrera Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May I, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. CD3 -123 COLVILLE RIV FIORD CD3 -123 See: Inspector Reviewed By: e10 P.I. Supry NON -CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3 -123 API Well Number 50-103-20617-00-00 Inspector Name: Matt Herrera Permit Number: 210-031-0 Inspection Date: 4/28/2019 Insp Num: mitMFH190429054050 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3 -123 Type Inj G 'TVD 6648 - Tubing 3,o8 3,-(j r31) 3z�1) PTD 2100310 - Type Test SPT Test psi 1662 IA zols 1911) 19(11) BBL Pumped: 2 BBL Returned. 2 OA 429 t 431 4z8 - Interval INITAL P/F P Notes: initial MIT -LA Post RWO Per Sundry 318-560 IA Pressure tested to 2000 PSI per Operator) Wednesday, May I, 2019 Page 1 of I a Operations Summary (with Timelog Depths) CD3 -123 Rig: DOYON 142 Job: RECOMPLETION Time Log Start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operabon Start Depth (ftKB) End Depth ptKS) 3/9/2019 3/9/2019 1.50 COMPZN RPCOMP PRTS P Pressure up tubing to 4200 psi to set 9,786.3 9,786.3 18:30 2000 packer. Chart for 5 mins. Bleed tubing to 2000 psi. Test IA to 3000 psi and chart for 30 mins. Bleed tubing to 0 psi and shear SOV. Pump 4 bbls seawater down IA taking returns up tubing at 1.5 bpm, 222 psi. Pump 4 bbls down tubing taking returns up IA at 1.5 bpm, 260 psi. 3/9/2019 3/9/2019 0.25 COMPZN RPCOMP RURD P Lay down landing joint. Pick up T bar. 9,786.3 0.0 20:00 20:15 3/9/2019 3/9/2019 0.50 COMPZN RPCOMP MPSP P Set HP BPV. Test to 1000 psi/10 mins 0.0 0.0 20:15 2045 1 from below. 3/9/2019 3/9/2019 1.00 COMPZN WHDBOP RURD P Blow down choke and kill lines. De- 0.0 0.0 20:45 21:45 energize accumulator. Remove tubing running equipment from rig Floor. 3/9/2019 3/9/2019 2.00 COMPZN WHDBOP NUND P Nipple down BOPE. 0.0 0.0 21:45 2345 3/9/2019 3/10/2019 0.25 COMPZN WHDBOP NUND P Clean and prep top of hanger. 0.0 0.0 23:45 0000 3/10/2019 3/10/2019 1.50 COMPZN WHDBOP NUND P Clean top of hanger. Clean and inpect 0.0 0.0 00:00 01:30 tree. Rig up surface lines for freeze protect. 3/10/2019 3/10/2019 2.00 COMPZN WHDBOP NUND P Install test dart. Align and and nipple 0.0 0.0 01:30 03:30 up tree. Adjust for daylight savings time. 3/10/2019 3/10/2019 1.50 COMPZN WHDBOP PRTS P Fill tree with diesel.. Test tree to 250 0.0 0.0 03:30 05:00 psi/5000 psi for 10 mins each. Charted. 3/10/2019 3/10/2019 1.25 COMPZN WHDBOP PRTS P Test hanger void to 250 psi/5 min's, 0.0 0.0 05:00 06:15 5000 psi/10 min's. 3/10/2019 3/10/2019 0.25 COMPZN WHDBOP MPSP P Pull BPV. 0.0 0.0 06:15 06:30 3/10/2019 3/10/2019 3.25 COMPZN WHDBOP FRZP P PJSM- Rig up LRS. Test surface lines 0.0 0.0 06:30 0945 to 2000 psi. Pump 80 bbls diesel down IA at 2 bpm, 450 psi. Allow to u -tube for an hour. 3/10/2019 3/10/2019 1.75 COMPZN WHDBOP MPSP P Set H BPV Test BPV to 1000 psi/10 0.0 0.0 09:45 11:30 min's. IA=O psi, Tbg=O psi OA=200 psi. Sim-ops/Slip and cut drilling line. 3/10/2019 3/10/2019 0.50 DEMOB MOVE RURD P Blow down lines. Secure tree and 0.0 0.0 11:30 1200 cellar. Rig release at 12:00 hrs 3/10/19 Page 414 ReportPrinted: 3/11/2019 7',0 � !o -03l Victoria T From: Loepp, Victoria T (DOA) Sent: Tuesday, March 19, 2019 6:48 AM To: 'Hampton, Kyle' Subject: RE: [EXTERNAL]RE: CD3 -198 and CD3 -123 Well Status Post RWO Follow Up Flag: Follow up Flag Status: Completed Yes, adjust the 10-404 to WAG and hand change the 10-403 to WAG. I will adjust in our files. Thanx, Victoria From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Thursday, March 14, 2019 2:06 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: CD3 -198 and CD3 -123 Well Status Post RWO It looks like we have not submitted them yet. Can we make the adjustment on that form? From: Loepp, Victoria T (DOA) <victoria.loeppPalaska ¢ov> Sent: Thursday, March 14, 2019 2:03 PM To: Hampton, Kyle <Kyle.Hampton anconocophillips com> Subject: [EXTERNAL]RE: CD3 -198 and CD3 -123 Well Status Post RWO Have the 30-404s been filed yet? From: Hampton, Kyle <Kyle Ha mpton(cDconocophillips com> Sent: Thursday, March 14, 2019 1:05 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska aov> Subject: RE: CD3 -198 and CD3 -123 Well Status Post RWO Victoria, I wanted to follow up and see if you had a moment to look at the Well Status Change for CD3 -123 (PTD 210-031) and CD3 -198 (PTD 211-024). 1 was wondering what is required to change the status from GINJ to WAG; I misunderstood the intentions for the production team when the application was submitted. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 [ Kyle Hampton Pcop com From: Hampton, Kyle Sent: Wednesday, March 6, 2019 3:12 PM To: Loepp, Victoria T (DOA) <victoria.loeppPalaska aov> Subject: CD3 -198 and CD3 -123 Well Status Post RWO Victoria, I filled out the form for the 10-403 on these wells incorrectly for the post-RWO status. I just found out that the production engineering team would like to use these wells for water and gas injection, but I only checked the box for gas injection. Is there something I can do to change the injection status of these two wells? Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle. Hampton@coo.com GrD alv-o3 i Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, March 6, 2019 9:48 AM To: Loepp, Victoria T (DOA) Subject: RE: CD3 -123 (PTD# 210-031, Sundry 318-560) Rig Change for Approved WO Follow Up Flag: Follow up Flag Status: Flagged Kyle, Approval is granted to change rigs for the workover on CD3 -123 from Nordic 1 to Doyon 142. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCalalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victorio.Loeoo@alaska.aov From: Loepp, Victoria T (DOA) Sent: Wednesday, March 6, 2019 8:06 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: Fwd: C(33-123 Rig Change (PTD# 210-031) Sent from my iPhone Begin forwarded message: From: "Hampton, Kyle"<KVIe.HamptonCo)conocophillips.com> Date: March 5, 2019 at 9:28:25 AM AKST To: "Loepp, Victoria T (DOA)" <victoria.loepp@alaska.gov> Subject: CD3 -123 Rig Change (PTD# 210-031) Victoria, We are proposing to workover CD3 -123 with Doyon 142 (well control equipment attached). It was originally premised to be done by Nordic 1. Our planned move date onto CD3 is tomorrow, 3/6/2019. 1 apologize for such a short notice; we had some very immediate scope change. Please let me know if you have any questions. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle.Hampton@cop.com Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 210031 1 ;t TRANSMITTALDATE ' TRANSMITTAL # Room SERVICE ORDER LL NAME API # # 50-103-20617-00 ® 50-103-2079 SERVICE FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE Color DATE LOGGED Prints CD's envelope, taletc Receipt signature confirms that a package (box' - envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this courier or sign/scan and email a copy o chlumberger and CPAI. point. Iter2slb com Tom OsterkampPconocoohillios com SLB Auditor- TU • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 20,2018 TO: Jim Regg Supervisor �� 9visor Z?1($ SUBJECT: Mechanical Integrity Tests P.I.P CONOCOPHILLIPS ALASKA,INC. CD3-123 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-123 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 34Z-- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-123 API Well Number 50-103-20617-00-00 Inspector Name: Lou Laubenstein Permit Number: 210-031-0 Inspection Date: 2/11/2018 Insp Num: mitLOL180212124936 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-123 Type Inj W 'TVD j 6648 Tubing 2464 . 2464 - 2464 1 2464 PTD 2100310 " Type Test SPT Test psi 3000 IA 640 3320 - 3250 3230- --- -- --- -- BBL Pumped: -1 3 1BBL Returned: 3 OA 277 418 - 416 - 412 Interval P ✓ REQVAR Notes: MITIA per AIO 30.005 to Maximum anticipated injection pressure ✓ SCANNED t4 Tuesday,February 20,2018 Page 1 of 1 RECEIVED 2_56 `°'` MAY 10 2017 WELL LOG TRANSMITTAL# AOGCC To: Alaska Oil and Gas Conservation Comm. April 12, 2017 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 g ieG,/2017 . . Anchorage, Alaska 99501 MKBENDER RE: Leak Detect Log with ACX: CD3-123 Run Date: 3/11/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 CD3-123 Digital Data in LAS format,Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20617-00 Leak Detect Log with ACX 1 Color Log 50-103-20617-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari SCAMS 6900 Arctic Blvd. Y 'Lir/ Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, May 19, 2016 4:15 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: RE:CRU CD3-123 (PTD 210-031) Update 5-19-16 Attachments: CD3-123 90 day TIO 5-19-16.PNG Chris, CRU Injection well CD3-123 (PTD 210-031) was brought on miscible injection May 6th, 2016 and exhibited continuing TxIA communication. Due to the delayed start of the MI monitor period the diagnostics outlined below will be unable to be performed until the next ice road season. The well was WAG'd back to water today and will remain on water injection per AIO 30.005. A 90 day TIO plot is attached. Please let us know if you disagree or have any questions. Regards, Jan Byrne/Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. SCAN$EL Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 illiWELLS TEAM Comps 1'rorn NSK Problem Well Supv Sent:Thursday, February 11, 2016 3:25 PM To:Wallace;Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com> Subject: CRU CD3-123 (PTD.210-031) Report of intent to perform diagnostics Chris, CRU Injection well CD3-123 (PTD 210-031) is waivered for water injection only(AIO 30.005)due to historic TxIA communication while on miscible injection. CPAI intends to perform diagnostics on the well to determine the feasibility of regaining the well's miscible injection capabilities. The plan'is as follows; Perform biennial AOGCC witnessed MITIA(due 2/23/16). Circulate out well bore with clean fluids. Bring well online, on miscible injection for a 30 day monitor period. If there are no signs of TxIA communication while on miscible injection apply for c ncellation of the current AA. If there are signs of TxIA communication while on miscible injection the wellbore will be flushed out with water and then diagnostic logging will be performed in attempt to locate the leak and evaluate potential repair options. Upon conclusion of the diagnostics and/or monitor period CPAI will provide a follow up email with the plan forward and submit any required paperwork for corrective action or continued injection. Attached is a 90 day TiOtrend and wellbore schematic. w • cc :' Lu rn C7 11 „ N Q U N Lu CC a w ' E:-.' G O ,n Le, w = a r o v 71 a, w E rn w cc a ,; cc ,., I— to w c, J O r 1 IV J J c, . f O' O Bap 0 0 0 r Q4 to F. 0U07 Lc, 1 1 I I 1 I I I 4 1 — ---- - r2 2 C co S� r S. L .—? 45- .._ <-.."\'' ..: tD y ..4 . . U . C . .0 .2 : = 0 co , co ._ , .... . c _ , . .. 0 .2. .2. :._. co i . U_ O co C m E E V m 1— c �4 N 07 C Q a :2766: 1 r rel CV r M 0 Q1 G CI N N_ v u-o a $ I iI t # f s ' H 0 I '4u E I 1 1 1 u_ FnY kId RI O OO O Y1, I' ' Z O R n Oo On o n Oo OvOo Ou .t N 7 `7 „7 C. C J C J .. '^I !Sd �yV) Ow • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,February 19,2016 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-123 FROM: Brian Bixby COLVILLE RIV FIORD CD3-123 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-123 API Well Number 50-103-20617-00-00 Inspector Name: Brian Bixby Permit Number: 210-031-0 Inspection Date: 2/18/2016 Insp Num: mitBDB160218174313 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-123 Type Inj W"TVD 6648 -H Tubing 2660 -J 2660- 2660 - 2660 PTD 2100310 - Type Test SPT Test psi 1662 IA 830 3303 3224 3210 Interval REQVAR PAF P OA 489 713 700 700 Notes: A1O 30.005.Bruce wanted to test to 3000 00 psi because they are wanting to get the well back on MI injection. GLICtr- S Ar K° SEP262016 Friday,February 19,2016 Page 1 of 1 • • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, February 11, 2016 3:25 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: CRU CD3-123 (PTD 210-031) Report of intent to perform diagnostics Attachments: CD3-123.pdf; CD3-123 90 day TIO trend 2-11-16.JPG Chris, CRU Injection well CD3-123 (PTD 210-031) is waivered for water injection only(AIO 30.005) due to historic TxIA communication while on miscible injection. CPAI intends to perform diagnostics on the well to determine the feasibility of regaining the well's miscible injection capabilities. The plan is as follows; Perform biennial AOGCC witnessed MITIA(due 2/23/16). Circulate out well bore with clean fluids. Bring well online, on miscible injection for a 30 day monitor period. If there are no signs of TxIA communication while on miscible injection apply for cancellation of the current AA. If there are signs of TxIA communication while on miscible injection the wellbore will be flushed out with water and then diagnostic logging will be performed in attempt to locate the leak and evaluate potential repair options. Upon conclusion of the diagnostics and/or monitor period CPAI will provide a follow up email with the plan forward and submit any required paperwork for corrective action or continued injection. Attached is a 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with the plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 scpaiKi. Pager(907) 659-7000 pgr. 123 'WELLS TEAM ConocoPhillips 1 • • dwualfalot.13 • CD L) C o CC (NJ S— 1- 1 11 I II t 1 1 ' 11 4 III I, II di h if I I , 1 .1 .11 1 1 .1 1 I' • .1:,In : ..""---.... — • r — r- 5 1 N : : : — c1- li f- - - V - . - ' (• — 03 4—# :\1) 1-,r) 0 - = - a : �� — ' - - ` ' LC) : : - . . . H 0 : : : �' - 06 - - • - c� 1 Lo f _ r �ti • — ti) 'I C : II • • 1-40 — 7 YI. i 'i I I' I it P 1 ' I '1 I' III 'I 1' i ' I 1 II I ' f 1 {'• I 'I 0 1 'U w 0 C'J C`s1 r r ISd 1 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. QI 0 - 03i Well History File Identifier Organizing (done) ❑ Two -sided III VIII III III ❑ Rescan Needed 1 1 11111 1111 RE CAN DIGITAL DATA OVERSIZED (Scannable) 2 Dlor Items: ❑ ' kettes, No. Greyscale Items: Other, No/Type: ( ❑ Maps: e: a o ❑ Other Items Scannable b YP N by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: her:: CIZia BY: Date: 1/1 CO. V / /s/ IY Project Proofing 1 111111111111 BY: Date: iV r 9— /s/ P Scanning Preparation 13 x 3 = ° O ++ BY: Date: = TOTAL PAGES ) 10 1 (Count does not include cover sheet) J� �� /s/ Production Scanning I 1 Stage 1 Page Count from Scanned File: I 1 1 (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: 1/10 ti a- /s/ /44 P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1141111111 I ReScanned 1 1111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked II llhlIIIIIIII 12/22/2011 Well History File Cover Page.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,June 18,2013 P.I.Supervisor �l'�(( �f z.-if i, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-123 FROM: Jeff Turkington COLVILLE RIV FIORD CD3-123 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 012 NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-123 API Well Number 50-103-20617-00-00 Inspector Name: Jeff Turkington Permit Number: 210-031-0 Inspection Date: 6/13/2013 Insp Num: mitJAT130614195255 Rd Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-123 - Type Inj I W TVD I 6648 - 1 IA 1114 7 3195 - 3130 - 3114 - PTD Type Test _ — 2100310 Test psi' 2100310 yp SPT 2900 OA 577 693- 684 675 . Interval ''REQVAR P/F P Tubing 2458 2458 2458 1 2458 - Notes: AIO 30.005.3.0 bbl diesel to fill. SCANNED FEB 2 0 2014 Tuesday,June 18,2013 Page 1 of 1 c pc, 0 6 3- i 2-3 • • p7,6 ZIOO10 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, January 10, 2013 11:27 AM 12,619 i i QI' To: 'NSK Problem Well Supv' Cc: Schwartz, Guy L (DOA); Nelson, Tim J; NSK Well Integrity Field Supv; Wallace, Chris D (DOA) Subject: RE: CD3 -123 (PTD 210 - 031 -0) report of suspect TxIA communication You may WAG to water as described below. , - Jim Regg APR �� AOGCC SCANNED 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: NSK Problem Well Supv [ mailto :n1617@conocophillips.com] Sent: Wednesday, January 09, 2013 9:33 AM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Schwartz, Guy L (DOA); Nelson, Tim J; NSK Problem Well Supv; NSK Well Integrity Field Supv Subject: CD3 -123 (PTD 210 - 031 -0) report of suspect TxIA communication Chris, Alpine WAG injector CD3 -123 (PTD 210 - 031 -0) is suspected of TxIA communication based on reported high IA pressures, T /I /O = 3907/2999/559. The well has been shut in as of 1/9/13. I would like permission to WAG CD3 -123 to wa 0'161 period of 7days to flush the miscible gas from the well and near well bore. Down hole diagnostics will be scheduled as soon as possible. The well has been added to the monthly report. Pending the out come of the diagnostics, the appropriate paperwork will be submitted to continue injection or repair as needed. Attached are the Well Schematic and 90 day TIO plot. SCE: 2 t9ps; Roger Mouser for Brent Rogers /Kelly Lyons (t15 P? 7259)s; Problem Wells Supervisor ConocoPhillips Alaska, Inc L� a Desk Phone (907) 659 -7224 / I 4 Pager (907) 659 -7000 pgr # 909 1 C3– - CHOKE FTP — FTT IAP — OAP T/1/0 Plot - CD3 4000 I • 3 200 3000 – 150 i 2000 — • • • • • 100 -a-, a. _c 1000 50 0 „ . .11111 I 0 09-Oct-12 22-Oct-12 04-Nov-12 17-Nov-12 30-Nov-12 13-Dec-12 26-Dec-12 08-Jan-13 Date • WNS CD3 -123 �{)noc 1il Well Attributes Fleltl Name Well Status tes Inc/ ' MD ftKB 1 i a « TD Inc ( ° I ( ) Act Btm (ftKB) _• 76ps 501032061700 FIORD NECHELIK INJ 93.08 17,075.68 17,142.0 " Comment H2S (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date ' •• Wall Coot.: HORIZONTAL• CD3.123 29(20111122,55 AM SSSV: TRDP Last WO: 41.70 4/26/2010 matic - .Actual Annotation Depth (kKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: PULL PLUG & GAUGES Imosbor 2/9/2011 HANGER.31 it . P •.,, @ 3 :{ r.:- e:= F ., e '�" =1 1 e Dscriptlon String 0 ... String ID ... Top (ftKB) S et D ep th (f . Set Dept ( TV D) ... S tring Wt... S tri ng . .. String Top Thrd' _ t UCTOR 24" 16 15.250 36.0 114.0 114 6 H-4 WELDED Insulated Driven Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd C ,:. SURFACE 95/8 8.835 35.7 2,833.0 2,462.2 40.00 L - 80 BTC Casing Description String 0... String ID .,. Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd � Z�+ 1 `1 INTERMEDIATE 7 6.276 33.5 11,041.3 6,952.9 26.00 L - 80 BTC - m Casing Description String 0... String ID ... Top (068) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 10,826.2 17,140.0 7,033.7 9.30 L -80 SLHT r _ _ _ ° Liner Details , Top Depth (TVD) Top mcl Nomi... C24 DUSiaTd 'I " Top (ftKB) (MR) ( °) nem Description Comment ID On) Drive 36 114 /0 10,826.2 6,927.8 82.97 SLEEVE Baker 5" x 7" "HRD" liner Setting Sleeve(5.25" ID) (5.79 OD" x 4.34" ID) 4.340 10,839.3 6,929.4 83.07 NIPPLE RS Packoff Seal Nipple w/ X-0 collar on top & bttm (5.64" OD x 4.260" 4.260 ID) 10,843.0 6,929.9 83.10 HANGER Baker 5" x 7" Flexlock liner hanger (5.93" 00 x 4.42" ID) 4.420 10,852.7 6,931.1 83.17 X0 BUSHING Crossover Bushing (5.58" 00 8 3.93" ID) 3.930 SAFETY VLV _ =71' 10,869.0 6,933.0 83.30 X0 - Reducing Crossover 4 -1/2" SLHT x 3 -1/2" SLHT 2.992 2.137 IS Tubing Strings if, Tub ng Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top lhrd . TUBING 4.5 "x3.5" 3 1/2 2.992 30.6 10,848.6 6,930.6 9.30 L-80 EUE-m Completion Details Top Depth SURFACE. _ (TVDI Top Inc! 36-2.833 Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) 30.6 30.6 -0.08 HANGER FMC Tubing Hanger (11" x 4 -1/2 ") 3.958 GAS LIFT, 122.8 122.8 0.84 X0 - Reducing Crossover 4-1/2" IBT -m 12.6 ppf L -80 box x 3-1/2" EUE 9.3 ppf L -80 pin 2.992 4.347 2,137.2 2,002.6 42.07 SAFETY VLV 3-1/2" Camco TRMAXX -5E SSSV w/ 2.813" X profile (2.813" profile) 2.812 it 9,795.1 6,647.7 65.63 PACKER Baker 3-1/2" x 7" Premier Packer - center of element 2.40' down f/ top 2.870 it 9,842.9 6,666.8 67.28 NIPPLE HES 3-1/2" "XN" nipple 2.750 10,823.1 6,927,5 82.95 LOCATOR Shear pinned Fluted No-Go Sub- above no go 3.000 10,824.2 6,927.6 82.96 LOCATOR Shear pinned Fluted No -Go Sub- below no-go 3.000 10,847.6 6,930.4 83.14 WLEG 3 -1/2" 9.3 ppf L-80 IBT WLEG - Fluted 1/2 muleshoe 3.000 igr cASLIFr. P erforations & Slots 7643 Shot Top (TVD( Btm (TVD) Dens Top (ftKB) Btm (ftKB) (kKB) (kKB) Zone Date (ate--• Type Comment 11,059.0 13,833.0 6,954.1 6,996.7 Nechelik, 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; CD3 -123 no slots 3' from box/pin 13 15,910.0 7,002.2 7,023.9 Nechelik, 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ t; GAS LIFT' .7o5 � � CD3 -123 no slots 3' from box/pin s 16,287.0 17,071.0 7,030.3 7,037.4 Nechelik, 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; a. CD3 -123 no slots 3' from box/pin x a PACKER. 9.795 End Date • nnotetion 2. 4/26/2010 NOTE: INJECTION WELL WILL BE PRE- PRODUCED 4/26/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NIPPLE, 9,843 v si LOCATOR, 10,823 LOCATOR. 10.824.ti' I WLEG, 10,848 l I NTERMEDIATE. IUyiiji t'll,.pl- Ps - , 34- 11.041 Top Depth Top Port (TVD) Inc/ OD Valve Latch Size TRO Run Stn Top (068) (ftKB) 11 Make Model (in) Sery Type Type On) (pal) Run Date Com... 1 4,347.3 3,393.2 51.81 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/13/2010 SLOTS. . - = _±1= - = --= 2 7,943.1 5,587.9 52.42 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/13/2010 11,05313,833 - ______ 3 9,705.5 6,609.8 63.98 Camco KBMG 1 GAS LIFT DMY BKO-5 0.000 0.0 9/13/2010 III SLOT 13,988- 15.910 S, ,,, SLOTS. - 16,287. 17.071 - s - LINER. 1 I TO. 10.826.17.140N TD, 17,142 • DATA SUBMITTAL COMPLIANCE REPORT 10/27/2011 Permit to Drill 2100310 Well Name /No. COLVILLE RIV FIORD CD3 -123 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20617 -00 -00 MD 17142 TVD 7034 Completion Date 4/25/2010 Completion 1- IL p Status O Current Status WAGIN 40 REQUIRED INFORMATION Mud Log No Samples No Directional Survey — — DATA INFORMATION Types Electric or Other Logs Run: gr / res (data taken from Logs Portion of Master Well Data Maint Well Log Information: III Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number yame Scale Media No Start Stop CH Received Comments 1—D C Pdf 19610 ement Evaluation 9270 11150 Case 5/6/2010 Cement PDF, CGM, EMF, and TIFF graphics Log Induction /Resistivity 25 Col 114 17142 Open 5/7/2010 MD ROP, DGR, EWR og Induction/Resistivity 25 Col 114 17142 Open 5/7/2010 TVD ROP, DGR, EWR ED C Lis 19613% r- uction /Resistivity 2805 17100 Open 5/6/2010 OH EWR LIS plus PDF, CGM, EMF, and TIFF graphics Cog Cement Evaluation 12 Col 9270 11150 Case MD BAT, DGR C Asc ---'"--- Directional Survey 34 17142 Open pt Directional Survey 34 17142 Open Well Cores /Samples Information: Sample Interval Set • Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /1 Daily History Received? ON Chips Received? '`t-N Formation Tops 6 / N AnalysisN– Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/27/2011 Permit to Drill 2100310 Well Name /No. COLVILLE RIV FIORD CD3 -123 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20617 -00 -00 MD 17142 TVD 7034 C mpletion Date 4/25/2010 Completion Status 1 -OIL Current Status WAGIN UIC Y Compliance Reviewed By: 1��' Date: ,;\. • STATE OF ALASKA ALASaIL AND GAS CONSERVATION COMMI9IION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair w ell r Plug Frforations r Stimulate r Other jr. Convert to WAG Alter Casing f Pull Tubing r Perforate New Pool r Waiver r Time Extension r Aft ,i(. Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r eic.41-' 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210 - 0310 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 17 - 50 - 103 - 20617 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105 c CD3 - 123 9. Field /Pool(s): Colville River Field / Fiord Oil Pool 10. Present Well Condition Summary: Total Depth measured 17142 feet Plugs (measured) None true vertical 7034 feet Junk (measured) None Effective Depth measured 17140 feet Packer (measured) 9795 true vertical 7034 feet (true vertucal) 6648 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 2797' 9.625" 2833' 2462' Intermediate 11005' 7" 11041' 6953' Liner 6314' 3.5" 17140' 7034' AE CCIVED Perforation depth: Measured depth: 11059'- 13833', 13999'- 15910', 16287'-17071' True Vertical Depth: 6954'- 6998', 7001'- 7024', 7028' -7037' 0 CT 2 6 2.0 10 0484 1 tatI 4819aston•CW"uu" Tubing (size, grade, MD, and TVD) 4.5" x 3.5 ", L -80, 10849 MD, 6648 TVD Anebtialle Packers & SSSV (type, MD, and TVD) Baker Premier packer @ 9795' MD and 6648' TVD Camco TRMAXX -5E SSSV @ 2137' MD and 2003' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation 1400 jPoe g-57o 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service (5i Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND ] — WAG IV GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 310 -232 Contact Jack Walker a 265 -6268 Printed Name Jack Walker Title Principal Production Engineer Signature Phone: 265 -6268 Date 'J i kat-/—t-- 24 Oa- /0 i1C /o•2c Form 10 - 404 Revised 10/2010 Submit Original Only 0 4111K- /0-41 �,. , go WNS 41 CD3 -123 COnOCOPhilht 4 W. I Attributes Max Angle & MD TD Alaska, 1YY.: 1,",»' Wel!bore APIIUWI Field Name Well Status Inc/( ° ) MD (ftKB) Act Min (11613) , ',� t.rsRnc4Yhtlf�lu e _501032061700 FIORD NECHELIK INJ 93.08 1 /075.68 i 17,142.0 ... Comment )12S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date SSSV' 1 RDP I Last WO 41 /0 i 4/26/2010 ,..W. L.GHQ.R1� NTAL /o- A nIndI. 2P1Q ._ - Scher .. l vtb cwal_ _. .;,__ Annotation Depth (1 (6) End Date Annotation Last Mod ... 1End Date Last Tag. Rev Reason GLV C/O Imosbor 10/8/2010 HANGER, 31 „ Casing Strings '^' Casing Description String 0... String ID ... Top (ftKB) Set Depth (0... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR24" 16 15.250 36.0 114.0 114.0 62.50 H-40 WELDED Insulated Driven ! Casing D escription String 0._ String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String _. String Top Thhd SURFACE 95/8 8 -835 35.7 2,833.0 2,462.2 40.00 L.-80 BTC -M • I _ _ - Casing Description Siring 0... 5trin9 ID ._ Top (NKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - - - - - - INTERMEDIATE 7 6.276 33.5 11,041.3 6,952.9 26.00 L BTC - m I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... St Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 10,8262 17,1400 7033.7 9.30 L - 80 SLHT : . , . . - . Liner Details - - Top Depth CONDUCTOR (TVD) Top lncl Nomi... 24" Insulated TopN (fi r) than Description comment ID (in) D,Nen, 36 - + 10,826.2 6,927.8 82.97 SLEEVE Baker 5" x 7" "HRD" liner Setting Sleeve(5.25" ID) (5.79 OD" x 4.34" ID) 4.340 10,839.3 6,929.4 83.07 NIPPLE RS Packoff Seal Nipple w/ X -O collar on top & bttm (5.64" OD x 4.260" 4.260 ID) r. 10,843.0 6,929.9 83.10 HANGER Baker 5" x 7" Flexlock liner hanger (5.93" OD x 4.42" ID) 4.420 1. - 10,852.7 6,931.1 83.17 X0 BUSHING Crossover Bushing (5.58" OD x 3.93" ID) 3.930 SAFETY VLV, 10,869.0 6,933.0 83.30 X0 - Reducing Crossover4 -1/2" SLHT x 3 -112" SLHT 2.992 2,137 - Tubing Strings Tubing Descdption String 0... String ID ... Top (266) Set Depth (f Set Depth (TVD).. (String Wt... String String Top Thrd II TUBING 45235 ". I 2.992 I 306 10848.6 I 69306 930 L-80 EUEm Completion Details Top Depth I SURFACE, (TVD) Top Intl 9000... 36 -2,833 Top(ftKB) ( B) (°) Item Description _ Comment ID(in) 30.6 30.6 -0.08 HANGER FMC Tubing Hanger (11 "x4 -1/2 ") 3.958 Ilit GAS LIFT, 122.8 122.8 0.84 X0 - Reducing Crossover 4-1/2" I87 -m 12.6 ppf L -80 box x 3-1/2" EUE 9.3 ppf L-80 pin 2.992 4,347 - 2,137.2 2,002.6 42.07 SAFETY VLV 3 -1/2" Camco TRMAXX -5E SSSV w/ 2.813" X profile (2.813" profile) 2.812 9,795.1 6,647.7 65.63 PACKER Baker 3 -1/2" x 7" Premier Packer center of element 2.40' down f/ top 2.870 9,842.9 6,666.8 67.28 NIPPLE I HES 3 -1/2" "XN" nipple 2.750 10,823.1 6,927.5 82.95 LOCATOR Shear pinned Fluted No -Go Sub- above no go 3.000 I 10,824.2 6,927.6 82.96 LOCATOR Shear pinned Fluted No -Go Sub - below no-go 3.000 . 10,847.6 68304 83 -14 WLEG 3-1/2" 9.3 ppf L -80187 WLEG -- Fluted 1/2 muleshoe 3.000 it . 939 .,,' 4 a . , °? GAS LIFT, ='_ Perforations & Slots ,..... _ ].943 _. - -. Shot - Top (TVD) Min (TVD) Dens Top (ftKB ) Btrn )ftKB (ftKB) OMB) Zone Date ( Type Comment 11,059.0 13,833.0 6,954.1 6,996.7 Nechelik, 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; CD3 -123 no slots 3' from box/pin I GAS LIFT, 13,988.0 15,910.0 7,002.2 7,023.9 Nechelik, 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; 9,705 - -- CD3 -123 no slots 3' from box/pin ar 16,287.0 17,071.0 7,030.3 7,037.4 Nechelik, 4/20 /2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/roW, 4 rows/ft; IL CD3 -123 no slots 3' from box/pin Notes: General & Safety ItZtir PACKER,9,795 VIMMOIMMIIM End Date Annotation 4/26/2010 NO 10: INJECTION WELL WILL BE PRE- PRODUCED 4/26/2010 NO 10: VIEW SCHEMATIC w /Alaska Schematic9. 0 NIPPLE, 9,843 ilk LOCATOR, 4 ':`w . ` 10,823 LOCATOR, ______ 10,824 Mb If v 1 . 1 WLEG, 10,848 " 1 II NTERMEDIATE, Mandrel Details - - .-.- -- 34- 11.041 Top Depth Top Port ('VD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( ") Make .., Model (in) sere Type Type (in) (psi) Run Date Can... 1 4,347.3 3,393.2 51.81 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/13/2010 SLOTS, - a 2 7,943.1 5,587.9 52.42 CAMCO KBMG GAS LIFT DMY BK 0.000 0.0 9/132010 11 ,059 - 13.833 5^"'"°q4- 41**°•`w'.9 3 9,705.5 6,609.8 63.98 Camco KBMG 1111 GAS LIFT DMY BKOS 0.000 0.0 9/13/2010 SLOTS, 13,988 - 15.910 SLOT5, y 16,287 - 17.071 I ' t,e LINER, 1 10,826-17,140 TD, TD, 17,142 CD3 -123 Well Work Summary DATE SUMMARY 9/12/10 GAUGED TBG TO 2.68" TO 10725' SLM; DEVIATION STOPPED TOOLS FROM FALLING. GAUGED TBG TO 2.80" TO 9842' RKB. MEASURED BHP @ 9778' SLM: 2663.25 PSI / TEMP 158.03 DEG. SET 2.81 XN PLUG @ 9842' RKB. IN PROGRESS. 9/13/10 CHECK SET 2.81 XN PLUG @ 9842' RKB. PULLED OV @ 9705', GLVs @ 7943', 4347' RKB. SET DVs @ 7943' & 4347'. CONTROL BOARD OPERATOR PUMPED DSL, LOADING TBG & IA. SET DV @ 9705' RKB. MIT IA 2500 PSI, PASSED. PULLED 2.81 XN PLUG @ 9842' RKB. COMPLETE. II I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, October 14, 2010 TO: Jim Regg 52� L 1 SUB JECT: Mechanical Integrity Tests P.I. Superviso l (JUG G g CONOCOPHILLIPS ALASKA INC CD3 -123 FROM: Bob Noble COLVILLE RIV FIORD CD3 -123 Petroleum Inspector Src: Inspector Reviewed By: P.1. Suprv,j TR— NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV FIORD CD3 -123 API Well Number: 50- 103 - 20617 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN101012141744 Permit Number: 210 - 031 - Inspection Date: 10/10/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3 -123 'Type Inj. W ( TVD 6648 IA 375 2016 ' 1993 2000 - P.T.D 2100310' TypeTest ; SPT Test psi 2016 OA 187 324 — 326 332 Interval INITAL r P/F P " Tubing 2286 2287 2287 2288 Notes: ik' n, red mod- iC,6z P5, Thursday, October 14, 2010 Page 1 of 1 Page 1 of 2 • Regg, James B (DOA) , zio_os From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Wednesday, October 06, 2010 8:43 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) } 1 t4'\' U Subject: RE: CD3 -123 (PTD# 210 - 031 -0) Pre - injection MITIA t � Attachments: MIT CRU CD3 -123 9- 13- 10.xls Jim, Attached is a corrected MIT form from CD3 -123. I apologize, the MIT was not witnessed by the inspectors. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, October 05, 2010 3:21 PM To: NSK Problem Well Supv; DOA AOGCC Prudhoe Bay Cc: Maunder, Thomas E (DOA) Subject: RE: CD3 -123 (PTD# 210 - 031 -0) Pre - injection MITIA AOGCC witness of MIT (post initial injection) can be delayed until we have another reason to be at Alpine. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [mailto:n1617©conocophillips.com] Sent: Tuesday, October 05, 2010 1:21 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); NSK Problem Well Supv Subject: RE: CD3 -123 (PTD# 210- 031 -0) Pre - injection MITIA Jim, Please find the attached MIT form. The MITIA was conducted by slickline following the post rig work. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 10/6/2010 Page 2 of 2 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, October 05, 2010 9:28 AM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: CD3 -123 (PTD# 210 - 031 -0) State Witnessed MITIA I do not find a copy of the pre- injection MITIA report in our files; was one sent? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [mailto:n1617©conocophillips.com] Sent: Monday, September 20, 2010 9:49 AM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord Subject: CD3 -123 (PTD# 210 - 031 -0) State Witnessed MITIA Alpine injector CD3 -123 (PTD# 210 - 031 -0) is a new injector that was brought on line on 09/16/10 and will need a witnessed MITIA once stabilized . Since our helicopters are gone for the year, ConocoPhillips requests that the inspection be postponed until a pad SVS test is performed or until there is some other reason for an inspector to be at CD3 for a full day. