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205-074
STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COl. 3510N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing rw Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 205-074 3.Address: 6.API Number: Stratigraphic r Service r° P. 0 Box 100360,Anchorage,Alaska 99510 50-029-23264-00 7.Property Designation(Lease Number). 8.Well Name and Number: ADL 25660 KRU 1E-170 9.Logs(List logs and submit electronic and printed data per 20AAC25 071). 10.Field/Pool(s). none Kuparuk River Field/West Sak Oil Pool 11 Present Well Condition Summary: Total Depth measured 15940 feet Plugs(measured) none true vertical 3354 feet Junk(measured) none Effective Depth measured 15940 feet Packer(measured) 9309, 9710, 9871 true vertical 3354 feet (true vertical) 3258, 3321, 3347 Casing Length Size MD ND Burst Collapse CONDUCTOR 120 20 120 120 SURFACE 5012 13.375 5054 2311 INTERMEDIATE 5582 9.625 10414 3451 A-SAND LINER 6048 5.5 15919 3355 RECEIVED MAY 11 26.E Perforation depth Measured depth: slotted liner from 10438'-15874' ;i + True Vertical Depth: 3456'-3355' ��((''����yY t3 L !'� %ACAS) I w�i 0 15 Tubing(size,grade,MD,and TVD) 4.5, L-80, 9388 MD, 3271 TVD Packers&SSSV(type,MD,and ND) PACKER-HRD ZXP LINER TOP PACKER @ 9309 MD and 3258 TVD PACKER-HRD ZXP LINER TOP PACKER @ 9710 MD and 3321 TVD PACKER-HRD ZXP LINER TOP PACKER @ 9871 MD and 3347 TVD no SSSV 12 Stimulation or cement squeeze summary. Intervals treated(measured): no stimulation or cement squeeze during this operation 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 shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development p- Service r Stratigraphic r 16 Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O.Exempt none Contact Jonathan Coberly(a)265-1013 Email Jonathan.Coberiy(a�cop.com Printed Name Jonathan Coberly Title Sr. Wells Engineer SignatureA;dti Phone:265-1013 Date 5-11- /5 vt` &ie0s RBDMS'Di4 MAX 1 2 2015 Form 10-404 Revised I 2l2 Submit Original Only KUP PROD 1E-170 M.. ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska,Inc° Wellbore API/UW1 Field Name Wellbore Stormy Incl(°) MD(ftKB) Act Sim(ftKB) c � 500292325400 WEST SAK PROD 94.77 15,722.01 15.940.0 ... Comment H25(ppm) Date Annotation End Date KBGrd(It) Rig Release Date 1E-170.4Q82015224:46 PM SSSV:NIPPLE 55 1216/2013 Last WO: 3/3012015 47.86 9/11/2005 Verecel schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date RANGER:403 Iasi Tag: Rev Reason:WORKOVER smsmith 4/24/2015 I- �� i4. Casing Strings III Casing Description 00(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 42.0 162.0 162.0 94.00 K-55 WELDED CONDUCTOR;12.4182.0 [�Casing Description00(In) ID(10) Top MB) Set Depth(MB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 133/8 12.415 42.8 5,054.3 2,311.9 68.00 1-80 BTC GAS LIFT:2./03.1 Casing Description OD(In) ID(In) Top DtKB) 581 Depth(ftKB) Set Depth(TVD)...WULen(H...Grade Top Thread D-SAND WINDOW 10 6.625 9.402.0 9,412.0 3,274.6 Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...VNLen(I...Grade Top Thread 13-SAND WINDOW 10 6.625 9.874.0 9,879.0 3,348.9 Casing Description 00(In) ID(In) Top(ItKB) Set Depth(Milli) Set Depth(TVD)...WtlLen(I...Grade Top Thread INTERMEDIATE Tie- 95/8 8.835 42.3 4.849.4 2,269.7 40.00 L-80 BTCM INTERMEDIATE oBsck 423- 3T.. BackT4.849.4 1 .1 Casing Description 00(In) 10(In) Top(ftKB) Sot Depth(ftKB) Set Depth(TVD)...VA/Len(I...Grade Top Thread PATCH;1,642.0 1: INTERMEDIATE 95/8 8.835 4.832.0 10,414.0 3,451.3 40.00 L-80 BTCM Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread D-SAND LINLR H(I 5 1/2 4.950 9,412.3 9.662.6 3,313.4 15.50 L-80 I Liner Details SURFACE;42.8-5,054.3 Nominal ID Top(ItKB) Top(TVD)DUB) Top Incl(°) Item Des Com (In) GAS LIFT;8.134.3 9,412.3 3,274.6 81.38 HANGER BAKER MODEL 8-2 HOOK HANGER FOR LEM 7.470 9,433.0 3.277.7 8142 HANGER BAKER MODEL B-2 HOOK HANGER FOR LEM 7.470 I 9,439.6 3.278.7 81.43 XO BUSHING 4.890 SLEEVE:9.191.7 9,554.9 3,296.1 80.84 ECP BAKER PAYZONE EXTERNAL CASING PACKER 4.920 9,620.8 3,306.8. 80.80 BENT JT 4.950 NIPPLE;9,247.0 Z;' Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) !Set Depth(TV13)...IWULen(l...l Grade ITop Thread -"" B-SAND I.INFR HH 5 1/2 4.950 9.772.9 9.991.5 3,368.4 1550 L-80 BTCM GAUGE.9,255.2 v " Liner Details Nominal ID Top(KKB) Top(TVD)(11K8) Top Inci I') tern Des Com (in) • 9,772.9 3,330.6 80.40 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.470 LOCATOR.9,369,3 - 9,794.0 3.334.2 80.25 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.470 SEAL ASSY;9,370.1 9,800.1 3,335.2 8022 XO BUSHING CROSSOVER BUSHING 4.890 9,860.3 3,345.6 7986 ECP BAKER PAY ZONE EXTERNAL CASING PACKER 4.910 9,918-1 3.361.0 80.14 BENT JT 4.950 Casing Description OD(In) ID(In) Top(ItKB) Set Depth IRKS) Set Depth(TVD)...WULen II...Grade Top Thread A-SAND LINER 5 1;2 4.950 9,870.5 15.918.9 3,355.7 15.50 L-80 BTCM L. ra Liner Details D-SAND WINDOW:9.402,0- 1, Nominal ID 8,412.0 .1 1, Top(ftKB) Top(ND)(MB) Top incl(°) hem Des Com HRD ZXP LINER 70P PA (In) P 9.870,5 3.347.4 79.80 PACKER PACKER 7.500 9,889.1 3.350.7 79.85 NIPPLE 'RS'PACKER SEAL NIPPLE 6180 - 9,891.9 3.351.2 79.87 HANGER FLEX-LOCK LINER HANGER 6.240 9,901.5 3.352.9 79.91 XO BUSHING XO BUSHING 4.880 9,902.7 3,353.11 79.92 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 • Casing Description IOD(In) IID(In) Top(ftKB) Set Set Depth(ftKB) I Set Depth(TVD)...!Wt/Len(1...l Grade ITop Thread ID-SANG LINER LEM 41/2 3.958 9,3086 9,739.2 3,325.1 12.60 L-80 IBTM D-SAND LINER RN:9.412 3- Liner Details 8,662.6 Nominal ID Top(11891 Top(TVD)(ftKB) Top Incl(°) hem Des Com (In) Ina 9.308.6 1258.r 80.08 PACKER HRD ZXP LINER TOP PACKER 7.500 0-SAND LINER LEM.9.3086- 9,370.6 3.268.3 80.97 SBE 190-47 SEAL BORE EXTENSION 4.750 9.739.2 $. 9,390.0 3,271.3' 81.24 XO BUSHING CROSSOVER BUSHING 3.930 9,391.4 3,271.5 81.26 SWIVEL CASING SWIVEL 3.950 111 I I 9,407.7 3,273.9 81.38 HANGER LEM ABOVE HOOK HANGER 3688 F Q 9,412.3 3.274.6 81.38 HANGER LEM INSIDE HOOK HANGER 3.688 f 9,736.0 3.324,6 80.82 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(1VD)...Wt/Len(1...Grade Top Thread B-SAND LINER LEM 41/2 3.958 9.710.1 9,912.6 3354.8 12.60 L-80 IBTM Liner Details Nominal ID isIITop(ftKB) Top(TVD)(ftKB) Top Ind(*) hC em Des Corn (In) e-SAND WINDOW,9874 0- s 1 9,710.1 3,320.6 81.12 PACKER HRD ZXP LINER TOP PACKER 7.600 9879'0 - -I 9,729.9 1323.7 80.89 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 is 9,749.3 3,326.8 80.67 XO BUSHING CROSSOVER BUSHING 3.940 molar 9,750.7 3,327.0 80.66 SWIVFI 3.950 ,'BIM a. 9,759.0 3.328.3 80,56 HANGER B-SAND LEM ABOVE HOOK HANGER 3.980 &SAND LINER LEM,9,710,1- 9.911.5 ili 9,772.8 3.330.6 80.40 HANGER 0-SAND LEM INSIDE HOOK HANGER 3688 I 9,909.3 3,354.3 79.95 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Tubing Strings 115AND LINER HN;8,772.6- Tubing Des°ripllon String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection 9991.5 TUBING 2015 W0 4 1/2 3.985 403 9,387.5 3,270.9 1260,1-80 IBTM Completion Details Nominal ID INTERMEDIATE.4.832.0- a is, Top(ItKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (In) 10.114.0 40.3 40.3 0.24 HANGER VETCO GREY TUBING HANGER 3.900 SLO7$10,438.0.10.521.0--I :- 9,191.7- 3,238.2 80.17 SLEEVE BAKER CMU SLIDING SLEEVE DB NIPPLE 3.820 9,2470 3,247.5 80.26 NIPPLE CAMCO DB NIPPLE 3813 SLOTS,10,731.0-11,211.0 9,295.2 3,255.7 80.06 GAUGE BAKER GAUGE W/SURESENS PRESSURE GAUGE 3.985 SLOTS;11,634.0-11,867.0-; KUP PROD 1E-170 ConocoPhillips iti AJas'•oa,Inc e n+re#MYps 1E-170 4/252015 2'24'50 0 V Vertical schematic(actual) HANDER 40.3 'aT9�� 1 71. ���� Other In Hole(W1retlne retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(HKBI 1n2726818.1 HKBJ (°) Des Com Run Date ID(In) t'^ 4,842.0 2.268.1 77.65 PATCH BAKER EXPATCH SET IN 9 518'CSG.Cannot pass 1/24/2009 8.000 CONDUCTOR:42.0-192 o [Nu W/7 718';passed w,7.5"MIA GAS LIFT:2.103.4 t= Perforations&Slots Shot Dens Top(TOO) Btm(TVD) (shotNR �� Top(ftK8) BM(HKB) (N 10,438.0 Zone Dat. 1) Type Com 10.438.0 10,521.0 3,456.2 3,470.0 WS A3,WS 8/10/2005 32.0 SLOTS Alternating slottedisolid INTERMEDIATE Tie-Back'42.3- r l A2,1E-170 PIPE 4.049.4 PATCH;4,842.0 10,734.0 11,244.0 3,492.9 3,493.5 WS A2,1E- 8/10/2005 32.0 SLOTS Alternating slottedisolid I/O pipe I 11,634.0 11,887.0 3,470.8 3,464.7 WS A2,1E- 8/10/2005 32.0 SLOTS Alternating slotted/solid 170 pIpe SURFACE:42.8-5.054.3 12,310.0 15,399.0 3,447.3 3,378.0 WS A2,1E- 8/10'2005 32.0 SLOTS Alternating slotted/solid 170 PIPS GAS LIFT;9.134.3 15,790.0 15.874.0 3,365.3 3,358.7 WS A2,1E- 8/10/2005 32.0 SLOTS Alternating slotte&solid 170 Pipe SLEEVE,91917- Mandrel Inserts St atl NIPPLE;9,247.0 on Top(TVD) Valve Latch Port Size TRO Run _ N Top(MB) (HKB) Make Model OD(In) Sere Type Type lin) (psi) Run Date Com 1 2,103.4 1,810.4 CAMCO KBG-2 1 GAS LIFT GLV 0.250 1,472.0 4/23.2015 GAUGE.9,295.2 2 9,134.3 3,228.0 CAMCO KBG-2 1 GAS LIFT DMY 0.000 0.0 4/11/2015 Notes:General&Safety End Date Annotation - 11;12/X0h NOTE:MULTI-LATERAL WELL:1E-170(A-SAND),1E-1701_1(B-SAND),1E-170L2(D-SAND) LOCATOR:9,369.4 E- 1,29,2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0REV SEAL ASSY;9,3701 D-SAND WINDOW.9/020 )I 'y 9 1 t Ili 11 I 13-SAND LINER HN:9,412 3- 9.662 6 -1 l 13-SAND LINER LEM,9,308.6' 9.739.2 MR Itt iI ll a • &SAND WINDOW:9,874.0- I 9.879.0 I I-I, S B-SAND LINER LEM,0710.1 9912.8 &SAND LINER 114;997729818..5- INTERMEDIATE.4.832.3 w. 10.414.0 SLOTS;10.439.0-10.321.0 SLOTS-,10,734.0-11,244.0—�— 51,078111,634.0-11,887.0 7 _- _ SLOTS:12.310.0-18.399.0 _ I— ' SLOTS:15.780.0-15874.0 —j — A-SAND LINER:9.870.5- J 15,918.9 1 1 E-170 WELL WORK SUMMARY DATE SUMMARY 1/30/2015 (PRE RWO) : POT-T INCOMPLETE, PPPOT-T INCOMPLETE, UPPER POT-T FAILED, UPPER PPPOT-T PASSED, LOWER POT-T PASSED, LOWER PPPOT-T PASSED, POT-IC FAILED, PPPOT-IC FAILED, FT-LDS ALL GOOD, MIT-OA PASSED TO 1800 PSI. 2/2/2015 MEASURED BHP @ 3120' SLM, EST. 1990' TVD: 951 PSI. COMPLETE. 2/4/2015 (PRE RWO) : POT-T PASSED, PPPOT-T PASSED. 2/19/2015 RIH PULLED POGLM ****TURN WELL OVER TO DSO**** PICS IN WSR POST-RIG WELL WORK 4/23/2015 GAUGED TBG TO 3.78" TO 2830' SLM; UNABLE TO PASS 84 DEG DEVIATION WITH PUMP ASSIST. PULLED SOV @ 2103' RKB, SET GLV© SAME. READY FOR E/L TRACTOR/ STROKER. ConocoPhillips Time Log & Summary Wel!vie.,Web Reporting Report Well Name: 1E-170 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 3/30/2015 12:00:00 AM Rig Release: 4/12/2015 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/30/2015 24 hr Summary Move shops, satillite camp, and pits to 1 E pad. Move the sub from 2V pad to Oliktot Y. 02:00 05:00 3.00 0 0 MIRU MOVE MOB P Move satillite office, shops, and pit modual from 2V pad to 1 E pad. 05:00 21:30 16.50 0 0 MIRU MOVE MOB P Spot shops and satillite office. Pits awaiting subs arrival. Contine preping sub to move. Lay down the derrick. Move off 2V-04. Move sub from 2V to CPF2. 21:30 00:00 2.50 0 0 MIRU MOVE MOB P Move sub from CPF2 to Oliktok Y. 03/31/2015 Continue moving sub base to 1 E pad. Spot sub over 1 E-170, and raise the derrick. Spot pit module and rig up interconnect. 00:00 00:45 0.75 0 0 MIRU MOVE MOB P Crew change and allow traffic to pass. 00:45 03:00 2.25 0 0 MIRU MOVE MOB P Move sub from Oliktok Y to 1E access road. 03:00 06:30 3.50 0 0 MIRU MOVE MOB P Move off the Spine road onto 1E access road to 1 E pad 06:30 12:00 5.50 0 0 MIRU MOVE MOB P Clear snow from pad,set rig mats and lay down herculite. Spot rig over 1E-170. Set Rig mats under sub. 12:00 18:00 6.00 0 0 MIRU MOVE RURD P Secure cellar. Raise the derrick. R/U TD and equipment. Clear rig floor. 18:00 00:00 6.00 0 0 MIRU MOVE RURD P Spot mud pits, pad operator observed while spotting. Set mats and release trucks. Berm around pits and run electrical lines to camp/shop. R/U interconnect and steam to pits. 04/01/2015 Finish R/U to kill well.Wait on trucks due to phase II conditions. Lubricate BPV out. Begin kill, bleed pressure off of IA and TBG. 00:00 06:00 6.00 MIRU MOVE RURD P Finish installing utility hose on top drive. Rig up hard line to choke house and tiger tank. Prep pits to take on fluid and blend. Rig accepted at 06:00 06:00 08:00 2.00 MIRU MOVE RURD P Rig up hoses in preparation to kill well. Blow air through hardline to kill tank. Page 1 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 10:30 2.50 MIRU WELCTL WAIT T Wait on Kill Weight Fluid from Prudhoe. Due to Phase II conditions and significant snow drifts on spine road trucks were unable to make it to Prudhoe last night to pick up 9.2 ppg KWF. 10:30 11:15 0.75 MIRU WELCTL SFTY P Pre-RWO meeting with night crew 11:15 13:30 2.25 MIRU WELCTL MPSP T R/U lubricater and test to 2500 psi. Attempt to lubricate out BPV. First try unsuccessful!. Attempt a second time. Observe poppet engage with 900 psi. Lubricate out BPV. No BPV. Observe pressure above BPV. 13:30 17:45 4.25 MIRU WELCTL MPSP P Rig lubricater back up. Engage BPV and reseat poppet. Ensure master and swab valves are holding. Lubricate out BPV. 17:45 19:00 1.25 MIRU WELCTL OTHR P R/D Lubricator and install tree cap. Service valves on tree. 19:00 20:30 1.50 MIRU WELCTL PRTS P R/U lines to the IA, TBG and Kill tank.Verify valve alignment. Test lines 250 psi low, 2500 psi high. 20:30 21:00 0.50 MIRU WELCTL SFTY P Pre job Safety Meeting/Bleed pressure off of IA and TBG. 21:00 23:00 2.00 MIRU WELCTL KLWL P TBG pressure 950 psi. Bleed pressure from 950 psi to 250 psi to Kill tank. Shut-in TBG and strap Kill Tank. 38 bbls mostly sand and gas, some oil to Kill tank. 23:00 00:00 1.00 MIRU WELCTL KLWL P 900 psi on IA. Bleed pressure from 950 psi to 150 psi to Kill tank. Strap Kill tank,44 bbls total returns. Continue to bleed and monitor well. 34/02/2015 Bleed pressure off of the TBG and IA. Pump 300 bbls of 9.2 ppg brine down the TBG. Pump 515 bbls down the IA. Monitor well, still blowing gas. Pump 600 bbls down the TBG. Shut-in the TBG and IA. 28 psi on the IA and 9 psi on the TBG. Call for 1500 bbls of Seawater to bullhead. 00:00 06:00 6.00 MIRU WELCTL KLWL P Begin killing well. Pump 300 bbls 9.2 ppg brine down the tubing staging pumps up to 4 bpm. No returns at surface. Shut down and observe tubing on vac. Rig up and begin circulating down the IA. 06:00 09:00 3.00 MIRU WELCTL KLWL P Continue reverse circulating annular volume at 4 bpm. No returns seen at surface. 09:00 11:00 2.00 MIRU WELCTL KLWL P Monitor well. Observe tubing on vac, slight blow on annular. Attempt to ciculate out gas. Circulate high viscosity pill and spot on bottom to mitigate losses. Page 2 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:00 2.00 MIRU WELCTL OWFF P Observe well, Tubing initially on vac going to static, IA blowing a small amount of gas. Downhole diagnostic on site to determine fluid level. Fluid level on IA 504';tubing 822'; indicating some lighter fluid in ,annular. 13:00 17:00 4.00 MIRU WELCTL KLWL P Pump 20 bbls of 9.2 brine down IA. Open both IA and TBG to kill tank. Shut-in TBG/5 psi, 80% LEL Monitor TBG. Blend fluid 9.2 ppg fluid in pits while observing well. 17:00 17:30 0.50 MIRU WELCTL SFTY P Pre-Job Safety Meeting-Pump down TBG taking returns out the IA to the kill tank. 17:30 19:30 2.00 MIRU WELCTL KLWL P Pump down the TBG taking returns out the IA to the kill tank. Stage pump to 10 bpm/1430 psi at the pump. Max pressure of the down side of the choke house 140 psi. Pumped 815 bbls total, kill tank returns 112 bbls crude oil. 19:30 20:00 0.50 MIRU WELCTL RURD P Blow down circulating manifold in the cellar and lines going the the kill _tank. 20:00 00:00 4.00 MIRU WELCTL OWFF T Shut-in the TBG and IA.TBG on a Vac, IA 60 pis shut-in pressure. Opened IA and bled pressure off to kill tank. Shut-in IA still 28 psi shut-in pressure. TBG went from a Vac to 9 psi. Monitor well/Call for 1500 bbls of seawater. 04/03/2015 Load pits with Seawater 3% KCL, Kill well by Bullheading down the Annulus and TBG. Set BPV and N/D Tree, N/U BOPE and prep for test. 00:00 06:00 6.00 MIRU WELCTL WAIT T Waiting on seawater to bullhead well. Monitor pressure onTBG and IA. TBG=8 psi, IA=34 psi. Prep cellar to N/D of tree and N/U BOP's. 06:00 11:00 5.00 MIRU WELCTL WAIT T Contirue to monitor TBG and IA. TBG =8 psi, IA=34 psi. Load 910 bbls • of seawater 3% KCL into the pits. Prep for Bullheading IA and TBG. 11:00 11:30 0.50 MIRU WELCTL SFTY T Pre-Job Safety Meeting-Bullheading _down IA and TBG. 11:30 13:30 2.00 MIRU WELCTL KLWL T Bullhead 724 bbls of seawater 3% KCL down the IA. Stage pumps up from .5 bpm= 121 psi, 1 bpm= 119 psi,2 bpm= 166 psi, 3 bpm=210 psi,4 bpm=292 psi, 5 bpm=373 psi,6 bpm=506 psi, 54 bbls pumped, start pumping Annulus volume660 bbls. Continue staging pumps up, 7 bpm =630 psi, 8 bpm= 840 psi, pump a total Annulus volume of 724 bbls. Page 3 of 11 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 13:30 14:30 1.00 MIRU WELCTL KLWL T Bullhead 235 bbls of seawater 3% KCL down the TBG.stage pumps up from 4 bpm=410 pis, 5 bpm =540 psi,6 bpm=666 psi, 7 bpm=874 psi, pump a total TBG volume of 235 bbls. 14:30 15:15 0.75 MIRU WELCTL OWFF P Monitor IA and TBG for 30 minutes. Flow check,well on Vac. Set BPV and intall Tree cap. 15:15 15:45 0.50 MIRU WHDBO SFTY P Pre-Job Safety Meeting-N/D Tree. 15:45 18:00 2.25 MIRU WHDBO NUND P N/D Tree and hang off on the off drillers side of the cellar. Clean TBG head flange, inspect Hanger threads and install blanking plug. _Fill IA every hour/first fill-3.4 bbls. 18:00 22:30 4.50 MIRU WHDBO NUND P N/U BOP's, install Riser, air boot, and flood BOP stack with water. 22:30 00:00 1.50 MIRU WHDBO BOPE P BOP test/witness waived by Matt Herrera AOGCC, 3/31 at 8:23 pm. Test Blinds, Choke valves 1,2,3,16, 4,5,and 6. 250 psi low, 2500 psi high. Total bbls to fill IA at 24:00 hrs=6.4 bbls. 34/04/2015 Finish testing BOPE. Pull Blanking plug and BPV. Slight blow, circulate 140 bbls Seawater down the TBG and fill the IA wtih 84 bbls. Pull and L/D the TBG Hanger and 1 joint of TBG. R/U and pull 4 1/2"TBG. 00:00 05:00 5.00 MIRU WHDBO BOPE P Continue testing BOPE. Test choke valves/7 thru 15, HCR choke, manual choke and kill valves. Test lower and upper rams and Annular preventer. Perform AOGCC and CPAI draw down on Koomey. Test 250 psi low and 2500 psi high. 05:00 08:00 3.00 MIRU WHDBO BOPE T Upper IBOP on TD failed test. Change out IBOP. Retest 250/2500 psi-pass. 08:00 09:00 1.00 MIRU WHDBO SVRG P Service rig,top drive, blocks and drawworks. 09:00 10:00 1.00 MIRU WHDBO SFTY P Pre-spud meeting with new crew. PJSM pulling BPV. 10:00 12:00 2.00 MIRU WHDBO MPSP P Empty stack, rig up and pull blanking plug. Lay down crossovers and joint. Plck up T-bar. Engage BPV. Fill stack and engage poppet on BPV to ensure no pressure underneath. 12:00 15:00 3.00 COMPZ RPCOM RURD P Load GBR equipment. Change out elevator bails and elevators. M/U landing joint,with TIW and Head pin on top of. Slight blow noted on IA, vent to kill tank to attempt and bleed off. Page 4 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:30 1.50 COMPZ RPCOM CIRC P Rig up and circulate 140 bbls down the tubing staging pumps up to 8 bpm 780 psi, no returns. Circulate 100 bbls down IA staging pumps up to 7 bpm 450 psi no returns. 16:30 17:00 0.50 COMPZ RPCOM OWFF P Monitor well,tubing on slight vac, IA on slight vac. R/D testing equipment 17:00 18:00 1.00 COMPZ RPCOM PULL P Back out lock down screws. Pull Hanger @ 145K, pull up 14'to clear Seal Assembly. Pull until Hanger was just below Annular preventer. Monitor well and fill IA. 18:00 21:30 3.50 COMPZ RPCOM RURD P R/U GBR tools and BAKER control TECH wire and Heat trace wire spooling units. Prep for pulling 4 1/2" IBTM Tubing. 21:30 22:00 0.50 COMPZ RPCOM SFTY P Pre-Job Safety Meeting-L/D TBG Hanger and pull)4 1/2"TBG. 22:00 00:00 2.00 9,386 9,264 COMPZ RPCOM PULL P L/D Landing joint, BIO TIW valve and XO. L/D Hanger and 1 TBG joint. L/D the long bails and R/U the short bails. Rack 1 stand of 4 1/2"TBG in the derrick and R/U the Spooling units sheaves. 04/05/2015 POOH with 4 1/2"Completion String f/9264' t11481'. Stand back TBG in the derrick. Drift and strap out of the hole. Spool Heat trace cable and TECH line. Fill IA with 25 bbls of Seawater every hour. 00:00 06:00 6.00 9,264 7,200 COMPZ RPCOM PULL P POOH with 4 1/2"Completion String f/9264' t/7200'Stand back TBG in the derrick. Drift and strap out of the hole. Spool Heat trace cable and TECH line. Fill IA with 25 bbls of Seawater every hour. 06:00 12:00 6.00 7,200 5,862 COMPZ RPCOM PULL P Continue POOH 4 1/2"completion string f/7200' t/5862'. Drift and strap out of the hole. Heat trace out of the hole and L/D. Contirnue to spool TECH line. Continue to fill the the IA 25 bbls/hr. Well took 300.6 bbs in 12 hrs. 147 clamps retrieved. L/D Joint#177,29.98'and P/U new joint 29.99'. 12:00 00:00 12.00 5,862 1,481 COMPZ RPCOM PULL P Continue POOH 4 1/2"completion string f/5682' t11481'. Drift and strap out of the hole. Continue to spool TECH line. Continue to fill the the IA 25 bbls/hr. Well took 300.6 bbs in 12 hrs. 147 clamps retrieved. L/D Joint#177, 29.98'and P/U new joint 29.99'.Total bbls Seawater pumped in 24 hrs=301.2 bbls. 04/06/2015 Pulled 4 1/2"completion string. Remove 9 5/8" Packoff and replace with new one.Test Packoff and lower Seals would not hold pressure. Remove Packoff and replace with another new Packoff. Removed running tool and pulled the Packoff past the lock down screws leaving the Seal ring on top of the 9 5/8"Emergency slips. Call for Baker Storm Packer for N/D of the BOP's. Page 5 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:30 3.50 1,481 148 COMPZ RPCOM PULL P POOH with 4 1/2"completion string to 148'. Continue to spoolTec wire. Set back 98 Stands of tubing in the derrick. Fill IA 25 bbls every hr. 03:30 05:00 1.50 148 0 COMPZ RPCOM PULL P L/D Sliding Sleeve,w/DB nipple profile. L/D DB nipple, Gauge mandrel, Locator and Seal assembly. 05:00 06:30 1.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. Lay down Tec Wire spool. 06:30 07:30 1.00 0 0 COMPZ WELLPF WWWH P Wash BOPE stack. 07:30 09:30 2.00 0 0 COMPZ WELLPF WWSP P Pick up Packoff retrieval tool. BOLDS. Engage IC pack off and POOH. Install new pack off. 09:30 12:45 3.25 0 0 COMPZ WELLPF WWSP T Attempt to energize and test packoffs. Pump JR between upper seals to energize on both sides of wellhead. Attempt to maintain pressure between upper seals on packoff, unable to. Continue to work; procedural error. Able to get pressure to hole in upper seal section. 12:45 15:00 2.25 0 0 COMPZ WELLPF WWSP T Attempt to test packoff void 250/2400 psi. Unable to pressure up. Discuss options with Vetco town. Second wellhead hand on location to assist. Vetco hand suspect hydraulic pump failed. Switch out pumps, build fitting for hoses. Still unable to pressure up on void 15:00 17:30 2.50 0 0 COMPZ WELLPF WWSP T Make up retrieval tool. Engage IC pack off, and pull. Took 10-12K to pull free. Inspect Packoff, seals in good condition. 17:30 18:15 0.75 0 COMPZ WELLPF WWSP T Discuss Options with Engineer and Vetco town. Order out Storm packer. Second new packoff on location 18:15 22:00 3.75 0 0 COMPZ WELLPF WWSP T Make up new IC Packoff and set Packoff. Removed running tool, Running tool did not release and pulled the Packoff past the lock down screws.The Seal ring was left on top of the 9 5/8"Emergency slips. Wrong Seal ring on Packoff. Called for Baker Storm Packer for N/D of the BOP's. 22:00 00:00 2.00 0 0 COMPZ WELLPF WAIT T Prep for running the Storm Packer _ and the N/D of the BOP's. 04/07/2015 Set Storm Packer.30 minute flow check on OA.Test Packer and N/D BOP's.Wait on casing tools due to Phase II conditions. N/D TBG spool. Pull casing up 11"and set slips. Cut casing 2"below bottle neck and dress cut for intallation of Packoff. 00:00 02:30 2.50 0 0 COMPZ WELLPF MPSP P P/U and run Baker Storm Packer, set at 276'. Page 6 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:00 0.50 0 0 COMPZ WELLPF OWFF P Flow check OA for 30 minutes. No flow. 03:00 03:30 0.50 0 0 COMPZ WELLPF MPSP P Pressure test Storm Packer to 1000 psi for 10 Minutes. 03:30 06:00 2.50 0 0 COMPZ WELLPF NUND P Nipple Down BOP's. 06:00 09:00 3.00 0 0 COMPZ WELLPF WAIT P Waiting on Vetco Gray service hands, 9 5/8" Packoff, and Baker Spear. Phase II conditions, all trucks buses had to be escorted to the rig. 09:00 12:00 3.00 0 0 COMPZ WELLPF NUND P N/D TBG spool as per Vetco Gray Rep. 12:00 15:30 3.50 0 0 COMPZ WELLPF BHAH P P/U all tools necessary to run Baker Casing Spear. Change elevators to 4"and P/U 1 joint of 4"DP and M/U Baker Casing Spear. 15:30 18:30 3.00 0 0 COMPZ WELLPF CUTP P Engage casing with casing spear. P/U to 150K and continue coming up slowly to 250K.The casing came up 8"above the well head flange and the emergency slips were set. Percautions were taken not to exceed the yield of the casing patch at 4834'. 18:30 20:00 1.50 0 0 COMPZ WELLPF CUTP P Consulting with Vetco Gray Rep he proposed to pull 2"more. If the cut is made at the bottle neck of the casing,there is a possibility of not getting a good test on the Packoff. Consulting with Vetco Gray engineering, they had determined as much as 400K could be pulled before affecting the Casing Patch.After consulting with the CPAI WO Engineer,the decision was made to pull 2". P/U to 150K and slowly P/U to 275K. The casing came up to 2"and the emergency slips set. 20:00 20:30 0.50 0 0 COMPZ WELLPF BHAH P B/D Spear and L/D 4" DP and tools. 20:30 23:00 2.50 0 0 COMPZ WELLPF CUTP P R/U FMC casing cutter. Cut casing 2"below the bottle neck. Dress cut with grinder and clean up all metal shavings from slips. 23:00 00:00 1.00 0 0 COMPZ WELLPF WWSP P Install 9 5/8" Packoff. Clean TBG spool sealing surface and prep to N/U TBG spool. 34/08/2015 N/U TBG Spool and intall 9 5/8"Packoff. Test Packoff, 1,500 psi Upper Seals and 2,400 psi Lower Seals. N/U and test BOP's and TBG Spool break. Release Storm Packer and Kill well. Pull Storm Packer and test Annular Preventer. R/U and Run 4 1/2"TBG Completion String. 00:00 03:00 3.00 0 0 COMPZ WELLPF NUND P N/U TBG spool and install 9 5/8" Packoff. 03:00 03:30 0.50 0 0 COMPZ WELLPF PRTS P Install and test upper Packoff Seals to 1500 psi and lower Seals to 2400 psi for 30 minutes. Both tests were good. Page 7 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 06:00 2.50 0 0 COMPZ WELLPF NUND P N/U BOPE 06:00 07:30 1.50 0 0 COMPZ WELLPF WAIT T Wait on VETCO GRAY test plug to arrive. 07:30 10:00 2.50 0 0 COMPZ WELLPF BOPE T Body tes BOP's and TBG Spool break,250 psi low/2500 psi high. 10:00 11:30 1.50 0 0 COMPZ WELLPF PULL T Retrieve Storm Packer at 278'and 10 Stands of TBG under it. Close Annular Preventer and IBOP. Open Ports on Packer, 50 psi on casing. 11:30 15:00 3.50 0 0 COMPZ WELCTL KLWL T Bleed 50 psi to Kill tank. Bullhead 64 bbls @ 2 bpm.Veryify no flow and open Annular. Fill hole with 17 bbls of Seawater. 15:00 15:30 0.50 0 0 COMPZ WELCTL OWFF T Monitor well for 30 minutes, no flow. 15:30 18:30 3.00 0 0 COMPZ WELLPF MPSP T POOH/Storm Packer and 14 stands of TBG. Fill well 25 bbls/ hr.1.5 18:30 20:00 1.50 0 0 COMPZ WELLPF BOPE T Test Annular Preventer to 250 psi low and 2,500 psi high. 20:00 21:30 1.50 0 0 COMPZ RPCOM RURD P R/U to run 4 1/2"TBG Completion String. Check running order of BHA. 21:30 22:00 0.50 0 0 COMPZ RPCOM SFTY P Pre-Job Safety Meeting, running 4 1/2"Completion String with Tec wire. 22:00 00:00 2.00 0 504 COMPZ RPCOM PUTB P P/U Seal Assembly with Locator and Gauge Mandre. M/U Tec wire. Contirnue to P/U DB nipple, Sliding Sleeve and GLM with Dummy Valve. Test wire and Gauge Mandre every 1000'. 348 bbls of Seawater lost. 04/09/2015 Run in the hole with 4 1/2"completion string.Attempt to Locate, could not sting into ZXP packer. POOH with 4 1/2"completion string. 00:00 12:00 12.00 504 8,765 COMPZ RPCOM PUTB P Run in the hole wtih 4 1/2"TBG Completion String withTec wire. Run from 504'to 8,765. RunTec wire clamps every other joint.Test Tec wire every1,000'. Used146 clamps. 12:00 13:00 1.00 8,765 9,310 COMPZ RPCOM PUTB P Continue to run 4 1/2"Completion String from 8,765'to 9,310'. total clamps used 148. PUW 98k/ SOW 50K. 13:00 18:00 5.00 9,310 9,310 COMPZ RPCOM HOSO T Locate with joint 299, roll 1/2 turn to sting into ZXP liner packer.Tag early at a Gauge Mandrel,question about the GM OD vs Tie back sleeve. GM OD=6.25"/Tie back sleeve= 6.75". 18:00 00:00 6.00 9,310 4,843 COMPZ RPCOM PULL T Pull 4 1/2"Completion String. Spool Tec wire and test every 1000'. Plan forward: Pull out of the hole, inspect and gauge GM, Seal Assemelby and Mule shoe. P/U 1 joint of TBG and place above the first joint of TBG at the Seal Assembly. 04/10/2015 POOH with 4 1/2"Completion string. M/U 4 1/2"Compltion BHA and run in the hole. M/U handling equipment for circulating and spacing out. Page 8 of 11 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 07:00 7.00 4,843 0 COMPZ RPCOM PULL T Continue to Pull 4 1/2"Completion String. Spool Tec wire and test every 1000'from 4,893-ft to Seal assy. Found 1"x 2.75"long piece of SS band stuck in first seal above mule shoe. Markings show to be pressed into entry of SBE top. Pictures are in the GKA well file 07:00 09:00 2.00 0 0 COMPZ RPCOM RURD T Clean and clear rig floor area in preparation of RIH. Cut 1"off mule shoe in order to create half mule shoe 09:00 11:00 2.00 0 263 COMPZ RPCOM PUTB T PJSM, PU, MU and RIH w/1/2 mule shoe w/17-ft seal assy, 5.188"OD Locator sub, 6-ft pup joint,2 jts, 2- pup joints w/gage carrier installed in between, 1 joint, MU Sure SENS pressure gauge, Continue to RIH installing SC Xcplg Cannon clamps on every other joint. PU, MU and RIH w/3.75" DB Nipple, 1 joint, Baker CMU Sliding sleeve w/2.813" DB Profile, 1 Joint, GLM#1 w/ dummy installed. to 263-ft. 11:00 19:30 8.50 263 7,276 COMPZ RPCOM PUTB T Continue to RIH w/4-1/2 IBTM completion string from 263-ft with tubing stands while installing single channel Xcplg cannon clamps from 263-ft to 7,276-ft 19:30 19:45 0.25 7,276 7,282 COMPZ RPCOM PUTB T PU, MU and RIH w/GLM#2 w/SOV 19:45 22:00 2.25 7,282 9,341 COMPZ RPCOM PUTB T Continue to RIH w/4-1/2 IBTM completion string from 7,282-ft with tubing stands while installing single channel Xcplg cannon clamps from 7,282-ft to 9,341-ft 22:00 00:00 2.00 9,341 9,341 COMPZ RPCOM HOSO P MU handling equipment for circulating and spacing out. SOW= 50K/PUW 95K, (3 1/2 ft)stretch. Ready to Locate and Space out. 04/11/2015 Locate and Space out. Spot corrosion Inhibitor in IA. M/U and land Hanger. Test IA and Shear out of SOV. Set TWC and N/D BOP's.Test Tec wire. 00:00 02:00 2.00 9,341 9,387 COMPZ RPCOM HOSO P P/U joints 300 and 301 to Locate. Top of Seal Bore 9,376'.Tag the bottom of Seal Bore Extension at 9,393'. Pulled up and layed down Joints 301, 300 and 299. M/U Hanger with 1 joint of TBG on the bottom and a 2'pup. Spaced out 5'to 9,385. 02:00 04:30 2.50 9,385 9,387 COMPZ RPCOM RURD P Install TIW valve in landing joint. Splice Tec wire and R/U to spot inhibitor down the IA. Page 9 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 09:00 4.50 9,387 9,387 COMPZ RPCOM CRIH P Pump 420 bbls of CI 8.7 ppg Brine and follow with 100 bbls of Clean 8.7 ppg Brine down IA. Pump 4 bpm of inhibitor. off of Vac trucks. 09:00 12:00 3.00 9,387 9,387 COMPZ RPCOM THGR P Land Hanger as per VETCO-GRAY, PUW 95K/SOW 50K. Line up side port on Hanger and run in the LDS's. 12:00 12:30 0.50 9,387 9,387 COMPZ RPCOM OWFF P Monitor well for 30 minutes. 12:30 13:30 1.00 9,387 9,387 COMPZ RPCOM PRTS P Test IA at 2500 psi for 30 minutes, bring pressure up to 4100 psi and shear out of SOV. Bleed pressure off and B/D lines. 13:30 14:00 0.50 9,387 9,387 COMPZ WHDBO MPSP P P/U Lubricator andLubricate TWC in. 14:00 16:00 2.00 9,387 9,387 COMPZ WHDBO OTHR P Clean out mud system, under rotary table, pipe rack and rig floor. Rinse pits and B/D lines. 16:00 16:30 0.50 9,387 9,387 COMPZ WHDBO SFTY P Pre-Job Safety Meeting/N/D BOPE 16:30 18:00 1.50 9,387 9,387 COMPZ WHDBO NUND P N/D BOPE, remove riser, mouse hole and N/D BOP's/ 18:00 18:30 0.50 9,387 9,387 COMPZ WHDBO SFTY P Pre-Job Safety Meeting/prep Tree fo N/U. 18:30 22:00 3.50 9,387 9,387 COMPZ WHDBO NUND T Prep well head and Tree adaptor for N/U.Test Tec wire,would not test. Trouble shoot computer, computer would not give read back of test. 22:00 00:00 2.00 9,387 9,387 COMPZ WHDBO WAIT T Trouble shoot Baker Computer. Computer would not give read back of test. Baker Service hand went to KOC for another computer. 34/12/2015 Test Tree to 5000 psi. Spot corrosion inhibitor in the tubing. Freeze protect well. Set BPV and secure well. Rig Released 23:59 hrs 4/12/15 00:00 02:00 2.00 9,387 9,397 COMPZ WHDBO NUND T Trouble shoot Baker Computer. Computer would not give read back of test. Baker Service hand went to KOC for another computer. Good test with new computer. 