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 10/6/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggftaalaska.aov; doa.aogcc.orudhoe.bay alaska.gov; phoebe.brooksealaska.gov; tom.maunder ••alaska..o OPERATOR: Conoco Phillips Alaska, Inc C1fq /D/6//o FIELD / UNIT / PAD: Alpine / CRU / CD3 DATE: 09/13/10 _ OPERATOR REP: Potter - HES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3 -123 Type Inj. N ' ND 6,648'' Tubing 962 1027 1032 1026 Interval 0 P.T.D. 2100310 Type test P Test psi 1662 Casing 586 " 2,491 2,428 2,407 P/F P Notes: MITIA was performed following post rig work and OA 331 555 537 521 rior to starting injection. / Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P /F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) II I Form 10 - 426 (Revised 06/2010) MIT CRU CD3 -123 9 -13 -10 (2).xls • Page 1 of 2 Regg, James B (DOA) at7 —o From: Regg, James B (DOA) 1 Sent: Tuesday, October 05, 2010 3:21 PM KCr, To: NSK Problem Well Supv; DOA AOGCC Prudhoe Bay Cc: Maunder, Thomas E (DOA) Subject: RE: CD3 -123 (PTD# 210 - 031 -0) Pre - injection MITIA AOGCC witness of MIT (post initial injection) can be delayed until we have another reason to be at ✓ Alpine. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Tuesday, October 05, 2010 1 :21 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); NSK Problem Well Supv Subject: RE: CD3 -123 (PTD# 210 - 031 -0) Pre- injection M1TIA Jim, Please find the attached MIT form. The MITIA was conducted by slickline following the post rig work. Please let me know if you have any questions. pre — otse ,c; Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, October 05, 2010 9:28 AM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: CD3 -123 (PTD# 210 - 031 -0) State Witnessed MITIA I do not find a copy of the pre - injection MITIA report in our files; was one sent? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [mailto:n1617©conocophillips.com] Sent: Monday, September 20, 2010 9:49 AM 10/5/2010 Page 2 of 2 To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord Subject: CD3 -123 (PTD# 210 - 031 -0) State Witnessed MITIA Alpine injector CD3 -123 (PTD# 210 - 031 -0) is a new injector that was brought on line on 09/16/10 and will need a witnessed MITIA once stabilized . Since our helicopters are gone for the year, ConocoPhillips requests that the inspection be postponed until a pad SVS test is performed or until there is some other reason for an inspector to be at CD3 for a full day. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 10/5/2010 ■ • 0 j d 0. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa alaska.gov; doa .aoacc.prudhoe.bay @alaska.aov; phoebe.brooks@alaska.gov; tom.maunder ialaska.aov D i 'A ( `) OPERATOR: ConocoPhillips Alaska, Inc Q-g I FIELD / UNIT / PAD: Alpine / CRU / CD3 1 DATE: 09/13/10 OPERATOR REP: Potter - HES AOGCC REP: Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3 -123' Type Inj. N ' TVD 6,648'' Tubing 962 1027 1032 1026 Interval 0 P.T.D. 2100310 " Type test P Test psi 1662 Casing 586 "2,491 2,428 -2,407 P/F P .." Notes: MITIA was performed following post rig work and / OA _ 331 555 537 521 prior to starting injection. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT CRU CD3 - 123 9 - 13 10.xls • SlfatrE LIEF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Jack Walker Principle Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 � o 03 Re: Colville River Field, Fiord Oil Pool, CD3 -123 Sundry Number: 310 -232 Dear Mr. Walker: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. peel Chair DATED this 3 day of August, 2010. Encl. STATE OF ALASKA 01' ALASIOIL AND GAS CONSERVATION COMMIS. $,i tO ' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: Convert to WAG rg • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pr . Exploratory r 210 -0310 ` 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20617 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No �' CD3 -123 . 9. Property Designation: 10. Field /Pool(s): ADL 372105 Colville River Field / Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17142 ' 7034 - 17140' 7034' Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 2797' 9.625" 2833' 2462' Intermediate 11005' 7" 11041' 6953' Liner 6314' 3.5" 17140' 7034' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11059' - 13833', 13999' - 15910', 16287- 17071' 6954' - 6998', 7001' - 7024', 7028' -7037' 4.5" x 3.5" L - 80 10849' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Baker Premier packer 9795' MD, 6648' TVD Camco TRMAXX -5E SSSV 2137' MD, 2003' ND 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service . 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/10/2010 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG 17 . Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker @ 265 -6268 Printed Name Jack Walker Title: Principal Production Engineer Signature y-44-- V `-L Phone: 265 -6268 Date 2 S 2 °/ 0 Commission Use Only Sundry Number: 3/O Or J D, Conditions of approval: Notify Commission so that a representative may witn ess Plug Integrity r BOP Test r Mechanical Integrity Test FV Location Clearance r Other: t "f ;m O ° ►., L O J 4� r'� 3 RECEIVED t,� ilk 29 2010 Subsequent Form Required: /U - yQ / Al MI & Cu Cans. C issior I Date Aitci�r Anchorage APPROVED BY �y /� /� Approved by. BDAAS AUG O A Zo COMMISSIONER THE COMMISSION Date: j Form 10 -403 Revised 1/2010 t ORIGINAL f:Z• /U Submit in Duplicate a w �; • a :;; WNS CD3 -123 • • CAN f hilFips Well Attributes ,Max Angle & MD TD Alaska Inc } Wellbore APUUWI Fieid Name Well Status Inc! ( °) MD (ftKB) Act 131m (ftKB) - 501032061700 I FIORD NECHELIK PROD 9308 I 17,07568 17,1420 ''"' Comment IO2S (ppm) (Date Annotation End Date I KB -Grd (ft) Rig Release Date ASSV Well Conlig HORIZONTAL . CO3123 5/14/2010 10 a 33AM : TRDP Last WO: 41 70 1 4(26/2010 Depth (ftKB) End Date Annotation Last Mod ... End Date schematic Actual Last Ta I Rev Reason: Pull ball /rod/plug, GLV C/O I Imosbor 1 5/14/2010 - HANGER, 31 Casing Strings Casing Description String 0... String ID... Top (ftKB) Set Depth (f_. Set Depth (ND)... String Wt... String... String Top Thrd CONDUCTOR 24" 16 15.250 36.0 114.0 114.0 62.50 H-40 WELDED 1 Insulated Driven Casing Description String 0... String ID ._ Top (HKB) Set Depth (f... Set Depth (ND) ... String Wi... String ... String Top Thrd J ' SURFACE 9 5/8 8.835 35.7 2833.0 2,462.2 40.00 L BTC - M - . _ C rig Descr phon Str rig 0... Str g ID .. Top (ftKB) Set Depth (f... Set DapM 9 ) ... String Wt... Str g .. Stdng Top Thrd - -- - -- - - -- INTERMEDIA IE 7 fi276 335 11 6,9529 2600 L80 BTC -m Casing Description String 0. String ID .. Top (ftKB) Set Depth (f.. Set Depth (ND) ... String Wt... String .. String Top Thrd , LINER 31/2 2.992 10,8262 17,1400 7,033 9.30 L80 SLHT Liner Details Top Depth CONDUCTOR Norm 1 0,826 .2 (,927.8 8 2.97 SLEEVE tr Comment ID (in) Top Intl 24• nwlated- p IRKS) Description Driven, 36 - 114 S Baker 5" x 7" "HRD" liner Setting Sleeve(525" ID) (5.79 OD" x 4.34" ID) 4.340 10,839.3 6,929.4 83.07 NIPPLE RS Packoff Seal Nipple w/ X-0 collar on top & bttm (5.64" OD x 4.260" 4.260 ID) ',. 10,843.0 6,929.9 83.10 HANGER Baker 5" x 7" Flexlock liner hanger (5.93" OD x 4.42" ID) 4.420 { 10,852.7 6,931.1 83.17 XO BUSHING Crossover Bushing (5.58" OD x 3.93" ID) 3.930 SAFEN 2,,137 137 10,869 -0 6,933.0 83.30 X0 - Reducing , Crossover 4 -1 /2" SLHT x3- 1 /2" SLHT 2.992 1 Tubigg Strin_gs Tubing Description IStr ng O .. String ID Top ( ftK B) Set Depth (5... Set Depth (ND) ... String Wt... Str g !String T p Thrd • TUBING 4.5"x3.5" 372 1 . 299 2 I 306 I 108486 I 69306 I 9.3 I L80 L EUEm j Completion Details Top Depth SURFACE, (ND) Top Inc! Nom,... 36-2,833 Top (ftKB) lftxB) ti item Deem _ Comment ID (in) 30.6 30.6 -0.08 HANGER FMC Tubing Hanger (11" x 4-1/2") 3.958 GAS LIFT, 122.8 122.8 0.84 X0 - Reducing Crossover 4-1/2" IBT -m 12.6 ppf L-80 box x 3-1/2" EUE 9.3 ppf L-80 pin 2.992 4 2,137.2 2,002.6 42.07 SAFETY VLV 3 -12" Cameo TRMAXX -5E SSSV w/ 2 813" X profile (2.813" profile) 2.812 Illt 9,795.1 6,647.7 65.63 PACKER Baker 3 -12" x 7" Premier Packer - center of element 2.40' down f/ top 2.870 9,842.9 6,666.8 67.28 NIPPLE HES 3-1/2" "XN" nipple - - -__ -- 2.750 10,823.1 6,927.5 82.95 LOCATOR Shear pinned Fluted No -Go Sub- above no go 3.000 10,824.2 6,927.6 82.96 LOCATOR Shear pinned Fluted No-Go Sub - below no -go 3.000 I , 10,847 -6 6,930.4 83.14 WLEG 3 -1/2" 9.3 ppf L-80 IBT WLEG -- Fluted 1,2 muleshoe 1000 GAS LIFT, __ -- ' it Perforations & Slots Shot ems' Top (ND) 131m (7VD) Dens . Top (ftKB) Ben MKS) (WEB) (ftKB) Zone Date Oh- Type Comment 11,059 13,833 6,954.1 6,996.7 Nechelik, 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; CD3 -123 no slots 3' from box/pin III GAS LIFT 13,988 15,910 7,002.2 7,023.9 Nechelik, 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; 9.705 - CD3 -123 no slots 3' from box/pin 16,287 17,071 7,030.3 7,037.4 Nechelik, 4202010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; CD3 -123 no slots 3' from box/pin Notes: General & Safety PACKER,9,795 End Date Annotation 4/26/2010 NOTE: INJECTION WELL WILL BE PRE- PRODUCED IN 4/26/2010 NOTE: VIEW SCHEMAT w /Alaska Schematic9.0 NIPPLE, 9,843- - LO- UR ! iii LOCATOR, 10,823 LOCATOR, 10,824 l 4' WLEG,10,848 113 11 1 1 i NTERMEDWTE, Mandrel Details 34. 11,041 Top Depth Top - Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (In) Sere Type Type tin) (Psi Run Date Can... 1 4,347.3 3,393.2 51.81 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,896.0 4/30/2010 SLOTS, 4, 2 7,943.1 5,587.9 52.42 CAMCO KBMG 1 GAS LIFT GLV 8K 0.188 1,839.0 4/302010 11,059 - 13,833 - 3 9,705.5 6,609.8 63.98 Cameo KBMG 1 GAS LIFT OV _ BKO 0.250 0.0 4/29/2010 SLOTS.- - _____ -. -. 13,988- 15,910 SLOTS, - i1 16,287 - 17,071 I b HER, 10,826-17,140 TD, TD, 17,142 ` • 1 • STATE OF ALASKA RECEJVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 e 2010 W ELL la. Well Status: oil COMPLETION OR RECO n REPORTA S QG 0 ❑ ❑ ❑ ❑ � na s Gnmm►�sjul 20AAC 25.105 20AAC 25.110 Development � ❑ GINJ ❑ ' WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: "5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 25, 2010 \. 210 - 0310 / 3. Address: t Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 2, 2010 50 103 - 20617 - 00 4a. Location of Well (Governmental Section): X. Date TD Reached: 14. Well Name and Number: Surface: 1277' FSL, 1108' FEL, Sec. 5, T12N, R5E, UM April 20, 2010 CD3 - 123 Top of Productive Horizon: 8. KB (ft above MSL): 49' RKB 15. Field /Pool(s): 142' FSL, 1536' FEL, Sec. 6, T12N, R5E, UM GL (ft above MSL): 12.6' AMSL Colville River Field Total Depth: '9. Plug Back Depth (MD + TVD): " 324' FSL, 1890' FWL, Sec. 8, T12N, R5E, UM 17140' MD / 7034' TVD Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 387935 y - 6003775 Zone 4 17142' MD / 7034' TVD ADL 372105 TPI: x - 382214 y - 6002728 Zone 4 N. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 385578 y 5997578 Zone 4 2137' MD / 2003' TVD 2112 18. Directional Survey: Yes • No 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: \ (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1543' MD / 1500' TVD St Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD GR/Res not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECOR e - v CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE ,- P LLED 16" _ 62.5# _ H -40 _ 36' _ 114' 36' - 114' _ 24" pre installed,�S�. 9.625" 40# L -80 36' 2833' 36' 2462' 12.25" 400 sx miss, 236 sx Class G, 37 sx AS I 7" 26# L -80 34' 11041' 34' 6953' 8.75" 310 sx Class G, 198 sx Class G 3.5" 9.3# L -80 10826' 17140' 6927' 7034' 6.125" slotted liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5" x 3.5" 10849' 9795' MD / 6648' TVD slots from 11059'- 13833' MD 6954' -6998' TVD 32 spf slots from 13999'- 15910' MD 7001-7024' TVD 32pf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. slots from 16287 MD 7028' - 7037' TVD 32 p �tP�ECt DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED E I • 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 2, 2010 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 5/5/2010 6.5 hours Test Period - -> 288 469 9 100% 1626 Flow Tubing Casing Pressure Calculated OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - API (corr) Press. 375 psi not available 24 - Hour Rate - 1080 1756 33 not available 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10 -407 Revised 12/2009 ONTINUED ON REVERSE Submit original only RBDMS MAY 18 2010 i" z `e) 28. GEOLOGIC MARKERS (List all formations and mar •rs encountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes is No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1543' 1500' needed, and submit detailed test information per 20 AAC 25.071. C -20 3488' 2865' K -3 5114' 3866' K -2 5390' 4035' Nanuq 8388' 5869' K -1 9972' 6715' Kuparuk D 10094' 6757' Kuparuk C 10232' 6799' Nuiqsuit 10240' 6802' Nechelik 10979' 6946' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS Summary of Daily Operations, final directional survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Robertson © 265 - 6318 Printed Name pp L. Alvord Title: Alaska Drilling Manner C 1 > Signature /J .4... Phone 265 -6120 , Date Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 / //t WNS I li CD3-123 Conoco Philllps i 4 Well Attributes Max Angle & MD TD Welibore APVUWI Field Name Well Inc' MD (f1KB MKS) ) Act Bim KS) ',' `�" 501032061700 (FIORD NECHELIK =Wt 93.08 17,075.68 2 68 17,140 "" Comment t H2S (PPrn) __ Date IAn End Date KB.Grd (ft) Rig Release Date _ Well Contig: HORIZONTAL CO3 123,4/26/20 3 16 08 PM.. , -- - -- LEST WOn I 41 70 4/26/2010 Scher^atic � AC,ual Annotation Dee pth (ff K6) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: NEW WELL Imosbor 4/26/2010 HANGER, 31 - -- � T` ° Ca Strin Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd 11 CONDUCTOR 24" 16 15250 36.0 114.0 114.0 62.50 11-40 WELDED C - Insulated Driven ;' _- Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SUR 95/8 8..7 3.0 2,4 .1 40.00 L-80 BTC - - -_ - -. _� -- t .._ : _ JCasing Descrption FACE String 0... Str 835 ng ID ... Top (RKB) 35 Set De (f... Set Dep ND) ... String Wt... String ... SMng Top Thrd - -- -1 - - - - - - INTERMEDIATE 7 6.276 33.5 11,041,3 6,952.9 26.00 L - 80 BTC - m Casing Description String 0... String ID ... Top OWE) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 3 1/2 2.992 10826.2 17,140.0 7,033.7 9.30 L-80 SLHT Liner Details - - - -- - -- Top Depth (TIM Top Incl -- - - Komi... CONDUCTOR " 24 insulated ( 1 Top MKS) (6KB) ( °) Itari Desviption Comment ID (in) Driven, 36114 �p. 10,826.2 6,928.1 83.37 SLEEVE Baker 5" x r "HRD" liner Setting Sleeve(5 25" ID) (5.79 OD" x 4 34" ID) 4.340 1. 10,839.3 6,929.6 83.37 NIPPLE RS Packoff Seal Nipple w/ X -0 collar on top & bttm (5.64" OD x 4.260 4.260 ID) `% 10,843.0 6,930.0 83.37 HANGER Baker 5" x 7" Flexlock liner hanger (5.93" OD x 4 42" ID) 4.420 10,852.7 6,931.2 83.37 XO BUSHING Crossover Bushing (5 58" OD x 3.93" ID) 3.930 SAFETY Vtv, ' 2,137 10869.0 6,933.0 83.37 Reducing Crossover 4- 1 /2 " SLHT x3 -1/2 "SLUT 2.992 Tubing Strings Tubing Description String 0 . String ID ... Top (HKB) ISM Depth (f... Set Depth (TVD) String Wt... Sting ... String Top Thrd I TUBING 4 583.5" 3 1/2 2 992 30.6 108486 6,930.7 I 9 30 L 80 EUE - m Completion Details ;Top Depth) (TVD) Top Itl N m'._ 36 -2833 . Top (ftKB)_ (ft(B) (*) Item Description Comment ID (in) 30.6 30.6 -0.08 HANGER FMC Tubing Hanger (11" x 4 -1/2") 3.958 IIIII' GAS LIFT . 122.8 122.8 0.78 XO - Reducing Crossover 4 -112 IBT -m 12.6 ppf L -80 box x 3-1/2" EUE 9.3 ppf L -80 pin 2.992 4.367 - - - _ - -- ' _ - -- - -- ' - 2,137.2 2,002.6 42.07 SAFETY VLV 3 -1/2" Cameo TRMAXX-5E SSSV w/ 2.813 X profile (2.813" profile) 2.812 9,795.1 6,647.8 65.78 PACKER Baker 3 -1/2" x 7" Premier Packer - center of element 2.40' clown f/ top 2.870 9,842.9 6,666.8 67.28 NIPPLE HES 3 -1/2" "XN" nipple w/ RCH plug installed (66.72 inc) (2.75" min 2.750 ID) 10,823.1 6,927.7 83.37 LOCATOR Shear pinned Fluted No -Go Sub- above no go 3.000 10,824.2 6,927.9 83.37 LOCATOR Shear pinned Fluted No -Go Sub - below no -go 3.000 1. 10,847.6 6,930.6' 83.37 WLEG 3 -1/2" 9.3 ppf L-80 IBT WLEG - Fluted 1/2 muleshoe 3 -000 GAS LIFT. 7,963 Perforations & Slots Shot Top (TVD) Bbn (TVD) Dons Top (HKB) Ban (ftKBD_ QUCB) (ftKB) Zone Date W - '5pe Comment ft 11,059 13,833 6,954.1 6,997.8 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots /row, 4 rows/ft; no slots 3' from box/pin GAS LIFT ____ 9 13,988 15,910 7,000.9 7,023.9 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; no slots 3' from box/pin It 16,287 17,071 7,028.3 7,037.4 4/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; no slots 3' from box/pin PACKER, 9,796 Notes: General & Safety End Date Annotation 426/2010_ (NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NIPPLE, 9,843 - - - - -- LOCATOR, 10,823 LOCATOR, 10,824 - WLEG, 10.848 ) 0 II 1 NTERMEDIATE,_ Mandrel Details 34- 11,041 Top Depth Top Port (ND) Ind OD Valve Latch Size TRO Run Stn Top (ftKB) (MB) (') Make Model (in) Sery 'typo Type (in) (psi) Run Date Corn... 1 4,347.3 3,392.4 50.78 CAMCO KBMG 1 GAS LIFT SOV BEK -5 0.000 0.0 4/25/2010 SLOTS, ___ _.. """""1"' 2 7,943.1 5,588.1 51.84 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 4/25/2010 11,059 - 13,833 5 .. _ .- 3 9,705.5 6,609.9 64.12 Cameo KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 4252010 SLOTS, __ 13,988 - 15,910 - SLOTS, I._ 16,287 - 17,071 LINER, 1 1 10,82617,140 TD, 17,142 1 ConocoPhillips Time Log & Summary We!lvMew Web Reportwg Report Well Name: CD3 - 123 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 4/1/2010 3:00:00 PM Rig Release: 4/26/2010 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/01/2010 24 hr Summary Move Rig Off of CD3 -121 - Stand By for Well Work (5.5 hrs) - Move In and Rig Up on CD3 -123 - P/U 5" DP - Accept Rig @ 1500 hrs 06:00 10:00 4.00 0 0 MIRU MOVE MOB P Move Rig f/ CD3 -121 10:00 15:30 5.50 0 0 MIRU MOVE OTHR P Stand By for Wireline Work, Gravel Work and Well House Setting - Install Slip Lock Adapter and Test t/ 400 Psi f/ 10 Minutes 15:30 22:00 6.50 0 0 MIRU MOVE MOB P Spot Sub, Motors, Pits, Pipe Shed and Bal (Mill - Hook Up Service Lines - Connect High Line Power @ 1930 - Respot Pipe Shed - Test Gas Alarms - Connect Mud Lines - N/U Riser, Flow Line and Hole Fill - Accept Rig @ 1500 Hrs *Time Backed Out for Slickline and Gravel Work Delaying Rig MIRU* 22:00 00:00 2.00 0 0 MIRU DRILL PULD P P/U Smaller BHA Components - Install Mouse Hole - Change Elevators - P/U 5" DP (5 Stands) 04/02/2010 P/U 5" DP - Repair Iron Roughneck - P/U Remaining 5" DP and HWDP - P/U BHA #1 - Clean Ice from Conductor t/ 114' MD - Drill f/ 114' t/ 720' MD - 1.5' f/ Ellipse of CD3 -124, Wait On Orders - Continue to Drill U 781' MD - Taking Gyro Surveys Every Stand t/ 720' MD, then Every 30' t/ 781' MD 00:00 00:45 0.75 0 0 MIRU DRILL PULD P Continue to P/U 5" DP (7 Stands) 00:45 02:45 2.00 0 0 MIRU RIGMN1 RGRP T Repair Iron Roughneck Electrical System - Replaced Contacts / Adjusted face Plate 02:45 08:30 5.75 0 0 MIRU DRILL PULD P Continue to P/U 5" DP (11 Stands and 8 Stands of HWDP) - PU (2) 7" flex collars and drilling jars - HWDP required steaming each joint to allow for drift to pass through 08:30 10:30 2.00 0 0 SURFA( DRILL PULD P PJSM - MU BHA # 1 - Bit, motor, IBS, EM Collar, Index Collar, Antenna Sub, FS, UBHO Sub 10:30 10:45 0.25 0 0 SURFA( DRILL SFTY P Held Pre -spud meeting with drilling crew and support personnel 10:45 11:45 1.00 0 0 SURFA( DRILL PRTS P Fill conductor and check for leaks - Pressure test mud lines to 3500 psi - Complete obtaining North Seeking Gyro reference points - 11:45 12:45 1.00 0 169 SURFA( DRILL DDRL P Clean out conductor from 82' to 114' - Drill 12 1/4" hole from 114' to 169' - 500 gpm @ 730 psi - 50 rpm @ 4k f /Ibs Spudded well @ 1205 hours. Page 1 of 30 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 13:30 0.75 169 169 SURFA( DRILL PULD P Stand back 1 stand of hwdp - MU flex collars and jars - scribe tools - orientate UBHO sub - RU to run Sperry free seeking gyro 13:30 21:30 8.00 169 720 SURFA( DRILL DDRL P Continue Drilling f/ 169' - 720' MD - Gyro's Taken Every Stand P/U 110, S/0 105, Rot 110 Torque On /Off 4.5/3 RPM 50, WOB 10 -20 500 GPM @ 980 Psi On/880 Psi Off 21:30 22:15 0.75 720 720 SURFA( DRILL OTHR T Last Survey 1.5 from the Elipse of CD3 -124 - Notified the Drilling Engineer and Directional Coordinator - Data Analyzed in Town - Decision Made to Drill Ahead 22:15 00:00 1.75 720 781 SURFA( DRILL DDRL P Continue Drilling f/ 720' to 781' MD - Gyro's Taken Every 30' f/ 720' to 810' MD ADT 4.84 P/U 120, S/O 117, Rot 118 500 GPM @ 990 Psi On/840 Psi Off RPM 50, WOB 10 -20 Torque On /Off 4.5/3 04/03/2010 Continued to Drill 12 1/4" Hole f/ 781' MD to 2,804' MD 00:00 12:00 12.00 781 1,662 SURFA( DRILL DDRL P Continue Drilling f/ 781' to 1,662' MD - Gyro's taken Every Stand t/ 1,006' MD ADT 6.45, AST 3.12 P/U 132, S/O 130, Rot 127 Torque On /Off 6.5/4.5 500 GPM @ 1080/908 Psi On /Off WOB 10 -25 12:00 00:00 12.00 1,662 2,804 SURFA( DRILL DDRL P Continue Drilling f/ 1,662' to 2804' MD ADT 9.14, S/O 1.29 P/U 148, S/O 125, Rot 137 Torque On /Off 8/6.5 550 GPM @ 1500/1370 Psi On /Off WOB 15 -30 04/04/2010 Continued to Drill 12 1/4" Hole t/ 2,843' MD (TD) - Circulate Bottoms Up X 2 - Back Ream t/ 907' MD - Observe Well For Flow (Static) - Trip in Hole, Worked Though hard Spot @ 1,153' MD and Minor Tight Spots @ 2,215' and 2,308' MD - Ream f/ 2,804' to 2,843' MD - Circ & Condition Mud - Trip Out -of -Hole on Elevators t/ 907' MD - Observe Well for Flow (Static) - UD BHA #1 - R/U and Run 9 5/8" Casing t/ 2,833' MD - Circulate and Condition Mud Prior to Cementing 00:00 01:00 1.00 2,804 2,843 SURFA( DRILL DDRL P Drilling f/ 2,804' to 2843' MD - 2,468' TVD ADT 0.57 ART 0.18 hr AST 0.39 hr PUW 149 SOW 127 Rot Wt, 136 Torque On /Off 7.5 / 5 550 GPM @ 1500/1350 Psi On /Off WOB 15 -30 Page 2 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 2,843 2,709 SURFA( DRILL CIRC P Circulate and condition mud - 600 gpm / 1830 psi / 60 rpm @ 5H ft/Ibs Stood back two stands to 2709' 02:00 05:45 3.75 2,709 907 SURFA( DRILL TRIP P Performed wiper trip to 907' - Back reamed from 2,709' to 907' - 600 gpm / 1650 psi / 60 rpm - slowed pump rate to 500 gpm from 1500' and - no problems - flow check well, static 05:45 07:00 1.25 907 1,187 SURFA( DRILL REAM P RIH from 907' - unable to pass 1151' - made several attempts to pass tight spot with out pumps - no good. Attempted to rotate passed tight spot with low pump (5 bpm) motor stalling - Increased pump rate to 450 gpm and oriented motor to high side - drilled past tight spot 1151' to 1154' - worked bit passed tight spot several times - hole conditions improved. Large volume of fine sand and chunks of compressed wood (coal) circulated out across shakers. Shut down pump and slid bit past tight spot - OK. Reamed stand down to 1187' - appeared to be cleaning out more sand. 07:00 08:15 1.25 1,187 2,804 SURFA( DRILL TRIP P RIH from 1,187' to 2,804' - minor tight spots @ 2215' and 2308' 08:15 09:45 1.50 2,804 2,804 SURFA( DRILL CIRC P Establish circulation - Precautionary ream from 2,804' to 2,843' - Staged pumps up to 600 gpm / 1830 psi / 60 rpm - Circulate and condition mud - increased MW from 9.8 ppg to 10.0 ppg - maintained high viscosity and added fluid loss materials - observed large amount of sand and cutting through first BU - shakers quite clean after second BU - set back one stand - Blow down top drive - Flow check well - static 09:45 12:45 3.00 2,804 170 SURFA( DRILL TRIP P POOH on elevators from 2,804' to 907' - no problems - Flow check well, static - Continue to POOH on elevators - stand back HWDP - Hole appears in good shape 12:45 14:45 2.00 170 0 SURFA( DRILL PULD P POOH - Laid down remainder of BHA components - Clear tools from floor - clean up trip mess 14:45 16:15 1.50 0 0 SURFA( CASING RURD P Rig up to run 9 5/8" casing 16:15 16:30 0.25 0 0 SURFA( CASING SFTY P Held Pre job safety and Ops meeting with crew 16:30 19:45 3.25 0 1,614 SURFA( CASING RNCS P _ Run 9 5/8" Casing per Detail U 1 614 MD (42 Joints) P/U 137, S/O 110 19:45 20:15 0.50 1,614 1,614 SURFA( CASING CIRC P CBU @ 5 BPM w/250 Psi Page 3 of 30 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 22:00 1.75 1,614 2,833 SURFA( CASING RNCS P Run 9 5/8" Casing t/ 2,794' MD (31 Joints) - M/U Landing Joint and Land Casing w/ tail @ 2,833' MD P/U 185, S/O 135 22:00 22:30 0.50 2,833 2,833 SURFA( CASING RURD P R/D Casing Running Equipment & R/U Cement Head 22:30 00:00 1.50 2,833 2,833 SURFA( CASING CIRC P Circ & Condition Mud Staging Pumps Up f/ 3 @ 240 Psi to 7 BPM @ 350 Psi Prior to Cementing 04/05/2010 Continue to Circulate and Condition Mud Prior to Cementing - Cement Surface Casing - N/D the Riser - Install Wellhead and Test t/ 1,000 Psi f/ 10 Minutes - N/U BOPE - R/U and Test BOPE w/ 5" Test Jt; Test Witnessed by AOGCC Inspector Bob Noble - P/U 5" DP - Slip & Cut Drill Line - Begin P/U BHA #2 00:00 01:00 1.00 2,833 2,833 SURFA( CASING CIRC P Circ & Condition Mud Prior to Cementing - 7 BPM @ 340 Psi 01:00 03:15 2.25 2,833 2,833 SURFA( CASING CMNT P PJSM - Pumped 51 Bbls of 10.0 PPG Mud w/ Nut Plug Marker, then 34 Bbls of Biozan /Nut Plug Pill w/ Rig Pumps @ 5 BPM w/ 280 Psi - Dowell Pumped 3 Bbls of Water - Pressure Tested Surface Lines t/ jo-1 3,500 Psi - Dropped the Bottom Plug and Pumped 50 Bbls Mud Push II, 1.$1. 321 Bbls of 10.7 PPG CialiWeiteari Cement and 50 Bbls of 15,8 PPG Tail Cement @ an Average of 7.5 BPM w/ 421 Psi - Dropped the Top Plug, Then Pumped 20 Bbls of Fresh Water - Rig Pumps Displaced the Cement w/ 188.5 Bbls of 10.0 PPG Mud @ 500 Psi - Bumped Plugs @ 1885 Strokes - Held 1100 psi on the Floats for 5 Minutes - Released Pressure Checked Floats (Good) - CIP @ 0315 hrs - 42 Bbls of Cement Returned to Surface 03:15 04:30 1.25 2,833 2,833 SURFA( CASING RURD P R/D Cementing Equipment While Monitoring Cement Level in Annulus - Dropped — 7' (1 Bbl) in 45 Minutes 04:30 06:15 1.75 2,833 2,833 SURFA( WHDBO NUND P N/D Surface Riser & Remove Slip Lock Assembly 06:15 07:30 1.25 2,833 2,833 SURFA( WHDBO NUND P Install Well Head & Test t/ 1,000 Psi f/ 10 Minutes 07:30 09:15 1.75 2,833 2,833 SURFA( WHDBO NUND P N/U BOPE - Change Swivel Packing 09:15 10:15 1.00 2,833 2,833 SURFA( WHDBO RURD P R/U to Test BOPE 10:15 14:00 3.75 2,833 2,833 SURFA( WHDBO BOPE P Test BOPE w/ 5" Test Joint - Test Annular Preventer t/ 250/2500 Psi - Test All Choke Manifold valves, 4" a a DEMCO, Upper and Lower Pipe Rams & Blind Rams t/ 250/3500 Psi / - Test Gas Alarms, Flow Alarms, 7 5 PVT Alarm, and Perform Accumulator Draw Down Test - Test Witnessed by AOGCC Inspector Bob Noble Page 4 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:45 0.75 2,833 0 SURFA( DRILL RURD P Set Wear Ring & R/U to P/U 5" DP 14:45 21:30 6.75 0 0 SURFA( DRILL PULD P P/U 5' DP f/ the Pipe Shed via the Mouse Hole (69 Stands) 21:30 23:00 1.50 0 0 SURFA( RIGMNT SLPC P Slip & Cut 60' of Drill Line - Service Top Drive 23:00 00:00 1.00 0 82 SURFA( DRILL PULD P P/U BHA #2 per DD t/ 82' MD 04/06/2010 Finish making up BHA #2 (GeoPilot) f/ 82' to 179', shallow pulse test MWD, continue w/ BHA #2 to 741', pickup 5" drill pipe from pipe shed, run in on BHA #2 to 2643', circulate and condition mud for casing test. Rig up, then test casing to 3500 psi f/ 30 minutes, chart test, rig down testing equipment, clean out to top of cement at 2725', drill to float collar @ 2753', then cement, and float shoe @ 2833', rat hole to 2843', then 20' new hole to 2863'. PJSM, then rig up/ perform LOT. Applied 1020 psi w/ 9.5 ppg MW, TVD of shoe at 2462.35', leak off 720 psi= EMW of 15.7 ppg. Rig down testing equipment. Directional drill 8 -3/4" hole w/ Sperry Sun GeoPilot TL 270 from 2863' to 4163' at midnight. 00:00 01:15 1.25 82 179 SURFA( DRILL PULD P Continue to P/U BHA #2 per DD f/ 82' to 179 01:15 02:15 1.00 179 179 SURFA( DRILL DHEQ P Shallow pulse test Sperry Sun MWD tools. Pumping 600 gpm w/ 1140 psi. Test surface lines to 4100 psi. Blow down the top drive. 02:15 02:45 0.50 179 741 SURFA( DRILL TRIP P Continue to P/U BHA #2 per DD f/ 82' to 179' (Run HWDP and jars). Make up ghost reamer #1. 02:45 04:45 2.00 741 2,643 SURFA( DRILL PULD P PU 5" dp, run in the hole w/ BHA #2 from 741' to 2643'. Make up ghost reamer #2. 04:45 05:15 0.50 2,643 2,643 SURFA( DRILL CIRC P Circulate and condition mud prior to performing casing test. Pumping 600 gpm w/ 1740 psi, rotate 70 rpm w/ 7.5k ft Ibs of torque. 05:15 05:30 0.25 2,643 2,643 SURFA( DRILL RURD P Rig up to test casing. 05:30 06:00 0.50 2,643 2,643 SURFA( DRILL PRTS P Test the 9 -5/8" casing to 3500 psi f/ 30 minutes. Chart test. 06:00 06:15 0.25 2,643 2,643 SURFA( DRILL RURD P Rig down testing equipment. 06:15 06:30 0.25 2,643 2,753 SURFA( CEMEN" COCF P Clean out cement, washing and reaming from 2643' to the top of cement at 2725'. Drill cement from 2725' to the float collar @ 2753'. 06:30 10:00 3.50 2,753 2,843 SURFA( CEMEN" DRLG P Drill float collar @ 2753', cement to 2831', flaot shoe from 2831' to 2833', then clean out rat hole to 2843'.Pumping 600 gpm w/ 1640 psi, rotate 60 rpm w/ 7.5k ft lbs of torque. 10:00 10:30 0.50 2,843 2,863 SURFA( DRILL DRLG P Drill 20' of new hole from 2843' to 2863' (2481' TVD). Actual drilling time .27 hrs. 10:30 10:45 0.25 2,863 2,863 SURFA( DRILL SFTY P Pre job safety meeting on upcoming leak off test. 10:45 11:00 0.25 2,863 2,863 SURFA( DRILL RURD P Ri• .: • • - • • 11:00 11:30 0.50 2,863 2,863 SURFA( DRILL LOT Perform Leak off test. Pressure to 1020 psi. Leak off picked at 720 psi w/ 9.5 ppg mud wt, shoe TVD @ 2462.35'. EMW 15.7 ppg. 11:30 12:00 0.50 2,863 2,863 INTRM1 DRILL RURD Rig down testing equipmen = ow Page 5 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 2,863 4,163 INTRM1 DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Sun GeoPilot (ser # TL270) from 2863' to 4163' (3279' TVD). Actual drilling time 8.24 hrs. Drill w/ 10 to 20k weight on bit. Pumping 550 to 650 gpm w/ 1080 to 1940 psi. Rotate 90 -150 rpm w/ 8 to 8.5k ft Ibs of torque on bottom and 7 to 8k ft Ibs off bottom. ECD's 10.28 to 10.95 ppg. PU wt 165k, SO wt 135k, Rot wt 148k. Note: Pump bit balling sweeps (2.5 ppb flozan and 5 ppb nut plug) (3230', 3515', and 3788'. Increase of 80 to 100% cuttings was seen at the shakers. Displaced to new 9.6 ppg LSND mud after LOT at 2863'. 04/07/2010 Directional drill 8 -3/4" hole w/ Sperry Sun GeoPilot TL 270 from 4163' to 6821' at midnight. Pump bit balling sweeps ( 2.5 ppb flozan and 5 ppb nut plug) at 4174', 4753', 4989' and 5600'. Whole mud dilutions of 175 bbl at 4550', then 275 bbls dilutions at 5135' and 5882'. 00:00 12:00 12.00 4,163 5,256 INTRM1 DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Sun GeoPilot (ser # TL270) from 4163' to 5256' (3955' TVD). Actual drilling time 7.23 hrs. Drill w/ 10 to 20k weight on bit. Pumping 650 gpm w/ 1940 to 2210 psi. Rotate 150 rpm w/ 8.5 to 11.5k ft Ibs of torque on bottom and 8 to 8.5k ft lbs off bottom. ECD's 10.58 to 10.93 ppg. PU wt 174k, SO wt 150k, Rot wt 161k. Note: Pump bit balling sweeps ( 2.5 ppb flozan and 5 ppb nut plug) at 4174', 4753', and 4989'. Increase of 75% to small amount of extra cuttings was seen at the shakers. 12:00 00:00 12.00 5,256 6,821 INTRM1 DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Sun GeoPilot (ser # TL270) from 5256' to 6821' (4916' TVD). Actual drilling time 8.7 hrs. Drill w/ 10 to 25k weight on bit. Pumping 650 gpm w/ 2030 to 2240 psi. Rotate 150 rpm w/ 9 to 13k ft Ibs of torque on bottom and 8.5 to 11.75k ft Ibs off bottom. ECD's 10.55 to 10.69 ppg. PU wt 220k, SO wt 150k, Rot wt 178k. Note: Pump a bit balling sweep 2.5 ppb flozan and 5 ppb nut plug) at 5600'. Slight increase of cuttings was seen at the shakers. 04/08/2010 Directional drill 8 -3/4" hole w/ Sperry Sun GeoPilot TL 270 from 6821' to 9329' ( 6428' TVD) at midnight. Pump bit balling sweeps (2.5 ppb flozan and 5 ppb nut plug) at 7205', miminal increase in cuttings. Performed 275 bbl dilution @ 7300', 8157' and 8822'. Started 550 bbl Glydril dilution while drilling at 9202' to bring Glydril to 5 %, Soltex to 6ppb & Resinex to 4ppb. Page 6 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 6,821 8,029 INTRMI DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Sun GeoPilot (ser # TL270) from 6821' to 8029' (5640' TVD). Actual drilling time 7.04 hrs. Drill w/ 10 to 25k weight on bit. Pumping 650 gpm w/ 2030 to 2200 psi. Rotate 150 rpm w/ 13 to 14.5k ft Ibs of torque on bottom and 11.75 to 10.5k ft Ibs off bottom. ECD's 10.51 to 10.62 ppg. PU wt 220 to 215k, SO wt 150 to 170k, Rot wt 178 to 190k. Note: Pump a bit balling sweep ( 2.5 ppb flozan and 5 ppb nut plug) at 7205'. Performed 275 bbl dilution @ 7300'. 12:00 00:00 12.00 8,029 9,329 INTRMI DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Sun GeoPilot (ser # TL270) from 8029' to 9329' (6428' TVD). Actual drilling time 8.43 hrs. Drill w/ 15 to 25k weight on bit. Pumping 650 gpm w/ 2130 to 2310 psi. Rotate 150 rpm w/ 11.5 to 15k ft Ibs of torque on bottom and 9 to 12k ft Ibs off bottom. ECD's 10.62 ppg. PU wt 215 to 237k, SO wt 170 to 180k, Rot wt 190 to 203k. Note: Performed 275 bbl dilution @ 8157' and 8822'. Started inhibycol dilution while drilling at 9202'. 04/09/2010 Directional drill 8 -3/4" hole w/ Sperry Sun GeoPilot TL 270 from 9329' to 11053' ( 6953' TVD). Circulate two bottom's up while backreaming 11053' to 11008', pump weighted nut plug hi vis sweep to surface (11.8 ppg, 7 ppb nut plug) (30% increase in cuttings). Backream a stand 2 -3' /min while circulate another bottom's up, reaming from 11008' to 10913'. Backream out of the hole pumping 650 gpm w/ 2650 to 2550 psi, rotate 100 rpm w/ 12k ft Ibs of torque, pulling speed 20' /min from 10913' to 10414' at midnight. 