02:00 03:00 1.00 9,397 9,387 COMPZ WHDBO PRTS P R/U Vetco Gray and test Hanger and spool adaptor to 5000 psi for 10 minutes. 03:00 06:30 3.50 9,387 9,387 COMPZ WHDBO PRTS T Test Tree 250 psi Low/5000 psi high.Would not test due to leaking TWC. Bled pressure off and pressured up on TWC pop-it to seat it. Test failed, pop-it would not seat. 06:30 07:30 1.00 9,387 9,387 COMPZ WHDBO PRTS T Pressure test Master valve to 5000 psi. Install Lubricator and test to 1000 psi. 07:30 08:30 1.00 9,387 9,387 COMPZ WHDBO PRTS T Install Lubricator and test to 1000 psi. 08:30 10:30 2.00 9,387 9,387 COMPZ WHDBO MPSP T Lubricate TWC out of wellhead and intall new one. Page 10 of 11 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 9,387 9,387 COMPZ WHDBO PRTS P Pressure testTree to 5000 psi for 5 minutes. 11:00 11:30 0.50 9,387 9,387 COMPZ WHDBO OTHR P Install and pressure test Lubricator to 1000 psi. 11:30 12:30 1.00 9,387 9,387 COMPZ WHDBO MPSP P Lubricate TWC out of wellhead. 12:30 13:00 0.50 9,387 9,387 COMPZ WHDBO CRIH P R/U an prep well to pump corrosion inibitor down the TBG. 13:00 14:00 1.00 9,387 9,387 COMPZ WHDBO CRIH P Pump 114 bbls of corrosion inhibitor down the TBG. Spot inhibitor with 29 bbls of brine. Spot corrosion inhibitor at 7,355'with 9 bbls of inhibitor in the Seal Bore. 14:00 16:30 2.50 9,387 9,387 COMPZ WHDBO FRZP P Freeze protect, pump 31 bbls of diesel down the TBG and 107 bbls down the IA.Top of diesel in the TBG 2,172'.Top of diesel in the IA 1,904'. 16:30 19:00 2.50 0 0 COMPZ WHDBO MPSP P Lubricate and set BPV into the wellhead. R/D lubricator and install Tree cap. 19:00 22:00 3.00 0 0 DEMOB MOVE RURD P Secure Tree and prep cellar for Move to 2G-02. 22:00 00:00 2.00 0 0 DEMOB MOVE RURD P R/D equipment and prep for rig move. Rig Released 23:59 hrs 4/12/15 Page 11 of 11 K tk (E-17 P D za u4.o Regg, James B (DOA) From: Nabors 9ES Co man <Nabors9ESComan@conocophillips.com> Sent: Wednesday, April 08, 2015 2:04 PM To: DOA AOGCC Prudhoe Bay Cc: Coberly, Jonathan; Rauchenstein, Rock D Subject: 1E-170 Nabors 9ES Pre - Annular closure before opening of safety valve on 9.625" OD Baker Storm Packer All, On Nabors 9ES while conducting a West Sak Producer RWO API#50-029-23264-00 PTD#205-074, We closed the annular in anticipation of trapped gas below Baker storm packer set 276-ft w/4-1/2 TBG tail set at 1,329-ft on 4-7- 15. When opening the equalizer valve we seen 60 psi SIP. We then bullheaded 100 bbls of 8.8 ppg Kill Weight Brine, Opened well from IA valve to off rig choke house and bled gas cap to tiger tank. We will set plug and test annular when get out of the hole w/4-1/2 TBG tail, prior to RIH w/4-1/2 Completion. Thank you, Randy Dolcater/John Haynes Nabors 9 ES Company Men 907-659-7718 Office 907-659-7614 Rig 1 o ~ 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. ~~ - Q ~ ~- Well History File Identifier Organizing (done> ^ Two-sided III II~III II III II III ^ Rescan Needed III VIII) II II III III RESCAN ~j Color Items: ^ Greyscale Items: ^ Poor Quality Originals: DIGITAL DATA Diskettes, No. g ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ''J ^ Other::. BY: Maria Date: ~ I ~ / Q /s/ Project Proofing III IIIIIIIIIII VIII BY: Maria Date: ~~ D /s/ Scanning Preparation ~ x 30 = ~~ + ~ =TOTAL PAGES f / ~ ~ ~ ~ ~ (Count does not i ~S~ude cover sheet) ' n /~ BY: Maria Date: I( I/' Production Scanning Stage 1 Page Count from Scanned File: ~ ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~ YES _ BY: Maria Date: ~ ~ ~ ~/~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s/ ~-t~ NO { "iiiiumimuiu ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III III III P 10/6/2005 Well History File Cover Page.doc ~• ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 26, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: .~c_s c?~~ ~ • ~~. ~~ ~~~ von ~~~~~"~~'9~ : ~tf r ,,, . ~`i~ F_ ~ ~ Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1 E-170, 1 E-170L 1, 1 E-170L2 concentric gaslift mandrel installation. Please call Brent Rogers or myself if you have any questions. Sincerely, ~~w~ Martin Walters Problem Well Supervisor ~~ ~ ~ ~ 0 2009 s • ,~P STATE OF ALASKA ~1as~a Oi~ ~ Gus Cans. Cammissiol~ ALASKA OIL AND GAS CONSERVATION COMMISSION Ant;~orage REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ Install CGLM Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^/ Exploratory ^ 205-074/ 3. Address: Stratigraphic ^ service ^ 6. APt Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23264-00 ' 7. KB Elevation (ft): 9, Well Name and Number: RKB 42' 1 E-170 ` 8. Property Designation: 10. Field/Pool(s): , ADL 25651'/25660 ' Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15940' • feet true vertical 3354' • feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 120' 20" 162' 162' SURFACE 5012' 13-3/8" 5054' 2312' INTERMEDIATE' 10372' 9-5/8" 10414' 3451' D-SAND WINDOW 10' 9-5/8" 9412' 3276' B-SAND WIND01 5' 9-5/8" 9879' 3350' A SAND LINER 6049' S-1 /2" 15919' 3356' Pertoration depth; Measured depth: Intervals from 10,438' -15,874' true vertical depth: Intervals from 3359' -3492' Tubing (size, grade, and measured depth) 4-1 /2", L-80, 9386.74' MD . 2.441" Concentric GLM set in CMU sliding sleeve ~ 9221' MD Packers &SSSV (type & measured depth) Baker 2.XP 9308' SSSV = 3.875 "DB" Nipple at 558' 12. Stimulation or cement squeeze summary: intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ` Service ^ Daily Report of Well Operations X 16. Well Status after work: CQ • Ga~ WAG^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: N/A contact Brent Rogers/Martin Walters Printed Name Martin Walters Title Problem Well Supervisor Signature ~~/ 65s-7224 Date 4/26/2009 Form 10-404 Revised 04/2006 = . ,_ ,. ~: ~~~ty ~'~ ~ IOD~ Submit Original my 1 E-170 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/7/2009 SET CAT-SV @ 9277 CTMD, FLUID PACK TUBING & IA WITH 663 BBLS DIESEL, PERFORMED SUCCESSFUL TXIA MIT 4/8/2009 CLOSED CMU, PERFORMED SUCCESSFUL TUBING MIT, PULLED CAT-SV & OPENED CMU. UNABLE TO SET CONCENTRIC GLM. RTN IN A.M. 4/11/2009 SET CONCENTRIC GLM IN CMU @ 9213 CTMD, JOB COMPLETE, 4/15/2009 Re-TIFL (passed ), T/I/0= 225/850/5. SI well and gas lift, shot initial IA-FL @ 9101'. Stacked well T/I/0= 675/700/5. Bled IA, T/I/0= 725/300/0. Shot second IA-FL @ same location. 15 min ost bleed and final T/I/0= 725/300/0. RE: 1E-170 (PTD# 205-074, 205-075, 205-076) Notification Of Gaslifting With TxIA Co... Page 1 of 3~ Maunder, Thomas E (DOA) From: NSK Problem Wetl Supv [n1617@conocophillips.com] Sent: Friday, April 17, 2009 12:27 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); NSK Problem Well Supv Subject: RE: 1E-170 (PTD# 205-074, 205-075, 205-076) Notification Of Gaslifting With TxIA Communication Tom, On 04/11/09, CTU was able to set the concentric GLM across the sliding sleeve @ 9221'. On 04/15/09 the well passed a TIFL. The 10-404's will be in the mail for the CGLM that was set. 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 I 11 h ..~ i~ Y ~.ooi_++r~ F :Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: nday, April 06, 2009 11:29 AM To: NSK lem Well Supv Cc: NSK We k Prod Engr; N5K Well Integrity Proj; CPFi DS Lead Techs; Pierson, is R; Jenkins, Lubbie Allen; Regg, Jam (DOA) Subject: RE: 1E-17 D# 205-074, 205-075, 205-076) Notification Of Gasli With TxIA Communication Walter, Continuing to produce is not an ue. Keep us advised. Tom Maunder, PE AOGCC From: NSK Problem Well Supv (mailto:n1617@c c i Sent: Monday, April 06, 2009 10:31 AM To: Maunder, Thomas E (DOA) Cc: NSK West Sak Prod Engr; NSK Problem ell Supv; N5 Chris R; Jenkins, Lubbie Allen Subject: RE: 1E-170 (PTD# 205-07 05-075, 205-076) Tom, Integrity Proj; CPF1 D5 Lead Techs; Pierson, Of Gaslifting With TxIA Communication Due to difficulties work on wells preceding the 1 E-170, The job has been postpone and is now scheduled to start tomorrow esday 4/7/09). CPAI re ests a 7 day extension through 4/12/09 to continue producing the 1 E-170 with TxIA co unication by usin CMU sliding sleeve to gaslift. 4/17/2009 RE: IE-170 (PTD# 205-074, 2075, 205-076) Notification Of Gasliftin~With TxIA Co... Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 06, 2009 11:29 AM To: 'NSK Problem Well Supv' Cc: NSK West Sak Prod Engr; NSK Weii Integrity Proj; CPF1 DS Lead Techs; Pierson, Chris R; Jenkins, Lubbie Allen; Regg, James B (DOA) Subject: RE: 1 E-170 (PTD# 205-074, 205-075, 205-076) Notification Of Gaslifting With TxIA Communication Walter, Continuing to produce is not an issue. Keep us advised. n k~ ?~~! Tom Maunder, PE ~~,,~`~~ ~~~ ~~ `~ AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, April 06, 2009 10:31 AM To: Maunder, Thomas E (DOA) Cc: NSK West Sak Prod Engr; NSK Problem Well Supv; NSK Well Integrity Proj; CPF1 DS Lead Techs; Pierson, Chris R; Jenkins, Lubbie Allen Subject: RE: 1E-170 (PTD# 205-074, 205-075, 205-076) Notification Of Gaslifting With TxIA Communication Tom, Due to difficulties with work on wells preceding the 1 E-170, The job has been postponed and is now scheduled to start tomorrow (Tuesday 4/7/09). CPAI requests a 7 day extension through 4/12/09 to continue producing the 1 E-170 with TxIA communication by using a CMU sliding sleeve to gaslift. Martin From: NSK Problem Well Supv Sent: Thursday, April 02, 2009 9:53 AM To: 'tom.maunder@alaska.gov' Cc: NSK West Sak Prod Engr; NSK Problem Well Supv; NSK Well Integrity Proj; CPF1 DS Lead Techs; Pierson, Chris R; Jenkins, Lubbie Allen Subject: RE: 1E-170 (PTD# 205-074, 205-075, 205-076) Notification Of Gaslifting With TxIA Communication Tom, As per our conversation, we are continuing to gaslift the 1 E-170 through an open CMU after being unable to get a passing test on the initial setting of a concentric gas lift mandrel. Our previous approval allows us to continue flowing in this condition until 4/5/09 but our justification has changed. CPAI plans to mobilize a coiled tubing unit to the well tomorrow (4/3/09) to diagnose the problem and ultimately install a new valve in the CMU. If the problem cannot be remedied this weekend, I will contact you on 4/6/09 for consideration of an extension. Please contact me at your convenience if you have questions or comments. Martin 4/6/2009 RE: IE-170 (PTD# 205-074, 2075, 205-076) Notification Of Gasliftin~With TxIA Co... Page 2 of 3 Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 From: NSK Problem Well Supv Sent: Sunday, March 08, 2009 1:37 PM To: 'tom.maunder@alaska.gov' Cc: NSK West Sak Prod Engr; NSK Well Integrity Proj; CPFl DS Lead Techs; Pierson, Chris R; Jenkins, Lubbie Allen; NSK Problem Well Supv Subject: RE: 1E-170 (PTD# 205-074, 205-075, 205-076) Notification Of Gaslifting With TxIA Communication Tom, Due to unforeseen issues obtaining the proper size POGLM (concentric gas lift valve) to cover the open CMU, well 1 E-170 (PTD #205-074, 205-075, 205-076) will remain online in gas lift service for an additional 28 days with an open CMU. Please contact us if there are any issues with the time extension. Ian Ives & MJ Loveland Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 From: NSK Problem Well Supv Sent: Friday, February 06, 2009 10:52 AM To: 'tom.maunder@alaska.gov' Cc: NSK West Sak Prod Engr; NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 DS Lead Techs; Pierson, Chris R; Jenkins, Lubbie Allen Subject: 1E-170 (PTD# 205-074, 205-075, 205-076) Notification Of Gaslifting With TxIA Communication Tom, West Sak tri-lateral producer 1 E-170 (PTD# 205-074, 205-075, 205-076) underwent a rig workover that was completed on 01 /27/09. The work consisted of converting from a failed packerless ESP utilizing gaslift to a traditional gaslift configuration. As a part of the post rig procedure, ConocoPhillips intends to produce the well using gaslift through an open Baker CMU sliding sleeve at 9221' MD (3243 TVD) until the well cleans up and a production profile can be completed. Once the profile is complete, we will install a concentric gaslift valve in the sliding sleeve and resume continuous gaslift operations. Since there will be TxIA communication while gaslifting through the CMU, CPAI does not plan to do so for more than 28 days from the date that the CMU is opened. Should it be necessary to extend the flow period beyond 28 days, we will request permission to do so at that time. Until the well is operated under normal conditions, it will be 4/6/2009 RE: 1E-170 (PTD# 205-074, 2075, 205-076) Notification Of Gasliftin~With TxIA Co... Page 3 of 3 included in the SCP report. Attached is an updated wellbore schematic. « File: 1 E-170 Wellbore Schematic.pdf » Please contact meat 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 4/6/2009 Maunder, Thomas E (DOA) • Page 1 of 2 From: Long, Jill W [JiII.W.Long@conocophillips.com] Sent: Tuesday, March 24, 2009 10:23 AM To: Maunder, Thomas E (DOA) Subject: FW: 1 E-170 (205-074) Attachments: 1 E-170 Multi-lat Drawing_Post RWO 2009.pdf; 1 E-170 Pre and Post RWO work.pdf Tom, Attached are the follow-up documents for 1 E-170. Please let me know what additional information you need. Thanks, Jilt Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-240-6574 Fax: 918-662-6330 From: Long, Jill W Sent: Monday, March 23, 2009 4:58 PM To: 'Maunder, Thomas E (DOA)' Subject: RE: 1E-170 (205-074) Tom- _ ~; I received your email on 1 E-170 and have responded below. I plan to provide you with the supporting documents that I reference but if you would like additional information or clarification just let me know. Thanks, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-240-6574 Fax: 918-662-6330 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, March 21, 2009 3:00 PM To: Long, Jill W Subject: 1E-170 (205-074) 3/25/2009 Page 2 of 2 Jill, I am reviewing the 404 for the recent workover on this well and have some requests. 1. Was any pre-rig work accomplished? If so, would you please send that summary. Yes- summary will be provided tomorrow. 2. Was a BPV set for move on? Yes. 3. Since this well is a multilateral, the "straight" drawing is a little confusing. Can you provide a simple drawing such as provided with the PTD application that illustrates the total 1E-170? Yes- schematic will be provided as soon as it is ready (hopefully tomorrow). 4. With different tubing depths, it is clear additional tubing was added. Was the old tubing rerun? It isn't clear from the operations report. Yes- the old tubing was re-ran. 5. Were 404s submitted for 1E-170L1 and 1E-170L2 as well? No. All the work was completed in the motherbore and since the LEM had already been previously installed, nothing changed with regards to the laterals. It is possible that they weren't needed since all the work appears to have been accomplished in the motherbore, but I will need you to confirm that. Thanks in advance. Email is fine. Call or message with any questions. Tom Maunder, PE AOGCC 3/25/2009 ~7 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION F~ `~ .~ ~ REPORT OF SUNDRY WELL OPERAT~n~ £. ~~~ ~~_. 2oas t. Operations Performed: Abandon ^ Repair Well ^ ' Plug Pertorations ^ Stimulate ^ OtI~G~OfB~@ Alter Casing ^ Pull Tubing ~ ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ~ ' Exploratory ^ 205-074 / 3. Address: Stratigraphic ^ .Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23264-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' - 1 E-170 8. Property Designation: 10. Field/Pool(s): ADL 25660. Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15940' ' feet true vertical 3355' feet Plugs (measured) Effective Depth measured 15940' feet Junk (measured) true vertical 3355' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 40' 20" 120' 120' SURFACE 5014' 13-3/8" 5054' 2311' INTERMEDIATE 10373' 9-5/8" 10414' 3451' LINER 6049' 5.5" 15919' 3355' Perforation depth: Measured depth: alternating slotted/solid li ner from 10438'-15874' true vertical depth: 3456'-3355 ' ''(( ~~~) q/R~/(.-~ a ~r~V /~1~~ 713. Tubing (size, grade, and measured depth) 4.5", 3271', 9387' MD. Packers & SSSV (type & measured depth) A sand 2:XP liner top pkr, SB E @ 9870', 9902' Baker'DB' nipple @ 558' 12. Stimulation or cement squeeze summary: r-- ~p Intervals treated (measured) not applicable Treatment descriptions including volume s used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 460 825 62 -- 273 Subsequent to operation 867 ~ 672 596 -- 253 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: none Contact Jill Long @ 263-4093 Printed Name Jill Long Title Wells Engineer ? G~ ~ ~ Signature Phone: 263-4093 , 1 Date o 21 ~/ Pre ar b Shar Allsu Drake 263-4612 Form 10-404 Revised 04/2006' t t ~'~ ~ a ,~d?j , Submit Orrigina Only ~~ 558' MD-3.675" DB Nipple .2100' MD - GLM. Camco d-1/2" % 1" KGB-2-1 R race Cable ro 3,000' MD b28' MD -9-518" x 13J/8" JMZXP Teback Packer 0831' MD -9-618" x 1JJ18" FkxLock Liner Hanger with HRD Sleeve ~ 0836'-0864' MD-EXPatch ezparMabk patch w18.00"ID 9221 MD 6MU SOding Skew, 4•K x 3.873 DB Profk i 9276' MD- 3.750" DS Nlppk Guartlian Gauge Carrier 5054' MD - 73-318" Casing Shoe, 68#, L-B0, BTC set, 2311' TVD 8308' MD -7" X 9-SIB" ZXP Liner Top Packer wkh Hold Downs 9397' MD-Tubing 9370' MD - Gsing Seabore Receptacle Swlw4 4-712" ~~ a7S' ID, 5.75' OD 20' Lengtlt 9012' MD -7" %9518" / ModN'B' HOOK Hanger Seal Bon 7.68"ID 9407' MD -Lateral Entry Module (LEM) OrknKng Pro/ile ConocoPhillips West Sak 9-5/8" Producer 1 E-170 Tri-Lateral Completion WP 09 'D' Sand Lateral 9412' MD - D-sand Window, 3275' TVD, 67 deg inc 5.712" 15.5x, L-0O Sbttetl Liner _ ~ 9554' MD -5-112" PayZone ECP / 5-112" Guide Snoe 15736' MD - 5-712" Casing Shoe, 15.5#, L-80 BTCM, 3185' TVD 9710' MD -T' %95/8" Z%P Winer Top Packer 1 'th Hold Downs Assembly _ 7" X 9-5/8" ZXP Liner Top Packer with Hold Downs 7.500" Tieback Ext.ID 6.278" Tool Body ID Casing Sealbore Receptacle 0.75" ID, 5.75" OD 20' Length - Tubing Swivel, 0-712" - Orienting Profile Automatic Alignment of LEM - Postive Latching Collet Indicates Correct Location ~ Seal Bore for Cabral Isolation - 3.68x" ID ~~~ Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.688" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID 2' Length 9730' MO • Casing Sealbore Receptacle a7s° lD. s.7s• oD 20' Lergm 9772' MD -7" X 9-516" Motlel'B' HOOK Hanger \ ~ 9612' MD - 7" Tieback Sleeve 9622' MD -5.112" bent joint 9739' MD - Bottom d Seal Assembly 6.75' Seal OD 3.875' ID ~/ _ 9750' MD -Tubing Swfw4 6-112" 9758' MO -Lateral Entry Module (LEM) Orienting Profile 9778'MD-B-sand Window, rBr Sand Lateral / 3331' TVD, BOdeg ine 9860' MD -5-112" .` PayZone ECP 5-112" Guide Shce ~ 15745' - MD 5-1/2" Casing Shoe, 15.5#, Seal Bores ~ \ 9950' MD - 7" Tieback Sleeve L-80 BTCM, 3231' TVD 3.68" ID j 9926' MD - 5-712" bent joint btl2"12.61 Tubing 3.833" Drift 3.958"ID 7" X 9-5/8" ZXP / ~ \ Liner Top Packer 7.500" Ezt. ID 6.278" TooIID \ 7" X 9-SIB" Fkx Lotk Liner Hanger 9870' MD -Liner Hanger I Packe~ fi.276" ID Assembly / / 9902' MD -Casing Sealbore Reeepkck 0.75' ID, 5.75" OD ZO' LengM BAK~~s Rn krr Oil Tnols As Completed Lateral With Di Entrv Module (LEMI rt d I l ti ve ers an so a on Lateral Access Diverter Lateral Isolation Diverter GS Running Tcol String Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbor e Drill) 'GS' Profk for Coll Connector (Running/Retrieving ,y (1.00'Length) ~ ~ Snap ln/Snap Out r Back Pressure Valve % Posaiw LocaHng~+ C ~t (1.60' Length) O Laeerallxokdon-~' I r Flow-Thru Swivel Seals (1.25' Length) Lateral Diverter / _.- Hydraulic Ramp ; ' Disconnect ' IsoktbN Mainbore r '~ (1.50 Length) Diverter Sleety ~ _, _ _ - GS Spear (7.50'Len9m) ," l.akral lsdation~ ',; 8.85 ft Approx. Seals ;,. OAL' 'Jars may be requiretl in highly deviated 19' Diverter Lenglh 7g' Skew Length or deep applicatbns (6' approx length). 1 5-112" 75.50, L-00 Blank antl Sbtted Liner 9912' MD -Bottom of Seal Assembly 6.75' Seal OD / 3.875•ID 'A' Sand Undulating Lateral 5-712" 75.SN, L-00 Sbtted and Bknk Liner 5-712" Gukle Shoe E~{uinment Specifications 7" X 9-518" HOOK Hanger Mainbore Drift: 7.00" Mainbore Drift, with diverter: 6.25" Lateral Drih, no diverter or LEM: 6.28" Lateral Driftt, wl diverter, no LEM: 5.12" LateraOMainbore Diverter OD: 6.50" 4112" Lateral Entry Module Mainbore Drift: 3.68" Mainbore Drift, w/ isolation sleeve: 2.50" Lateral Drift, w/ coil diverter: 3.00" OD of Diverter and Sleeve: +I_ 3.60" Diverter and Sleeve Length: +1-19' 15919' MD - 5-112" Casing Shoe, 15.5#, BTCM, 3354' TVD 10414' MD - 9-5/8" Casing Shoe, 40.0#, L-80 BTC, 3451' TVD ¢~ Baker Hughes 2005. This dxument may not be reproduced or distributed, n whole er In part, in any norm or by (77 deg inc) anv mean> elacuonk or m«nanioal, molvam9 pnorocopyin9. r«omir,9. or br am mrorma0on>rora9. «,6 retrieval system now known or nereatter inventee, witnout mitten permissron from Bawer Hughes Inc. ~. ConocoPhiltips Ai~;~. .t. II Y'. ... ,_ ~_.,_- Well F4! -1E~170, Shcernetk.:. nc HANGER, 40 CONDUCTOR. 0-120 Heat Tmce. 0 - GAS uFT. z,1oo SURFACE.- __ 0-5.054 SLEEVE, s.n1 NIPPLE. 9,276 GAUGE. 9,321 - SEAL ASSV. SBR L1, 9, %O Bushirg 9. CSG Swivel 5, ECP, 9,860 - 'ACKER, 9,870 - _ - _. _._ PUP, 9,801 -.~ B-SAND WINDOW,- 9,874-9,8]9 NIPPLE, 9.889 - HANGER,- 9.892 %O Busting, 9,901 SBE, 9.902 -- TERMEDNTE, 0-10,414 Slots, `_ tOd38-10,521 ~ I r _ 51n~. -- 1 10,72d-11,244 _ 1 slots, _ - 11,634-11,887 -- ` I 1 r t ll I -. ~ I ~ ~ w Slots. 12 310 1 3 -- . - 5. 99 sl I ar SIOLS, - I 15.790-15,874 ' „-, SHOE, 15 91 J AAAND ~ t LINER. \\`-~.' 9.87015,519 TD (1 E-1701. y KUP • I; Ma~I =ieltl Name Well Status '. Protlllnj Type Inc! (° NEST SAK PROD 94.: H2S (ppm) Date Annotation Entl Data 0 ( ~ 7;1;2008 Last WO' '~ 1/26/2009 tpth (ftK6) ' End Data Annofation I Rev Reason' WORKC7VER > _ String 0.. . String ID .. . Top (ftK6) Sat Depth ((..,Set Dopih (ND) ... 1 E-170 Oct Btm (ftK6) 15,940.0 Rig Release Date 9!11/2005_ _ End Date 1 /29/2009 firing Top Thrd Description Description 'ing 0... i String ID ... Top (ftK6) Set Depth (f... Sat Depth (ND) ... String Wt... 10 6.625 9,874.0 9,879.0 ( 3.350.2 'ing 0... String ID ... Top (ftK6) Set Depth (1... Set Depth (ND) ...' String WI... 9 5/8 8.835 0.0 10,414.0 3,451.3 40.00 'ing O._'.String ID ... Top (ftK6) Set Depth (f... Sat Depth (ND) ... String Wt... S 1/2 4.950 9,870.0 15,919.0 3,355.7 15.50 'ing 0... iShing ID ... Top (ftKe) Set Depth (i... Set Depth (ND) ... String Wt... 4__1/2 ~ 3.958 40.3 9,386.7 3.270.8 12.60 S Inc! °) Item Descriptio n _ _ Command _ 0.51 HANGER 4 12, 12.6q, L-8016TM, Range 2 Hanger Jt 6.161 NIPPLE 13.875" "DB" Nipple 0.37 SLEEVE ~4 .5" Baker Sliding Sleeve w/ 3.813"'DB Nipple Profile 0.14 NIPPLE ', 3.750"'DB' Nipple w/ RHC Plug in Place 1.24 GAUGE 6.75" OD Baker Guardian Gauge 1.37 LOCATOR Baker "GBH-22" Locator w' 3' Space out Thrd TUBING Inc IBTM 15,917.0 3,355.9 93.64 SHOE A-SAND WEATHERFORD GUIDE SHOE 8/10/2005 '. 4.950 Perforations '. ~ ~ snm'. _. ~~ ~ Top (ND) Bim (NDI 7 Dens ~ Top (ftK6) ~ Btrn (ftK6) ' (ftK6) (ftK6) Zone 1 Date i~h... Type I Commeed 10,438.0 1g521.0 1i 34570 3,468.6 WS A3, WS A2, 8/102005 1 32.0$1015 Alternating slotted/solid pipe 1E-170 10,724.0 11,244.0 7 3,490.9 3,490.5 WS A2, 1E-170 8/10/2005 32.0 Slots Alternating slotted/solid pipe t 1,634.0 11,887.0 7 3,471.0 3462.0 WS A2, 1E-170 8/10/2005 32.0 Slots i Alternating slotted/solid pipe 12.310.0 15,399.0 1 3,447 6 3,377.8 WS A2, tE-170 8/10/2005 32.0 Slots Alternating slotted/solid pipe 15, /9(1.0 15 874.0 3,365.3 3,358.6 WS A2, tE170 8/10/2005 32.OSIOts ,Alternating slotted/solid pipe - - Notes: General End Date & Safet y ---_ Annot ation , _ _ _ 1 1/1 2120 0 5 ~NOTEt MULTI-LATERAL WELL 1E-170(A-SAND), 1E-170L7(B-SAND), 1E-170L2(D-SAND) Details Top Dep[h ToP -'- i Port _._. _ (ND) Inc! ~ OD ~~ - Valve Latch Size TRO Run KB) (ftK6) (°I Make I Model (ini Serv Type Type (ml (psi) Run Data 10.11 ICAMCOKBG-2-1R ilGas Llft SOV BEK O O.O V252009 -170 Pre and Past Rig Workover Summar~ DATE SUMMARY 1/29109 SET CATCHER. PULLED SOV @ 2100' RKB & REPLACED WITH DV. TESTED 7BG 2000 PSI, GOOD. PULLED CATCHER. READY FOR CTU. 2/3109 PULLED BALL & ROD FROM 9262 CTMD, PERFORMED WEEKLY BOP TEST, RTN IN A.M. TO PULL PLUG BODY & OPEN CMU. 2/4109 LATCHED INTO RHC PLUG @ 9252 CTMD, UNABLE TO PULL AFTER 32 JAR LICKS, RTN IN A.M. WITH HIPP TRIPPER. 215/09 ATTEMPT TO PULL RHC PLUG @ 9246 CTMD, MOVED PLUG APPROX 10 FT, RTN IN A.M. WITH JARS. 2/6/09 ATTEMPT TO PUSH FISH DOWN WITH NIP TRIPPER, NO SUCCESS, SHEARED PINS IN PRS PULLING TOOL, SECOND RUN WITH JARS & NEW PULLING TOOL, JARS MALFUNCTIONED, WOULD NOT FIRE, RTN IN A.M. WITH NEW JARS. 2/7/09 PULLED RHC PLUG BODY FROM 9241 CTMD WITH 4 JAR LICKS,_2ND RUN OPENED CMU (cD 91$5 CTMD, WELL IS FREEZE PROTECTED, TURNED OVER TO DSO. r~ Conoc©Phillips Time Log & Summary 1NelNiew iNeb Reg°rting Report Well Name: 1 E-170 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1!19/2009 4:00:00 AM Rig Release: 1/27/2009 2:00:00 AM Time Lo s -- 9- --- _ - - --_ - Date From To _ _ Dur _ _ _ S. De~ath__E Depth Phase Code Suncode T_ Comment ___ 1/18/2009 24 hrSummarv Road rig from 3G-03 to CPF3 and Standby for CPAI field change out. Continue to Road rig from CPF3 to 1A Pad Access road. 09:30 12:00 2.50 COMPZ MOVE MOB P Remove Handy-Berm. Loaded mats,clean location and move rig off 3G pad toward 1 E pad. Rig broke down (brakes) between 3F pad and 36 ad. 12:00 15:00 3.00 COMPZ RIGMNT RGRP T Changed out brakes on 15:00 17:00 2.00 COMPZ MOVE MOB P Road rig to CPF 3 17:00 19:00 2.00 COMPZ MOVE WOCC P Standby w/ Rig crews for CPAI feild crew than e 19:00 00:00 5.00 COMPZ MOVE MOB P Move rig from CPF 3 to 1A Pad access road as of 2400 hrs. 1 /19/2009 Cont' to Road rig from 1A Pad to 1 E Pad. MIRU on 1 E-170. Accept rig @ 0400 hrs on 1-19-09. Berm up and load its w/ 6%KCL. Pull BPV, O en u well Kill well. 00:00 03:00 3.00 COMPZ MOVE MOB P Road rig from 1A Pad to 1 E-Pad 03:00 04:00 1.00 COMPZ MOVE PSIT P Spot rig over 1 E-170, set down and Berm up. Accept Nordic 3 rig @ 0400 hrs. 1/19/2008. 04:00 07:00 3.00 COMPZ RPCOM NUND P Spot tanks and equipment, RU hardline and load pits with hot seawater w/6% KCL. 07:00 13:00 6.00 COMPZ WELCTL KLWL P Test upper and lower seals on TBG hanger to 5,000 psi -good. Opened well. SICP = 800 psi SITP = 820 psi. Attempt to bleed off press. Bled down to IA=750 psi, Tbg= 760 psi. Pumped 116 bbls down tubing taking returns (gas) to kill tank @ 3 BPM. Swapped over, pumped 240 bbls. down IA @ 36PM. SD monitor SICP = 470 psi SITP = 0. Monitor well, Pressures built up to SICP = 430 psi SITP = 380 si. 13:00 15:00 2.00 COMPZ WELCTI OTHR P Load 290 bbls more Seawater w/KCL. Loaded ESP cables ooler. 15:00 18:00 3.00 COMPZ WELCTI KLWL P Pumped 80 bbls down tbg taking returns thru IA (gas only) ITCP= 440 psi ICP= 380 psi pumped @ 5 BPM. Shut down switched valves to pump down IA taking returns thru tubing. Pumped @ 5 BPM ICP=520 psi ITCP = 20 psi. Pumped 540 bbls. Shut down open choke (IA) wide o en, bleed down ress on IA. P~ 1 ~aC 3 l Time Logs Date From To Dur S. De th E. De th Phase Code Subco_d_e_ T Comment 18:00 00:00 6.00 4,974 COMPZ WELCTI KLWL _ P SITP 10 psi, IA on a full open choke 20 psi. Pump down TBG w/ full open choke on IA to TT @ 2 bpm 50 psi for 1 TBG vol.- Calc. TBG vol. to 4,974 = 76 bbls. Fluid loss was 176 bbls. Charge pump out running rig pump. Calculated fluid loss 100 bbls / hr. IA Pressure never changed during pumping operation. Load Pits w/ 290 bbls 6% KCL leaving total pit volume @ 410 bbls. Pump down TBG w/ full open choke on IA to TT @ 10 bpm @ 360 psi w/ 20 psi choke side pressure. Increase pump rate to 12 bpm @ 510 psi w/ 30 psi choke side ressure. 1 /20/2009 Continue to attempt to kill well. Set BPV, ND Tree and NU BOPE. Test BOPE. BOLDS, Unland hanger. Pum 160 de ree 6% KCL down IA. 00:00 01:00 1.00 COMPZ WELCTI CIRC P Continuing to Pump down the TBG @ 12 bpm @ 510 psi. Calculated TBG +TBG/IA Vol. to 4,974' = 343 bbls - 5,883 stks. @ 5,223 stks - 305 bbls away pump loosing suction had slow pump down to 5 bpm and IA pressure dropped back to 20 psi @ 5,883 stks. Stage down pump. Load pits w/ 290 bbls. Continue to rack and tall 3 1/2 DP. 01:00 01:30 0.50 COMPZ WELCTL OWFF P Monitor well -TBG on Vac. & IA o en to Gas buster @ 10 psi. Discuss options w! RWO engr. - TBG on Vac. and IA Stable. 01:30 02:00 0.50 COMPZ WELCTL OTHR P Set BPV. 02:00 03:30 1.50 COMPZ WELCTL NUND P PJSM, ND Tree -Pump 100 bbls down IA w/ char a um eve hr. Continue to Rack and Tall 3 1/2 DP. 03:30 08:30 5.00 COMPZ WELCTL NUND P Inspect lift threads and Test plug threads. NU BOPE. Pump 100 bbls down IA w/ charge pump every hr - IA on a vac. Continue to Rack and Tall 3 1/2 DP. 08:30 16:00 7.50 COMPZ WELCTI BOPE P Testing BOPE 250/2500 psi. Koomey draw down - 3,000 psi @ start, 1,600 psi after, 200 psi - 29 sec., 3,000 psi - 2 min 12 sec., 4 nitrogen bottles @ 2,275 psi. Test waived by Chuck Schieve 1 /20/09 05:30 16:00 20:00 4.00 COMPZ WELCTI EORP T Change out actuator valve on top drive 20:00 21:00 1.00 COMPZ WELCTI BOPE P PT BOPE Upper Kelly Cock 250!2,500 si 21:00 22:00 1.00 COMPZ WELCTL OTHR P Pull Blanking plug ~'ae 2 of ~ ~~ Time Logs_ -- ---_ _ Date_ _ From To Dur S. De th E. Depth Phase Code___ Subcode T Comment --- - - _ 22:00 22:30 0.50 COMPZ WELCTI CIRC P Pump 20 bbl hi visc pill and chase w/ 50 bbls 6% KCL. 22:30 23:00 0.50 COMPZ WELCTI OTHR P Pull BPV 23:00 23:30 0.50 COMPZ RPCOM HOSO P MU Landing jt, BOLDS, and un-land hanger @ 90k. 75k up wt, 57k do wt. 23:30 00:00 .0.50 COMPZ RPCOM CIRC P Flush IA w/210 bbls of 140 degree 6% KCL @ 5 bpm @ 140 psi ICP and 90 psi FCP. Calculated pump strokes was 3,602 and actual was 3,347 = 15 bbl difference. 1 /21 /2009 Pull hanger to floor and POOH w/ 4 1/2 Completion. Offload ESP Equip. Change out Mud saver Valve and Test. PU,MU and RIH w/Vacs tool and Globe Basket. 00:00 02:00 2.00 5,073 5,050 COMPZ RPCOM OTHR P RD Circulating equip., Load ESP boxes, Baker fishing tools, and containment boxes for Clamps and misc. in Pipe shed. Pull hanger to ri floor. Meg thru penetrator and disconnect ESP cable and Meg ESP cable. 02:00 02:30 0.50 5,050 4,955 COMPZ RPCOM TRIP P POOH w/ 3 jts. and drift w/ 3.833" drift. 02:30 03:30 1.00 4,955 4,955 COMPZ RPCOM OTHR P Run ESP cable thru sheeve and han sheeve. 03:30 11:00 7.50 4,955 4,850 COMPZ RPCOM TRIP P C n inue to PO w/ 1/2" 12.75# IBTM TBG. Triple displacing from 4,955'. Up wt = 70 K, down wt = 55 K. 11:00 13:30 2.50 4,850 0 COMPZ RPCOM PULD P La in down the ESP assembly. Recovered 170 cable clamps and 25 SS bands. All clamps recovered, 2 SS bands remain downhole. 13:30 17:00 3.50 0 0 COMPZ RPCOM RURD P Cleaning and preping rig floor for clean out run on 3-1/2" DP. Kicking out ESP com letion. 17:00 23:00 6.00 0 0 COMPZ WELCTI EQRP T Changing out mud saver valve on top drive, test 250/2500 psi. Notified AOGCC about having to swap out mud saver valve and test same @ 16:40 hrs on 1-21-09. Chuck Scheve called back stating that we were not required to send in ahother test report, but to record it in the IADC report and Conocophillips dail re ort. 23:00 00:00 1.00 0 84 COMPZ FISH PULD P PU, MU and RIH w/ 7.875" OD Globe basket, Vacs Tool, LBS. UP 37k do wt 37k 1 /22/2009 Continue to RIH w/Globe basket PU 3 1/2 DP to 4,868' not abl to get passed. Cycle tool. Still unable to get passed. Bottom of Patch @ 4,872'. POOH and change BHA to 7.5" Shop made Mule shoe w/wire inside to forie n matr'I. RIH to 9,316' C cle tool f/ 9,308' to 9,316' multi le asses. POOH f/ 9,316' to 6,006'. m i-~Bj~ J f.T) V r 1 ', Time Lo s Date From To Dur S d_e th E. De th Phase Code Subcode T Comment 00:00 01:00 1.00 84 297 COMPZ FISH PULD P Continue to PU Globe Basket BHA to 297'. RIH with 3-1/2" DP. Filling hole eve hr w/ 50 bbls. 01:00 05:30 4.50 297 4,868 COMPZ FISH TRIP P RIH to 4782'. Pumping 5 bpm @ 760 psi, RIH. Can not pass through 4868 (casing patch). Made several attempts, sat down 8K. Had 8k overpull. Attemmpted to slowly rotate through 3 rpm, torqued up to 4000 ft#. 05:30 08:30 3.00 4,868 297 COMPZ FISH TRIP P Clean rig floor. POOH standing back DP. Tri le dis lacin . 08:30 11:00 2.50 297 296 COMPZ FISH PULD P Rack back DC, change outjunk basket from 7-7/8" OD to 7-1/2" OD. RIH with cleanout BHA and DC. Tri le dis lacin . 11:00 13:00 2.00 296 4,849 COMPZ FISH TRIP P RIH with 3-1/2" DF,f/ 296' to 4,849'. Fillin hole eve hr w/ 50 bbls. 13:00 14:00 1.00 4,849 4,911 COMPZ FISH TRIP P AT 4849', up wt = 74 K, down wt = 57 K. Start pumping, make several passes across the casing patch 4849' to 4911'. 14:00 16:00 2.00 4,911 4,911 COMPZ FISH RURD P Crane on location. Remove ESP cables ooler from the ri floor. 