00:00 06:00 6.00 9,329 9,867 INTRM1 DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Sun GeoPilot (ser # TL270) from 9329' to 9867' (6676' TVD). Actual drilling time 3.96 hrs. Drill w/ 15 to 25k weight on bit. Pumping 650 gpm w/ 2310 to 2580 psi. Rotate 150 rpm w/ 14 k ft Ibs of torque on bottom and 11 to 10 k ft Ibs off bottom. ECD's 10.59 to 10.82 ppg. PU wt 237 to 240k, SO wt 178 to 180k, Rot wt 203 to 207k. 06:00 12:00 6.00 9,867 10,394 INTRM1 DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Sun GeoPilot (ser # TL270) from 9867' to 10394' (6843' TVD). Actual drilling time 4.4 hrs. Drill w/ 15 to 25k weight on bit. Pumping 650 gpm w/ 2580 to 2790 psi. Rotate 150 rpm w/ 14 to 15 k ft Ibs of torque on bottom and 10.5 to 11.5 k ft Ibs off bottom. ECD's 10.75 to 10.82 ppg. PU wt 250k, SO wt 178 to 180k, Rot wt 205 k. Page 7 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 20:00 8.00 10,394 11,053 INTRM1 DRILL DDRL P Drill 8 -3/4" hole w/ Sperry Sun GeoPilot (ser # TL270) from 10394' to 11053' (6953' TVD). Actual drilling time 5.59 hrs. Drill w/ 20 to 25k weight on bit. Pumping 650 gpm w/ 2790 to 2660 psi. Rotate 150 rpm w/ 15 to 15.5 k ft Ibs of torque on bottom and 11.5 to 12 k ft lbs off bottom. ECD's 10.82 to 10.68 ppg. PU wt 260k, SO wt 170 k, Rot wt 205 k. 20:00 22:00 2.00 11,053 11,008 INTRMI DRILL CIRC P Circulate and condition mud and hole. Pumping 650 gpm w/ 2650 psi. Rotate 150 rpm w/ 14.5k ft Ibs of torque. Working from 11053' to 11008'. Pumped two bottom's up, then pumped a weighted hi vis sweep w/ nut plug (11.8 ppg, 7ppb nut plug) surface to surface. 30% increase in cutting w/ sweep. 22:00 23:00 1.00 11,008 10,913 INTRM1 DRILL CIRC P Backream f/ 11008 to 10913' (one stand) while pulling 2 -3' /minute. Rotate 120 to 100 rpm w/ 12 k ft Ibs of torque. Circulated a bottom's up. 23:00 00:00 1.00 10,913 10,414 INTRM1 DRILL REAM P Backream out of the hole f/ 10913' to 10414'. Pumping 650 gpm w/ 2550 psi. Pulling 20 ft/minute. Rotate 100 to 120 rpm w/ 12k ft Ibs of torque. PU wt 245k, SO wt 175k w/o pumps. 04/10/2010 Continue to backream out of the hole pumping 650 gpm w/ 2550 to 2480 psi, rotate 100 rpm w/ 12.5 k ft Ibs of torque, pulling speed 20' /min from 10414' to 9202', circulate bottom's up while backreaming f/ 9202' to 9107' pulling 2' -3' /minute, flow check - static, run in the hole from 9107' to 9202', blow down the top drive, con't to run in the hole from 9202' to 11008', make a top drive connection, then precautionary ream from 11008' to TD at 11053'. Backream out of the hole from 11053' to 10843' while circulating hole clean and weighting up from 9.8 ppg to 10.0 ppg. Pulling speed 4' /minute. Obtain slow pump rates. Trip in the hole to 11053'. Circulate 378 gpm w/ 1430 psi, loading casing running pill into the drill pipe. Pull out of the hole, laying in the casing running pill. Pumping 126 gpm, pulling 30' /minute from 11053' to 9202'. Blow down the top drive. Pull out of the hole on elevators f/ 9202' to 3495' (wipe tight spots @ 6272', 4731', 4700' and 3640'), monitoring the well on the trip tank. Backream f/ 3495' to 2640' (cleaning up the 8 -3/4" open hole & 9 -5/8" surface casing), pumping 600 gpm w/ 1600 psi, rotate 115 rpm w/ initial 8k ft Ibs, final 5.5k ft Ibs of torque. ECD spikes of 11.41 at 2929' and 11.07 ppg @ 2830'. Monitor well, pull out of the hole on the trip tank from 2640' to 740'. Monitor well @ the HWDP- static, continue to pull out of the hole to 78', plug in to download MWD, break bit, clean floor, lay down BHA #2. Wash stack w/ 800 gpm and 530 psi w/ stack washing tool (45' to surface), lay down tool. Blow down the top drive, set back a stand of 5" drill pipe. Pull FMC long (10" ID) wear bushing. Pre job safety meeting. Changing upper pipe rams from 3 -1/2" x 6" to 7" solid body. 00:00 02:15 2.25 10,414 9,202 INTRMI DRILL REAM P Continue to Backream out of the hole pumping 650 gpm w/ 2550 to 2480 psi, rotate 100 rpm w/ 12.5 k ft Ibs of torque, pulling speed 20' /min from 10414' to 9202'. 02:15 02:45 0.50 9,202 9,107 INTRMI DRILL CIRC P Circulate bottom's up while backreaming f/ 9202' to 9107' pulling 2' -3' /minute, pumping 650 gpm w/ 2480 psi, rotate 100 rpm w/ 12.0 k ft Ibs of torque. Page 8 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:00 0.25 9,107 9,202 INTRM1 DRILL OWFF P Run in the hole from 9107' to 9202'. Flow check - static. Blow down the top drive. 03:00 04:00 1.00 9,202 11,008 INTRM1 DRILL TRIP P Continue to run in the hole from 9202' to 11008'. 50' to 60' /minute. Obtain PU and SO wt's every 5 stands. Hole took 5k at 10442' and 10880', then 15k at 10986'. Worked these areas- OK. PU wt 247k, SO wt 173k. 04:00 04:15 0.25 11,008 11,053 INTRM1 DRILL REAM P Make a top drive connection, then precautionary ream from 11008' to TD at 11053'. Pumping 650 gpm w/ 2580 psi, rotate 100 rpm w/ 12.0 k ft Ibs of torque 04:15 05:30 1.25 11,053 10,843 INTRMI DRILL REAM P Backream out of the hole from 11053' to 10843' while circulating hole clean ( two bottom's up) and weighting up from 9.8 ppg to 10.0 ppg. Pumping 650 gpm w/ 2580 psi, rotate 100 rpm w/ 12.0 k ft Ibs of torque, pulling speed 4' /min. 05:30 05:45 0.25 10,843 10,843 INTRMI DRILL CIRC P Obtain slow pump rates. 05:45 06:00 0.25 10,843 11,053 INTRM1 DRILL TRIP P Trip in the hole from 10843' to 11008'. Make a top drive connection. Ream to bottom @ 11053'. PU wt 246k, SO wt 176k. 06:00 06:30 0.50 11,053 11,053 INTRM1 DRILL CIRC P Circulate, loading casing running pill in the drill pipe. Pumping 378 gpm w/ 1430 psi. Rotate 100 rpm w/ 12.5k ft Ibs of torque. Note: Casing running pill consists of 70 bbls new Glydril mud, 110 bbls mud f/ active pits, then 5 ppb each: Safe Carb 40, Safe Carb 250, Sack black, Alpine beads. 06:30 08:30 2.00 11,053 9,202 INTRM1 DRILL TRIP P Pull out of the hole while pumping, laying in the casing running pill from 11053' to 9202'. Pumping 126 gpm w/ 230 psi., pulling 30' /minute. 08:30 08:45 0.25 9,202 9,202 INTRMI DRILL OTHR P Blow down the top drive. Line up the trip tank. 08:45 12:00 3.25 9,202 6,065 INTRMI DRILL TRIP P Pull out of the hole on elevators from 9202' to 6065. Monitor well on the trip tank. At 6065': PU wt 185k, SO wt 152'. Tight spot at 6272'. 12:00 13:15 1.25 6,065 3,495 INTRM1 DRILL TRIP P Crew change, then continue to pull out of the hole on elevators from 6065' to 3495'. Monitor well on the trip tank. Tight spots @ 4731', 4700' and 3640'. Wiped tight spots. 13:15 13:30 0.25 3,495 3,495 INTRM1 DRILL OTHR P Line up to circulate. Make a top drive connection. Page 9 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 15:45 2.25 3,495 2,640 INTRM1 DRILL REAM P Backream from 3495' to 2640', cleaning up the 8 -3/4" open hole & 9 -5/8" surface casing.. Pumping 600 gpm w/ 1600 psi. Rotate 115 rpm w/ initial 8k, final 5.5k ft Ibs of torque. ECD spike of 11.41ppg @ 2920', ECD spike of 11.07 ppg @ 2830'. 15:45 16:00 0.25 2,640 2,635 INTRM1 DRILL OWFF P Monitor well- static. 16:00 18:30 2.50 2,635 740 INTRMI DRILL TRIP P Pull out of the hole f/ 2635' to 740', monitor on the trip tank. Remove ghost reamer @ 1824'. 18:30 18:45 0.25 740 618 INTRM1 DRILL OWFF P Monitor well at the HWDP (740') - static. Pull out to ghost reamer @ 618', lay down ghost reamer. 18:45 19:45 1.00 618 78 INTRM1 DRILL TRIP P Continue to pull out and stand back HWDP, jars, stand of 6 -3/4" flex drill collars, and integral blade stabilizer from 618' to 78'. 19:45 21:00 1.25 78 78 INTRM1 DRILL OTHR P Make up lift sub, then pick up, plug in to download, continue to pick up and break bit while downloading MWD. Clean floor. 21:00 21:45 0.75 78 0 INTRMI DRILL PULD P Lay down BHA #2 from 78'. 21:45 22:15 0.50 0 0 INTRM1 DRILL CIRC P Make up stack washing tool, run in to 45', wash stack 800 gpm w/ 520 psi. Work twice. 22:15 22:30 0.25 0 0 INTRM1 DRILL TRIP P Blow down the top drive. Set back a stand of 5" drill pipe. 22:30 23:00 0.50 0 0 INTRM1 WHDBO OTHR P Pull FMC long wear bushing (10" ID). Note: Noticed a small piece of iron, below top seal, when wear bushing was pulled out. 23:00 23:15 0.25 0 0 INTRM1 WHDBO SFTY P Pre job safety meeting on changing top pipe rams. 23:15 00:00 0.75 0 0 INTRMI WHDBO NUND P Change upper pipe rams from 3 -1/2" x 6" to 7" solid body rams. Sim ops, working to rig up top drive for running 7" casing. 04/11/2010 Continue changing upper pipe rams from 3 -1/2" x 6" to 7" solid body. rig up to test, test rams to 250 psi and 3500 psi f/ 5 minutes each. Chart test. Rig down testing equipment. Set FMC casing running wear bushing (10- 15/16" OD x 10 -3/8" ID x 1.53' long), lay down running tool. PJSM, then rig up to run 7" 26 ppf L -80 BTC -m casing. PJSM, then run 7" casing per detail- circulate @ 2815', 5039', 7315', and 9403'. Once landed on hanger w/ shoe © 11041', rig down Frank's fillup tool, make up Dowell cement head, continue to circulate stagging pumps from 3.5 bpm w/ 380 psi to final of 6 bpm w/ 450 psi. Held pre job safety meeting on cement job while circulating. Note: Held Safety Standown with crew coming out at noon. Time of meeting 0945 hrs. Held Safety Standown with crew coming out at midnight. Time of meeting 2145 hrs. Held Safety Standown with crews @ MI mud plant. Time of meeting approx 1730 hrs. 00:00 00:15 0.25 0 0 INTRM1 WHDBO NUND P Continue changing upper pipe rams from 3 -1/2" x 6" to 7" solid body. 00:15 00:45 0.50 0 0 INTRM1 WHDBO BOPE P Set FMC test plug. Rig up to test 7" upper pipe rams. Fill stack with water. Lower annulus open. 00:45 01:00 0.25 0 0 INTRMI WHDBO BOPE P Test upper pipe rams to 250 psi and 3500 psi f/ 5 minutes each. Chart test. Page 10 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:15 0.25 0 0 INTRM1 WHDBO RURD P Rig down testing equipment. 01:15 01:30 0.25 0 0 INTRM1 WHDBO RURD P Set FMC thin wall casing running wear bushing (10- 15/16" OD x 10 -3/8" ID x 1.53' long), lay down running tool. 01:30 01:45 0.25 INTRMI CASING SFTY P Pre job safety meeting on rigging up to run 7" 26 ppf L -80 BTC -m casing. 01:45 02:30 0.75 0 0 INTRMI CASING RURD P Finish rigging up to run 7" 26 ppf L -80 BTC -m casing. 02:30 02:45 0.25 0 0 INTRM1 CASING SFTY P Pre job safety meeting on running 7" 26 ppf L -80 BTC -m casing. 02:45 03:15 0.50 0 165 INTRM1 CASING RNCS P Run 7" casing per program:Pick upjt #1: Ray Oil tool 7" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7" x 8 -3/8 ") floating from shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ 7 "x8 -3/8" aluminum centralizer between box and 10' below box with stop ring.Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Thread lock joint #3 w/ ray Oil Tool aluminum centralizer (7" x 8 -3/8 ') floating f/ pin to 10' above pin with stop ring.Baker lock Halliburton Baffle adapter, then baker lock pin of joint #4 with centralizer floating the full joint. Four connections were baker locked. 03:15 03:30 0.25 165 165 INTRMI CASING CIRC P Stab Frank's fill up tool into box of joint #4. Then circulate 25 bbls of mud to check floats. Pumping up to 6 bpm w/ 300 psi. 03:30 06:00 2.50 165 1,680 INTRM1 CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing g/ 165' to 1680' (40 joints in the hole). PU wt 110k, So wt 109k. Obtain PU and SO wt's per rig engineer. 06:00 07:15 1.25 1,680 2,815 INTRMI CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing g/ 1680' to 2815' (67 joints in the hole). PU wt 110k, SO wt 109k. Obtain PU and SO wt's per rig engineer. 07:15 07:45 0.50 2,815 2,815 INTRMI CASING CIRC P Circulate, staged pumps up from 3.5 bpm w/ 250 psi - FCP 7 bpm w/ 440 psi. Circulated 120 bbls - highest MW out 10.0 ppg PUW 130K SOW 122K 07:45 10:15 2.50 2,815 5,039 INTRMI CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing f/ 2815 to 5039' (174 joints in the hole). PU wt 177k, SO wt 143k. Obtain PU and SO wt's per rig engineer. Page 11 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 11:00 0.75 5,039 5,039 INTRMI CASING CIRC P Circulate, staged pumps up from 3.5 bpm w/ 320 psi - FCP 7 bpm w/ 570 psi. Circulated 256 bbls - highest MW out 10.2 ppg PUW 170K SOW 143K 11:00 13:30 2.50 5,039 7,315 INTRMI CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing f/ 5039 to 7315' (174 joints in the hole). PU wt 245k, SO wt 157k. Obtain PU and SO wt's per rig engineer. 13:30 14:45 1.25 7,315 7,315 INTRM1 CASING CIRC P Circulate, staged pumps up from 3.5 bpm w/ 375 psi - FCP 6 bpm w/ 530 psi. Circulated 340 bbls - highest MW out 10.35 ppg PUW 225K SOW 160K 14:45 17:00 2.25 7,315 9,403 INTRM1 CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing f/ 7315 to 9403' (224 joints in the hole). PU wt 285k, SO wt 175k. Obtain PU and SO wt's per rig engineer. 17:00 18:30 1.50 9,403 9,403 INTRM1 CASING CIRC P Circulate, staged pumps up from 3.5 bpm w/ 440 psi - FCP 6 bpm w/ 560 psi. Circulated 470 bbls - highest MW out 10.35 ppg PUW 275K SOW 173K 18:30 20:45 2.25 9,403 11,000 INTRM1 CASING RNCS P Continue to run 7" 26 ppf L -80 BTC -m casing f/ 9403 to 11000' (262 joints in the hole). PU wt 285k, SO wt 175k. Obtain PU and SO wt's per rig engineer. 20:45 21:00 0.25 11,000 11,041 INTRMI CASING RNCS P Make up FMC 7" hanger and landing joint. Run in hole and land on hanger with shoe at 11041'. PU wt 320k, SO wt 175k. 21:00 21:15 0.25 11,041 11,041 INTRM1 CEMEN" RURD P Blow down the top drive. Make up Dowell cement head. attatch hose and valves to head. 21:15 00:00 2.75 11,041 11,041 INTRMI CEMEN" CIRC P Circulate and condition mud and hole for cement job. Stage pumps up from 3.5 bpm w/ 380 psi to 6 bpm w/ 450 psi. Note: Held Safety standown with crew coming out at noon. Time of meeting 0945 hrs. Held Safety standown with crew coming out at midnight. Time of meeting 2145 hrs. Held Safety standown with crews @ MI mud plant. Time of meeting approx 1730 hrs. Page 12 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/12/2010 24 hr Summary Continue to circulate and condition mud f/ cement job. Flow check- slight flow (air in mud), continue to circulate while increasing mud weight f/ 10 ppg to 10.2 ppg, flow check- static, Dowell perform 1st stage cement job (see cement report)- rig bumped plug, loaded 2nd stage plug, preesured up to open stage tool @ 5950', circulate, Dowell perform 2nd stage cement job (see cement report), bumped plug- shifted tool shut. PJSM on rigging down cementing equipment. Rig down cementing equipment. Lay down 7" FMC landing joint, clear floor, pull casing running wear bushing, install FMC 7" packoff, lay down landing joint, test packoff to 5000 psi f/ 5 minutes- good test. Install drilling bales and 5" elevators to the top drive. PJSM, lay down a stand of 6 -3/4" drill collars, 8 stands of 5" HWDP (includes jars). Lay down 37 stands of 5" drill pipe. Service rig. Lay down 76 stands of 5" drill pipe. PJSM, then start changing out the top pipe rams. Change from 7" to 3 -1/2" x 6 ". Note: Dowell performed LOT on the 9 -5/8" x 7" annulus - -15.3 ppg EMW w/ 10.2 ppg mud (652 PSI) (Shoe @ 2833', 2468' TVD), then flushed w/ 300 bbls water, followed by 45 bbls diesel on 4 -12 -2010. 00:00 01:00 1.00 11,041 11,041 INTRM1 CEMEN "CIRC P Circulate and condition mud and hole for cement job. Pumping 6 bpm w/ 450 to 480 psi. Reciprocate 7" casing 30' stroke f/ 11041' to 11011'. PU wt 295k, SO wt 175k. 01:00 01:15 0.25 11,041 11,041 INTRMI CEMEN" OWFF P Flow check well, slight flow. Air in the mud. 01:15 04:15 3.00 11,041 11,041 INTRMI CEMEN" CIRC P Increase mud weight from 10.0 ppg to 10.2 ppg precautionary. Pumping 6 bpm w/ 470 to 530 psi. Reciprocate 30' stroke from 11041' to 11011'. 04:15 04:30 0.25 11,041 11,041 INTRMI CEMEN "OWFF P Flow check well, static. No air in mud. 04:30 05:30 1.00 11,041 11,041 INTRMI CEMEN "CMNT P Dowell pump 2 bbl CW 100, pressure test lines to 3500 psi -ok. Pump another 38 bbls of CW100 (40 bbls total) @ 4 bpm w/ 350 to 380 psi. Mix and pump 35 bbls 11.5 ppg mud push @ 4 bpm w/ 330 final pressure, shut down. Load Halliburton bottom plug, kick out plug w/ 5 bbls more MudPush f/ a total of 40 bbls. Load Halliburton top plug while Dowell mixing cement. Reciprocate 30'. 05:30 05:45 0.25 11,041 11,041 INTRMI CEMEN" PUCM P Dowell pump 64.2 bbls 15.8 ppg (310 sx) (1.16 cuft/sx) (5.08 qal /sx water) (5.34 hr thickening time). Drop Halliburton top shut off plug. / Reciprocated pipe 30' stroke. ,/ 05:45 06:00 0.25 11,041 11,041 INTRM1 CEMEN" DISP P Kick plug out with 20 bbls water through the tub, pumping 6 bpm w/ 118 to 72 psi. Page 13 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:30 1.50 11,041 11,041 INTRMI CEMEN "DISP P Rig displace cement w/ 10.2 ppg mud, pumping 6 bpm w/ initial 120 psi, final 630 psi. Stayed on hanger (10 bbls before and 10 bbls after) when CW100, MudPush II and cement came around shoe, then continued reciprocation. Reciprocated 30' stroke until slowing displacement to 3 bpm w/ 420 psi initial and 430 psi final for last 5.4 bbls prior to bumping plug w/ 930 psi @ 0652 hrs 4/12/2010. Held pressure f/ 5 minutes, then bleed off and checked floats -OK. Load Halliburton 2nd stage closing plug in the cement head. Note: Final PU wt 280k, Final SO wt 170k. Plug bumped 37 strokes early. 07:30 07:45 0.25 11,041 11,041 INTRM1 CEMEN "CIRC P Rig pressure up to open Halliburton stage tool @ 5950'. Tool opened with 3330 psi applied. 07:45 08:45 1.00 11,041 11,041 INTRMI CEMEN "CIRC P Circulate and condition mud for cementing through the Halliburton stage tool @ 5950'. Pumping 5 bpm w/ 210 psi. 08:45 09:00 0.25 11,041 11,041 INTRM1 CEMEN P Dowell pump 30 bbl CW 100 @ 4 bpm w/ 208 to 257 psi. Mix and pump 30 bbls 11.5 ppg mud push @ 5.2 bpm w/ 275 psi final pressure, shut down. 09:00 09:15 0.25 11,041 11,041 INTRM1 CEMEN" PUCM P Dowell mix, then pump 41 bbls 15.8 ppg (198 sx) (1.16 cuft/sx) (5.11 gal /sx water) (5.34 hr thickening time). Drop Halliburton closing plug. 09:15 09:30 0.25 11,041 11,041 INTRM1 CEMEN" DISP P Kick plug out with 20 bbls water through the tub, pumping 6 bpm w/ 99 psi. 09:30 10:15 0.75 11,041 11,041 INTRM1 CEMEN" DISP P Rig displace cement w/ 10.2 ppg mud, pumping 5 bpm w/ initial 70 psi, final 300 psi, slowing displacement to 3 bpm w/ 230 psi initial and 250 psi final for last 7.3 bbls prior to bumping plug w/ 1460 psi to close @ 01914 hrs, then pressure to 1930 psi @ 0915 hrs 4/12/2010. Held pressure f/ 5 minutes, then bleed off and checked floats -OK. Blow down lines. Note: Bumped plug 2.7 bbls early. 10:15 10:30 0.25 11,041 11,041 INTRMI CEMEN" SFTY P Pre job safety meeting on rigging down cementing equipment. 10:30 11:00 0.50 11,041 11,041 INTRM1 CEMEN" RURD P Rig down cement head and equipment. 11:00 11:30 0.50 INTRM1 DRILL PULD P Lay down the 7" FMC landing joint. 11:30 11:45 0.25 INTRM1 DRILL OTHR P Clean and clear rig floor. Page 14 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 12:15 0.50 INTRM1 DRILL PULD P Pickup test joint with wear ring running tool. Pull FMC thin wall casing running wear bushing (10- 15/16" OD x 10 -3/8" ID x 1.53' long), lay down running tool. 12:15 12:45 0.50 INTRMI WHDBO PULD P Install FMC 7" packoff, using a test joint. Lay down the test joint. 12:45 12:45 0.00 INTRMI WELLPF PRTS P Test FMC 7" packoff to 5000 psi f/ 5 minutes. 12:45 13:00 0.25 INTRM1 DRILL RURD P Install drilling bales and 5" elevators to the top drive. 13:00 13:15 0.25 INTRMI DRILL SFTY P Pre job safety meeting on laying down 5" drill pipe from the derrick using the mouse hole. 13:15 18:00 4.75 INTRMI DRILL PULD P Lay down a stand of 6 -3/4" non mag flex drill collars, 8 stands of 5" HWDP (includes jars), 37 stands of 5" drill pipe. 18:00 18:30 0.50 INTRM1 RIGMNT SVRG P Service rig: Grease blocks, iron roughneck and drawworks. 18:30 23:30 5.00 INTRMI DRILL PULD P Lay down 76 stands of 5" drill pipe from the derrick, via the mouse hole. A total of 113 stands were layed down. 23:30 23:45 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting on changing top pipe rams. 23:45 00:00 0.25 INTRM1 WHDBO OTHR P Change out the top pipe rams from 7" to 3 -1/2" x 6" variables. 04/13/2010 Con't to change top pipe rams from 7" to 3 -1/2" x 6 ". Pick up 4" test joint & FMC upper test plug, set test plug w/ annulus open. PJSM on rigging up, then testing BOPE. Rig up to test BOPE. Fill stack with water. Test BOPE: Test BOPE. Witness of test waived by AOGCC inspector John Crisp. Electrician tested gas alarms. Performed Koomey recovery test. All tests were charted. All tests were held 5 minutes. All tests with 4" test joint. Tested annular to 250 psi low and 2500 psi high. Test upper and lower pipe rams, blinds, kill and choke line valves, choke manifold, mud valve in mezzanine, top drive IBOP valves and floor safety valves to 250 psi low and 3500 psi high. Valve in mezzanine leaked. Pre job safety meeting on replacing bonnet, valve gate and seat on 4" mud line valve. Replace bonnet, valve gate and seat on 4" mud line valve in mezzanine. Con't Test BOPE:Test with 3 -1/2" test joint. Tested annular to 250 psi low & 2500 psi high. Test upper & lower pipe rams, mud valve in mezzanine. Rig down testing equipment. Pull FMC test plug. Install FMC wear bushing. (7 -3/8" ID). PJSM, Pick up BHA #3, run in the hole w/ HWDP & jars to 287'. Change elevators to 4 ". Pick up & run in on top of BHA #3, 4" drill pipe from the pipe shed to 5804'. Circ, test the 7" 26 ppf L -80 BTC -m casing to 3500 psi f/ 10 minutes. Wash and ream from 5804' to tag cement at 5933', drill cement to stage collar @ 5950'. Drill stage collar to 5953' then stringers and wash to 6279', circ BU, test casing to 1000 psi, pull out of the hole f/ 6279' to 1325'. Note: Dowell performed LOT on the 9 -5/8" x 7" annulus -15.3 ppg EMW w/ 10.2 ppg mud (652 PSI) (Shoe @ 2833', 2468' TVD), then flushed w/ 300 bbls water, followed by 45 bbls diesel on 4 -12 -2010. Note: Dowell performed top job on 16" x 9 -5/8" annulus. Cement was 32' below top of landing ring, filled w/ Arctic Set 1 15.7 ppg cement to 20" below landing ring. 3 bbls to fill, pumped 6 bbls (37 sx). 00:00 01:15 1.25 INTRM1 WHDBO OTHR P Continue to change out the top pipe _rams from 7" to 3 -1/2" x 8" variahI s. 01:15 01:45 0.50 INTRMI WHDBO PULD P Pick up 4" test joint and FMC upper test plug, run in and set test plug w/ annulus open. 01:45 02:00 0.25 INTRM1 WHDBO SFTY P Pre job safety meeting on rigging up, then testing BOPE. 02:00 02:15 0.25 INTRMI WHDBO BOPE P Rig up to test BOPE. FiII stack with water, work air out of system. Page 15 of 30 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 07:00 4.75 INTRM1 WHDBO BOPE P Test BOPE: Test BOPE. Witness of test waived by AOGCC inspector John Crisp. Electrician tested gas alarms. Performed Koomey recovery test. All tests were charted. All tests p were held 5 minutes. All tests with 4" R('1 test joint. Tested annular to 250 psi f/ low and 2500 psi high. Test upper and lower pipe rams, blinds, kill and choke line valves, choke manifold, mud valve in mezzanine, top drive IBOP valves and floor safety valves to 250 psi low and 3500 psi high. Valve in mezzanine leaked. 07:00 07:15 0.25 INTRMI RIGMNT SFTY T Pre job safety meeting on replacing bonnet, valve gate and seat on 4" mud line valve. 07:15 07:45 0.50 INTRMI RIGMNT RGRP T Replace bonnet, valve gate and seat on 4" mud line valve in mezzanine. 07:45 08:30 0.75 INTRM1 WHDBO BOPE P Continue Test BOPE:All tests were charted. All tests were held 5 minutes. Test with 3 -1/2" test joint. Tested annular to 250 psi low and 2500 psi high. Test upper and lower pipe rams, mud valve in mezzanine, 08:30 09:00 0.50 INTRMI WHDBO RURD P Rig down testing equipment. Blow down lines. Pull FMC test plug. 09:00 09:15 0.25 INTRMI WHDBO OTHR P Install FMC wear bushing. (7 -3/8" ID). 09:15 09:30 0.25 INTRMI DRILL SFTY P Pre job safety meeting on picking up BHA #3. 09:30 10:45 1.25 0 287 INTRMI DRILL PULD P Pick up BHA #3, run in the hole w/ HWDP and jars to 287'. Change elevators to 4 ". Note: Sim Ops: Cement was tagged at 32' below the landing ring. Filled annulus of 16" (1.031" wall thickness) x 9.625" casing with water from tag of 32' below landing ring, taking returns in the cellar from landing ring.. Took 3 bbls to fill, using centrifugal pump. Mix and pump 6 bbls of ASI cement @ 15.7 ppg (.93 cuft/sx) (3.553 gal /sx water) (1:47 thickening time), using centrifugal pump. Pumped all the cement allowing returns to cellar, sucking cellar w/ vac truck. Pulled out the 3/4" hose from between the conductor and surface pipe. Then sucked the cement down to 20" (1.67') below the top of landing ring. 10:45 12:00 1.25 287 1,704 INTRM1 DRILL PULD P Pick up and run in on top of BHA #3, 4" drill pipe from the pipe shed. PU wt 97k, SO 97k. Page 16 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:45 3.75 1,704 5,804 INTRM1 DRILL PULD P Continue to pick up and run in on top of BHA #3, 4" drill pipe from the pipe shedf/ 1704' to 5804'. PU wt 155k, SO wt 125k. 15:45 16:00 0.25 5,804 5,804 INTRMI DRILL CIRC P Make a top drive connection, then circulate prior to casing test to 1000 psi. Pumping 250 gpm w/ 960 psi. 16:00 16:15 0.25 5,804 5,804 INTRMI DRILL RURD P Blow down the top drive. Rig up to test casing. 16:15 16:30 0.25 5,804 5,804 INTRM1 DRILL PRTS P Test the 7" 26 ppf L -80 BTC -m casing to 3500 psi f/ 10 minutes. 16:30 16:45 0.25 5,804 5,804 INTRMI DRILL RURD P Rig down testing equipment. Blow down lines. 16:45 17:15 0.50 5,804 5,950 INTRMI CEMEN' DRLG P Wash and ream from 5804' to tag cement at 5933', drill cement to stage collar @ 5950'. Pumping 300 gpm w/ 1170 psi. Rotate 90 rpm w/ 7.5k ft Ibs of torque. Rot wt 132k. 17:15 18:30 1.25 5,950 5,953 INTRM1 CEMEN' DRLG P Drill Halliburton 7" stage collar f/ 5950' to 5953'. Pumping 300 gpm w/ 1170 psi. Rotate 90 rpm w/ 7.5k ft Ibs of torque. Rot wt 132k. Drill w/ 6 -10k wt on bit. 18:30 20:00 1.50 5,953 6,279 INTRMI CEMEN" DRLG P Wash and ream tagging stringers @ 6070'. Weight on bit 5 to 10k. Wash down to 6279'. 20:00 20:30 0.50 6,279 6,279 INTRMI DRILL CIRC P Circulate bottom's up prior to testing casing to 1000 psi. Pumping 300 • gpm w/ 1170 psi. Rotate 90 rpm w/ 9k ft Ibs of torque. PU wt 170k, SO wt 125k. 20:30 20:45 0.25 6,279 6,279 INTRM1 DRILL RURD P Blow down the top drive. Rig up to test casing. 20:45 21:00 0.25 6,279 6,279 INTRM1 DRILL PRTS P Test the 7" 26 ppf L -80 BTC -m casing to 1000 psi f/ 10 minutes. 21:00 21:15 0.25 6,279 6,279 INTRM1 DRILL RURD P Rig down testing equipment. Blow down lines. 21:15 00:00 2.75 6,279 1,325 INTRM1 DRILL TRIP P Pull out of the hole w/ BHA #3 from 6279' to 1325'. PU wt 90k, SO wt 90k. 04/14/2010 Con't to pull out of the hole w/ BHA #3 f/ 1325' to 287', PJSM, OWFF- static, Work BHA, PJSM, PU /MU /RIH w/ BHA #4 (6 -1/8" bit & GeoPilot ser # TL081) to 94', upload, con't PU /MU /RIH w/ BHA #4 f/ 94' to 417'. Shallow pulse test MWD -OK. PU /MU /RIH w/ 4" dp from pipe shed on top of BHA #4 from 417' to 6707'. PJSM, slip and cut 90' of 1 -3/8" drill line, service top drive. Trip in the hole running 4" dp from the derrick f/ 6707' to 9371'. MADD pass logging (max speed 5' /minute) from 9371' (BAT sensor depth 9262') to 10767' (BAT sensor depth 10658'). Drill cement f/ 10767' to 10865', circulate bottom's up, stand back a stand to 10800', rigup then test casing to 3575 psi for 30 minutes (charted test) (no pressure loss). Rig down testing equipment, make a top drive connection and drill cement from 10865' to the Halliburton baffle collar @ 10910'. 00:00 00:45 0.75 1,325 287 INTRM1 DRILL TRIP P Pull out of the hole w/ BHA #3 from 1325' to 287'. 00:45 01:00 0.25 287 287 INTRM1 DRILL SFTY P Pre job safety meeting on laying down BHA #3. Flow check well - static. 01:00 01:15 0.25 287 0 INTRMI DRILL TRIP P Stand back HWDP, jars and flex drill collars. Lay down stab, bit sub and bit. Page 17 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:30 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on picking up BHA #4 (6 -1/8" bit w/ GeoPilot). 01:30 02:45 1.25 0 94 INTRMI DRILL PULD P Pick up/ Make up BHA #4 (6 -1/8" bit, GeoPilot ser # TL 081). 02:45 03:30 0.75 94 94 INTRMI DRILL PULD P Upload Sperry Sun MWD. 03:30 04:15 0.75 94 417 INTRMI DRILL PULD P Continue to pick up/ Make up BHA #4 (6 -1/8" bit, GeoPilot ser # TL 081). 04:15 04:45 0.50 417 417 INTRM1 DRILL DHEQ P Shallow pulse test MWD. Pumping 200 gpm w/ 870 psi. Break in seals on the GeoPilot (ser # TL081). Blow down the top drive. 04:45 10:00 5.25 417 6,707 INTRMI DRILL TRIP P Pick up /Make up / Run in the hole w/ 4" drill pipe from the pipe shed from 417' to 6707'. Fill pipe every 20 stands. 10:00 10:15 0.25 6,707 6,707 INTRM1 DRILL SFTY P Pre job safety meeting on cutting drilling line. 10:15 11:00 0.75 6,707 6,707 INTRMI RIGMNT SLPC P Slip and cut 90' of 1 -3/8" drilling line. 11:00 11:30 0.50 6,707 6,707 INTRM1 RIGMNT SVRG P Service the top drive. 11:30 12:00 0.50 6,707 8,035 INTRMI DRILL TRIP P Trip in the hole from the derrick w/ BHA #4 from 6707' to 8035'. PU wt 205k, SO wt 130k. 12:00 12:45 0.75 8,035 9,371 INTRM1 DRILL TRIP P Continue to trip in the hole from the derrick w/ BHA #4 from 8035' to 9371'. PU wt 223k, SO wt 135k. 12:45 18:30 5.75 9,371 10,767 INTRM1 DRILL DLOG P MADD pass logging cement lob w/ BAT /Sonic. Travel speed maximum of 5' /minute. Log from bit depth 9371' (BAT sensor depth 9262') to 10767' (BAT sensor depth 10658'). (BAT sensor 109.03' behind bit). PU wt 240k, SO wt 140k. 18:30 19:30 1.00 10,767 10,865 INTRM1 CEMEN" COCF P Drill cement from 10767' to 10865'. Pumping 200 gpm w/ 1820 psi, rotate 100 rpm w/ 14k ft Ibs of torque. Rot wt 165k. 19:30 21:00 1.50 10,865 10,865 INTRMI DRILL CIRC P Circulate bottom's up, pumping 200 gpm w/ 1810 psi, rotate 100 rpm w/ 14.5k ft lbs of torque. Note: GeoPilot ( ser# TL081) quit responding while circulating. 21:00 21:15 0.25 10,865 10,800 INTRMI DRILL TRIP P Stand back stand #110. Blow down the top drive. 21:15 21:30 0.25 10,800 10,800 INTRMI DRILL RURD P Rig up to test 7" 26 ppf L -80 BTC -m casing. 21:30 22:15 0.75 10,800 10,800 INTRM1 DRILL PRTS P Test casing to 3575 psi f/ 30 minutes. Chart test. Good Test. 22:15 22:45 0.50 10,800 10,800 INTRMI DRILL RURD P Rig down testing equipment. 22:45 00:00 1.25 10,800 10,910 INTRM1 CEMEN" COCF P Make a top drive connection w/ stand #110, then continue to drill cement from 10865' to the baffle adapter @ 10910'. Rotate 85 rpm w/ 14 -15k ft lbs of torque. Pumping 200 gpm w/ 1850 psi. Page 18 of 30 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/15/2010 24 hr Summary Drill the Halliburton baffle collar @ 10910', cement to the Halliburton Sure Seal II Float collar, then cement to 11029', circ hole clean, SPR's, monitor well, pump dry job, set back a stand, blow down the top drive, pull out of the hole f/ Sperry Sun GeoPilot failure from 10990' to 417', work BHA, PJSM, lay down BHA #4, trouble shoot Sperry Sun MWD- tools, download tools. Break and test GeoPilot- Geopilot failed test. PJSM, PU BHA #5, upload MWD, continue making up BHA #5 to 417', shallow test MWD -OK, RIH f/ 417' to 10993', make top drive connection, ream f/ 10993' to 11029', displace mud from 10 ppg LSND to 9.1+ ppg Flow Thru, drill cement from 11029' to top of Ray Oil Tools Silver Bulledt eccentric shoe @ 11039', drill shoe to 11041', clean out cement in the rat hole to 11053', then drill 20' of new hole to 11073', circulate, set back a stand to 10992', continue to circulate hole clean, rig up to test formation. Perform Formation Integrity test to 12.6 ppg (9.1+ MW, shoe @ 6952.2' TVD, 1280 psi applied pressure). Rig down testing equipment. Proceed to drill 6 -1/8" hole w/ Sperry Sun GeoPilot (TL 064) from 11073' to 11083'. 00:00 01:00 1.00 10,910 10,953 INTRM1 CEMEN "COCF P Drill the Halliburton baffle collar © 10910 feet, drill cement to the Halliburton Sure Seal II Float collar @ 10953 feet. Pumping 203 gallons per minute with 1750 pounds per square inch. Equivalent circulating density 11.19 pounds per square inch. Rotate 50 revolutions per minute with 14000 foot pounds of torque. 01:00 01:30 0.50 10,953 11,029 INTRMI CEMEN" DRLG P Drill the Halliburton Sure Seal II Float collar @ 10953 feet, then drill cement to 11029 feet. 01:30 03:15 1.75 11,029 11,029 INTRMI CEMEN T Circulate the hole clean - Will be tripping for failed GeoPilot- pumping 203 gallons per minute with 1710 pressure per square inch, rotate 50 rpm with 14000 foot pounds of torque, acquire slow pump rates. 03:15 03:30 0.25 11,029 11,029 INTRM1 DRILL OWFF T Monitor well- static, pump dry job. 03:30 03:45 0.25 11,029 10,990 INTRM1 DRILL OTHR T Set back a stand, blow down the top drive. 03:45 07:45 4.00 10,990 417 INTRMI DRILL TRIP T Pull out of the hole (Sperry Sun GeoPilot- serial number TL081 failure) from 10990 feet to 417 feet. Monitor the well on the trip tank. 07:45 08:15 0.50 417 94 INTRM1 DRILL TRIP T Work the bottom hole assembly number 4: Stand back heavy weight drill pipe and flex non mag drill collars from 417 feet to 94 feet. 08:15 08:30 0.25 94 94 INTRM1 DRILL SFTY T Pre job safety meeting. Lay down Bimodel Acoustic Tool, stabilizer and break bit. 08:30 10:00 1.50 94 0 INTRMI DRILL DHEQ T Trouble shoot Sperry Sun Measure while drilling tools. Download measure while drilling tools. While downloading, break and test GeoPilot (serial number TL081)- failed test- shorted out. 10:00 10:15 0.25 0 0 INTRM1 DRILL SFTY T Pre job safety meeting on picking up bottom hole assembly number 5. 10:15 10:45 0.50 0 94 INTRMI DRILL PULD T Pickup bottom hole assembly number 5: Sperry Sun GeoPilot and MWD tools. Page 19 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 11:15 0.50 94 94 INTRM1 DRILL OTHR T Upload Sperry Sun measure while drilling tools. 11:15 11:30 0.25 94 125 INTRMI DRILL PULD T Continue to pick up bottom hole assembly number 5: Make up bit, then pick up BAT, stabilizer, and float sub. 11:30 12:00 0.50 125 417 INTRM1 DRILL TRIP T Run in the hole from the derrick, making up the flex drill collars, crossover, then the 4 inch heavy weight drill pipe with the Weatherford /Daily jars. 12:00 12:15 0.25 417 417 INTRMI DRILL DHEQ T Make up the top drive, then pulse test Sperry Sun measure while drilling tools. Pumping 198 gallons per minute with 740 pounds per square inch. Rotate 40 revolutions per minute with 3500 foot pounds of torque. 12:15 17:45 5.50 417 10,993 INTRM1 DRILL TRIP T Trip in the hole with bottom hole assembly number 5 from 417 feet to 10993 feet. Monitor well on the trip tank. Fill the drill string every 20 stands. 17:45 18:15 0.50 10,993 11,029 INTRM1 DRILL REAM T Make a top drive connection, then pump 203 gallons per minute with 1650 pounds per square inch. Rotate 40 revolutions per minute with 13500 foot pounds of torque. Rotate down to tag top of the cement at 11029 feet. 18:15 19:30 1.25 11,029 11,029 INTRM1 DRILL CIRC P Change over mud from 10 ppq LSND w/ glydril to 9.1+ Flo Thru mud. Pump a 35 bbl high vis spacer with 1.25 ppb Biozan and 1.25 ppb ECF -612 in fresh water ahead of the 9.1+ ppg Flow thru mud. Pumping 194 gallon per minute with 1450 to 1540 pounds per square inch. Rotate 55 revolutions per minute with 8000 foot pounds of torque. 19:30 20:00 0.50 11,029 11,039 INTRM1 CEMEN" DRLG P Drill cement from 11029 feet to the top of the Ray Oil Tools Silver bullet eccentric float shoe at 11039 feet. Pumping 194 gallons per minute with 1540 pounds per square inch. Rotate 55 revolutions per minute with 8000 foot pounds of torque. Drilling with 4000 to 6000 pounds weight on bit. 20:00 20:45 0.75 11,039 11,041 INTRMI CEMEN DRLG P Drill to the bottom of Ray Oil Tools Eccentric Float shoe, 11039 feet to 11041 feet. Pumping 194 gallons per minute with 1540 pounds per square inch. Rotate 55 revolutions per minute with 8500 foot pounds of torque. Drill with 2000 to 4000 pounds weight on bit. Page 20 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 21:15 0.50 11,041 11,053 INTRM1 CEMEN DRLG P Clean out the rat hole from 11041 feet to 11053 feet, Pumping 194 gallons per minute with 1450 pounds per square inch. Rotate 55 revolutions per minute with 8500 foot pounds of torque. 21:15 21:30 0.25 11,053 11,073 INTRMI DRILL DRLG P Drill 20 feet of new hole from 11053 feet to 11073 feet (True vertical depth = 6955.2 feet). Pumping 194 gallons per minute with 1450 pounds per square inch. Rotate 55 revolutions per minute with 8500 foot pounds of torque. Actual drilling time .27 hours. 21:30 21:45 0.25 11,073 10,992 INTRM1 DRILL CIRC P Circulate, pumping 202 gpm w/ 1450 to 1550 pounds per square inch. Rotate 55 revolutions per minute with 8500 foot pounds of torque. Backream from 11073 feet to 10992 feet. 21:45 22:45 1.00 11,073 10,992 INTRM1 DRILL CIRC P Set back a stand and continue to circulate prior to performing a leak off test or formation integrity test. Pumping 190 gallons per minute with 1310 pounds per square inch. Rotate 50 revolutions per minute with 7000 foot pounds of torque. Mud weight in and out 9.1+ pound per gallon. Blow down the top drive. 22:45 23:00 0.25 10,992 10,992 INTRMI DRILL RURD P Rig up to test formation. 23:00 23:15 0.25 10,992 10,992 INTRM1 DRILL LOT P Perform formation integrity test. to 12.6 pounds per gallon equivalent mud weight. Mud weight 9.1 heavy, shoe depth 11041' ((6952.2 foot true vertical depth), applied 1280 pounds per square inch surface pressure. 23:15 23:30 0.25 10,992 10,992 PROD1 DRILL RURD P Bleed off pressure, rig down testing equipment. Blow down lines. Pick up weight 203000 pounds. Slack off weight 160000 pounds. Rotating weight 182000 pounds. 23:30 23:45 0.25 10,992 11,073 PROD1 DRILL REAM P Make a top drive connection, then ream from 10992 feet to 11073 feet'. Pumping 194 gallons per minute with 1450 pounds per square inch. Rotate 55 revolutions per minute with 8500 foot pounds of torque. Page 21 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:45 00:00 0.25 11,073 11,083 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 11073 feet to 11083 feet with Sperry Sun GeoPilot (Serial number TL 064). Pumping 203 gallons per minute with 1430 pounds per square inch. Rotate 65 revolutions per minute with 8000 foot pounds of torque. Drill with 5000 to 8000 pounds weight on the bit. Equivalent circulating density 10.07 pounds per gallon. Pick up weight 207000, Slack off weight 160000 pounds, Rotating weight 175000 pounds. Actual drilling time .21 hours. 04/16/2010 Continue to drill 6 -1/8" hole w/ Sperry Sun GeoPilot (TL 064) from 11083' to 12345'. Note: Performed a 275 bbl whole mud dilution while drilling at 11850'. 00:00 12:00 12.00 11,083 11,745 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 11083' to 11745' with Sperry Sun GeoPilot (Serial number TL 064). Pumping 203 to 220 gpm w/ 1430 to 1660 psi. Rotate 65 to 110 rpm with 8 to 10k ft Ibs of torque on bottom, 7 to 7.5k ft Ibs off bottom. Drill with 6 to 12k weight on the bit. ECD's 10.07 to 10.40 ppg. PU wt 207 to 212k, SO wt 160 to150k, Rot wt 175 to 180k pounds. Actual drilling time 8.23 hours. 12:00 00:00 12.00 11,745 12,345 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 11745' to 12345' with Sperry Sun GeoPilot (Serial number TL 064). Pumping 220 to 205 gpm w/ 1660 to 1720 psi. Rotate 110 rpm with 9 to 10k ft Ibs of torque on bottom, 7.5 to 8k ft Ibs off bottom. Drill with 7 to 14k weight on the bit. ECD's 10.40 to 10.55 ppg. PU wt 212 to 220k, SO wt 150 to145k, Rot wt 180 to 175k pounds. Actual drilling time 7.97 hours. Note: Performed a 275 bbl whole mud dilution while drilling at 11850'. 04/17/2010 Continue to drill 6 -1/8" hole w/ Sperry Sun GeoPilot (TL 064) from 12345' to 13755' (6995.4' TVD). Note: Perfromed a 275 bbl whole mud dilution while drilling at 12537' and 13200'. 00:00 06:00 6.00 12,345 12,672 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 12345' to 12672' (6981' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 205 to 210 gpm w/ 1720 to 1840 psi. Rotate 110 to 120 rpm with 10 to 10.5k ft lbs of torque on bottom, 8 to 8.5k ft Ibs off bottom. Drill with 7 to 13k weight on the bit. ECD's 10.52 to 10.61 ppg. PU wt 220 to 225k, SO wt 145 to147k, Rot wt 180 to 175k pounds. Actual drilling time 4.88 hours. Note: Performed a 275 bbl whole mud dilution while drilling at 12537'. Page 22 of 30 • 1 Time Logs Date From To Dur S. Depth E. Depth Phase _ Code Subcode T Comment 06:00 12:00 6.00 12,672 12,991 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 12672' to 12991' (6989' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 gpm w/ 1800 psi. Rotate 110 to 120 rpm with 10.5 to 11 k ft Ibs of torque on bottom, 8.5 to 9k ft Ibs off bottom. Drill with 6 to 11 k weight on the bit. ECD's 10.61 to 10.47 ppg. PU wt 220 to 225k, SO wt 145 to147k, Rot wt 180 to 175k pounds. Actual drilling time 3.99 hours. 12:00 18:00 6.00 12,991 13,385 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 12991' to 13385' (6990' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 gpm w/ 1800 to 1900 psi. Rotate 120 rpm with 10.5 to 12k ft Ibs of torque on bottom, 9 to 9.5k ft Ibs off bottom. Drill with 6 to 12k weight on the bit. ECD's 10.47 to 10.53 ppg. PU wt 220 to 230k, SO wt 147 to138k, Rot wt 180 to 182k pounds. Actual drilling time 4.95 hours. Note: Performed a 275 bbl whole mud dilution while drilling at 13200'. 18:00 00:00 6.00 13,385 13,755 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 13385' to 13755' (6995.4' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 gpm w/ 1900 to 1960 psi. Rotate 120 rpm with 12 to 12.5k ft Ibs of torque on bottom, 9.5k ft Ibs off bottom. Drill with 6 to 12k weight on the bit. ECD's 10.53 to 10.57 ppg. PU wt 230k, SO wt 138k, Rot wt 183k pounds. Actual drilling time 4.58 hours. 04/18/2010 Continue to drill 6 -1/8" hole w/ Sperry Sun GeoPilot (TL 064) from 13755' to 14994' (7026' TVD). Note: Perfromed a 275 bbl whole mud dilution while drilling at 14050' and 14520'. Note: Fault @ 13855, drilled out the top of formation at 0205hrs, depth out 13848', back in formation © 13878'. 00:00 06:00 6.00 13,755 13,981 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 13775' to 13981' (7001' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 gpm w/ 1960 to 1940 psi. Rotate 120 rpm with 12k ft Ibs of torque on bottom, 9.5k ft Ibs off bottom. Drill with 6 to 14k weight on the bit. ECD's 10.56 to 10.36 ppg. PU wt 228k, SO wt 138 to 140k, Rot wt 183 to 182k pounds. Actual drilling time 3.88 hours. Note: Fault @ 13855', drilled out the top of formation at 0205hrs, depth out 13848', back in @ 13878'. Page 23 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 13,981 14,327 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 13981' to 14327' (7018' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 gpm w/ 1940 to 1970 psi. Rotate 120 rpm with 11 to 14k ft Ibs of torque on bottom, 9.5 to 10k ft Ibs off bottom. Drill with 14 to 4k weight on the bit. ECD's 10.36 to 10.57 ppg. PU wt 235k, SO wt 134k, Rot wt 182k pounds. Actual drilling time 4.34 hours. Note: 275 bbl whole mud dilution @ 14050'. 12:00 18:00 6.00 14,327 14,657 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 14327' to 14657' (7026' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 to 205 gpm w/ 1970 to 1860 psi. Rotate 120 rpm with 14 to 13.5k ft Ibs of torque on bottom, 10 to 11 k ft Ibs off bottom. Drill with 4 to 9k weight on the bit. ECD's 10.57 to 10.52 ppg. PU wt 234k, SO wt 135k, Rot wt 183k pounds. Actual drilling time 4.47 hours. Note: 275 bbl whole mud dilution while drilling @ 14520' 18:00 00:00 6.00 14,657 14,994 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 14657' to 14994' (7026' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 to 215 gpm w/ 1970 to 2000 psi. Rotate 120 rpm with 12.5k ft Ibs of torque on bottom, 10k ft Ibs off bottom. Drill with 4 to 11 k weight on the bit. ECD's 10.52 to 10.58 ppg. PU wt 234k, SO wt 135k, Rot wt 180k pounds. Actual drilling time 4.13 hours. 04/19/2010 Continue to drill 6 -1/8" hole w/ Sperry Sun GeoPilot (TL 064) from 14994' to 16551' (7038' TVD). Note: Perfromed a 275 bbl whole mud dilution while drilling at 15050', 15580', 15850', 16426'. Note: Drilled out the top of formation at 1300 hrs, depth out 15915', back in the formation @ 16315'. 00:00 06:00 6.00 14,994 15,444 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 14994' to 15444' (7029.6' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 215 gpm w/ 2040 psi. Rotate 120 rpm with 12.5 to 14k ft Ibs of torque on bottom, 10 to 10.5k ft Ibs off bottom. Drill with 5 to 10k weight on the bit. ECD's 10.57 to 10.53 ppg. PU wt 242k, SO wt 125k, Rot wt 181k pounds. Actual drilling time 4.66 hours. Note: 275 bbl whole mud dilution @ 15050'. Page 24 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code _Subcode T Comment 06:00 12:00 6.00 15,444 15,830 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 15444' to 15830' (7025' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 215 gpm w/ 2040 to 2010 psi. Rotate 120 rpm with 13 to 14k ft Ibs of torque on bottom, 10.5k ft Ibs off bottom. Drill with 5 to 10k weight on the bit. ECD's 10.55 ppg. PU wt 245k, SO wt 120k, Rot wt 183k pounds. Actual drilling time 4.37 hours. Note: 275 bbl whole mud dilution @ 15580'. 12:00 18:00 6.00 15,830 16,235 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 15830' to 16235' (7028' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 gpm w/ 2090. Rotate 120 rpm with 14 to 13k ft Ibs of torque on bottom, 11k ft lbs off bottom. Drill with 5 to 10k weight on the bit. ECD's 10.55 to 10.6 ppg. PU wt 248k, SO wt 120k, Rot wt 180k pounds. Actual drilling time 4.76 hours. Note: 275 bbl whole mud dilution @ 15850'. 18:00 00:00 6.00 16,235 16,551 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 16235' to 16551' (7038' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 gpm w/ 2090. Rotate 120 rpm with 14 to 15k ft Ibs of torque on bottom, 11 to 11.5k ft Ibs off bottom. Drill with 5 to 13k weight on the bit. ECD's 10.55 to 10.61 ppg. PU wt 253k, SO wt 110k, Rot wt 180k pounds. Actual drilling time 4.0 hours. Note: 275 bbl whole mud dilution while drilling @ 16426'. 04/20/2010 Continue to drill 6 -1/8" hole w/ Sperry Sun GeoPilot (TL 064) from 16551' to 17142' (7033' TVD). Note: Perfromed a 275 bbl whole mud dilution while drilling at 16850'. - CBU X3 - BROOH t/ 13,372' MD - Noted Parameter Change @ 13,600' MD Torque Momentarily Increased and Stand Pipe Pressrue Dropped 550 Psi - Inspected Pumps and Surface Equipment - Pressure Tested Surface Lines t/ 2500 Psi - Suspect Wash Out - OWFF (Static) - Attempt to POOH on TT but Hole Fill was Improper - Begin to Pump Out @ 1.5 BPM & 240 psi Page 25 of 30 Time Logs Date From To Dur S. Depth _E. Depth Phase Code Subcode T Comment 00:00 11:00 11.00 16,551 17,142 PROD1 DRILL DDRL P Drill 6 -1/8" hole from 16551' to 17,142' (7,033' TVD) with Sperry Sun GeoPilot (Serial number TL 064). Pumping 210 gpm w/ 2090 to 2130. Rotate 120 rpm with 15 to 14.5k ft Ibs of torque on bottom, 11.5 to 11.0k ft Ibs off bottom. Drill with 5 to 11k weight on the bit. ECD's 10.61 to 10.57 ppg. PU wt 255k, SO wt 110k, Rot wt 184k pounds. Actual drilling time 8.44 hours. Note: 275 bbl whole mud dilution while drilling @ 16850'. 11:00 15:00 4.00 17,142 16,808 PROD1 DRILL CIRC P CBU X3 While Standing Back 1 Stand Every Hour t/ 16,808' MD - 200 GPM @ 2070 Psi Rotating 100 RPM 15:00 15:15 0.25 16,808 16,808 PROD1 DRILL OWFF P OWFF (Slight Flow) 15:15 22:15 7.00 16,808 13,372 PROD1 DRILL REAM P BROOH f/ 16,808' - 13,372' MD - At 13,600' MD (Bit Depth) While Back Reaming @ 100 RPM w/ 200 GPM and 1600 Psi Lost 550 Psi, Torque Momentarily Increased f/ 10 to 15 and Lost 5K String Weight - Inspected Pumps and Surface Lines for Leaks - PT'd Lines t/ 2500 Psi (Good) - Suspect Wash Out 22:15 22:30 0.25 13,372 13,372 PROD1 DRILL OWFF P OWFF ( Slight Flow then Static) 22:30 23:45 1.25 13,372 12,991 PROD1 DRILL TRIP P POOH on TT t/ 12,991' MD (Improper Hole Fill) 23:45 00:00 0.25 12,991 12,991 PROD1 DRILL OWFF P OWFF (Static) 04/21/2010 POOH w/ Pumps t/ 10,990' MD - OWFF (Flowing) - CBU - OWFF (Flowing) - Displace t/ 9.2 PPG KCL Brine - OWFF (Flowing) - Increase Brine Weight t/ 9.4 PPG - OWFF (Static, Dropping) - POOH on TT; Noted Badly Worn Tool Joints Beginning at Stand #36 (22 Total) - Second Joint From the Top on Stand 8 Sheared at 3" Down on Box - Fish Left in Hole is BHA #5, 7 Stands + 2 Singles of 4' DP (Total Length 1148.87') - Estimated Top of Fish @ 12,450' MD - P/U Baker Fishing BHA and RIH t/ 185' MD 00:00 03:15 3.25 12,991 10,990 PROD1 DRILL TRIP P POOH w/ Pumps f/ 12,991' - 10,990' MD; 1.5 BPM @ 220 Psi 03:15 03:45 0.50 10,990 10,990 PROD1 DRILL OWFF P Blow Down the Top Drive and OWFF (Flowing) 03:45 06:30 2.75 10,990 10,990 PROD1 DRILL CIRC P CBU X1 While Treating Mud w/ Defoamer 06:30 08:15 1.75 10,990 10,990 PROD1 DRILL OWFF P Blow Down the Top Drive and OWFF (Flowing) - Rate Decreasing Continuously but Never Quit 08:15 10:15 2.00 10,990 10,990 PROD1 DRILL CIRC P Displace Well Bore to 9.2 PPG KCL Brine @ 4 BPM w/ 580 Psi 10:15 11:00 0.75 10,990 10,990 PROD1 DRILL OWFF P OWFF (Slight Flow) 11:00 13:00 2.00 10,990 10,990 PROD1 DRILL CIRC T Increase Brine Weight to 9.4 PPG while Circulating @ 4 BPM w/ 370 Psi 13:00 13:15 0.25 10,990 10,990 PROD1 DRILL OWFF T OWFF (Static - Dropping) Page 26 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase _ Code _ Subcode T Comment 13:15 19:00 5.75 10,990 0 PROD1 DRILL TRIP P POOH on TT - During Trip Noted 22 Jts of Badly Worn Tool Joints Beginning at Stand #36; Original TJ OD is 5" Drill Pipe Pulled from this Well Measured 4.375" to 4.22" - Some Joints Leaking at Connections - Second Joint on Stand 8 Sheared 3" Down f/ the Top of the Box - Fish Left in Hole 1148.87' Long (BHA #5, 7 Stands plus 2 Joints of 4" XT39 DP) - Estimated Top of Fish 12,450' MD 19:00 22:00 3.00 0 0 PROD1 DRILL PULD T P/U & Stand Back 7 Stands of 4" DP and 5 Stands of 4" HWDP while Waiting for the 4.25" Grapple 22:00 00:00 2.00 0 185 PROD1 DRILL TRIP T P/U Baker Fishing Tools as Follows: 5 3/4" Guide, 5 3/4" Bowl w/ 4 1/4" Grapple, Top Sub, Float Sub, Pump Out Sub, XO, 2 Jts HWDP, XO, Bumper Sub, Jars, XO and 1 Stand of 4" HWDP - RIH t/ 185' MD 04/22/2010 Continued to M/U Fishing BHA - RIH t/ 11,033' MD - Displace Well to 9.2 PPG Flo- Through while Slipping & Cutting Drill Line - RIH t/ 12,366' MD - CBU - Wash Down & Tag & Engage Fish @ 12,437' MD - POOH w/ Fish t/ 10,941' MD - Displace Well t/ 9.4 PPG KCL Brine - POOH w/ Fish t/ 1,702' MD 00:00 00:30 0.50 185 555 PROD1 DRILL PULD T P/U 4 Stands of HWDP (Remainder of Fishing BHA) t/ 555' MD 00:30 06:15 5.75 555 11,033 PROD1 DRILL TRIP T RIH w/ Fishing Assy to 11,033' MD (110 Stands) 06:15 08:15 2.00 11,033 11,033 PROD1 RIGMNT SLPC P Slip & Cut Drill Line While Displacing Wellbore f/ 9.4 PPG KCL Brine t/ 9.2 PPG Flo -Thru 08:15 09:00 0.75 11,033 12,366 PROD1 DRILL TRIP T RIH t/ 12,366' MD (14 Stands) - P/U 203, S/O 160 09:00 09:45 0.75 12,366 12,366 PROD1 DRILL CIRC T CBU @ 5.5 BPM w/ 980 Psi 09:45 10:30 0.75 12,437 13,585 PROD1 DRILL FISH T Wash Down and Tag Top of Fish @ 12,437' MD - Engage Fish & Work Loose - Circulate Through MWD Tools @ 5 BPM w/ 1670 Psi P/U 225, 5/0 145 1 10:30 14:30 4.00 13,585 10,941 PROD1 DRILL TRIP T POOH w/ Fish U 10,941' MD While Pumping 3 BPM @ 600 Psi - P/U 220 14:30 14:45 0.25 10,941 10,941 PROD1 DRILL OWFF T OWFF (Static) 14:45 16:45 2.00 10,941 10,941 PROD1 DRILL CIRC T Displace Wellbore f/ 9.2 PPG Flo -Thru to 9.4 PPG KCL Brine 16:45 00:00 7.25 10,941 1,702 PROD1 DRILL TRIP T POOH w/ Fish (BHA #5) t/ 1,702' MD (124 Stands) 04/23/2010 L/D Fishing BHA - UD Fish (BHA #5 + 23 Joints of 4" DP) - R/U and Run 3 1/2" Slotted /Blank Liner & Hang Off w/ Tail @ 17,140' MD - CBU - Increase Brine Weight t/ 9.6 Due to gas Observed at Surface 00:00 01:15 1.25 1,702 1,149 PROD1 DRILL PULD T L/D Fishing BHA t/ 1,149' MD Page 27 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 03:30 2.25 1,149 89 PROD1 DRILL PULD P UD 23 Joints of 4" XT39 DP, 4 Jts of HWDP, Bumper Sub, 1 Jt of HWDP, jars, XO, 3 NMFDC's, NMFS, Bat Sonic Tool and IBS t/ 89' MD - NOTE: 12 Joints of 4" DP and 2 NMFDC's Closest to the Bit Showed Signs of Excessive Wear on Tool Joints and Stand -Off Areas 03:30 04:30 1.00 89 89 PROD1 DRILL PULD P Plug In and Download MWD Data 04:30 06:00 1.50 89 0 PROD1 DRILL PULD P UD Remainder of BHA #5 06:00 06:45 0.75 0 0 PROD1 DRILL RURD P Clean /Clear Rig Floor- R/U to Run Liner 06:45 07:00 0.25 0 0 COMPZ CASING SFTY P PJSM on Running 3 1/2" SLHT Liner 07:00 12:00 5.00 0 6,308 COMPZ CASING PULD P P/U 3 1/2' Slotted /Blank Liner per Detail t/ 6308' MD (204 Joints) 12:00 13:15 1.25 6,308 6,318 COMPZ CASING PULD P P/U & M/U Liner Running Tools - Mix and Apply Pal -Mix; Allow to Cure 13:15 21:00 7.75 6,318 17,142 COMPZ CASING RUNL P RIH w/ 3 1/2" Liner on 4" DP t/ 17,142' MD (114 Stand 21:00 22:00 1.00 17,142 17,140 COMPZ CASING HOSO P P/U and Hang Liner w/ Tail @ 17,140' and Top @ 10,826' MD y Pump Setting Ball Down; On Seat © 898 Strokes - Increase Pressure to 3200 Psi and Set Down t/ 100K to Set Hanger - Increase Pressure t/ 4200 Psi to Shear ball Seat and Release Hanger Tools f/ Hanger - Stand Back 1 Stands to Pull Tools f/ Hanger 22:00 23:00 1.00 17,140 10,768 COMPZ CASING CIRC P CBU @ 5 BPM w/ 580 Psi - Gas Units Rose t/ 1150 & Gas Observed Breaking Out at Surface During Circulation - Gas Dropped to 0 Prior to Stopping Circulation 23:00 23:15 0.25 10,768 10,768 COMPZ CASING OWFF P OWFF (Static/Falling w/ Gas Continuously Breaking Out at Surface) 23:15 00:00 0.75 10,768 10,768 COMPZ CASING CIRC T Weight Up Brine t/ 9.6 PPG . 04/24/2010 Continue to Increase Brine Weight to 9.6 PPG - OWFF - POOH w/ Liner Running Tools - R/U and Run 3 1/2" Upper Completion per Detail t/ 10,850' MD 00:00 00:45 0.75 10,768 10,768 COMPZ CASING CIRC T Continue to Circulate While increasing Brine Weight to 9.6 PPG 00:45 01:15 0.50 10,768 10,768 COMPZ CASING OWFF T OWFF (Effervescing and Level Dropping in Annulus) 01:15 08:30 7.25 10,768 0 COMPZ CASING CIRC P Pump Dry Job and POOH on Elevators w/ Liner Running Tools t/ 08:30 10:00 1.50 0 0 COMPZ RPCOM PULD P Clear Rig Floor - Rig up to Run Completion String 10:00 10:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM on Running 3 1/2" EUE Completion String 10:15 19:00 8.75 0 8,697 COMPZ RPCOM RCST P RIH w/ XN Nipple, Packer, 3 GLM's and 271 Joints of 3 1/2" EUE Tubing t/ 8,697' MD Page 28 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:00 1.00 8,697 8,697 COMPZ RPCOM PULD P M/U SSSV - P/U Control Line, Spooler and Sheave - Connect Control Line to SSSV and Test t/ 6000 Psi 20:00 22:45 2.75 8,697 10,706 COMPZ RPCOM RCST P Continue of RIH w/ 3 1/2" EUE Completion String and Control Line per Detail t/ 10,706' MD (63 Jts) 22:45 23:15 0.50 10,706 10,850 COMPZ RPCOM HOSO P Space Out Completion w/ 4" DP - Fully Located Position has WLEG @ 10,850' MD - Calculate 4 1/2" IBT Pup Joints Needed to Space Out Completion - Space Out 2' Above Fully Located Position 23:15 00:00 0.75 10,850 10,850 COMPZ RPCOM OTHR P P/U Landing Joint B and Pull Wear Ring 04/25/2010 M/U Tubing Hanger and Terminate SSSV Control Line - Land Tubing w/ Tail @ 10,848' MD - Set TWC - N/D BOPE - N/U & Test Tree t/ 5,000 Psi f/ 10 Minutes - R/U and Displace Wellbore Fluids t/ 9.0 PPG Inhibited Brine and 6.8 PPG Diesel - Set Packer and Test Tubing t/ 4650 Psi f/ 30 Minutes - Test Tubing X Casing (IA) t/ 3500 Psi f/ 30 Minutes - Shear GLM Valve - Bleed Tubing Pressure t/ 750 Psi - Set BPV and Secure Well - R/U and UD 80 Stands of 4" DP (2400 hrs) SITP 850 Psi, IA 500 Psi, OA 75 Psi 00:00 01:45 1.75 10,850 10,848 COMPZ RPCOM RCST P M/U 4 1/2" IBT Tubing and Hanger - Terminate & Secure Control Line - Test Void t/ 5,000 Psi 01:45 02:30 0.75 10,848 10,848 COMPZ RPCOM HOSO P Land Hanger in Well Head and RILDS 02:30 03:00 0.50 10,848 10,848 COMPZ RPCOM PRTS P Install TWC - R/U and Test Hanger Seals t/ 5,000 Psi f/ 5 Minutes 03:00 03:15 0.25 10,848 10,848 COMPZ WHDBO SFTY P PJSM on N/D BOPE Stack 03:15 07:15 4.00 10,848 10,848 COMPZ WHDBO NUND P N/D BOPE Stack and N/U Tree, 07:15 07:30 0.25 10,848 10,848 COMPZ WHDBO PRTS P Test Tree to 5,000 Psi f/ 10 Minutes 07:30 08:30 1.00 10,848 10,848 COMPZ RPCOM RURD P Pull TWC - R/U Squeeze Manifold & Hard Lines 08:30 11:30 3.00 10,848 10,848 COMPZ RPCOM CIRC P Test Surface Lines t/ 3500 Psi - Displace Wellbore Fluids Above WLEG f/ 9.6 PPG KCL Brine w/ 236 Bbls of 9.0 PPG Inhibited KCL and 200 Bbls of 6.8 PPG Diesel 11:30 12:00 0.50 10,848 10,848 COMPZ RPCOM OTHR P Drop Ball & Rod 12:00 12:45 0.75 10,848 10,848 COMPZ RPCOM PACK P Test Surface Lines t/ 5,000 Psi - Set Packer w/ 4800 Psi 12:45 15:00 2.25 10,848 10,848 COMPZ RPCOM PRTS P Test Tubing t/ 4650 Psi f/ 30 Minutes - Bled Pressure Tubing Pressure t/ 2000 Psi - Tgst 3 1/2" by 7" Annulus t/ 3500 Psi f/ 30_Minutes - Blaad Tubing Pressure & Open DCK -2 Valve - Bleed Tubing Pressure t/ 750 Psi - Secure Well 15:00 15:30 0.50 10,848 10,848 COMPZ DRILL RURD P Flush and Blow Down Surface Lines - Rig Down hard Lines 15:30 16:00 0.50 10,848 0 COMPZ WHDBO MPSP P Set BPV in Profile - UD Lubricator NOTE: First BPV SeaL Failed and is in the Tubing; Second BPV Sealed and Held Pressure - Tubing Pressure 850 Psi, IA 500 Psi, OA 75 Psi • Page 29 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:15 0.25 0 0 COMPZ DRILL RURD P Install Mouse Hole - R/U to UD 4' DP 16:15 16:30 0.25 0 0 COMPZ DRILL SFTY P PJSM on UD 4' DP and Preparing Rig to Move 16:30 00:00 7.50 0 0 COMPZ DRILL PULD P UD 80 Stands of 4" DP 04/26/2010 Continue to UD 4" DP - Prep Rig for Move - Release Rig @ 1200 00:00 11:00 11.00 0 0 COMPZ RPCOM PULD P Continue to L/D 4" DP (91 Stands) 11:00 12:00 1.00 0 0 COMPZ MOVE RURD P Prep Rig for Move to CD1 -15 - Release Rig @ 1200 Page 30 of 30 • • , 1: . :.::. . : ,-,: ij :. .. .; Cono coPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3 -123 50103206170000 I 11 1 1 Sperry Drilling Services a Definitive Survey Report 29 April, 2010 1 I i : HALLIBURTON . =r _, Sperry Drilling Services II '3 • 0 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -123 Project Western North Slope TVD Reference: Rig: CD3 -123 (36.4 +12.6) @ 49.00ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig: CD3 -123 (36.4 +12.6) @ 49.00ft (Doyon 19) Well: CD3 - 123 North Reference: True Wellbore: CD3 - 123 Survey Calculation Method: Minimum Curvature Design: CD3 -123 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor I Well CD3 - 123 Well Position +NI -S 0.00 ft Northing: 6,003,775.23ft Latitude: 70° 25' 9.302 N! +E/ - 0.00 ft Easting: 387,935.21 ft Longitude: 150° 54' 46.554 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft Wellbore CD3 - 123 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) l°) (nT) BGGM2009 4/5/2010 21.23 80.78 57,630 Design CD3 - 123 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.40 Vertical Section: Depth From (TVD) +W-S +E/ -W Direction (ft) (ft) (ft) (°) 36.40 0.00 0.00 145.00 Survey Program Date From To (ft) (ft) Survey (Wel!bore) Tool Name Description Survey Date 81.00 911.00 CD3 -123 Gyro (CD3 -123) CB- GYRO -SS Camera based gyro single shot 4/2/2010 12: 950.50 2,795.76 CD3 -123 (R100) (CD3 -123) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 4/5/2010 12: 2,795.76 11,021.23 CD3 -123 (R200) (CD3 -123) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 4/6/2010 12: 11,115.06 17,075.68 CD3 -123 (R300) (CD3 -123) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 4/16/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +EI -W Northing Easting DLS Section (ft) (") ( °) (ft) (ft) (ft) (n) (ft) (it) ( °/100') (ft) Survey Tool Name 36.40 0.00 0.00 36.40 -12.60 0.00 0.00 6,003,775.23 387,935.21 0.00 0.00 UNDEFINED 81.00 0.62 244.77 81.00 32.00 -0.10 -0.22 6,003,775.13 387,934.99 1.39 -0.04 CB- GYRO -SS (1) 171.00 0.97 257.96 170.99 121.99 -0.47 -1.40 6,003,774.78 387,933.80 0.44 -0.42 CB- GYRO -SS (1) 263.00 1.22 255.12 262.97 213.97 -0.88 -3.11 6,003,774.40 387,932.08 0.28 -1.06 CB- GYRO -SS (1) 355.00 1.68 276.93 354.94 305.94 -0.97 -5.40 6,003,774.34 387,929.80 0.77 -2.30 CB- GYRO -SS (1) 448.00 2,20 279.43 447.89 398.89 -0.52 -8.51 6,003,774.84 387,926.69 0.57 -4.46 CB- GYRO -SS (1) 539.00 3.02 293.05 538.80 489.80 0.71 -12.44 6,003,776.13 387,922.78 1.12 -7.72 CB- GYRO -SS (1) 631.00 4.30 302.95 630.61 581.61 3.53 -17.56 6,003,779.03 387,917.70 1.55 -12.97 CB- GYRO -SS (1) 664.00 5.41 305.00 663.49 614.49 5.10 -19.88 6,003,780.63 387,915.41 3.40 -15.58 CB- GYRO -SS (1) 694.00 6.26 308.52 693.33 644.33 6.93 -22.32 6,003,782.49 387,913.00 3.07 -18.48 CB- GYRO -SS (1) 724.00 6.58 316.29 723.15 674.15 9.19 -24.78 6,003,784.79 387,910.57 3.08 -21.74 CB- GYRO -SS (1) 4/29/2010 2:10:52PM Page 2 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -123 Project Western North Slope TVD Reference: Rig: CD3 -123 (36.4 +12.6) @ 49.00ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig: CD3 -123 (36.4 +12.6) @ 49.00ft (Doyon 19) Well: CD3 - 123 North Reference: True Wellbore: CD3 - 123 Survey Calculation Method: Minimum Curvature Design: CD3 - 123 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 817.00 7.99 322.80 815.39 766.39 18.19 -32.37 6,003,793.91 387,903.11 1.75 -33.47 CB- GYRO -SS (1) 911.00 10.43 315.27 908.18 859.18 29.44 -42.31 6,003,805.30 387,893.35 2.89 -48.39 CB- GYRO -SS (1) 950.50 11.65 315.78 946.95 897.95 34.84 -47.61 6,003,810.78 387,888.13 3.10 -55.85 MWD +IFR -AK- CAZ -SC (2) 1,045.46 13.17 316.26 1,039.69 990.69 49.53 -61.78 6,003,825.68 387,874.19 1.60 -76.01 MWD +IFR -AK- CAZ -SC (2) 1,140.30 14.09 310.01 1,131.86 1,082.86 64.76 -78.09 6,003,841.15 387,858.10 1.83 -97.84 MWD +IFR -AK- CAZ -SC (2) 1,235.77 16.89 308.52 1,223.85 1,174.85 80.87 -97.85 6,003,857.55 387,838.60 2.96 - 122.37 MWD +IFR -AK- CAZ -SC (2) 1,330.73 20.35 302.75 1,313.84 1,264.84 98.40 - 122.54 6,003,875.45 387,814.17 4.12 - 150.89 MWD +IFR -AK- CAZ -SC (2) 1,425.41 23.68 297.65 1,401.61 1,352.61 116.14 - 153.23 6,003,893.64 387,783.75 4.05 - 183.02 MWD +IFR -AK- CAZ -SC (2) 1,521.05 25.55 292.67 1,488.56 1,439.56 133.00 - 189.29 6,003,911.05 387,747.96 2.92 - 217.52 MWD +IFR -AK- CAZ -SC (2) 1,615.51 27.94 293.06 1,572.91 1,523.91 149.52 - 228.45 6,003,928.15 387,709.05 2.54 - 253.51 MWD +IFR -AK- CAZ -SC (2) 1,709.82 30.39 291.27 1,655.26 1,606.26 166.83 - 271.02 6,003,946.10 387,666.75 2.76 - 292.11 MWD +IFR -AK- CAZ -SC (2) 1,805.55 34.46 287.11 1,736.06 1,687.06 183.59 - 319.49 6,003,963.59 387,618.54 4.85 - 333.64 MWD +IFR -AK- CAZ -SC (2) 1,900.85 35.41 286.54 1,814.18 1,765.18 199.39 - 371.73 6,003,980.16 387,566.55 1.05 - 376.54 MWD +IFR -AK- CAZ -SC (2) 1,995.66 36.18 286.49 1,891.09 1,842.09 215.15 - 424.89 6,003,996.72 387,513.63 0.81 - 419.95 MWD +IFR -AK- CAZ -SC (2) 2,091.15 38.66 286.25 1,966.92 1,917.92 231.50 - 480.56 6,004,013.90 387,458.22 2.60 - 465.27 MWD +IFR -AK- CAZ -SC (2) 2,186.12 42.79 286.36 2,038.88 1,989.88 248.89 - 540.02 6,004,032.18 387,399.03 4.35 - 513.62 MWD +IFR -AK- CAZ -SC (2) 2,281.01 44.19 286.51 2,107.72 2,058.72 267.37 - 602.65 6,004,051.60 387,336.69 1.48 - 564.69 MWD +IFR -AK- CAZ -SC (2) 2,375.78 47.42 286.30 2,173.77 2,124.77 286.56 - 667.83 6,004,071.75 387,271.82 3.41 - 617.78 MWD +IFR -AK- CAZ -SC (2) 2,470.82 50.68 285.98 2,236.05 2,187.05 306.50 - 736.77 6,004,092.73 387,203.18 3.44 - 673.67 MWD +IFR -AK- CAZ -SC (2) 2,566.68 51.19 286.13 2,296.46 2,247.46 327.09 - 808.30 6,004,114.39 387,131.98 0.55 - 731.55 MWD +IFR -AK- CAZ -SC (2) 2,661.84 51.76 286.53 2,355.73 2,306.73 348.02 - 879.74 6,004,136.39 387,060.87 0.68 - 789.68 MWD +IFR -AK- CAZ -SC (2) 2,757.61 51.22 286.49 2,415.37 2,366.37 369.32 - 951.59 6,004,158.76 386,989.35 0.56 - 848.34 MWD +IFR -AK- CAZ -SC (2) 2,795.76 51.53 286.34 2,439.18 2,390.18 377.74 - 980.18 6,004,167.61 386,960.89 0.87 - 871.63 MWD +IFR -AK- CAZ -SC (2) 2,848.49 52.50 287.72 2,471.63 2,422.63 389.91 - 1,019.91 6,004,180.38 386,921.35 2.76 - 904.40 MWD +IFR -AK- CAZ -SC (3) 2,898.56 52.37 287.15 2,502.16 2,453.16 401.80 - 1,057.78 6,004,192.83 386,883.67 0.94 - 935.86 MWD +IFR -AK- CAZ -SC (3) 2,993.18 52.39 288.04 2,559.92 2,510.92 424.46 - 1,129.22 6,004,216.56 386,812.59 0.75 - 995.39 MWD +IFR -AK- CAZ -SC (3) 3,086.75 51.99 287.23 2,617.28 2,568.28 446.86 - 1,199.67 6,004,240.01 386,742.49 0.81 - 1,054.14 MWD +IFR -AK- CAZ -SC (3) 3,182.27 51.72 285.25 2,676.28 2,627.28 467.87 - 1,271.78 6,004,262.09 386,670.70 1.65 - 1,112.72 MWD +IFR -AK- CAZ -SC (3) 3,278.33 51.39 285.78 2,736.01 2,687.01 487.99 - 1,344.28 6,004,283.30 386,598.52 0.55 - 1,170.78 MWD +IFR -AK- CAZ -SC (3) 3,372.03 52.17 285.58 2,793.98 2,744.98 507.88 - 1,415.15 6,004,304.26 386,527.96 0.85 - 1,227.73 MWD +IFR -AK- CAZ -SC (3) 3,467.91 52.22 285.02 2,852.75 2,803.75 527.87 - 1,488.22 6,004,325.34 386,455.21 0.46 - 1,286.02 MWD +IFR -AK- CAZ -SC (3) 3,560.31 52.48 284.15 2,909.19 2,860.19 546.29 - 1,559.02 6,004,344.82 386,384.70 0.80 - 1,341.72 MWD +IFR -AK- CAZ -SC (3) 3,656.87 51.78 283.35 2,968.47 2,919.47 564.41 - 1,633.06 6,004,364.05 386,310.94 0.98 - 1,399.03 MWD +IFR -AK- CAZ -SC (3) 3,752.60 51.94 281.39 3,027.59 2,978.59 580.54 - 1,706.60 6,004,381.27 386,237.66 1.62 - 1,454.42 MWD +IFR -AK- CAZ -SC (3) 3,848.48 51.91 283.14 3,086.73 3,037.73 596.57 - 1,780.35 6,004,398.41 386,164.17 1.44 - 1,509.85 MWD +IFR -AK- CAZ -SC (3) 3,941.25 51.79 284.14 3,144.03 3,095.03 613.78 - 1,851.24 6,004,416.67 386,093.55 0.86 - 1,564.61 MWD +IFR -AK- CAZ -SC (3) 4,038.33 52.42 284.59 3,203.66 3,154.66 632.78 - 1,925.46 6,004,436.79 386,019.63 0.74 - 1,622.74 MWD +IFR -AK- CAZ -SC (3) 4,129.24 52.07 283.94 3,259.32 3,210.32 650.50 - 1,995.12 6,004,455.55 385,950.25 0.68 - 1,677.21 MWD +IFR -AK- CAZ -SC (3) 4,228.56 52.29 284.12 3,320.23 3,271.23 669.52 - 2,071.23 6,004,475.71 385,874.44 0.26 - 1,736.45 MWD +IFR -AK- CAZ -SC (3) 4,317.92 52.06 284.88 3,375.03 3,326.03 687.19 - 2,139.57 6,004,494.40 385,806.38 0.72 - 1,790.12 MWD +IFR -AK- CAZ -SC (3) 4/29/2010 2:10:52PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -123 Project Western North Slope TVD Reference: Rig: CD3 -123 (36.4 +12.6) @ 49.00ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig: CD3 -123 (36.4 +12.6) © 49.00ft (Doyon 19) Well: CD3 - 123 North Reference: True Wellbore: CD3 - 123 Survey Calculation Method: Minimum Curvature Design: CD3 - 123 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 4,418.79 51.21 283.87 3,437.63 3,388.63 706.83 - 2,216.18 6,004,515.18 385,730.08 1.15 - 1,850.15 MWD +IFR -AK- CAZ -SC (3) 4,511.88 51.77 286.40 3,495.60 3,446.60 725.85 - 2,286.48 6,004,535.26 385,660.08 2.21 - 1,906.05 MWD +IFR -AK- CAZ -SC (3) 4,608.62 52.18 286.19 3,555.19 3,506.19 747.23 - 2,359.63 6,004,557.73 385,587.27 0.46 - 1,965.52 MWD +IFR -AK- CAZ -SC (3) 4,703.95 52.14 287.02 3,613.68 3,564.68 768.74 - 2,431.77 6,004,580.33 385,515.46 0.69 - 2,024.52 MWD +IFR -AK- CAZ -SC (3) 4,798.52 52.46 286.96 3,671.51 3,622.51 790.61 - 2,503.33 6,004,603.26 385,444.24 0.34 - 2,083.48 MWD +IFR -AK- CAZ -SC (3) 4,893.90 52.37 286.97 3,729.68 3,680.68 812.66 - 2,575.62 6,004,626.40 385,372.29 0.09 - 2,143.01 MWD +IFR -AK- CAZ -SC (3) 4,988.80 51.77 286.89 3,788.02 3,739.02 834.46 - 2,647.23 6,004,649.26 385,301.03 0.64 - 2,201.94 MWD +IFR -AK- CAZ -SC (3) 5,083.98 51.04 285.30 3,847.39 3,798.39 855.09 - 2,718.70 6,004,670.96 385,229.88 1.51 - 2,259.83 MWD +IFR -AK- CAZ -SC (3) 5,178.80 51.51 285.49 3,906.71 3,857.71 874.73 - 2,790.02 6,004,691.66 385,158.87 0.52 - 2,316.82 MWD +IFR -AK- CAZ -SC (3) 5,272.49 52.95 285.88 3,964.10 3,915.10 894.75 - 2,861.32 6,004,712.75 385,087.89 1.57 - 2,374.12 MWD +IFR -AK- CAZ -SC (3) 5,369.08 52.99 284.62 4,022.27 3,973.27 915.03 - 2,935.71 6,004,734.15 385,013.81 1.04 - 2,433.41 MWD +IFR -AK- CAZ -SC (3) 5,462.83 53.65 283.96 4,078.27 4,029.27 933.59 - 3,008.57 6,004,753.79 384,941.25 0.90 - 2,490.40 MWD +IFR -AK- CAZ -SC (3) 5,558.56 52.53 283.16 4,135.76 4,086.76 951.54 - 3,082.98 6,004,772.86 384,867.12 1.35 - 2,547.78 MWD +IFR -AK- CAZ -SC (3) 5,655.77 50.79 282.69 4,196.06 4,147.06 968.59 - 3,157.29 6,004,791.03 384,793.09 1.83 - 2,604.37 MWD +IFR -AK- CAZ -SC (3) 5,750.52 50.67 282.59 4,256.03 4,207.03 984.65 - 3,228.86 6,004,808.15 384,721.77 0.15 - 2,658.58 MWD +IFR -AK- CAZ -SC (3) 5,844.18 51.14 283.64 4,315.10 4,266.10 1,001.14 - 3,299.66 6,004,825.71 384,651.24 1.00 - 2,712.69 MWD +IFR -AK- CAZ -SC (3) 5,940.56 51.76 284.87 4,375.16 4,326.16 1,019.70 - 3,372.71 6,004,845.36 384,578.48 1.19 - 2,769.80 MWD +IFR -AK- CAZ -SC (3) 6,033.36 52.47 285.02 4,432.15 4,383.15 1,038.59 -3,443.47 6,004,865.31 384,508.01 0.78 - 2,825.86 MWD+IFR-AK-CAZ-SC (3) 6,129.91 52.31 284.19 4,491.07 4,442.07 1,057.88 - 3,517.48 6,004,885.70 384,434.30 0.70 - 2,884.11 MWD +IFR -AK- CAZ -SC (3) 6,224.54 52.31 283.98 4,548.93 4,499.93 1,076.10 - 3,590.11 6,004,905.01 384,361.96 0.18 - 2,940.70 MWD +IFR -AK- CAZ -SC (3) 6,316.88 51.45 282.65 4,605.93 4,556.93 1,092.84 - 3,660.80 6,004,922.80 384,291.54 1.47 - 2,994.95 MWD +IFR -AK- CAZ -SC (3) 6,415.07 51.77 281.54 4,666.91 4,617.91 1,108.96 - 3,736.05 6,004,940.05 384,216.54 0.94 - 3,051.32 MWD +IFR -AK- CAZ -SC (3) 6,508.80 52.22 279.62 4,724.62 4,675.62 1,122.52 - 3,808.65 6,004,954.70 384,144.17 1.68 - 3,104.06 MWD +IFR -AK- CAZ -SC (3) 6,603.38 52.00 279.63 4,782.71 4,733.71 1,135.00 - 3,882.24 6,004,968.28 384,070.78 0.23 - 3,156.50 MWD +IFR -AK- CAZ -SC (3) 6,698.58 52.14 279.68 4,841.23 4,792.23 1,147.59 - 3,956.27 6,004,981.98 383,996.95 0.15 - 3,209.27 MWD +IFR -AK- CAZ -SC (3) 6,795.43 51.71 279.02 4,900.96 4,851.96 1,159.98 - 4,031.49 6,004,995.50 383,921.93 0.70 - 3,262.57 MWD +IFR -AK- CAZ -SC (3) 6,888.78 51.85 279.01 4,958.71 4,909.71 1,171.47 - 4,103.93 6,005,008.07 383,849.68 0.15 - 3,313.53 MWD +IFR -AK- CAZ -SC (3) 6,985.05 52.48 277.17 5,017.76 4,968.76 1,182.16 - 4,179.20 6,005,019.89 383,774.59 1.65 - 3,365.46 MWD +IFR -AK- CAZ -SC (3) 7,081.79 52.69 275.31 5,076.55 5,027.55 1,190.51 - 4,255.57 6,005,029.39 383,698.35 1.54 - 3,416.11 MWD +IFR -AK- CAZ -SC (3) 7,175.47 53.02 275.28 5,133.11 5,084.11 1,197.40 - 4,329.93 6,005,037.39 383,624.12 0.35 - 3,464.40 MWD +IFR -AK- CAZ -SC (3) 7,270.55 52.84 273.69 5,190.43 5,141.43 1,203.34 - 4,405.55 6,005,044.46 383,548.59 1.35 - 3,512.64 MWD +IFR -AK- CAZ -SC (3) 7,365.75 54.29 269.87 5,246.98 5,197.98 1,205.69 - 4,482.08 6,005,047.96 383,472.11 3.57 - 3,558.46 MWD +IFR -AK- CAZ -SC (3) 7,459.78 54.16 268.53 5,301.95 5,252.95 1,204.63 - 4,558.36 6,005,048.05 383,395.83 1.16 - 3,601.34 MWD +IFR -AK- CAZ -SC (3) 7,555.64 54.55 265.40 5,357.82 5,308.82 1,200.50 - 4,636.13 6,005,045.08 383,318.01 2.68 - 3,642.57 MWD +IFR -AK- CAZ -SC (3) 7,651.14 54.59 262.22 5,413.20 5,364.20 1,192.11 - 4,713.48 6,005,037.86 383,240.56 2.71 - 3,680.06 MWD +IFR -AK- CAZ -SC (3) 7,746.34 53.55 258.31 5,469.07 5,420.07 1,179.10 - 4,789.43 6,005,025.99 383,164.42 3.50 - 3,712.97 MWD +IFR -AK- CAZ -SC (3) 7,841.20 52.65 253.84 5,526.05 5,477.05 1,160.87 - 4,863.03 6,005,008.87 383,090.57 3.89 - 3,740.25 MWD +IFR -AK- CAZ -SC (3) 7,936.08 52.55 251.30 5,583.68 5,534.68 1,138.29 - 4,934.94 6,004,987.38 383,018.34 2.13 - 3,763.00 MWD +IFR -AK- CAZ -SC (3) 8,025.80 50.90 249.19 5,639.26 5,590.26 1,114.50 - 5,001.22 6,004,964.59 382,951.71 2.61 - 3,781.53 MWD +IFR -AK- CAZ -SC (3) 8,123.71 49.79 246.23 5,701.75 5,652.75 1,085.93 - 5,070.96 6,004,937.07 382,881.55 2.59 - 3,798.13 MWD +IFR -AK- CAZ -SC (3) 4/29/2010 2:10:52PM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -123 Project Western North Slope TVD Reference: Rig: CD3 -123 (36.4 +12.6) © 49.00ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig: CD3 -123 (36.4 +12.6) © 49.00ft (Doyon 19) Well: CD3 - 123 North Reference: True Wellbore: CD3 - 123 Survey Calculation Method: Minimum Curvature Design: CD3 - 123 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) mow) (ft) Survey Tool Name 8,220.92 49.85 243.97 5,764.47 5,715.47 1,054.67 - 5,138.32 6,004,906.82 382,813.74 1.78 - 3,811.15 MWD +IFR -AK- CAZ -SC (3) 8,315.52 51.68 242.47 5,824.31 5,775.31 1,021.64 - 5,203.72 6,004,874.78 382,747.85 2.29 - 3,821.61 MWD +IFR -AK- CAZ -SC (3) 8,404.11 51.63 238.16 5,879.28 5,830.28 987.25 - 5,264.06 6,004,841.30 382,687.01 3.82 - 3,828.05 MWD +IFR -AK- CAZ -SC (3) 8,506.85 51.39 234.05 5,943.24 5,894.24 942.42 - 5,330.79 6,004,797.49 382,619.63 3.14 - 3,829.60 MWD +IFR -AK- CAZ -SC (3) 8,600.21 52.10 228.43 6,001.08 5,952.08 896.55 - 5,387.90 6,004,752.48 382,561.83 4.79 - 3,824.78 MWD +IFR -AK- CAZ -SC (3) 8,695.73 53.70 223.73 6,058.71 6,009.71 843.70 - 5,442.73 6,004,700.47 382,506.23 4.27 - 3,812.94 MWD +IFR -AK- CAZ -SC (3) 8,791.03 53.84 219.33 6,115.06 6,066.06 786.18 - 5,493.67 6,004,643.72 382,454.43 3.73 - 3,795.04 MWD +IFR -AK- CAZ -SC (3) 8,887.68 54.33 214.40 6,171.77 6,122.77 723.58 - 5,540.60 6,004,581.84 382,406.57 4.16 - 3,770.68 MWD +IFR -AK- CAZ -SC (3) 8,981.86 53.48 210.42 6,227.27 6,178.27 659.36 - 5,581.39 6,004,518.24 382,364.83 3.53 - 3,741.47 MWD +IFR -AK- CAZ -SC (3) 9,076.66 54.43 204.25 6,283.09 6,234.09 591.31 - 5,616.53 6,004,450.74 382,328.67 5.36 - 3,705.89 MWD +IFR -AK- CAZ -SC (3) 9,170.75 55.13 201.00 6,337.36 6,288.36 520.38 - 5,646.09 6,004,380.26 382,298.05 2.92 - 3,664.73 MWD +IFR -AK- CAZ -SC (3) 9,266.46 56.62 198.45 6,391.06 6,342.06 445.80 - 5,672.81 6,004,306.10 382,270.22 2.70 - 3,618.97 MWD +IFR -AK- CAZ -SC (3) 9,362.45 58.60 194.51 6,442.49 6,393.49 368.10 - 5,695.76 6,004,228.75 382,246.10 4.03 - 3,568.48 MWD +IFR -AK- CAZ -SC (3) 9,457.70 59.02 192.38 6,491.82 6,442.82 288.85 - 5,714.71 6,004,149.81 382,225.97 1.96 - 3,514.43 MWD +IFR -AK- CAZ -SC (3) 9,551.95 61.01 191.47 6,538.92 6,489.92 208.98 - 5,731.57 6,004,070.21 382,207.92 2.27 - 3,458.68 MWD +IFR -AK- CAZ -SC (3) 9,648.24 62.69 190.98 6,584.35 6,535.35 125.71 - 5,748.09 6,003,987.20 382,190.15 1.80 - 3,399.94 MWD +IFR -AK- CAZ -SC (3) 9,740.08 64.76 189.59 6,625.00 6,576.00 44.69 - 5,762.78 6,003,906.41 382,174.24 2.63 - 3,342.00 MWD +IFR -AK- CAZ -SC (3) 9,837.95 66.58 188.91 6,665.33 6,616.33 -43.33 - 5,777.11 6,003,818.63 382,158.59 1.96 - 3,278.12 MWD +IFR -AK- CAZ -SC (3) 9,928.07 68.58 187.08 6,699.70 6,650.70 - 125.82 - 5,788.69 6,003,736.33 382,145.78 2.91 - 3,217.19 MWD +IFR -AK- CAZ -SC (3) 10,028.45 70.11 184.72 6,735.11 6,686.11 - 219.24 - 5,798.33 6,003,643.07 382,134.73 2.68 - 3,146.20 MWD +IFR -AK- CAZ -SC (3) 10,119.11 71.28 182.41 6,765.08 6,716.08 - 304.63 - 5,803.65 6,003,557.78 382,128.14 2.73 - 3,079.30 MWD +IFR -AK- CAZ -SC (3) 10,218.96 73.09 180.90 6,795.63 6,746.63 - 399.64 - 5,806.39 6,003,462.83 382,123.98 2.31 - 3,003.04 MWD +IFR -AK- CAZ -SC (3) 10,314.19 73.87 177.83 6,822.72 6,773.72 - 490.92 - 5,805.37 6,003,371.55 382,123.62 3.20 - 2,927.68 MWD +IFR -AK- CAZ -SC (3) 10,408.74 74.70 176.38 6,848.33 6,799.33 - 581.82 - 5,800.77 6,003,280.60 382,126.86 1.72 - 2,850.59 MWD +IFR -AK- CAZ -SC (3) 10,500.88 76.79 176.13 6,871.01 6,822.01 - 670.92 - 5,794.94 6,003,191.43 382,131.35 2.28 - 2,774.25 MWD +IFR -AK- CAZ -SC (3) 10,599.03 78.81 173.84 6,891.76 6,842.76 - 766.48 - 5,786.54 6,003,095.77 382,138.31 3.07 - 2,691.16 MWD +IFR -AK- CAZ -SC (3) 10,687.07 80.00 171.13 6,907.95 6,858.95 - 852.26 - 5,775.22 6,003,009.83 382,148.34 3.31 - 2,614.40 MWD +IFR -AK- CAZ -SC (3) 10,788.27 82.69 167.76 6,923.18 6,874.18 - 950.59 - 5,756.89 6,002,911.24 382,165.19 4.23 - 2,523.34 MWD +IFR -AK- CAZ -SC (3) 10,878.85 83.37 164.27 6,934.17 6,885.17 - 1,037.82 - 5,735.16 6,002,823.70 382,185.60 3.90 - 2,439.42 MWD +IFR -AK- CAZ -SC (3) 10,978.97 83.37 161.10 6,945.74 6,896.74 - 1,132.75 - 5,705.57 6,002,728.35 382,213.77 3.15 - 2,344.68 MWD +IFR -AK- CAZ -SC (3) 11,021.23 84.43 160.08 6,950.23 6,901.23 - 1,172.39 - 5,691.61 6,002,688.51 382,227.13 3.47 - 2,304.21 MWD +IFR -AK- CAZ -SC (3) 11,115.06 86.28 154.47 6,957.83 6,908.83 - 1,258.61 - 5,655.49 6,002,601.77 382,261.95 6.28 - 2,212.86 MWD +IFR -AK- CAZ -SC (4) 11,211.30 86.46 147.18 6,963.93 6,914.93 - 1,342.41 - 5,608.70 6,002,517.28 382,307.47 7.56 - 2,117.38 MWD +IFR -AK- CAZ -SC (4) 11,306.43 86.09 142.22 6,970.12 6,921.12 - 1,419.86 - 5,553.86 6,002,439.02 382,361.14 5.22 - 2,022.48 MWD +IFR -AK- CAZ -SC (4) 11,355.46 87.26 142.25 6,972.96 6,923.96 - 1,458.56 - 5,523.88 6,002,399.88 382,390.53 2.39 - 1,973.59 MWD +IFR -AK- CAZ -SC (4) 11,399.86 88.38 142.55 6,974.65 6,925.65 - 1,493.71 - 5,496.81 6,002,364.33 382,417.06 2.61 - 1,929.27 MWD +IFR -AK- CAZ -SC (4) 11,497.95 90.85 144.90 6,975.31 6,926.31 - 1,572.77 - 5,438.79 6,002,284.41 382,473.89 3.48 - 1,831.22 MWD +IFR -AK- CAZ -SC (4) 11,547.01 91.34 146.94 6,974.37 6,925.37 - 1,613.40 - 5,411.30 6,002,243.38 382,500.76 4.28 - 1,782.18 MWD +IFR -AK- CAZ -SC (4) 11,588.26 90.66 147.32 6,973.65 6,924.65 - 1,648.04 - 5,388.92 6,002,208.41 382,522.62 1.89 - 1,740.96 MWD +IFR -AK- CAZ -SC (4) 11,688.24 90.48 146.97 6,972.66 6,923.66 - 1,732.02 - 5,334.68 6,002,123.63 382,575.59 0.39 - 1,641.06 MWD +IFR -AK- CAZ -SC (4) 4/29/2010 2:10:52PM Page 5 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -123 Project Western North Slope TVD Reference: Rig: CD3 -123 (36.4 +12.6) @ 49.00ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig: CD3 -123 (36.4 +12.6) @ 49.00ft (Doyon 19) Well: CD3 - 123 North Reference: True Wel lbore: CD3 - 123 Survey Calculation Method: Minimum Curvature Design: CD3 - 123 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) (`) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,783.12 90.60 147.82 6,971.76 6,922.76 - 1,811.94 - 5,283.56 6,002,042.96 382,625.50 0.90 - 1,546.27 MWD +IFR -AK- CAZ -SC (4) 11,879.07 90.85 148.19 6,970.55 6,921.55 - 1,893.31 - 5,232.72 6,001,960.84 382,675.10 0.47 - 1,450.46 MWD +IFR -AK- CAZ -SC (4) 11,966.24 91.28 148.28 6,968.93 6,919.93 - 1,967.41 - 5,186.84 6,001,886.07 382,719.86 0.50 - 1,363.44 MWD +IFR -AK- CAZ -SC (4) 12,068.14 90.60 147.27 6,967.26 6,918.26 - 2,053.60 - 5,132.51 6,001,799.08 382,772.89 1.19 - 1,261.68 MWD +IFR -AK- CAZ -SC (4) 12,162.26 90.36 148.50 6,966.47 6,917.47 - 2,133.32 - 5,082.48 6,001,718.63 382,821.71 1.33 - 1,167.68 MWD +IFR -AK- CAZ -SC (4) 12,254.93 87.89 146.06 6,967.88 6,918.88 - 2,211.26 - 5,032.40 6,001,639.95 382,870.61 3.75 - 1,075.11 MWD +IFR -AK- CAZ -SC (4) 12,353.92 87.82 145.93 6,971.59 6,922.59 - 2,293.27 - 4,977.08 6,001,557.13 382,924.69 0.15 - 976.20 MWD +IFR -AK- CAZ -SC (4) 12,449.60 88.56 141.76 6,974.61 6,925.61 - 2,370.46 - 4,920.67 6,001,479.10 382,979.93 4.42 - 880.61 MWD +IFR -AK- CAZ -SC (4) 12,544.90 88.38 140.04 6,977.16 6,928.16 - 2,444.39 - 4,860.59 6,001,404.29 383,038.89 1.81 - 785.59 MWD +IFR -AK- CAZ -SC (4) 12,639.99 88.63 144.58 6,979.64 6,930.64 - 2,519.59 - 4,802.49 6,001,328.23 383,095.85 4.78 - 690.67 MWD +IFR -AK- CAZ -SC (4) 12,735.86 87.57 146.37 6,982.82 6,933.82 - 2,598.53 - 4,748.19 6,001,248.49 383,148.96 2.17 - 594.86 MWD +IFR -AK- CAZ -SC (4) 12,831.42 88.13 145.75 6,986.40 6,937.40 - 2,677.75 - 4,694.87 6,001,168.48 383,201.07 0.87 - 499.38 MWD +IFR -AK- CAZ -SC (4) 12,922.94 89.18 147.74 6,988.55 6,939.55 - 2,754.26 - 4,644.70 6,001,091.24 383,250.08 2.46 - 407.93 MWD +IFR -AK- CAZ -SC (4) 13,012.77 89.61 149.39 6,989.50 6,940.50 - 2,830.90 - 4,597.86 6,001,013.91 383,295.77 1.90 - 318.29 MWD +IFR -AK- CAZ -SC (4) 13,114.35 90.11 149.63 6,989.75 6,940.75 - 2,918.43 - 4,546.32 6,000,925.62 383,345.98 0.55 - 217.02 MWD +IFR -AK- CAZ -SC (4) 13,212.21 89.68 147.68 6,989.93 6,940.93 - 3,002.00 - 4,495.42 6,000,841.30 383,395.62 2.04 - 119.37 MWD +IFR -AK- CAZ -SC (4) 13,307.49 90.05 144.83 6,990.15 6,941.15 - 3,081.22 - 4,442.49 6,000,761.31 383,447.35 3.02 -24.12 MWD +IFR -AK- CAZ -SC (4) 13,400.91 89.74 145.24 6,990.32 6,941.32 - 3,157.78 - 4,388.96 6,000,683.96 383,499.72 0.55 69.30 MWD +IFR -AK- CAZ -SC (4) 13,496.64 89.37 148.41 6,991.07 6,942.07 - 3,237.89 - 4,336.58 6,000,603.08 383,550.88 3.33 164.97 MWD +IFR -AK- CAZ -SC (4) 13,593.94 89.12 149.44 6,992.35 6,943.35 - 3,321.22 - 4,286.36 6,000,519.01 383,599.84 1.09 262.03 MWD +IFR -AK- CAZ -SC (4) 13,689.47 89.24 145.75 6,993.72 6,944.72 - 3,401.85 - 4,235.18 6,000,437.63 383,649.80 3.86 357.43 MWD +IFR -AK- CAZ -SC (4) 13,785.23 88.50 144.90 6,995.60 6,946.60 - 3,480.59 - 4,180.72 6,000,358.09 383,703.08 1.18 453.17 MWD +IFR -AK- CAZ -SC (4) 13,880.98 88.87 145.93 6,997.80 6,948.80 - 3,559.40 - 4,126.38 6,000,278.48 383,756.22 1.14 548.89 MWD +IFR -AK- CAZ -SC (4) 13,976.13 86.65 146.18 7,001.52 6,952.52 - 3,638.27 - 4,073.29 6,000,198.83 383,808.11 2.35 643.95 MWD +IFR -AK- CAZ -SC (4) 14,067.19 86.22 145.51 7,007.18 6,958.18 - 3,713.47 - 4,022.27 6,000,122.87 383,858.00 0.87 734.82 MWD +IFR -AK- CAZ -SC (4) 14,165.53 87.20 146.44 7,012.83 6,963.83 - 3,794.84 - 3,967.33 6,000,040.70 383,911.70 1.37 832.98 MWD +IFR -AK- CAZ -SC (4) 14,259.47 87.33 145.29 7,017.31 6,968.31 - 3,872.51 - 3,914.68 5,999,962.26 383,963.18 1.23 926.80 MWD +IFR -AK- CAZ -SC (4) 14,356.93 87.70 145.18 7,021.54 6,972.54 - 3,952.49 - 3,859.16 5,999,881.45 384,017.48 0.40 1,024.17 MWD +IFR -AK- CAZ -SC (4) 14,448.78 88.81 144.70 7,024.33 6,975.33 - 4,027.64 - 3,806.42 5,999,805.53 384,069.08 1.32 1,115.98 MWD +IFR -AK- CAZ -SC (4) 14,547.63 89.30 143.64 7,025.96 6,976.96 - 4,107.77 - 3,748.57 5,999,724.54 384,125.72 1.18 1,214.80 MWD +IFR -AK- CAZ -SC (4) 14,643.20 90.11 143.63 7,026.45 6,977.45 - 4,184.73 - 3,691.90 5,999,646.75 384,181.22 0.85 1,310.34 MWD +IFR -AK- CAZ -SC (4) 14,738.12 90.36 143.48 7,026.07 6,977.07 - 4,261.09 - 3,635.52 5,999,569.56 384,236.45 0.31 1,405.23 MWD +IFR -AK- CAZ -SC (4) 14,825.76 90.11 145.36 7,025.71 6,976.71 - 4,332.36 - 3,584.53 5,999,497.54 384,286.36 2.16 1,492.86 MWD +IFR -AK- CAZ -SC (4) 14,927.05 90.05 143.99 7,025.56 6,976.56 - 4,415.00 - 3,525.96 5,999,414.04 384,343.68 1.35 1,594.15 MWD +IFR -AK- CAZ -SC (4) 15,024.61 89.49 143.81 7,025.96 6,976.96 - 4,493.83 - 3,468.48 5,999,334.36 384,399.96 0.60 1,691.69 MWD +IFR -AK- CAZ -SC (4) 15,118.95 89.74 142.81 7,026.59 6,977.59 - 4,569.47 - 3,412.11 5,999,257.89 384,455.18 1.09 1,785.98 MWD +IFR -AK- CAZ -SC (4) 15,215.13 90.11 143.37 7,026.72 6,977.72 - 4,646.37 - 3,354.35 5,999,180.13 384,511.78 0.70 1,882.11 MWD +IFR -AK- CAZ -SC (4) 15,309.14 89.43 143.73 7,027.09 6,978.09 - 4,721.99 - 3,298.50 5,999,103.69 384,566.48 0.82 1,976.09 MWD +IFR -AK- CAZ -SC (4) 15,405.90 90.17 146.83 7,027.43 6,978.43 - 4,801.51 - 3,243.40 5,999,023.36 384,620.38 3.29 2,072.83 MWD +IFR -AK- CAZ -SC (4) 15,498.16 89.68 147.65 7,027.55 6,978.55 - 4,879.10 - 3,193.47 5,998,945.04 384,669.13 1.04 2,165.02 MWD +IFR -AK- CAZ -SC (4) 4/29/2010 2:10:52PM Page 6 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -123 Project Western North Slope TVD Reference: Rig: CD3 -123 (36.4 +12.6) © 49.00ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig: CD3 -123 (36.4 +12.6) @ 49.00ft (Doyon 19) Well: CD3 - 123 North Reference: True Wel!bore: CD3 - 123 Survey Calculation Method: Minimum Curvature Design: CD3 - 123 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!S +El -W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 15,597.12 90.05 147.56 7,027.79 6,978.79 - 4,962.66 - 3,140.46 5,998,860.70 384,720.88 0.38 2,263.88 MWD +IFR -AK- CAZ -SC (4) 15,689.51 90.54 147.30 7,027.31 6,978.31 - 5,040.52 - 3,090.72 5,998,782.11 384,769.44 0.60 2,356.18 MWD +IFR -AK- CAZ -SC (4) 15,781.03 90.60 145.44 7,026.40 6,977.40 - 5,116.71 - 3,040.04 5,998,705.17 384,818.97 2.03 2,447.67 MWD +IFR -AK- CAZ -SC (4) 15,880.77 91.16 143.70 7,024.87 6,975.87 - 5,197.97 - 2,982.23 5,998,623.06 384,875.55 1.83 2,547.39 MWD +IFR -AK- CAZ -SC (4) 15,975.37 89.12 143.73 7,024.64 6,975.64 - 5,274.22 - 2,926.25 5,998,545.98 384,930.37 2.16 2,641.96 MWD +IFR -AK- CAZ -SC (4) 16,070.85 88.81 143.79 7,026.36 6,977.36 - 5,351.22 - 2,869.81 5,998,468.15 384,985.64 0.33 2,737.40 MWD +IFR -AK- CAZ -SC (4) 16,169.03 89.49 144.83 7,027.82 6,978.82 - 5,430.95 - 2,812.54 5,998,387.58 385,041.70 1.27 2,835.56 MWD +IFR -AK- CAZ -SC (4) 16,262.48 88.44 148.29 7,029.51 6,980.51 - 5,508.90 - 2,761.06 5,998,308.87 385,092.00 3.87 2,928.95 MWD +IFR -AK- CAZ -SC (4) 16,359.69 87.08 149.62 7,033.31 6,984.31 - 5,592.12 - 2,710.97 5,998,224.92 385,140.84 1.96 3,025.85 MWD +IFR -AK- CAZ -SC (4) 16,451.19 88.38 149.60 7,036.93 6,987.93 - 5,670.98 - 2,664.72 5,998,145.37 385,185.89 1.42 3,116.98 MWD +IFR -AK- CAZ -SC (4) 16,551.09 87.39 146.80 7,040.62 6,991.62 - 5,755.82 - 2,612.12 5,998,059.76 385,237.21 2.97 3,216.64 MWD +IFR -AK- CAZ -SC (4) 16,646.05 88.81 143.94 7,043.77 6,994.77 - 5,833.90 - 2,558.19 5,997,980.88 385,289.96 3.36 3,311.54 MWD +IFR -AK- CAZ -SC (4) 16,742.62 89.24 144.06 7,045.41 6,996.41 - 5,912.02 - 2,501.43 5,997,901.93 385,345.53 0.46 3,408.08 MWD +IFR -AK- CAZ -SC (4) 16,837.20 89.98 143.30 7,046.05 6,997.05 - 5,988.22 - 2,445.42 5,997,824.91 385,400.39 1.12 3,502.63 MWD +IFR -AK- CAZ -SC (4) 16,933.54 92.45 143.22 7,044.01 6,995.01 - 6,065.40 - 2,387.81 5,997,746.88 385,456.83 2.57 3,598.90 MWD +IFR -AK- CAZ -SC (4) 17,028.87 92.89 143.31 7,039.57 6,990.57 - 6,141.72 - 2,330.85 5,997,669.72 385,512.63 0.47 3,694.08 MWD +IFR -AK- CAZ -SC (4) 17,075.68 93.08 143.74 7,037.13 6,988.13 - 6,179.31 - 2,303.06 5,997,631.72 385,539.85 1.00 3,740.81 MWD +IFR -AK- CAZ -SC (4) 17,142.00 93.08 143.74 7,033.57 6,984.57 - 6,232.71 - 2,263.89 5,997,577.75 385,578.21 0.00 3,807.02 PROJECTED to TD 4/29/2010 2:10:52PM Page 7 COMPASS 2003.16 Build 69 • • • pTi 210 1 2ECBANICAL T,NTEGRI R�•...3'ORT - pit.Z — C'_ ..� . � /v oPER E FIELD C � - SPUD ir. • • �or .1 Z � Z 3. tom°. rL P.S:. • ., r.(Z 5— 20b° WELL NUMBER CD 3 - ,Z (� .._._, eLL DATA STD : /7/V1--.) 703Y IND.; ?ETD: (7 70 3 4 1 TAT'D Sc,4 Casing: c i r • Shoe: S SJ / HD Z / z'TVD; DV: lam- ....intl.- 71( Sboe: // `IS TOP: ® MD ( ry 1r ubing: .D. P acker 17gs ' G n) 6 YJ TVD; Set at . . Hole S �. I Z " and ; Perfs • to .� . 5 4.oTEo L-rxie,L r 0 PLG -I 1 7/ '/cc AA 0 . ' CRAY ICAL IITTRGRITY - PART # 1 ,. / gl nnuius Press Test: IP 35 d D t 15 mitt ______- ; BO min . Comments : ` 4 o(c o1, f MECHANICAL INTEGRITY - # 2. ,-7.i..: k--. 1,,-(- - Cement Volumes s Amt. Cs 6 c l g DV Cmr vol ® cover Peret __-___ ,m Theoretical 'HOC _ e 97' 4 , - 5's, . 5a7.5_,. C ....... a r 2-0. '-'- o ' `,-tb 1 C Bond Log ("les or No) r /e/CcTn AOGCC File • Ve-i" • CBL Evaluation, zone above perfs giS l.' S ryo ..0 wdo-� Cal g C- (IO`I t ` T - n-a-=- '30v Production Log: Type /1 z Evaluation CONCLUSIONS: . • err j 1 : ,-fn255.1e.e M (1 _ C.4 . A. • r F D 2_10- 037_ fl'N �h Cement Detail Report a y, isi el s , r CD3 -123 t er j ConocoPhillips j/ String: Surface Casing Cement Job: DRILLING ORIGINAL, 4/1/2010 06 :00 Cement Details . - - ... ` _ . _:, , y s Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 4/5/2010 01:00 4/5/2010 03:45 CD3 -123 Comment 42 bbls Returned to Surface Cement Stages - - ., A Stag# e: ' _ ' _ -- Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Primary 36.0 2,834.0 Yes 42.0 Yes Yes Q (start) (bbl /min) 'Q (end) (bbl /min) Q (avg) (bbllmin) P (final) (psi) P (bump) (pal) ' Recap? 'Stroke (ft) Rotated? Pipe RPM (rpm) 8 4 8 500.0 1,100.0 Yes 15.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (In) Drill Bit 8 3/4 Comment Cement - Fluids & Additives ?"•tea '-'14 Fluid; Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class a Volume Pumped (bbl) 51 Lead Cement 36.0 2,343.0 400 .—G- A 321.0 Yield (fP /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (1b/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.52 21.23 10.70 7.00 Additives Additive 'Type Concentration 'Cone Unit label Fluid. Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbi) Tail Cement 2,843.0 2,343.0 236 G 50.0 Density (1b/ gal) Plastic Viscosity (cp) Thickening Time (hrs) Cm Free Water { P Yield fNlsack Mix H2O Ratio atlsa.. (%) ( g ) tY { P) 9 CmprStr 1 (psi) { 1 fg t) ny 1.16 5.10 15.80 4.50 Additives Additive Type Concentration Conc Unit label • Page 1/1 Report Printed: 7/30/2010 ` • • nom, ' £ Cement Detail Report , + &wells , itt: _ CD3 -123 ConocoPhiilips String: Cement Intermediate Job: DRILLING ORIGINAL, 4/112010 06:00 Cement Details t . f.,- - Description Cementing Start Date Cementing End Date WellboreName Cement Intermediate 4/12/2010 04 :38 4/12/2010 09:15 CD3 - 123 Comment Circ & cond mud & hole for cmt job. Stage pumps up f/ 3.5 bpm w/ 380 psi to 6 bpm w/ 450 psi. Con't pumping 6 bpm w/ 450 to 480 psi. Recip 7" csg 30' stroke f/ 11041' to 11011'. PU wt 295k, SO wt 175k. Flow check well, slight flow. Air in the mud. Increase MW from 10.0 ppg to 10.2 ppg precautionary. Pumping 6 bpm w/ 470 to 530 psi. Dowell pump 2 bbl CW 100, PT lines to 3500 psi. Pump another 38 bbls of CW100 (40 bbls total) @ 4 bpm w/ 350 to 380 psi. Mix & pump 35 bbls 11.5 ppg mud push @ 4 bpm w/ 330 final pressure, shut down. Load Halliburton bottom plug, kick out plug w/ 5 bbls more MudPush f/ a total of 40 bbls. Load Halliburton top plug. Dowell pump 64.2 bbls 15.8 ppg (310 sx) (1.16 cuft/sx) (5.08 gal/sx water) (5.34 hr thickening time). Drop Halliburton top shut off plug. Kick plug out with 20 bbls water, pumping 6 bpm w/ 118 to 72 psi. Rig displ cmt w/ 10.2 ppg mud, pumping 6 bpm w/ initial 120 psi, final 630 psi. Stayed on hanger (10 bbls before and 10 bbls after) when CW100, MudPush II and cmt came around shoe, then con't recip. Recip'd 30' stroke until slowing displacement to 3 bpm w/ 420 psi initial & 430 psi final for last 5.4 bbis prior to bumping plug w/ 930 psi @ 0652 hrs 4/12/2010. Held press f/ 5 minutes, then bleed off & checked floats -OK. Load Halliburton 2nd stage closing plug in the cement head. Note: Final PU wt 280k, Final SO wt 170k. Open Halliburton stage tool @ 5950' with 3330 psi applied. Circ & cond mud f/ cementing through the Halliburton stage tool @ 5950'. Pumping 5 bpm w/ 210 psi. Dowell pump 30 bbl CW 100 @ 4 bpm w/ 208 to 257 psi. Mix and pump 30 bbls 11.5 ppg mud push @ 5.2 bpm w/ 275 psi final , shut down. Dowell mix, then pump 41 bbls 15.8 ppg (198 sx) (1.16 cuft/sx) (5.11 gallsx water) (5.34 hr thickening time). Drop Halliburton closing plug. Kick plug out w/ 20 bbls water through the tub, rig displ 5 bpm w/ final 300 psi, slow to 3 bpm last 7.3 bbl, bump plug & tool shut w/ 1460 psi, press to 1930 psi, hold 5 minutes. Cement Stages... Stage # 1 ,, - _ .e = . ` - 10. ,, Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Cement Intermediate 9,360.4 11,053.0 Yes Yes Yes Q (start) (bbl /min) Q (end) (bbUmin) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 3 5 430.0 930.0 Yes 30.00 No Depth tagged (ft(B) Tag Method Depth Plug Drilled Out To (ftKB) (Drill Out Diameter (in) Comment II Ciro & cond mud & hole for cmt job. Stage pumps up f/ 3.5 bpm w/ 380 psi to 6 bpm w/ 450 psi. Con't pumping 6 bpm w/ 450 to 480 psi. Recip 7" csg 30' stroke f/ 11041' to 11011'. PU wt 295k, SO wt 175k. Flow check well, slight flow. Air in the mud. increase MW from 10.0 ppg to 10.2 ppg precautionary. 1 Pumping 6 bpm w/ 470 to 530 psi. Dowell pump 2 bbl CW 100, PT lines to 3500 psi. Pump another 38 bbls of CW100 (40 bbls total) @ 4 bpm w/ 350 to 380 psi. Mix & pump 35 bbls 11.5 ppg mud push @ 4 bpm w/ 330 final pressure, shut down. Load Halliburton bottom plug, kick out plug w/ 5 bbls more MudPush f/ a total of 40 bbls. Load Halliburton top plug. Dowell pump 64.2 bbls 15.8 ppg (310 sx) (1.16 cuft/sx) (5.08 gallsx water) (5.34 hr thickening time). Drop Halliburton top shut off plug. Kick plug out with 20 bbls water, pumping 6 bpm w/ 118 to 72 psi. Rig displ cmt w/ 10.2 ppg mud, pumping 6 bpm w/ initial 120 psi, final 630 psi. Stayed on hanger (10 bbls before and 10 bbls after) when CW100, MudPush II and cmt came around shoe, then con't recip. Recip'd 30' stroke until slowing displacement to 3 bpm w/ 420 psi initial & 430 psi final for last 5.4 bbls prior to bumping plug w/ 930 psi @ 0652 hrs 4/12/2010. Held press f/ 5 minutes, then bleed off & checked floats -OK. Load Halliburton 2nd stage closing plug in the cement head. Note: Final PU wt 280k, Final SO wt 170k. Open Halliburton stage tool @ 5950' with 3330 psi applied. Circ & cond mud f/ cementing through the Halliburton stage tool @ 5950'. Pumping 5 bpm w/ 210 psi. Cement Fluids & Additives. = _ _ Fluid Fluid Type Fluid Description Estimated Top (ftKB) - Est Btm (ftKB) Amount (sacks) , Class Volume Pumped (bbl) CW 100 7,226.0 8,293.2 40.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening lime (hrs) CmprStr 1 (psi) 8.35 Additives Additive Type Concentration Conc Unit label Fluid . _ Fluid Type Fluid Descriptio Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 8,293.2 9,360:4 40.0 Yield (fN /sack) Mix H2O Ratio (gallsa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) - Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid . .. ~ . Fluid Type Fluid Description Estimated Top (ftKB) Eat Btm (ftKB) Amount (sacks) Class Volume Pumped (bbi) Alpine Tail cement 9,360.4 11,053.0 310 G 64.2 Yield (ft'lsack) Mix H2O Ratio (gaUsa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr i (psi) 1.16 5.08 15.80 5.34 Page 1/2 Report Printed: 7/30/2010 • I ortn IOW Cement Detail Report x CD3 -123 CanocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 4/1/2010 06:00 Cement Details _ ': . . Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 4/13/2010 10:09 4/13/2010 10:29 CD3 -123 Comment Filled annulus of 16" (1.031" wall thickness) x 9.625" casing with water from tag of 32' below landing ring, taking returns in the cellar from landing ring.. Took 3 bbls to fill, using centrifugal pump. Mix and pump 6 bbls of ASI cement @ 15.7 ppg (.93 cuft/sx) (3.553 gal /sx water) (1:47 thickening time), using centrifugal pump. Pumped all the cement allowing returns to cellar, sucking cellar w/ vac truck. Pulled out the 3/4" hose from between the conductor and surface pipe. Then sucked the cement down to 20" (1.67') below the top of landing ring. Cement Stages ,Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement top fill conductor w/ 37.8 68.1 No No No cement from 32'. , Q (start) (bbl /min) 0 (end) (bbilmin) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 1 1 1 92.0 - No No 'Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Filled annulus of 16" (1.031" wall thickness) x 9.825" casing with water from tag of 32' below landing ring, taking returns in the cellar from landing ring.. Took 3 bbls to fill, using centrifugal pump. Mix and pump 6 bbls of ASI cement @ 15.7 ppg (.93 cuft/sx) (3.553 gal /sx water) (1:47 thickening time), using centrifugal pump. Pumped all the cement allowing returns to cellar, sucking cellar w/ vac truck. Pulled out the 314" hose from between the conductor and surface pipe. Then sucked the cement down to 20" (1.67') below the top of landing ring. Cement. Fluids. &Additives " - Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Water 3.0 Yield (fN /sack) Mix H2O Ratio (gailsa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.34 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Arctic Set I 37.8 68.1 37 G 6.0 Yield (ft'/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.93 3.55 15.70 1.73 Additives Additive Type Concentration Conc Unit label D013 %BWOC Additive Type Concentration Conc Unit label D044 0.05 %BWOC Additive Type Concentration Conc Unit label D053 0.57 %BWOC Additive Type Concentration Conc Unit label D065 %BWOC Additive Type Concentration Conc Unit label D097 0.38 %BWOC Page 1/1 Report Printed: 7/30/2010 • f WELL LOG TRANSMITTAL To: State of Alaska April 30, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Logs: CD3 -123 AK- MW- 0007104613 CD3 -123 2" x 5" MD Gamma Ray/Resistivity Logs: 1 Color Log 50- 103 - 20617 -00 2" x 5" TVD Gamma Ray/Resistivity Logs: 1 Color Log 50 -103- 20617 -00 Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom 50- 103 - 20617 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3536 Fax: 907 - 273 -3535 or 0 --63 Bryan.Burinda @halliburton.com ` / / /.[)� -4 _Y '7'3 s a r l to • V iJ Date: Signed: Aziaka - Al Sonic Page 1 of 2 Anderson, Nina M From: Schwartz, Guy L (DOA) [guy.schwartz @alaska.gov] Sent: Thursday, April 15, 2010 9:57 AM To: Anderson, Nina M r S ubject: FW: BAT Sonic Nina, ,.- p� List is below of what is not here. For injectors we need both hard copy and digital. _ r� Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Mahnken, Christine R (DOA) Sent: Thursday, April 15, 2010 8:21 AM To: Schwartz, Guy L (DOA) Subject: RE: BAT Sonic CD2 -•21 No BAT ' a6� -f9� ll,l CD3 -124 BAT is there OT C !9 6// CD4 -24 BAT is there USC 9/0 °a CD2 -78 BAT is there . CD2 -73 N6 BAT t 0/0 - 031 j � It is on RBDMS under Logs or Data List to look for what we have and what I have put into it. From: Schwartz, Guy L (DOA) Sent: Wednesday, April 14, 2010 10:38 AM To: Mahnken, Christine R (DOA) Subject: FW: BAT Sonic Christine, Is this something that is easy to check ? ?? I would still like hard copies... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Anderson, Nina M jmailto: Nina .Anderson @conocophillips.com) Sent: Wednesday, April 14, 2010 10:30 AM To: Schwartz, Guy L (DOA) Subject: FW: BAT Sonic Guy - Can you please verify your records and see if you have hard copies of the BAT sonic data from the following injectors? If the data from any of these wells still needs to be updated, would you prefer just a log or also a CD? Thanks. Page 1 of 1 Schwartz, Guy L (DOA) From: Robertson, Ryan G [ Ryan .G.Robertson @conocophillips.com] Sent: Monday, April 12, 2010 4:38 PM To: Schwartz, Guy L (DOA) 2to - 0 31 Subject: RE: CD3 -123 Top Job (PT�) 11 o 3 ( Guy, The surface pipe had a slight lateral movement to it. Ryan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, April 12, 2010 4:35 PM To: Robertson, Ryan G 21c' - 0 31 Subject: RE: CD3 -123 Top Job (PTD49 -e31} Ryan, What do you mean by the " casing moving " .... Do you mean the cement level moved or the actual pipe ?? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Robertson, Ryan G [mailto: Ryan. G.Robertson @conocophillips.com] Sent: Monday, April 12, 2010 4:03 PM To: Schwartz, Guy L (DOA) Subject: CD3 -123 Top Job Guy, As per our discussion regarding the CD3 -123 well we are currently drilling: The surface cement job went according to plan, with full returns throughout. After bumping the plug, the surface casing / conductor annulus was monitored for 45 minutes, with the cement dropping roughly 7 ft during that time. While drilling the last part of the 8 -3/4" intermediate hole, it was noticed that the surface casing was moving very slightly. Further investigation showed that the surface cement had dropped to roughly 30 ft. Currentty we are handling drillpipe after successfully running and performing a two stage cement job on the 7" intermediate casing. We intend to perform a top job on the surface casing / conductor annulus later on this evening if the cementer's schedule permits. I will ensure the rig supervisors notify the State inspectors on the Slope of our intentions to perform a top job. Ryan Drilling Engineer ConocoPbiiiips Alaska i Direct: (907) 265-63181 Mobile. (907 980 -5107 4/12/2010 • • SINCE IF ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Colville River Field, Fiord Oil Pool, CD3 -123 ConocoPhillips Alaska, Inc. Permit No: 210 -031 Surface Location: 4003' FNL, 1108' FEL, Sec. 5, T12N, R5E, UM Bottomhole Location: 4909' FNL, 3424' FEL, Sec. 8, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ji day of March, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) ConocoPhillips Alaska, Inc. • • NV Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 March 12 2010 RECEI\/EIJ Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 MAR 6 Anchorage, Alaska 99501 2010 X8018 Gas Cons. Commission Re: Application for Permit to Drill CD3 -123 Anchorage Dear Sir or Madam: // //�, i l i x 1 5 .r y .