16:00 20:30 4.50 4,911 9,274 COMPZ FISH TRIP P PJSM. Continue to RIH with 3-1 /2" DP f/ 4,911' to 9,274'. Filling hole eve hour w/ 50 bbls. 20:30 22:00 1.50 9,274 9,306 COMPZ FISH FISH P Obtain parameters w/ jt# 279 on the hook: Dry Pipe wt -105k up wt, 60k do wt. Circulate @ 6.5 bpm @ 1,840 psi. Up wt 110k, Dn wt 62k. Circulate down to 9,300' and pump pressure increased to 2,020 psi then dropped back to normal. Continue to clean out to 9,308' and took wt. PU 10' and work back down 9,316' in 2' down increments and 10' up increments before taking wt 9,316'. Pu to 9,306' and BO and LD 't# 280. Blow down to drive. 22:00 00:00 2.00 9,306 6,006 COMPZ FISH TRIP P POOH f/ 9,306' to 6,006' Triple Displacing. Calculated string wt = 72k U wt 80k, Dn wt 50k 1 /23/2009 Continue to POOH f/ 6,006' LD Vacs tool, PU and MU Lat nozzle and RIH to 9,380' and wash SBE. POOH LD 3 1/2 DP t/ 5,361'. Stand back 3 1/2 DP f/ 5,361' to 326'. LD DC's, and fishing equip. Clean and lay down strin ma net. 00:00 03:00 3.00 6,006 296 COMPZ FISH TRIP P Continue to POOH f/ 6,006' to 296'. Tri le dis lacin . 03:00 05:00 2.00 296 0 COMPZ FISH PULD P POOH standing back DC's, Lay down Jar adn LBS. POOH and Break down VAC's Tool. Recovered 1 - 2" pc stuck in gap on fishin 'ars and nothing in VAC's tool or the Poor bo mule shoe. 05:00 05:30 0.50 0 0 COMPZ FISH OTHR P Clean and prep to RIH w/ clean out BHA. r~ Time Logs ___ __ _ _ ~ Date__ From T S. De th E. De th Phase Code Subcode T Comment o Dur 05:30 _ 07:30 __ 2.00 0 326 COMPZ __ FISH PULD P MU and RIH w/ 2.875" Lat Nozzle, 3 jts - 2 7/8 8rd TBG, X-O, String magnet, LBS, Jars, 2 stands DC's to 326'. 07:30 10:30 3.00 326 9,236 COMPZ FISH TRIP P RIH w/ Lat. Nozzle ass f/ 326' to 9236'. Up wt = 105K, down wt = 60K. Performed a fire drill on the ri . 10:30 12:30 2.00 9,236 9,400 COMPZ RPCOM FCO P RIH to 9300'. Pumping 2.5 bpm @ 1850 psi. Wash down from 9300' to 9400' made several passes. Pump DP volume. 12:30 13:00 0.50 9,400 9,400 COMPZ RIGMN7 SVRG P Service rig 13:00 17:00 4.00 9,400 5,361 COMPZ RPCOM TRIP P POOH laying down 124 jts. 3-1/2" DP t/ 5,361'. 17:00 17:30 0.50 5,361 5,361 COMPZ RPCOM OTHR P Empty pipe shed and prep for loading com letion a ui . 17:30 18:00 0.50 5,361 4,395 COMPZ RPCOM TRIP P Pooh standing back 3 1/2 DP f/ 5,361' to 4,395'. 18:00 20:30 2.50 4,395 4,395 COMPZ RPCOM OTHR P Send out Baker fishing tools and load 4 1/2 Com letion a ui ment. 20:30 22:30 2.00 4,395 326 COMPZ RPCOM TRIP P Continue to POOH standing back 3 1/2 DP f/4,395' to 326'. 22:30 23:00 0.50 326 94 COMPZ FISH PULD P POOH f/ 326' laying down 4 3/4" DC's, Jars and LBS. 23:00 00:00 1.00 94 94 COMPZ FISH OTHR P Clean String magnet -recovered a rox. 5 lbs. metal consisting of Shavings, Clamp particles, SS Band cs, and Misc sli cs. 1 /24/2009 POOH LD 2 7/8 TBG and nozzle. Pull wear ring. Hang sheeve. MU and RIH w/ Seal assy, 1jt TBG, Gauge carrier. S lice in au a to Itec wire. Continue to RIH w/ 4 1/2 Com letion to 7,685'. 00:00 00:30 0.50 94 0 COMPZ FISH PULD P POOH, laying down 3 jts - 2 7/8 TBG and wash nozzle. 00:30 01:30 1.00 0 0 COMPZ RPCOM OTHR P Load Cannon clamps,and change over to RIH w/ 4 1/2 Completion. Add 50 bbls 6% KCL to well. 01:30 02:00 0.50 0 0 COMPZ RPCOM OTHR P Pull wear ring. Add 50 bbls 6% KCL to well. 02:00 03:30 1.50 0 0 COMPZ RPCOM RURD P Hang Itec wire sheeve and spot spooler. Add 50 bbls 6% KCL to well 03:30 04:00 0.50 0 68 COMPZ RPCOM PULD P PU and MU Seal Ass to jt # 1 - found 1/4" hole from inside in TBG 5' f/ Conn. Break out and LD. -This would have been 2nd jt above TTC X-O where the pack off was installed. MU and RIH w/jt # 2 ,Guardian Gau a carrier to 68'. 04:00 07:30 3.50 68 68 COMPZ RPCOM OTHR P Splice sensor to I Tec wire ~ ~'ag~ ~ of ~ m n Time Logs Date From To Dur S. De th E. De th _ Phase Code Su'bcode T _ Comment 07:30 17:30 _ 10.00 68 6,388 COMPZ RPCOM RCST P _ _ RIH with 4-1/2" qas lift completion f/ 68' to 4,853' installing single cross couplling clamps. Tagged casing atch with seal assembl at 4853', sat down 10K#. Rotated tubing 90 de twice to work ast the atch. Continue to RIH w/ 4 1/2" Gas lift completion to 6,388'. 70k up wt, 55k do wt. 17:30 18:30 1.00 6,388 6,388 COMPZ RPCOM OTHR P RU heat Trace sheeve. MEGG heat trace and test I tec wire. 18:30 00:00 5.50 6,388 7,685 COMPZ RPCOM PULD P Continue to RIH f/ 6,388' to 7,685'. Installing dual channel clamps and dual channel cross coupling clamps. Megging heat trace and I Tec wire every 1,000' in the hole. 80k up wt, 55k do wt 1 /25/2009 Continue to RIH f/ 7,685' and engage seals into SBE @ 9,370'. Fill IA and Space out. MU TBG hanger. Spot CRW 132 6% KCL in IA. Land hanger and RILDS. Hanger test failed, pull hanger to floor and change O-rings and res lice Itec wire. 00:00 00:30 0.50 7,685 7,740 COMPZ RPCOM PULD P Continue to RIH PU 4 1/2" Gas Lift Completion f/ 7,685' to 7,740'. Installing dual channel clamps and dual channel cross cou lin clam s. 00:30 01:30 1.00 7,740 7,740 COMPZ RPCOM PULD T Clamp tensionerfailed -Repair air control button. 01:30 10:00 8.50 7,740 9,390 COMPZ RPCOM PULD P Continue to RIH PU 4 1/2" Gas Lift Completion f/ 7,740' to '. Installing dual channel clamps and dual channel cross coupling clamps. Megging heat trace and I Tec wire eve 1,000' in the hole. 10:00 12:00 2.00 9,390 9,390 COMPZ RPCOM HOSO P No Go at 9390' corrected de th, sat down 20 K#. Up wt = 95K#, down wt = 60K#. Filled IA with brine, required 62 bbl (1100'). Pulled 14 ft before fluid level in the IA dro ed. Sat back down at the same de th. 12:00 15:00 3.00 9,390 9,360 COMPZ RPCOM HOSO P Spaced out for 3'. MU hanger and s lice heat trace and TEC wire. 15:00 16:30 1.50 9,360 9,360 COMPZ RPCOM CIRC P Pumped 530 bbl of corrosion inhibited brine down the IA. 16:30 18:30 2.00 9,360 9,360 COMPZ RPCOM OWFF T Corrosion inhibited 6% KCL Foamed up and was aerated and blowing back. 18:30 19:00 0.50 9,360 9,360 COMPZ RPCOM OTHR P Dro ball and rod, et fall and chase w/ 2 tills 6% KCL seat and preesure u to 250 si. 19:00 22:00 3.00 9,360 9,387 COMPZ RPCOM CIRC P Load IA w/ 182 bbls of 6% KCL and pressure up to 250 psi, bleed off and re-pressure to 250 psi two times. Lower n r~ Time Logs _ ___ ~I Date From To Dur S. De th E. De th Phase Code Subcod_e T Comment __ 22:00 00:00 2.00 9,387 9,387 COMPZ RPCOM HOSO P Land Han er and RILDS. PT Lower body seal -test good, Upper body seal test failed. Pull hanger to floor and I-tec wire above TBG Hanger was severed during pull to surface as it un-spooled into BOP Ram cavity. Change out upper O-ring as it was cut. Also changed out lower O-ring for minor scratches. Splice in new I-tec wire below hanger w/enough tail to handle on rig floor. Lost 1' of .25" I-tec wire into well bore. +/- 9' still in ram cavi 1 /26/2009 Meg heat trace and test Itec wire. Land hanger and test. Fill IA and PT TBG @ 3,000 psi -drop to 2,000 psi. PT IA 3,000 si. Shear out SOV. Set BPV and ND BOPE NU Tree. FP and well to U Tube. 00:00 01:30 1.50 9,387 9,387 COMPZ RPCOM SFEQ P Continue to splice Itec wire and test. Me heat trace. 01:30 02:30 1.00 9,387 0 COMPZ RPCOM HOSO P RIH w/ hanger thru Itec wire in BOP cavity and Land hanger. RILDS and PT Tower and Upper seals to 5,000 si - ood test. 02:30 03:30 1.00 0 0 COMPZ RPCOM CIRC P Fill IA w/ 56 bbls 6% KCL and bleed back air. Continue to pressure up to 250 psi and bleed back working air from IA. 03:30 06:00 2.50 0 0 COMPZ RPCOM DHEO P Attem t to PT TBG to 3,000 si - bled down to 2,750 psi in 12 minutes. Pressure back up to 3,100 psi and bled down to 2,750 psi in 17 1/2 minutes. Bleed down to 0 psi. Surge TBG multiple times and PT to 1,000 psi. Check landing jt and found fuild above penetrators. Tighten Landing jt and PT TBG @ 3,000 psi and 100 psi in 30 minutes. Bleed TBG to 2,000 psi and Pressure up on IA to 3,000 psi. Lost 100 psi in 12.5 minutes. Pressure up to 3,250 psi and lost 100 psi in 15 minutes. Found surface leak @ graylok fitting. Bled IA down to 0 psi and re air leak. 06:00 08:00 2.00 0 0 COMPZ RPCOM DHEQ P Pressure testing IA. Completion fluid was exteremly foamy after pumping it down the IA prior to landing the hanger. Required several attempts to obtain a 30 min 3000 i tes Bleed down IA and tubin . Pressure up on the IA and shear the SOV at 1450 si. 08:00 10:00 2.00 0 0 COMPZ RPCOM OWFF P Monitor well, some u-tubing occurring. Circulate hole volume through the sheared SOV to balance well. Pumped 150 bbl at 2 bpm, 1510 si. Page 7 gat ~ i Time Logs _ 'Date From To Dur _ _ S_De th E. Depth Phase Code. __ Subcode _ T __ Comment _ _ 10:00 12:00 2.00 0 0 COMPZ RPCOM OWFF P Monitor well, set 2 way check. Some well fluid was seeping past the 2 way check. The 2 way check was ulled and a BPV was set. Monitored well, no flow. 12:00 16:00 4.00 0 0 COMPZ RPCOM NUND P PJSM. ND BOPE. 16:00 18:30 2.50 0 0 COMPZ RPCOM NUND P NU Tree and test void to 5,000 psi - ood test 18:30 20:00 1.50 0 0 COMPZ RPCOM OTHR P PU Lubricator and pull BPV and install TWC 20:00 21:00 1.00 0 0 COMPZ RPCOM SFEQ P RU LRS and test tree to 5,000 psi. 21:00 21:30 0.50 0 0 COMPZ RPCOM OTHR P Pull TWC 21:30 23:30 2.00 0 0 COMPZ RPCOM FRZP P RU and Pump 160 bbls freeze protect down IA w/ LRS @ 2 bpm. RD LRS. 23:30 00:00 0.50 0 0 COMPZ RPCOM OTHR P Allow well to U tube. 1 /27/2009 Continue to allow well to U Tube. Lubricate i n BPV and Secure well. Dress tree. RDMO Clean and clear cellar. Release Nordic ri 3 0200 hrs on 1-27-09. 00:00 00:30 0.50 0 0 COMPZ RPCOM OTHR P Continue to U Tube well. 00:30 01:00 0.50 0 0 COMPZ RPCOM OTHR P Lubricate BPV -Shut in well pressures -50 psi TBG, 10 psi IA, 0 si OA. Secure well. 01:00 02:00 1.00 0 0 COMPZ RPCOM OTHR P Dress tree, RDMO 1 E-170 w/Nordic Rig 3. Clean and clear cellar. Release ri 0200 hrs on 1-27-09. ~_...wV__w_ Page 8 of f3 1 E-170 Pre and Post Rig Workover Summary DATE SUMMARY 1/29/09 SET CATCHER. PULLED SO~ 2100' RKB & REPLACED WITH DV. T ED TBG 2000 PSI, GOOD. PULLED CATCHER. READY FOR CTU. 2/3/09 PULLED BALL & ROD FROM 9262 CTMD, PERFORMED WEEKLY BOP TEST, RTN IN A.M. TO PULL PLUG BODY & OPEN CMU. 2/4/09 LATCHED INTO RHC PLUG {g~ 9252 CTMD. UNABLE TO PULL AFTER 32 JAR LICKS, RTN IN A.M. WITH HIPP TRIPPER. 2/5/09 ATTEMPT TO PULL RHC PLUG ~ 9246 CTMD. MOVED PLUG APPROX 10 FTr RTN IN A.M. WITH JARS. 2/6/09 ATTEMPT TO PUSH FISH DOWN WITH HIP TRIPPER,~NO SUCCESS, SHEARED PINS IN PRS PULLING TOOL, SECOND RUN WITH JARS & NEW PULLING TOOL, JARS MALFUNCTIONED, WOULD NOT FIRE, RTN IN A.M. WITH NEW JARS. 2/7/09 PULLED RHC PLUG BODY FROM 9241 CTMD WITH 4 JAR LICKS, 2ND RUN,t OPENED CMU @ 9185 CTMD, WELL IS FREEZE PROTECTED, TURNED OVER TO DSO. ia: ~. ~lr~f#t~ Schlumberger -DCS ~~ •~ ~ ~~"~ ~ ~ =~ ~ '' ~'~ 2525 Gambell Street, Suite 400 ~"~~~~" `~'~~~~ ~~~ ~ ~~~ ~~L~(~ Anchorage, AK 99503-2838 j ~f ATTN: Beth Well Job # ~, ri ~, ~ ` ~„ . ,<., ~~&!,~ ~~ . ,. ' NO.5138 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 03/18/09 2A-26 604C-00011 OH EDIT (PEX,SSCANNER & CHFR) -~jqc{ / . ~~/ 02/14/09 6 1 E-170 ANHY-00057 PRODUCTION PROFILE a~~ "- 03/06/09 1 1 1A-11 ANHY-00058 LDL C./ 03/08/09 1 1 3G-04 ANHY-00060 PRODUCTION PROFILE Q_ 03/10/09 1 1 3B-15 ANHY-00061 INJECTION PROFILE U '- '~ 03/11/09 1 1 1 R-10 ANHY-00063 INJECTION PROFILE ~ 03/13/09 1 1 2M-16 ANHY-00064 INJECTION PROFILE / _ 03/14/09 1 1 2G-15 ANHY-00065 PRODUCTION PROFILE I'LL(- / 03/15/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~ RE.~-..1'70 (PPI'D# 205-074, ~ 075, 205-076) Natificati~.Gasii~ With TxIA Co... Page 1 of 2 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, March 08, 2009 1:37 PM To: Maunder, Thomas E (DOA) Cc: NSK West Sak Prod Engr; NSK Well Integrity Proj; CPF1 DS Lead Techs; Pierson., Chris R; Jenkins, Lubbie Allen; NSK Problem Well Supv Subject: RE: 1 E-170 (PTD# 205-074, 205-075, 205-076) Notification Of Gaslifting With 7xIA Communication Tom, Due to unforeseen issues obtaining the proper size POGLM (concentric gas lift valve) to cover the open CMU, well 1 E-170 (PTD #205-074, 205-075, 205-076) will remain online in gas lift service for an .additional 28 days with an open CMU. Please contact us if there are any issues with the time extension. Ian Ives & MJ Loveland Problem Wells Supervisor ConocoPhillips Alaska Inc. ,~,~~~ ~~~ ~~~ Office 907-659-7224 From: NSK Problem Well Supv Sent: Friday, February 06, 2009 10:52 AM To: 'tom.maunder@alaska.gov' Cc: NSK West Sak Prod Engr; NSK Well Integrity Proj; NSK Problem Well Supv; CPFl DS Lead Techs; Pierson, Chris R; Jenkins, Lubbie Allen Subject: 1E-170 (PTD# 205-074, 205-075, 205-076) Notification Of Gaslifting With TxIA Communication Tom, West Sak tri-lateral producer 1 E-170 (PTD# 205-074, 205-075, 205-076) underwent a rig workover that was completed on 01/27/09. The work consisted of converting from a failed packerless ESP utilizing gaslift to a traditional gaslift configuration. As a part of the post rig procedure, ConocoPhillips intends to produce the well using gaslift through an open Baker CMU sliding sleeve at 9221' MD (3243 TVD) until the well cleans up and a production profile can be completed. Once the profile is complete, we will. install a concentric gaslift valve in the sliding sleeve and resume continuous gaslift operations. Since there will be TxIA communication while gaslifting through the CMU, CPAI does not plan to do so for more than 28 days from the date that the CMU is opened. Should it be necessary to extend the flow period beyond 28 days, we will request permission to do so at that time. Until the well is operated under normal conditions, it will be included in the SCP report. Attached is an updated wellbore schematic. « File: 1E-170 Wellbore Schematic.pdf» 3/9/2009 RE: 1E-170 (PTD# 205-074, ~ 075, 205-076) Notification Of Gaslif~ With TxIA Co... Page 2 of 2 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 3/9/2009 ConocoPhillips Atauca. I'h' Stlr~tle-A< HANGER. 00 CONDUCTOR. 0.120 cAS a Fr. z.1aD Intermeaisle Tr-Beck. 00.0.848 PATCH,/.802 SURFACE. 435.054 :LE EVE. 9.221 NIPPLE, 9,278 GAUGE. 9.321 LOCATOR. 9,388 SEALASSY. 9.388 o-snho WINDOW, 9.002-9.612 D-SAND LEM, 9,308-9,]39 B-SANC WINDOW 9.8]49, 8]I B-SAND LEM 9.I10.9.9t: &SAND HH 9.T1}9 99i KUP • 1 E-170 a APUUWI Fi eld Name Well Status Pray 32326400 WEST SAK PROD ~~ M - -- _ M2S IPPmI Drte -Annotrtiw NIPPLE 0 7/112008 Last WO: ion - --Depth Ifncel End Drta Annotation _. 1g: -' Rev Reason: GLV C/O Descrpdon SMrp 0... Stang ID ... Top IfgcBl Srt Depth IL.. UCTOR 20 19.124 0.0 120.0 Description _ SMrq 0... String ID ... 7oP IImBI Set DepM If... \CE 13 3/8 12 415 42.8 _ 5,054.3 Dascrptlon String 0... String ID .. Top (RKB) Set DepM If... D WINDOW 10 6.625 9,402.0 9,412.0 Description String 0... String ID ._ -Tap (RKB) Set Depth (t.. D WINDOW 10 6.625 9,874.0 9.679.0 Description String 0... ~String ID ... lop (RKB) Set DapM (f... Bdiate 9 5/8 8.835 40.3 4.849.4 Ck Description Strirq 0... String ID ... lop IfncBl __ Set Depth If... MEDIATE 9 5/8 8.835 4,832.0 10.414.0 Descrpaon String 0... SMrp ID ... Top (fdcBl - -Set Depth (1... D LINER 5 1/2 4.950 9,870.5 15.918.9 1/3012009 epih (ND) ... String WL.. String ... String Top Thrd 120.0 94.00 K-55 WELD --- epth IN01 ~~~ String Wt... SMng ... String lop Thrd 2,312.0 68.00 L$0 BTC epth (ND) ... String Wl.. String ... String Top Thrtl 3,275.9 _ epth (ND) ...String WL.. String ... String Top Thrtl 3,350.2 --- apth (ND) ~~~ SMng WL.. String ... String Top Thrtl 2,269.6 40.00 L$0 BTCM apth IND1 ~~~ Sting NK... Strkq ... Stang Top Thrtl 3,451.3 40.00 L$0 BTCM eplh (ND) ... String WL.. String ... String Top Thrd 3.355.7 15.50 L$0 BTCM ..y ..... .......y ... ... .ter ~.~_~i __. __•_. ~.... 4 1l2 3.958 40.3_ _ _9,386.7 - - -- InU (TVDI Top lncl (ftKB) _ _ _ (°) Dascri_p_tlo_n Cw -- - - - 2.268.1 77.65~PATCH BAKER EXPATCH SET IN 9 w(7 7/8"; passed w/7.5" BHA ItI009 lop ITVDI etm (ND) ', I Btm (tncBl IfncBl Ifncfil Zone _Dm__ I i 10,521.0 3,457.0 3,468.6~W5 A3, WS A2, 8/10/2005 - 1E-170 1 /29/2009 Sbt, • 1o.43a1 oszl ~ • n4 r ~ I°P1~°I 1 ~ 2,100.1 I Sbls. 10, T3411,2N 1 I ~Ilil t I i 1 ~U(1 II .. 1 Sbt. I 11,8341 1.887 -. I 1 ~ Illll Sbte. ' 12.710.1 s.]99 _._ 1'€_ . I i i ~11~1 Sbta, I 18,79f1-t 5,871 ~ -_ _~ I A-SAND LINER, ~ 9,8]0.15.919 i0 (1E~170), 15.900 • Run passthru 1/241: OD Valve Lrtch Size TRO Run ~ Maks Model liN Serv TYPe TYPe '~ linl IPaO Run Date G __ __ _. _ _ -t- AMCO KBG-2-1 R 1 Gas Lift DMV BK 0 _ 0 0 1129/2009 12.60 L$0 IBTM Jt RECEIVED • • STATE OF ALASKA O E C 2 3 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATId oil & Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ Alter Casin g ^ Pull Tubing ^ Perforate New Pool ^ ^ EsP to Gaslift Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development^ • Exploratory ^ 205-074 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23264-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' 1 E-170 8. Property Designation: 10. Field/Pool(s): ADL 25660 ~ KUPARUK RIVER UNIT /WEST SAK OIL POOL 11. Present Well Condition Summary: Total Depth measured 15940' feet true vertical 3354' feet Plugs (measured) Effective Depth measured 15940 feet Junk (measured) true vertical 3355 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 120' 20" 120' 120' SURFACE 5054' 13-3/8" 5054' 2312' WINDOW D 10' 9-5/8" 9412' 3275' WINDOW B 5' 9-5/8" 9879' 3350' INTERMEDIATE 10414' 9-5/8" 10414' 3451' LINERA 1049' 5-1/2" 10919' 3356' Perforation depth: Measured depth: 10438-10521, 10724-11244, 11634-11887, 12310-15399,15790-15874 true vertical depth: 3491-3468, 3491-3491, 3471-3462, 3448-3378, 3365-3359 Tubing (size, grade, and measured depth) 4.5, L-80, 4990 MD. c ,tom/~ ` ~ ~~c cr~ ~t~ ~~~;' "~ `~ 2~~ N ~ : . - - ~ . Packers &SSSV (type & measured depth) Packer =none 0 SSSV =none 0 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 392 375 23 272 266 Subsequent to operation 460 62 501 273 14. Attachments 15. Well Class after proposed work: Copies of logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact B. Christensen/ D. Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature 1 ~ Phone: 659-7535 Date l Z. Z t, (Og Form 10-404 Revised 04/2004 W~`~ Submit Original Only 1 E-170 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/04/08 CLEAN DOWN TO TOP OF SLIP-STOP @ 4913' CTMD.MADE MULTIPLY ATTEMPTS TO START ESP WITH NO SUCCESS. RETURN IN AM TO START PULLING SLIP-STOP, PACKOFF AND ESP TO TEST MOTOR. DEPLOYMENT FLANGE ON TREE TO HOLD ESP UNTIL SLICK-LINE CAN PULL PUMP. CYCLE ESP UP & DOWN TO CONFIRMED PUMP MOVE FREELY) 12/06/08 12/07/08 12/12/08 PULLED & LAYED DOWN 4-1/2" x 47' 10" FC6000 ESP FROM DEPLOYMENT FLANGE. READY FOR CTU. RIH AND CLEAN TUBING DOWN TO TOP INTAKE CROSSOVER @ 4966' CTMD. WHILE MAKING UP BAKER BHA TO TEST MOTOR, TILT CYLINDER SEAL STARTED LEAKING ON T-BAR.ROAD UNIT TO PRUDHOE TO PERFORM MAINTENANCE AND REPAIRS. JOB INCOMPLETE RAN IN HOLE TO 4968' CTMD WITH ESP MOTOR TEST TOOL, SEATING PINS SHOWN THAT TEST TOOL WAS ENGAGED INTO ESP MOTOR SHAFT BUT ROTATIONAL '.TATTLE TAILS WERE STILL INTACT INDICATING ESP MOTOR SHAFT PROBLEMS, 'WELL LEFT SHUT IN AND FREEZE PROTECTED WITH DIESEL DOWN TO TOP OF 'MOTOR. (( COMPLETE )) 12/16/08~REPLACE SOV @ 817' RKB W/ DV. RAN HOLEFINDER, GOOD TEST OF DV. JOB ~~ KUP • 1E-170 COIIOCOP~l1~~I~JS ~l WellAttributea l ALr ~ r !~ Wellbara API/UWI Field Name Well Statue Protl/lnj Well Type Inc! (°) MD (ftKB) iD (max) (ft . , .. 500292326471 WEST SAK PROD 97.84 11,422.93 15,940.0 Comment H23 (ppml Ogle Annotation Eno Date KB-Grtl (RI Rlg Release Date ••• Wall Con -1E-070 1182008 1 06 52 PM SSSV: NONE 0 7/1/2008 Last WO: 11/13/2005 mane-AC1ual An notatbn DapN (ftKB) End Dace Annotation End Data Last Tag: Rev Reason: SET ESP 11/2/2008 -- Castn Strip a String 00 String ID Sat Depth Sat Depth (TVD) S[rfng Wt String KANGER, 11 Casing Descriptlon (In) (In) Top (/UtB) (ftNB) (ftKB) (IbsRt) Orede String Top Thrd CONDUCTOR 2 0 19.124 0.0 120.0 120.0 94.00 K-55 WELD coNDUCTOR, SURFACE 13 31 8 12.415 0.0 054.0 5 2 311.9 68.00 L-80 BTC 1X1 , , WINDOW D 1 0 6.625 9,402.0 9,412.0 3,275.9 MANDREL, 817 WINDOW B 1 0 6.625 9,874.0 9,879.8 3,350.2 INTERMEDIATE 95/ 8 8.835 0.0 10,414.0 3,451.3 40.00 L-80 BTCM PuMPASSV. /,D/S LINERA 511 2 4.950 9,870.0 15,919.0 3,355.7 15.50 L-80 BTCM DISCHARGE. / e99 Tubin Strip s . String OD String IO Sel Dap[h Set OapN (TVD) String Wt String Tubing Descriptlon (In) (in) Top (ftKB) (ftKB) (ftKB) (Iba/F[) Grade Siring TOp Thrtl xo.4.974 TUBING 41/ 2 3.958 0.0 4,990.0 2,299.0 12.60 L-80 IBTM Other In Hole All Je wel : Tubi n Run 8 RetHevable Fish etc. SEAL 4 990 Top Depth (TVDI T , . Top (ftKB) (ftKB) op Inc! (°) Descriptlon Comment Run Date ID (In) Moron. s.DD3 41.0 41.0 0.51 HANGER VETCO GRAY MB222 TUBING HANGER, 4.909 MCA 11/1212005 3.900 cenval~:er, CONNECTOR 5,039 817.0 807.2 19.88 ESP CAMCO/KBG-2l1lSOVIBK-5//2000/ Comment: STA 1 4!7/2006 3.860 suRPACE, MANDREL 5,051 4,043.0 2,082.3 82.65 PUMP ASSY 4-12" X 31'1" ESP TOP @ 4943; PACKOFF ASSY TOP 11/112008 0.000 snoE, 5,D73 @4934'; SLIP STOP TOP @ 4933' 4,899.0 2,279.9 77.85 DISCHARGE PHOENIX DISCHARGE PRESSURE SUB 11!12/2005 4,974.0 2,295.7 78.36 X0 TTC XO w/PERF SUB 11/12/2005 4,990.0 2,299.0 78.37 SEAL BAKER SEAL SECTION 11/12/2005 0.000 5,003.0 2,301.6 78.38 MOTOR 418 HP KMH 21610 V / 98A MOTOR & PHOENIX XT-1 @ 111722005 0.000 503T OD - 4.6 WINDOW D. 9,/1z 5,039.0 2,308.8 78.42 Centraliztx 6FINCENTRALIZER 11/122005 1.990 PACKER Lt, s,nD 5,073.0 2,315.7 78.49 SHOE BAKER JUNK SHOE 11112@005 6.750 xo u, 9,7n 9,870.0 3,347.4 79.80 PACKER ASAND ZXP LINER TOP PACKER w/HRD PROFILE A/10/2005 7.000 SBR L7 9 730 9,889.0 3,351.7 80.74 NIPPLE ASAND'RS' PACKOFF SEAL NIPPLE 8/10/2005 , , xo ewn~ng u. g,gg2.0 3,352.1 80.72 HANGER A-SAND FLEXLOCK LINER HANGER 8/102005 7.000 9.749 CSG Svnrol L1 9,901.0 3,353.5 80.66 XO Bushing ASAND CROSSOVER BUSHING 8/10/2005 4.880 . 9.7s1 9,902.0 3,353.7 80.66 SBE A-SAND 190-47 CASING SEAL BORE EXTENSION &10/2005 4.750 MANGER Lt, 9,759 15,917.0 3,355.9 93.64 SHOE A-SAND WEATHERFORD GUIDE SHOE 8/102005 Perforations HANGER L7. Shot 9.773 Top (TVD) Btm (TVD) Oene Top (/tKB) etm (ftNB) I~BI (RKBI Zone Date (°h... Type Comment HANGER, 10,436.0 10,521.0 3,457.0 3,468.6 WS A3, WS A2, 8/102005 32.0 Slots Alternating slottedlsolid pipe 9,791 tE-170 xo s 9~ 10,724.0 11,244.0 3,490.9 3,490.5 WS A2, 1 E-170 8!102005 32.0 Slots Altt3matirg slottedlsolid pipe 11,634.0 11,887.0 3,471.0 3,462.0 WS A2, 1E-170 8/102005 32.0 Slots Altemating slotteNsolid pipe ECP, 9.860 12,310.0 15,399.0 3,447.6 3,377.8 WS A2, 1 E-170 81102005 32.0 Slots Altemaeng slotted/solid pipe 15,790.0 15,874.0 3,365.3 3,358.6 WSA2. 1E-170 8/102005 32.0 Slots Altemating slotted/solid pipe PACKER, 9,870 _ Cement S ueeZ e$ Top Depth Blm Depth (TVDI (TVDI PUP 801 9 Top (ftKB) Btm (ftNB) (ftKB) (ftKB) Descriptlon Start Dela Comment , . WINDOW B, k 9879 Notes: General dt Safe NIPPLE 9 889 End Date Annotation . . 11/122005 NOTE:MULTI-LATERAL WELL: 1E-170(A-SAND),1E-170L1(B-SAND), 1E-170L2(DSAND) HANGER, 9.892 %O eushirp, 9,9m - 88E. 9.902 `~~~ TERMEDIATE. 10,111 Sbb, , 10.438-10.521 Sbb. 70,724112M~ ' Sbb, 11,63411,887 Sbb, ` 12,310.15,399 I Sbb, 15.790.15.871 „ , SHOE. 15.917 ~, ~~ , LINER q 15,919 ~ TD (1E-170), y 15,910 Page 1 of 1 • o Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com~ Sent: Monday, December 15, 2008 8:40 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; NSK West Sak Prod Engr Subject: 1 E-170 (PTD# 205-074) Report Of Failed ESP Jim/Tom, West Sak ESP producer 1 E-170 (PTD 205-074. 205-075, 205-076) is a tri-lateral West Sak packerless well that was confirmed to have a failed ESP on 12/12/2008. CPAI utilized a coiled tubing unit to diagnose a broken shaft. The well is currently scheduled to undergo a rig workover in the first quarter of 2009. Our current plan is convert the well to gaslift until the workover can be completed. We will submit a 10-404 once the work is finished. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7724 Cell 907-943-1720 Pager 907-659-7000 #909 '~~3Ut~.ar~ ~ ,_ ~, ~ v~r~' ;,~, iznsizoog .7 Con ' ' ocoPh' I I ~ ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ ~S'~~~ a_ ' ~ ~` '~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl7, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 11~4n Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-18A 204-167 15' 5" 2.50 44" 10/30/2008 27.2 11/7/2008 1E-168 204-200 15" NA 15" NA 3.4 11R/2008 1 E-17 205-074 13" NA 13" NA 5.53 11 /7/2008 1J-122 207-070 15" NA 15" NA 3.4 11!7/2008 1 J-14 200-200 16" NA 16" NA 1.27 11 /7/2008 1J-152' 206-016 3' NA 3' NA 19.55 11/17/2008 1 J-158 207-054 6' NA 6' NA 27.2 11 /7/2008 1 J-162 2 7-080 15" NA 15" NA 2.55 11 /7/2008 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1 J-168 205-060 10" NA 10" NA 3.82 11 /7/2008 1 J-170 206-062 8" NA 8" NA 1 11 /7/2008 1J-174 207-143 24" NA 24" NA 17 11/7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 1E-170 (205-074) Gas Lift Question • Maunder, Thomas E (DOA) From: Gober, Howard [Howard.Gober@conocophillips.com] Sent: Monday, October 06, 2008 3:32 PM To: Maunder, Thomas E (DOA) Subject: RE: 1 E-170 (205-074) Gas Lift Question Tom, Page 1 of 2 That is correct. Pull ESP and run a tubing string with GLM's. The seal assembly on bottom would be stabbed into the seal bore, and the IA will be pressure tested. I appreciate the help. We will move forward with planning. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 06, 2008 3:22 PM To: Gober, Howard Subject: RE: 1E-170 (205-074) Gas Lift Question Hi Howard, I presume that you will be pulling the ESP and then rerunning the string with GLMs? I don't see an issue. The wellbore was pressure tested when repaired and if you are doing a workover and stinging into the liner top, then you will have an opportunity to pressure test again. Call or message with any questions. Tom Maunder, PE AOGCC From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Monday, October 06, 2008 3:13 PM To: Maunder, Thomas E (DOA) Subject: 1E-170 (205-074) Gas Lift Question Tom, We are considering changing the lift method on 1 E-170 (PTD 205-074) from ESP to gas lift. The 9-518" casing has a patch over a casing hole. The patch was run during a workover in November of 2005. The 9-5/8" production casing passed a pressure test to 2500 psi as part of the workover. The OA (9-5/8"x13-3/8") was cemented off during the workover and it passed an MIT to 1800 psi in March of 2008. Do you see any issues with converting this well to gas lift? We would use the existing casing sealbore receptacle and ZXP at 9308'-9370' as 10/6/2008 1E-170 (205-074) Gas Lift Question Page 2 of 2 • a packer. The casing patch would see gas lift against it, but it is designed with elastomeric seals to handle gas. I do not see any problems with doing this, but I wanted your opinion before proceeding. Since this is a change of artificial lift we would not be submitting a 10-403 only a 10-404. 1 have attached a schematic for you to reference. Please let me know if you have any questions. «1 E-170 Multi-Lat drawing.pdh> Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com 10/6/2008 81T MD - GLM, Camco 4112" X 1" 4699' MD -Phoenix Discharge Pressure Sub 4828' MD -9.516" x 13316" JMZXP Tieback Pecker 4931' MD - 9-516" x 13316" FlexLock Liner Hanger whh HRD Sleeve ~ 4934' -4964' MD - EXPatch expandable patch w16.00" ID 5073' MD -Bottom o1 Motor Centralizer Centraldt 418HP FC6000 wireline deployed pump 5054' MD - 133/6" ~ / Casing Shoe, 68N, L-60, '~'~„` BTC set, 2311' TVD /: 9308' MD - 7" % 9-919" ZXP Llnar Top Paelur win Haa Downs 939t'MD-Tudn9 Swl d, 4tR" 91t2'MD-7"%9-6M" Moad'B' HOOK Hanger Sad Bon 3.69"ID 9770' MD- Casing Sedbore Raupbde 1.75" ID, 9.76" OD 20' Lengm 9107' MD •Lebrd Entry Moada (LEM) OUMUn9 Prdlle ConocoPhillips West Sak 9-5/8" Producer 1 E-170 Tri-Lateral Completion 'D' Sand Lateral 9412' MD - D-sand Window, 3275' ND, 61 deg inc 9-112" 16.98, L-so slatoa uner 9554' MD -5-112" Pay2one ECP ~ sv2- cdae snoe 15736' MD - S71Y' Casing Shae, 15.5M, L-80 BTCM, 3185' ND 9710' MD -7"X9-9/9" ZXP Liner Top P+clbr Lateral Entry Module (LEM1 ~~~~,~ i~~~ppT!!! Assembly ~!~_- __ 7"X&513"ZXP Liner Top Packer with Hdd Downs ~i 7.500" Tieback ExL ID ~~ 6.278" Tod Body ID ~~ Gsing Sadbore Recepbcb ~ 4.76" ID, 5.75' OD r I 20' Length Tubing 9wivd, 4112" Orienting Prdde Automatic Alignment of LEM - PosiDva Latching Collet Indicebs Como Location Seal Bora for Letard \ Isdation - 3.388" 10 Access window Positive Lateral Access Vu Thru-Tubing Divarter Seal Bore for Lateral Isdation -1.638" ID Isdation Seal Asembly 4.75" 9ed OD 7.375" Sed ID Y Lengm with Hda Downs 9730' MD - Caslnq Sedbora Regptade A76" ID, 9.79" OD 20' Lengm 977x' M D - 7"X9.918" Moad'B' HOOK Manger \ ~ 9612' MD - 7" Tieback 9bew 882Y MD- 5112" bent joint 9739' MD -Bottom of Sad ASHmdy 1.79" Sad OD 7.975" ID 9790' MD-TUdng Swlvd, 41/2" 9799' MD-Lebrd Entry Moada (LEM) Onsntlng Proala 9779' MD- B-sand Window, rBr Sand Lateral ~ / 3331' TVD, 80deg inc Final As Completed n..~ M-Rs Bakcr Oil Tools With Di verters and Isolation Le9erd Aenss Dlvarbr Letard Isdatlon Dlvarler GS Runnlrp Tod Smnq Instilled Insfdlea I7.oo" ubd Ddfq 12.90" lD Mainbore Dnrt) 'Ga' Prof9e br Cog Conr]sctor ' ~ ?' +/ RunninglRemeving ~; 1 _ . 1 (1.00' Lengm) Snap INSnaP Out sack Preasun Vdw ~ ~POSItlva LOUtlng~ ,~{,( Collet (1.90' ungml ~ ' Lmfd lsdatlan J'~ y .~ Flow-ThN Swlvd I ; i Seds (1.25' Lanpml p\ ~ J ubN 0lwrtar _, »~Hyaradl< Dlsconneet \ Ramp Isdatlon/Mdnbole~^~ (1.60' Lengm) t) '' quarter Sleeve I GS Spear (~~ (' '" ~~ I ~' (1.50' Lengm) Lebrd Isdatlon I 3.35 n Approc Seds i --- OAL' ~ I nay bs rpulrW In hlpMy aevlated /9' DlveMr Lengm t0' SINw Lengm p appll<atlons (3' appros tenpin). 8330' MD - 5112" 6-1R" 16.68, L-90 Blank and 91oaW Liner ~`~ / PayZone ECP / ~ 9.112" Gulaa Shoe / ,r 15745' - MD S1lY' Casing Shoe, 15.5N, sad Bores ~ 9950' MD - 7" Teback 91eew L-80 BTCM, 3231' TVD 7.63"ID / 8826' MD -5.112" bent joim 4vz"u.asTUemg a.97s° Drlrt - 1969"ID r x 9-sie" zxP LIMrTOp Packer ~..~ 7.900" E+L ID / 3.279" Tod ID r 7" % 9-918" Fle, Lock Llnx Hangar .~..t 9870' MD - Liner Henper I Packer 8.279" ID ~~ ~ R Assembly / 9902' MD- Caslnp Sadbora Reppbda 476" ID, 6.78" OD 20' Lengm 9912' MD- aottom of 9ed Assemdy / 176" Sed OD ''°76~~'D 'A' Sand Undulating Lateral 6-112" 15.58, L20 91oKad end Bonk Llnar 6.1 R" Gulae Shw 10414' MD -9.516" Casing Shoe, 40.ON, L-80 BTC, 3451' ND m e,k.r Hg9n..:o9a. Tnu aocum•,w m,r nm 1» r.vroag+aa «a,ml,nea, m w1w1. +r m win. m +nr arm+r ev (77 deg inc) .nr m.,n. w.v,N<gr m.cn,nmr, ~navan9 vlwm.,vnna. r•c.m~rw. or er ,nv Id,rm,n.n .Inr•9•.na » r»vr .r+»m now k,»vm o, n•r•,n« mvm•g, wnnom wrm.n vrmuaon nom 9,k.r Hv9n., inc. ~yuioment Specifications 7" X 9-5/B" HOOK Hanger Mainbore Drill: 7.00" Mainbon Drift, with diwrter: 3,25 Lebrd Drift, no diwrter or LEM: 6.29" Lateral Drift, vW diwrtar, no LEM: 5.12" LabrallMainboro Diverter OD: 9.50" 4112" Lateral Entry Module Mainbore Drift: 3.89" Mainbore Drift, w/ Isdation sleety: 260" Letard Drm, wl coi divarter: 3.00" OD d Diwrter and Sleaw: +l- 3.60" Diwrter and Sleeve Length: */- 19' 15919' MD - 5112" Casing Shoe, 15.5#, BTCM, 3354' ND ]D99 West 6,k TrHal«M comq•I»n - Proeuc•, ~.- ~: ,.~.,,;,p,:- .~ ~t_. •~„: DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2050740 Well Name/No. KUPARUK RIV U WSAK 1E-170 Operator CONOCOPHILLIPS ALASKA INC AP1 No. 50-029-23264-00-00 MD 15940 TVD 3355 Completion Date 9/10/2005 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/RES, CCL, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name _ --- -- - Log See Notes D Asc Directional Survey i.'~D D Asc Directional Survey ~D D Asc Directional Survey D D Asc Directional Survey D D Asc Directional Survey M1~ED D Asc Directional Survey ~~ED D Asc Directional Survey (,/~D D Asc Directional Survey G,.Log Sonic „VED D Lis ~'"~ 1345q.- Induction/Resistivity Rgt 13450 LIS Verification L, ~ pt 13449.., LIS Verification D D Lis 13449-ifiduction/Resistivity Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Survey Yes /" (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval Start Stop OH / CH Received Comments 5 Blu 1 1500 9284 Case 9/28/2005 USIT on MaxTrac SAH- Tractor-GR-USIT 9 Aug 2005 13686 15940 Open 10/26/2005 IIFR 0 11230 Open 10/26/2005 IIFR PB 1 10387 11887 Open 10/26/2005 IIFR PB 2 11336 14397 Open 10/26/2005 IIFR PB 3 13686 15940 Open 10/26/2005 MWD 0 11230 Open 10/26/2005 MWD PB 1 10387 11887 Open 10/26/2005 MWD PB 2 11336 14397 Open 10/26/2005 MWD PB 3 5 Col 1 0 5600 .Case 11/18/2005 USIT on MaxTrac -GR- USIT 19 Oct 2005 5054 14359 Open 1/31/2006 ASLD/GR/EWR4/CNP(SLD /ROP/ACAL/PWD/GEOPIL OT P63 5054 14359 Open 1/31/2006 ASLDiGR/EWR4/CNP/SLD /ROP/ACAL/PWD/G EOP I L OT P63 5054 11848 Open 1/31/2006 ASLD/GR/EWR4/CNP/SLD /ROP/ACAL/PWD/GEOPI L OT P62 5054 11848 Open 1/31/2006 ASLD/GR/EWR4/CNP/SLD /ROP/ACAL/PWD/GEOPIL OT P62 DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2050740 Well Name/No. KUPARUK RIV U WSAK 1 E-170 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23264-00-00 MD 15940 TVD 3355 Completion Date 9/10/2005 Completion Status 1-OIL Current Status 1-OIL UIC N D D Lis °° 13448 Induction/Resistivity 5054 11848 Open 1/31/2006 ASLD/GR/EWR4/CNP/SLD /ROP/ACAL/PWD/GEOPIL // OT PB1 ~~ `Rfpt 13448 LIS Verification 5054 11192 Open 1/31/2006 ASLD/GR/EWR4/CNP/SLD /ROP/ACAL/PWD/GEOPIL OT P61 ED D Lis 13448 Induction/Resistivity 5054 11192 Open 1/31/2006 ASLD/GR/EWR4/CNP/SLD /ROP/ACAL/PWD/GEOPIL ED D Lis "~ 13447 ~j Induction/Resistivity ~ss v v ~Y?L`~ ~~, ~1 ~ i > ~~'`5054 15900 Open 1/31/2006 OT P61 ASLD/GR/EWR4/CNP/SLD /ROP/ACAL/PWD/GEOPIL ~ OT ~_/ 'Kpt 13447 LIS Verification 5054 15900 Open 1/31/2006 ASLD/GR/EWR4/CNP/SLD /ROP/ACAL/PWD/GEOPIL OT ..~'D D Lis 13791 ~nduction/Resistivity 5054 15900 Open 3/9!2006 DGR EWR4 PWD GeoPilot CTN ACAL ASLD C Pdf 14212 Neutron 30 3377 Open TVD CTN, ALD, DGR 08- Aug-2005 C Pdf 14212 Neutron 30 3377 Open MD CTN, ALD, DGR 08- Aug-2005 C Pdf 14212 Induction/Resistivity 30 3377 Open TVD DGR, EWR, Inverted Section 08-Aug-2005 (~ C Pdf 14212 Induction/Resistivity 30 3377 Open MD DGR, EWR, Inverted Section 08-Aug-2005 Well C ores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? ~ N Chips Received? ~~1.P4~ Formation Tops ~ N Analysis '~Y1.D~ Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2050740 Well Name/No. KUPARUK RIV U WSAK 1E-170 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23264-00-00 MD 15940 ND 3355 Completion Date 9/10/2005 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 • September 10, 2007 RE: MWD Formation Evaluation Logs: 1E-170,+PBl+PB2+PB3+L1+L2 AK-MW-3778283 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 E-170,+PB 1+PB2+PB3+L 1+L2 Digital Log Images: 50-029-23264-00, 70, 71, 72, 60, 61 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~„ ~~ .~ G ~. ~~ =~6~ ( t5G3~ ~`~ r 563 . Date ,~~ ' is ~.~ ~ r gn ~ ~ Si ed: ~S 6G/b ~.~:~,`",~~ »,:tr of ~s~~'~'-~ L,ilf~li')i ~~~ ~oSa~S i5~~1~ aoso~-~ ~s~~a 3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 10, 2006 RE: MWD Formation Evaluation Logs 1E-170, AK-MW-3778283 1 LDWG formatted Disc with verification listing. API#: 50-029-23264-00 ~~ s PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ ~ ~ ~ Signed: his -~®~~~ ~`~~ • • WELL LOG TRANSMITTAL To: State of Alaska January 10, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1E-170, ~~`~7~~---- AK-MW-3778283 r.~4~-~ 1 LDWG formatted Disc with verification listing. API#: 50-029-23264-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: l V blv Signed: WELL LOG TRANSMITTAL To: State of Alaska Jan~~ary 10, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1T:-170 PBl, ~rO~~AK-MW-3778283 ~~ 1 LDWG formatted Disc with verification listing. A PI# : 50-029-23 264-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETIJI2NING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: l - 0(p Signed: ~ • WELL LOG TRANSMITTAL To: State of Alaska January 10, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1E-170 PB2, AK-MW-3778283 1 ~ ¢ ~-9 1 LDWG formatted Disc with verification listing. API#: 50-029-23264-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETLJI2NING A COPY OF TIIE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ Signe • • WELL LOG TRANSMITTAL To: State of Alaska January 10, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~5 - 0~4-- RE: MWD Formation Evaluation Logs 1E-170 PB3, AK-MW-3778283 1~4s~' 1 LDWG formatted Disc with verification listing. API#: 50-029-23264-72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSNHTTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ Signed• • ConocoPhillips December 12, 2005 Commissioner State of Alaska Alaska Oii & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone:. 907-265-6830 Subject: Well Completion Reports for 1 E-170, 1 E-170L1, 1 E-170L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the West Sak wells 1 E-170, 1 E-170L1, 1 E-170L2. Also attached are the directional surveys for each lateral. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, ~ _ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~t ~E~ ~ ~~~ WELL COMPLETION OR RECOMPLETION REPORT~~1'~C~ ~E~3S• Commisso!le 1a. Well Status: Oita ~ Gas Plugged Abandoned ^ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: Development a Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., / or Aband.: September 10, 2005 12. Permit to Drill Number: 205-074 / 305-271 / 305-285 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 26, 2005 ~ 13. API Number: ~ 50-029-23264-00 4a. Location of Well (Governmental Section): Surface: 24T FNL, 641' FEL, Sec. 21, T11N, R10E, UM ' 7. Date TD Reached: August 7, 2005 ' 14. Well Name and Number: 1E-170 ' At Top Productive Horizon: 1351' FSL, 213' FWL, Sec. 27, T11 N, R10E, UM 8. KB Elevation (ft): 41' RKB 15. FieldlPool(s): Kuparuk River Field Total Depth: 1149' FSL, 170' FWL, Sec. 34, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 15940' MD / 3355' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549890 ' y- 5959340 ~ Zone- 4 10. Total Depth (MD + TVD): 0 15940' MD / 3355' TVD ' 16. Properly Designation: ADL 25660 TPI: x- 550822 y- 5950385 Zone- 4 Total Depth: x- 550828 - 5944903 ' Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 470 18. Directional Survey: Yes ~ No ^ 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1733' MD 21. Logs Run: GR/Res, CCL, USIT ` ~~~~s 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 94# H-40 41' 120' 41' 120' 42" 375 sx AS I 13.375" 68# L-80 41' 5054' 41' 2311' 16" 917 sx AS Lite, 272 sx DeepCrete 9-5/8" 40# L-80 41' 10414' 41' 3451' 12.25" 305 bbls DeepCrete 5.5" 15.5# L-80 9870' 15919' ` 3347' 3355' 8.5" slotted liner kick-off plug @ 10215'-11230' 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" / 2-7/8" 5042' 15072' 9229', 9309' & slotted liner from 10438'-15874' MD 3456'-3355' TVD 9710' 25. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4858'-4860' 20 bbls 15.8# Class G 10215'-11230' 70 bbls Class G 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) ESP Oil Producer -shares production with 1 E-170L1 and 1 E-170L2 -waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ,.. y~ ~B~~ss ,; ~~~7Vla~ ~~ ~^ n e s ZOOS NONE _~ •-~_,16~~Q~ Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~ ~ ~<~ ~ ! CONTINUED ON REVERSE +~~ ~~ - ~~~ L ~ r 2s. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 E-170 West Sak A2 10450' 3458' Base West Sak A2 15940' 3355' N/A 1E-170P61 TD 11230' 3551' 1E-170PB2 TD 11887' 3484' 1E-170P63 TD 14397 3367 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. l hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Na~ R andv Thomas Title: Greater Kuoaruk Area Drillino Team Leader l Z/r 2 /o T ~ ~ Signature ~ `°-`--+~-~ Phone ~~6-~ -~ Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 r~ ~~ ConocoPhillips Alaska Page 1 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date ;; From - To Hours Code ~ Code Phase 6/22/2005 03:30 - 00:00 20.50 MOVE MOB MOVE 6/23/2005 00:00 - 03:00 3.00 MOVE MOVE MOVE 03:00 - 04:00 1.00 MOVE MOVE MOVE 04:00 - 06:30 2.50 MOVE MOVE MOVE 06:30 - 18:00 11.50 MOVE MOVE MOVE 18:00 - 21:30 I 3.50 i MOVE I MOVE MOVE 21:30 - 00:00 I 2.50 {MOVE I MOVE 1 MOVE 6/24/2005 00:00 - 00:30 0.50 MOVE MOVE MOVE 00:30 - 05:00 4.50 MOVE MOVE MOVE 05:00 - 09:00 4.00 MOVE MOVE MOVE 09:00 - 12:00 3.00 MOVE MOVE MOVE 12:00 - 17:00 5.00 MOVE MOVE MOVE 17:00 - 19:30 2.50 MOVE MOVE MOVE 19:30 - 21:30 2.00 MOVE MOVE MOVE 21:30 - 23:00 1.50 MOVE MOVE MOVE 23:00 - 23:30 0.50 MOVE POSN MOVE 23:30 - 00:00 0.50 MOVE MOVE MOVE 6/25/2005 00:00 - 01:00 1.00 MOVE POSN MOVE 01:00 - 03:00 2.00 MOVE POSN MOVE 03:00 - 04:45 1.75 MOVE POSN MOVE 04:45 - 09:30 4.751 MOVE POSN MOVE 09:30 - 10:30 1.001 DRILL RIRD RIGUP 10:30 - 12:00 I 1.501 DRILL I RIRD I RIGUP 12:00 - 18:00 6.00 DRILL RIRD RIGUP 18:00 - 23:00 I 5.001 DRILL I RIRD I RIGUP 23:00 - 00:00 I 1.001 DRILL I PULD I RIGUP Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Move Rig T/ 1 E-170 Tum Key Rig Move: Lay Matts Over all colvert crossings and plywood. Turn Key Rig Move: Rig trying to get over matted culvert crossing powered out. While Trying to work over crossing by backing up and getting run at crossing the back end of Drill unit was allowed to get to close to side of road causing road to blow out. Turn Key Rig Move: Call for Equip, to pull out of hole. Move pit module back to where equipment would have access to rear of drill module. Turn Key Rig Move: W.O. equipment, 08:30 Unload and Road equipment to drill module, Hook up cats to rear beam, Pull sub backwards out of hole unhook cats road back to reload take to FRONT FURTHER HELP. Turn Key Rig Move: Lay plywood Move rig T/KIC. Junction Inspect Rig Wait to lay malts, Move Front of K.O.C. APRS laying plywood 1 E tum off build up acsess road with plywood. Rig Crews waiting on road crew to lay plywood and mats. Turn Key Rig Move: Move rig to 1E acsess road hook up cats and help pull overUp grade Acsess. Move Pit complex over road to back of KOC. Stop Move pits and rig back of koc Wait on mats to be layed and mats to be around. Move from behind KOC to 1E pad. Derrick Module broke through road Build up road. Back module out, Matt road all the way to 1 E pad, Move derrick module and pit Module to entrance of 1 E pad, Set malts for rig foot print Move derrick and pit modules onto 1 E pad, Move pits around. derrick module, Lay more mats not a big enough foot print layed the first time. Spot pit module on mats Repair hose on pit module. Moving system. Spot Pit Module on Matts Move Sub base on Matts spot over Well. Skid Rig and spot pits.To be moved into sub. Crane called to move well house to be able to set pit module.Not reconized until sub and pits on well. Hook up service lines that can be hooked up Set beaver slide. Move well house @ 07;00 Set pit module cont, hooking up service line's. Set rock washer unit,Rigging up service lines, Switch to high line power. Rig Accepted By Fred Herbert @ 10:OOhr. Rig up cutting tank and berm ,Nipple Up Riser, Rizer was to short had to add 27 inches, Could of found out @ 0600 when asked, but did not check until 12;OOhrs. Continue R/U koomey lines, Make up flow lines, Turn Buckles, Start filling pits with fluid. Start loading pipe shed loaded 78jts. Herculate around riser and drip pan. Clear floor of 4"XT subs and handling equipment. Change Saver Sub on top drive,lnstall Shaker screens on shakers.Tighten bolts on riser, Change air boot on flow Iine,Tighten dresser sleeve on flow Iine.Start Building Spud mud, Load pipe shed with 180 5" D.P. 29 HWT DP 3 - 8" flex Collar 8" Motor and MWD.Function test, Koomey Test, Waived by State Man Jeff Jones. Rig Up and start picking up 5" Drill Pipe. standing back in derrick. Printed: 9/30/2005 6:19:05 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conoco phillips.com Rig Name: Doyon 15 Date i From - To Hours Code Sub ' Phase Code __ 6/26/2005 00:00 - 05:30 5.50 DRILL PULD 05:30 - 09:00 3.50 DRILL PULD RIGUP 09:00 - 10:00 I 1.001 DRILL I PULD I RIGUP 10:00 - 13:00 I 3.001 DRILL I PULD I SURFAC 13:00 - 13:30 0.50 DRILL TRIP SURFAC 13:30 - 14:00 0.50 DRILL DRLG SURFAC 14:00 - 14:30 0.50 DRILL RGRP SURFAC 14:30 - 16:30 2.00 RIGMNT DRLG SURFAC 16:30 - 17:30 1.00 DRILL TRIP SURFAC 17:30 - 18:00 0.50 DRILL SURV SURFAC 18:00 - 00:00 6.00 DRILL DRLG SURFAC 6/27/2005 00:00 - 06:00 06:00 - 12:00 12:00 - 18:00 18:00 - 20:00 6.00 DRILL DRLG SURFAC 6.001 DRILL I DRLG I SURFAC 6.001 DRILL DRLG SURFAC 2.001 DRILL I DRLG I SURFAC 20:00 - 20:30 20:30 - 00:00 6/28/2005 00:00 - 02:00 02:00 - 03:00 03:00 - 04:30 04:30 - 05:00 0.50 DRILL CIRC SURFAC 3.50 DRILL TRIP SURFAC 2.00 DRILL TRIP SURFAC 1.00 DRILL PULD SURFAC 1.50 DRILL TRIP SURFAC 0.50 DRILL TRIP SURFAC Page 2 of 45 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Pick Up 5" Drill Pipe and stand in Derrick total 180 joints. Pick Up 5" HWT Drill Pipe and stand in Derrick total 29 joints and set Jars. Pick Up BHA Subs to rig floor, Fill Conductor and check surface equipment. PJSM; Pick Up BHA, Upload MWD, Rick up slick line in derrick for Gyro. Test Mud lines 3,000psi. Tag fill @ 88', Clean out to 120'. Drilling From; 120' - 135'. Working on Power limit control to SCR's Drilling From; 135' - 230'. Gravel returns. Trip Out Hole; Replace with 3 flex Collars, and jars. Gyro Survey @ 215' Drill and survey 16" Hole from 230' MD to 645'MD (640 TVD. TST = 2.77 hrs, TRT = 2.65 hrs, TDT = 5.42 hrs. Avg. ROP = 96 fph. UP WT. 105K, DN WT. 105K, ROT Wt 100K. Tq on Btm 3K, Tq off Btm 1 K, at 50 rpm. Pump at 155 spm, 650 gpm 2,340 psi. APIG= 61.76'per Hr. Jar hrs, 128 Drill and Slide; survey(gyro) 16" Hole. From 645' MD. (640 TVD). To 1,111 MD (1,074' tvd)AST =1.73 hrs, ART =2.62 hrs, TDT = 5.42 hrs. Avg. ROP = 85.9 fph. UP WT. 110K, DN WT. 110K, ROT Wt 115K. Tq on Btm 2K, Tq off Btm 1 K, WOB 15-30k, 60 rpm. Pump at 180 spm, 763 gpm, 3500 psi.Total Drill time 8.32. 106 ROP Average, APIG= 73.41'per Hr. Total Ft Drilled 881' 12hrs. Drill and Slide; survey 16" Hole From 1,111' MD. (640 TVD). To 1,637' MD (1,519'TVD)AST =2.70 hrs, ART =1.43 hrs, ADT = 4.03hrs. Avg. ROP = 130 fph. UP WT. 130K, DN WT. 120K, ROT Wt 125K. Tq on Btm5K, Tq off Btm 3K, WOB 15-30k, 60 rpm. 553 - 763 gpm, 3500 psi.Total Drill time 12.45. 106 ROP Average, APIG= 78.16'per Hr. Total Ft Drilled 1,407' 18hrs. Drill and Slide; survey 16" Hole From 1,637'MD. (1,519' TVD). To 2,253' MD (1,857'TVD) AST= 2.22 hrs, ART =1.58 hrs, ADT = 3.8hrs. Avg. ROP = 162 fph. UP WT. 130K, DN WT. 120K, ROT Wt 125K. Tq on Btm 7K, Tq off Btm 4K, WOB 15-30k, 60 rpm. 553 - 763 gpm, 3500 psi. Total Drill time 16.12. ROP Average,125.4'. APIG= 84.29 'per Hr. Total Ft Drilled 2,023' 24hrs. Drill and Slide; survey 16" Hole From 2,253' MD. (1,857 TVD). To 2,411' MD (1,894'TVD) AST= .2 hrs, ART =1.52 hrs, ADT = 1.74hrs. Avg. ROP = 90.80 fph. UP WT. 140K, DN WT. 120K, ROT Wt 125K. Tq on Btm 7K, Tq off Btm 4K, WOB 15-30K 60 rpm. 553 - 763 gpm, 3500 psi. Total Drill time 17.36hrs .125.6 ROP Average, APIG= 83.88' per Hr. Total Ft Drilled 2,181' 26hrs. Total Jar hrs. 141.21. Circ & Condition Hole for Trip. Last Survey 76.97 incl. 173.56 Azm. 2,347' MD (TVD 1,894') Trip Out Hole; Pump out hole To 900' Pull Out Of Hole. Alot of clay bound to Tool Joints and BHA. Trip Out Hole; Pump out hole To 900' Pull Out Of Hole. Alot of clay bound to Tool Joints and BHA. Clean Bit and BHA. Work BHA; Change bend in Motor from 1.83deg to 1.15deg. Lay Down Pony Collar and drop press drop sub, Orientate tools. Change pulsar valve and attemt to grease valve, Tool Failure, Low Amp hours on Battery, Down load MWD, Pick up new pulsar valve. Re- Orientate Upload MWD. Welding on 4" outlets on Conducter, Printed: 9/30/2005 6:19:05 AM .7 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 6/28/2005 04:30 - 05:00 05:00 - 06:00 06:00 - 10:00 1 E-170 1 E-170 ROT -DRILLING D15CM@conocophillips.com Doyon 15 II Hours Code Code Phase 0.501 DRILL (TRIP ISURFAC 1.00 RIGMNT RSRV SURFAC 4.00 RIGMNT OTHR SURFAC 10:00 - 10:30 0.50 DRILL TRIP SURFAC 10:30 - 11:00 0.50 DRILL CIRC SURFAC 11:00 - 11:45 0.75 DRILL TRIP SURFAC 11:45 - 12:15 0.50 DRILL CIRC SURFAC 12:15 - 12:30 0.25 DRILL TRIP SURFAC 12:30 - 12:45 0.25 DRILL REAM SURFAC 12:45 - 18:00 5.25 DRILL DRLG SURFAC 18:00 - 00:00 6.00 DRILL ~ DRLG ISURFAC 6/29/2005 100:00 - 06:00 I 6.001 DRILL I DRLG ISURFAC 06:00 - 12:00 6.001 DRILL DRLG ISURFAC 12:00 - 18:00 I 6.001 DRILL I DRLG ISURFAC 18:00 - 22:30 i 4.501 DRILL DRLG ISURFAC 22:30 - 23:00 0.50 DRILL CIRC SURFAC 23:00 - 00:00 1.00 DRILL TRIP SURFAC 6/30/2005 100:00 - 05:00 I 5.001 DRILL I REAM ISURFAC Page 3 of 45 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Working with Surface mud, Clean Rock Washer tank torn screens allowed alot of solids in tank. Rig Service ,Grease Crown ,Inspect Drill line. Welding 4" outlets on conductor, Finish up cleaning out rock washer and run fluid back over screens Ship to 1 r pad. Trip in Hole; Finish Picking up upper Bha. Trip in hole to 1,116' Circ and Condition @ 400 gpm 870psi. 200bb1s. High Vis Mud returns. Trip in Hole to 2,064' MD, UP WT. 115k DN WT 110k. Break Circulation, Condition Mud, @400gpm 1050psi. High Vis. Mud Returns. Trip in Hole to 2,360 MD Wash 51' to 2,411' @ 600 gpm, 80 RPM, Drill and Slide; survey 16" Hole From 2,411' MD. (1,894' TVD). To 2,916" MD (1,980'TVD) AST= .72 hrs, ART =2.11 hrs, ADT = 2.83hrs. Avg. ROP = 177.8 fph. UP WT. 130K, DN WT. 110K, ROT Wt 120K. Tq on Btm 7K, Tq off Btm 5K, WOB 15-30K 120 rpm.600-800 gpm,2300 psi. Total Drill time 21.01 hrs .133.63 ROP Average, APIG= 85 'per Hr. Total Ft Drilled- 2686', 31.25hrs. Drill and Slide; survey 16" Hole From 2,916' MD. (1,980' TVD). To 3,549' MD (2,029' TVD) AST= .82 hrs, ART =3.31 hrs, ADT = 4.13hrs. Avg. ROP = 153 fph. UP WT. 130K, DN WT. 90K, ROT Wt 110K. Tq on Btm 9-10kK, Tq off Btm6K, WOB 15-30K 120 rpm.800-900 gpm,2,590 psi. Total Drill time 25.14 hrs .136 ROP Average, APIG= 89' per Hr. Total Ft Drilled-3,319', 37.25 hrs. Drill and Slide; survey 16" Hole From 3,549' MD. (2,029' TVD). To 3,875' MD (2,064' TVD) AST= 2.00 hrs, ART =2.56 hrs, ADT = 4.56hrs. Avg. ROP = 72 fph. UP WT. 130K, DN WT. 95K, ROT Wt 110K. Tq on Btm 9-10K, Tq off Btm 6K, WOB 15-20K 120 rpm.900 gpm,2,950 psi. Total Drill time 32.26 hrs 116ROP Average, APIG= 79' per Hr. Total Ft Drilled-3755', 53.25 hrs. Drill and Slide; survey 16" Hole From 3,875' MD. (2064' TVD). T/ 4,340' MD (2,140' TVD) AST= 2.80 hrs, ART =2 hrs, ADT = 4.80hrs. Avg. ROP = 97 fph. UP WT. 140K, DN WT. 90K, ROT Wt 110K. Tq on Btm 11 K, Tq off Btm 9K, WOB 15K 120 rpm.900 gpm,2,850 psi. Total Drill time37.06 hrs 113ROP Average, APIG= 71 'per Hr. Total Ft Drilled4220', 59.25 hrs. Drill and Slide; survey 16" Hole From 4,340' MD. (2140' TVD). T/ 4,733' MD (2,245' TVD) AST= 3.13 hrs, ART =.89 hrs, ADT = 4.02hrs. Avg. ROP = 97 fph. UP WT. 160K, DN WT. 80K, ROT Wt 115K. Tq on Btm 14K, Tq off Btm 11 K, WOB 15K 120 rpm. 750 gpm,2240 psi. Total Drill time 41.08 hrs 112ROP Average, APIG= 70 'per Hr. Total Ft Drilled4,613', 65.25 hrs. Drill and Slide; survey 16" Hole From 4,733' MD. (2245' TVD). T/ 5,090' TD (2319 TVD} AST= 1.45 hrs, ART =1.46 hrs, ADT =2.91 hrs. Avg. ROP = 122 fph. UP WT. 170K, DN WT. 75K, ROT Wt 115K. Tq on Btm 14K, Tq off Btm 11K, WOB 15K 120 rpm. 900 gpm,3300 psi. Total Drill time 43.99 hrs 112 ROP Average, APIG= 71 'per Hr. Total Ft Drilled4,970', 69.75 hrs. Circulate and pump 11 ppg density sweep 60bbls. Trip Out Hole; Back Ream Out Hole 800 GPM 120 RPM Pull @ 35 Ft per Min. Trip Out Hole; Back Ream Out Hole 800 GPM 120 RPM Pull @ 35 Ft per Min. Attempt to pull pipe (over pull 20k,) Cont. Back Reaming to Printed: 9/30/2005 6:19:05 AM ~~ .J ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophiflips.com Rig Name: Doyon 15 Date !From - To ,Hours Code_ Code Phase 6/30/2005 00:00 - 05:00 5:00 DRILL REAM SURFAC 05:00 - 08:30 3.50 DRILL REAM SURFAC 7/1 /2005 7/2/2005 08:30 - 09:30 I 1.001 DRILL I CIRC I SURFAC 09:30 - 18:00 I 8.501 DRILL I REAM I SURFAC 18:00 - 19:45 I 1.751 DRILL I REAM I SURFAC 19:45 - 21:00 1.251 DRILL TRIP SURFAC 21:00 - 21:30 0.50 DRILL PULD SURFAC 21:30 - 22:00 0.50 DRILL PULD SURFAC 22:00 - 22:30 0.50 DRILL PULD SURFAC 22:30 - 23:00 0.50 DRILL PULD SURFAC 23:00 - 00:00 1.00 CASE SFTY SURFAC 00:00 - 01:15 1.25 CASE RURD SURFAC 01:15 - 02:00 0.75 CASE RURD SURFAC 02:00 - 04:00 2.00 CASE RUNC SURFAC 04:00 - 05:15 1.251 CASE OTHR SURFAC 05:15 - 06:00 I 0.751 CASE I RUNC I SURFAC 06:00 - 07:30 07:30 - 10:00 10:00 - 10:45 10:45 - 12:15 12:15 - 14:45 14:45 - 16:00 16:00 - 16:15 16:15 - 17:30 17:30 - 18:30 18:30 - 19:00 19:00 - 20:00 20:00 - 00:00 1.50 CASE CIRC SURFAC 2.50 CASE RUNC SURFAC 0.75 CASE CIRC SURFAC 1.50 CASE RUNC SURFAC 2.50 CASE CIRC SURFAC 1.251 CASE 0.25 CASE 1.25 CASE 1.00 CASE 0.50 CASE 1.00 CASE 4.00 CASE 00:00 - 02:00 2.00 RUNCISURFAC RURD SURFAC OTHR SURFAC OTHR SURFAC RUNC SURFAC RURD SURFAC CIRC SURFAC RC I SURFAC Page 4 of 45 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations 1,300' Shakers Clean, Pull 2 stands. Pulled free. T/ 1,160'. Trip Back in Hole, Plotting Torq and Drag, Tight Spot @ 4,061' to 4,221' MD. Pumped one jt. down was able to work Dn to 4,221' Up WT. 150k- DN WT.70k After 4,221' Dn wt increased T/ 75-78k Run in To 5,050 Circulated 11 ppg. weighted sweep @ 940 GPM, W/ 3,670 PSI and 150 RPM, out of drill pipe. Trip Out Hole; Backreaming Pumping @ 940 GPM W/ 3600 PSI and 150 RPM, F/ 5090' T/ 1397' MD Trip Out Hole; Cont. back reaming @ Step Down Rate supplied by MWD to circ, with out causing damage Pular Valve 700,600,500,400, 300 GPM and 100 RPM, F/ 1,397' (tvd 1,273' 30.22incl.) T/ 670' (Tvd 660' ). Shakers Cleaned Up pulling slow to 670' Trip Out Hole; Handling BHA, Stand back HWT-Jar, One stand of Flex DC. Trip Out Hole; L/D BHA, Stab, Float Sub, Ubho Sub to MWD. MWD; Service Puiser valve and L/D same. Trip Out Hole; Flush Motor, Drain same, Break bit and grade, L/D Motor Clean and clear floor of BHA. PJSM, on running casing, R/U casing equipment. PJSM, on running casing, R/U casing equipment. M/U hanger and Landing Jt. Make dummy run with Vetco/Gray hanger. P/U & M/U franks fillup tool. P/U and run Shoe2- jts Float 1- Jt fill each test Floats. Run 13 3/8 68# L-80 BTC. 893'. Wieght stacked out on ledge work pipe. From 893' hang collar on conductor 863'. Circulate @ 230 gpm 100psi. Work pipe hitting hard no gain Turn pipe and work down. Run in Hole W/ 13 3/8 Csg. 68# L-80,BTC.F/ 893' T/ 1,533', Fill every Jt. UP WT. 155k, DN WT. 130k. Circulate; Work 2-Jts Down @ 300 bbls. 5.5 bpm 340 psi. UP WT. 168k, DN WT. 140k. Run in Hole W/ 13 3/8 Csg. 68# L-80,BTC. F/ 1,645, T/ 3,100' Fill every Jt. UP WT. 225k, DN WT. 140k. Circulate; Work Pipe pump 273 bbls. 6.5 bpm 440 psi. UP WT.225k, DN WT. 140k. Run in Hole W/ 13 3/8 Csg. 68# L-80,BTC. F/ 3100, T/ 4500' Fill every Jt. UP WT. 280k, DN WT. 125k. Circulate; Work Pipe pump 638 bbls. 6.2 bpm 450 psi. UP WT.260k, DN WT. 130k. Run in Hole W/ 13 3/8 Csg. 68# L-80,BTC. F/ 4,500 T/ 5,032' Fill every Jt. UP WT. 335k, DN WT. 115k. Install Centalizer. M/U Hanger and Landing Jt. Centralizer 17 1/8 would not go through landing ring 17" (shoe @ 5,035'). L/D Hanger Jt. P/U to the centralizer on jt # 121. Circulate and Condition; While Grinding Centralizer down to 16 3/4" OD. ` M/U Hanger and Landing Jt. and land hanger @ 5,079'. L/D Franks Circulating tool and Install Cement Head. Circulate and Condition Mud for Cmt Job. Before Treatment PV 23, YP 33, Gels 10/10/30= 21/49/75, 9.6ppg. MW, F.V. 92. After Treatment PV 18, YP 18, Gels 10/10/30min 10/15/25, 9.6ppg. F.V. 60. Circulate and Condition Mud for Cmt Job. Before Treatment PV 23, YP 33, Gels 10/10/30= 21/49/75, 9.6ppg. MW, F.V. 92. After Treatment PV Printed: 9/30/2005 6:19:05 AM ConocoPhillips Alaska Page 5 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common W ell Name: 1 E-170 Event Nam e: ROT -D RILLING Contractor Name: D15CM @conoco phillip s.com Rig Name: Doyon 1 5 Date ` From - To Hours I Code ~ '! C d Phase o e 7/2/2005 00:00 - 02:00 2.00 CEMEN CIRC SURFAC 02:00 - 05:00 3.00 CEMEN PUMP SURFAC 05:00 - 07:00 2.00 CEMEN DISP SURFAC 07:00 - 09:00 2.00 CASE OTHR SURFAC 09:00 - 12:45 3.75 CASE OTHR SURFAC 12:45 - 16:45 4.00 CASE OTHR SURFAC 16:45 - 20:00 3.25 CASE OTHR SURFAC 20:00 - 23:00 3.00 CASE OTHR SURFAC 23:00 - 00:00 1.00 RIGMNT RSRV SURFAC 7/3/2005 00:00 - 03:00 3.00 RIGMNT RSRV SURFAC 03:00 - 04:30 1.50 RIGMNT RSRV SURFAC 04:30 - 06:30 2.00 RIGMNT RGRP SURFAC 06:30 - 08:30 2.00 WELCT OTHR SURFAC 08:30 - 10:30 2.00 WELCT OTHR SURFAC 10:30 - 16:30 6.00 WELCT NUND SURFAC 16:30 - 20:30 4.00 WELCT BOPE SURFAC 20:30 - 00:00 3.50 WELCT BOPE SURFAC 7/4/2005. 00:00 - 01:00 1.00 WELCT BOPE SURFAC Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations 18, YP 18, Gels 10/10/30min 10/15/25, 9.6ppg. F.V. 60. Pump 10,bb1's CW 100, Test Line to 3,500 psi, Pump 40 bbl's CW100, 50 bbl's mudpush@ 10.5 ppg W/red dye/ Shutdown and drop BTM plug, Pump 734 bbl's lead cement 10.7 ppg Silo's class ASL yield-4.49 FT3/SK Mix 21.150 Gal/Sk Porosity 62.9% Solid Fraction 37.1 % Slurry type tail cement 12.0 ppg Deep Crete Yield 2.47 FT3/SK Mix Fluid 8.231 GAUSK Porosity 44.5% Solid Fraction 55.5% Recriprocating casing could not get back down to hanger. Casing stuck pulled 420K up casing broke free. Up Wt after free 330 K. Could not work back down came up free stopped 24' above hanger. Drop top plug chase with 20 bbl's water Start displacement at 7 bpm - 260 PSI with rig pumps. Diverted to cellar with contaminated mud at 4,352 strokes. Slowed pump rate down to 3 bpm at 5,405strks. To handle returns @ surface. Staged pump rate back up to 5.5 bpm by 5,941 strokes. At 6,200 strokes good cement to surface / 7,050 Strokes pump rate decreased to 3 BPM. 790 psi. Plug bumped at 7,185 strokes W/500 psi over. Total psi 1,300 // CIP 06:46 With 98 bbl's good cement returned to surface. 06:52 checked floats. O.K. C.I.P. Rig Down and Wash. Pump Retarder pill through stack and surface lines and stack Function and wash out hydril. Nipple down Diverter, Flow lines and turn buckles. Pull Riser and hydril, Cut 4" lines off conductor. Back out lock downs. P/U hydril To set Emergency slips. Center 13 3/8" Csg. Set Slips 330,000#-70,000 Block WT. = 260k on slips. Cut Hole in 13 3/8" Csg. Drain, R/D Cement head Do Ruff Cut on csg. UD landing jt, Hanger and cut off piece 13 3/8". N/D diverter, Hydril, and 16" riser, Remove Vetco grey head Had trouble removing wellhead (skirt). Welder working on well head doing final cut, Lay Down all csg Tools, Change out bails, Cleaning Rock washer and pits. Change Oil & Filters in Top Drive, Sevice Rig. Heating and welding on well head. Change Oil & Filters in Top Drive, Sevice Rig. Heating and welding on well head. Wrap well head. Let cool 00;45. Cut and slip drill line 110'. Inspect brakes, Work on Top Drive. Could not P/U Drill Pipe. Clean Rig Floor, Well head cooling, Making up LSDN mud. Clean Rig Floor, Well head cooling, Making up LSDN mud. Test Weld Transition to casing 80% Collapse 1,800psi.Test Well head to 5,000psi. F/15min. M/U csg. head and test 5,000psi. F/15min. Nipple up BOP's need to cut down 20" flow nipple. Still Working on Top Drive. Test BOPE per AOGCC Regs, Approved Drilling Permit, .Test pressures were 250 psi and 3,000 psi. test lower tree seal 250,5,000psi.All test pressures held for 5 min and charted on test recorder. Waived By AOGCC Chuck Scheve, Drilling Supervisor ,and DDI Tourpusher witnessed BOPE test. # 10 Choke Manifold Valve Failed. Will replace before drilling out shoe Notified State Repersenative of plan O.K. By Chuck Scheve. Nipple up and test. Time Exceeded 10hrs Contract time allowed. Continue Testing BOP Equipment. Test BOPE per AOGCC Regs, Approved Drilling Permit, .Test Printed: 9/30/2005 6:19:05 AM ConocoPhillips Alaska Page 6 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours Code Code I Phase 7/4/2005 00:00 - 01:00 1.00 WELCT BOPE SURFAC 01:00 - 02:00 1.00 WELCT OTHR SURFAC 02:00 - 06:00 4.00 DRILL PULD SURFAC ~~ 06:00 - 12:00 I 6.001 DRILL I TRIP I SURFAC 12:00 - 13:45 1.75 DRILL CIRC .SURFAC 13:45 - 16:00 2.25 DRILL DEQT SURFAC 16:00 - 18:00 2.00 CEMEN DSHO SURFAC 18:00 - 19:15 I 1.251 DRILL I CIRC I SURFAC 19:15 - 21:15 2.00 DRILL CIRC SURFAC 21:15 - 21:30 0.25 DRILL CIRC SURFAC 21:30 - 23:00 1.50 DRILL FIT SURFAC 23:00 - 23:15 0.25 DRILL OTHR INTRM1 23:15 - 00:00 0.75 DRILL DRLG INTRM1 7/5/2005 00:00 - 03:45 3.75 DRILL TRIP INTRMI 03:45 - 04:00 0.25 DRILL TRIP INTRM1 04:00 - 06:00 2.00 DRILL DRLG INTRM1 06:00 - 08:00 I 2.001 DRILL I DRLG I INTRM1 08:00 - 08:45 I 0.751 DRILL (CIRC I INTRM1 08:45 - 12:00 I 3.251. DRILL I DRLG I INTRMI Description of Operations pressures were 250 psi and 3,000 psi. test lower tree seal 250,5,000psi.All test pressures held for 5 min and charted on test recorder. Waived By AOGCC Chuck Scheve, Drilling Supervisor ,and DDI Tourpusher witnessed BOPE test. # 10 Choke Manifold Valve Failed. Will replace before drilling out shoe Notified State Repersenative of plan O.K. By Chuck Scheve. Time Exceeded 10hrs Allowed to Nipple up and test BHA. Contractors Charge. L/D Test Equipment, Set Wear Ring I.D. OF wear ring 12.312. Move 5" HWT. in Derrick and Change Out Jars. P/U GEO Pilot and Bit. P/U MWD and Upload. P/U BHA. Trip In Hole P/U 5" Drill Pipe, Install Ghost Reamer #1 on jt. # 11, Run 28 more Install Ghost Reamer #2, Run in hole P/U Drill Pipe. Shallow test Geo Tools and MWD.