(O ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD3 pad. The intended spud date for this well is April 4 2010. It is intended that D°oyon Rig 19 be used to drill the well. CD3 -123 will penetrate the reservoir horizontally. After setting the 7" intermediate casing, the horizontal section will be drilled and the well completed as a Nechelik injector. 'Once completed, the well will be flowed back to mitigate reservoir damage and then hooked up to begin pre - production. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement through the intermediate casing shoe and then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. This will be the 6 winter season of drilling on the CD3 pad, and to date there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10 -401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program with request for approval of annular pumping operations. • 3. A proposed completion diagram. 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Nina Anderson at 265 -6403 or Chip Alvord at 265 -6120. Sincerely, iE Nina derson Drilling Engineer 1 • • Attachments: cc: CD3 -122 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Ryan Robertson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation III RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 6 2010 PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anshorage la. Type of Work: 1 b. Proposed Well Class: Development - Oil ❑ Service - Winj ❑ Single Zone 0 • lc. Specify if well is proposed for: Drill 0 • Re -drill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG zi * Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket ❑ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 . CD3 - 123 . 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 17092' . TVD: 7074' • Colville River Field 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): 4003' FNL, 1108' FEL, Sec. 5, T12N, R5E, UM ADL 37210524' .. Fiord Oil Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 5011' FNL, 1584' FEL, Sec. 6, T12N, R5E, UM LAS2112 4/4/2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4909' FNL, 3424' FEL, Sec. 8, T12N, R5E, UM 2560 • +/ 4.0 miles north to ADL 391451 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: • 49.1 feet 15. Distance to Nearest Well Open Surface: x - 387935.1 • y - 6003775.2 Zone 4 GL Elevation above MSL: 4r1 eet to Same Pool: CD3 -114 , 10852 i /E' 16. Deviated wells: Kickoff depth: 370 • ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25 035) Maximum Hole Angle: 88 - 9" d Downhole: 3200 psig • Surface: 2493 psig • 18. Casing Procram: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5 H -40 Welded 77 37 37 114 114 Pre Installed 12.25" 9.625" 40 L -80 BTC -M 2815 37 37 2852 ' 2470 • 465 sx AS Lite 3, 230 sx 15.8 'G' 8.75" 7" 26 L -80 BTC-M 10814 37 37 10851 ' 6936 • 1st - 278 sx 15.8 'G' 2nd - 188 sx 15.8 G 3.5" 9.3 L -80 EUE 10676 32 32 10708 6,915 Tubing 6.125" 4.5" ,.zaec" ..yr' X 32-• 17092 7074 Blanks and Slotted Liner 6391 Io7olt 4 9 /Y 19 PRESENT WELL CONDITION SUMMARY y2.I.d 3•/$•/o (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis El Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: y� 22. I hereby certify that the foregoing is true and correct. Contact Nina Anderson 265 - 6403 K ` Printed Name Chip Alvord Title Alaska Drilling Manager ` C /1 _ Phone 265 -6120 Date 3 (( Signature ' (2 0( 0 / Commission Use Only Permit to Drill API Number: Permit App v al See cover letter 1 Number: _ /C'�'3 / t! ' 50- /63 "` 2 l Date: 3 ` a I -0 for other requirements Conditions of approval : If box is ecked, well may not be used to explore for, test, or produce coalbed m in ane, gas hydrates, or gas contained in shales: 2 -!F 3500 /0 se. F� Ie-s i Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No Cs Other: *Z5Q0 e' A., . 746,.425 measures: Yes ❑ No III Directional svy req'd: Yes g No Diva, r (..)Q-<oe,, ZO AAC, Z5 o35C 4 )(Z)) fr1IT+€ � ui Q 4 L 7 tfiK.a,t'C o 2.r, , Le. 4C czrJ 41f Arc 3a APPROVED BY THE COMMISSION 3/ / 0 DATE. - .f ,COMMISSIONER SW Form 10 - 401 (Revised 7/2009) This permit is valid for 2 f t - • • • rf . . 0 AAC 25.005(g)) .� sl ubmit in Duplicate 1,4-- .!d jib - .- -7 /%. 3 t s .. ., • CD3 -123 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12 -1/4" Hole / 9 -5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Employ gyro single shots and traveling cylinder diagrams Gas Hydrates Low Monitor well at base of permafrost, increase mud weight, decreased mud viscosity, increase • circulating times, control drilling rates and low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, increase mud weight if needed and use weighted sweeps. Abnormal Pressure in Low Increase mud weight to 9.6 — 9.8 pp Surface Formations • >2000' TVD Lost Circulation Low Reduced pump rates, thin mud rheology, pump LCM pills and use of low density cement slurries 8 -3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills. Mud weight above 9.6 ppg. Flow Surface Formations checks during connections. Mud weight increase if • >2000' TVD needed. Lost circulation Low Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties. Ensure proper hole fill. Pump out of hole if needed. Monitor real time equivalent circulating density (ECD). Use of weighted sweeps. Abnormal Reservoir Low Well control drills. Increase mud weight. No mapped Pressure faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H drills. Detection systems and alarms. Use • standard well control practices. Employ mud scavengers. 6 -1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates and trip speeds. Real time equivalent circulating density (ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density (ECD). Use weighted sweeps. Abnormal Reservoir Medium BOPE drills. Keep mud weight above 9.1 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Perform well control drills. Increase mud weight if needed. Hydrogen Sulfide gas Low H drills. Detection systems and alarms. Use • standard well control practices. Employ mud scavengers. OR!GINAL • • Rict Procedure 1. Move rig onto CD3 -123. 2. Rig up riser. - p va w - ;rer ctiU " i./r/ 3. Drill 12 -1/4" hole to surface casing point as per the directional plan (Directional /MWD) ' 4. Run and cement 9 -5/8" surface casing. 5. Install BOPE and test to 3,500 psi high and 250 psi low. 6. Pressure test casing to 2,500 psi. 7. Drill out 20' of new hole and perform leak off test. 8. Pick up and run in the hole with 8 -3/4" drilling BHA. 9. Drill 8 -3/4" hole to intermediate casing point into the Nechelik reservoir sand (GR/RES /PWD).• 10. Run and cement 7" casing as per drilling program. Perform a leak off test down the 9 -5/8" x 7" annulus to , confirm the fracture pressure referenced to the surface casing shoe. If needed, a second stage cement job will ✓ be pumped to isolate the K2 (Qannik) formation. 11. Freeze protect the casing annulus to surface. 12. Perform BOPE test to 3,500 psi high and 250 psi low. 13. Pick up and run 6 -1/8" drilling BHA. 14. Pressure test 7" intermediate casing to 3,500 psi. 15. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. Run BAT sonic log across reservoir and top of cement for cement evaluation. 16. Displace well to Flo -Thru mud system. 17. Drill 6 -1/8" horizontal section to well TD (LWD Program: GR/RES/PWD) • 18. Circulate hole clean and pull out of hole. 19. Run upper completion: 3 -1/2 ", 9.3 ppf, L -80 tubing with TRMAXX SSSV, 3 GLM, Premier Packer, and XN nipple. l e w ". 20. Install two way check valve and pressure test hanger seals to 5,000 psi. It. 21. Nipple down BOP. 3/e{, 22. Install tubing head adapter assembly. fti 23. Pressure test adapter assembly to 5,000 psi. 24. Remove two way check valve. 25. Circulate tubing to diesel and install freeze protection in the annulus. 26. Install BPV and secure well. 27. Move rig off CD3 -123. ORIGINAL . • WELL PROXIMITY RISKS Directional drilling and collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3 -122 is the nearest existing well to the CD3 -123 plan. Ellipse to ellipse separation is 6.46' at 599' MD. DRILLING AREA RISKS There are no high risk events anticipated. No over pressured zones are expected. • Faulting within the Nechelik reservoir is considered to be the most likely cause of lost circulation. Standard LCM • material is expected to be effective in dealing with any drilling fluid losses to the drilled formations. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. ANNULAR PUMPING OPERATIONS: Incidental fluids developed from drilling operations on well CD3 -123 will be injected into a permitted annulus on the CD3 pad, or the class 1 disposal well on CD1 pad. The CD3 -123 surface /intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. Significant hydrocarbon zones include the Nechelik reservoir, and potentially the Qannik and Kuparuk reservoir. There will be 500' of cement fill placed above the top of the Kuparuk reservoir, along with 500' of cement above and below the Qannik reservoir as per regulations. Once CD3 -123 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 would then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones 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. Surface casing will be set near the base of the Schrader Bluff Formation (C -40). These 450 -500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surface Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,470') + 1,500 psi = 3,041 psi Pore Pressure = 1,117 psi Therefore Differential = 3,041 psi —1,117 psi = 1924 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9 -5/8" 40 L -80 3 BTC 3,090 psi 2,626 psi 5,750 psi 4,888 psi 7" 26 L -80 3 BTC -Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 1 Ofl \!GINAL • • DRILLING FLUID PROGRAM SPUD to 9 -5/8" Intermediate hole to 7" Production Hole surface casing point casing point — 8 3/4" Section — 6 1/8" — 12 1/4" Density 8.7 — 9.8 ppg 9.6 — 9.8 ppg 9.1 — 9.2 ppg • PV 10 — 16 7 —12 YP 30 -60 13 -16 10 -15 Funnel Viscosity 70 — 300 Initial Gels 8 —10 6 - 9 10 minute gels <20 8 - 12 API Filtrate NC —10 cc / 30 min 5 — 12 cc /30 min (drilling) HPHT Fluid Loss at 165 10 cc /30 min PH 8.5 -9.0 9.0 -10.0 9.0 -9.5 KCL 3 % Surface Hole: A standard high viscosity fresh water gel spud mud is planned for the surface interval. Flow line viscosity will be kept at ± 300 sec /qt while drilling gravels. Viscosity prior to cementing will be reduced to ± 80 -100 sec /qt. Mud weight will be maintained at < 9.8 ppg by use of solids control system and dilution where necessary. Using cold make up water will help keep the flow line temperature as low as possible. Intermediate Hole Section: A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists, particularly after the Nechelik reservoir is penetrated. Mud weight will be maintained at or below 9.8 ppg to minimize losses, and lost circulation material will be introduced to the system if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be beneficial in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a MI Swaco's Flo -Thru drill -in fluid. The base fluid will consist of 3% KCI, with calcium carbonate bridging material to minimize formation damage. Flowzan Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. ECD's will be monitored with real time PWD data, and controlled by maintaining fluid rheology and pump rates within specifications. 1NAL 1.3 • • Fiord (CD3) Colville River Field CD3 -123 Pre - produced Injector , Updated 03/12/10 A , 16" Conductor to 114' Sperry Drilling Services CD3- 123wp03 mou 3 -1/2" Camco TRMAXX SSSV at 2000' TVD or 2300' MD I! Q meooi®r 9 -5/8" 40 ppf L -80 BTC -Mod Surface Casing AM kli 2852' MD / 2470' TVD cemented to surface 0 > ,:GLJ J TOC @ +/ - Upper Completion Top MD TVD 4903' MD / 3733' TVD IIIIIII 1) Tubing Hanger 32' 32' Qannik Interval 2) 4 -W 12.6 # /ft IBT -Mod Tubing (2 jts), XO Top +/- 5403' MD / 4041' TVD 3) 3 -'/=" 9.3 #/ft EUE -Mod Tubing ES Cementer ( 4) Camco TRMAXX -5E SSSV (2.812" ID) 2133' 2000' 0l' with control line to surface +/ - 5936' MD / - 5) 3-W 9.3 #/ft EUE -Mod Tubing 4367' TVD 6) Camco KBMG GLM (2.867" ID) w /DCK2 shear 4362' 3400' Pinned for 2500 psi casing to tbg shear 7) 3 -' /z' 9.3 #/ft EUE -Mod Tubing 8) Camco KBMG GLM w/ DV 7963' 5600' 3 1/2" 9.3 ppf L -80 EUE M 9 ) 3 -' /z' 9.3 #/ft EUE -Mod Tubing 10) Camco KBMG GLM w/ DV 9600' 6560' tubing run with Jet Lube Run'n'Seal 11) 3-W 9.3#/ft, EUE -M (2) 8 GL: J pipe dope 12) Baker 3.5" X 7" Premier Packer 9700' 6606' 13) 3 -' /" 9.3#/ft, EUE -M (1) 14) HES "XN" (2.75" min ID) @ 65.5 9800' 6649' 15) 3 -' /z' 9.3#/ft, EUE -M 16) 3 -' /z' 9.3 # /ft, EUE -M WLEG w/ muleshoe 10708' 6915' Lower Completion: Top MD L 17) Baker 5 "x7 -5/8" Flexlock Liner Hanger w /setting sleeve 10701' 6914' 18) 4 -' /2', 12.6 # /ft, SLHT Liner 19) 4-W 12.6 #/ft L -80 SLHT liner with blanks TOC Calculated when out of Nechelik sand @ +/- 9400' MD / 6460' TVD 20) Orange Peel Shoe with 4-W 12.6# L -80 Box Up 17082' 7073' (300' above Packer or 500' above Kuparuk C) Packer Fluid mix: Inhibited 9.2 - 9.4 ooa KCI Brine w ith 1500' TVD diesel cap 4 -' /" 12.6 # /ft SLHT liner and blanks: 8 slots / ft, 2'/ < "x1 /8 " slots zo Top Kuparuk C 18 10,241' MD / 6806' TVD ____________ _ > ,ii 19 1 Top Nechelik 11,052' MD / 6954' TVD 6 - 1/8" Hole 7" 26 ppf L -80 BTC Mod Casing TD at 17,092' MD / 7074' TVD . 10851' / 6936' ND @ 83° 0 i CD3 -123 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (ppg) (psi) (psi) 16" 114 / 114 10.9 52 53 9 -5/8" 2852 / 2470 14.5 1117 1615 7" 10851 / 6936 16.0 3138 2493 N/A 17092 / 7074 , 16.0 3200 • N/A • 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 lb/gal 0.052 = Conversion from lb/gal to psi /ft 0.1 = Gas gradient in psi /ft D = True vertical depth of casing seat in ft RKB OR 2) ASP =FPP — (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD ASP CALCULATIONS 1. Drilling below conductor casing (16 ") ASP = [(FG x 0.052) — 0.1] D = [(10.9 x 0.052) — 0.1] x 114 = 53 psi OR ASP = FPP — (0.1 x D) = 1117 — (0.1 x 2470') = 870 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 2470 = 1615 psi OR ASP = FPP — (0.1 x D) = 3138 — (0.1 x 6936') = 2444 psi 3. Drilling below intermediate casing (7 ") ASP = FPP — (0.1 x D) = 3200 — (0.1 x 7074') = 2493 psi • • Cementing Program: 9 5/8" Surface Casing run to 2852' MD / 2470' TVD. Cement from 2852' MD to 2352' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2352' to surface with 10.7 ppg Arctic Set Lite 3. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1540' MD). Lead slurry: (2352'- 1540') X 0.3132 ft /ft X 1.5 (50% excess) = 381 ft below permafrost 1540' X 0.3132 ft /ft X 3.5 (250% excess) = 1688.1 ft above permafrost Total volume = 381 + 1688.1 = 2069 ft => 465 Sx @ 4.45 ft /sk System: 465 Sx ArcticSet Lite 3 @ 10.7 PPG Tail slurry: (2852' - 2352') X 0.3132 ft /ft X 1.5 (50% excess) = 234.9 ft annular volume 80' X 0.4341 ft /ft = 34.7 ft shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft => 230 Sx @ 1.17 ft /sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft /sk 7" Intermediate Casing run to 10851' MD / 6936' TVD: Cemented in two stages Cement from 10851' MD to 9400' MD (300' MD above the packer & minimum 500' MD above top of Kuparuk reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage: Lead: (10851' - 9400') X 0.1503 ft /ft X 1.4 (40% excess) = 305 ft annular vol. 80' X 0.2148 ft /ft = 17.2 ft shoe joint volume Total volume = 305 + 17.2 = 323 ft => 278 Sx @ 1.16 ft /sk System: 278 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: (5936' - 4903') X 0.1503 ft /ft X 1.4 (40% excess) = 218 ft annular vol. Total Volume = 218 ft => 188 Sk @ 1.16 ft /sk . O z G 8 884/ /OA) z 7 84 27138z/vi System: 188 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 : 3g accelerator @ 15.8 PPG yielding 1.16 ft3 /sk ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3 -123 Plan: CD3 -123 Plan: CD3- 123wp03 Standard Proposal Report ' _ AlArt 12 March, 2010 Large print O • HALL DURT ■ ' Sperry Drilling Services ORIGINAL 00 '+ Project: Western North Slope CD3- 123wp03 oPh Site: CD3 Fiord Pad ConocoPhillips Well: Plan: CD3 -123 4� o D zi50 1 1 � I, 07 Welbore: Plan: CD3 - 123 1 1 1 I 1 1 1 1 1 I I 1 1 1 Al aska Del < 60: Relatively short. simple wells or dmq prollkw with low bW0ed - C O with DDI 8 0 - 8 4: Shorter wells w high tortuosity or wager wells with lox taIoosall DDI = 6.865 p /�a� 00'004 6 8 • • Long, larluo s profiles I wM a high degree of SlT ulty - 7_ m 9.516" x 12 - 1/4" HJ "#kL1.91BURTGIN I REFERENCE INFORMATION Surface LOcabn 1:,." O O O / Northing 8003522 43 - T5 g5 ' . p p Co- ordinate NIE) Referee. Well Plan CD3 -123, T North Emting 1527967 12 O / a..............--......--.........-...- __...... - Vertical (TVD) Reference. Plan CO3 -123 (36 3.12 6) 48.9011 (Dryon 19) Ground Level 12 60 Oe O ction (VS)Refer Sld- (O.00N, ODE) Latitude 70 8136 N `Yp p'�. Sperry �i9 =III ➢1r Se ce. 0 IMZ AlasAlaska Zone44wre ogtutle15054'S7932W - s a Start DLS 3.12 TFO 105.84 0 - � N ° O - 10:35, March 12 2010 Geodetic Datum. Nora, American Datum 1983 _ / � • e - Start DLS 1.50 TFO •90.00 / - CASING DETAILS SURVEY PROGRAM _ _ 10 000 ' - - Start DLS 2.00 TFO 0.00 / I I `; . / T TV MD Name Sire - _ 247000 242110 285186 93 3/8 /8 9'x12 - 1/4' 38.30 1200.00 C O3.1200 3 Han: C09 -123 CR- GYRO -SB - - - 6935139 688679 1085147 7 T 08 -3/4' 1200.00 1709 CD] 12]wp09 lHen: CD9 -123 MWDNFR- AKCKEC 1800 Start OLS 3.23 TFO .64.01 / I Start Build 1.50 707390 702500 1709196 4 -1/2 4 -1 /Y x8 -1/8' / I . _ 0 .7" x 83/4" Start 3945.98 hold at 2528.00 MD 'Start Build 2.20 . Taman - A1Y I - Na Tvnss caws .Er - snaps - _ Start DLS 2.75 TFO 31.88 CO3- 123ay03 Heal 6910.00 - 124397 -5662 51 C Ja IRedas 100 00) ,� - Start DLS 2.00 TFO X9.12 CD3.123xp03 Toe 702500 318627 - 229740 Ceala(ftadwa 10000) - • - ry 1 CO3 - 123wp03 Heell il,,, ry°pQ _ _ SECTION DETAILS - 2000 - ,,, , , Start 5421.19 hold at 11870.78 MD - 889 MD OAO Ins 0.00 Ail 96 TVD .30 -1280 0 WOOS oS.00 0OS •raw .00 0 0.00 O 0.0 DLagy TF VSec Tsr9a1 C -, 1 38.90 _ - 2 000.14 3.40 0.00 900.00 321.10 0 00 0.00 1.50 0.00 0 - _ 9 000.14 4.41 310.00 00.00 051.10 446 -0.11 1.50 310.00 -3.45 66 - _Lx0 4 1107.21 14.81 310.00 1100.00 1051.10 5553 -88.18 2.20 43.45 rt" - 5 2328.00 52.50 285.00 227081 2241.71 328.17 - 711.77 2.15 -3 ,00 - 709.85 $ - 8 8473.88 52.00 285.00 470000 4851.10 1130.95 3 0 100 77529 0.00 -309185 7 679.98 30.18 282.59 5426.70 53T780 1181.12 4722.11 1.50 -9080 .00 .3884.20 O :47-,.--,-,.., �Iy'�Ip 8 9548.58 80.50 192.00 0535.00 0438.10 208.38 4734.88 312 - 105.84 -345998 ce - 1 �, - 9 9877.00 87.07 194.00 0880.00 663110 -79.88 4795.91 2.00 0.00 4259.14 - 1111 10 11170.12 88.88 155.00 6956.90 8910.00 -1311.98 4030.35 3.23 44.01 - 2159.41 � ', �� 11 11570.78 88.99 145.10 898847 8919.57 -1737.40 -539348 2.00 40.12 - 1070.38 '' k- 12 17091.98 88.89 145.18 673.00 7025.00 4188.27 -429740 0.00 0.00 3719 76 CD3- 12]wp09 Toe - 11 11 1 '' - " TD A5 4000 -4000 ;11 4 $°° - --:- - V 1 111111 1 : ��- - -'--- _ " "1 :Ip', `y9 / a500 3000 -2500 0 25 090 - l O l 1111 ^l Start Build 1.50 • _ 1 hV 1 II *. TI , - 6550 D- - -600111 1V' i l�ii�l IL. _ ..w _ Start Build 2.20 \ 0° y sS 1CO3- 123wp03 Tool _ O n A 4 ti - _ Base Permafrost Start DLS 2.75 TFO -31.86 n d 11111 _ G - _ _ 7 9 ° 4.1/2" x 8 -1/8" - 0 Start 3945.98 hold at 2528.00 IIIII _ 3 1 III 20. 1j IIIV1i1i I I I I 1 1 I I I I I I I I I I I I 1 1 1 4000 4000 -2000 0 I, 0 ° - l)/East(+ ( ) 2000 ft/In) I iIi, i ' We - C-40 C -30 9 - 5/8" x 12 - ` � "'OpO - • 0 2500- • '11tH -2500 o C_20 A - ' 111 ANNOTATIONS N N - /- 1I V I I I - D NOSS MD Annotation 1 b 5 37000 32110 37000 Start d t Bu15D _ 800.00 551 10 80014 Start Bdtd 2 20 t1 - %2 1100 DD 1051 10 1107 21 Start OLS 2.75 TFO -31.88 g7 K - K - Basal 'U 0 ' hI11111 227061 2221.71 252800 Start 3945.98 hold al 252800 MD 11 Start DLS 1.50 TF - 90.00 - - 5428 70 4851 77 BO 673.98 Start OLS 312 TFO 10 • ' •. `. - -- 653500 648610 954858 Start 01S 200TFO 000 "' o 688000 6631.10 987700 Start DLS 3.23 TF0-6401 -- - - -- - - -- -' - - - - - 6958 90 6910.00 1117912 Start DLS 2 00 TFO -9012 6988 47 6919 57 11670.76 Sled 5421 19 hold at 11670.78 MD _ K - Basal - K - . 60 - 7073 90 7025 00 17091 98 TO et 17091.98 0 2 Start DLS 3.12 TFO - 105.84 o Start DLS 2.00 TFO 0.00 -5000 I- 5050 2 97 - _ , SA° .0 O ' Start DLS 3.23 TFO -64 01 - - Albian 96 . Se'lo 8 0 5 , - - DLS 2.00 TFO -90.12 FORMATION TOP DETAILS Op ._ -_ - _ _ - - _ _ - _ Top HRZgase 11 1, 3 7-K-1 T 1VDPeth TVDasPath MDPeth Formation op Kuparuk f p K uparuk (` 9 ° ' o 7" x 8- 3 64 ", Start Start 5421.19 hold at 11670.78 MD ICD3- 123wI03 _ 2328 B0 2280 DD 262287 Base �r C-40 - / - - - - - - - - - - r op - O O O .1 248690 243800 287931 C O - -. _ _ - S -p� _ �y�0' _ _ a _ ._ _ O - - Q - - _.- - DO _ _ - - - ... -- 38 9 3822 00 5129 30 K 3 - " _ -_ - - _ 401090 398800 538119 K -3 Basal - r �_ _ - - ._ .._ _ - - - _ - - - - - _ -" '- - - 404090 398200 5403.42 K -2 -� - 414590 409700 5573.97 K -2 Basel _ - • 541390 536500 7652,14 Aldan 97 arse Nui suTop Nuiqsut CD3 - 123 w D3 Toe 650390 849500 9566 Top Aldan 7500 Base NecheTIPP Necheli� q I P I 4 -1/2" x 6 -1 /8" - 7500 s 8719 90 6671100 9983 72 Base HRZ 8769 90 871100 905.62 K -1 I I I I I I I I I I I I I I I I I I I 1 I I I 1 I I I I I 1 1 I 1 I 1 I 1 1 I I 6005.90 875740 101145.22 Top Kuparuk C 805 90 6750.00 10241.22 Top Kuparuk C ' -7500 .5000 -2500 0 2500 5000 7500 8800890 676000 10251.29 LCU 8808 876000 1025129 Top NUgaul Vertical Section at 145.00 °(2500 ft/in) 6868 5390 6905.00 112 47727 Base Top 7028 90 6980 00 14778 15 Base NecheM Project: Western North Slope aT Site. CD3 Fiord Pad CD3- 123wp03 ©no` �.r r +r� �r �' � Well: Plan: CD3 -123 -71 ° Ali ° -2500 I zsI B I I V `1 Wellborn. Plan: CD3 - 123 I I I I I I I I I I I I I Al aska DDI < 60 Relatrey short, simple wale einoee Ur 061 M w low tan.. OI _ DDI84 -68 Long welled ph wO, ele3.ely tortu tortuosity sprofles or > wells with lox tor y l DDI = 6.865 DDI 8.8. Long. tortuous profiles with a high degree of difficulty k HALLIEURTDN REFERENCE INFORMATION Surface Location G'JI Northing 60°352243 2500- -2500 Coordinate (ME) Reference Well Plan. CD3 -123, Tme North EaLtirg 1527967.12 �""""' - -- Vertical (TVD) Reference' Plan CD3 - 123(36 3 +12 6) @ 48 906 (Doyen 19) Ground Level 12 00 Section (VS) Reference slot - (0.00N. 00E) Latitude 70 °25' S 136 N Sperry riling Laudation MMwd Minimum Curvature Long.*15°°54'57932W - - Geodetic Zone Alaska Zone 4 10:43, March 12 2010 Geodetic Datum NOM American Datum 1983 r ° - o ° o o 9 - 518" x 12 CASING DETAILS SURVEY PROGRAM _ N A O C x 8 - 3 / TVD rvDS5 MD Name Sim G y Al O O / - 2470.00 2421.10 2851 86 9 -5/8 0 12 -1/4' 38.30 3x 77.00 CD3- ixiwpm %an: C09 - 723 CB- GYRO-SO - y � O , 6935.89 888679 1085147 7 P x8.3/4" 120°.00 17091.88 CD3- 123wp03 Ran: CD3 -129 MWD +IFR- AKCAZ4C © / 7073.90 702550 1709196 4 -1/2 4- 1/7x8 -1/8' wk POp H ,p Targets - - Start DL3 _ _ 3 - TFO - 105.64 / D- -g Nene TYDSS .ws +E/-w shape - rt DLS 1.50 TFO - 90.00 ■ S' co3aztwpm Heel � t0.m - 1243 W - S6fi2 51 Crap (Ratllae: ice m) 1 00 0 - - Start DLS 2.00 TFO 0.00 I CD3423xpm T 702500 -6188.27 - 229740 Circle (Remus 100 m) _ 180 - - - _ - - yy Start DLS 3.23 TFO -64.01 / I Start Build 1.50 Et 11' 6 7" X 8314" / 1 1 BECTON DETAILS - - - "1 0 00 / . 17 0 z q _ - O - 901 '15.98 hold at 2528.00 MD Start Build 2.20 1111 sac MD me Al rvlsa +w-5 it DLe TPac. v:/.% Target ° - 4 1, A s 4 0 F Start DLS 2.00 TFO -90.12 2 370.00 1 .00 0.00 300.00 321.10 0.00 0.70 0.00 0.00 0.00 2 36.00 0.00 9.80 3P. -21.60 0.00 0.00 0.08 0.00 0 '`' 1 X111 I O Start DLS 2.75 TFO - 31.86 s 007.14 3.01 310.00 00.00 651.10 5.53 48.18 1.50 910.00 43 CD3123Mrp93 NII llp I - �xy0� 4 2521.22 5211 910.00 281 22 21 21 2.2 7051 51.17 .53 460 0.00 4345 5 - 8 8 4700.00 9.95 9x.99 285.00 99b1.10 1190.98 - 97TSS9 9.00 1.88 x 0.00 3091.65 011 �II ;l Start 5421.19 hold at 11870.78 MD 7 7873.98 54.16 262.58 5426.70 5377.80 1191.12 -4722.11 1.50 -4000 .884.20 -1 N -25°0- 1ry1 11 I,II 4 9548.58 60.50 19200 6535.00 6485.10 208.35 -5734.65 3.12 85.84 -3459.w 0 --x500 9 987700 67.07 192.00 6850.00 6631.10 -79.65 -579541 2.00 000 -3259.12 I1 'll�l. _ - _� 10 1117912 66.09 15500 6958.50 6910.00 - 1311.86 4638.35 3.23 -0401 -x155.41 - - 1 11 11670.75 88.85 145.18 895847 8919.57 -1737.48 -5393.48 2.00 .3012 - 1870.38 - 12 17091.06 88.89 14518 7073.50 7025 00 4186.27 -2297.40 0 00 0.00 3749.75 CD3- 123wp03 Tao - IIII C IIII i1Ii111 O I 111111 1 a � r I ll1111 , - -. _, AN" I I II , 13 - 11i1 I - - t�,� x..w ®s -7500 -5000 -2500 0 4mo -ly. X - - me I I I I I 1 I I 1- I I I I � 6 I 1 - _- - 4.- Start am 1 .50 j 9 s I ''' 1 Start Build 2.20 1tli 1 "' "11+,11111 ��Is1� ^ 1. x+' _ _ _ 0 I I I11 111 Co ICD9123wp03 Toe _ Ono n. 0 - Base Permafrost Start DLS 2.75 TFO 31 86 1 i ' I i l l0 1 11 11 1 1 8 4-1/1" x 6 -1/8" DD II - - Start 3945.98 hold at 2528,00 MD 111 111 - I p° I I 1 I I I I I 1 I I I I I I I I I I I I - IJ lu1u�p ° 1 500 0 2500 _ C -40 C -3p 1 39 -7500 -5000 - West( -) /Fast( ♦) (2500 ft/In) 9 -518" x 12 -1/4 v ` - 2500- O C - ANNOTATIONS to - 1 ND TVDSS MD Annotation • CNI 91 II 370 00 321 10 370 DD Start Build 150 g BOOM 551.10 60014 Sled Budd 220 L - O lll 110000 105110 1107.21 Start DLS 275 TFO -31 a K - K - Basal 8 0 0 IIII I11 1 1 111 3 1 II � I' 31 1 1 ,� 227061 222171 252800 Start 3945.98 hold 31252800 MD CD Start DLS 1.50 TFO - 90.00 1 i,11,, I,,1 - 4700 00 4851 10 6473 96 Start DLS 1 50 TFO -90.0 Q - 542670 53778° 767398 S/at 0/.5312 TFO -10584 l6 - % 8880 00 863 10 9877 00 Start 015 3 23 TFO -64 01 U - - ■ 6958 90 6910 00 11179 12 Start DLS 2 00 TFO -9012 02 - - _ 6988 47 6919 57 11670.78 Slat 5421 19 hold at 11670 78 MO - K Basal K - 2 S _ � 707390 702500 1709198 TD at 1709196 O 0 5°°°- Start DLS 3.12 TFO \ 105.64 0 Start DLS 2.00 TFO 0.00 -0000 Albian 97 Spa - 0 0 �' Start DLS J 3.23 TFO -64.01 Albian 96 SZ° 8000 / , ' Start DLS 2.00 TFO -90.12 - _ FORMATION TOP DETAILS Top HRZBase HRZK_1 To P Pa K u C 0 ' - 4 " , ' Start 5421.19 hold at 11670.78 MD ICD3- 123w�03 _ 1z a en ND 2oP tt o l DP Ali Base v n - , - _ ruk fbp Kuparuk 9 CU 9 9 , ' ° 0 7 " 6 . ° ° o �,+ 2328'90 228800 2672 30 _ - - - - - - - _ - , r.,-, ' , N - G _ _ O _ _ _ r& - _ ey- _ _ ._ _ - - 860.90 282200 349770 C --0 a = =.-- - - - - _ - - _ _ -- - _ - - _ _ - - - - _ __ _ - K- � 4-, - - _ _ ~�� 536119 K-3 Basal _ - W -' - - - - - - - - - - - -- T 404090 399200 4040 90 3992 00 5403 42 K-2 - - _ - - _ - _ _ - - - - -- - - - - - - 4145 409700 5573.97 K -2 Basel - _ 5413 90 5315 00 7852 14 Aldan 97 8353 37 7300 - Base NecheIIT P 58 90 51 Pe Nu Nuiqsut I CD3 Toe q - 'j /2" x 6 - 1/8" - 7300 854]80 8.09800 958878 op HRZ 6674 99 6628 00 9863 90 Base HRZ 6719.90 8871 DD 9982 72 0-1 I I I I I 1 I I 1 I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I 8762.90 6714.00 101°5.61 Top KspausD 6805.90 8757.00 10241 22 Top Kuparuk C -7500 -5000 -2500 0 2500 5000 7500 , 160190 6760.00 1025129 LCU 6808 90 8780.00 10251 29 Top Nu BBBa.90 882000 10477 27 Section at 145.00 0 (2500 Mn) 8°5390 90500 Base Nu 1p °52.17 Top Neche 6 7028 9° 698000 1477115 Base Nechelk Easting (3500 ft/in) 1 I 1 1 1 1 I 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 1 1 1 1 1 I 1 1 1 1 i 1 1 II I �_I I I_I I �_ I I_ — 10:34F March 122010 — — CD3- 126wp02 — _ CD3 -109 CD3- 125wp02 - . CD3 106 CD3 -10.. D3 -108 — CD3 -110 - CD3-111L CD3 -3i 1 - CD3 -301 Awp07 CDz- : L1 - CD3- 111 -_ CD3 -112 CD3 -107 • - CD3 -113 i ; D3- 302Aw.13 \r3 wp0 - — h, C D3-114 I'i'1111•iilluu''i I 1 Ui I pi - Z ui CD3 302 — o - CD3 -118 CD3 -115 � ° D y1 CD3 -307 _ S �n g - CD3 -117 a,pi ° o _ CD3 124 � I Y ��,� �I Z I' / i , �01 ..;1 Rig F ' ' ui9 '``.�, 1 %A CD3-303 • 'Idq'9PI;' �' ` ' "� ►mss_ CD3- 198wp01 _ CD 6 CD3 316A _ CD3- 199wp01 �/► ��� CD3- 120wp$ . ` 3 119wp02 _ - — - CD3- 121wp03 _CD3 -304 - CD3 305PB1 — CD3 - 122 CD3 -305 - ConocoPhillips(Alaska) Inc. -WNS CD3 123wp03 _ - Western North Slope CD3 Fiord Pad - I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I 1 I 1 I I I I I I I I I I I I I I I I I I 1 I I I Easting (3500 ft/in) • 0 Conoco Phillips HALLIBURTON Standard Proposal Report , ___ , _.....„.„..„„n___ _ _ aaaaaaaaaaaimanuanammumambiraaaaaaataaataaaaaraaaannamminanNiiimilmararanammaraavanaar aaaaal Database: aa00 EDM v16 Prod liLai0[004laiktait RataOncez, Well Plan: CD3-123 ! T.ontipait]]"t: ConocoPhillips(Alaska) Inc. ]t4iNitiffitikiiii Plan: CD3-123 (36.3+12.6) @ 48.90ft (Doyon 19 . • proloarr:01110[Ai Western North Slope zlip Reference :z= ,,,, ... Plan: CD3-123 (36.3+12.6) @ 48.90ft (Doyon 19 1 . t, :tt ._,,, -,,,AtItttt,,ltilttitiltltttt,tt.' Site: CD3 Fiord Pad t'iNO#kiXtifeer*KWisiE1211)1 True - CD3-123 Su Notiscitid "---.4 0 tiiirt, 7, . n . Weill; Plan: an• irVey cat a ,ict;,,, M Curvature I "Autztittst • We Plan: CD3-123 gtttttttttlritgrilglitillttltAt4:t.::] 1 Djatitint, CD3-123t003 tttt,ttitttoot.tmt-4t ,..r,tr,,t,,:s t. ... .7-7- ..-,,,,,!,,,,,,,,, . ,,,,,,,,-•::: t:t,,,,,,,,,,,,,,toitiittiii, . , - , ...,-......,,,NA-4e, 'alllaffia ,,,,,,, '4,11111EIVIIIPIIIIIIP1111111111111 a , , , an . • - "-ann..'""""'' Project = Western North Slop Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD I927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor riiiiiiiiiii':h4:ili''4: CD3 Fiord paci Site Position: Northing: 469.98ft Latitude: 53° 58 43.652 N From: Map Easting: -401.26ft Longitude: 152° 19' 30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88 ° iialL4K:;F:::- ,. Plan: CD3-123 Nur Well Position +NI-S 0.00 ft Northing: 6,003,775.23 ft • == ]: Latitude: 70° 25' 9.302 N +E/-W 0.00 ft Easting: 387,935.21e .' 150° 54' 46.554 W Position Uncertainty 0.00 ft Wellhead Elevation: _=,, ft,...0 - ratind Level; 12.60ft • Taaa aaalliiill 'aara-a=al:;:aa all aa a ataaallaa, a>afaaaaaE,a l i*: 6b3 . z...-w.. r1[77 r- - - -? '1 . 1 11V , 1 114,7s;R - 34:,0: : 111!Wei , 77 !!!r ''''''''::: M9010,1::-.11!"..irAT''-a:':1- Sample Date : ::i.1111, 1 11,il!1*,„ !, .......`,1,.-Elt=1!?,f=4 , ,,, = - 41a41' g 1 1;1:! ,, !W ,, -.3., 0 .c14;FPrIgt U h.,:30111:11iin:F.P! --_ - ------- --1s,::: 1 ■ 1 1 I IFI tli T F. - :: r : : n1 1 1 lipt,,,,,LrfK :ii?r ■:' : ::: ::: : : ::: ::::::::::::-''''::::, '';- ' : ' 1 ' E, '''- aZ,1 ::'': : 4 - - : .:a - ■, - ' ' r ' r: ,■ !'''''''-i ''' k BGGM2009 3/11/2010 : 1.6.611-gNi: !!!:, 79.72 57,336 - .," ,I!!!!:31:,,,„„ •.=_•_,„,,,,,' PteSicit,:? CD3-123wp03 5" 'ii:i'l:!illi , --, Audit Notes: Version: Phase: -Je'l',LAk!'',„ Tie On Depth: 36.30 5trticaltectiontiiiii-i*-]-]]]-]]]]]-ii-2=!-iii ,,,,,,:::: : : .... ,. ■ r rr , .. , - . ,=, , .-m,, " ..:p ......:,=-=,_,,,,-=';,,,:,,,EE.,, , =i : ,,,,r, , , :-. : - 1 r=1,7,W, L 1-' .' 1 , i:Ii-": ihr C1-1, ,: 00 0.00 145.00 --- Plan-Sections . ' r ' H IM ' : ' T . . _,,,-,.=;=,--7Ae* Measured h ::,: ,,i;,A:wg. .3,1,011$0,05k -L---jP0.0t1):1411g:rliitinattott]---Azi*OtkiaAWit41::;ir :4140NT:; 4 rigff-T7kE(..IV :iE4 ' tMate 1 1D I APO t-- '-' ]7.- , *4013 7-1-HAft)::!9$1N4r.:T:T f :44111---Stitri30" !! -74V17:(IYtttf 42 0 C4 i (1 T 36.30 0.00 0.00 36.30 -12.60 0.00 0.00 0.00 0.00 0.00 0.00 370.00 0.00 0.00 370.00 321.10 0.00 0.00 0.00 0.00 0.00 0.00 600.14 3.45 310.00 600.00 551.10 4.46 -5.31 1.50 1.50 0.00 310.00 1,107.21 14.61 310.00 1,100.00 1,051.10 55.53 -66.18 2.20 2.20 0.00 0.00 2,528.00 52.00 285.00 2,270.61 2,221.71 326.17 -771.77 2.75 2.63 -1.76 -31.86 6,473.98 52.00 285.00 4,700.00 4,651.10 1,130.96 -3,775.29 0.00 0.00 0.00 0.00 7,673.98 54.16 262.59 5,426.70 5,377.80 1,191.12 -4,722.11 1.50 0.18 -1.87 -90.00 9,548.58 60.50 192.00 6,535.00 6,486.10 208.36 -5,734.68 3.12 0.34 -3.77 -105.64 9,877.00 67.07 192.00 6,680.00 6,631.10 -79.68 -5,795.91 2.00 2.00 0.00 0.00 11,179.12 88.89 155.00 6,958.90 6,910.00 -1,311.86 -5,638.35 3.23 1.68 -2.84 -64.01 11,670.63 88.89 145.17 6,968.46 6,919.56 -1,737.28 -5,393.56 2.00 0.00 -2.00 -90.12 17,091.54 88.89 145.17 7,073.90 7,025.00 -6,186.08 -2,297.86 0.00 0.00 0.00 0.00 3/1212010 11:42:14AM Page 2 COMPASS 2003.16 Build 69 ! f 1 A )ii\!ti , , , t , , 1 S 410 Conoco Phillips HALLIBURTON Standard Proposal Report wiligneigi-7.=±-Fr'!_ D a ta b as 6ii1:1!!11111110 E : : - : , , EDM v16 Prod iLocal C Well Plan: CD3-123 .,,Company: ,„- ConocoPhillips(Alaska) Inc. ::']:TVIlitafeciiiiau;i:; Plan: CD3-123 (36.3+12.6) @ 48.90ft (Doyon 19 (Doyon 19 !!0iii,i,1,11141.:111.1111,:rri:lb,11.111,1:1111i.1,,i1.,1:,1,1,.,1,1.;:p,7::,:, Western North Slope MD Reference: Plan: CD3-123 (36.3+12.6) @ 48.90 - ] :114WiggRriiiii ft Bite:'' CD3 Fiord Pad iiiiiiiiiififiiel'iUAi True . __-__.,, .__ ,.[.. (9!! Plan: CD3-123 :]:s Minimum Curvature il ..' weitibi4 Plan: CD3-123 Desigu:"!= CD3-123wp03 Planne ,....... ....PrYey:,::.!:.:....: ::'-..--:-:'-•':'-,:!':':-I!!'4.-',.:H'::.:.1.:..:,,.:::!,,..,,,:,.E.,Z..:]:!_:-:::_,•_-- ............................................................................................................................................................................................................................................................................................. 74107.P :------- --------------.. •---....-, ---- •::::.!!. 11 !1511111141m11 1 11!ill. : !!....:z : 1 , M!1.;E.z...:•;•:-::,=• , .- - ! -- : ---,-----,-- ! , ff , .:: , ------,,, :,,:,,•:,:::•;- •: -- .10, Depth Iipalitit= i:a=t==_51 11',g.',i4Oltre6tioii-']]!