@ 700gpm 1,380psi. RiH P/U singles T/ 4,925' Up Wt 155k - DN WT. 70K. Top Drive wieght is 70K Circulate and Condition for Casing Test. Test Casing T/ 3,000psi. Chart and plot. F/30min. Drill Float Equipment and shoe, Float @ 4,967', Shoe @ 5,054 Drilling F/ 5,090'MD New Hole 650GPM 1500 psi. 80 Rpm ART=.14 Pull back up into shoe and circulate while spotting trucks for mud swap over operation Displace well to 9.1 ppg LSND new mud @ 6.5 BPM W/ 280 PSI max. due to cuttings auger. Preform Base Line for PWD with new mud and record SPRs R/U and perform FIT, open hole MD= 5110' TVD= 2323' ,Casing shoe @ 5054' MD/ 2311' TVD, LOT @ 430 psi =EMW= 12.7ppg w/ New Mud wt=9.1 ppg Attemp to down link command to Geo Pilot with 720 GPM, losing mud over shakers. Changed jet bn skid to size 22 Drill F/ 5110' T/ 5181' ART= .87 TVD= 2326' Pull out of hole f/ 5181' to 13 3/8" casing shoe @ 5054'. Change out jet in Geo pilot skid. Change out shaker screens on shakers. Attempt to work Geo pilot. Change out jet on Geo Pilot skid. Attempting to pump 400 gpm. Shakers running over. Change out all shaker screens to one shaker (set of 4 screens) all 80 mesh, other two shakers to 50 mesh screens. RIH Trip in hole f/ 5084' to 5181 Directional drill 12 1/4" hole f/ 5181' to 5568' (2410' TVD) (387') ART 1.96 hrs w/ Sperry Sun geo pilot, 10-25 WOB, 150 rpm's, 600-900 gpm, 9.1 ppg mw, on bottom pressure 1040-1300 psi, off bottom pressure 980-1500 psi, on bottom toque 10-20k fUlb, off bottom torque 8-10k ft/Ib, PU wt 145-150k, SO wt 90-100k, Rot wt 118-120k. Directional drill 12 1/4" hole f/ 5568' to 5780' (2441' TVD) (212') ART 1.48 hrs w/ Sperry Sun geo pilot, 10-15 WOB, 150 rpm's, 900-855 gpm, 9.1 ppg mw, on bottom pressure 1300-1770 psi, off bottom pressure 1500-1750 psi, on bottom toque 10-15k ft/Ib, off bottom torque 7-9k ft/Ib, PU wt 140k, SO wt 100k, Rot wt 115k. PU off bottom, circ @ reduced rate (440 gpm) while change out shaker screens to finer size. Directional drill 12 1/4" hole f/ 5780' to 5998' (2478' TVD) (218') ART 2.16 hrs w/ Sperry Sun geo pilot, 10-20 WOB, 150 rpm's, 865-938 gpm, 9.1 ppg mw, on bottom pressure 1770-1920 psi, off bottom pressure 1750-1890 psi, on bottom toque 10-12k ft/Ib, off bottom torque 7-10k ft/Ib, PU wt 145k, SO wt 95k, Rot wt 120k. Hard stringers between Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 7 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To I Hours ~ Codde Code ~ Phase 7/5/2005 08:45 - 12:00 3.25 DRILL DRLG INTRMI 12:00 - 18:00 6.00 DRILL DRLG INTRMI 18:00 - 00:00 6.00 DRILL DRLG INTRM1 7/6/2005 100:00 - 08:45 I 8.751 DRILL I DRLG I INTRM1 08:45 - 12:00 I 3.251 DRILL I REAM I INTRM1 12:00 - 14:00 2.001 DRILL OTHR INTRM1 14:00 - 14:45 0.75 DRILL REAM INTRM1 14:45 - 16:45 2.00 DRILL TRIP INTRM1 16:45 - 18:00 1.25 DRILL OTHR INTRM1 18:00 - 20:30 2.50 DRILL OTHR INTRM1 20:30 - 00:00 3.501 DRILL ~ OTHR INTRM1 7/7/2005 100:00 - 11:00 11.00 DRILL OTHR INTRM1 11:00 - 11:15 0.25 FISH SFTY INTRM1 11:15 - 13:15 2.00 FISH RURD INTRM1 13:15 - .14:00 0.751 FISH ELIN ~ INTRM1 14:00 - 15:00 1.00 FISH ELIN INTRM1 15:00 - 17:00 2.00 FISH OTHR INTRM1 17:00 - 18:30 I 1.501 FISH ELIN I INTRMI Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations 5900' and 6998'. Directional drill 12 1/4" hole f/ 5998' to 6736' (2635' TVD) (740') ART 3.51 hrs w/ Sperry Sun geo pilot, 10-20 WOB, 150 rpm's, 855-942 gpm, 9-9.1 ppg mw, on bottom pressure 1690-2200 psi, off bottom pressure 1650-2190 psi, on bottom toque 10-13k ft/Ib, off bottom torque 7-11 k ft/Ib, PU wt 140-170k, SO wt 100-88k, Rot wt 115-125k. Directional drill 12 1/4" hole f/ 6736' to 7681' (2867' TVD) (945') ART 3.39 hrs w/ Sperry Sun geo pilot, 15-20 WOB, 150 rpm's, 900-933 gpm, 9-9.1 ppg mw, on bottom pressure 2110-2350 psi, off bottom pressure 2100-2310 psi, on bottom toque 10-13k ft/Ib, off bottom torque 8-12k ft/Ib, PU wt 170-172k, SO wt 95-90k, Rot wt 125-127k. Directionally drilled 12 1/4" hole with Geo-pilot f/ 7681' to 9,108' MD/ 3,225' TVD, (1,427') ART 4.29 hrs, 10-20 WOB, 90- 150 rpm's, circ at between 576 at 1,850 psi, to 930 gpm at 2,370 psi, , on bottom torque 13-17k ft-Ibs, off bottom torque 10-14k fUlb, PU wt 180k, SO wt 100k, Rot wt 130k, 9-9.1 ppg mw, ave ECD 10.1 ppg, while backreaming up to make Conn at 9,068' hole packed off and lost returns Backreamed out of hole slowly while rotating and attempting to regain circ, backreamed out from 9,108' to 8,803' at 150 rpm's and 23K ft-Ibs torque and was unable to regain circ Attempted to regain circ while rotating pipe at 8,803' at 150 rpm's with no success, PU to 300K on DP slacking off to block wt of 70K with no upward movement Reamed down from 8,803' to 9,016' at 150 rpm's while attempting to circ and would pump mud away with no returns POOH f/ 9016' to 8824', PU wt 250-270k ,ream up f/ 8824' to 8774' (tight @ 8774'). While attempting to est circ, pipe rotation stopped, pulled 430K on DP and worked DP up from 9,016' to 8,712', still unable to rotate or circ Attempted to pull pipe free, began PU to 500K on DP while maintaining 900 psi on DP, hydrauliced and moved pipe up hole 24' from 8,712' to 8,688' and pipe stopped Cont to work pipe up while attempting to circ, working pipe up to 500K and down to block wt of 70K, attempting to rotate pipe and circ with no success, called out Baker fishing hand along with Schlumberger wireline, cont. to work pipe while waiting on Schlumberger Cont to work pipe up while attempting to circ, working pipe up to 500K and down to block wt of 70K, attempting to rotate pipe and circ with no success while W.O. Schlumberger (SWS) E-line Held PJSM with SWS and rig crew on RU of E-line RU SWS wireline scheaves and lubricator, MU 1.56" pert gun on 1 11/16" tool string, tool length 16.1' RIH with 1.56" pert gun with CCL on E-line to 2,200' with no pump, attempted to pump down tool from 2,200' and was only able to get to 2,400', staged pump rate up from 1/2 bpm to 4 bpm at 1,080 psi and was unable to get tool deeper POOH and LD perf gun Changed out E-line from .39" to .23" line and added 3- 2" pieces (4' total) of roller stem to tool string, overall tool length 17.9' RIH with 1.56" perf gun with CCL on E-line to 2,200' with no pump, attempted to pump down tool from 2,200' and was only able to get to 2,500', staged pump rate up to 3 bpm at 960 psi and was unable to get tool deeper Printed: 9/30!2005 6:19:05 AM • ConocoPhillips Alaska Page 8 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To 7/7/2005 1 i Hours I Code Sole ~Phase 19:45 - 2 :30 1.75 FISH ELIN INTRM1 21:30 - 23:00 I 1.501 FISH I ELIN I INTRM1 23:00 - 00:00 1.00 FISH ELIN INTRM1 7/8/2005 00:00 - 01:30 1.50 FISH ELIN INTRM1 01:30 - 09:30 8.00 WAITON EOIP INTRM1 09:30 - 12:30 3.00 WAITON EQIP INTRM1 12:30 - 13:30 1.00 FISH FISH INTRM1 13:30 - 16:15 2.751 RIGMNT RSRV INTRM1 16:15 - 17:15 1.00 FISH JAR INTRM1 17:15 - 00:00 6.75 WAITON EQIP INTRM1 7/9/2005 00:00 - 00:30 0.50 FISH SFTY INTRM1 00:30 - 04:30 4.00 FISH ELIN INTRM1 04:30 - 06:15 I 1.751 FISH I ELIN I INTRMI 06:15 - 07:15 1.00 FISH ELIN INTRM1 07:15 - 08:15 1.00 FISH RURD INTRM1 08:15 - 09:15 1.00 FISH OTHR INTRM1 09:15 - 10:30 I 1.251 FISH I ELIN I INTRM1 10:30 - 11:15 0.75 FISH RURD INTRM1 11:15 - 12:20 1.08 FISH ELIN INTRM1 12:20 - 14:15 1.92 FISH ELIN INTRM1 14:15 - 15:30 I 1.251 FISH I ELIN I INTRM1 15:30 - 16:45 1.251 FISH ELIN INTRM1 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations POOH and LD perf gun MU perf string with roller stem and MU 5" OD x 1/4" thick piece of DP rubber wiper plug on btm of perf string to aid in pumping tool down RIH with 1.56" perf gun pumping tool down, staged pump rate up from 1 bpm at 870 psi to 4 bpm at 1,050 psi, was only able to get tool down to 2,200', appears to be pumping mud past tool string POOH and LD perf gun, saw no wear on wiper plug, Note: while attempting to pump tool down hole on the 3 runs we pumped a tota{ of 216 bbls away RD Schlumberger wireline and scheaves Waited on coiled tbg unit and crane, repositioned HWDP in derrick for coiled tbg and performed derrick inspection, tightening bolts on top drive rails, decision was made at 09:30 not to run coil tbg and re-run E-line, crane and coiled tbg unit on location at 06:30 hrs Called out SWS, prep rig for wireline while W.O. SWS, called out WeIlTech tractor tool and equipment also Performed blind back off on top jt and changed out same due to egged spot on tube Changed out 4 1/2" IF saver sub on top drive, inspected and serviced top drive and greased blocks Jarred on fish at 8,688' with no movement, PU to 500K working jars Waited on E-line unit with tractor tool, SWS and Well Tech worked on hooking tractor tool electronics to E-line unit at KIC, E-line unit arrived location at 23:45 hrs Held PJSM with SWS, Welltec and rig crew on RU of wireline tools RU SWS scheaves, grease injector head and control line, 2-5" pup jts with safety valve, MU 1.56" x 5' perf gun with 30 shots on 1 11/16" tool string with 2 pieces of roller stem (3' long) along with SWS SCUD tool used to assist in pumping down tools RIH with 1.56" perf gun to 2,320' without pumping, began staging pump rate up from 1/2 bpm to 4 bpm at 970 psi while working tool string down to 2,952', took 30 min to work tool last 12', pumped a total of 217 bbls of 9.0 ppg mud while attempting to pump tool down POOH w/ wireline. Deepest could get was 2952'. Held PJSM. Rig down Schlumberger lubricator, hoses f/ grease tube, sheaves, and drill pipe pup jts. PU on string to 225k. Set slips w/ 225k on slips. Rig up Schlumberger sheaves, TIW valve, and grease head for tractor run w/ perf guns. Waiting on Schlumberger tools (40' gun spacer-(2) 20' jts- blank gun stock w/ TCP connection on top). PU Schlumberger wireline gun and Weltech tractor assembly. MU pump in head and packoff. Tool string consisted of 1-11/16" wireline head, 1-11/16" Swivel, 2-1/8" Weltech tractor, 1-11/16" CCL, 1-11/16" Addressable tractor protection switch, 1-11/16" Firing head, 1.56" Gun (High Shot Density (HSD powerjet) 60 deg phase/360 deg, 6 shots per ft). Total tool string length 31.7'. RIH w/ Schlumberger wireline tools to 2202' using gravity. Start using Welltec tractor to get 31.7' tool string (5' perf guns) in hole f/ 2202' to 6500'. Running 40'/min. Continue Welltec tractor, RIH f/ 6500' to tie in CCL w/ 2nd ghost reamer in hole @ 7882.39'. Continue Welltec tractor, RIH f/ 7882' to 8300' Printed: 9/30/2005 6:19:05 AM r~ ConocoPhillips Alaska Page 9 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Code Phase 7/9/2005 16:45 - 17:00 0.25 FISH ELIN INTRM1 17:00 - 18:15 I 1.251 FISH I ELIN I INTRM1 18:15 - 19:30 1.25 FISH ELIN INTRM1 19:30 - 20:45 1.25 FISH ELIN INTRM1 20:45 - 21:00 0.25 FISH SFTY INTRM1 21:00 - 21:30 0.50 FISH ELIN INTRM1 21:30 - 00:00 2.50 FISH ELIN INTRM1 7/10/2005 00:00 - 01:00 1.00 FISH ELIN INTRM1 01:00 - 02:45 I 1.751 FISH I ELIN I INTRM1 02:45 - 06:00 3.25 FISH ELIN INTRM1 06:00 - 06:45 0.75 FISH ELIN INTRM1 06:45 - 07:45 1.00 FISH ELIN INTRM1 07:45 - 09:42 1.951 FISH ELIN INTRM1 09:42 - 09:45 I 0.051 FISH I ELIN I INTRM1 09:45 - 09:50 0.08 FISH ELIN INTRM1 09:50 - 10:45 0.92 FISH ELIN INTRM1 10:45 - 11:30 0.75 FISH ELIN INTRM1 11:30 - 11:45 I 0.251 FISH I CIRC I INTRM1 11:45 - 14:30 2.751 FISH CIRC INTRM1 14:30 - 14:45 0.251 FISH CIRC INTRM1 14:45 - 15:15 0.501 FISH (CIRC INTRM1 15:15 - 16:15 1.001 FISH CIRC INTRM1 16:15 - 17:45 ~ 1.50 ~ FISH ~ CIRC ~ INTRM1 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Continue to RIH w/ tool string f/ 8300' to CCL depth of 8376.5'. This places top shot @ 8381'- bottom shot @ 8386'. (This is 3'-4' away f/ bottom tool joint upset and 3'-4' f/ middle upset bottom, on first 5" HWDP above Daily/Weatherford jars). Another way to put this is: 5.36' above box on jars is bottom shot placement. Tooljoint is 2.3' long. Attempt to fire Schlumberger guns @ 8381'- 8386' in jt of 5" HWDP above jars. Could not fire guns. Confirm w/gun manufacter on rig up, running w/ tractor. Toolstring needs another piece. Note: 4 bbls fluid lost in last 12 hours to the hole. POOH w/ Schlumberger WL and Welltec tractor f/ 8376' to surface. UD Schlumberger toolstring. Reconfigure toolstring w/ xtra switch. PJSM on picking up wireline tools. PU tool string, RIH 200' MU grease head and control lines. RIH w/ Schlumberger WL and Welltec tractor w/ 5' pert gun at 4000' Continue RIH w/ Schlumberger WL and Welltec tractor w/ 5' pert gun at f/ 4000' to 6233'. Generator supporting Weltech tractor drive, failed. Change out generator. Continue RIH w/ Schlumberger WL and Weltech tractor w/ 5' pert gun at f/ 4000' to 7882'. Second ghost reamer @ 7882'. Continue RIH w/SWS WL and Welltec tractor f/ 7882'. Tie in w/ CCL with second ghost reamer @ 7882' PU wt 1550 pounds while pulling @ 50'/ min Continue RIH w/SWS WL and Welltec tractor f/ 7950'-8250' (First HWDP @ 8237). Continue RIH w/SWS WL and Welltec tractor f/ 8250' to CCI on depth @ 8372.3' (top shot @ 8381', bottom shot @ 8386'. SWS fire guns w/ 1120 pounds line tension, lost 20-25 pounds line tension once guns were activated. POOH w/ SWS wireline. Log ghost reamer on way out. 7882'-7888' WLM. On depth. Continue POOH w/ wireline f/ 7882' to 200' @ 150'/min. Wireline size .32": wireline displacement 185#/ft/1000' @ 8300'= .5 bbls= 31' inside dp. R/D SWS packoff, finish POOH w/ wireline tools, L/D tools. leave equipment on floor. All shots fired. MU top drive. Pump @ 1 bpm 800/810 psi. 6 bbls to fill and/or pump away. Pump total of 9 bbls. Shut down pumps. Attempt to cock jars w/ no success, work pipe down to 500K (pressure bleed to 670 psi). Start pumps @ .75 bpm w/ 530 psi. 7% flow. Work up slow to 2.5 bpm w/ 860 psi w/ 14% flow. MW out 9.4 ppg vis 108. MW in 9.0+ vis 55. Total fluid pumped 350 bbls so far. Increase pumps f/ 2.5bpm to 3 bpm. 3BPM w/ 940-753 psi w/ 25% flow. Total fluid pumped 420 bbls so far. Increase pumps f/ 3bpm to 5 bpm. 5 BPM w/ 800 psi w/ 26% flow. Total fluid pumped 500 bbls so far. Increase pumps f/ 5 bpm to 6 then 7 bpm. 7 BPM w! 900 psi w! 30% flow. Total fluid pumped 870 bbls so far. Increase pumps f/ 7bpm to 8 then 9 bpm. 9 BPM w/ 940 psi w/ 33% flow. Total fluid pumped 2475 bbl, then pump 62 bbl sweep 9.2 ppg wl 83 vis. Follow w/ 9.1 59-62 vis mud. Started working pipe @ 1645 hrs. PU 480k Printed: 9/30/2005 6:19:05 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 7/10/2005 7/11 /2005 1 E-170 1 E-170 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Hours Code i Code Phase __ 17:45 - 20:00 2.25 FISH CIRC INTRM1 20:00 - 20:30 0.501 FISH CIRC INTRM1 20:30 - 21:30 I 1.001 FISH I CIRC I INTRM1 21:30 - 23:15 1.751 FISH CIRC INTRM1 23:15 - 00:00 0.751 FISH PULL INTRM1 00:00 - 00:30 0.50 DRILL TRIP INTRM1 00:30 - 06:00 5.50 DRILL REAM INTRM1 06:00 - 07:45 I 1.751 DRILL (CIRC I INTRM1 07:45 - 08:30 0.75 DRILL CIRC INTRM1 08:30 - 08:45 0.25 DRILL TRIP INTRMI 08:45 - 09:15 0.50 DRILL CIRC INTRM1 09:15 - 11:15 2.00 DRILL TRIP INTRM1 11:15 - 11:45 0.50 DRILL TRIP INTRM1 11:45 - 12:30 0.751 DRILL PULD INTRM1 12:30 - 13:30 1.001 DRILL PULD INTRM1 13:30 - 14:30 1.00 DRILL PULD INTRM1 14:30 - 15:30 1.00 DRILL PULD INTRM1 15:30 - 16:30 I 1.001 RIGMNTI RSRV I INTRM1 16:30 - 18:00 1.50 DRILL PULD INTRM1 18:00 - 19:00 1.00 DRILL PULD INTRM1 19:00 - 20:00 1.00 DRILL PULD INTRM1 20:00 - 21:30 1.50 DRILL TRIP INTRM1 21:30. - 22:00 0.50 DRILL TRIP INTRM1 22:00 - 22:30 0.50 DRILL CIRC INTRM1 22:30 - 23:15 0.75 DRILL TRIP INTRM1 23:15 - 23:45 0.50 DRILL TRIP INTRM1 23:45 - 00:00 0.25 DRILL OTHR INTRMI 7/12/2005 00:00 - 01:15 1.25 RIGMNT RSRV INTRM1 01:15 - 02:00 0.75 DRILL OTHR INTRM1 02:00 - 02:30 0.50 DRILL TRIP INTRM1 02:30 - 06:00 3.50 DRILL REAM INTRM1 06:00 - 07:45 1.751 DRILL REAM INTRM1 Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Page 10 of 45 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations Increase pumps f/ 9 bpm to 10 bpm. 10 BPM w/ 940 psi w/ 34% flow. Total fluid pumped after sweep, 600 bbls so far. Increase pumps f/ 10 bpm to 11 bpm. 11 BPM w/ 1150 psi w/ 35% flow. Total fluid pumped after sweep, 850 bbls so far. MW in 9.1 vis 61, mw out 9.1 vis 59. Increase pumps f/ 11 bpm to 12 bpm. 12 BPM w/ 1230 psi w/ 37% flow. Total fluid pumped after sweep, 1200 bbls so far. MW in 9.1 vis 61, mw out 9.1 vis 59. Pump 40 bbls water, follow w/ 80 bbl 9.0 mw 92 vis sweep. Continue circ @ 12 bpm 1100 psi 38% flow while working drill pipe and jars, pulled 450K and actuated jars, after jars hit continue to pull up to 500K BHA began to move, worked pipe and BHA, pulled bit to 8,418' with 420K-480K at report time Pulling bit f/ 8,418' with 420K-480K, continue pulling to 8226'. Backream out of hole f/ 8226' to 4992'. Ream w/ 60 RPM, 12-14k torque, 337 gpm w/ 500 psi. Rig down Schlumberger wireline. Circ and condition mud and hole. Pump 920 gpm w/ 1750 psi, rotate 150 rpm. Perform derrick inspection afterjarring.. Bit is inside of 13 3/8" casing. POOH 5 stands f/ 4992' to 4527', monitor fill, ok. Pump dry job, blow down top drive. POOH f/ 4527' to 1699'. L/D top ghost reamer. Continue POOH f/ 1699' to 800', L/D second ghost reamer. POOH f/ 800' to 358'. L/D 1 jt 5" HWDP, L/D HWDP above jars w/ shot holes. 31 dimples in jt. (lowest 7.35' above pin end connection)( while in hole perfs @ 8379'-8384'). L/D Daily/Weathertord jars( ser # 15161078). POOH 1 stand 5" HWDP. L/D Sperry Sun BHA. 8" NM flex DC's (ser# 192421, 192413, 192417), NM float sub {ser # 4150). Break Security 12 1/4" FMFX 553 bit (ser # 10394493) Download Sperry Sun MWD/LWD. L/D 8" pulsar (ser # 78388K8), 8" GR/RES/PW D(ser # 7745HAWRG8), NM GP flex DC(ser # CP972705), Geo Pilot 9600 with top stab (ser # TL078) Service top drive. PJSM, PU/MU new BHA, MU bit #3. Upload Sperry Sun MWD tools. Continue PU/MU Sperry BHA. SLM 4 stands 5" HWDP. Continue trip in hole 11 jts 5" DP, MU Weatherford 12 1/4",ghost reamer, 28 jts 5" DP, Weatherford ghost reamer. RIH 5" DP f/ 1828' to 2550'. Fill pipe, break circ. RIH 5" DP f/ 2550' to 3500', fill pipe. RIH 5" DP f/ 3500' to 5026', fill pipe. Move 5" dp in derrick f/ ODS to DS. Inspect brakes on drawworks. Loose jam nut, tighten same. Replace broken grease fitting line. Base line PWD. RIH f/ 5086' to 5290'. Taking weight going down. No string weight left. Ream in hole f/ 5290' to 6389', rotate @ 60 rpm, pump 900 gpm w/ 2350 psi, 10'/min. PU wt 170k, so wt 80k, rot wt 125k. Torque 10-11 k. Ream in hole f/ 6389' to 6975', rotate @ 60 rpm, pump 900 gpm w/ Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conoco phillips.com Rig Name: Doyon 15 Date From - To Hours Code ' Phase Cad e 7/12/2005 06:00 - 07:45 1.75 DRILL REAM INTRM1 07:45 - 14:30 6.75 DRILL REAM INTRM1 14:30 - 16:30 16:30 - 17:00 17:00 - 18:00 2.001 DRILL iCIRC INTRM1 0.501 DRILL I REAM I INTRM1 1.001 DRILL I DRLG I INTRM1 18:00 - 00:00 7/13/2005 00:00 - 06:00 06:00 - 11:00 6.001 DRILL ~ DRLG INTRM1 6.001 DRILL I DRLG I INTRM1 5.001 DRILL DRLG INTRM1 11:00 - 11:30 0.50 DRILL CIRC INTRM1 11:30 - 12:00 0.50 DRILL REAM INTRM1 12:00 - 18:00 6.00 DRILL REAM INTRM1 18:00 - 00:00 I 6.001 DRILL I REAM I INTRM1 7/14/2005 00:00 - 02:15 2.25 DRILL REAM INTRM1 02:15 - 03:30 1.25 DRILL CIRC INTRM1 03:30 - 04:00 0.50 DRILL TRIP INTRM1 04:00 - 05:30 1.50 DRILL CIRC INTRM1 05:30 - 06:00 0.50 DRILL OBSV INTRM1 06:00 - 09:30 3.50 DRILL TRIP INTRM1 09:30 - 11:00 1.50 DRILL PULD INTRM1 11:00 - 11:45 0.75 DRILL PULD INTRM1 11:45 - 12:00 0.25 DRILL TRIP INTRM1 12:00 - 13:00 1.00 DRILL TRIP INTRMI 13:00 - 16:30 3.50 CASE OTHR INTRM1 16:30 - 17:00 0.50 CEMEN PULD INTRM1 17:00 - 18:00 1.00 CASE RUNC INTRM1 18:00 - 18:30 0.50 CASE SFTY INTRM1 18:30 - 00:00 5.50 CASE RUNC INTRM1 7/15/2005 ~ 00:00 - 04:30 ~ 4.50 ~ CASE ~ RUNC ~ INTRM1 Page 11 of 45 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations 2350 psi, 10'/min. PU wt 170k, so wt 80k, rot wt 125k. Torque 10-11 k. Ream in hole f/ 6975' to 9048', rotate @ 150 rpm, pump 900 gpm w/ 2650 psi, 15'/min. PU wt 180k, so wt 95k, rot wt 133k. Torque 16-19k ft/Ibs ECD 9.98. No losses while reaming to bottom. Circ & cond to clean hole. Backream @ 2 fpm f/ 9048'-8950'. 910 gpm w/ 2650 psi, Up wt, 180k, Dn wt. 95k, Rt wt. 133k, Torque 16-19k ft/Ibs. Perform Base line for PWD w/ clean hole (9.94). Ream to bottom f/ 9048' to 9108' All reaming parameters same as above. Drilling f/ 9108' to 9170'. 750 gpm w/ 2050 psi. 120 rpm, Torque on bttm 16-18 k ft/Ibs, off bottom 16k ft/Ibs, Up wt 180k, Dn wt 95k, Rot wt 134k. ADT .55 hrs Drilling f/ 9170' to 9506'. 905 gpm w/ 2750 psi, 150 rpm, Up wt. 190k, Dn wt. 98k, Rot wt. 133k. Torque 14-20k ft/Ibs. ADT = 4.96 hrs. Drilling f/ 9506' to 9960'.(TVD 3363'). Up wt. 195k, Dn wt 100k, Rot wt 130k, Torque 20-21 k ft/Ibs on bttm, 15-16k ft/Ibs off bttm w/ 150 rpm, 916 gpm w/ 2950 psi. ART= 3.95 hrs. ECD= 10.33 Drilling f/ 9960' to 10,420'.(TVD 3452'). Up wt. 190k, Dn wt 90k, Rot wt 130k, Torque 20-22k ft/Ibs on bttm, 17-22k ft/Ibs off bttm w/ 150 rpm, 900 gpm w/ 2950 psi. ART= 2.55 hrs. ECD= 10.4 Circulate w/ Rotation & reciprocation. MWD survey, SPR's Backream out of hole @ 2 fpm w/ 150 rpm, 900 gpm to clear cuttings from BHA. Back ream out of hole f/ 10,365' to 8706' @ 15 fpm w/ 150 rpm, 900 gpm. Record TAD data w/ backreaming. Torque 13-18k ft/Ibs. No Losses Back ream out of hole f/ 8706' to 6960'. 850 gpm w/ 2500 psi, 125 rpm. From 8706' to 8007' BROOH @ 2-3 fpm (Torque erratic 10-22k ft/Ibs) to help clean hole. BROOH f/ 8007' to 7436' @ 15-16 fpm (Torque 10-22k ft/Ibs). From 7436' to 6960' @ 15-16 fpm (Torque 13-17k ft/Ibs). ECD's f/ 10.4-10.1. Steady cuttings load @ shakers (no waves). Slight Losses (16 bhr) Continue BROOH from 6,960' - 5,897'. Circ bottoms up 2X, at 874 gpm, 1,900 psi. POOH from 5,897' - 5,054' - no problems. Circ hole clean @ 874 gpm and 1,900 psi, spot tube pill. RPM = 125, TO = 9,000 ft-Ib, UWT = 135K, DWT = 100K, ROT = 115K. Monitor well -static. Pump dry job, blow down TD, drop 2-7/8" Rabbit. POOH to BHA. SLM 5" DP. LD Reamers. LD BHA -Jars, 3-Flex DCs, and break out bit. Download MWD. LD MWD Continue LD BHA, clean and clear floor. Change out bottom RAMs to 9-5/8". Function test Blind RAMs, Lower Pipe RAMs and Annular preventer. Pull Wear Ring, test 9-5/8" RAMS to 250 / 3,000 psi, 5 min each. Install Wear Ring and LD test Jt. RU Cement head. RU 9-5/8" Csg equipment. PJSM with all parties. PU/MU liner shoe joints. Check floats -okay. Run 70 jts of 9-5/8", 40 Ib/ft, L-80, BTC to 2,690' tmd. Spiralglider centralizers run on everyjoint (floating). Fill pipe every 5 joints. Run torque rings in every joint. Average MU t0 = 8,500 ft-Ib. Continue running 9-5/8" liner without problems. Run a total of 144 jts Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To '' Hours Code Phase ' ' Code 7/15/2005 00:00 - 04:30 4.50 CASE RUNC INTRM1 04:30 - 05:30 1.00 CASE RUNC INTRM1 05:30 - 06:00 06:00 - 12:00 12:00 - 15:00 15:00 - 18:00 18:00 - 20:45 0.50 CASE RUNC INTRMI 6.00 CASE RUNC INTRM1 3.00 CASE RUNC INTRM1 3.00 CASE RUNC INTRM1 2.75 CASE RUNC INTRM1 20:45 - 21:00 21:00 - 00:00 7/16/2005 100:00 - 01:30 01:30 - 02:15 02:15 - 03:15 03:15 - 04:00 04:00 - 05:15 05:15 - 05:30 05:30 - 07:45 0.25 CEMEN~RURD INTRM1 3.00 CEMEN CIRC INTRM1 1.501 CEMENlf CIRC I INTRM1 0.751 CEMENIIPUMP I INTRM1 1.001 CEMENl~OTHR I INTRMI 0.751 CEMENlf PUMP I INTRM1 1.251 CEMENlf DISP I INTRM1 0.251CEMENl~OTHR INTRM1 2.251 CEMENl1CIRC INTRMI Page 12 of 45 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group:. Rig Number: 15 Description of Operations with a total of 142 spiralglider centralizers -floating. RD casing handling equipment and change elevators for 5" DP. Install wiper plug and MU 9-5/8" x 13-3/8" hanger. Mix packer hydraulic fluid and fill same. Set Iron Roughneck track and MU first stand of DP. CBU at 300 GPM and 200 psi. Rotate liner string at 10 rpm with 12-17K ft-Ib of torque. UWT=190K, DWT=102K, ROT=112K RIH w/ liner to 7,350'. Circ new mud in hole every 5 stds. UWT - 195K, DWT - 80K, ROT - 120K. Wash and ream pipe from 7,350 - 8100'. Note: Pipe would no longer slide downhole without pumping and or rotating from 7,350' on. Work pipe from 8,100 - 9,200'. UWT - 125K, DWT - 80K, ROT - 125K. Rotate at 10-15 rpm with 15-20K ft-Ib of TO, 65 SPM and 320 psi. Continue to work liner to bottom circulating at 4-6 BPM with 320-380 psi, 15-20 RPM and 20 ft-Ib of TQ. Tag bottom and PU 6'. UWT=245K, DWT=90K. RU cmt head and circ lines. MU same. Rotate and reciprocate liner at 20 rpm. Circ and condition mud for cmt job. Stage pump from 4.5 BPM to 86PM at 500 psi. Mud before/after = 9.45/9.0 ppg, PV/YP = 16/25 =>11/16. Fin circ & cond mud for cementing, circ at 80 spm, 8 bpm at 560 psi, st up wt 205K do wt 145K, torque limiter set at 20K ft-Ibs with 10-20 rpm's up & down. Held PJSM W/Dowell, ASRC and rig crew on cementing detail and potential hazards, cont to circ hole while holding PJSM, Mud before/after = 9.45/9.0 ppg, PV/YP = 16/25 =>11/16. Turned over to Dowell and pumped 10 bbls CW 100, pressure tested lines to 4,000 psi, pumped 30 bbls add. CW 100 at 8.3 ppg, ave 6.75 bpm at 350 psi, then pumped 40 bbls of MudPush at 10.5 ppg, ave 5 bpm at 100 psi, began mixing cmt @ 02:00 hrs, started pumping cmt at 02:02 cont to rotate & reciprocate pipe, at 02:15 after pumping 63 bbls of cmt, pump truck went down, appears to be an electrical problem (5hrs pump time on cmt). Worked pipe every 5 min's rot &recip & ck ok while Dowell swapped out pump trucks. Resumed pumping at 03:18 hrs, pumped an additional 242 bbls of cmt, pumped a total of 305 bbls (761 sxs) of DeepCrete cement at 12.5 ppg and 2.25 yield with additives, ave 5.75 bpm at 80 psi , cont to rotate and recip. pipe with fullreturns, shut down. Dropped DP wiper plug, Dowell pumped 10 bbls water and rig displaced cmt. With 9.0 ppg LSND mud, Initial rate 8 bpm at 400 psi, slowed pump rate to 3 bpm and saw LWP shear at 1,100 psi, cont to displace cmt at 8 bpm, final pressure at 8 bpm 690 psi, slowed to 3 bpm and landed liner wiper plug, cont to rot. &recip pipe till within 5 min of bumping plug, st wt up 200K, do wt 110K, with torque limiter set at 25K ft-Ibs had 10-15 rpms while working pipe, bumped plug on calc displacement, CIP at 05:10 hrs, Est TOC @ 6,305', had full returns during the job Pressured up on liner wiper plug to 2,500 psi and slacked off 40K and set Flex-Lock hanger, pressured up to 4,000 psi and released from HR running tool, bled pressure down to 750 psi and pulled out of "RS" packoff and pressure bled off, st up wt 140K, set TOL at 8,432' MD/2,265' TVD. Circ hole clean above TOL at 8,432', circ at 150 spm, 640 gpm at 1,180 Printed: 9/30/2005 6:19:05 AM ~1 U ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours I Code 'Code Phase 7/16/2005 1 05:30 - 07:45 2.25 CEMEN1 fCIRC INTRMI 07:45 - 08:00 0.25 CEMEN RURD INTRMI 08:00 - 11:00 3.00 CEMEN TRIP INTRM1 11:00 - 12:00 1.00 CEMEN PULD INTRM1 12:00 - 12:30 0.50 CASE OTHR INTRM1 12:30 - 13:30 1.00 CASE RURD INTRM1 13:30 - 13:45 0.25 CASE SFTY INTRMI 13:45 - 00:00 10.25 CASE RUNC INTRM1 7/17/2005 100:00 - 00:30 I 0.501 CASE I RUNC I INTRM1 00:30 - 01:30 I 1.001 CASE I RUNC I INTRM1 01:30 - 02:15 0.751 CASE RUNC INTRM1 02:15 - 03:15 1.00 CASE CIRC INTRM1 03:15 - 05:30 2.25 CASE CIRC INTRM1 05:30 - 06:00 0.50 CASE OTHR INTRM1 06:00 - 08:00 2.00 CASE OTHR INTRM1 08:00 - 09:30 I 1.501 CASE I OTHR I INTRMI 09:30 - 11:00 1.50 CASE OTHR INTRM1 11:00 - 12:30 1.50 WELCT NUND INTRM1 12:30 - 14:30 I 2.001 WELCTU NUND I INTRM1 14:30 - 15:30 1.00 WELCT NUND INTRM1 15:30 - 18:00 2.50 WELCT NUND INTRM1 18:00 - 19:00 1.00 DRILL PULD INTRM1 19:00 - 20:15 1.25 DRILL PULD INTRM1 20:15 - 21:00 0.75 WELCT OTHR INTRM1 21:00 - 00:00 3.00 WELCT BOPE INTRM1 7/18/2005 00:00 - 02:00 2.00 WELCT BOPE INTRMI Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Page 13 of 45 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations psi, at btms up saw a slight amount of CW 100 back at surface, monitored well static RD cement head/plug dropping head and lines POOH from 8,432' to liner running tool at 34' Made service breaks on liner running tool and LD same Pulled wear bushing RU GBR's 9 5/8" csg equipment Held PJSM on MU seal assembly, packer and RIH with 9 5/8" csg MU Baker 13 3/8 x 9 518" JMZXP packer with seal assembly and RIH slow with 9 5/8", 40#, L-80, BTCM csg to 4,650', RIH with 120 jts of 125 total to be ran, installed 1 straight blade aluminum centralizer on every 3rd jt st wt up 175K, do wt 118K Run 9-5/8", L-80, BTC-Mod, 40 ppf casing to liner top. 124 joints total, run one centrilizer every third joint 41 total. Up Wt 175k, Dn wt 118k. M/U XO sub f/ Top Drive & torque same. P/U joint 125 & M/U same to TopDrive. PJSM w/ Company Rep, Toolpusher & Rig Hands. Break Circ w/ mud, 3 bpm @ 70 psi, 4 bpm @ 80 psi. Slack off locate seals S/D pumps slack to 4840' (No-Go) Mark Casing. Circ Bottoms up w/ Mud @ 4 bpm 100 psi. Displace to H2O @ 4830', Pump 6 bpm w/ 100 psi. Monitor well for flow (static) R/U lines & Reverse Diesel into annulus. 2.5 bpm. 110 psi. Continue to freeze protect annulus w/diesel @ 2.5 bpm 270 bbls total FCP 320 psi. Slack off to insert seals & set JMZX packer. Set down all the available weight unable to get complete set, bleed off annular pressure to 200 psi & transfer more weight to packer. Press. up to test packer bleeding by. Increase pressures 700 psi & bleed off same. Packer set. Pressure up to 1000 psi / 15 minutes O psi loss. Bleed off pressure & open Hydril. P/U to 275k to check packer (up wt 175k) PJSM- Break circ swedge, f/ 9-5/8" casing & Top Drive. blow down all lines, Pump out casing for cut-off, drain stack. Nipple down flow liine, turnbuckles choke line, drip pan, split stack stack & raise same. P/U casing to 225k, center casing, set slips, cut-off 9-5/8" casing and clean up metal shavings. Install 13-3/8" X 9-5/8" pack-off seals. Set down BOPS. Test seals to 2200 psi / 15 min. OK. Nipple up BOPs, Clean out cement in flow line fl surface job. Change bottom rams to 6" X 3-1/2" VBRs. Check accumulator bottles. Break down TIW valve & XO f/ Top of joint. L/D 9-5/8"joint & cut off joint (9.90') P/U cmt head & break down same. Clear floor R/U for BOP test Test BOP's. Lou Grimauldi, AOGCC rep witnessed test. Test to 250 psi low, 3000 psi high. Test BOP's 250/ Low 5 min, 3000/ high 5 min, Chart test. AOGCC rep. Lou Grimauldi witnessed the test. Tested Hydril, HCR's, Upper rams, Choke manifold (valves 1-18), Floor safety valve, Dart valve, Manual choke & Kill line valves, Lower pipe rams, Blind rams, Upper IBOP, Lower IBOP. Perform Accumulator test, Starting pressure 3000, PSI Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 14 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To i Hours i Code Code Phase Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations 7/18/2005 00:00 - 02:00 2.00 WELCT BOPE INTRMI 02:00 - 02:30 0.50 DRILL RIRD INTRM1 02:30 - 04:30 2.00 DRILL TRIP INTRM1 04:30 - 05:30 1.00 RIGMNT RSRV INTRM1 05:30 - 06:00 0.50 DRILL PULD INTRM1 06:00 - 06:30 0.50 DRILL PULD INTRM1 06:30 - 14:00 7.50 DRILL TRIP INTRM1 14:00 - 15:00 1.00 RIGMNT RSRV INTRM1 15:00 - 18:00 3.00 RIGMNT OTHR INTRM1 18:00 - 20:00 2.00 RIGMNT OTHR INTRM1 20:00 - 23:00 3.00 DRILL PULD INTRM1 23:00 - 00:00 1.00 DRILL PULD INTRM1 7/19/2005 00:00 - 00:30 0.50 DRILL PULD INTRM1 00:30 - 01:45 1.25 DRILL PULD INTRM1 01:45 - 08:30 6.75 DRILL TRIP INTRM1 08:30 - 11:30 3.00 DRILL TRIP INTRM1 11:30 - 12:00 0.50 DRILL SFTY INTRM1 12:00 - 15:30 3.50 DRILL CIRC INTRM1 15:30 - 18:00 I 2.501 DRILL I DEOT I INTRM1 18:00 - 19:15 1.251 DRILL OTHR INTRM1 19:15 - 00:00 4.751 DRILL TRIP INTRM1 7/20/2005 00:00 - 01:30 1.50 DRILL PULD INTRMI 01:30 - 02:00 0.50 DRILL OTHR INTRMI 02:00 - 04:15 2.25 DRILL TRIP INTRM1 04:15 - 06:30 2.25 DRILL OTHR INTRM1 06:30 - 07:30 1.00 DRILL OTHR INTRM1 07:30 - 09:00 1.50 DRILL OTHR INTRM1 09:00 - 10:00 1.00 DRILL OTHR INTRM1 10:00 - 12:00 2.00 DRILL DEOT INTRM1 12:00 - 13:30 1.50 DRILL OTHR INTRM1 13:30 - 16:30 3.00 DRILL OTHR INTRM1 16:30 - 17:00 0.50 DRILL OTHR INTRM1 17:00 - 18:00 1.00 RIGMNT RSRV INTRMI after function 1450, 200 psi increase 38 seconds, Final pressure build 3 minutes 45 seconds. Nitrogen bottles average press, 2450 psi. Rig down Test Equipment & set wear ring. OD = 13-7/16", ID = 9", Length = 3.18' RIH w/ 50 Stds f/ Derrick. Cut & Slip Drilling Line 106' Bring Lo-Tads to floor. Bring Lo-Tads to floor. Caliper, strap & record serial numbers. POOH install Lo-Tads on stands. SLM stds in derrick. Service Top Drive. Shim Top Drive rails for motor alignment Continue to Shim Top Drive rails. P/U Geo-Pilot and MWD tools. Make up BHA Upload LWD tools, Shallow test Tools Load Nuculear Sources in MWD Picking up BHA, Breaking in new heavy Wt. Drill Pipe. Picking up new 5" Drill Pipe Make and Brake. Trip in Hole (out of Derrick). Tag CMT @ 10,306' PJSM; All Personal Involved in change out well to Oil Base Mud Displace well to 9ppg Oil Base Mud. Start Pumping @ 2 bpm, Rotate @ 5 rpm. Staging Up SPM + RPM to 70spm, 120 rpm's. Pumped; 50bbls Mineral oil,65bbls High Vis Spacer, Oil Base Mud 9ppg. Test 9 5/8" 40ppf Csg. Bit Depth 10,249' Pressure up to 3,000psi. Bleed off. Check Surface Equipment and pressure test surface equipment T/3,000psi.O.K. Pressure up Csg, To 500psi. Watching press on 13 3/8 x 9 5/8 annulas, 240psi. 9 5/8 csg bled down To 110psi.13 3!8 x 9 5/8 Annulas press to 260psi. Monitior Well, Build and pump Dry Job 2ppg over, Trip Out the hole for RTTS. Trip Out Hole T/ Bha, Calculated Fill 75bbls-Actual Fill 117bb1s. Working BHA Calc fill 7.7bbls -Actual 8.2bbls. PJSM; Remove Nukes, De-energize MWD, Lay Down Pressure sub. Clean Rig Floor, Load RTTS in Pipe shed. P/U RTTS Tool, Run in Hole to 5,059' Set RTTS Set RTTS Tool pump down 9 5/8 annulas. Test Tie Back, Press up to 800psi. injecting. Shut in Press bleed down to 280psi. in 6 minutes. Test down Drill Pipe testing 5,059' to 10,306' T/ 3,000psi. held for 15 min loss 70psi. Pull up to 4,812' test annulas 3,000 psi. no loss. Move 4,869' Pump down Drill Pipe Press 3,000psi. 10min no loss. Leak Isolated @ 4,812'-4,869' R/U Test 13 3/8 x 9 5!8 annulas to 1,000psi. 10 min no Loss. Pull up RTTS to 4,812' and perform infectivity test. @ 1bpm =1,081 psi. 1.5 bpm 1,370psi. 2 bpm 1,730 psi. Shutin Well bled down to 510psi. Unset RTTS, Blow down test line's. Monitior well, Clean pits #5, Pill pits #1 . Isolate leak Set RTTS, 4,853-4,863', 4,862',4,861',4,860',Leak @ 4,858'-4,860'. Mix 65 bbls Biozan Spacer, Mix 35 bbls Mineral Oil Pill, PJSM W/Crew and support Personal, Displace Well 35 bbls Mineral Oil Pill, 50 bbls Biozan Spacer, Water Spot 10 bbls Biozan pill @ 4,965 Service Top Drive, Grease Crown Printed: 9/30/2005 6:19:05 AM I~ J ConocoPhillips Alaska Page 15 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common W ell Name: 1 E-170 Spud Date: 6/26/2005 Event Nam e: ROT -D RILLING Start: 6/22/2005 End: 9/10!2005 Contractor Name: D15CM @conoco phillip s.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 1 5 Rig Number: 15 Date II From - To ~ Hours ~ Code '~ Sub C d I Phase I I Description of Operations ---- ' --_I - ! ---J o e --- 7/20/2005 18:00 - 21:00 3.00 WAITON EOIP INTRM1 Wait On Cementers, Rig Serv. Prepare for Cmt Job. 21:00 - 21:45 0.75 CEMEN SQEZ INTRMI R/U Cementers, Install TIW Head Pin space out.Set @ 4,812' RTTS @ 4,810' 21:45 - 22:15 0.50 CEMEN SQEZ INTRM1 Pump 5 bbls water, Press Test 3,000psi.Set RTTS Perform Injection test W/ Dowe11.1BPM-500psi. 1 1/2 BPM-950psi. 2 BPM-1,100psi. Shut in 1 min press 600psi. Pumped total of 21 bbls. Bled Back total 17.3 bbls. 22:15 - 23:45 1.50 CEMEN SQEZ INTRM1 PJSM; Pump 2 bbls water to insure RTTS unseated. Close Hydril Batch up CMT. Pump 20 bbls CMT. Hold holding 350psi. Back pressure @ 36PM. 150 psi. 55 bbls. Water @ 4BPM. 500psi. Slow to 2 bbls min. Set RTTS. Bleed press off 9 5/8x5" Annulas. Open Hydril. to insure RTTS set. 73bbls into displcement 150 psi. increase. 100 to 150psi. increase per bbl. Squeezed 18 bbls Cmt. into leak 2 bbls left in csg.13 318 x 9 5/8 annulas = 14bbls cap to shoe. RTTS to leak capacity 3.7 bbls. Capacity Drill pipe 86 bb1s, Pump total 89 bbls water final Press 2,408psi. Hold for 5 min press no losses. Bleed back volume 5 1i2 bbls. 23:45 - 00:00 0.25 CEMEN SQEZ INTRM1 Unseated RTTS Pull 10' Monitior no flow back. Line up To Reverse Circulate. 36 spm 360 psi. 3bbl of contamanated return's @ BTM up. 7/21/2005 00:00 - 01:15 1.25 DRILL CIRC INTRM1 Reverse Circulate. 36 spm 360 psi. 2x Btms Up. Approx. 3 bbls Contaimanated Water Back to surface. 01:15 - 04:45 3.50 DRILL TRIP INTRM1 Monitior well, POOH W/ RTTS. 04:45 - 06:45 2.00 DRILL PULD INTRM1 P/U Rotary Steerable BHA, P/U Pulsar sub, Plug into Mwd tools Upload. Shollow Test tools. 06:45 - 07:15 0.50 CASE MIT INTRMI R/U to test casing. Press up to 300psi. Call from town shut down test. Bleed off 07:15 - 10:30 3.25 DRILL TRIP INTRM1 Trip in hole Rotary steerable and W/ MWD pulse test Load sources. Trip in to 4,957' Up Wt. 120k, Dn Wt. 95k. Rt Wt. 120k. Trq 8k. 640gpm. 500 psi. 10:30 - 12:00 1.50 CASE CIRC INTRM1 Circulate 640 gpm 500 psi. Btm Up. 12:00 - 14:00 2.00 CASE DEOT INTRM1 Rig Up & Test Csg. Would not test.bled back to 300 psi Bleed off pressure 6 bbls. retuns. R/D test equipment, Monitior well. 14:00 - 18:30 4.50 DRILL TRIP INTRM1 Pull out hole, PJSM remove Nukes, Download MWD, L/D pulsar Sub. 18:30 - 19:30 1.00 DRILL OTHR INTRM1 P/U RTTS Change out element. 19:30 - 22:00 2.50 DRILL TRIP INTRM1 Trip in Hole, T/ 5,235' took weight 4,000#. 22:00 - 22:15 0.25 DRILL TRIP INTRM1 Pull out hole T/ 4,960' 22:15 - 22:45 0.50 DRILL CIRC INTRMI Spot 12 bbls Bio-zan pill, 38spm 159gpm 130psi. 22:45 - 00:00 1.25 CASE MIT INTRM1 Pull Out Hole T/ 4,866' Set RTTS test Failed, Move down to 4,869' set RTTS test failed. Pull 4,813' test Bacck side T/2,000psi. Test O.K. Move to 4,894' Tested O.K. Pulled up to 4,884 test failed. Pull up T/ 4,854' test annulas test O.K. Good Test, From 4,854' to Surface all tested Good. From 4,894' to 10,306' tested good. 7/22/2005 00:00 - 01:15 1.25 CASE OTHR INTRM1 Pull up Hole T/ 4,780' R/U for squeeze talk to Engineer trouble shoot leak. 01:15 - 01:30 0.25 CASE OTHR INTRM1 R/D Cmt equipment 01:30 - 01:45 0.25 DRILL TRIP INTRM1 Trip in Hole. T/ 4,970' 01:45 - 02:15 0.50 CASE MIT INTRMI R/U to Test 13 3/8x9 5/8 500 psi. Held F/ 10 min. no loss, Pull up to Re-Test and isolate leak. 02:15 - 05:30 3.25 CASE MIT INTRM1 Pull up to 4,895 Re-Test and isolate leak. No test trouble setting RTTS. Move down to 4,957' Test down Drill pipe. Tested T/ 1,500psi. @ 5'-10' Increaments T/ 4,862' all good test. 4,857' Did not test. Tested down 9 5/8"x5" Ann. Tested T/ 1,800psi. Tested Good. Isolating Leak @ 4,857'-4,862'. 05:30 - 06:30 1.00 CASE OTHR INTRM1 Monitior well R/D Testing Equipment. Blow down lines. Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 16 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common W ell Name: 1 E-170 Spud Date: 6/26/2005 Event Nam e: ROT -D RILLING Start: 6122!2005 End: 9/10/2005 Contractor Name: D15CM @conocophillip s.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 1 5 Rig Number: 15 Date ~ From - To ~~ Hours ~~ Code !~ Code, Phase ~ Description of Operations 7/22/2005 06:30 - 08:00 1.50 CASE PTCH INTRM1 P.O.O.H; Position RTTS Packer @ 4,589' R!U To Squeeze CMT. 08:00 - 11:45 3.75 CEMEN SOEZ INTRMI PJSM: Unseat packer Circulate 5 bbls water, Test lines T/ 3,000psi. Seat RTTS. Establish Injection rate 2 bpm @ 950 psi. after shut down for 1min 550 psi 2min 490 psi.Bled back 6 112 bbls Total pumped 14bbls, Release packer pump 2 bpm verify circulation, Close Hydril Circulate through Choke, Batch up CMT @ 09:30. Pump 20 bbls 15.81b per gal.yield 1.17 mix fluid 5.207per/sx Porisity 59.4°!° solid frac. 40.6%. CMT. 3 bbls per min. 150 psi. 400psi. back press. Displace W/ Water 56 bbls water displaced Slow T/ 1 BPM seat RTTS bleed off annulas Open Hydril to verify no communacation past RTTS. Pump 82 bbls CMT T/ Leak @ 4,862' Press 1,111 psi. @ 1 BPM. Squeeze 10 bbls stop press. 1,240psi. Press drop 1,029' after 5 min. Start pumping 16PM squeeze 5 bbls Press 1,794psi. Stop hold 15 min. press drop T! 1,258psi. Pump @ 112 BPM. Squeeze 1 bbl stop press. 1,551 psi. CIP @ 11:05. Hold F/ 30 min. press drop 905 psi. Bleed back volume 4 3/4 bbls. 11:45 - 13:30 1.75 CEMEN CIRC INTRM1 Unseat RTTS Reverse Circulate 4 bpm 530 psi. No Cmt returns no losses or gains. High PH in retums. Circulate 3 Drill pipe Volume's Ph dropped. 13:30 - 17:30 4.00 CEMEN CIRC INTRM1 Circulate down Drill pipe @ 3 BPM 60 psi. 17;30 - 18:00 0.50 CEMEN RURD INTRM1 RID CMT Equipment Blow Down. 18:00 - 19:00 9.00 WAITON CMT INTRM1 Monitior Well, W.O.C. 19:00 - 22:00 3.00 CEMEN TRIP INTRM1 P.O.O.H. Lay down RTTS small piece of rubber stuck above element. Not Part of element. 22:00 - 23:00 1.00 CEMEN TRIP INTRM1 P/U Clean out BHA. 23:00 - 00:00 1.00 CEMEN TRIP INTRM1 Trip in hole with BHA # 7. Drill pipe has cement remnants rattle pipe going in hole.4,576'. 7/23/2005 00:00 - 01:15 1.25 DRILL TRIP INTRM1 Trip in hole with BHA # 7. Slow Looking for Cmt Stringers T/ 5,046' No Cement. 01:15 - 03:00 1.75 DRILL CIRC INTRM1 PJSM; Displace Top of Hole back to Oil Base Mud, Pump 40 bbl high vis Spacer, 70 bbl Base Oil Pill, Chase With OBM. Rotate and Reciprocate pipe. 03:00 - 05:15 2.25 DRILL REAM INTRM1 TIH took weight @ 5,054', Wash and Ream CMT stringers F/ 5,054 - 5,718' Started to clean up @ 5,430' - 5,718' 05:15 - 06:00 0.75 DRILL CIRC INTRM1 Circulate and clean hole for Casing Test. 06:00 - 07:00 1.00 CASE OTHR INTRM1 R/U Test Equipment, 07:00 - 09:00 2.00 CASE MIT INTRM1 Test 9 5/8" CSC, Pressure up T/ 500psi. Bleed off pressure test surface lines T/ 2,000psi., Pressure CSC. TI 1,000psi. Shut in F/ 30 min 695psi. Final Pressure, Bleed Back 6.8 bbls. 09:00 - 10:30 1.50 CASE PTCH INTRM1 Pull out of hole. T/ 4,850' 10:30 - 12:00 1.50 CASE PTCH INTRM1 Mix 67 bbl Calcium pill, 10 ppg, 280 Viscosity 12:00 - 14:00 2.00 CASE PTCH INTRM1 Pump 50 bbls of Pill, Close Hydril ,Squeeze @ 112 - I bbls per min., Final pump press. 1100-850psi. Bleed off pressure, Check Flow, Open Hydril 14:00 - 15:30 1.50 CASE CIRC 1NTRM1 Circulate B/U, Monitor well, Pump dry job, Blow down Top Drive. 15:30 - 18:00 2.50 DRILL TRIP INTRM1 Pull out of hole for BHA # 8 18:00 - 20:00 2.00 DRILL TRIP INTRM1 Pick Up BHA # 8 load MWD tools and PJSM on Nukes. Load Nukes. 20:00 - 21:00 1.00 DRILL TRIP INTRMI Trip in Hole, Rattle Drill Pipe while tripping in hole, cement in pipe. 21:00 - 22:15 1.25 DRILL TRIP INTRM1 Pull out Hole, To pulsar check for Cmt, Pieces. Clean Out Cement From Float Sub and Pulsar. 22:15 - 23:00 0.75 DRILL TRIP INTRM1 Trip in Hole 20 stands inspect Drill Pipe see no More Cmt in Pipe. @ 2099' 23:00 - 00:00 1.00 DRILL TRIP INTRM1 Pull Out Hole Laying Down pipe with Cement Stringers in pipe. Wet Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 17 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Sub I Phase Code 7/23/2005 23:00 - 00:00 1.00 DRILL TRIP INTRM1 7/24/2005 00:00 - 03:45 3.75 DRILL PULD INTRM1 03:45 - 04:30 0.75 DRILL OTHR INTRM1 04:30 - 12:00 7.50 DRILL TRIP INTRM1 12:00 - 12:45 0.751 DRILL CIRC INTRM1 12:45 - 14:00 1.25 DRILL TRIP INTRM1 14:00 - 17:30 3.50 CEMEN DSHO INTRM1 17:30 - 18:00 0.50 CASE MIT INTRM1 18:00 - 19:00 1.00 CEMEN DSHO INTRM1 19:00 - 21:00 2.00 DRILL CIRC INTRM1 21:00 - 22:30 I 1.501 DRILL I LOT I INTRM1 22:30 - 00:00 1.501 DRILL DRLH PROD 7/25/2005 00:00 - 01:15 1.251 DRILL DRLH PROD 01:15 - 02:15 I 1.001 DRILL I TRIP I PROD 02:15 - 03:45 1.50 DRILL OTHR PROD 03:45 - 05:00 1.25 DRILL CIRC PROD 05:00 - 05:30 0.50 DRILL TRIP PROD 05:30 - 10:30 5.00 DRILL DRLH PROD 10:30 - 13:00 I 2.50) DRILL i CIRC PROD 13:00 - 13:45 0.75 DRILL TRIP PROD 13:45 - 14:15 0.50 DRILL OTHR PROD 14:15 - 18:00 3.75 DRILL TRIP PROD 18:00 - 22:00 4.00 DRILL TRIP PROD 22:00 - 22:30 0.50 DRILL PULD PROD 22:30 - 00:00 1.50 DRILL TRIP PROD 7/26/2005 00:00 - 00:30 0.50 CEMEN OTHR PROD 00:30 - 05:00 4.50 CEMEN TRIP PROD 05:00 - 05:30 0.50 CEMEN CIRC PROD 05:30 - 05:45 0.25 CEMEN PLUG PROD 05:45 - 06:45 1.00 CEMEN TRIP PROD 06:45 - 07:15 0.50 CEMEN CIRC PROD 07:15 - 07:30 0.25 CEMEN SFTY PROD 07:30 - 09:15 1.75 CEMEN PLUG PROD 09:15 - 10:30 I 1.251 CEMENl~TRIP I PROD Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Pipe, Suck Out with Vac. Plug W/Absorbant. 20 Jts down. Pull Out Hole Laying Down pipe with Cement Stringers in pipe. Wet Pipe Suck with Vac. Plug W/Absorbant. Clean Rig Floor and Derrick leg. Trip in Hole With BHA #8 Pick up New 5" Drill Pipe Make and Brake and Make all new jts. Trip in Hole Tl8,168' Circulate Bottoms Up @ 8,168' 633 GPM, 3,120psi. 40 RPM 8-9k nTorq. Rt Wt-120k, Up Wt-165k, Dn Wt-110k Trip in Hole T/ 10,302' Drill Landing Collar @ 10,302'. Float Collar @ 10,343',. CMT T/ 10,410' Circulate and Perform Press Test T/ 525psi. Drill Out Shoe @ 10,417', Drill To 10,450' 30' New Hole. Pull Back T/ Shoe.Circulate and Condition For Leak Off Test, MWD base line test ECD. R/U Perform Leak Off Test EMW 12.1 @3,437' TVD 3437' 9 ppg.10 min gels 34, Pumped 10.1 bbls, Bleed Back 9 bbls. Drilling f/ 10,450' -T/ 10,602'.TVD 3,489' 600 gpm. W/3,720 psi. 120 rpm, Torque on bttm 10-15 k ft/Ibs, off bottom 12k ft/Ibs, Up wt 200k, Dn wt 95k, Rot wt 134k. ADT .55 hrs. Drilling f/ 10,602' -T/ 10,757'.TVD 3,518' 500 gpm. W/2200 psi. 100 rpm, Torque on bttm 10-20 k ftllbs, off bottom 12k fUlbs, Up wt 200k, Dn wt 95k, Rot wt 134k. ADT .89 hrs. Pump Out Hole T/ 10,329' Circulate Bottoms Up. Directional difficutly's not able to build. dropped out of A sands. Monitior Well, Clean Rig. Call 1E-170 engineer. Circulate and Condition Waite On Decision From Town Trip In Hole T/ 10,757' Drilling f/ 10,757' -T/ 11,230'.TVD 3,550' 420 gpm. W/2,270 psi. 60-70 rpm, Torque on bttm 10-15 k ft/Ibs, off bottom 12k ft/Ibs, Up wt 230k, Dn wt 95k, Rot wt 140k. ADT 3.29 hrs. Circulate and Condition, 600 GPM 3,660psi. Was Building incl, 3.5 to 4 last 100' lost ability to build. Monitior Well: Pull Out Of Hole above Shoe @ 10,371' Monitior Well; Pump Dry Job. Trip Out Hole; To 5" Hwt DP monitior well. Stand Back HWT Drill Pipe/Jars, PJSM On handling Sources, Clear Floor, Remove Source. Down Load MWD L/D BHA. Change Out Elevators and R/U Tbg. Tongs to Run 2 7/8 tbg. stinger. Trip in Hole P/U 2 7/8" Rabbit 1-Mule Shoe jt. and 31Jts. Move Flex Collars and 5" HWT DP. to drillers side to run 5" Drill Pipe. M/U XO and Trip in Hole W/5" Drill Pipe, From derrick to 10,385' Break circulation @ 10,385' 3pm 480 psi. Trip in Hole; T/ 11,206' Break circulation @ 10,385' 6pm 980 psi. Up Wt - 195k, DN WT.-100k, R/U To Cement. PJSM; Pump Cement Balanced Plug. Pumped 15 bbls biozan Pill, 3 bbls water test cement lines to 3,000psi. 70 bbls 17 ppg yield 1 mix Fluid 3.867 gal/sx Cement porosity 51.5%, solid fraction 48.5% Slurry type Conventional. Hold Back press on Annulas not exceed LOT. 3 bbls water 2 bbls biozan. Displaced W/ 9 ppg. OBM. 172 bbls. L/D top Single with head pin P.O.O.H. Slowly Approximately 3 min stand, pipe 2/3 dry. T/ 10,187, Printed: 9/30/2005 6:19:05 AM r~ ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours ! Code .Code Phase __ ~__ _ -- 7/26/2005 110:30 - 12:45 12:45 - 14:30 2.251 CEMENl~CIRC PROD 1.751CEMENliCIRC (PROD 14:30 - 14:45 0.25 CEMEN OTHR PROD 14:45 - 18:00 3.25 CEMEN TRIP PROD 18:00 - 19:00 1.00 CEMEN RURD PROD 19:00 - 21:15 2.25 CEMEN PULD PROD 21:15 - 22:15 1.00 CEMEN RURD PROD 22:15 - 23:30 1.25 WELCT BOPE PROD 23:30 - 00:00 0.50 WELCT BOPE PROD 7/27/2005 00:00 - 03:45 3.75 WELCT ROPE PROD 03:45 - 04:45 1.00 WELCT NUND PROD 04:45 - 08:30 3.75 DRILL PULD PROD 08:30 - 13:30 5.00 DRILL TRIP PROD 13:30 - 14:45 1.25 RIGMNT RSRV PROD 14:45 - 15:45 1.00 RIGMNT RSRV PROD 15:45 - 16:15 0.50 DRILL TRIP PROD 16:15 - 18:00 1.75 DRILL OTHR PROD 18:00 - 00:00 6.00 DRILL DRLH PROD 7/28/2005 00:00 - 06:00 06:00 - 12:00 12:00 - 18:00 6.001 DRILL I DRLH I PROD 6.001 DRILL I DRLH I PROD 6.001 DRILL I DRLH I PROD Page 18 of 45 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations M/U Top Drive 10,187' pumped 5bbls to clear pipe, P/U joint W/ Head Pin run in T/ 10,215 R/U cement Hose to Reverse Circulate Btms up. Taking returns to one tank monitor losses, No Losses @ 3BPM-630 psi. Dump 20 bbls Spacer pill Contaminated OBM. Approximant Cement Top @ 10,245'. Circulated Total. 238bb1s. Rig Down Cement Hose and Head pin, Make Up Top Drive Circulate Down drill Pipe 7 BPM - 1,030psi. 10 RPM Pumped BTMS UP @ 545 bbls. Monitor well pump slug. Trip out hole T/ 1,013' 2 7/8 tbg. R/U Csg. Tongs, To lay Down 2 7/8 tbg.(Crew Change) Lay Down 2 7/8 Tbg. Stinger. R/D Tbg. Equipment and Clean Rig Floor. Rig Up Test Equipment To test BOPE, Test BOPE 250 low, 3,000High. Test BOP's 250/ Low 5 min, 3000/ high 5 min, Chart test. AOGCC rep. Chuck Scheve waived wittness of test. Tested Hydril, HCR's, Upper rams, Choke manifold (valves 1-18), Floor safety valve, Dart valve, Manual choke & Kill line valves, Lower pipe rams, Blind rams, Upper IBOP, Lower IBOP. Perform Accumulator test, Starting pressure 3000, PSI after function 1700, 200 psi increase 39 seconds, Final pressure build 2 minutes 58 seconds. Nitrogen bottles average press, 2450 psi. Pull Test Plug, Set Wear ring. P/U BHA; Motor W/1.5 deg bend, MWD, Up load Tools, PJSM handle Source, Shallow Test MW D tools Rate 445 gpm-800psi. Load Source. TIH W/ BHA. Trip in hole: Filling Pipe every 25 stands, SLM in Hole. Strap difernce 2'. Cut Drill Line, 154', Inspect Brake linkage and re-seal chain cover Rig Service Trip in hole: Tag Cement @ 10,216' Drill Cement; From 10,216' - 10,420' Rot Wt 130k Dill Ahead: Side Track From 10,420' to 10,544' Tie in Survey's @ 10,463' 78.24 incl. 180.75 Azm. @ 10,512' 78.64 incl. 181.27 Azm. New Survey @ 10,481' 82.06 incl 179.12 Azm. ** Up Wt. 210,Dn Wt. 85, Rot Wt. 135, Tq on Btm 18-20, Tq Off Btm 15, W.O.B. 10-20. Art-.41 hrs, Ast-3.41 hrs.Jar Hrs- 9.85. Bit Hrs-4.52. Drill Ahead: From 10,544'to 10,917' M. D. 3,498' TVD. Up Wt. 225,Dn Wt. 90, Rot Wt. 140,RPM 80, GPM 590, Press On BTM 3,200, Off BTM 3,100psi. Tq on Btm 18-20, Tq Off Btm 15, W.O.B. 10-20.Art-.68hrs, Ast-2.47hrs.Jar Hrs- 12.95. Bit Hrs-7.62. APIG=41.41, Total ft Drilled 497', Average ROP 65' per hr. Drill Ahead: From 10,917'to 11,282' M.D. 3,469' TVD. Up Wt. 230,Dn Wt. 85, Rot Wt. 140,RPM 90, GPM 600, Press On BTM 3,540, Off BTM 3,450psi. Tq on Btm 18-22, Tq Off Btm 17, W.O.B. 5-15. Art-.2.88hrs, Ast-1.49hrs.Jar Hrs- 15.58. Bit Hrs-10.25. APIG=47' per hr. Total ft drilled 862' Average ROP 84 ft per hr., Began Running 5" Hwt Drill Pipe @ 10,943' for push pipe. Pumped Weighted Sweep @ 11,173' 11 ppg. 117vis. Approximately 20% increase in cutting sweep to surface. Drill Ahead: From 11,282' to 11,700' M.D. 3,469' TVD. Up Wt. 245,Dn Wt. 85, Rot Wt. 150, RPM 90, GPM 600, Press On BTM 3,580, Off BTM 3,430 psi. Tq on Btm 18-22, Tq Off Btm 18, W.O.B. 5-15. Art- 1.36hrs, Ast-1.35hrs. Jar Hrs- 18.29. Bit Hrs-12.96. APIG=53' per hr. Total ft drilled 1280' Average ROP 98.7 ft per hr., Continue Running 5" Printed: 9/30/2005 6:19:05 AM ConocoPhillips Alaska Page 19 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To I~, Hours Code Phase Code 7/28/2005 12:00 - 18:00 6.00 DRILL DRLH PROD 18:00 - 21:00 3.00 DRILL DRLH PROD 21:00 - 00:00 3.00 RIGMNT RGRP PROD 7/29/2005 ~ 00:00 - 02:45 2.751 DRILL TRIP PROD 02:45 - 03:15 0.50 DRILL OTHR PROD 03:15 - 08:00 4.75 DRILL TRIP PROD 08:00 - 12:00 4.00 DRILL PULD PROD 12:00 - 13:30 1.50 RIGMNT RSRV PROD 13:30 - 15:30 2.00 LOG TRIP PROD 15:30 - 17:45 2.25 LOG TRIP PROD 17:45 - 18:00 0.25 LOG TRIP PROD 18:00 - 19:00 1.00 LOG TRIP PROD 19:00 - 19:15 0.25 LOG TRIP PROD 19:15 - 20:00 0.75 LOG TRIP PROD 20:00 - 21:15 1.25 LOG CIRC PROD 21:15 - 00:00 2.75 RIGMNT RSRV PROD 7/30/2005 00:00 - 00:30 0.50 RIGMNT RSRV PROD 00:30 - 03:45 3.25 DRILL TRIP PROD 03:45 - 04:15 0.50 DRILL OTHR PROD 04:15 - 05:30 1.25 DRILL OTHR PROD 05:30 - 06:00 0.50 DRILL OTHR PROD 06:00 - 07:15 1.25 LOG RURD PROD 07:15 - 07:30 0.25 LOG SFTY PROD 07:30 - 08:45 1.25 LOG RURD PROD 08:45 - 09:15 0.50 LOG PULD PROD 09:15 - 09:45 0.50 LOG ELOG PROD 09:45 - 13:00 3.25 LOG ELOG PROD 13:00 - 13:15 0.25 LOG ELOG PROD 13:15 - 14:30 1.25 LOG ELOG PROD 14:30 - 16:15 I 1.751 LOG I ELOG I PROD 16:15 - 17:00 I 0.751 LOG I ELOG I PROD 17:00 - 19:00 I 2.001 LOG I ELOG I PROD Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Hwt Drill Pipe for push pipe. Changed Over to rig power @ 13:15hrs. Drill Ahead: From 11,700' to 11,887' M. D. 3,481' TVD. Up Wt. 255,Dn Wt.100, Rot Wt. 160, RPM 90, GPM 600, Press On BTM 3,610, Off BTM 3,450 psi. Tq on Btm 18-20, Tq Off Btm 18, W.O.B. 5-15. Art- .63hrs, Ast-.90hrs. Jar Hrs- 19.82. Bit Hrs-14.49. APIG=54' per hr. Total ft drilled 1467' Average ROP 101ft per hr, Continue Running 5" Hwt Drill Pipe for push pipe. Top Drive Down: Can Pump and Break and Make Up Drill Pipe, Cannot Rotate in Drilling Mode. Pump and Work pipe out of hole slowly T /11,589' while Trouble shooting Top Drive, GPM 425, 2,000psi. Talk with Geologist, Strata Steer, Directional Driller, Project Engineer and Project Geologist on Directional Plan Pump Out Hole From 11,589' - 10,351'. @ 400 gpm, 2000psi. Up Wt. 240k, Dn Wt 100k, Monitior Well, 15min. Pump Dry Job. Trip Out Hole. 10,351' to 287'. Top Drive Still Down Waiting on Part. Work BHA: PJSM on pulling Sources, Remove and Store I Density(gamma) and Neutron Sources. Plug in and Down Load LWD Tools. Lay Down BHA. Rig Service Pick Up, BHA #10 - 8 1/2 Bit / 9 5/8 Scrapper /Junk Basket, Run Collars and all Hwt Drill Pipe. Trip in Hole to 5,877' Up Wt. 150k, Dn Wt. 85k. Monitior Well Trip Out Hole From 5,877 to 4,737' Monitior Well, Clean Floor Trip in Hole; To 5,837' W/Scrapper Circulate 2x Btms Up @ 650 GPM, 2,000 psi. PJSM: Change Out Drill Line, Change Out To new drill Line Spool. Finish Changing Out Drill Line New Spool, Trip Out Hole: With 9 5/8" Scrapper, Lay Down Bit and Scrapper Retrieved pieces of Alunimuim and Cmt Chunks out of Junk Baskets. Clean and Clear Rig Floor, P/U Geo Pilot and LWD Tools. hook up tool and check connections, Stand back in Derrick Hook up Geo Skid connections and safety chains While spotting Schlumberger unit and picking up tools, cont. cleaning OBM from under rotary table Held PJSM with Schlumberger, Rig crews, and Co. Rep. Rig up wire sheaves, M/U USIT, Gamma Ray and collar locator assembly M/U Tractor assembly on top, Total Length. = 64.3' RIH with wire Line, Able to free fall to 2175' with wire line Active Tractor assembly to get wire line down F/2175'- T/3,483'. Taking Wieght made 4 attemps. No Go, POOH to 2600' Attempted to Tractor back into hole, second attempt made it to 3,121' set down. Taking weight P.O.O.H L/D Tractor assembly Approx. 4 oz fine metal shavings found on collar locator. Change oil in the tractor. From 10wt. to 16 wt. P/U tractor assembly and RIH T/2400' Good 2,974' set down hard. 6 times, Able to run tractor and wire line down F/2,974 ' T/3,430' (Test Top Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 20 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common W ell Name: 1 E-170 Spud Date: 6/26/2005 Event Nam e: ROT -D RILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM @conoco phillip s.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 1 5 Rig Number: 15 Date From - To Hours Code Phase Description of Operations Code 7/30/2005 17:00 - 19:00 2.00 LOG ELOG PROD Drive) All Working. 19:00 - 20:00 1.00 LOG ELOG PROD P.O.O.H 20:00 - 20:30 0.50 LOG PULD PROD Break Down Tools and Rig Down Wireline. 20:30 - 20:45 0.25 DRILL PULD PROD Pick Up BHA Stood Back in Derrick and M/U bit. Run in hole. 20:45 - 23:00 2.25 DRILL PULD PROD P/U Load Pulsar in TM H.O.C, Make Up to BHA, Up Load LWD Tools, and Shallow Test Tools. PJSM Load Nuetron and Gamma Sources. Test Geo Surface Equipment T/3,500psi. 23:00 - 23:30 0.50 DRILL TRIP PROD Trip Hole Jars and 8 Jts 5"Hwt Drill Pipe, 23:30 - 00:00 0.50 DRILL TRIP PROD Trip in Hole; 31jts 5" Drill Pipe 8 1/2" ghost Reamer. Continue to Trip in Hole W/5" Drill Pipe 7/31/2005 00:00 - 00:45 0.75 DRILL TRIP PROD Trip in Hole: To 3,055' 00:45 - 02:00 1.25 DRILL CIRC PROD Fill Pipe: Test Top Drive, Went to Fault, Reset Worked Good 130 RPM backed down Torq ,Until Stopped, Start Back up and function all Controls, Test MWD No Pulse, Cycle Pumps Still Failed. 02:00 - 04:00 2.00 DRILL TRIP PROD Trip Out Hole for Directional Assembly Failure. Break Off Top of Pulsar was Clean, 04:00 - 05:00 1.00 DRILL PULD PROD PJSM; Remove Nuetron and Gamma Sources, Plug into to tools to trouble shoot Tools Check Out OK, Break Top Of T.M. Collar pull Pulsar Looks Clean, Change Out Pulsar. 05:00 - 06:30 1.50 DRILL OTHR PROD Plug into LWD Tools and Upload Tools. Pick Up BHA. 06:30 - 07:30 1.00 DRILL TRIP PROD Trip in Hole, To 2,900' fill pipe, Test MWD, 417 GPM, 1,010' MD. 07:30 - 11:15 3.75 DRILL TRIP PROD Trip in Hole; To 10,160' fill pipe every 25 stands, Monitiorwell before going in open hole, Up Wt. 200k,Dn Wt. 88k. 11:15 - 12:45 1.50 DRILL TRIP PROD Trip in Hole; To 11,300' Establish Circulation at 450 GPM 2430 psi., Up Wt. 210k, Dn Wt. 85k, Rot Wt.130k. Record SPR. 12:45 - 14:30 1.75 DRILL OTHR PROD Start Troughing F/ 11,300' MD To 11,342' Up wt, 21 k, Dn Wt. 85k, Rot Wt. 130k, 450 GPM, 2,460' psi. 14:30 - 18:00 3.50 DRILL DRLH PROD Start side track; F/ 11,342'MD, 3,489' TVD, Drill T/ 11,619' MD. 3,469' TVD, ART-2.44hrs. Bit Hrs.- 2.44hrs., Jar Hrs. 22.26hrs., GPM 525 - 2,680ppsi. On Btm. - 2,660 Off Btm, 17k Torq on Btm, 15k Off Btm. 120 RPM. 10-20 WOB, 230k Up Wt., 80k Dn Wt., 130k Rot Wt.11.0 ECD. 18:00 - 22:30 4.50 DRILL DRLH PROD Drill Ahead; F/ 11,619'MD, 3,469' TVD, Drill T/ 11,887' MD. 3,464' TVD, GPM 550-600 - 2970psi.-3,520psi. On Btm. - 2,800psi.-3,460psi. Off Btm, Torq. Off Btm, 17k, Torq on Btm, 20k. 120 RPM. 10-20 WOB, 230k Up Wt.,90k Dn Wt., 140k Rot Wt.11.4 ECD. 22:30 - 00:00 1.50 DRILL DRLH PROD Drill Ahead; F/ 11,887'MD, 3,464' TVD, Drill T/ 12,036' MD. 3,464' TVD, ART-4.06 Bit Hrs.- 6.5hrs., Jar Hrs. 2ti.3hrs., GPM 550-600 - 2970psi.-3,520psi. On Btm. - 2,800psi.-3,460psi. Off Btm, Torq. Off Btm, 17k, Torq on Btm, 20k. 120 RPM. 10-20 WOB, 230k Up Wt.,90k Dn Wt., 140k Rot Wt.11.4 ECD. Note: Drilled Out of Sands Formation ramp up or fracture, True vertical throw Estamate 17' Out at 11,915'MD. 3,465' TVD, Back in Sands 12,268'MD, 3,448' TVD. 353ft sands lost. 8/1/2005 00:00 - 06:00 6.00 DRILL DRLH PROD Drill Ahead; F/ 12,036'MD, 3,464' TVD, Drill T/ .12,487' MD. 3,440' TVD, ART----- Bit Hrs.-10.77hrs., Jar Hrs.26.32hrs., GPM 550-600 - 2970psi.-3,520psi. On Btm. - 2,800psi.-3,460psi. Off Btm, Torq. Off Btm, 17k, Torq on Btm, 20k. 120 RPM. 10-20 WOB, 230k Up Wt.,90k Dn Wt., 140k Rot Wt.11.4 ECD. 12,295' Pumped Sweep 11.ppg, 107 Vis. 40% increase at Shakers of Cuttings. ECD F/11.8, T/ 11.4ppg. Concreations 12,459-12461' (2'), Note: Drilled Out of Sands Formation ramp up or fracture, True Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Code Phase 8/1/2005 100:00 - 06:00 6.00 DRILL DRLH PROD 06:00 - 12:00 12:00 - 18:00 18:00 - 00:00 8/2/2005 00:00 - 07:00 6.00 DRILL DRLH PROD 6.001 DRILL I DRLH I PROD 6.001 DRILL I DRLH I PROD 7.001 DRILL I DRLH I PROD Page 21 of 45 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations vertical throw Estamate 17' Out at 11,915'MD. 3,465' TVD, Back in Sands 12,268'MD, 3,448' TVD. 353ft sands lost. Drill Ahead; F/ 12,487'MD. 3,440'TVD. T/ 12,713'MD. 3,436'TVD. ART-5.07hrs. Bit Hrs-15.84hrs. GPM-600, W/ 3,420psi. On Btm.-3,400.Off BTM. 120RPM.-18-23 Tq.On Btm.-17-20. Up Wt.-240k,Dn Wt.-70,Rot Wt.-135k. ECD 11.3 ppg. Concreations 12,543'-12,552'(9'), 12,568'-12,580'(12'), 12,624'-12,630'(6'), 12, 646'-12, 650' (4'), Drill Ahead; F/ 12,713'MD. 3,436'TVD. T/ 12,847'MD. 3,433'TVD. ART-4.96hrs. Bit Hrs-20.80hrs. GPM-600, W/ 3,420psi. On Btm.-3,400.Off BTM. 120RPM.-18-23 Tq.On Btm.-17-20. Up Wt.-240k,Dn Wt.-70,Rot Wt.-135k. ECD 11.4 ppg. Concreations 12,670'-12,680'(10'), 12,700'-12,708'(8'), 12,712'-12,718'(6'), 12,743'-12,752'(9'), 12,775'-12,800'(25'), 12,836-12,844'(8'), Drill Ahead; F/ 12,847'MD. 3,433'TVD. T/ 13,284'MD. 3,429'TVD. ART-4.15hrs. Bit Hrs-24.95hrs. GPM-600, W/ 3,500psi. On Btm.-3,480.Off BTM. 120RPM.-19 Tq.On Btm.-20. Up Wt.-240k,Dn Wt.(less then block Wt of 70k),Rot Wt.-130k. ECD 11.6 ppg. APIG- 58ft per hr. 33.5hrs, Footage Drilled 1,942' Average ROP 77' per Hr. Concreations 12,954'-12,985'(9'). Drill Ahead; F/ 13,284'MD. 3,429'TVD. T/ 13,879'MD. 3,408'TVD. ART-4.20hrs. Bit Hrs-28.75hrs. GPM-600, W/ 3,760psi. On Btm.-3,670.Off BTM. 120RPM.-19 Tq.On Btm.-20. Up Wt.-255k,Dn Wt.(less then block Wt of 70k),Rot Wt.-132k. ECD 12.2 ppg. APIG- 62.64ft per hr. 40.5hrs, Footage Drilled 2,537' Average ROP 88' per Hr. 07:00 - 11:30 4.50 DRILL REAM PROD Back Ream Out Of Hole: From 13,879' To 12,150', 20-25ft per min. 120RPM, 575GPM, 3,320psi. 18-20T0, 11:30 - 13:00 1.50 DRILL REAM PROD Back Ream Out Of Hole: From 12,150' To 11,727',Slow Pull Rates To 10-15ft per min. 120RPM, 575GPM, 3,200psi. 18T0, The last 300' Pumped 1200 bbls 2x BTM Up, 13:00 - 14:00 1.00 DRILL TRIP PROD Trip Out Of Hole: Attempt to Pull pipe with out back reaming, 11,727'-11,536' Hole not taking correct fill Up Wt 220-235, Pumped out To 11,156'. 500GPM. 2,250 psi. 200k Up Wt. Ghost Reamer 9,690'. 14:00 - 14:45 0.75 DRILL TRIP PROD Trip in Hole: From 11,156' - 11,628' Up Wt,220, Dn Wt. 85k. Lost Dn Wt. 11,628' 14:45 - 00:00 9.25 DRILL TRIP PROD Trip in Hole; Pump and Rotate because of loss of down Wieght From 11,628' - 13,879', 11,727' Attempt to run in hole with out Rotating No Down Wt. Check Shot survey to Confirm in Side Track, at 11,622', 11,722', 90RPM 600GPM 3,450 psi.110Rot Dn Wt. Started install of LoTads on Stand # 126 at (12,624'Depth of Lodtad), To Stand # 139 (13,897' Depth of LodTad) Total LodTads Picked Up 14. Total in Hole 69 LodTads. ECD 12 8/3/2005 00:00 - 00:15 0.25 DRILL TRIP PROD Trip in Hole; Pump and Rotate because of loss of down Wieght From 13,866' - 13,879',.600GPM 3,800 psi120Rot Dn Wt. Started install of LoTads on Stand # 126 at (12,624'Depth of Lodtad), To Stand # 139 (13,897' Depth of LodTad) Total LodTads Picked Up 14. Total in Hole 69 LodTads. ECD 12 Pumped 11 ppg. 120vis sweep. No Increase in returns. 00:15 - 05:30 5.25 DRILL DRLH PROD Drill Ahead; F/ 13,879'MD. 3,408'TVD. T/ 14,196'MD.3,380'TVD. ART 3.30hrs. Bit Hrs 32.48hrs. GPM-600, W/ 3,884psi. On Btm.-3,840.Off BTM. 140RPM.-18 Tq.On Btm.-18. Up Wt.-225k,Dn Wt.(less then block Wt of 70k),Rot Wt.-138k. ECD 12.2 ppg. 2,854'. Started with 5" HWDP Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 22 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To ' Hours Code Code Phase 8/3/2005 00:15 - 05:30 5.25 DRILL DRLH PROD 05:30 - 06:30 1.00 DRILL DEOT PROD 06:30 - 09:15 2.751 DRILL DRLH PROD 09:15 - 09:45 0.501 DRILL CIRC PROD 09:45 - 11:30 1.751 DRILL REAM PROD 11:30 - 12:00 I 0.501 RIGMNTI RGRP I PROD 12:00 - 17:00 5.00 DRILL DRLG PROD 17:00 - 22:15 5.25 DRILL DRLG PROD 22:15 - 00:00 1.751 DRILL DRLG PROD 8/4/2005 ~ 00:00 - 01:30 1.501 DRILL DRLG PROD 01:30 - 03:30 2.00 DRILL DRLG PROD 03:30 - 13:00 I 9.501 DRILL I REAM I PROD 13:00 - 13:30 0.50 DRILL OBSV PROD 13:30 - 14:30 1.00 DRILL CIRC PROD 14:30 - 18:45 4.25 DRILL TRIP PROD 18:45 - 20:30 1.75 DRILL PULD PROD 20:30 - 20:45 0.25 DRILL CIRC PROD 20:45 - 22:30 1.75 DRILL TRIP PROD 22:30 - 22:45 0.251 DRILL TRIP PROD 22:45 - 00:00 1.25 DRILL PULD PROD 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 03:00 1.00 DRILL PULD PROD 03:00 - 04:45 I 1.751 DRILL I PULD I PROD Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Stand # 140, 13,965'. Slow R.O.P T/50ft per Hr. From 14,020'-14055' 100-120ft per Hr 14,055' - 14,196' Per Directional Driller. MWD Pulsar and detection problems, Problems down linking to Geo-Pilot. Drill Ahead; F/ 14,196'MD. 3,380'ND, T/ 14,397'MD.3,364'ND. ART2.03hrs. Bit Hrs 34.51 hrs. GPM-610, W/ 4,010psi. On Btm.-3,990.Off BTM. 120RPM.-19 Tq.On Btm.-19. Up Wt.-240k,Dn Wt.(less then block Wt of 70k),Rot Wt.-140k. ECD 12.3 ppg. Footage Drilled 3,055' Average ROP 88' per Hr. Motors overheat Pick up off Btm. Slow Pumps and Rotary let motors cool Down. Back Ream Out Hole:From 14,397'MD 3,364'ND To 13,768'MD 33,412' 600GPM, 3,900psi. 120RPM, Up Wt. 230k Rot WT. 125k, Mode switched LWD tools, Change Liner Out in #2 Pump. Work Pipe Low side, From 13,758'-13,768' Open Hole Side Track: From 13,768'MD 3,412'ND, @ 13,864' Geo inclination confirmed sidetrack, Drill Ahead From 13,864'MD 3,412ND To 14,330'MD 3,405' ND, ART 4.44hrs. Including side track, Bit Hrs.38.95. 614 GPM, 3,780psi. on BTM, 3,750psi. off Btm. 235 Up Wt. W/O pumps, 130k Rot W/O pumps. neg Dn WT. ECD 11.9. Drill Ahead; F/ 14,330'MD. 3,405'ND. T/ 14,388'MD.3,402'ND. Total Drilled 58', @ 14,371'MD .Bad Detection on LWD tools, Work with Sperry sun on parameters, Mode Change, Check and clean pump suction screens, Screens O.K. Continue trouble shoot pull 1 stand back, Survey Drill Ahead; F/ 14,388'MD. 3,405'ND. T/ 14,397'MD.3,405'ND. Total Drilled 10", Bad Detection on LWD tools, Work with Sperry sun on parameters, Change modes, Stand Back 1 stand HWDP, Pump 450 GPM and Press Up Pulsation dampeners, to 1,000psi. From #1- 800psi, #2 -750psi. Good Detection on LW D tools both modes. Drill Ahead; F/ 14,397'MD. 3,405'ND. T/ 14,435'MD.3,397'ND. Total Drilled 38', tools, Work with Sperry Sun on Down link and Geo-Pilot problem. Last Survey @ 14,393 94.49 incl. 180.53 Azm. Back Ream Out Hole: 25-35ft per min. Re -Check, Geo -Tool at 13,658' and at 12,297 - 12,200, Monitor Well, @ 10,367'. Clean Rig Floor. Circulate Btms Up at 10,367', 600 GPM 3,100psi. Press, Worked on Pipe Handler. Trip Out Hole: Pump Dry Job, Pull Out Hole. Pick Up 30 jts. 5" HWT Drill Pipe, T/ 2,632' Circulate 70 Bbls through 5" HWT DP, Pump Dry Job. Trip Out Hole: 10 stands 5" HWT DP,13 Stands 5" DP, UD Ghost Reamer 1/8" under gauge, 3 stands 5" HWT DP and Jars, 1 stand Flex Drill Collars, PJSM; Removing and storing Neutron and gamma Sources, Remove and Store Sources. Down Load LW D Tools. Down Load LW D Tools. Pull Pulsar, P/U 15' Pup to stand Back in Derrick, P/U Break Out Bit, L/D Geo Pilot, could not rotate housing, Housing locked up. P/U new Geo pilot (housing turned), Make up Bit, MWD,Install Pulsater in H.O.C. collar Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 23 of 45 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From- To 8/5/2005 04:45 - 05:45 i 05:45 - 06:30 06:30 - 08:00 08:00 - 12:00 12:00 - 13:15 13:15 - 14:15 14:15 - 15:15 15:15 - 16:15 16:15 - 19:00 19:00 - 20:00 20:00 - 00:00 8/6/2005 00:00 - 02:45 02:45 - 03:45 03:45 - 05:00 05:00 - 06:00 06:00 - 08:00 08:00 - 09:00 09:00 - 09:30 09:30 - 12:00 12:00 - 12:30 1 E-170 1 E-170 ROT -D D15CM Doyon 1 ~~ Hours RILLING @conoco 5 Code ~ hillip Code .com Phase Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations 1.00 DRILL DEQT PROD Up Load and test & Test MWD. 0.75 RIGMNT RGRP PROD Trouble Shoot Top Drive fault. 1.50 DRILL DEQT PROD Shallow test MWD Tools, PJSM on Install of Nuetron and gamma sources, Install sources, Pick up BHA. 4.00 DRILL TRIP PROD Trip in Hole: Fill pipe every 25 stands to 10,370' MD, 175k Up Wt. 95 Dn Wt. 1.25 RIGMNT RSRV PROD Cut and slip Drill line 104', Inspect Brakes 1.00 RIGMNT RSRV PROD Service Rig, Adjust Compensator. 1.00 DRILL TRIP PROD Trip in Hole: From 10,370' to 11,612'MD Up Wt 190k, Dn Wt. 90k. 1.00 DRILL REAM PROD Make Up Top Drive, Wash and ream From 11,612'MD, to 12,013'MD. 2.75 DRILL TRIP PROD Trip in Hole: Fill Pipe every 10 stands, 12,013'- 14,241' {13,180' Up Wt. 200k Dn Wt 100k, 14,148' Up Wt. 205k Dn Wt. 100k. 14,148'. Up Wt. 205k Dn Wt.100k.} Check Shot Survey new hole Confirmed. 1.00 DRILL REAM PROD Wash and Ream: From 14,148' to 14,435'MD 3,397'TVD. 230 Up Wt. 100 Dn Wt, 4.00 DRILL DRLH PROD Drill Ahead; F/ 14,435'MD. 3,397'TVD. T/ 14,610' MD. 3,386'TVD. ART2.46hrs. Bit Hrs2.46hrs. GPM-600, W/ 4,200psi. On Btm.-4,120.Off BTM. 120RPM.-20 Tq.On Btm.-19. Up Wt.-250k,Dn Wt.-85,Rot Wt.-155k. ECD 11.9 ppg. No Concretions, APIG,43.75 Average ROP 71' hr. 2.75 DRILL DRLH PROD Drill Ahead; F/ 14,610'MD. 3,397'TVD. T/ 15,065' MD. 3,379'TVD. 1.76ARThrs. Bit Hrs 4.22hrs. GPM-600, W/ 4,200psi. On Btm.-4,120.Off BTM. 120RPM.-20 Tq.On Btm.-19. Up Wt.-250k,Dn Wt.-85,Rot Wt -155k. ECD 11.9 ppg. No Concretions, APIG,43.75 Average ROP 71' hr. ChargePump Pulsater Dampners T/ 1,400psi. 1.00 DRILL REAM PROD Loss signal, No Pulse Back Ream Out 3 stands Hwt Drill Pipe, replace with 5" drill Pipe, Trip Drill Pipe back in hole on Elevators, Down Wt 90k, 240 Up Wt. 1.25 DRILL DRLH PROD Drill Ahead: F/ 15,065 MD, T/ 15,078'MD, TVD 140 Up Wt. 90 Dn Wt. 152k Rot Wt. Tried One pump @ 430 GPM 2,700psi.signal but to dirty to read, Bumped Up Pulsater T/ 1,500 #2 Pump. No Change, Raised GPM TI630 4,350 psi. Pulse signal Drill Kelly down Make Connection lost signal. @ same Rate, Total hrs on bit @ 15078' = 4.69 hrs. 1.00 DRILL REAM PROD Back Ream Out of Hole f/ 15078' T/14610'. Will replace HWDP w/ 5" DP w/o Lo-tads. 2.00 DRILL REAM PROD Continue back Ream Out of Hole f/ 14610' T/13,868. All HWDP out of hole on pipe rack. 1.00 DRILL TRIP PROD RIH on elevators, replacing 5" HWT Drill Pipe W/ 5" Drill Pipe (no lo-tads). RIH f/ 13868' to 15014'. 0.50 DRILL REAM PROD Fill pipe, test Sperry Sun MWD/LWD and Sperry Sun geopilot, OK. Take SPR's. Wash and ream f/ 15014' to 15078'. 2.50 DRILL DRLG PROD Directional drill 8 1/2" hole f/ 15078' to 15135' (3378.5' TVD) (57') ART 1.91 hrs w/ Sperry Sun geo pilot, 6-7k WOB, 120 rpm's, 600 gpm, 9.0-9.1 ppg mw, on bottom pressure 4010 psi, off bottom pressure 3960 psi, on bottom torque 19k ft/Ib, off bottom torque 18k ft/Ib, PU wt 240k, SO wt 75k, Rot wt 130k. Note: Poor detection, intermittent MWD/LWD data Total bit hrs 6.6 0.50 RIGMNT RGRP PROD Work on #1 mud pump. Replace liner and swab. Liner gasket was leaking earlier, liner gasket was changed earlier. Back reamed +/- 30' of a stand, set stand back, backream slow w/ circ @ reduced rate w/ #2 mud pump, while working on #1 pump. Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Code Phase ''. ~ _ ~ _~ 18/6/2005 112:30 - 14:30 I 2.001 DRILL I DRLG I PROD 14:30 - 18:00 .3.501 DRILL DRLG PROD 18:00 - 00:00 I 6.001 DRILL I DRLG I PROD ~ 8/7/2005 ~ 00:00 - 02:30 2.501 DRILL DRLH PROD 02:30 - 02:45 0.25 DRILL -CIRC PROD 02:45 - 06:30 3.75 DRILL REAM PROD 06:30 - 07:45 I 1.251 RIGMNTI RGRP I PROD 07:45 - 10:45 I 3.001 DRILL I REAM I PROD 10:45 - 12:45 I 2.001 DRILL I REAM I PROD 12:45 - 15:15 2.501 DRILL REAM PROD 15:15 - 17:00 1.751 DRILL CIRC PROD Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Page 24 of 45 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations Directional drill 8 1/2" hole f/ 15135' to 15202' (3378' TVD) (67') ART 1.33 hrs w/ Sperry Sun geo pilot, 25k WOB, 120 rpm's, 610 gpm, 9.0-9.1 ppg mw, on bottom pressure 4080 psi, off bottom pressure 3990 psi, on bottom torque 19k ftllb, off bottom torque 19.5k ftilb, PU wt 230k, SO wt 70k, Rot wt 130k. Note: 15202' is the last of 5" drill pipe slick drilled down. Next will be 5" HWDP. Total hours on bit 7.93 hrs Note: MWDlLWD/PWD working ok, so far. Directional drill 8 1/2" hole f/ 15202' to 15,297' (3,377' TVD) ART 2.60 hrs w/ Sperry Sun geo pilot, 20-25k WOB, 120 rpm's, 600 gpm, 9.0-9.1 ppg mw, on bottom pressure 3,940 psi, off bottom pressure 3,920 psi, on bottom torque 19k ft/Ib, off bottom torque 19k ft/Ib, PU wt 230k, Dn Wt. none ,Rot wt 138k. Note:Drilling W/ 5" HWDP. Lost detection 1530 hrs @ 15261' MD/ 3370' TVD, cylcled pumps and came on. Lost Detection on and off. MAD Pass 15,297' - 15,290' lost detection. Directional drill 8 1/2" hole From 15,297' to 15,727' (3,370' TVD) ART2.13 hrs w/ Sperry Sun geo pilot, 20-25k WOB, 120 rpm's, 600 gpm, 9.0-9.1 ppg mw, on bottom pressure 3,940 psi, off bottom pressure 3,920 psi, on bottom torque 19k ft/Ib, off bottom torque 19k fUlb, PU wt 230k, Dn Wt. none ,Rot wt 138k. Note: #1 Pump 100strks - #2 38strks'. When detection lost send downlink to start back up, Drilling Ahead, Making mad Passes on Log area needed for Geoligist. 430' Footage Drilled, Out of A2 sands 15,440' Back in sands @ 15,730' Pumped 10.9 130 vis sweep 40 bbls @ 15,674'. seen sweep no increase of cuttings. Directional drill 8 1/2" hole From 15,727' to T.D.@15,940' (3,354' TVD). ART1.22 hrs. 14.46 Bit Hrs. w/ Sperry Sun geo pilot, 20-25k WOB, 120 rpm's, 580 gpm, 9.0-9.1 ppg mw, on bottom pressure 3,929' psi, off bottom pressure 3,910 psi, on bottom torque 19-20k ft/Ib, off bottom torque 19k ft/Ib, PU wt 240k, Dn Wt. none ,Rot wt 145k. Note: When detection lost send downlink to start back up Detection instead of restarting pump, Drilling Ahead, Making mad Passes on Log area needed for Geoligist that missed on detection. 213' Footage Drilled, Note: Drilled out of A2 sands Base 15,440'MD, 3,377'TVD, Back in sands 15,730'MD,3,370TVD. lost sands 290'. Ciculate, Survey @ T.D. 15,940'MD. 3,354' TVD. 93.64incl. 182.97AZM. Slow Pump rates. Back Ream Out Hole: F/ 15,940' T/ 13,871', 600GPM . 3,750'psi. Pull 25-30' per min. Running Speed. S pipe leaking on Top Drive, Tighten up, pressure up still leaking, R/U to circiulate,Break pipe free no Down Wieght, Circ, While Change out seal on Union, Lay Down Three jt, to keep LodTads in wind Wall area. Back Ream Out Hole: F/ 13,773' T/ 12,686', 600GPM . 3,740'psi. Pull 25-30' per min. Running Speed. Back Ream Out Hole: F/ 12,686' T/ 11,632', 447GPM . 1,830'psi. Pull 15-20' per min. Running Speed. Shut in #2 Pump, Shock Hose leaking, Continue backreaming slower rate. Back Ream Out Hole: F/ 11,632' T/ 10,167', 600GPM . 3,740'psi. Pull 25-30' per min. Running Speed. #2 Pump Back On Line Pump and pull at full rate. Pump High Wieghted,Vis Sweep - 120RPM - 600GPM - 3,151 psi. Rotate and Recipacate pipe 2 Btms Up 1211 bbs, Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 25 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date ~ From - To ~ Hours Code Code Phase 8/7/2005 17:00 - 17:30 0.50 RIGMNT RSRV PROD 17:30 - 21:45 4.25 DRILL TRIP PROD 21:45 - 22:00 22:00 - 00:00 8/8/2005 00:00 - 01:00 01:00 - 03:00 0.25 DRILL REAM PROD 2.00 DRILL CIRC PROD 1.00 DRILL i CIRC PROD 2.001 DRILL I CIRC I PROD 03:00 - 03:15 03:15 - 06:00 06:00 - 06:45 06:45 - 08:15 08:15 - 09:00 09:00 - 11:15 11:15 - 14:00 14:00 - 16:30 16:30 - 17:30 1.00 DRILL 17:30 - 18:45 1.25 DRILL 18:45 - 19:15 0.50 DRILL 19:15 - 19:30 0.25 LOG 19:30 - 21:30 2.00 LOG 21:30 - 00:00 2.50 LOG 8/9/2005 00:00 - 02:00 2.00 LOG 02:00 - 04:00 2.00 LOG 04:00 - 06:00 2.00 LOG TRIP PROD TRIP PROD OTHR PROD SFTY CMPLTN RURD CMPLTN ELOG CMPLTN ELOG I CMPLTN ELOG CMPLTN ELOG CMPLTN 06:00 - 10:00 4.00 LOG ELOG CMPLTN 1.0:00 - 12:00 2.00 LOG ELOG CMPLTN 12:00 - 13:30 1.50 LOG ELOG CMPLTN Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Service Rig, Monitior Well Trip in Hole: From 10,167' To 15,851' Fill every 10 stands 200k Up Wt, 95 Dn Wt. Had 95-100 Dn Wt all the way in Hole. Wash and Ream F/ 15,831' - T/ 15,940' Circulate; 600 GPM 4050 psi. @ 15,940' Getting Trucks with Solids Free OBM loaded up and all OLD O.B.M out of Pits. Trucks not lined up slow circ rate and rotary after Btms Up. Wait On Trucks. Circulate; Getting Trucks with Solids Free OBM loaded up and all OLD O.B.M out of Pits. Trucks not lined up slow circ rate and rotary after Btms Up. Wait On Trucks. Pump Sweep 40bbls, 100bb1s OBM, Followed By Solids Free OBM, Old OBM: While Pumping and Rotate and Recipacation 138 Up Wt.129 Dn Wt. 120 RPM Torque 19k, 600 Gpm, 4,100psi. Solids Free OBM around: Up Wt.143k, DnWt, 135k, 120 RPM, Torque 23-24k, 600 Gpm, 4,100 Psi. Total Strks Solids Free Mud To surface 11,200 Strks, Calculated 10,557 strks, 7 % over Calculated. Monitior Well, Slow Pump Rates, Pull 1 stand watch hole for swab. PU wt 240k, SO wt -no down wt. Trip Out Hole on elevators: F/ 15,831' - 11153' Trip Out Hole on elevators: F/ 11153' - 9900' Sperry Sun LWD MAD pass West sak "B" sands, log 9900' MD to 9700' MD/ 3353' ND-3319' ND. Log @ 200. ft/hr or less. Gamma Ray is 38' behind bit depth. Continue POOH f/ 9700' to 8713'. Sperry Sun LWD MAD pass West sak K13 marker, log 8713' MD to 8432" MD/ 3129' ND-3057' ND. Log @ 200 ft hr or less. Gamma Ray is 38' behind bit depth. Continue POOH f/ 8432' to 1376', L/D Ghost reamer. Continue POOH f/ 1376' to 1376', UD Ghost reamer. Stand back dp,stand back HW DP & jas, retrieved 2.33": rabit on top of jars, Stand back flex collars. PJSM, remove nuke sources. Download MWD/ LWD. L/D BHA, break and grade bit. Clear and clean rig floor. PJSM; Sclumberger RU Schlumberger. and P/U Tools Run in Hole with wire line tools for USIT Log. Free Fall T/ 2,500' start tracktering, 5,300' @ Midnight. Run in Hole with wire line tools for USIT Log. 5,300' - 6,600' @ 02;OOhrs 650' a Hr. Run in Hole with wireline tools for USIT log, 6,600' - 7,390' @ 04;OOhrs 395'/ Hr. Run in Hole with wireline tools for USIT log, 7,390'- 8,300' @ 06;OOhrs 455'/Hr. Run in Hole with wireline tools for USIT log, using Schlumberger tractor.RlH f/ 8300'- 9284' Tractor not able to get tools deeper than 9284'. Tool string 87.6' long (SON, USIT, centralizer, (2) knucle jts, 5 1/2" rollers GR, Telemtry, 5 1/2" rollers, adapter, Tractor, adapter, swivel, logging wireline head. Log cement job on 9 5/8: casing f/ 9284' to 4900'. Top of good cement @ 5910'. Log f/ hole in 9 5!8" in tie back area of 9 5/8" casing f! 4900' to 4800'. POOH to 2500'. 0.251 DRILL ~ OBSV PROD 2.75 DRILL TRIP PROD 0.75 DRILL TRIP PROD 1.50 LOG DLOG PROD 0.75 DRILL TRIP PROD 2.25 LOG DLOG PROD 2.75 DRILL TRIP PROD 2:50 DRILL TRIP PROD Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 26 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours ' Code Code Phase I 8/9/2005 13:30 - 15:30 .2.00 LOG ELOG CMPLTN 15:30 - 16:30 1.00 LOG ELOG CMPLTN 16:30 - 17:00 0.50 WELCT OTHR CMPLTN 17:00 - 17:30 0.50 WELCT OTHR CMPLTN 17:30 - 21:45 4.25 WELCT BOPE CMPLTN 21:45 - 22:45 1.00 WELCT OTHR CMPLTN 22:45 - 00:00 1.25 CMPLTN RURD CMPLTN 8/10/2005 00:00 - 00:30 0.50 CMPLTN SFTY CMPLTN 00:30 - 06:00 5.50 CMPLTN RUNT CMPLTN 06:00 - 09:45 I 3.751 CMPLTNI TRIP I CMPLTN 09:45 - 11:30 I 1.751 CMPLTNI TRIP I CMPLTN 11:30 - 12:30 I 1.00 I CMPLTNI TRIP I CMPLTN 12:30 - 14:30 I 2.00 I CMPLTNI TRIP I CMPLTN 14:30 - 15:00 I 0.501 CMPLTNI PCKR I CMPLTN 15:00 - 16:00 1.00 CMPLTNI PCKR CMPLTN 16:00 - 16:15 0.25 CMPLTN PCKR CMPLTN 16:15 - 16:30 0.25 CMPLTN PCKR CMPLTN 16:30 - 18:00 I 1.501 CMPLTNI TRIP I CMPLTN 18:00 - 21:30 3.501 CMPLTNI TRIP CMPLTN Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Log for casing wear in 9 5/8" casing f/ 2500' to 1500'. POOH. R/D Schlumbrger, L/D tools, clear rig floor. Drain stack, pull Vetco/Gray wear bushing. RU BOP test equipment. Test BOPE. Weekly test waived by AOGCC inspector Jeff Jones. Tested all componets to 250 psi low and 3000 psi high. Held each test 5 min each. Tested accumulator,2950 psi full charge, bled down to 1400, 52 sec f/ 200 psi build up, 3 min 59 sec full charge Pull test plug. Set wear Vetco/Gray wear bushing (3.18' long, 9" ID). Blow down kill and choke lines and choke manifold. RU to run 5.5", 15.5 #/ft, L-80, BTC-mod liner f/A2 lateral. Blanks and slots. PJSM on running 5.5", 15.5 #/ft, L-80, BTC liner (slots and blanks). Ran Weatherford float shoe, one blank jt, (1)slotted w/ insert P/O bushing, (1) slot, (9) blanks, (73) slots, (10) blanks, (6) slots, (9) blanks, (12) slots, (5) blanks, (2) slots, (12) blanks w/ seal rings installed, pup jt, x-o, 190-47 casing seal bore ext, x-o, Baker flexlock liner hanger, "RS" packoff seal nipple, "HRD" ZXP liner top packer, running tool. Ran total of (8) easy solutions swell packers 7.98" OD. Install Weatherford 5.5" x 8.25" spiralgliders on all joints other than jts w/ swell packers and shoe jt, total ran 132 spiralgliders. PU wt 115k, SO wt 85-90k, Blocks 70k. Liner length 6048.46' + Baker running tool 12.72'= 6061.18'. 46 joints blank = 1974.81' + 95 jts slotted 4020.39' = 5995.2' PU wt 115k, SO wt 85-90k, blocks 70k. RIH w/ liner on 44 stands of 5" dp w/ LoTads. SLM. Record PU & SO wt's every 10 stands in casing. With liner @ 9 5/8" shoe, 30 rpm: torque 10K w/ PU wt of 145k, 8500 ft/lb down wt of 125k, Rot wt 130k w/ 9k ft/ Ib torque. With liner @ 9 5/8" shoe, 15 rpm: torque 8k w/ PU wt of 145k, 8k ft/Ib down wt of 105k, Rot wt 130k w/ 8.5k ft/Ib torque. PU wt not rotating 170k, SO wt not rotating 110k Continue RIH w/ liner in open hole to 12500' (66 stands. total of5" dp, 55 stands 5" dp w /LoTads + 13 stands slick 5" dp. Continue RIH w/ liner in open hole f/ 12730' to 15940' (66 stands total of 5" dp, 55 stands w /LoTads + 13 stands 5" dp slick + 14 stands 5" dp w/ LoTads + 20 stands 5" HW DP (first 10 stands Weatherford pipe, last 10 stands Doyon pipe). Fill pipe and circ down last stand @ 3bpm w/ 270 psi. Tag bottom. SO wt 110k, PU wt 265k. POOH f/ 15940' to 15919' (Top of "HRD" ZXP liner top packer 9870.46') Drop 1 7/16" ball. Circ ball down @ 5 bpm w/ 500 psi. Slow down to 3.5 bpm w/ 110 bbls pumped. Ball landed @ 136 bbls pumped (1350 strokes). Pressure to 2000 psi to set hanger. Slacked off 30k on slips. Increase pressure to 3000 psi to shear pusher tool. Increased pressure to 3300 psi and saw presure drop. Pressure continued to drop with 'slight returns in annulus. PU to 220k to check to see if released. Did not think released. Apply left hand rotation f/ safety release f/liner. PU wt was 240k. Exposed dog sub. Set down 70k wt on ZXP packer 3 times. Rotate 70k on top of packer w/ dog sub. POOH to 9670', verify pump pressure. 30 spm (3bpm) = 150 psi. Continue POOH f/ 9670' to 6964' I Continue POOH w/ Baker running tools f/ 6964' to surface. Calc fill 95.5 Printed: 9/30/2005 6:19:05 AM ~ • ConocoPhillips Alaska Page 27 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To II Hours Code '~, Code Phase 8/10/2005 18:00 - 21:30 3.50 CMPLTN TRIP CMPLTN 21:30 - 22:00 0.50 CMPLTN PULD CMPLTN 22:00-22:30 0.50 WINDO ULD CMPLTN 22:30 - 22:45 0.25 WINDO SFTY PROD2 22:45 - 23:15 0.50 WINDO ULD PROD2 23:15 - 00:00 0.75 WINDO ULD PROD2 18/11/2005 100:00 - 00:45 I 0.751 WINDOV'VPULD I PROD2 00:45 - 02:00 I 1.251 WINDOV'UOTHR I PROD2 02:00 - 03:15 I 1.251 WINDOVY/OTHR I PROD2 03:15 - 04:00 0.75 WINDOV'~OTHR PROD2 04:00 - 06:00 2.00 WINDO RIP PROD2 06:00 - 08:00 I 2.001 WINDOV'VTRIP I PROD2 08:00 - 09:00 I 1.001 WINDOV'VOTHR I PROD2 09:00 - 10:00 1.00 WINDO OTHR PROD2 10:00 - 11:30 1.50 WINDO OTHR PROD2 11:30 - 12:30 1.00 WINDO RIP PROD2 12:30 - 13:00 .0.50 WINDO SFTY PROD2 13:00-15:00 2.00 WINDO RIP PROD2 15:00 - 16:30 1.50 WINDO RIP PROD2 16:30 - 17:30 1.00 WINDO ULD PROD2 17:30 - 18:00 0.50 WINDO OTHR PROD2 18:00 - 18:30 0.50 RIGMNT RSRV PROD2 18:30 - 20:00 1.50 FISH PULD PROD2 20:00 - 22:15 2.25 FISH TRIP PROD2 22:15 - 22:45 0.50 FISH FISH PROD2 22:45 - 23:00 I 0.251 FISH I FISH I PROD2 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations bbls, actual fill 120.1bbls, 24.6 bbls over. Made service breaks and L/D Baker liner running tools. Break down stand of 5" HWDP f/derrick to use in whipstock assembly. Measure joints. PJSM on PU and running Baker whipstock assembly. Pick tools to rig floor. PU/MU Whipstock assembly. Baker 8" Window mill, 8" Lower mill, Flex joint, 8.5" upper mill, (1) joint 5" HWDP, float sub, MWD. PU/MU Whipstock assembly. Baker 8" Window mill, 8" Lower mill, Flex joint, 8.5" upper mill, (1) joint 5" HWDP, float sub, MWD. Upload Speery Sun MWD, shallow test tools., check orientation of mills and MWD, stand back MWD & mills. PU whipstock assembly, bolt together. Whipstock assembly: Seal assembly w/ bull nose, stop sub (8.5" OD), unloader sub, (1) jt 5" HWDP, (2) 5" pup joints, blanking sub, bottom trip anchor, safety disconnect, ported drain sub, debris sub, Windowmaster shipstock, window mill, lower mill, (1) joint HWDP, float sub, Sperry sun telemetry module, Sperry sun memory module, sperry sun Gamma ,Sperry sun DM MU Baker/ Bowen bumper sub. 2 stands 5" HWDP Trip in hole w/ Baker Windowmaster system using 5" DP w/ LO-Tads ,SLM, running speed 2 min/stand f/ 384' to 2856'. Fill pipe. Trip in hole wl Baker Windowmaster system using 5" DP w/ Lo-Tads, SLM, running speed 2 min/stand f/ 2856' to 4844'. PU wt 170k, SO wt 90K. Note: on Hi-line power @ 0830 hrs. Set down @ 4844' (45 stands +10'). Check string weight. Check location of assembly in relation to 9 5/8" Tie-Back Note: 4844'MD = 2268.5 TVD, 77.67 deg inclination, 174.79 azimuth, 1.31 deg dogleg. Check casing profiles, logs and options. MU top drive, work string. Rotate ! 15 rpm, up and down, rotate up watching torque (7-10k ft/Ib), Rotate/PU slow. POOH to check whipstock assembly. 12 stands out. Quarterly Safety Assessment w/ Doyon, CPAI and rig crew. Continue POOH w/ Baker whipstock. Set back 2 stands 5" HWDP. Work BHA f/ whipstock. Drain stack. Pull through stack slow. NO Whipstock. UD Sperry Sun MWD, UD (1) HWDP, L/D Baker mills. Clear rig floor of tools. Service rig and top drive. PU tools to fish whipstock. MU BHA: Baker retieving hook , (1) 5" HWDP, float sub, 6.25" Bowen, 6.25" Oil Jar, (5) stands 5" HWDP. (Total length of BHA = 523.86') RIH w/ 5" DP w/ LoTads to fish whipstock. Run 42 stands. MU top drive on stand 43, strap 5' going in hole, to locate slot in whipstock w/ retrieving tool. Apply torque to drill string and rotate. Found top of whipstock @ 78.4' in and keyhole @ 84.7' in on stand 43. PU wt 135k, SO wt 100k PU 60-65kk over (210k) to release bottom trip anchor. Note: next daay recoved whipstock. Whipstock had signs of retieving tool @ slot had jumped off, anchor did not release. Pulled anchor loose next trip. Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 28 of 45 Operations Summary Report (Legal Well Name: 1E-170 'Common Well Name: 1E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date I From - To I Hours I Code I Code I Phase Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations 8/11/2005 23:00 - 00:00 1.00 FISH TRIP PROD2 POOH slow w/ whipstock assembly FISH f/ 4762' to 3490' (Window Master Whipstock, debris sub w/ 9.625" barrier cup, ported drain sub, safety disconnect sub, 9 518" bottom trip anchor, blanking sub, 14.68' 5" pup jt, 9.48' S" pup joint, (1) joint 5" HWDP, unloader sub, 8.5" OD stop sub, 7 7/16" OD Seal assembly w/ bull nose) Note: no fish recovered 8/12/2005 00:00 - 02:30 2.50 FISH TRIP PROD2 POOH slow w/ whipstock assembly f/ 3490' to 524' FISH (Window Master Whipstock, debris sub w/ 9.625" barrier cup, ported drain sub, safety disconnect sub, 9 5/8" bottom trip anchor, blanking sub, 14.68' 5" pup jt, 9.48' 5" pup joint, (1) joint 5" HWDP, unloader sub, 8.5" OD stop sub, 7 7/16" OD Seal assembly w/ bull nose) 02:30 - 03:00 0.50 FISH TRIP PROD2 Stand back 5 stands 5" HWDP, UD Oil jars, bumper jars and float sub. 03:00 - 04:45 1.75 FISH OTHR PROD2 PU & Inspect Baker retrieving hook; whipstock assembly not recovered, signs of contact on top edge of retrieving tool. L/D Baker hook, PU/MU Baker box tap (rolling dog sub), MU same. 04:45 - 05:00 0.25 FISH TRIP PROD2 Trip in hole w/ whipstock retrieving tool (Box Tap) on (1) jt 5" HWDP, float sub, 6.25" Bowen bumper sub, 6.25" Bowen Oil jar, (5) stands 5" HWDP. 05:00 - 06:30 1.50 FISH TRIP PROD2 Trip in hole w/ fishing BHA to latch whipstock. RIH w/ 5" dp w/ Lo-Tads f/ 520' to 4756', run a total of 42 stands 5" dp w/ to-Tads, MU top drive on stand 43 and 5' strap in. Tag @ 4756.74'. (82.5' on stand 43) Note: PU wt 132k, SO wt 100k, Rot wt 115k, rot torque 5-7k ft/Ib. 06:30 - 07:45 1.25 FISH FISH PROD2 Engage fish (top of whipstock), PU 3' w/ 145k PU wt, SO, apply turns- watching torque-max 9k ft/Ib. Let jars bleed W/ PU wt of 170k, final of 140k, PU to 160k, 170k, 185k, 205k, 210k anchor released. Pull up hole w/ 140-145k PU wt. Slack off to tag up again; but went past stop point. Slack off to 10' past (4766'). PU again w/ 140-143k past stop point, slack off and tagged up this time (Indication of still having whipstock fish assembly). 07:45 - 11:00 3.25 FISH TRIP PROD2 POOH slow w/ fish (Whipstock window master assembly). Pull 50-60 ft/min. 11:00 - 11:30 0.50 FISH TRIP PROD2 Stand back (5) stands 5" HWDP, Lay down bumper sub, jars and float sub. 11:30 - 13:30 2.00 FISH PULD PROD2 Pull (1) joint 5" HWDP and box tap w/ whipstock assembly(flsh). LID Fish consisting of: Whipstock, debris sub, ported drain sub, safety disconnect, bottom trip anchor, blanking sub, 5" pup joint 14.68' long, 5" pup joint 9.48" long, one joint 5" HWDP, unloader, 8.5" OD stop sub, 7-7/16" OD seals w/ bull nose. Total length 94.21'+ seals below stop. 13:30 - 14:00 0.50 FISH OTHR PROD2 Clear rig floor of unneccessary tools. 14:00 - 16:45 2.75 WINDO ULD PROD2 PU/MU Whipstock assembly #2. PU/MU Debris sub, ported drain sub, safety disconnect, bottom trip anchor, blaking sub. L/D same to pipe shed. 16:45 - 18:00 1.25 WINDO ULD PROD2 PU1MU MWD assembly: 8" window starting mill, 8" lower mill, flex joint, 8.51" upper mill, (1) joint 5" HWDP float sub, Sperry Sun directional probe, Sperry Sun MWD/LWD, Sperry Sun telemetry module. Up load Sperry Sun MWD, shallow test @ 505 gpm w/ 640 psi. Stand back MWD assembly. 18:00 - 18:45 0.75 WINDO ULD PROD2 PU whipstock, MU whipstock. 18:45 - 19:30 0.75 WINDO ULD PROD2 Attatch mills and MWD to whipstock. Check orientation. 19:30 - 20:15 0.75 WINDO ULD PROD2 MU bumper sub, PU (3) 6 3/4" spiral drill collars. Rabbit w/ 2 3/8" drift before Picking up DC's. Trip in (2) stands 5" HWDP. Whipstock assembly consists of: Seals, stop sub, unloader (1) jt 5" HWDP, 9.48' long 5" pup jt, 14.68' long 5" pup jt, blanking sub, bottom trip anchor, Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Operations Summary Report Page 29 of 45 .Legal Well Name: 1 E-170 ,Common Well Name: 1 E-170 Spud Date: 6/26/2005 .Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date ;From - To I~, Hours Code Code Phase Description of Operations _ _ _- I 8/12/2005 ~ 19:30 - 20:15 ~ 0.751 WINDO ULD PROD2 20:15 - 00:00 3.751 WINDOVI/TRIP PROD2 8/13/2005 ~ 00:00 - 04:45 4.751 WINDOVIITRIP PROD2 04:45 - 06:30 1.751 WINDOV'~/OTHR PROD2 06:30 - 08:30 2.001 WINDOV~ITRIP PROD2 08:30 - 09:30 I 1.001 WINDOV'VSETW I PROD2 09:30 - 09:45 0.25 WINDO~SFTY PROD2 09:45-11:30 1.75 WINDO CIRC PROD2 11:30 - 14:20 I 2.831 WINDOV'VSTWP I PROD2 14:20 - 18:00 3.671 WINDOV'VSTWP PROD2 18:00 - 00:00 I 6.001 WINDOV'VSTWP I PROD2 8/14/2005 100:00-06:00 ~ 6.OO~WINDOV'I/STWP PROD2 06:00 - 08:00 2.00 WINDOV'VCIRC PROD2 08:00 - 08:30 I 0.501 WINDOV'VOTHR I PROD2 08:30 - 10:00 1.50 RIGMNT RSRV PROD2 10:00 - 10:30 0.50 WINDO CIRC PROD2 10:30 - 15:00 4.50 WINDO RIP PROD2 15:00 - 16:30 1.50 WINDO ULD PROD2 16:30 - 17:00 0.50 WINDO ULD PROD2 17:00 - 18:30 1.50 WINDO OTHR PROD2 18:30 - 19:15 I 0.751 WINDOV'VOTHR I PROD2 safety disconnect, ported drain sub, debris sub, Whipstock, 8" starter mill, 8" lower mill, flexjoint, 8.51" upper mill, (1) joint 5" HWDP, float sub, Sperry Sun irectional, Sperry sun LWD, Sperry sun telementry module, Bown bumper sub, (3) 6 3/4" Spiral DC's, (2 stands) 5" HWDP. Follow w/ 5" drill pipe w/ Lo-Tads RIH in hole slow w/ Whipstock on 5" drill pipe w/ Lo-Tads f/ 477' to 2949', fill pipe, RIH w/ 5" drill pipe w/ Lo-Tads f/ 2949' to 4927'. RIH in hole slow w/ Whipstock on 5" drill pipe w/ Lo-Tads f/ 4927'- 8857.72' MAD pass log f/ 8857.72' to 9061'. Pumping 600 gpm w/ 2875 psi. Logging @ less than 300 ft/min RIH in hole slow w/ Whipstock on 5" drill pipe w/ Lo-Tads f/ 9061' to 9820'. PU wt 220k, SO wt 115k Orient whipstock. Set whipstock top 9776.6' w/ top of window @ 9778'. Set 24 deg Left of high side. PU wt 210k, SO wt 102k. PJSM w/ crew and AES vac truck operators, mud engr. Displace well f/ 9.0 ppg Solids free oil base mud to 9.0 ppg Mineral oil base mud. Displace @ 505 gpm w/ 2545 psi. Start milling window f/ "B" lateral @ 9778.5' to 9794.5' (16'). 75-105 RPM, torque 13-19k ft/Ib. Pump 505 gpm w/ 2550 psi. PU wt 220k, SO wt 115k, Rot wt 160k.Top of window @ 9778.5'/ 3331'ND. Bottom of window @ 9794.5'/ 3334' ND. Continue milling window f/ 9794' to 9803' (9'). PU wt 220k, SO wt 115k, Rot wt 160k, 95rpm, 19-13k ft/Ibs on bottom, 12-13k ft/Ib off bottom torque, 505 gpm w/ 2680 psi. Continue milling window f/ 9803' to 9808 (5') ND = 3336'. PU wt 220k, SO wt 115k, Rot wt 160k, 105-120rpm, 14-17k ft/Ibs on bottom, 12-13k ft/Ib off bottom torque, 505 gpm w/ 2680 psi. Weight on mill 25k. Pumped 30 bbls weighted Hi-Vis sweep @ 2230 hrs (9807'), no improvement in milling ROP. Note: This section of hole was slow drilling in 12 1/4" hole section. 9810' starter mill depth, rate gets better. Starter mill to upper mill = 19.34' Continue milling window f/ 9808' to 9818 (10') ND = 3337'. PU wt 220k, SO wt 115k, Rot wt 160k, 105-120rpm, 14-17k ft/Ibs on bottom, 12-13k fUlb off bottom torque, 505 gpm w/ 2680 psi. Weight on mill 25-30k. Note: "B" lateral window: 9778.5' to 9794.5' MD (3331' ND-3334' ND) Pump 30 bbls weighted (2ppg over =11.0 ppg) Hi-Vis sweep @ 520 gpm w/ 2580 psi. Circ to surface + a bottoms up (12,000 strokes, 1208 bbls). Work through window several times. No Problems. PU wt 220k, SO wt 140k. TD of starter mill w/ no compression is 9818' (3337' ND), full 8.5" guage mill 4.76' outside of window. PU to 9756', stand a stand back Slip and cut drilling line, adjust brakes. Pump dry job. POOH f/ 9756' to 383'. UD milling BHA. Upper mill guaged @ 8.5" OK. Clear rig floor of unneccessary tools. Pull wear bushing. Wash stack, function all rams & annular, kill line valves, choke line valves. Install Vetc/Gray wear bushing. UD (2) 5" HWDP. Printed: 9/30/2005 6:19:05 AM • . ConocoPhillips Alaska Page 30 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Na me: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date 'From - To Hours Code ~' Code' Phase ; 8/14!2005 19:15 - 20:15 1.00 RIGMNT RSRV _ PROD2 20:15 - 22:00 1.75 DRILL PULD PROD2 22:00 - 23:00 1.00 DRILL OTHR PROD2 23:00 - 23:30 0.50 DRILL TRIP PROD2 23:30 - 23:45 0.251 DRILL OTHR PROD2 23:45 - 00:00 0.25 DRILL TRIP PROD2 8/15/2005 00:00 - 05:30 5.50 DRILL TRIP PROD2 05:30 - 06:30 1.00 DRILL OTHR PROD2 06:30 - 07:00 I 0.501 DRILL I LOT I PROD2 07:00 - 12:00 I 5.001 DRILL I DRLG I PROD2 12:00 - 13:00 I 1.001 DRILL I DRLG I PROD2 13:00 - 13:30 0.50 DRILL CIRC PROD2 13:30 - 14:00 0.50 DRILL TRIP PROD2 14:00 - 14:30 0.50 DRILL CIRC PROD2 14:30 - 18:00 3.50 DRILL TRIP PROD2 18:00 - 18:30 ~ 0.501 DRILL TRIP PROD2 18:30 - 19:30 1.00' DRILL TRIP PROD2 19:30 - 20:00 0.50 DRILL OTHR PROD2 20:00 - 21:00 1.00 DRILL PULD PROD2 21:00 - 22:30 1.50 DRILL PULD PROD2 22:30 - 23:30 1.00 DRILL OTHR PROD2 23:30 - 00:00 0.50 DRILL OTHR PROD2 8/16/2005 00:00 - 01:00 1.00 DRILL TRIP PROD2 01:00 - 05:30 4.50 DRILL TRIP PROD2 05:30 - 06:00 I 0.501 DRILL I REAM I PROD2 Spud Date: 6/26/2005 Start: 6/22/2005 .End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Change out washpipe packing on top drive. PU drilling assembly to drill out of "B" lateral whipstock/window. PU Sperry Sun motor, MU bit, PU Sperry Sun MWD/LWD, float sub, then orient. Upload MWD. PU stand of flex collars, stand of HWDPw/jars., RIH 1 stand of Weatherford 5" slick dp to 440' Shallow test Sperry Sun MWD tools @ 440'. Pressure test swivel packing to 4500 psi. OK. SLM while RIH w/ Weatherford 5" dp f/ 440' to 824'. SLM while RIH w/ Weatherford 5" dp f/ 824' to 9719'. RIH w/ 1.5 deg motor to drill out of "B" lateral window, fill pipe every 25 stands. Picked up 10 more Lo-Tads to stand back in derrick. Have a total of 79 Lo-Tads in derrick or hole. Orient motor to high side. Turn off pumps, go past top of whipstock @ 9776', top of window 9778.5' MD/ 3331' TVD, bottom of window @ 9794.5' MD/ 3334' TVD, then to full guage hole @ 9799'. Break circ @ 9799', wash/ream underguage hole f/ 9799' to 9820' w/ 600 gpm 3650 psi. PU wt 185k w/o pumps, SO wt 112 w/o pump. PU wt 162k w/ pump, SO wt 105 w/ pump. PU f/ 9820' to 9719'. No trouble going through window. RU to perform LOT. Decided not too. R/D test equipment. Directional drill 8 1/2" hole f/ 9820' to 9990' (3341' TVD) ART 2.35 hrs, AST 1.15 hrs w/ Sperry Sun 1.5 deg motor, 10-25k WOB, 0-80 rpm's, 550 gpm, 9.0-9.1 ppg mw, on bottom pressure 3150 psi, off bottom pressure 2980 psi, on bottom torque 14-17k ft/Ib, off bottom torque 12k ft/Ib, PU wt 180k, Dn Wt 95k ,Rot wt 130k. Directional drill 8 1/2" hole f/ 9990' to 10050' (3337' TVD) ART .27 hrs, AST .19 hrs w/ Sperry Sun 1.5 deg motor, 10-25k WOB, 0-80 rpm's, 550 gpm, 9.0-9.1 ppg mw, on bottom pressure 3150 psi, off bottom pressure 2890 psi, on bottom torque 14-17k ft/Ib, off bottom torque 13k ft/Ib, PU wt 180k, Dn Wt 95k ,Rot wt 130k. Circ w/ recip and rotate pipe. MWD survey, SPR's, monitor well. POOH f/ 10050' to 9705'. No problems through window bottom @ 9794.5' to 9778.5' top of window. Monitor well, pump dry job. Continue POOH fi 9705' to 1295' w/ Sperry Sun 1.5 deg motor to PU Geo-pilot. No problems. Continue POOH f/ 1295' to 348' w/ Sperry Sun 1.5 deg motor to PU Geo-pilot. Work BHA. Stand back HWDP, jars, flex collars, break bit. Download Sperry Sun MWD. UD Sperry Sun MWD and motor. PU/MU Geopilot, Sperry Sun LWD/MWD tools, nuke sub and pulsar sub. Up Load MWD/LWD. PJSM on loading nuke sources Shallow test MWD/LWD tools @ 108' w/ 560 gpm 1180 psi. Shallow test MWD/LWD tools @ 108' w/ 560 gpm 1180 psi. PJSM; Load Gamma and Nuetron sources. Trip in Hole with BHA # 17 Trip in Hole; 5" Drill Pipe 31jts Pick Up ghost Reamer, Continue trip in Hole Fill Pipe Every 25 stands To 9,778' Go Through window, Wash and Ream from 9,960' To 10,038' Up WT. 180k, Dn Wt. 110k, Rot Wt. 125k, 120 RPM, 600GPM, 3,330psi. Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 31 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date ,From - To Hours ,Code 8/16/2005 06:00 - 12:00 12:00 - 18:00 18:00 - 00:00 8/17/2005 ~ 00:00 - 06:00 06:00 - 12:00 12:00 - 18:00 18:00 - 00:00 8/18/2005 100:00 - 06:00 Sub Phase Code 6.001 DRILL I DRLH I PROD2 6.001 DRILL I DRLH I PROD2 6.00 DRILL DRLH PROD2 6.001 DRILL !DRLH I PROD2 6.001 DRILL I DRLH I PROD2 6.001 DRILL I DRLH I PROD2 6.001 DRILL I DRLH I PROD2 6.001 DRILL I DRLH I PROD2 06:00 - 13:00 7.00 DRILL PROD2 Description of Operations Directional Drill 8 1/2" hole F/ 10,050' T/ 10,305' (3,333' TVD) ART 4.62 hrs, Bit Hrs 4.62, 5-20k W0B,80 - 120 RPM, 550 gpm, 9.0-9.2ppg MW, On BTM 2,870 psi, Off BTM 2800 psi, On BTM 11-17k ft/Ib,Off Btm 14k ft/Ib, PU wt 165k, Dn Wt 90k ,Rot wt 130k. ECD 11.4ppg. Directional Drill 8 1/2" hole F/ 10,305' (3,333' TVD) T/ 10,549' (TVD 3,338') ART 5.28 hrs, Bit Hrs 9.9, 5-20k W06,80 - 120 RPM, 550 gpm, 9.0-9.2ppg MW, On BTM 2,940 psi, Off BTM 2,850 psi, On BTM 13-18k ft/Ib,Off Btm 14k ft/Ib, PU wt 180k, Dn Wt 80k ,Rot wt 130k. Directional Drill 8 1/2" hole F/ 10,549' (TVD 3,338') T/ 11,018' (TVD 3,328') ART 3.49 hrs, Bit Hrs 13.65, 5-20k W0B,80 - 120 RPM, 600 gpm, 9.0-9.2ppg MW, On BTM 3,210 psi, Off BTM 3,160psi, On BTM 13-18k ft/Ib,Off Btm 14k ft/Ib, PU wt 215k, Dn Wt 95k ,Rot wt 140k. ECD 11.8 Directional Drill 8 112" hole F/ 11,018' (TVD 3,328') T/ 11,238' (3,331'Tvd) ART 4.97 hrs, Bit Hrs 18.62, 15-25k WOB,140 RPM, 600 gpm, 9.0-9.2ppg MW, On BTM 3,330 psi, Off BTM 3,260psi, On BTM 15-24k ft/Ib,Off Btm 14k ft/Ib, PU wt 220k, Dn Wt 95k ,Rot wt 140k. ECD 11.8. Average Rate of Penatration 45'per hr 220' Total ft Drilled. Directional Drill 8 1/2" hole F/ 11,238' (3,331') T/ 11,673' (3,331' Tvd)ART 3.69 hrs, Bit Hrs 22.31, 5-25k W06,140 RPM, 550 gpm, 9.2ppg MW, On BTM 2,870 psi, Off BTM 2,840psi, On BTM Torq 13-24k ft/Ib,Off Btm Torq 21 k ft/Ib, PU wt 225k, Dn Wt 80k ,Rot Wt. 140k. ECD 11.7 Average Rate Penetration 117' per hr. 435' Total Ft. Drilled. Directional Drill 8 1/2" hole F/ 11,673' (3,331') T/ 11,814' (3,330' Tvd) ART 5.53 hrs, Bit Hrs 27.84, 10-25k W06,140 RPM, 550 gpm, 9.0-9.1 ppg MW, On BTM 2,930 psi, Off BTM 2,840psi, On BTM Torq 15-214k ft/Ib, Off Btm Torq 15-21 k ft/Ib, PU Wt. 225k, Dn Wt. 85k ,Rot Wt. 140k. ECD 11.4 Average Rate Penetration 25' per hr. 141' Total Ft. Drilled. Directional Drill $ 1/2" hole F/ 11,814' (3,330' Tvd) - T/ 12,093' (3,324'Tvd) - PU Wt. 220k,- Dn Wt. 95k, -Rot Wt. 140k.- GPM 600 - Press on Btm-3,280'.- Press off Btm 3,180' -RPM 140,- Torq,on Btm. 17-22,- Torq Off Btm. 14-16,- Actual Drill Time 5.10 -Bit Hrs. 32.94 - Average Rate Penetration 55' per hr.- 279' Total Ft. Drilled. -Max Gas 242 units. Directional Drill 8 1/2" hole F/ 12,093' (3,324'Tvd) T/ 12,489' (3,319' Tvd) - UP Wt. 230k,- Dn Wt. 90k, -Rot Wt. 140k.- GPM 557 -Press on Btm-2,900'.- Press off Btm 2,870' -RPM 120,- Torq,on Btm. 17-22,- Torq Off Btm. 18,- Actual Drill Time 4.92 -Bit Hrs. 37.86 -Average Rate Penetration 80' per hr.- 396' Total Ft. Drilled. -Max Gas 127 units. Note; Hit possible fault @ approximately 400' further then expected @12,300' Dropped RPM and GPM to help build angle. 12,490' Back in sands. Directional Drill 8 1/2" hole F/ 12,489' (3,319'Tvd) T/ 12,687' (3,311' Tvd) - UP Wt. 225k,- Dn Wt. 85k, -Rot Wt. 130k.- GPM 600 -Press on Btm-3,430'.- Press off Btm 3,380' -RPM 120,- Torq,on Btm. 15-22,- Torq Off Btm. 14-19k,- Actual Drill Time 6.15 -Bit Hrs. 44.01 -Average Rate Penetration 33' per hr.- 198' Total Ft. Drilled. -Max Gas 161 units. 13:00 - 16:30 3.50 RIGMNT RGRP PROD2 Circulate while repair on #1 pump liner gasket, Broke stud on pony rod. 16:30 - 18:00 1.50 DRILL DRLH PROD2 Directional Drill 8 1/2" hole F/ 12,687' (3,311' Tvd) - T 12,697' (3,310' Tvd)Up Wt. 225k,- Dn Wt. 85k, -Rot Wt. 130k.- GPM 600 -Press on Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 32 of 45 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To E-170 E-170 ROT -D D15CM Doyon 1 Hours ~ RILLING @conoco 5 Code hillip Code .com Phase 8/18/2005 16:30 - 18:00 1.50 DRILL DRLH PROD2 18:00 - 23:15 5.25 DRILL DRLH PROD2 23:15 - 00:00 0.75 RIGMNT RGRP PROD2 8/19/2005 00:00 - 06:00 6.00 DRILL DRLH PROD2 06:00 - 12:00 6.00 DRILL DRLH PROD2 12:00 - 18:00 6.00 DRILL DRLH PROD2 18:00 - 00:00 6.00 DRILL DRLH PROD2 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Btm-3,430'.- Press off Btm 3,380' -RPM 120,- Torq,on Btm. 15-22,- Torq Off Btm. 14-19k,- Actual Drill Time 1.41 -Bit Hrs.45.42 -Average Rate Penetration 7' per hr.- 10' Total Ft. Drilled. -Max Gas151units. ECD 11.6ppg. Directional Drill 8 1/2" hole F/ 12,687' (3,311' Tvd) - T 12,920' (3,308' Tvd) UP Wt. 225k,- Dn Wt. 85k, -Rot Wt. 130k.- GPM 600 -Press on Btm -3,430'.- Press off Btm 3,380' -RPM 120,- Torq,on Btm. 15-22,- Torq Off Btm. 14-19k,-Actual Drill Time 3.78 -Bit Hrs.49.20 -Average Rate Penetration 59' per hr.- 223' Total Ft. Drilled. -Max Gas 242 units. ECD 11.8ppg Work on Kelly hose wearing on stand Upper Tool Jt. While Drilling. Showing signs of wear. Loosen union and put turn in hose. Directional Drill 8 1/2" hole F/ 12,920' (3,308' Tvd). T/ 13,323'(3,302 ND) PU Wt. 220k,- Dn Wt. 90k, -Rot Wt. 140k.- GPM 600 -Press on Btm-3,430'.