--:; e _i______::_i_. () 6_- _______:_:_:_:_:_:_:_-_-# ----]- rr rr- Ht : ::r'---]]-:!r-"'`---.1:'1:&.ff: ..:- A71,,,,t-4 36.30 0.00 0.00 36.30 -12.60 0.00 0.00 6,003,775.23 387,935.21 0.00 0.00 100.00 0.00 0.00 100.00 51.10 0.00 0.00 6,003,775.23 387,935.21 0.00 0.00 200.00 0.00 0.00 200.00 151.10 0.00 0.00 6,003,775.23 387,935.21 0.00 0.00 300.00 0.00 0.00 300.00 251.10 0.00 0.00 6,003,775.23 387,935.21 0.00 0.00 370.00 • 0.00 0.00 370.00 321.10 0.00 0.00 6,003,775.23 387,935.21 0.00 0.00 'Start Build 1.50,.:,,:lw! 400.00 0.45 310.00 400.00 351.10 0.08 -0.09 6,003,775.31 387,935.12 1.50 -0.11 500.00 1.95 310.00 499.97 451.07 1.42 -1.69 6,003,77WW8 387,933.54 1.50 -2.14 _ ,-._ 600.00 3.45 310.00 599.86 550.96 4.45 -5.30 6,003,779.76. -1 , '- -- - 387,929.97 1.50 -6.69 600.14 3.45 310.00 600.00 551.10 4.46 -5.31 AW003,779.7 1.50 -6.69 Start Stifittt2S':' 700.00 5.65 310.00 699.54 650.64 9.55 -11.38 H6.0014184,95 '' 2.20 -14.35 . ...,. ...,._ 800.00 7.85 310.00 798.84 749.94 17.10 -20.38 6:003,792.64 387,915.09 2.20 -25.70 900.00 10.05 310.00 897.62 848.72 27.10 -32,30 .6,003,80Z81 387,903.33 2.20 -40.72 1,000.00 12.25 310.00 995.72 946.82 39.53 A47 387,888.70 2.20 -59.40 .:., . :: . .... _. _ 1,100.00 14.45 310.00 1,093.02 1,044.12 54.37 =I -64.79:.: . : 387,871.24 2.20 -81.70 ..; .. T :,-,-■ _, 1,107.21 14.61 310.00 1,100.00 1,051.10 55.53 :-1" -66.18 .- ; . W001,831.74 387,869.88 2.20 -83.45 " stiiiibLS 2-75 179 - 1,200.00 16.83 305.34 1,189.31 1,140.41 70.82 45.: 387,850.19 2.75 -107.40 1,262.51 18.38 302.83 1,248.90 1,200.00 11 -101.77 6,003,858.14 387,834.68 2.75 -125.05 1 . ... . . . .. .. Base Permafrost 1,300.00 19.32 301.51 1,284.38 4,236.481,, ''',:i9T 5.,7-4_ 84 ,Hr.:_,-112.02 6,003,864.74 387,824.53 2.78 -136.21 ,,411,11,,,„ -- 1,400.00 21.86 298.53 1,377.98 1,329.08 105.39 -142.48 6,003,882.74 387,794.34 2.75 -168.05 1,500.00 24.45 296.16 1 ,460:pg ,421 .02 - .123.41-; -177.42 6,003,901.28 387,759.68 2.75 -202.85 1,600.00 27.07 294.21 1:566.97 , H 1,511.07 141.87 -216.76 6,003,920.33 387,720.62 2.75 -240.54 " • 1,700.00 29.72 292.59 A 1 ' 647.94A4399 60.72 -260.41 6,003,939.83 387,677.27 2.75 -281.02 '4,,!5k.,.. ..,. _..r 1,800.00 32.38 291.21 1,733.61 ':'''::1,614;7'1-:-..: 179.93 -308.26 6,003,959.76 387,629.71 2.75 -324.20 1,900.00 35.05 290.02 1,816.78 - 1367 - .13i" 199.45 -360.21 6,003,980.05 387,578.07 2.75 -369.99 .... 2,000.00 37.73 288.97 1,897.28 1,648.38 219.23 -416.13 6,004,000.66 387,522.45 2.75 -418.27 2,100.00 40.42 288.05 1,974.90 1,926.00 239.23 -475.90 6,004,021.56 387,462.99 2.75 -468.93 2,200.00 43.12 287.22 2,049.48 2,000.58 259.40 -539.39 6,004,042.67 387,399.82 2.75 -521.86 2,300.00 45.82 286.48 2,120.83 2,071.93 279.69 -606.43 6,004,063.97 387,333.10 2.75 -576.94 2,400.00 48.53 285.79 2,188.80 2,139.90 300.06 -676.88 6,004,085.39 387,262.97 2.75 -634.04 2,500.00 51.24 285.17 2,253.23 2,204.33 320.46 -750.57 6,004,106.90 387,189.59 2.75 -693.02 2,528.00 52.00 285.00 2,270.61 2,221.71 326.17 -771.77 6,004,112.93 387,168.49 2.75 -709.85 Start 394548 hold at 2528.00 MD 2,600.00 52.00 285.00 2,314.94 2,266.04 340.86 -826.57 6,004,128.43 387,113.92 0.00 -753.32 2,622.67 52.00 285.00 2,328.90 2,280.00 345.48 -843.83 6,004,133.31 387,096.7 3 :1 -77.00 C -40 1:1:,i1H:iiH.' . = : _ '''• ' .: -,=---_---- - - ' '' : ' ' -. --::,-'---- ,,, - --------': :41 .- --:: 2,700.00 52.00 285.00 2,376.51 2,327.61 361.25 -902.69 6,004,149.96 387,038.12 0.00 -813.68 2,800.00 52.00 285.00 2,438.07 2,389.17 ' 381.65 -978.80 6,004,171.50 386,962.33 0.00 -874.05 2,851.86 • 52.00 285.00 2,470.00 • 2,421.10 392.23 -1,018.27 6,004,182.66 386,923.02 0.00 -905.35 9 x12-441M...:.,.:.. 2,879.31 52.00 285.00 2,486.90 2,438.00 397.82 -1,039.17 6,004,188.57 386,902.22 0.00 -921.92 0 740:401 , 41H:'':' - -:::!:=:i: . - - - r 7 - ' '''':H . __:: ---- - '''''' .---,,_-=]-- :-:'1'i:ii 1 _ - ' •-----"-'-': - -- .''''''''':: __-,-':' ''''N41,:,,, ' ' ' '''' _ 3/1212010 11:42:14AIVI Page 3 COMPASS 2003.16 Build 69 (-1 7:1 17)1 1 A, L L , • 0 Conoco Phillips HALLIBLIRTON Standard Proposal Report Databate,t.: EDM v16 Prod . Refotendet Well Plan: CD3-123 -, Company :_--- -'r ConocoPhillips(Alaska) Inc. ']-171/D]Referencem-4----,--,7 ]* -:f .:77-1 Plan: CD3-123 (36.3+12.6) @ 48.90ft (Doyon 19 -) .. ,- ----------------_,---_---___--- -,; - -,-. Project: : j ; .!::.)1 1 ,4i i ii.m Western North Slope i : , M1) - 11eterence::„ - :. -- 7 , - ..r - - - , _-]_-i-i_-_-] - _:,:f: - 'ij Plan: CD3-123 (36.3+12.6) @ 48.90ft (Doyon 19 .... Site: CD3 Fiord Pad ':Nortlikefetince True !I Wolti=W_T -:_-- Plan: CD3-123 - ',Survey Calculation ilaathod:r Minimum Curvature Wellbitre:: Plan: CD3-123 D4,40. CD3-123wp03 ---, , , , , - ---------------------- _,...„ rtaunitul.-0uruey..:..,.!i,:.1.....“ .. ..“ ..p..... _ ... ]-_-_-__ ..,' :':::!:: , ,.,H.4'1011! 7 ' - ::- - :- '' -'':':'!-- --:-'-:--,,---' '. :': 1 '': .:.' :.,-::::--,::::=-:;:-- -71110 -., . - 7 ' ' . -,,- :-_,-- ..,- :_'-_- _: 1:]: :-::]:, ' ' ::':.,:1,:'!■:: :'' :'q:'_ . '!''''!' : :',;: 1 1,,VV:i' ,Y1 -,' L - ' ' -"- --- ..-=,' - - -;.- - ... :, _ :-_:: .]_::',]:]:]:]:],::_-,:--,__ ., !:' . :''..' 'IL!H - : - ] : _ - : =7? -- -,:- ± .. . l'I'I:::,:.: „:.::,,: ,. , .. , ; __ _'_ _-: _,!1 -L- --- ----:--------'-...M .--; - -- - ':- -- : fti d s (ft) Measured . - --- - . _ ' . -- -_:: -_-_ _---- - ,:,,, ']:--] ''''''- Depth ......... ---- h - 12-Thiclination 'Azimuth Depth TV1i.i .: '- 1 Northing Dt..* (ft) 0, .tkli :-:- f :_ ,_i _ .------. --- ---------- -- ------------:::2:1 ..:.,,..i.,.,:::.,.- , I 2,900.00 52.00 285.00 2,499.64 2,450.74 402.04 -1,054.92 6,004,193.03 386,886.53 0.00 -934.41 3,000.00 52.00 285.00 2,561.21 2,512.31 422.44 -1,131.03 6,004,214.56 386,810.74 0.00 -994.78 3,100.00 52.00 285.00 2,622.77 2,573.87 442.83 -1,207.15 6,004,236.10 386,734.95 0.00 -1,055.14 3,200.00 52.00 285.00 2,684.34 2,635.44 463.23 -1,283.27 6,004,257.63 386,659.15 0.00 -1,115.51 3,300.00 52.00 285.00 2,745.90 2,697.00 483.62 -1,359.38 6,004,279.17 386,583.36 0.00 -1,175.87 3,400.00 52.00 285.00 2,807.47 2,758.57 504.02 -1,435.50 6,004,300.70 386,507.56 0.00 -1,236.24 3,499.78 52.00 285.00 2,868.90 2,820.00 524.37 -1,511.45 6,004,322.19 -:,--- 386,431.93 0.00 -1,296.47 ._. C -20 3,500.00 52.00 62.00 285.00 2,869.04 2,820.14 524.42 -1,511.61 6,064,322..23.:: 386,431.77 0.00 -1,296.60 3,600.00 52.00 285.00 2,930.60 2,881.70 544.81 -1,587.73 . : 1304,343.174V386,355.97 0.00 -1,356.97 3,700.00 52.00 285.00 2,992.17 2,943.27 565.21 -1,663.85 , 6,,004,365.30 - - :::'--366;280.18 0.00 -1,417.33 3,800.00 52.00 285.00 3,053.74 3,004.84 585.60 -1,739.96 _:.-6,0ft*,:i86:83 - - - --2:266;204.38 0.00 -1,477.70 3,900.00 52.00 285.00 3,115.30 3,066.40 606.00 -1,816.08 6,1114406.37,_ 386,128.59 0.00 -1,538.06 4,000.00 52.00 285.00 3,176.87 3,127.97 626.39 -1,892.10,4k:A,004,420.610-Y 386,052.79 0.00 -1,598.43 . ..., , 4,100.00 52.00 285.00 3,238.43 3,189.53 646.79 -1,968.31 1!:1!;= 385,977.00 0.00 -1,658.79 ,,-. 4,200.00 52.00 285.00 3,300.00 3,251.10 667.18 -2,044.43 li. :16;004472.97 385,901.20 0.00 -1,719.16 :,] ----,_:-_ ..: ...__--%.- 4,300.00 52.00 285.00 3,361.57 3,312.67 687.58 4,120.54 - 1004,494.50 385,825.41 0.00 -1,779.52 4,400.00 52.00 285.00 3,423.13 3,374.23 707.97 -2,196.66==, 6,004,516.04 385,749.61 0.00 -1,839.89 4,500.00 52.00 285.00 3,484.70 3,435.80 _728.37 -2,272.11-E-'= '.: 6,004 ,537.57 385,673.82 0.00 -1,900.25 4,600.00 52.00 285.00 3,546.26 3,497.36 -:-=-E-=48„.7-6 -2,345:89 6,004,559.10 385,598.02 0.00 -1,960.62 4,700.00 52.00 285.00 3,607.83 3,558.93 NIF769.1. , -2,425.01 6,004,580.64 385,522.23 0.00 -2,020.98 4,800.00 52.00 285.00 3,669.40 .:' .3 ,529.50'''-: . 789:55: ::::]?-2,501.12 6,004,602.17 385,446.43 0.00 -2,081.35 4,900.00 52.00 285.00 3,730.98: . 3,682.06 11,809.95 %,.. 6,004,623.71 385,370.64 0.00 -2,141.71 ..... . .. .. . .. .. 5,000.00 52.00 285.00 3,79158 : 3,743.63 630.34 -2,653.35 6,004,645.24 385,294.84 0.00 -2,202.08 5,100.00 52.00 285.00 3,864.10 850.74 -2,729.47 6,004,666.77 385,219.05 0.00 -2,262.44 5,127.30 52.00 285.00 3,870.90±1;82. 1856.31 -2,750.25 6,004,672.65 385,198.36 0.00 -2,278.92 MHK.4 5,200.00 52.00 285.00 3,915.66 3,866.78 871.13 -2,805.59 6,004,688.31 385,143.26 0.00 -2,322.81 5,300.00 52.00 285.00 3,977.23 3,928.33 891.53 -2,881.70 6,004,709.84 385,067.46 0.00 -2,383.17 5,361.19 52.00 285.00 4,014.90 3,966.00 904.01 -2,928.28 6,004,723.02 385,021.08 0.00 -2,420.11 - ' - K-1 Basal_ 5,400.00 52.00 285.00 4,038.79 3,989.89 911.92 -2,957.82 6,004,731.37 384,991.67 0.00 -2,443.54 5,403.42 52.00 285.00 4,040.90 3,992.00 912.62 -2,960.42 6,004,732.11 384,989.07 0.00 -2,445.60 ,:,:... K - 2 - ' 5,500.00 52.00 285.00 4,100.36 4,051.46 932.32 -3,033.93 6,004,752.91 384,915.87 0.00 -2,503.90 5,573.97 52.00 285.00 4,145.90 4,097.00 947.41 -3,090.24 6,004,768.84 384,859.81 0.00 -2,548.56 K Basal 5,600.00 52.00 285.00 4,161.93 4,113.03 952.71 -3,110.05 6,004,774.44 384,840.08 0.00 -2,564.27 5,700.00 52.00 285.00 4,223.49 4,174.59 973.11 -3,186.17 6,004,795.98 384,764.28 0.00 -2,624.63 5,800.00 52.00 285.00 4,285.06 4,236.16 993.51 -3,262.28 6,004,817.51 384,688.49 0.00 -2,685.00 5,900.00 52.00 285.00 4,346.62 4,297.72 1,013.90 -3,338.40 6,004,839.04 384,612.69 0.00 -2,745.37 6,000.00 52.00 285.00 4,408.19 4,359.29 1,034.30 -3,414.51 6,004,860.58 384,536.90 0.00 -2,805.73 6,100.00 52.00 285.00 4,469.76 4,420.86 1,054.69 -3,490.63 6,004,882.11 384,461.10 0.00 -2,866.10 6,200.00 52.00 285.00 4,531.32 4,482.42 1,075.09 -3,566.75 6,004,903.64 384,385.31 0.00 -2,926.46 6,300.00 52.00 285.00 4,592.89 4,543.99 1,095.48 -3,642.86 6,004,925.18 384,309.51 0.00 -2,986.83 3/12/2010 11:42:14AM Page 4 COMPASS 2003.16 Build 69 r'"ikle"'N.ifk " ' • i ConocoPhillips iliALLIBURTON Standard Proposal Report ,,Database - EDM v16 Prod 5Locai Co ordinate Reference Well Plan: CD3 -123 Company ConocoPhillips(Alaska) Inc. _TVD Referen Plan: CD3 -123 (36.3 +12.6) @ 48.906 (Doyon 19 Prooject, tl',IIl,ulfl I, Western North Slope MD Reference j1 ;; Plan: CD3 -123 (36.3 +12.6) @ 48.90ft (Doyon 19 Site: CD3 Fiord Pad NorthReference , True Well: - Plan: CD3 -123 SurveyCaicutation Method '' Minimum Curvature pl,;l I VW�elitbot e 1 g4i!o11QIIPi Plan: CD3 -123 ;ij 1 Design CD3123wp03 1 IlP won ed Sur*ey f �,r,; oip, p ppi1 11 Measur ` Verti Map lul Ma a , I l p ll '_' - ' "�llhllll i ,d l 1 !!1.l11 De i'! V I, �I p I V1 IIiIG111 . th "- De th - I+ I-S +EI Nn - Ea tin DLS V/ n p inciin Azimuth p TVDss Nf orthi � �' � - ertSe� (ft} ) � ) I . I III I11(R} (ft) t� (ft „ . tft1 j X 605.55, IIIIIdu'ul .. - I '' s. 6,400.00 52.00 285.00 4,654.45 4,605.55 1,115.88 - 3,718.98 6,004,946.71 384,233.72 0.00 - 3,047.19 6,473.98 52.00 285.00 4,700.00 4,651.10 1,130.96 - 3,775.29 6,004,962.64 384,177.65 0.00 - 3,091.85 Start DLS 1.50 TFO -90.00 6,500.00 52.00 284.50 4,716.02 4,667.12 1,136.19 - 3,795.12 6,004,968.16 384,157.90 1.50 - 3,107.50 6,600.00 52.02 282.60 4,777.57 4,728.67 1,154.65 - 3,871.73 6,004,987.77 384,081.58 1.50 - 3,166.57 6,700.00 52.08 280.70 4,839.07 4,790.17 1,170.58 - 3,948.96 6,005,004.85 384,004.61 1.50 - 3,223.91 6,800.00 52.16 278.80 4,900.48 4,851.58 1,183.95 - 4,026.74 6,005,019.39 .,,,. 383,927.04 1.50 - 3,279.47 6,900.00 52.28 276.91 4,961.74 4,912.84 1,194.75 - 4,105.03 6,005,031.361,,, 383,848.93 1.50 - 3,333.23 7,000.00 52.42 275.03 5,022.83 4,973.93 1,202.98 - 4,183.77 6,005 04077 , 383,770.33 1.50 - 3,385.13 7,100.00 52.60 273.15 5,083.69 5,034.79 1,208.63 - 4,262.91 6,A05,047=61 3 8 1 3, 6 91.29 1.50 - 3,435.16 7,200.00 52.80 271.28 5,144.30 5,095.40 1,211.70 - 4,342.39 6 ; 005,051.88 -- 383,61 1.50 - 3,483.26 7,300.00 53.04 269.42 5,204.60 5,155.70 1,212.19 - 4,422.16 .._ 6,005,053.56 .:,383,532.12 1.50 - 3,529.41 7,400.00 53.30 267.58 5,264.55 5,215.65 1,210.09 - 4,502.16 6,005 383,452.10 1.50 - 3,573.58 7,500.00 53.59 265.74 5,324.11 5,275.21 1,205.41 - 4,582.35__ 6 005,049.19 - 383,371.86 1.50 - 3,615.74 7,600.00 53.91 263.93 5,383.25 5,334.35 1,198.15 -4,662.66K__ 383,291.46 1.50 - 3,655.86 7,652.14 54.08 262.99 5,413.90 5,365.00 1,193 34 -4 704 56 6,005,038.96 383,249.50 1.50 - 3,675.95 Albian 97 No '4 : ` 7,673.98 54.16 2 6 2 .59 5,426.70 5,377.80 1,191.12 - 4, 6,005,037.00 383,231.91 1.50 - 3,684.20 Start DLS 3.12 TFO - 105.64£ "p a' '(= 7,700.00 53.94 261.63 5,441.98 5,393.08 ,188.23 - 4,742. 98. 6,005,034.42 383,211.00 3.12 - 3,693.80 7,800.00 53.19 257.86 5,501.38 5,452.48 , 4,173,9Z‘__-4,822.13 6,005,021.30 383,131.66 3.12 - 3,727.48 7,900.00 52.56 254.03 5,561.75 _ 5,512.85 1,1,5458 X4,899.45 6,005,003.12 383,054.06 3.12 - 3,755.98 8,000.00 52.05 250.14 5,622.90 5,574.00 11 11,130.25 _`'. "" -4,974.72 6,004,979.93 382,978.44 3.12 - 3,779.23 8,100.00 51.68 246.20 5,684.67', _[5,635.77 1,101.02 - 5,047.72 6,004,951.80 382,905.02 3.12 - 3,797.16 8,200.00 51.43 242.23 5,746,8D.1 5 1,066.97 - 5,118.22 6,004,918.82 382,834.02 3.12 - 3,809.70 8,300.00 51.32 238.24 5,809.29 5,76d 39 1,028.20 - 5,186.02 6,004,881.07 382,765.66 3.12 - 3,816.83 8,363.37 51.33 235.71 5,848.90` 5,800.00 - `1,001.24 - 5,227.49 6,004,854.74 382,723.78 3.12 -3,818.53 Albian 96 8,400.00 51.35 234.24 5,871.78 5,82T88 984.82 - 5,250.91 6,004,838.68 382,700.12 3.12 - 3,818.52 8,500.00 51.51 230.26 5,934.14 5,885.24 936.97 - 5,312.71 6,004,791.77 382,637.62 3.12 - 3,814.77 8,600.00 51.81 226.30 5,996.18 5,947.28 884.79 - 5,371.23 6,004,740.47 382,578.32 3.12 - 3,805.59 8,700.00 52.24 222.38 6,057.73 6,008.83 828.42 - 5,426.30 6,004,684.94 382,522.42 3.12 - 3,791.00 8,800.00 52.80 218.51 6,118.60 6,069.70 768.05 - 5,477.76 6,004,625.35 382,470.07 3.12 - 3,771.06 8,900.00 53.48 214.71 6,178.60 6,129.70 703.84 - 5,525.44 6,004,561.87 382,421.43 3.12 - 3,745.81 9,000.00 54.28 210.97 6,237.57 6,188.67 635.98 - 5,569.22 6,004,494.69 382,376.64 3.12 - 3,715.34 9,100.00 55.19 207.32 6,295.32 6,246.42 564.69 - 5,608.96 6,004,424.00 382,335.84 3.12 - 3,679.73 9,200.00 56.21 203.75 6,351.69 6,302.79 490.16 - 5,644.54 6,004,350.03 382,299.14 3.12 - 3,639.09 9,300.00 57.33 200.27 6,406.50 6,357.60 412.63 - 5,675.86 6,004,272.98 382,266.67 3.12 - 3,593.54 9,400.00 58.54 196.87 6,459.60 6,410.70 332.31 - 5,702.83 6,004,193.08 382,238.50 3.12 - 3,543.22 I 9,500.00 59.84 193.57 6,510.83 6,461.93 249.45 - 5,725.36 6,004,110.58 382,214.73 3.12 - 3,488.27 ' 9,548.58 60.50 192.00 6,535.00 6,486.10 208.36 - 5,734.68 6,004,069.63 382,204.79 3.12 - 3,459.96 Start DLS 2.00 TFO 0.00 9,566.76 60.86 192.00 6,543.90 6,495.00 192.86 - 5,737.98 6,004,054.18 382,201.26 2.00 - 3,449.15 . Top HRZ 9,600.00 61.53 192.00 6,559.92 6,511.02 164.36 - 5,744.03 6,004,025.78 382,194.78 2.00 - 3,429.28 3/12/2010 11:42:14AM Page 5 COMPASS 2003.16 Build 69 :r-N1 n 11 . I: 1 t\ I 1\ 1 • 0 ConocoPhillips HALLIBLIRTON Standard Proposal Report oiI �8 1 t 1 ` IrGh; V Pf . '- _. .. - = - �_,:.: n nluramllanruulr r G < -- "aVUUI limp , ' a ,,,,,,, : _ ^ ., - - uuu. pV EDM t-ocat - ordinate Referen Well Plan: CD3 123 Company .IIh-- : ConocoPhillips(Alaska) Inc. 1 1TVD Reference " 1°G +Ilnhhr1lk 01111IVrrilillI ,_ Plan: CD3-123 (36.3 +12.6) @ 48 90ft (Doyon 19 Project; Western North Slope : MD Refiereiice ', i�`Ialar,,lllloIl, Plan: CD3 -123 (36.3 +12.6) @ 48.90ft (Doyon 19 Sited - CD3 Fiord Pad North Reference : �h�IlghV True ahWell a Ilr r I " Plan: CD3 -123 I1SurveyCafcu1at[oln M Minimum Curvature Welltbore Plan: CD3-123 p ll !; ..... , r u „ti Illi ,,. ,:,��IGI IrIIIIIIrIIIIIIIUN __ - ,••••1•41 ll l Design. C,IIaDG3 123wp03 wG ° II PlannecSurvey o p Vr a I IIP VIII, �' H 7 1V �p @, Io-i III I I I j,I I �I 1::,11111:11141,' r I G I 1 NG�Illil� Ili Me lVIII11111 I II,1 ?,;I I II I (Vertical Me Ma oI VII II ° 1 1 0 1 : I II I' � 111II ° IIrII Depth __ Inclination ''A :° : be pth .,€ TVD + Nt- +E1 W : ? , ortjung I , Basting uIIG Iu ,IlillrVr .DL : � Vatt Sect ; . gill l I (fta t7j t) jftj ft ffq ( a - 6,$6,n7 -- - : - IVd IJI, 9,700.00 63.53 192.00 6,606.05 6,557.15 77.58 - 5,762.48 6,003,939.30 382,175.04 2.00 3,368.77 9,800.00 65.53 192.00 6,649.05 6,600.15 -10.72 - 5,781.25 6,003,851.29 382,154.95 2.00 3,307.21 9,863.98 66.81 192.00 6,674.90 6,626.00 -67.96 - 5,793.42 6,003,794.25 382,141.92 2.00 3,267.29 Base HRZ __ _ 9,877.00 67.07 192.00 6,680.00 6,631.10 -79.68 - 5,795.91 6,003,782.57 382,139.26 2.00 - 3,259.12 Start DLS 3.23 -TFO, -64.01 - -__.- 9,900.00 67.40 191.28 6,688.90 6,640.00 - 100.46 - 5,800.19 6,003,766 382,134.67 3.23 3,244.56 1.3 9,982.72 68.60 188.71 6,719.90 6,671.00 - 175.98 - 5,813.48 6,003,686 382,120.24 3.23 3,190.32 K-1 i -- - :- 1IlIrizl lallll, 10,000.00 68.85 188.17 6,726.17 6,677.27 -191.91 -5,815. 85 O03 82, 17 1 .63 3.23 3,178.63 10,100.00 70.37 185.13 6,761.02 6,712.12 - 284.99 - 5,826.69 K0;00 1 382,105.39 3.23 3,108.60 10,105.61 70.45 184.96 6,762.90 6,714.00 - 290.26 - 5,827.16 6603,572,.50 382,104.85 3.23 - 3,104.55 Top Kuparuk.a - 10,200.00 71.93 182.15 6,793.34 6,744.44 - 379.42 -5,832.69 : = 6,003,483.44'` '` 382,097.98 3.23 3,034.69 10,241.22 72.59 180.94 6,805.90 6,757.00 - 418.67 -5 833= = 61'',003,444,21 382,096.33 3.23 - 3,003.15 - Top__Kuparuk C _ _ ` y l �I101„� -- - 10,251.29 72.75 180.64 6,808.90 6,760.00 -428 28 - 83 6 003,434.61 382,096.05 3.23 2,995.35 LCU -,Top Nuigsut - ;,- i'.G. ,r r 10, 7 3.54 179.22 6,823.03 6,774.13 - 474.89 - 5833.82.' 6,003,388.00 382,095.41 3.23 2,957.13 10,400.00 75.18 176.34 6,849.99 6,801.09 571..1 - 5,83OE0 ` "" 6,003,291.76 382,097.71 3.23 2,876.18 10,477.27 76.48 174.14 6,868.90 6,820.00 5 75,. - 5,823.87 6,003,217.03 382,102.80 3.23 2,811.46 ° 'IIuI , Base Nuigsut _ ; r Q ,9G +ld 10,500.00 76.87 173.50 6,874.14 - 6,825.24 't- 66775 ' - 5,821.49 6,003,195.00 382,104.85 3.23 - 2,792.08 10,600.00 78.58 170.70 6 895..4. .6,846.50 -764.52-:44'-5,808.05 6,003,098.05 382,116.83 3.23 2,705.11 10,700.00 80.32 167.94 6,13.7't 6,864.81 -861.11 - 5,789.83 6,003,001.20 382,133.60 3.23 2,615.53 10,800.00 82.08 165.20 692901. , 1 6,880.11 - 957.22 - 5,766.88 6,002,904.77 382,155.10 3.23 2,523.64 10,851.47 • 83.00 163.81 6,935.69 _ E,886.79 , - 5,753.25 6,002,855.39 382,168.00 3.23 2,475.53 7 x 8 -314" _.^ 10,900.00 83.86 162.49 6,941.24 6,892.34 - 1,052.54 - 5,739.27 6,002,809.05 382,181.28 3.23 2,429.72 11,000.00 85.66 159.80 6,950.38 6,901.48 - 1,146.76 - 5,707.09 6,002,714.37 382,212.04 3.23 2,334.08 11,052.17 86.60 158.40 6,953.90 6,905.00 - 1,195.39 - 5,688.52 6,002,665.47 382,229.88 3.23 2,283.60 Top'Nechelik - 11,100.00 87.46 157.12 6,956.38 6,907.48 - 1,239.59 - 5,670.44 6,002,621.00 382,247.29 3.23 - 2,237.01 11,179.12 88.89 155.00 6,958.90 6,910.00 - 1,311.86 - 5,638.35 6,002,548.27 382,278.29 3.23 - 2,159.41 Start DLS 2.00 TFO -90.12 11,200.00 88.89 154.58 6,959.30 6,910.40 - 1,330.75 - 5,629.46 6,002,529.25 382,286.89 2.00 2,138.84 11,300.00 88.89 152.58 6,961.25 6,912.35 - 1,420.29 - 5,584.97 6,002,439.06 382,330.02 2.00 2,039.98 11,400.00 88.88 150.58 6,963.19 6,914.29 - 1,508.22 - 5,537.40 6,002,350.44 382,376.27 2.00 1,940.66 11,500.00 88.88 148.58 6,965.14 6,916.24 - 1,594.43 - 5,486.78 6,002,263.48 382,425.59 2.00 1,841.01 11,600.00 88.88 146.58 6,967.09 6,918.19 - 1,678.82 - 5,433.18 6,002,178.30 382,477.91 2.00 1,741.13 11,670.63 88.89 145.17 6,968.46 6,919.56 - 1,737.28 - 5,393.56 6,002,119.26 382,516.64 2.00 1,670.52 11,670.78 88.89 145.17 6,968.47 6,919.57 - 1,737.40 - 5,393.48 6,002,119.14 382,516.72 0.00 1,670.38 - - Start 5421.19 hold at MD ' - - - 11,700.00 88.89 145.17 6,969.04 6,920.14 - 1,761.38 - 5,376.79 6,002,094.91 382,533.05 0.00 - 1,641.16 11,800.00 88.89 145.17 6,970.98 6,922.08 - 1,843.45 - 5,319.68 6,002,012.00 382,588.91 0.00 1,541.18 3/12/2010 11:42:14AM Page 6 COMPASS 2003.16 Build 69 • • ConocoPhillips Standard Proposal Report "inf 1 1 °'Ii 11.1.0�1 Well Plan: CD3 123 databa X00 EDM v16 Prod Local C Refere ce: Vlu Company ConocoPhillips(Alaska) Inc. + Reference V'; ; Plan: CD3 -123 (36.3 +12.6) @ 48.90ft (Doyon 19 Project 1 Western North Slope MC? Reference 11 :111 Plan: CD3 -123 (36.3 +12.6) @ 48.90ft ( Doyon 19 :Site: _ CD3 Fiord Pad ;:North Reference: 1'II'p6' VI ? True 'Well Plan: CD3 -123 " 'Su " rve h;u Calation Method l lllll Minimum Curvature Welibare 1 Plan: CD3 -123 10 Desi n CD3 - 03 9 , - ' 11 Planned S urvey 11 1 11r 1 "111 a �i ll I Vi i i s. 1d' ",1 r i i i l ll l l , 1 1'� Measured 11 Vertical Ma 1 u Ma ' 1 1 ' Illll II I P I p .VI 'c � er 4 utiulll�l, Depth Inclination Azimuth Depth TVI ss 1 +Nt-S rEt-W : Northing I �' n,lull, Illly'Il Easting DLS 1iµ Vt, Section I I i (ftl p t , °) (ft) ft I� (f 1 iftff - 11pU I IC I' 6,924 _ . 11,900.00 88.89 145.17 6,972.93 6,924.03 - 1,925.52 - 5,262.58 6,001,929.09 382,644.77 0.00 - 1,441.2 u I,I,1 V 'Villll V V i 1� o 1 ' , .. - . . . ' ; :rr. . i.dIIIV6'11 = .., = 0 . 12,000.00 88.89 145.17 6,974.87 6,925.97 - 2,007.59 - 5,205.47 6,001,846.18 382,700.64 0.00 - 1,341.22 12,100.00 88.89 145.17 6,976.82 6,927.92 - 2,089.65 - 5,148.36 6,001,763.27 382,756.50 0.00 - 1,241.24 12,200.00 88.89 145.17 6,978.76 6,929.86 - 2,171.72 - 5,091.26 6,001,680.37 382,812.36 0.00 - 1,141.26 12,300.00 88.89 145.17 6,980.71 6,931.81 - 2,253.79 - 5,034.15 6,001,597.46 382,868.23 0.00 - 1,041.28 12,400.00 88.89 145.17 6,982.65 6,933.75 - 2,335.85 - 4,977.04 6,001,514.55 382,924.09 0.00 - 941.30 12,500.00 88.89 145.17 6,984.60 6,935.70 - 2,417.92 - 4,919.94 6,001,431 382,979.95 0.00 - 841.31 12,600.00 88.89 145.17 6,986.54 6,937.64 - 2,499.99 - 4,862.83 6,001,346J8:10.. 383,035.82 0.00 - 741.33 12,700.00 88.89 145.17 6,988.49 6,939.59 - 2,582.06 - 4,805.72 „ 6,001,265,8301 11 1, 11 1100 0 383,091.68 0.00 - 641.35 12,800.00 88.89 145.17 6,990.43 6,941.53 - 2,664.12 - 4,748.62 1 6 001 182.92 111 0.00 - 541.37 1 12,900.00 88.89 145.17 6,992.38 6,943.48 - 2,746.19 - 4,691.51 6,00,1,100.07 35,, 0.00 - 441.39 13,000.00 88.89 145.17 6,994.32 6,945.42 - 2,828.26 - 4,634.40 6,001,0'17.10 ' 383,259.27 0.00 - 341.41 13,100.00 88.89 145.17 6,996.27 6,947.37 - 2,910.33 -4 577 30 6,000,834.0. 383,315.13 0.00 - 241.43 13,200.00 88.89 145.17 6,998.21 6,949.31 2,992.39 -4,520,180 - 383,371.00 0.00 - 141.45 13,300.00 88.89 145.17 7,000.16 6,951.26 - 3,074.46 -4,463.084K-0 383,426.86 0.00 -41.47 13,400.00 88.89 145.17 7,002.10 6,953.20 - 3,156.53 -4 40598 ` 6,000,685.47 383,482.72 0.00 58.51 13,500.00 88.89 145.17 7,004.05 6,955.15 - 3,238.60 4,348.67 6,000,602.56 383,538.59 0.00 158.49 13,600.00 88.89 145.17 7,005.99 6,957.09 - 3,320,66 - 4,251`.76!!„ 6,000,519.65 383,594.45 0.00 258.47 13,700.00 88.89 145.17 7,007.94 6,959.04 - 3,402.73 -4,234.0p01010006,000,436.74 383,650.31 0.00 358.45 13,800.00 88.89 145.17 7,009.88 6,960.98 _A73,464:60 -4,177.65 6,000,353.83 383,706.18 0.00 458.43 13,900.00 88.89 145.17 7,011.83 6,962.93 3,,58686 -.- 4,120.44 6,000,270.93 383,762.04 0.00 558.41 14,000.00 88.89 145.17 7,013.77 - 6 964.87 4 0uo 1 3 ,1 , 648.93 4,063.34 6,000,188.02 383,817.90 0.00 658.40 14,100.00 88.89 145.17 7,015,72 6,966.82 ,731.00 ,1- 4,006.23 6,000,105.11 383,873.77 0.00 758.38 14,200.00 88.89 145.17 7 017 66,6,968.76 -3,813.07 ' - 3,949.12 6,000,022.20 383,929.63 0.00 858.36 14,300.00 88.89 145.17 7,0"19.60 ".;,6,970.70 - 3,895.13 - 3,892.02 5,999,939.29 383,985.49 0.00 958.34 14,400.00 88.89 145.17 7,021.551_ „6,672:65 - 3,977.20 - 3,834.91 5,999,856.38 384,041.36 0.00 1,058.32 14,500.00 88.89 145.17 7,023.49 -- - 6,,874:59„ - - 4,059.27 - 3,777.80 5,999,773.48 384,097.22 0.00 1,158.30 14,600.00 88.89 145.17 7,025.44 6,978,54 - 4,141.34 - 3,720.70 5,999,690.57 384,153.08 0.00 1,258.28 14,700.00 88.89 145.17 7,027.38 6,978.48 - 4,223.40 - 3,663.59 5,999,607.66 384,208.95 0.00 1,358.26 14,777.90 88.89 145.17 7,028.90 6,980.00 - 4,287.33 - 3,619.11 5,999,543.08 384,252.46 0.00 1,436.14 Base Nechelik 14,800.00 88.89 145.17 7,029.33 6,980.43 - 4,305.47 - 3,606.48 5,999,524.75 384,264.81 0.00 1,458.24 14,900.00 88.89 145.17 7,031.27 6,982.37 - 4,387.54 - 3,549.38 5,999,441.84 384,320.67 0.00 1,558.22 15,000.00 88.89 145.17 7,033.22 6,984.32 - 4,469.61 - 3,492.27 5,999,358.93 384,376.54 0.00 1,658.20 15,100.00 88.89 145.17 7,035.16 6,986.26 - 4,551.67 - 3,435.16 5,999,276.03 384,432.40 0.00 1,758.18 15,200.00 88.89 145.17 7,037.11 6,988.21 - 4,633.74 - 3,378.06 5,999,193.12 384,488.27 0.00 1,858.16 15,300.00 88.89 145.17 7,039.05 6,990.15 - 4,715.81 - 3,320.95 5,999,110.21 384,544.13 0.00 1,958.14 15,400.00 88.89 145.17 7,041.00 6,992.10 - 4,797.87 - 3,263.84 5,999,027.30 384,599.99 0.00 2,058.12 15,500.00 88.89 145.17 7,042.94 6,994.04 - 4,879.94 - 3,206.74 5,998,944.39 384,655.86 0.00 2,158.11 15,600.00 88.89 145.17 7,044.89 6,995.99 - 4,962.01 - 3,149.63 5,998,861.49 384,711.72 0.00 2,258.09 15,700.00 88.89 145.17 7,046.83 6,997.93 - 5,044.08 - 3,092.52 5,998,778.58 384,767.58 0.00 2,358.07 15,800.00 88.89 145.17 7,048.78 6,999.88 - 5,126.14 - 3,035.42 5,998,695.67 384,823.45 0.00 2,458.05 15,900.00 88.89 145.17 7,050.72 7,001.82 - 5,208.21 - 2,978.31 5,998,612.76 384,879.31 0.00 2,558.03 16,000.00 88.89 145.17 7,052.67 7,003.77 - 5,290.28 - 2,921.20 5,998,529.85 384,935.17 0.00 2,658.01 16,100.00 88.89 145.17 7,054.61 7,005.71 - 5,372.35 - 2,864.10 5,998,446.94 384,991.04 0.00 2,757.99 3/12/2010 11:42:14AM Page 7 COMPASS 2003.16 Build 69 40 • Conoco Phillips HALLIBURT0r4 Standard Proposal Report 11 Database: EDM v16 Prod '- ff-10c.1- i 'L---- ;i01• 1 C 111 4 : 41.;Riete Reference: Well Plan: CD3-123 Company: ConocoPhillips(Alaska) Inc. IVD !Rele re1iCe r --- ',' Plan: CD3-123 (36.3+12.6) @ 48.90ft (Doyon 19 Project Western North Slope ' ' ''::: : '--:' --' :: ' Plan: CD3-123 (36.3+12.6) @ 48.90ft (Doyon 19 :1 :j,4,,H::,,:: ,,,,,,,-, lite: - --- ' - CD3 Fiord Pad ::1NoittiRereiteticar-m=_:=_,-'_"rliiiiiiiLiiii.,i',,,,,,--;-,_..-,.,-: True ': 'ilk th dH'L' iirici4Calf04 F,,„„ 9 ' Minimum Curvature ------------=: 1 ..,)(liAlk16'!4i:,' Plan: c°3 iAleilbOeil H "-,1! ! ','':l Plan: CD3-123 Design: -------. ::, CD3-123wp03 P . tn40,illiiiiiiililil',-1-,T--, Depth Measured .. 11------:f11.-:-: : ' : :::::::-:1°W:::iiii-,-;::":1:1110Qiii10, iii-L4Vr)4,,H17.Aigr::-.Z2-1-'':::i---I:: 1 1------ iiied Va ' '-"_ '1 ',"-::!-! ::::. -.--------::::-.- --::: - ''' ',, , , --- -.....,,.!. .':H:' '''"'::" '",- ''1='=' : -_:-. '': Northing - ' Map --:- '-itLS - - - - - -{f-c‘retiSeCilOti , :i'-W Depth Inclination Azimuth th: ,, - .. - -..-7-vces + ,-_-_----_---- - :.!14if-S _-_-_-] -_,-: ..1.E.AW . -. _ .-_-.- , ::: .:: -----..,-,==-,,,==:-----,:t::::v.,.-.:= ':::::-::01::: ::'::'" -------- ---'--------- -: :'.- fro: ------- - - : "oil': : : ::': --- fo ):::::::::::::: .-. -,..--..-..-,-...,---,-.(::,.:::::::::::::. (ft) .........ry„,..:,::::: .........::.: :'.:-.-.-. :-( - :-- -,,-,---te--,.:- ,:.1 .. .- ---_- ,-:-, ..,- 16,200.00 88.89 145.17 7,056.56 7,007.66 -5,454.41 -2,806.99 5,998,364.04 385,046.90 0.00 2,857.97 16,300.00 88.89 145.17 7,058.50 7,009.60 -5,536.48 -2,749.88 5,998,281.13 385,102.76 0.00 2,957.95 16,400.00 88.89 145.17 7,060.45 7,011.55 -5,618.55 -2,692.78 5,998,198.22 385,158.63 0.00 3,057.93 16,500.00 88.89 145.17 7,062.39 7,013.49 -5,700.62 -2,635.67 5,998,115.31 385,214.49 0.00 3,157.91 16,600.00 88.89 145.17 7,064.34 7,015.44 -5,782.68 -2,578.56 5,998,032.40 385,270.35 0.00 3,257.89 16,700.00 88.89 145.17 7,066.28 7,017.38 -5,864.75 -2,521.46 5,997,949.49 385,326.22 0.00 3,357.87 16,800.00 88.89 145.17 7,068.23 7,019.33 -5,946.82 -2,464.35 5,997,86A9 - - 385,382.08 0.00 3,457.85 16,900.00 88.89 145.17 7,070.17 7,021.27 -6,028.88 -2,407.24 5,997,783 - 385,437.94 0.00 3,557.83 17,000.00 88.89 145.17 7,072.12 7,023.22 -6,110.95 -2,350.14 5,997,700:.77: . 385,493.81 0.00 3,657.82 • 17,091.54 88.89 145.17 7,073.90 . 7,025.00 -6,186.08 -2,297.86 ,,''5,9R7:,,624.8-'/,!'-'H.,. b. oo 3,749.34 CD3'A23iip03 Toe Targets -Ii..::::.:ORM:=-'74111;::$00kr!;f:?---;:;'-'=---- -.- lihi411,101101Ph'.7-*Til.,1 l':4i9et-,r140:-' _ -. 7' - . - ;- - - - - - - : ;= c -: - - --- '''' .. -_ -- T.'57:lifig: :: '-' - .:: '-' ' -:-'- ' - '!-:1: f l ''' - * : : - '...:-= - F. - . - - Northing. gai4 -''--.shitih...n',i4ii).!ij;',"',r,,1!r;-:'-':'il''':i'---i:-:-.------:--'i'j'':':':'-':''.'-''--::::j1=--II-----s-'5-----''L'Ill':'";:'-'''':::-':"-1::::''-''L-1::!''''----L-''--'t''':::'''!-?'?-"'''fi"l!':''':'-'-:':'"':)'''Pr'D} D i r.. : -''''''''' '' ' '''''' ----1 ' ' ' ' '' '' '''' '' ''' '' ' ' '' '' ' '' ''''' ''' ' ' ' ' ' ''' '' ' ' ';":':;4 : 1111111 ' = " -- ' ---L--' ''' 11-(1!.11Ai:],i ' t- : ,--- " 1--,,---------i0 ::" !' " 11$111,-, " ,-,:--,---'1,'Ll ' I' ' :",h1,1, '" :- ' ,i- _ - _':' - ' „I'(4 " )„11:1I I'll'il' ,1', i' Ej.ilill,'„',,,--„ ':' ,. '" il .,. .1." CD3-123wp03 Toe 0.00 0.00 H,!:-7,073.90 - _ :il -2,297.86 5,997,624.87 385,544.94 - plan hits target center - Circle (radius 100.00) CD3-123wp03 Heel 0.00 -= -.6,958.90 -1,243.45 -5,662.58 6,002,617.03 382,255.08 - plan misses target center by 6.15ft at 11106.7811 yD16956 , : , 124 , 5.83 N, -5667.79 E) - Circle (radius 100.00) - - - .- . Casing PaiPts--------------.--......____.---.-- aii 0 ,...a0 i.ilisii:iiiirit,-,:j':':'41;tti-ijt:diiZ: ::[„; ,::411::::,E_''-',:' -1,:::,,:-.1.-----t-,:10:----7---::lh::ilWI_F:1-:W- :: ': ' ' , :. , - '''' ''''''''''' '''iNV!"-' : '.' - ''.."-." - 1 -- .".'-'2 = _ --- - : - : , -- - --)MIWZ -- t- -- _ -!- T : : ' ote:,-, Depth ..:-.-.-,...;:.: Depth: :F --''-----' .-- --. ; .- ..-1 - - --- ' 1 ''-'.:7:it. --- - .-------::::-- - - -- 4 -,, ,- - - - "i:,T , ,,i,:-,...;,...,,O.mi - i=j - -, ''.HlIIIII1lAj __-==:-Li:-.,..--- !,10,.5..,.:-._ ,,..,...,:-..::-.---.-,.--:;-----,------,,--,--?.:.,:,.:::::::::: :: :. :- ---_-_-- ...- 7177,M.:1::-..:,, (ft) : -::-- ] - :-::: -t a(ft/ ' -- E:31.f.' . :: :!:. t-....::,::irofil, ::.:.-..: , .E.. , ..:4- -- -4,--- - ....::::::: --- ,,...,..., ,-.- 2,851.86 2,470.00 9-5/8' tvl2-1/4" 9-5/8 12-1/4 10,851.47 6,935.69 7" x 8-3/4 7 8-3/4 - 17,091.96 7,073.91 4-1/2" x 6-1/8" 4-1/2 6-1/8 3/12/2010 1142:14AM Page 8 COMPASS 2003.16 Build 69 .:?--, 1\d 1 iL S • ConocoPhillips Standard Proposal Report Database EDM v16 Pro . . , , ,.w., , ,u6,,,,,,,,,,,,, ,". local C o - ordinate Re fere n ce Well Plan: CD3 - 12 3 " ° "ullllll whrl IIII''' �. wP,lllllnl,Gl,l Il Com "' " ' ConocoPhillips(Alaska) Inc. -YVD Reference i'I Plan: CD3 -123 (36.3 +12.6) @ 48.90ft (Doyon 19 Project: Western North Slope MD R Plan: CD3 123 (36.3 +12.6) @ 48.90ft ( Doyon 19 'ill Site: CD3 Fiord Pad I North Reference G„ True Well Plan: CD3 -123 SurveyCalculation MIfethod: " U Minimum Curvature .Wellbore III : Plan: CD3 - 123 Des 1gr1 luu I, . I IIIpI CD3-123wp03 ,, .. - Formations „„ gll Mlleasure Vert I , Vertical I Dip ii D epth Depth . Depth SS I ' Dip Direction i t) _ (lit) Name I Litho -- � I ( ' . ' .... . II I I 9,863.98 6,674.90 Base HRZ 5,573.97 4,145.90 K -2 Basal 9,982.72 6,719.90 K -1 7,652.14 5,413.90 Albian 97 1,262.51 1,248.90 Base Permafrost 10,251.29 6,808.90 LCU 5,403.42 4,040.90 K -2 3,499.78 2,868.90 C -20 5,361.19 4,014.90 K -3 Basal I I I II 10,477.27 6,868.90 Base Nuiqsut IIhI i,Il P li , lhp .,. 14,777.90 7,028.90 Base Nechelik 2,622.67 2,328.90 C-40 II , I NI " 10,241.22 6,805.90 Top Kuparuk C rriI ,. 8,363.37 5,848.90 Albian 96 11,052.17 6,953.90 Top Nechelik ' 2,879.31 2,486.90 C -30 II - 5,127.30 3,870.90 K-3 -;'," __i .------- - :-:!wiiiii 10,105.61 6,762.90 Top Kuparuk D I p, 10,251.29 6,808.90 Top Nuiqsut II ,,i 9,566.76 6,543.90 Top HRZ @I,,, Plan I , _ 1 PI 5 I IP li4lul = '*' mil I, -s, F 001 }Ir I yyIIil1li, is Y� I,I�I�lijlu _ I'hIIII Measured 4VertiCar I Lp rdi t yti Depth +N/ Depth I � ,�Iu�Ill�IIIIII,g�6 {R _ � _ FIIIII -^, t -_ (ft om n met h .. :.- - �, " � . ..... .. .... .. _ ... . �� . ..vim ... .- ..��� �. 370.00 370.00 - 400 " 0.00 Start Build 1.50 600.14 600.00 446" X1 1 -5.31 Start Build 2.20 1,107.21 1,100.00 55.53 ° " "66.18 Start DLS 2.75 TFO -31.86 2,528.00 2,270.61 326.17 - . - -_-_M". - . - ' - 771.77 Start 3945.98 hold at 2528.00 MD 6,473.98 4,700.00 1,130.96 - 3,775.29 Start DLS 1.50 TFO -90.00 7,673.98 5,426.70 1,191.12 - 4,722.11 Start DLS 3.12 TFO - 105.64 9,548.58 6,535.00 208.36 - 5,734.68 Start DLS 2.00 TFO 0.00 9,877.00 6,680.00 -79.68 - 5,795.91 Start DLS 3.23 TFO -64.01 11 ,179.12 6,958.90 - 1,311.86 - 5,638.35 Start DLS 2.00 TFO -90.12 11,670.78 6,968.47 - 1,737.40 - 5,393.48 Start 5421.19 hold at 11670.78 MD 17,091.96 TD at 17091.96 3/12/2010 11:42:14AM Page 9 COMPASS 2003.16 Build 69 • 1! F V I I II II p II I 4 � 1 ConocoPhillips(Alaska) Inc. -WNS 4 ConocoPhillips( as a) Western North Slope ifi 1 CD3 Fiord Pad Plan: CD3 -123 1II Plan: CD3 -123 p 1 CD3- 123wp03 1 i, 1I , 1ul l 11 1 11 1 Ik ICI I 4 I ll ills III I..... !4111Il� I pipyQil I 1 P 1'i �I h �1 Sperry Drilling S r „I 111x X 11 _ 1 1 1 111; ,I�,u 0 1 Clearance Summa II III I i��e .� I r Risk . Anticollision Report .„„ .�, --"1 11 1 ti 1 I I 71 11 March, 2010 �1 1 01111111 Tray. Cylinder North Proximity Scan Q IIM c urrent Survey Data (North Reference) Ill Ig Reference Design: CD3 Fiord Pad Plan CD3 -123 - Plan: CD3 -123 - CD3- 123wp03 II I �1� Well Coordinates: 6,003,522.43 N, 1,527,967 „E (70 ° 08.14” N, 150° 54' 57.93" W) Ih Datum Height: Plan: CD3 -123 (36.3 +12.6) @ 48.9(Ift (Doyon 19) • Scan Range: 0.00 to 17,091.96 ft. Measured l p th. h9 1 Scan Radius is 1,905.57 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited l ° Geodetic Scale Factor Applied V I I 1 1 I IiIi Version: 2003.16 Build: 69 11 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference fl II Scan Type: +254Q0 1 11111 111 7 1-1ALLIEILIRTOP41 Ilialler :_•.. V4 Sperry Drilling Services x tI @ I, ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -123 - CD3- 123wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -123 - Plan: CD3 -123 - CD3- 123wp03 Scan Range: 0.00 to 17,091.96 ft. Measured Depth. Scan Radius is 1,905.57 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) • (ft) (ft) ft CD3 Fiord Pad O ";' + - CD3 -111 - CD3 -111 - CD3 -111 519.01 235.50 519.01 224.63' 25.00 21.664 Centre Distance Pass - Major Risk • CD3 -111 - CD3 -111 - CD3 -111 591.35 235.94 591.35 223:78 -_ 600.00 - - 19.401 Clearance Factor Pass - Major Risk CD3 -111 -CD3-111L1 - CD3 -111 L1 519.01 235.50 519.01 224.63 ;, 525 00 - 21.664 Centre Distance Pass - Major Risk CD3 -111 - CD3-111L1 - CD3-111L1 591.35 235.94 591.35 223.78'. 600.00 19.401 Clearance Factor Pass - Major Risk CD3 -112 - CD3 -112 - CD3 -112 1,372.29 205.05 1,372.29 179.06', 1;425.00 7.890 Centre Distance Pass - Major Risk CD3 -112 - CD3 -112 - CD3 -112 1,418.20 205.45 1,41820 � l � i i,u 178.65 , t,:::::::!1,475.00 7.666 Clearance Factor Pass - Major Risk Ii CD3 -113 - CD3 -113 - CD3 -113 149.00 199.27 149.00 1 23 +, 150.00 65.446 Centre Distance Pass - Major Risk I CD3 -113 - CD3 -113 - CD3 -113 470.69 200.96 470.89 .'190$0 475.00 19.994 Clearance Factor Pass - Major Risk CD3 -114 - CD3 -114 - CD3 -114 373.75 179.48 373:75 171.55:::,::::::" " 375.00 22.630 Centre Distance Pass - Major Risk Past ', Majat Risk 0p3.4115 i 3 -115 - CD3 115 9,861.15 ,452,32 2 8 63 11 452;82 4 , , 71 9,300M); ,500,00 3,032 Centre Distance Factor Pass - _Major Risk: ,CD3 -1 -'15 - C01'�-1 "i5„ CD3 -115 1,475.90 81.7,�8i '&475.90 :: " 5459 1,525.00 3.008 Clearance Factor Pass - _Major_, Risk r ""°' CD3 -117 - CD3 -117 - CD3 -117 857.18 ---- . 97 33 HHH 857.18 79.03 875.00 5.319 Centre Distance Pass - Major Risk c CD3 -117 - CD3 -117 - CD3 -117 880.62- - $ 97.37=, X80.62 78.70 900.00 5.215 Clearance Factor Pass - Major Risk 57 00 r54 36.53 1,^ V 2,785 tlleara PPSS - Major r CD3 918 CDC 1"18 1 18 91 450:'00 8.18 2.841 Centre Distane,�� Pass - Major Risk ' Ci -118 CD3118 1010,3 "1,08 - ilp'uPli,l 56 84 51 38.83' 1;11()P,00 125r0q Clearance Factof jor Risk 9,22 CD2122 451 �„ 1 4 50 , 450 00 1.937 .Centre Distance Pass - Major Risk 00 9,1 . 3-122 CD -', 122 � CI08 -122 599.6, . � I 1 599a 5, 46 801E00. 1,555 ,,Clearanee Factor P -a$s Major Rsk • CD3 -124 -CD3 124 -CD3 -124 36.40 � ' ; Vjlll l l 1 19 .99 36.40 19.03 36.79 20.821 Centre Distance Pass - Major Risk D3 -124 - CD3 " - 124;, 4 CD3 -124 575. il 1 l24.76 575.34 1241 575.00 2421 Clearance Factor Pass - Major Risk; CD3 -316 - CD3 -316 - CD3 -316 569.56 138.15 569.56 126.50 575.00 11.863 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316 - CD3 -316 593.86 138.32 593.86 126.27 600.00 11.485 Clearance Factor Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 569.56 138.15 569.56 126.50 575.00 11.863 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 593.86 138.32 593.86 126.27 600.00 11.485 Clearance Factor Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 569.56 138.15 569.56 126.50 575.00 11.863 Centre Distance Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 593.86 138.32 593.86 126.27 600.00 11.485 Clearance Factor Pass - Major Risk Plan: CD3 -119 - Plan: CD3 -119 - CD3- 119wp02 224.80 79.87 224.80 75.24 225.00 17.244 Centre Distance Pass - Major Risk Plan: CD3 -119 - Plan: CD3 -119 - CD3- 119wp02 448.79 81.04 448.79 71.53 450.00 8.525 Clearance Factor Pass - Major Risk 11 March, 2010 - 16:15 Page 2 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -123 - CD3- 123wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -123 - Plan: CD3 -123 - CD3- 123wp03 Scan Range: 0.00 to 17,091.96 ft. Measured Depth. Scan Radius is 1,905.57 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp03 374.95 59.75 374.95 51.86 375.00 7.573 Centre Distance Pass - Major Risk Plan: CD3 -120 Plan: CD3 120 CD3- 120wp03 548.37 61.61 548.37 49.94 III'6' °1 550.00 5.279 Clearance Factor Pass - Major Risk Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp02 374.75 59.75 374.75 51.86 375.00 7.576 Centre Distance Pass - Major Risk • Plan: CD3 -120 - Plan: CD3 -120 - CD3- 120wp02 548.18 61.60 548.18 49.94 550,00 5.280 Clearance Factor Pass - Major Risk Plan: CD3 -125 - Plan: CD3 -125 - CD3- 125wp02 549.94 37.49 549.94 25 7£L_ 559.00 T li 3.203 Centre Distance Pass - Major Risk Plan: CI:*125:= Plan: CO37125 • CD34'125wp02 599471^ 38 :20 599 :47 'arr _ 60Q j 12 -_ 2:986 Clearance Factor Pass = `Major Risk Plan: CD3 -126 - Plan: CD3 -126 - CD3- 126wp02 600.73 59.09 600.73 46'.:2 600.00 4.617 Centre Distance Pass - Major Risk 648.60 1 ' l i�ilil , l i �l� 9, i Factor Pass -Major Risk Rig: CD3�121 Rig. CD3- -121 6 CD3 - 121 R_gSurvey 5 48 . 60 3 650.35 1l l i 111 CI S 6 00 3 ' C e ntre Di s t ance. Pass - Major Risk Plan: CD3 la Rigr - CD3 121 4 RIM' D133.121 - CD3 - 121 RigSurveys 623.21. -35.24 6230 ' , 625 : 00 2,921 "Clearance Factor Pass •_Major Risk, [TA Rig: CD3 -121 - Rig: CD3 -121 - CD3 -121 wp03 400.00 39.93 400:00 32,20: 400.00 5.168 Centre Distance Pass - Major Risk ,� Rig: CD3 -121 - Rig: CD3 -121 - CD3 -121 wp03 623.48 4221 , 623:48 30 :e 625.00 3.491 Clearance Factor Pass - Major Risk 4 ,aa i "�" Note: Deeper than Survey tool oroaram usual . From To " "'�I 1 'ipl9llll Survey /Plan Survey Tool • (ft) (ft) 1111111 �Vf, 36.30 09 .00 CD3123wp03 i , l , il „ r CB- GYRO -SS 1,236.30 17 1.96 CD3- 123wp03 I '__ MWD +IFR- AK- CAZ -SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 11 March, 2010 - 16:15 Page 3 of 5 COMPASS GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10 :14, March 12 2010 CD3- 123wp03 Ellipsoid Color 36.30 To 17091.96 36 250 1750 2250 7750 9250 21250 22250 (Major Risk 250 500 2250 2750 9250 750 2750 11750 22250 23250 ICD3 121wp03 500 3500 11750 14250 23250 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 CD3- 120wp021 1000 -- 1250 4250 5250 16250 — 18250 1250 1500 5250 6250 18250 19750 -30 / 330 Ail, - . 30, _ / _ , CD3 120wp031 1500 1750 6250 7750 19750 21250 , 441 / 4 0P- ICD3- 119wp02 201 I „ ICD3 -112 • A f CD3 -111L1 -60 / 300 f� �� ^ '� ' 0/360 Q , i CD3 - 11 -30 / 330 50 30 D V 5 1 r _ ° .a�' ` '• CD3 -121 RigSurveysi CD3 - 121 RigS�� M • \ ' ICD3 -122 (�� I���A� o 1`' 60 / 300 60 , `�+ i g��1k�� , , /-/ pp r m' r P • ���� \ �� � � / CD3 -121w 03 w ,af,�.'m r /.� A 4.0 1 Jam - - + `�, _90 / 270 --_1 z i ° u b ' ... 01fir + v 7' 1 r 90 ; w o h F � ' .■'�� 1 .. - 0 10!",„ 4 „1,0101,10-11 3 r , ggg K fi , �������� I � � � �� i �C r �s � ' y r� a�] ' � ,, `,it ?fa €`! �1 ' / I .,�� p Ir ti a n r� CD3 -122 { . y t . z 5 ` ., 1 '' R e� 'V - tt: a 10 v 90 / 27 90 !- � + l i► `CD3 -113 i� r „�, � . �, � e !`' ICD3 -1141 , i /t 4. d } ! r , S � 1' - t, �d f , 4 a vl 3 �1 ���� : h s : � c CD3 -316 I IE '/ `'t }. F as a /frA v i1J° v, V �C�2 �ti ''''t• �J 120/240 r �� , .4 atill,+ " 120 �,, Ci e ° j 1s�� 4 ffi / a � 9h � i r .: > , , CD3 -316A 120 / 240 1 i 4 � a 7 � 0�+��ti it 120 i �r ► .,��f. � i — a "7 0J IC D3- 316APB1I \ Ai`�!'�ii1 l ®� � \ f OM Afar i . '� . [ a ®" \ � �� r � 1 / CD3 125w 02 �� .® �� \ \ _ l. � l � 10/ �Ilh`` • � ; �i I p - 150 / 21 t'� �` ", � e 50 -150 /21� �, �� i�,� 150 CD3- 126wp02 CO3 -124 , � � t . v..' I -180 / 180 I CD3 -1241 ;18b'L 180 CD3- 125wp02 ICD3 -1181 1CD3 -1171 ICD3 -1151 Travelling Cylinder Azimuth (TFO+AZI) [O] vs Centre to Centre Separation [25 ft/in] Easting (3000 ft/in) I I I I I I I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I I I I I I I I I I I I I I I I milliiilmillIIIIIIIIIIIIIIIIIIIIIIIIiiIIIIIJ — - 10 , March 12 2010 t ONLY �/ CD3- 126wp02 _ . C w 13 er I ls O L T CD3- 125wp02 _ (NOT a Spider) • CD3-111L1 CD3 -111 - CD3 -112 • - CD3113 ; III l - - - CD3 -114 - - Z c o -- S 8 _ CD3 -118 CD3 -115 cl CD3 -117 = 0 ` ■ t - - CD3-124 - - . _. .___ . : ,____.:47:11:_i 1 I 1:_l_111_,;.„ _____ ,1 .:, ' ' '' . . : : ._ . _ . ' :_. ,_ -_i : ; : .., ;11,!0,. . 4!111 411111111m illi - ''` • 1 RigSurveys CD3- 316APB i —'` CD3 -316 CD3-318A • I lip u, i �� ►� CD3- 120wp03 CD3- 119wp02 CD3- 121wp03 = — ConocoPhililps(Alaska) Inc. -WNS _ Western North Slope CD3 - 122 = - CD3 Fiord Pad = CD3- 123wp03 I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I 1 I I I I I I 1 I I I I I I I Easting (3000 ft/in) ! 0 ii p H LLIBURTON C©noc llips CD3- 123wp03 M . - . Alaska Sperry Drilling ANTI - COLLISION SETTINGS 16:18, March 11 2010 Interpolation Method: MD, interval: 25.00 Major Risk Depth Range From: 36.30 To 17091.96 Results Limited By: Centre Distance: 1905.57 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey /Plan Tool 36.30 1200.00 CD3- 123wp03 (Plan: CD3 -123) CB- GYRO -SS 1200.00 17091.96 CD3- 123wp03 (Plan: CD3 -123) MWD +IFR- AK- CAZ -SC CASING DETAILS TVD MD Name Size 2470.00 2851.86 9 -5/8" x 12-1/4" 9 -5/8 6935.69 10851.47 7" x 8 -3/4" 7 7073.90 17091.96 4-1/2" x 6-1/8" 4-1/2 NA IN III I I I - _ OCD 33 3 NMI N N . N 00:0 U 0 U U IIJ'I _ ' =IIIII1IIIIIIIIIp'' Ip,,1l I 414l�� IU I II I' gii !111111 1141 1114 , a) -- .4411111 , 11/ 0 ;001f I HL ,, '-- fi= ' 4' , 1 _. .... ..����� I I!, � � = H ,._.,....... _ , I . _ - ui iEu u u uu uuiii fili l� I l i' ip _ , ,, -. !,111i111Illlllllli11 II __ 0 I , I 1 I I I I I I 1 ` _ .1 I 1 I 1 i 1 1 1 I 1 i 1 1 1 1 1 1 i 1 1 i i i 0 450 900 1350 1800 2250 2700 Measured Depth LEGEND -e- Plan: CD3 -126, Plan: CO3 -126, CD3- 126wp02 VO O CD3 -115, CD3 -115, CD3 -115 VO $ Plan: CO3 -125, Plan: CD3 -125, CD3- 125wp02 V0-0- Plan: CD3 -120, Plan: CD3 -120, CD3- 120wp03 VO -j- Plan: CD3 -119, Plan: CD3 -119, CD3- 119wp02 VO X CD3 -113, CO3 -113, CD3 -113 V6 - CD3 -114, CD3 -114, CD3 -114 V14 -e- Rig: CD3 -121, Rig: CD3 -121, CD3 -121 RigSurveys VO --A- CD3 -111, CD3- 111L1, CD3 -111L1 V1 --- CD3 -316, CD3 -316, CD3 -316 VO -2A- CD3 -117, CO3 -117, CD3 -117 VO -B- CD3- 123wp03 CD3 -111, CD3.111, CD3 -111 V7 --t- CD3 -316, CD3- 316APB1, CD3- 316APB1 VO --T- CD3 -118, CD3 -118, CD3 -118 VO -B- Rig: CD3 -121, Rig: CD3 -121, CD3- 121wp03 VO -B- CD3 -316, CO3 -316A, CD3-316A V0 -F CO3 -122, CD3 -122, CD3 -122 VO Q CD3 -112, CD3 -112, CD3 -112 V3 -e - Plan: CD3 -120, Plan: CD3 -120, CO3- 120wp02 V0-B- CD3 -124, CD3 -124, CD3 -124 VO 9 ,'''5 ! tx R r r � k GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10:27, March 12 2010 CD3- 123wpO3 Ellipsoid Color 36.30 To 500.00 36 – " "' 250 1750 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 -- - -- 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 – - 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 - -" " "" 1750 6250 7750 19750 21250 201 • -60 / 300 60 "IN 0/360 __ 50 1 !1 , 1,0 , - -30 / 330 30 CI -2 CD3 -121 Rig meys o3 r664 t a a .t CD 111L1 1►.,�� 1 w r ii - iii _ CD3 -121 RME r � �FF � _ , � IC D3 111 -60 / 300 60 'iC�� n c ` D3 -122 - 9 0/270 � 90 / /74,= CD3 -122 a i �f i \ CD3- 121wp03 /�( ')) w CD3 -3 �� d — gg \ - CD3 -11 D3 -117 � �' \ ��f , .�. 03 -124 t %% I�( � \i ii %/ CD -90 - 90/270 / li s P 90 rya "` it 101 IL; d i. 1 i -120 / 240 120 CD3 -124 -120 / 240 120 • 200 CD 3-125w w. C 3 5 - 150 / 210 150 -150 / 210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10:27, March 12 2010 CD3- 123wp03 Ellipsoid Color 500.00 To 1000,00 36 250 1750 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 _ – 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 _ 5250 16250 — 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 200 -60 / 300 60 w pia i iliiii,„ 0 / 360 CD3 -111 L1 50 CD3- 121wp0 rN � , u, "I IIII 30 / 330 30 ii, _ - CD3 -121 Ri Surve s it 4 � a.,.�.w✓ 9 Y D3121 Ri S CD3 -122 g _, 3 111 M ��: �� 1133,3 3 -11 ��, CD3 1 t �� � i $ w �rlAl, - / 300`. 60 CD3- 121wp03 r i k..,,.; 90 / 270 � iF a�aK krir I ,, 90 ', riS, ,, � ' 1 III 'i �� •.w .i, 3 316 ' -... , ',••••74-(..... w C 311 [ .. ' V -_-_, 90/270 P � � ��� � . 90 .i CD3 -124 1 �� ,z' ] b3117 St PI q CD3 - 316 ; ' :1 O L \ CD3 125w pi \ \ ,' ,, � j' � � \ ° / 120 /240 120 ,„ ,� � O' �� - • 120 / 240 1 CD3 -126w. i 1:i ®��a � � 0144 I � mark �� 120 20 t Si r ital �+ ��� -150 / 210 -411 � 150 -150 /210 150 • -180 / 180 300 CD3 -124 -180 / 180 CD3- 125wp02 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10:28, March 12 2010 CD3- 123wp03 Ellipsoid Color 1000.00 To 1 500.00 36 250 1750 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 - - -- 1750 6250 7750 19750 21250 ICD3- 119wp02 200 CD3 -1 . - +! • CD3 -121 se a ? CD3 -111 L1 -60 / 300 r� iS i� r" 3- -'1+ a ' 00 0 / 360 �>� CD3 -111 50 � � � r ` g co ti " 30 / 330 30 CD3 -121 RigS 11 y : � � CD3 -122 VIA 60 / 300 '' 60' =le;�a# -ds� 1 ' .. J -90 / 270 90 ,; ii ' , \ \ c Y - , : i \ \ I ; tw � , ,,J ; I CD3 113 - / 270 90 • CD3 115 II _` . 4...�ya. s - is C + 9 s Ali'' -1� 7-;-:',. I'' �a� �' C D3 -316 - 120 / 240 rr -\ t -- ; ,,, , . `' � 120 fi r "�+ r CD3 -316A '1` ' • CD3 - I, ;: ' I ),t' 120 / 240 120 ', 21 �- ' ; joith j 7/ - 7).-„,__,..:12.,, , f CD3- 316APB1 - 't_ s. =i i"` ' k ' F ICD3 125wp02 - CD3 -124 -.; a : ¢ Y` '. ,.. /Fr t.:, ICD3 -117 ,, -150 /210 jI ' 150 -150 / 21i 150 CD3- 126wp02 50 -180 / 180 ' 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] _ GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10:29, March 12 2010 ' CD3- 123wp03 Ellipsoid Color 1500.00 To 2000.00 36 -- 250 1750 2250 7750 9250 21250 22250 250 500 2250 - 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 CD3- 121wpfL3l 750 1000 3500 4250 14250 16250 24000 24500 300 , 3- 120wp02 1000 1250 4250 5250 16250 -- 18250 1250 1500 5250 6250 18250 19750 -30 / 330 ;. ■30, - " _ _ CD3- 120wp03 1500 1750 6250 7750 19750 21250 ftel'c7: 200 �7 • kk �i _ ]j _ _ it, Cc - 112 -60 / 300 60 llo , 0 / 360 50 -30 / 330 30 11s 0 i tr - iil -60 / 300 6 0 q' I , l I , -90 / 270 CU3 - 122 90 p:,,,,, axw.r. ay . t.., . , -90 / 270 90 F .... _- f S - 120 / 240 1 ' 120 - 120 / 240 120 . '`� t, f- 3 114 /;1 - - l -_ CD3 -115 150 / 210 150 150 /21s{ 150 50 dH .h 3{ 180 / 180 CD3 -124 -180 / 180 CD3-118 1CO3 -117 Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10:30, March 12 2010 CD3- 123wp03 Ellipsoid Color 2000.00 To 2500.00 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 CD3 121wp03 500 750 2750 3500 11750 14250 23250 24000 0 / 360 ■ 750 1000 3500 4250 14250 16250 24000 24500 300 1 1000 1250 4250 5250 16250 18250 1250 1500 5250 6250 18250 19750 -30/ 330 { I „ 3b 1500 1750 6250 7750 19750 21250 iij CD3 -112 20i i i - 60/300 _.. 60 0 / 360 AI - 50 30 / 330 30 10r -60 / 300 60 Allik ' -90 / 270a 90 ,,L ' CD3 122 1 -- . liripp! - -90 / 270 90 5 -': :: H, :' i 1 1011 ,1 -120 / 240 120 120 / - • 120 20� - I ' t a &-.` a , - 150 / 21150 150 / 210 } i s ! r I `'' ' 150 ts l' / t {] -180 /180 3'1 -180 / 180 , CD3 -114 CD3 -115 Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10:31, March 12 2010 CD3- 123wp03 Ellipsoid Color 2500.00 To 3500.00 36 " " " " " " " " " " " " "" " " " " " """ " "" 250 1750 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 - - 24000 1 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 5250 16250 — 18250 1250 1500 5250 6250 18250 19750 - 30/ 330 30 1500 1750 6250 7750 19750 21250 201 • -60 / 300 60 0/360 iV dine I .lfli ii,i 50 � -30 / 330 - 30 60 / 300 60 90 / 270 1'..#3X'; 90 ... � ��r ifil .. ' _ IC O3 -122 Ilk .„, ` ` 'y`+�� -90 / 270 90 '' ' MI" ' : -120 / 240 f "u 120 120 /240 120 le 200 - 150/210 -- 150 150 / 210 150 50 300 - - -= - -_ -- -180 / 180 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10:32, March 12 2010 CD3- 123wp03 Ellipsoid Color 3500.00 To 9000.00 36 250 1750 " 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 -- 5250 16250 _ 18250 1250 1500 5250 6250 18250 19750 30/ 330 30 1500 1750 6250 7750 19750 21250 200 -60 / 300 60 - 0 / 360 50 aj -30 / 330 30 101 1 I:1 -60 / 300 60 - 10 / 270 90 - .,::,„„_„..,,, Al ,, -90 / 270 90 r 120 /240 120 IIF -120 / 240 120 201 -150 / 210 150 -150 / 210 150 50 -180 / 180 300 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10:33, March 12 2010 CD3- 123Wp03 Ellipsoid Color 9000.00 To 10000.00 36 " "' " "" 250 1750 " 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 - _. 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 -- 5250 16250 ----- 18250 1250 1500 5250 - 6250 18250 19750 30 / 330 30 1500 1750 6250 7750 19750 21250 200 • -60 / 300 60 0/360 30 / 330 30 ':11li'li::!!,,',!...„,..'. 1-11'2 10� tlIINI �Th \, /11111%.** 60 / 300 60 _\ �. 90 / 270 �������a 90 ,, „...... ,, . � � ��Ik i h 11* III1 I1'�'�i�� -90 / 270 90 � . , D3 114 � � �11 �\111' 1 1 chip „ . L *1 �111k ��'III ��� ■mo 120 / 24�� ������� \� I�Q ldlljl: I : 12 ��.���� u.�;lllplgl,lllpll" —120 / 240 120 e 0 11111 � ���V 150 /210 150 -150 / 210 /I• �e \ � \ * 150 50 ��%��` -180 / 180 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation [25 ft/in] I GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 10:33, March 12 2010 CD3- 123wp03 Ellipsoid Color 10000.00 To 17091.96 36 250 1750 2250 7750 9250 21250 22250 250 500 2250 2750 9250 11750 22250 23250 500 750 2750 3500 11750 14250 23250 24000 0 / 360 750 1000 3500 4250 14250 16250 24000 24500 300 1000 1250 4250 5250 16250 - - "" - 18250 1250 1500 5250 6250 18250 19750 - / 330 30 1500 1750 6250 7750 19750 21250 20• • -60 / 300 60 0/360 ,,, . , , , 1 , 1 11 , 111:,h , ,,,„„.1:::: ,,, '-11 ' ' ,T,...,..: ' J: ::::. i; 50 dill -30 / 330 30 10 r �I9' ,,, - 60 / 300 60 ' - `- 90/270 9 .. r gip .- 90 / 270 90 dJ i ■ 120 / 240 i 120 -120 /240 - 120 ilk 20• -150 /210 150 -150 / 210 150 50 300 -180 / 180 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [25 ft/in] Conoc©Phillips WELLBORE TARGET DETAILS (MAP CO- ORDINATES) V ��� CD3- 123wp03 Name TVDSS 43.9 +E / Chape CD3- 123wp03 Heel 6910.00 - 1243.97 7 - 5662.5 Circle (Radius: 100.00) CD3- 123wp03 Heel Circle 6910 00 - 1243.97 -5662.5 Circle (Radius: 1320 00) CD3- 123wp03 Toe 702500 - 6186.27 - 2297.4 Circle (Radius: 100 00) Q u a rte r Mile View CD3- 123wp03 Toe Circle 7025.00 -6186.27 - 2297.4 Circle (Radius: 1320 00) 10.40, March 12 2010 �" .,o og G � �3 G Gp� ^� GO ^ � p 3,1 A G�G�3�� GP GO 3.1 �� 3 i∎C G . Y C. 0.3. a. i f . , 411411k Y 6D • 1 ,, , - ' ' 4\ : -- \ \ 2000 -\ 10626 -TD (1933)' 1933 �■,' �,� j Ell 3-1 07L1 APB1 Ri Sury M 4° CD 12168 IL . -TD (2479) --- r ' ■ - • CO a � • / '.. .. itY o G / 0 ;� 0 2000 = .- �� Ga y 0 -C 1 ti o33 fir Z � C7 ^4000 -- 9130 -TD (2030) =r o -;-,,,,_--_L__: .,.. .. \ 0 9 i . . ' : : i _:= ; - . ( �� G2 - 6000 G 10851 -TD . - 8000 i • I I I I I I -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 West( -) /East( +) (2000 ft/in) Opera la: ConocoPhlelpe(Aksko)Inc.-W145 GrklCogrectIon: .626 ° 501300. tN/A FCC Wadwn Narlfl5lope Atc14.11:Decincilon: 2126 ° AR No. MIA Wel CD3-123,,03 Dr. 8038 ° ..71800 tN/A - RC 86/6 Deglog per 100 ft System CIVO) Reference won Sea Level SwIciola Lacallon Original VS Plane: 145.0D • Parent Wok 9800603.123 X. 1527967.12 it View VS Plane: 145.00 • 5581.18101: 4890 I Y 6003522.43 ft UnttSydem: .491111.41/1.75 Section (VS) Redolence: Vol Comments: POOL: FSOn Vie& 8 8 .§. 8 § 8 8 8 8 8 § 8 CD3-123wp03 Plan: 10851 to 17091.96 MD _ _ _ ,••• _ _ _ _ _ 6010600 CD3-114: 10626 to 18042' MD ,,, CD3-115: 12168' to 19564' MD • 6009600 CD3-122: 9130' to 15408' MD . • 6008600 . i . . ; - 6007600 6006600 I", • - 6005600 -... . F.. 6004600 o . z illilli 11111 11 1 1111 1 11111 1 11 ..- -- - • 6003600 . :1.. - - illillEMMIIIIIPP. . .. ... , „,„, ■ 6002600 ) ' Section View — CD3-123wp03 Pksn — CD3-114 —.— — CD3-115 —• C D3-122 ...''.' . . . . t - 6001600 ' -' , 1• 1 1111111 . . .• 1 . 1,1 :j:'' ..:10.01'''' .,71 1 ..,.. • ! • - - 5999600 III • : -_, .".,,',.-,+- ''-'+'4+ 1 ..sj ''' . . „ • ; _ k '+j,,,-,:„.L,4„:.112:-_,441" • 5998600 ' ' ''. i -;___--- ; ' „4„_„' 1 ' -lik '1'':' "'.. : 1 '. !3. --b . - 5997600 • - ; . , _ „141.614, ,I• : - ---__ _ : 1 ,-_ .,1: . – ,,, — 5996600 : .• • ' .„., ,,,,... ,, . . . - ""'" '''' . L' . 1 5995600 _c ' East (+) / West (-) O . -6 ''''1..i:,. ' ' i ' 'i '''!,i'''kj.!'1 • ' . i ' 0 > 't:Al101ill:liAll!'''''!'HI•H ' 0 , ',' t :14191lAiliqfkl,.,,'' , (Y) • • ,6 . ■ .: . . .. , .. . _ • • ' • - - '7_ :-„,.,.......:,:: : -. -- .. _, ' o 7300 8 8 8 8 8 8 8 8 8 8 8 8 8 § § E 1 § 1 1 § Vertical Sect ion along View VS Plane" Combo Preview ' Page 1 of 1 (CD3-123wp03 Toolbcoals) 3/12/2010 11:09AM Closest in POOL Closest Approach: Reference Well: CD3- 123wp03 Plan Offset Well: CD3 -114 Coords. - Coords. - ASP ASP 3- D ctr - ctr 1 , 11,,,,1ta - _,.I. ..r l', Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( + /S( -) View VS Distance. I'q 4,: „ ro , d - . 1. i1 , Depth Angle Azi. TVD E( + /W(- (145) Jomments Depth Angle Azi. TVD E( +) /W(- (145) Jomments POOL Min FOUL Min Distance (1933.02 Distance (1933.02 ft) in POOL (10851 ft) in POOL (10851 III - 17091.96 MD) to - - 17091.96 MD) to CD3 -114 (10626 - =_ = CD3- 123wp03 Plan 1933 1'" ! i I I HI.? I 10851 47 83 16181 688616 i_ - 2475.53 18042 MD) 10601.9 :, 83.08 32339 1' _ _ -4472.97 (10626 - 18042 MD) Closest Approach: Reference Well CD3- 123wp03 Plan nl j101: 666422 Coords. - I ::,:::N11::„1:,1 1, I Coords. - 111:11'll I {{ ASP II I ASP „ ` 3 - ctr I ,,,, I a, II a k sz-, Meas. Incl. TRUE Subsea N( +) /S( -) View VS Mea.S Incl TRUE Subsea N( +) /S( -) View VS ' I Distance. 1 `, ad 1 1'1,11,,,.I : Depth Angle Azi. TVD E( + )/W(- (145) omelents 1:7(6611 Angle Azi. TVD E( + /W(- (145) :omments ., P 1UL Min POOL Min II , Distance (?�)3Q, 57 - Distance (2030.57 I 1'1!V ft) in PttCL (10851 - ft) in POOL (10851 --•` _ i - 17091918 MD) to - 17091.96 MD) to = ` CD3 -122 ('91',36' ml ^ CD3- 123wp03 Plan 2 1'. _1994 2030.6 - -- .:, 11 I 12250 88.89 145.16 6930.77 6001386 1522872 - 1091.,26 154°8 MD) 9752.71 89.43 145.28 6918.94 INN _ . (9130 - 15408 MD) Closest Approach: Reference Well CD3- 123wpO3 Plan` Offset Well CD3 -115 - -,„ Coords. - 'l i! , I I , -= - Coords. - : ASP ASP 3- Dctr -ctr 1I. 'Iir,n,liJ F,.,a Meas. Incl. TRUE III S ubsea N(+yS( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. 1 - In ,.,: Irf'ei 21i: Depth Angle Azi. 'I D I 5.( +)f1N( (145) 3omments Depth Angle Azi. TVD E( + /W(- (145) Jomments ill POOL Min POOL Min Distance (247073 Distance (247073 ft) in POOL (10851 ft) in POOL (10851 - 17091.96 MD) to - 17091.96 MD) to CD3 -115 (12168 - CD3- 123wp03 Plan 2479.7 ,,, I,r, I r, p, ^ 10851.47 83 163.81 6886 767 6002602 1522199 - 2475.53 19564 MD) 12143 79.39 332.75 6889.52 _ _ - 3589.63 (12168 - 19564 MD) PoolSummaryl 3/12/2010 11:17 AM 0 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 5 4/8/07 AG DB C.A. UPDATED PER K07041ACS 6 4/13/09 AG DB C.A. UPDATED PER K090003ACS ' Q 100 CD3 \� ��� ■ t _ I� 4 _ Go�P . 'M� LOCATION OF Z 1E474■4ellE ∎ ∎ THIS SURVEY ^� � .� \ ww,rairimmwri AS N alMillE ALPINE SATELLITE DEVELOPMENT • �" VICINITY MAP NOT TO SCALE OER OF 9M) l C!�1 N . N S 1 G . S C D 3 D l - PAD t o N m — 4 • -�;1, Qi•• - -IP °d0 rn NN%% Nt�O�caeV 8 � „ • i REAM � ` Cz .. I N :4-1- 11; ;;-",-7 . 7 1pou c ; I ' ll e l:111111 ;' \15- -- -- `- EN -rEi G F ��` M00 1 . AGE SWD ' �� W A R E OUSE PLANT ' cl N 1/�RGENCY G ASPC E T ERS N 13'00'00” : 41 41 N i[1 LCUF LEGEND: 0 ° n 2 Z 0 PROPOSED CONDUCTOR ., w �° N N • EXISTING CONDUCTOR ° Ny v 0 rl ov o 0 P KUUKPIK 1 U U w o LC M FLLC �� i eri �� uoce1MAv..- Mc�aal.,Mwa aea-�071z/slao nlpin"OMro 150T ]]9 Alpine Survey Office ALPINE MODULE: CD30 UNIT: CD C•noc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS —BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1A 11/3/05 f . .,C , -111 1 OF 3 6 • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 6 4/8/07 AG DB C.A. ISSUED PER K07041ACS 7 4/13/09 AG DB C.A. UPDATED PER K090003ACS NAD 83 ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. V SEC.LINE 0/S EXIST WELL ' Y ' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD3 -X98 6,003,630.37 1,528,434.35 70' 25' 09.267" 150' 54' 44.278" 1392' 642' 7.3 12.5 CD3 -X99 6,003,625.99 1,528,415.38 70° 25' 09.221" 150° 54' 44..833" 1387' 661' 7.3 12.8 CD3 -301 6,003,621.33 1,528,395.58 70' 25 09.172" 150' 54' 45.4111;1 " 1387' 680' 7.3 13.5 CD3 -302 6.003.616.72 1,528,376.38 70' 25' 09.124" 150' 54 454972 ". 1377' 700' 7.3 13.2 CD3 -303 6,003,612.52 1,528,356.72 70' 25' 09.080" 150' 54` 46.547 " - �1373' 719' 7.3 13.3 CO3 -304 6,003,607.82 1,528,337.04 70' 25' 09.031" 150 47.122" 1368'= 739' 7.3 13.4 CO3 -305 6,003,603.48 1,528,317.56 70' 25' 08.985" 150' 54"x: 47.691" :1363' 758' 7.3 13.6 CD3 -106 6.003,599.43 1,528,298.37 70' 25' 08.942" 150" 54 48.252" -1359 ° ' 777' 7.3 13.4 CD3 -107 6,003,594.38 1,528,278.93 70' 25' 08.890" 150° 54' 4 8.820" T354' 797' 7.3 13.2 CD3 -108 6.003.589.85 1.528.259.61 70' 25' 08.842" 150° 54' 4S.-385 1349' 816' 7.3 13.1 CD3 -109 6,003,585.27 1,528,239.85 70' 25' 08.794" 150' 54' 49.962';!!' 1344' 836' 7.3 13.1 CD3 -110 6,003,580.97 1,528,220.32 70' 25' 08.749" 150` 54' 50.533" 1339' 855' 7.3 13.0 CD3 -111 6,003,576.13 1,528,201.08 70' 25' 08.699" 150' 54 51.095" 1334' 874' 7.3 12.9 CD3 -112 6,003,572.43 1,528,181.20 70' 25' 08.660" .150 54`::51.676" 1330' 894' 7.3 13.1 CD3 -113 6,003,567.62 1,528,161.38 70' 25' 08.609" =f :. 150' ,54',;52.255" 1325' 914' 7.3 13.1 CO3 -114 6,003,563.04 1,528,142.21 70' 25' x8.561" ='-� - - 150° 54' 52.815" 1320' 933' 7.3 13.3 CD3 -115 6,003,558.57 1,528,122.60 70' 25' 08.515" 150° 54' 53.388" 1315' 953' 7.3 13.9 CD3 -116 6,003,554.04 1,528,103.39 70' 25' 08.467" ' i50 '" 54' 53.950" 1311' 972' 7.3 1.3.2 CD3 -117 6,003,549.51 1,528,083.99 70`25 ` - 08.420" 150' 54' 54.516" 1306' 991' 7.3 131 CD3 -X18 6,003,544.88 1,528,064.44 70' - 08.372" 150' 54' 55.086" 1301' 1011' 7.3 12.8 CD3 -X19 6,003,540.17 1,528,044.86 70' 25 68.322" 150' 54' 55.660" 1296' 1030' 7.3 12.8 CD3 -X20 6.003.535.95 1.528,025.39 70` -25'08.278 _ 150° 54' 56.229" 1291' 1050' 7.3 12.6 CD3 -X21 6,003,531.41 1,528,006.04 70' 25' 08.230" 150' 54' 56.794" 1286' 1069' 7.3 12.5 CD3 -X22 6.00.3,527,00 1.527.968.67 70' 75' 08.184" 150' 54' 57.360" 1282' 1088' 7.3 12 6 CD3 -X23 6,003.522.43 1.527;987.12 70' 25' 08.136" 150' 54' 57.932" 1277' 1108' 7.3 12.6 CD3 -X24 6,003,518.17 1,527,947:59 70' 25' 08.091" 150' 54' 58.502" 1279' 1127' 7.3 12.5 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4,1 NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B. .M.S.L.) ALPINE MODULE: CD30 UNIT: CD C.noc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1A -2 3 -17 -05 CE -CD30 - 111 2 OF 3 7 • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 4 4/8/07 AG DB C.A. ISSUED PER K07041ACS 5 4/13/09 AG DB C.A. UPDATED PER K090003ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD -3 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK /LCMF, MARCH 2005 4. DATES OF AS -BUILT SURVEYS: WELL CONDUCTORS CD3 -108, CD3 -109, CD3 -110, CD3 -111, 3/16/05, FB 2005 -08 PGS 52 -53; CD3 -301, CD3 -302, 3/19/05, FB 2005 -09 PGS. 24 -25; CD3 -304, 4/16/05, FB 2005 -12 PGS 35 -37. CD3 -303 2/10/06, FB 2006 -03 PG 11. CD3 -112, 2/23/06, FB 2006 -05 PGS 29 -31. CD3 -107, 3/26/06, FB 2006 -09, PG5.9,25 -27. CD3 -305, CD3 -106, CD3 -113, CD3 -114, CD3 -115, CD3 -116, CD3 -117, 5/2f00 :1 FB 2006 -11 PGS 57 -61; CD3 -X18, 4/7/07, FB 2007 -07 PG. 67; CD3 - X98, - =DX 419,I,.CD3 -X19, CD3 -X20, CD3 -X21, CD3 -X22, CD3 -X23, CD3 -X24, 4/13/09, =FB 2009.05 PGS. 70 -72. SURVEYOR'S CERTIFICATE . vo yankimi • _ 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO P , THAT THIS .4 . ••� ♦♦ ASS -BU TILT ICE REP ESE TS MADE B MY DIRECT • �;:' •• ♦ 1 ♦ SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST ♦ AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE * : 49th A� 0 CORRECT. • DATE: REGISTRATION NO. LS -5077 • • p Donald G. Bruce o • ;r No. LS -5077 4 `" � F ' ' • •.. KUUKPIK F4 131 Le1dAva. • mamma, mix C weal • (amlxt1 Alpine Survey Office y/ ALPINE MODULE: CD30 UNIT: CD CelloCePhi I lips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1A -3 3 -17 -05 ,-., r) 3 OF 3 5 • Page 1 of 1 Schwartz, Guy L (DOA) From: Robertson, Ryan G [ Ryan. G.Robertson @conocophillips.com] Sent: Thursday, March 18, 2010 4:01 PM To: Schwartz, Guy L (DOA) Subject: RE: CD3 -123 completion (PTD 210 -031) Guy, There are no plans to frac the CD3 -123 well before it is converted to an injector. As far as the slotted liner on the well sketch and 401 PTD goes, the plan is to not run the liner unless we exit the Nechelik formation into the overlying shale while drilling the lateral section. In that case we would run the liner to prevent the shales from collapsing into the wellbore, as has been the case in the past. Nina will be out of the office until March 31St. Please let me know if you have any other questions or concerns. Thanks, Ryan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, March 18, 2010 3:47 PM To: Robertson, Ryan G Subject: FW: CD3 -123 completion (PTD 210 -031) Guess Nina is out... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Thursday, March 18, 2010 3:37 PM To: 'Anderson, Nina M' Subject: CD3 -123 completion (PTD 210 -031) Nina, Is there a chance you will frac this well before converting to injection? Also the procedure outline doesn't mention running the slotted liner... the well sketch and 401 PTD cover page says you are running one. I know there have been some injectors in the past that don't have liners. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 3/18/2010 . _. 6 7 0 3 -/z 3 Aok N. , . D \ i \ , \ , )3-118 \ • \ j o n-- )6 1 00 3-302PB 0 ‘,,,,i2 1" i 250 21450' \ \ - + ) / 7210 2060100 9882 , N \ zvi P1 / 7 , _ . ... . \ \ t , ..,, J1 - "At \ . , 4 7 ?, 1 „ CD3-302PB1 2060100 8932 1. •-- /-/ .--- 10 9620 \ \ \ \ : • • \ \ , . 0 1 ,, .....,...,, • , k 4L "c, 413.PH ,.' " 1 ''' i ik;• ' .' '"''2' \ : ■ ■ el: • f ' 41 at Y. • • . , r „is,'4,-.4- ,, .47.. , .-,..!....\ , ot ..,_ \ „. . -4 V Ito' , . ..,t \ \ \ \50, „AP ..... \ Is ..1. vi. •• • \ 1\ I Agribb" \ _ \ IS - i • ..------- :,, -- - 17 177 0 \J \ _ _ i . ■ Jr. I Ih111-11.__ _____ _____, \ \ ■ " .-1 - \ 1/4 , • 1 \ \ \ \ : \ k. l '1/4 \ \ 11. . ' \ !\\,. i7:). xf' . !, i CD3-1 tj .: . f:' ' 2100220 4982 CD3-122 • • 201530 15364 k. . \ CD3- 23 , \ .. . . . . _ 21001 it, 17.142 0 55 8 2 372107 lk . 4 TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# - / �} � ' /CD Development 1/ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: / / 7 Lie' - 1" POOL: A -7'0,-- / Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(D, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, FIORD OIL - 120120 Well Name: COLVILLE RIV FIORD CD3-123 Program SER Well bore seg PTD#: 2100310 Company CONOCOPHILLIPS ALASKA-INC — Initial Class/Type SER / PEND_ _- GeoArea 890 _ ____ __ Unit 50360_ _ _ On /Off Shore On _ __ _ Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Corrected 10-401 form: Entire well will lie within ADL 372105. 3 Unique well name and number Yes 4 Well located in a defined pool Yes COLVILLE RIVER, FIORD OIL - 120120, governed by CO 569 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 569 contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes Conservation Order No. 569 has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 569 has no interwell spacing restrictions. Wellbore will be more than 500' from 8 If deviated, is wellbore plat included Yes external property line where ownership or landownership changes. 9 Operator only affected party Yes '10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 3/18/2010 1 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 30, issued July 25, 2006 15 All wells within 1/4 mile area of review identified (For service well only) Yes None 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) Yes 17 Nonconven. gas conforms to AS31.05.0300.1.A),(1.2.A -D) Yes 1 118 Conductor string provided Yes Engineering 1 19 Surface casing protects all known USDWs Yes No Aquifers AIO 30, Conclusion 3 '20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate_ to tie -in long string to surf csg No 122 CMT will cover all knownproductive horizons No OH slotted liner proposed ... 1 23 Casing designs adequate for C, T, B & permafrost Yes 124 Adequate tankage -or reserve pit Yes Rig equipped with steel pits. All waste to . approved disposal wells. 25 If a re- drill, has a 10-403 for abandonment been approved NA 126 Adequate wellbore separation proposed Yes Proximity analysis performed. Close approach to CD3 -122 at 600' and (6' eclipse separation) 27 If diverter required, does it meet regulations NA Diverter waiver requested. No shallow gas-issues at CRU. 20 AAC 25.035(h) (2) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation press = 3200 psi (8.7 ppg EMW) Will drill with 9.1 -9.2 ppg mud GLS 3/18/2010 1129 BOPEs, do they meet regulation Yes 30 BOPE -press rating appropriate; test to -(put psig in comments) Yes MASP = 2493 psi Will test BOP to 3500 psi 1 31 Choke manifold complies w /API RP -53 (May 84) Yes '32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No No H2S on CD3 .. Rig is equipped with sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR completed.. No wells within 1 /4mi . '35 Permit can be issued w/o hydrogen sulfide measures Yes None expected, but H2S and gas detectors will be used during drilling, Mitigation measures in Hazards Geology 36 Data presented on potential overpressure zones Yes Summary. Expected gradient is 8.7 ppg EMW; will be drilled with 9.1 - 9.2 ppg mud. Appr Date 137 Seismic analysis of shallow gas zones NA SFD 3/18/2010 38 Seabed condition survey_(if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering r..•o Pre- produced Fiord Oil Pool injector. Commissioner: Date: Com issio r: Date Date C; .ner