- Press off Btm 3,380' -RPM 140,- Torq,on Btm. 16-23,- Torq Off Btm. 18k,- Actual Drill Time 4.25 -Bit Hrs.53.45 -Average Rate Penatration 94.82' per hr.- 403' Total Ft. Drilled. -Max Gas 142 units. ECD 11.8ppg NOTE; Pumped Sweep @ 13,118', 40% increase on returns. 10.9 ppg 160vis.40bbls. ECD 12.2ppg 11.8ppg. After Sweep. Directional Drill 8 1/2" hole F/ 13,323'(3,302 ND) T/ 13,711' (3,290' Tvd). PU Wt. 230k,- Dn Wt. 80k, -Rot Wt. 125k.- GPM 600 -Press on Btm-3,430'.- Press off Btm 3,390' -RPM 140,- Torq,on Btm. 15-21,- Torq Off Btm. 18k,- Actual Drill Time 4.25 -Bit Hrs.57.61 -Average Rate Penatration 91.29' per hr.- 388' Total Ft. Drilled. - ECD 12ppg. Directional Drill 8 1/2" hole F/ 13,711' (3,290' ND) T/ 13,811' (3,284' Tvd}. PU Wt. 230k,- Dn Wt. 80k, -Rot Wt. 125k.-GPM 600 -Press on Btm-3,560'.- Press off Btm 3,490' -RPM 140,- Torq,on Btm. 15-21,- Torq Off Btm. 18k,- Actual Drill Time 5.29 -Bit Hrs. 62.90 -Average Rate Penatration 18' per hr.- 100' Total Ft. Drilled. - ECD 12.2ppg. Directional Drill 8 1/2" hole F/ 13,811' (3,284' ND) T/ 14,058' (3,277' Tvd). PU Wt. 220k,- Dn Wt. 85k, -Rot Wt. 135k.- GPM 600 -Press on Btm-3,570'.- Press off Btm 3,510' -RPM 140,- Torq,on Btm. 19,- Torq Off Btm. 19k,-Actual Drill Time 4.35 -Bit Hrs. 67.25 -Average Rate Penatration 18' per hr.- 247' Total Ft. Drilled. - ECD 12.3ppg. Pumped Sweep @ 14,038' 40 bbl sweep 25% increase in returns. 8/20/2005 00:00 - 01:30 1.50 DRILL DRLH PROD2 01:30 - 04:00 2.50 DRILL REAM PROD2 04:00 - 06:30 2.50 RIGMNT RGRP PROD2 06:30 - 13:00 6.50 DRILL REAM PROD2 Directional Drill 8 1/2" hole F/ 14,058' (3,284' ND) T/ 14,101' (3,277' Tvd). UP Wt. 220k,- Dn Wt. 85k, -Rot Wt. 135k.-GPM 600 -Press on Btm-3,570'.- Press off Btm 3,510' -RPM 140,- Torq,on Btm. 19,- Torq Off Btm. 19k,- Actual Drill Time.57 -Bit Hrs. 67.42 -Average Rate Penetration 75' per hr.- 43' Total Ft. Drilled. - ECD 12.6ppg. No Change in ECD. After Sweep. Back Ream Out of Hole,F/14,101' T/12,490' Pull Speed 10-20 feet a min, 600 GPM, 3,560psi. Short Trip to Place Ghost Reamer at window Circulate Hole while Cleaning up fluid discharged from broken mud bucket line. 3 bbls in Containment Approximately 6 gals Outside containment Security and Environmental notified @ 04;05am. Replace line and clean up. Back Ream Out of Hole,F/12,290' T11,275' Pull Speed 4-6 feet a min, 600 GPM, 3,360psi. Short Trip to Place Ghost Reamer at window. Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 33 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date ~ From - To Hours Code Phase ~ - Code - 8/20/2005 13:00 - 14:00 1.00 DRILL CIRC PROD2 14:00 - 16:00 2.00 DRILL TRIP PROD2 16:00 - 16:30 0.50 DRILL REAM PROD2 16:30 - 18:00 1.50 DRILL DRLH PROD2 18:00 - 00:00 6.00 DRILL DRLH PROD2 8/21/2005 ~ 00:00 - 06:00 6.001 DRILL DRLH PROD2 06:00 - 17:30 11.501 DRILL DRLH PROD2 17:30 - 18:00 0.50 DRILL CIRC PROD2 18:00 - 23:45 5.75 DRILL TRIP PROD2 23:45 - 00:00 0.25 DRILL CIRC PROD2 8/22/2005 00:00 - 00:30 0.50 DRILL CIRC PROD2 00:30 - 01:00 0.50 DRILL TRIP PROD2 01:00 - 01:45 0.75 DRILL REAM PROD2 01:45 - 08:15 6.501 DRILL REAM PROD2 08:15 - 15:30 7.25 DRILL OTHR PROD2 15:30 - 16:30 1.00 RIGMNT RSRV PROD2 16:30 - 19:15 2.75 DRILL TRIP PROD2 19:15 - 22:45 3.50 DRILL REAM PROD2 22:45 - 00:00 1.251 DRILL CIRC I PROD2 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Circulate and Recipacate F/ 11,275' - T/ 11,330' Trip in Hole; F/11,275' - 14,006' Average slack off wt 80k Dn Wt. Wash and Ream F/ 14,006' - T/ 14,101' No Hole Problems on Trip. Directional Drill 8 1/2" hole F/ 14,101' (3,277' TVD) T/ 14,138' (3,3,274' Tvd). UP Wt. 230k,- Dn Wt. 80k, -Rot Wt. 120k.- GPM 585 -Press on Btm-3,640'.- Press off Btm 3,510' -RPM 140,- Torq,on Btm. 19,- Torq Off Btm. 19k,- Actual Drill Time..65 -Bit Hrs. 68.47 -Average Rate Penetration 56 per hr.- 37' Total Ft. Drilled. - ECD 12.6ppg. No Change in ECD. After Sweep. Directional Drill 8 1/2" hole F/ 14,138' (3,274' TVD) T/ 14,575' (3,269' Tvd). UP Wt. 230k,- Dn Wt. 80k, -Rot Wt. 120k.-GPM 550 -Press on Btm-3,120'.- Press off Btm 3,090' -RPM 140,- Torq,on Btm. 20,- Torq Off Btm. 18k,- Actual Drill Time. 4.07 -Bit Hrs. 72.54 -Average Rate Penetration 107 per hr.- 437' Total Ft. Drilled. - ECD 11.7ppg. Max Gas Units 247, Lower Pump Rate @ 14,292' F/600GPM - T/ 550 GPM T/ Manage ECD. Annular Velocity 220 ft per min. @ 550GPM in 8.8 hole. Directional Drill 8 1/2" hole F/ 14,575' (3,269' Tvd). T/ 15,000' (3,252'Tvd) UP Wt. 230k,- Dn Wt. 80k, -Rot Wt. 130k.- GPM 550 - Press on Btm-3,200'.- Press off Btm 3,170' -RPM 140,- Torq,on Btm. 20,- Torq Off Btm. 18k,- Actual Drill Time. 4.53 -Bit Hrs. 77.07 - Average Rate Penetration 94 per hr.- 425' Total Ft. Drilled. - ECD 11.7ppg. Max Gas Units 550, Pumped Sweep @ 14,903' 35% increase in returns at Shakers. Directional Drill 8 1/2" hole F/ 15,000' (3,252'Tvd) T/ 15756' (3,231' Tvd)TD. UP Wt. 2250k,- Dn Wt. Ok, -Rot Wt. 139k.-GPM 550 -Press on Btm-3,640'.- Press off Btm 3,580' -RPM 140,- Torq,on Btm. 20,- Torq Off Btm. 18k,-Actual Drill Time. 6.98 -Bit Hrs. 84.05 -Average Rate Penetration 94 per hr.- 425' Total Ft. Drilled. - ECD 12.6ppg. Max Gas Units 490. Pumped Sweep @ 15,430' Circulate Rotate and Reciprcate Back Ream Out of Hole,F/15,756' - T/ 14,000' Pull Speed 4-6 feet a min, first 8 stands, 25-30 feet per min. while backreaming out 550 GPM, 3,210psi. Short Trip to last short trip depth 14,000' Pull 3 stands on Elevators pulled good.T/ 13,714. Circulate, Rotate and Recipacate BTMs Up. Circulate, Rotate and Recipacate BTMs Up. 600 GPM - 3,340psi - 140 RPM Up Wt. Trip in Hole 13,714 Would not go down Wash and Ream F 13,912' - T/ 14,420' Still would not go down with out washing and reaming @ 550 GPM -140 RPM - Back Ream Out of Hole F/ 14,420' - T/ 10,700' - 140 RPM - 560GPM -3,100psi. Pumped Sweep while slowly pulling up T/Windoow W/ Ghost Reamer, 40% increase in cutting (fine sand). Pull through window with Ghost reamer continue back reaming T/10,700 Mad Pass F/10,700' - T/ 9,762' @ 3-oft amin/Per MWD. Service Rig, Monitior well Trip in Hole; F/ 9,762' - T/ 14,450' Wash and Ream in Hole F/ 14,450' 6 stands of Heavy wieght on top. 14,450' Wash 2stands down try to go down without rotation, Still no down wieght, Ream stand down, Pull up 30' try to go down just with pumps, No down wieght, 15,561, 18 stands Heavy wt. Was able to get down wt. 80k down Ream to Btm. 15, 756'. Circulate and condition hole, Pump 35 BBL Sweep 10.5ppg 130vis. Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To .Hours Code Code Phase 8/22/2005 122:45 - 00:00 8/23/2005 100:00 - 01:45 01:45 - 06:45 1.25 ~ DRILL CIRC PROD2 1.751 DRILL (CIRC IPROD2 5.001 DRILL ITRIP IPROD2 06:45 - 07:45 1.00 RIGMNT RSRV PROD2 07:45.- 12:00 4.25 DRILL TRIP PROD2 12:00 - 13:30 1.50 DRILL PULD PROD2 13:30 - 14:15 0.75 DRILL PULD PROD2 14:15 - 18:15 4.00 DRILL PULD PROD2 18:15 - 19:15 1.00 DRILL PULD PROD2 19:15 - 19:45 0.50 DRILL OTHR CMPLT2 19:45 - 00:00 4.25 WELCT BOPE CMPLT2 8/24/2005 00:00 - 03:00 3.00 WELCT BOPE CMPLT2 03:00 - 10:00 7.00 RIGMNT RGRP CMPLT2 10:00 - 10:30 0.50 WELCT BOPE CMPLT2 10:30 - 11:15 0.75 RIGMNT RGRP CMPLT2 11:15 - 12:00 0.75 CMPLTN RURD CMPLT2 12:00 - 12:30 0.50 CMPLTN SFTY CMPLT2 12:30 - 20:00 7.50 CMPLTN RUNT CMPLT2 20:00 - 20:15 20:15 - 00:00 8/25/2005 ~ 00:00 - 01:00 01:00 - 01:30 0.251 CMPLTNI OTHR I CMPLT2 3.751 CMPLTNI RUNT CMPLT2 1.001 CMPLTNI RUNT CMPLT2 0.501 CMPLTNI CIRC I CMPLT2 Page 34 of 45 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations 50% increase in returns. GPM-537, PSI.-3,840' RPM-140, UP WT. 260k - Dn Wt.- 115k, -Rot Wt. 170k. Torq 20k.After sweep. Circulate and Condition Hole: Displace hole with solids free Oil Base Mud. GPM 537- PSI 4,000-RPM 140- Up Wt. 280k.-Dn Wt.95k-Rot Wt.170.- Torq 22k. after Displaced. Note; Before displacement GPM 537-PSI 3,840. -RPM 140.-Up Wt. 260k.-Dn Wt. 115k.- Rot Wt. 170k. Torq 20 Trip Out Hole. Drop Drift 2", SLM, F/ 15,756'- T/ 9,650' Up Wt 230k, Dn Wt.90k. Note: Tight Spot @ F/13,417' - T/13,222' 30-35k overpull. Cut Drill Line, 140' Inspect Brakes, Monitor Well Tnp Out Hole: SLM, F/ 9,650' - T/ 385' UD HWT D.P. Jars, and flex collars. PJSM on removing gamma and nuetron sources, and remove. Download LWDtools. Lay Down BHA. Clean rig floor. Rig Up to test BOPE 250psi. low 3,000psi. high, Pull wear ring. Set test plug, Test ROPE (test Jt Bad had to L/D and R/U new Jt.) Rig Up to test BOPE 250psi. low 3,000psi, high, Test BOPE, All test except Hydi11 Tested. Hydril Failed. Nipple Down Bell Nipple,Flow Line, Change Out Hydril Element. Nipple up Flow nipple and equipment, Re-Test Hydril 250 low, 3,000high. Pull test plug and set wear ring. Re-Install Drip Pan R/U to run 5 1/2" liner PJSM; Co-Man, Baker Rep and rig crew on running 5 1/2" Liner. Make Up Shoe Jt.-Insert Pack off Jt.Run. -Cross -Over Pup DWCxBTC- 5 1/2" L-80 slotted Liner 42- DWC, Cross-Over Pup BTC x BTCM, 32- BTCM 5 1/2" L-80 15.5 Slotted Liner, 10- BTCM 5 1/2" L-80 15.5 Blanks with 4 Restrictors, 50- BTCM 5 1/2" L-80 15.5 Slotted Liner. 1-BTCM 5 1/2" L-80 Blank,- 5 1/2"x7" Cross Over,1-Jt. BTCM 7" 26ppf. I-80 CSG, 1- 7" BTCM 26ppf L-80 Pup, Baker "HR" liner setting Sleeve 7", Running Tool,-5,799' of 5 1/2 liner W/ Running Tool.(4.22'), liner Up Wt,115k, Dn Wt, 90k, 5" DP, 5 -stands slick Pipe-35 Stands 5" W/ LodTads, 5 1/2" liner @ 9 5/8" Window 9,738' ,Pumps On 30RPM: Torque 7K - UP wt of 150k, 7500 ft/Ib Dn Wt 115k, Rot wt 125k w/ 7500k ft/ Ib torque.3 bpm 150psi. Pumps Off 30 RPM 7,500k Torq, Up Wt. 170k, Dn Wt. 105k. Rot Wt.130k. Run in Hole; F / 9,738' T/ 13,770' W/ 5 1/2" Liner. 43 Stands 5" W! LodTads, 3 stand 5" HWDP. Trouble Getting in hole F/ 11,648' Work pipe. Rotated through and work through tight spot Depth 11,648' 11,728',11,900', 12,155', 12,205', 12,801', 12,420', Up Wt 210k, Dn Wt 85k when we could get down weight. 30 RPM, 15,000 Torq. Worked pipe down T! 13,493', to best use 5" Hwt. Drill Pipe. Ran 3 stands 5" Hwt Up Wt.240k, Dn Wt 80k. Run in Hole W/ 5 1/2" Liner. F/ 13,770' - T/ 15,756' Total = 5 stands- 5" Drill Pipe. 73 Stands 5" W/ LodTads, 19 stand 5" HWDP. 6 -Stands 5" Drill pipe W/ LodTads. Tagged Btm @ 15,756', Up Wt. 290k. Dn Wt. 105k. Drop 7/16" ball. put liner on depth @ 15,745' Liner Top @ 9,950' Circ Printed: 9/30/2005 6:19:05 AM ConocoPhillips Alaska Page 35 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date I From - To I Hours Code Phase Code 8/25/2005 01:00 - 01:30 0.501 CMPLTNI CIRC CMPLT2 01:30 - 05:45 4.25 CMPLTN TRIP CMPLT2 05:45 - 06:00 0.25 CMPLTN OTHR CMPLT2 06:00 - 07:00 1.00 CMPLTN PULD CMPLT2 07:00 - 10:00 3.00 CMPLTN TRIP CMPLT2 10:00 - 11:00 I 1.00 I CMPLTNI OTHR CMPLT2 11:00 - 12:45 I 1.751 CMPLTNI CIRC I CMPLT2 12:45 - 16:45 4.00 CMPLT TRIP CMPLT2 16:45 - 18:00 1.25 CMPLTN PULD CMPLT2 18:00 - 19:00 1.00 CMPLTN OTHR CMPLT2 19:00 - 20:30 1.50 CMPLTN RURD CMPLT2 20:30 - 22:45 2.25 CMPLTN PULD CMPLT2 22:45 - 23:30 0.75 CMPLTN PULD CMPLT2 23:30 - 00:00 0.50 CMPLTN TRIP CMPLT2 8/26/2005 100:00 - 05:30 I 5.50 I CMPLTNI TRIP I CMPLT2 05:30 - 09:45 4,251 CMPLTNI SOHO CMPLT2 09:45 - 13:30 3.75 CMPLTN TRIP CMPLT2 13:30 - 15:00 1,50 CMPLTN RURD CMPLT2 15:00 - 15:30 0.501 CMPLTNI RURD CMPLT2 15:30 - 17:00 1.50 CMPLTN PULD CMPLT2 17:00 - 17:30 0.50 CMPLTN OTHR CMPLT2 17:30 - 00:00 6.501 CMPLTNI TRIP CMPLT2 8/27/2005 00:00 - 03:45 3.751 CMPLTNI TRIP CMPLT2 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations ball down @ 5 bpm w/ 500 psi. Slow down to 3.5 bpm w/ 125 bbls pumped. Ball landed @ 152 bbls pumped (1,504 strokes). Pressure to 3000 psi to set hanger. Slacked off 10k .Pull Up 240k Up Wt. Up Wt was 290k W /liner. Press 4,000psi. T/ Unseat ball Liner Released. Trip Out hole. Break Off Liner Running tool Clean rig Floor P/U Whip Stock Retrieval BHA Trip in Hole With Whipstock Retrieval BHA. T/ 9,710' Up Wt. 230k-Dn Wt. 120k. Fill Pipe, Establish Circulation 53 SPM W/ 535psi. Up Wt. 230k- Dn Wt. 120k. Slack Off T/ 9,785' Latch Up Whip Stock @ 9,783'. Pulled 100k Over Up Wt. No Movement Jarred Up, Took 8 Attempts and sheared out @ 120k Over. Pulled up T/ 9,685' and Flow Check, Circulate Btms Up @ 115 SPM W/ 2,210psi.Pumped 470 bbls. Btms Up Gas 120 units Circulate Additional Btms Up 470 bbls Flow Check ,well static, Trip Out Hole W/ Whipstock. L/D Retrieving Tool, Whipstock Assembly and Seal Assembly Clean Rig Floor of Tools and Oil Base R/U Csg Equipment Tongs and Elevators. P/U Hook Hanger Assembly and 2 7/8" Internal Assembly, R/D Csg Tools and Handling Tools Trip In Hole W/ Hook Hanger Assembly Total Assembly Length 227.77' T/1098' Trip in Hole W/ Hook Hanger F/ 1,098' - T/ 9,761' 2 min a stand. Up Wt. 230k, Dn Wt. 130k. @ Window Trip in Hole Tagged @ 9,900 P/U Wt 240. Dn Wt.130k.Pull Back Up T/ Window 9,780' Rotate Pipe 3 Turns Slacked off tagged at 9,883'. Showed on tally 5 1/2" x 8" centralizer On spacerjt @ Window, Worked pipe Through window Tagged @ second Centralizer 78' on Pup above ECP Work Through window, Hooked on window on Depth 9,794' depth of hook P/U rotate Pipe Went down and tagged on 7" x 5 1/2" Cross-over on Depth @ 10,004' pull Back Up Rotate Missed Hoook, Rotate work Torque down Landed on hook pulled back off came right back down hooked window again. on depth 9,794' set down 50k 2x Each time 10-15k over pull coming back off. Pull up break connection drop 29/32 Ball. Pump Total of 160 bbls press up to. SOOpsi. ball unseated. PuH Up Break connection Dropped 1 314 ball press up staged up T/2,700Psi. Ecp started to fill press back up T/2,700psi total amount to fill ecp .8 bbl. Pressure up to 3,500psi Hydrolic release Up Wt. 240k Trip Out Hole W/ Running tool. Lay Down Running tools and 2 7/8 and 2 3/8 Inner string. Clean Rig Floor and clear of Equipment. PJSM on Running L.E.M. running order R/U Tongs, Elevators, and Handling equipment. Make Up seal, LEM, and Packer Assembly, Change Elevators, Clear Floor, Pick up LodTads to Replace worn loadtads, While Tripping in hole. Trip in Hole: 70'-80' Per Min. With L.E.M. Assembly. Replacing Worn LodTads. Trip in Hole: With L.E.M. Assembly remove Worn LodTads Replace with new. Ti 9,748' Total Changed Out 34 LodTads, Up Wt. 235k. Dn Wt. 130k. Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 36 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common W ell Name: 1 E-170 Spud Date: 6/26/2005 Event Nam e: ROT -D RILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM @conoco phillip s.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 1 5 Rig Number: 15 I I ~ Sub ~ ' I Date j From - To L _ Hours Code ' Code Phase - I Description of Operations 8/27/2005 03:45 - 04:15 0.50 CMPLTN TRIP CMPLT2 Trip in Hole: With L.E.M. Assembly T/ 9,772' Top of Hook hanger with Seal Jt. Up Wt.235k Dn Wt. 130k. Did not see any weight change, Run in T/ 9,912' set 30k Down pull up 25k Over Pull Release. Slack Back off set 30k Pull 15k over set slips break Jt. Drop Ball. Depth's Mule Shoe @ 9,912', Hanger @ 9,772', Top Of L.E.M. 9,710' 04:15 - 05:30 1.25 CMPLTN PCKR CMPLT2 Circulate 1 3l4" Ball down T/ Set Packer Press up T/ 3,000psi Hold for 2 min press stayed at 3,000psi. Bleed down. Press up Annulus T/ 500psi to test Packer, Hole @ (4,857'-4,861') LOT 620 Psi. W/ 9ppg. Put 500psi on 9 5/8 annulus bleed Down, Monitor 13 3/8x9 5/8" Annulus started W/ 200psi.(Diesel in Annulus). Press up 9 5/8"x 5" to 500psi. 13 3/8"x 9 5/8" Press climbed to 740psi. Bleed Down 9 5/8 annulus. 13 3/8 x 9 5/8 annulus tracked down with bleed Off. Back T/250psi. Pull up to confirm release, Pulled free set back down 3 times 40k to manually confirm packer set. Up Wt. 230k. Dn Wt. 130k. 05:30 - 09:45 4.25 CMPLTN TRIP CMPLT2 Trip Out Hole: With L.E.M. Running Tool F/ 9,710' 09:45 - 10:15 0.50 CMPLTN TRIP CMPLT2 L/D L.E.M. Running Tool, Clear Floor of handling tools 10:15 - 10:45 0.50 CMPLTN OTHR CMPLT2 Test 13 3/8" x 9 5/8" Rate .5 BPM @ 300psi. Pumped 3 bbls returns at flow nipple. 10:45 - 12:00 1.25 RIGMNT RSRV CMPLT2 Change Out Saver Sub on Top Drive 12:00 - 13:00 1.00 RIGMNT RSRV CMPLT2 Rig Service 13:00 - 14:00 1.00 RIGMNT RGRP CMPLT2 Change Out Low Drum Drawworks Chain (Preventive Maintance) 14:00 - 16:15 2.25 WINDO ULD PRODS Pick Up seal, Whip stock and Mill Assembly 16:15 - 17:00 0.75 WINDO ULD PRODS Upload MWD Tools. P/U Remainder BHA and Shallow Test MWD tools. 17:00 - 18:00 1.00 WINDO ULD PRODS Continue to P/U BHA and shallow test MWD 18:00 - 23:45 5.75 WINDO RIP PRODS Trip in Hole: W/Whip Stock Assembly and Mill Assembly T/ 9,650' 23:45 - 00:00 0.25 WINDO OTHR PRODS Break circulation and Orientate Whip Stock 16 left. Up Wt. 240k, Dn Wt. 128. 8/28/2005 00:00 - 00:45 0.75 WINDO SETW PRODS Set Anchor (Locator sub at 9,710') W! 50k, Pulled 10k over 250k insure set. Set 15,000 Torque limit rotate Stall, Worked pipe rotate at free point. Whip Stock set Depth; Top of Window 9412' (TVD 3,274') Bottom of Window, 9,428'. (TVD 3,276') All Markers on Depth. 00:45 - 01:15 0.50 WINDO CIRC PRODS PJSM: Mud Change Out From Solids Free Oil Base To Drilling Oil base Mud, 504 GPM, 2,950psi. When Drilling OBM Clears Bit. Start Milling Window. 01:15 - 07:15 6.00 WINDO SCML PRODS Milling Window, RPM 80-100 (Less vibration on MWD higher RPM), Torq 10-15k, GPM 505, PSI 2,950, WOB 3-6k, Milling Depth Top of Window 9,412', BTM Of Window 9,428' TVD 3,276'. Note; Mud Swap Done @ 02:00. 07:15 - 08:30 1.25 WINDO CIRC PRODS Pump Sweep 130vis, 11ppg. GPM 600- PSI 3,640', 08:30 - 08:45 0.25 WINDO RIP PRODS Monitior Well, Trip Out Hole T/ 9,355' 08:45 - 10:00 1.25 RIGMNT RSRV PRODS Cut and Slip Drill Line, Inspect Brakes, Service Top Drive. 10:00 - 12:00 2.00 WINDO RIP PRODS Trip Out Hole: F/ 9,335' - T/ 5,807' 12:00 - 12:15 0.25 WINDO CIRC PRODS Pipe came wet, Stop Pump Sweep, 12:15 - 13:30 1.25 WINDO RIP PRODS Trip Out of Hole: F/ 5,807' - T/ 200' 13:30 - 15:15 1.75 WINDO ULD PRODS L/D Mill BHA, Upper Mill in Gauge, 15:15 - 16:00 0.75 WINDO OTHR PRODS P/U stack washer and wash out B.O.P. 16:00 - 18:00 2.00 DRILL PULD PRODS Pick Up Drilling BHA, Surface Test MWD, GPM 500, PSI 440, P/U Total BHA. 18:00 - 22:00 4.00 DRILL TRIP PRODS TIH W/ 5" D.P. F/ DERRICK FILLING EVERY 25 STANDS TO 9396' 22:00 - 22:30 0.50 DRILL OTHR PRODS ORIENT TOOL FACE TO 16L STOP PUMP AND SLIDE THROUGH WINDOW 9412' TO 9431' START PUMPS 22:30 - 00:00 1.50 DRILL DRLG PRODS Directional Drill 8 1/2" D Lateral sands: W/ 1.5 Motor: F/ 9,448' T/ Printed: 9/30/2005 6:19:05 AM ConocoPhillips Alaska Page 37 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date I From - To Hours ~ Code I Sub it Phase i~ l Code -- - - . 8/28/2005 22:30 - 00:00 ~ 1.50 DRILL DRLG I PROD3 8/29/2005 00:00 - 05:45 5.751 DRILL DRLH PROD3 05:45 - 07:15 1.501 DRILL REAM PROD3 07:15 - 07:30 0.25 DRILL TRIP PROD3 07:30 - 08:15 0.75 DRILL CIRC PROD3 08:15 - 08:30 0.25 DRILL OBSV PROD3 08:30 - 12:00 3.50 DRILL TRIP PROD3 12:00 - 13:45 1.75 DRILL PULD PROD3 13:45 - 14:00 0.25 DRILL OTHR PROD3 14:00 - 17:00 3.00 DRILL PULD PROD3 17:00 - 17:30 0.50 DRILL SFTY PROD3 17:30 - 18:00 0.50 DRILL PULD PROD3 18:00 - 22:45 4.75 DRILL TRIP PROD3 22:45 - 23:00 0.25 DRILL TRIP PROD3 23:00 - 00:00 1.00 DRILL REAM PROD3 8/30/2005 00:00 - 01:30 1.50 DRILL OTHR PROD3 01:30 - 06:00 I 4.501 DRILL I DRLG I PROD3 06:00 - 12:00 I 6.001 DRILL I DRLG I PROD3 12:00 - 18:00 I 6.001 DRILL I DRLG I PROD3 18:00 - 00:00 6.00 i DRILL DRLG I PROD3 8/31/2005 100:00 - 03:00 3.00 DRILL DRLG PROD3 Description of Operations 9,678' Up Wt. 195k Dn Wt. 115k Rot Wt. 125k GPM 508 PSI 2,965 RPM 50 Tq On BTM 10K Tq Off BTM 8K JAR HRS 1.0 ADT .59 AST .41 BIT HRS 1.0, Directional Drill 8 1/2" D Lateral sands: W/ 1.5 Motor: F/ 9,678' - T/ 10,154' (3,279 TVD) Up Wt. 195k Dn Wt. 115k Rot Wt. 125k GPM 508 PSI 2,965 RPM 80 Tq On BTM 12K Tq Off BTM 9K JAR HRS 4.70 ADT 3.42 AST 1.24 BIT HRS 4.70, Pump Sweep 30% increase at shakers, Back Ream Out Hole: F/ 10,154' - T/ 9,491' Check Shots every 100', Up Wt. 185k, Dn Wt 115k, Rot Wt. 135, Torq. 11k, RPM 80, GPM 500, PSI 2,870, Trip Out Hole: F( 9,491' - T( 9,301' Circulate: Clean Hole @ GPM 550, PSI 3,100, Pumped Total 480bb1s. Monitioor Well: Pump Dry Job Trip Out Hole: F/ 9,301' - T/ 350' UD BHA # 21 and download MWD. Clear and Clean Rig Floor. P/U BHA # 22 Geo-Pilot; Up link LWD and shallow Test Tools. PJSM: Handling and loading of Nuetron and Gamma Sources and Install. P/U BHA # 22 Flex Collars, Jars and Hwt Dp. Total 292.89 Trip in Hole: Fill every 25 stands, T/ 9,360' Fill Pipe, set Deflection, Go Through window (9,412'-9,428'). Ream F/ 9,480' - T/ 10,051' Pump Sweep 30 bbl 11 ppg 146 vis Reamed F/ 10,051' Tagged at 10,060', Took Wieght went T/ 10,065' Picked Up to verify Depth,( Depth is correct). Look at logs and Drilling slide sheet. Started Drilling @ 10,060' Old logs and Tag coralate With being 95' off of Motor Run. Directional drill 8 1/2" "D" lateral sands f/ 10,060' to 10,486' (3267' TVD) ART 3.17 hrs, w/ Sperry Sun Geo-Pilot, 4-9k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3100 psi, off bottom pressure 3015 psi, on bottom torque 13-16k ft/Ib, off bottom torque 15k ft/Ib, PU wt 190-195k, Dn Wt 98-95k ,Rot wt 140-138k. Directional drill 8 1/2" "D" lateral sands f/ 10,486' to 10,939' (3267' TVD) ART 3.52 hrs, w/ Sperry Sun Geo-Pilot, 10-20k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3150 psi, off bottom pressure 3120 psi, on bottom torque 15-17k ft/Ib, off bottom torque 15-16k ft/Ib, PU wt 200k, Dn Wt 95k ,Rot wt 135k. EGD 11.22ppg Directional drill 8 1/2" "D" lateral sands f/ 10,939' to 11,500' (3262' TVD) ART 4.3 hrs, w/ Sperry Sun Geo-Pilot, 10k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3190 psi, off bottom pressure 3110 psi, on bottom torque 15-17k ft/Ib, off bottom torque 17-21 k ft/Ib, PU wt 202k, Dn Wt 90k ,Rot wt 130k. ECD 11.63ppg. Pumped Hi-vis weighted to 11.0 ppg sweep @ 11240' f/ ECD's. Note: Vetco/Gray tested 13 3/8" x 9 5/8" packoff to 4200 psi f/ 15 min. OK. Directional drill 8 1/2" "D" lateral sands f/ 11,500' to 12,127' (3257' TVD) ART 3.95 hrs, w/ Sperry Sun Geo-Pilot, 7-17k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3200-3320 psi, off bottom pressure 3100-3280 psi, on bottom torque 14-20k ft/Ib, off bottom torque 14-20k ft/Ib, PU wt 210-215k, Dn Wt 85-90k ,Rot wt 135k. ECD 11.7 ppg. Pumped Hi-vis weighted to 11.0 ppg sweep @ 12050' f/ ECD's. Directional drill 8 1/2" "D" lateral sands f/ 12,127' to 12,405' (3253' TVD) Printed: 9/30/2005 6:19:05 AM • • CortocoPhillips Alaska Page 38 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To~~ Hours Code tI Cod~Phase 8/3112005 100:00 - 03:00 I 3.001 DRILL I DRLG PROD3 03:00 - 05:30 2.50 RIGMNT RGRP PROD3 05:30 - 06:00 0.50 RIGMNT RGRP PROD3 06:00 - 12:00 6.00 DRILL DRLG PROD3 12:00 - 18:00 6.00 DRILL DRLG PROD3 18:00 - 00:00 6.001 DRILL ~ DRLG PROD3 9/1/2005 ~ 00:00 - 06:00 6.001 DRILL DRLG PROD3 06:00 - 12:00 I 6.001 DRILL I DRLG I PROD3 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations ART 1.98 hrs, w/ Sperry Sun Geo-Pilot, 5-10k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3270-3320 psi, off bottom pressure 3250-3200 psi, on bottom torque 14-19k ft/Ib, off bottom torque 14-18k ft/Ib, PU wt 210-215k, Dn Wt 85-90k ,Rot wt 135k. ECD 11.6 ppg. Back ream f/ 12,405' to 11,745' w/ 454 gpm and 2000 psi, w/ 120rpm, 15-17k torque. Pulling @ 6-7 ft/min. Working on # 2 mud pump liner gasket. RIH from 11,745' to 12,405' w/ no problems Directional drill 8 1/2" "D" lateral sands f/ 12,405' to 12,816' (3255' TVD) ART 4.08 hrs, w/ Sperry Sun Geo-Pilot, 10-20k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 2990-3300 psi, off bottom pressure 3240-3200 psi, on bottom torque 15-19k ft/Ib, off bottom torque 14-19k ft/Ib, PU wt 210-205k, Dn Wt 80-82k ,Rot wt 135-140k. ECD 11.6-11.8 ppg. Pumped 11.0 ppg hi vis sweep @ 12050' and 12,780', 30% increase in cuttings returns. Directional drill 8 1/2" "D" lateral sands f/ 12,816' to 13510' (3237' TVD) ART 3.98 hrs, w/ Sperry Sun Geo-Pilot, 10-15k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3350-3460 psi, off bottom pressure 3210-3310 psi, on bottom torque 16-19k ft/Ib, off bottom torque 16-20k ft/Ib, PU wt 210k, Dn Wt 85-80k ,Rot wt 142-135k. ECD 11.8-11.95 ppg. Directional drill 8 1/2" "D" lateral sands f/ 13510' to 14199' (3221' TVD) ART 3.78 hrs, w/ Sperry Sun Geo-Pilot, 6-12k WOB, 120-140 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3550-3720 psi, off bottom pressure 3500-3650 psi, on bottom torque 19k ft/Ib, off bottom torque 18-20k ft/Ib, PU wt 215-230k, Dn Wt 80- 70k ,Rot wt 135-132k. ECD 12-12.4 ppg. Pumped weighted hi vis sweep @ 13,640' and 14,110', no increase in cuttings returns. Directional drill 8 1/2" "D" lateral sands f/ 14199' to 14780' (3209' TVD) ART 3.43 hrs, w/ Sperry Sun Geo-Pilot, 6-12k WOB, 140 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3690-3890 psi, off bottom pressure 3650-3800 psi, on bottom torque 19-20k ft/Ib, off bottom torque 18-20k fUlb, PU wt 220k, Dn Wt 75-70k (block wt 70k) ,Rot wt 128-135k. ECD 12.4-12.6 ppg. Pump 11.0 ppg 140 vis sweep @ 14464' w/ no increase in cuttings. All 83 Lo tads in hole, started HWDP @ 14594'. Directional drill 8 1/2" "D" lateral sands f/ 14780' to 15405' (3194' TVD) ART 3.78 hrs, w/ Sperry Sun Geo-Pilot, 6-20k WOB, 140 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3890-4140 psi, off bottom pressure 3800-4030 psi, on bottom torque 19-21 k ft/Ib, off bottom torque 18-21 k ft/Ib, PU wt 220-235k, Dn Wt 70k (block wt 70k) ,Rot wt 135-138k. ECD 12.6-12.8 ppg. Pump 11.0 ppg 140 vis sweep @ 15116' MD w/ 10% increase in cuttings. 12:00 - 15:30 3.50 DRILL DRLG PROD3 Directional drill 8 1/2" "D" lateral sands f/ 15405' to 15748' (3185' TVD) ART 1.94 hrs, w/ Sperry Sun Geo-Pilot, 10-15k WOB, 140 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 4140-4260 psi, off bottom pressure 4030-4260 psi, on bottom torque 20-23k ft/Ib, off bottom torque 18-21k ft/Ib, PU wt 235-2455k, Dn Wt 70k (block wt 70k) ,Rot wt Printed: 9!30/2005 6:19:05 AM ConocoPhiHips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date ~ From - To ~ Hours ~ Code ~ Code I Phase 9/1/2005 9/2/2005 9/3/2005 12:00 - 15:30 f 3.501 DRILL I DRLG I PROD3 15:30 - 15:45 0.251 DRILL CIRC PROD3 15:45 - 18:00 I 2.251 DRILL I REAM I PROD3 18:00 - 00:00 6.00 DRILL {REAM PROD3 00:00 - 03:00 3.00 DRILL REAM PROD3 03:00 - 05:30 2.50 LOG DLOG PROD3 05:30 - 06:00 0.50 DRILL TRIP PROD3 06:00 - 08:00 2.00 DRILL CIRC PROD3 08:00 - 08:45 0.75 RIGMNT RSRV PROD3 08:45 - 09:45 1.00 RIGMNT RSRV PROD3 09:45 - 14:00 4.25 DRILL TRIP PROD3 14:00 - 14:15 0.25 {DRILL I REAM PROD3 14:15 - 14:45 0.501 DRILL CIRC PROD3 14:45 - 16:30 1.751 RIGMNT RGRP PROD3 16:30 - 16:45 0.25 RIGMNT RGRP PROD3 16:45 - 18:00 1.25 DRILL REAM PROD3 18:00 - 19:00 1.00 DRILL REAM PROD3 19:00 - 20:30 I 1.501 DRILL I CIRC I PROD3 20:30 - 22:00 1.501 DRILL CIRC PROD3 22:00 - 22:15 0.25 DRILL CIRC PROD3 22:15 - 23:15 1.00 DRILL CIRC PROD3 23:15 - 00:00 0.75 DRILL TRIP PROD3 00:00 - 00:45 0.75 DRILL TRIP PROD3 00:45 - 01:30 0.75 DRILL TRIP PROD3 01:30 - 06:00 4.50 DRILL TRIP PROD3 06:00 - 09:30 3.50 DRILL TRIP PROD3 09:30 - 10:00 0.50 DRILL PULD PROD3 10:00 - 10:30 0.50 DRILL SFTY PROD3 10:30 - 12:00 1.50 DRILL OTHR PROD3 12:00 - 13:00 1.00 DRILL PULD PROD3 13:00 - 14:00 1.00 CMPLTN RURD CMPLT3 Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Page 39 of 45 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations 135-142k. ECD 12.6-12.8 ppg. Pump 11.0 ppg 140 vis sweep @ 15702' w/ 30% increase in cuttings. Circ on bottom @ 15748' (3185' TVD) @ 600 gpm w 4240 psi, 140 rpm to move cuttings above BHA. Pump up survey @ 15745'. Backream f/ TD @ 15748' to 14597' @ 600 gpm w/ 4240- 4100 psi, rotate @ 120 rpm, torque 18k ft/Ib. Rotating weight 125k w/ pumps on. Pulling speed 30-40 ft/min. Continue backream f/ TD @ 15748' to 11437' @ 600 gpm w/ 4100-3120 psi, rotate @ 120-180 rpm, torque 18-16k ft11b. PU wt 205-190k. SO wt 85k-98k .Pulling speed 30-40 ft/min. Continue backream f/ 11437'- 9850' @ 600 gpm w/ 3120-3000 psi, rotate @ 180 rpm, torque 16k ft/Ib. Pulling speed 30-40 ft/min. PU wt 180k, SO wt 100k, Rot wt 128k. Record PU & SO wt's. Mad Pass logging f/ 9850' to 9502' bit depth. Logging tool depth 9763' to 9415'. Pumping 600 gpm w/ 2950 psi, 120 rpm, torque 12k. Pull BHA f/ 9502', thru window (9428'-9412'), then up to 9360'. Circ 45 bbls weighted 11 ppg 140 vis sweep, follow w/ 3 bottoms up (1600 bbls), Rotate 120 rpm, 600 gpm w/ 2960 psi. Slip and cut 109' drilling line. Inspect brake bands. Service rig and top drive. Trip in hole on elevators f/ 9360' to 15702'. Pu wt 215k, SO wt 90K. No problems. Fill pipe every 20 stands. Record PU SO wt's. MU top drive, establish circ, precautionary ream f/ 15702'- TD @ 15748'. Pump @ 580 gpm w/ 4190 psi. Circ total of 180 bbls when stand pipe "Y" leaked on rig floor. Blow down mud line. POOH slow while repair leak on stand pipe. POOH f/ 15748' to 14700'. PU wt 260k, SO wt 70k (block wt 70k). Pressure test stand pipe to 4000 psi. OK. Ream in hole f/ 14700' to 15428'. Pump 500 gpm w/ 3800 psi, 120 rpm. Finish reamin back to bottom f/ 14700' to 15748'. Pump 460 gpm w/ 3100 psi, 120 rpm. Torque 12-20k. Circ BU prior to displacing well f/ 9.0 ppg oil base mud to solids free oit base mud. PJSM w/ vac drivers, rig crew and mud engr while circ. Pump 35 bbls spacer, follow w/8.9+ solids free oil base mud. Pump total of 1094 bbls solids free. Shut down. Line up pits to take returns. Take slow pump rates. Continue circ solids free total of 668 bbls pumped. Circ 600 gpm w/ 4200 psi. Monitor well. Drop 2.00" rabbit, POOH f/ 15748' to 14689'. PU wt 300k, SO wt 70K= block wt POOH F/ 14689' to 13990'. Air boot leaking on flow line @ BOP riser. POOH F/ 13990' to 13865' slowly while working to replace air boot on flowline. Changed out (2) 12" air boots. POOH F/ 13865' to 7480'. Ghost reamer and BHA came through window w/ no problems. Monitor well @ window- static. PU wt 220k, SO wt 85k. POOH F/ 7480' to 292'. PU wt 230k, SO wt 85k. L/D HW DP, jars and flex collars. PJSM on unloading nuke sources. Remove sources. Download MWD/LWD tools. L/D tools. Continue L/D tools. Clear floor of handling tools, change elevators, hold PJSM on running Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 40 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Code j Phase 9/3/2005 13:00 - 14:00 1.00 CMPLTN RURD CMPLT3 14:00 - 18:00 4.00 CMPLTN RUNT CMPLT3 18:00 - 19:00 I 1.001 CMPLTNI RUNT I CMPLT3 19:00 - 23:00 4.001 CMPLTNI TRIP CMPLT3 23:00 - 00:00 I 1.001 CMPLTNI TRIP I CMPLT3 9/4/2005 100:00 - 06:00 6.00 CMPLTNI TRIP CMPLT3 06:00 - 07:15 1.251 CMPLTNI TRIP CMPLT3 07:15 - 08:30 ~ 1.251 CMPLTN TRIP ~ CMPLT3 08:30 - 09:00 I 0.501 CMPLTNI OTHR I CMPLT3 09:00 - 10:00 I 1.001 CMPLTNI CIRC I CMPLT3 10:00 - 12:00 2.00 CMPLTN TRIP CMPLT3 12:00 - 12:45 0.75 CMPLTN OTHR CMPLT3 12:45 - 14:15 1.50 CMPLTN TRIP CMPLT3 14:15 - 16:00 1.75 FISH PULD CMPLT3 16:00 - 20:15 4.25 FISH TRIP CMPLT3 20:15 - 20:45 0.501 FISH FISH CMPLT3 20:45 - 21:00 0.251 FISH ~ TRIP CMPLT3 Spud Date: 6/26/2005 Start: 6/22/2005. End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations liner, RU to run liner. Clean floor. Run 5 1/2" "D" lateral completion liner to 6004' (5 1/2" guide shoe, 1 jt 5 1/2" BTCM 15.5 ppf L-80 blankjt, 1 jt 5 1/2" 15.5 BTCM L-80 slotted jt w/insert packoff @ pin end, 138 jts 5 1/2" BTCM 15.5 ppf L-80 slotted pipe). 120k PU wt, 110K SO wt. Torque rings installed in all connections. Continue PU/MU/Run 5 1/2" "D" lateral completion liner f/ 6004' to 6127'. Run 1 5 1/2" BTCM 15.5 ppf L-80 blank pup jt, 1 5 1/2" BTCM 15.5 ppf L-80 blankjt, 7" BTC box x 5 1/2" BTCM pin crossover, 1 jt 7" BTCM 26 ppf L80 blankjt, 1 7" BTCM 26 ppf L-80 blank pup jt, Baker 7" "HR" liner setting Sleeve, Baker running tool. PU wt 125k, SO wt 80k, Block wt 70k. Torque rings installed in all connections. Run liner in hole on 5" dp. Run 5 stands slick, 62 stands w/ to-tads= 67 stands total dp. Record UP/Down and rotating weights @ 6223', 7099', 8089', 8584', 9079', 9376', 10067', 10561', 11056', 11551', 12045', 12539'. PU wt 205k, SO wt =block wt 70K, rot wt 145k. Started rotating 5 1/2" liner in hole @ 12605' w/ 25RPM, 14k torque, string speed 5'/min. Rotate to 12735'. Rotating 5 1/2" liner in hole f/ 12735' to' 14197'w/ 25RPM, 16k torque, string speed 5-10'/min. Recording PU/SO/ Rotating weight @ 13031', 13525', 14012'. PU wt 240k, S0= block wt 70k, rotation 110k w/ slacking off. Rotating 5 1/2" liner in hole f/ 14197' to' 15748' w/ 25RPM, 16k torque, string speed 10-15'/min. Recording PU/SO/ Rotating weight @ 14475' and 14844'. Rotating 5 1/2" liner in hole f/ 14844'- 15748', w/ 25 rpm, 15k torque,string speed 45'/min- 60'/min. Recording PU/SO/ Rotating weight @ 15388' and TD 15748'. PU wt 290K, SO wt 80k, block wt 70k. Tag bottom w/ liner @ 15748' rotating w/ 25RPM. Drop 29/32" ball. Put pipe on depth w/ shoe @ 15736'. Note: Liner was run w/ 5 stands 5" slick dp (476.27'), 74 stands 5" dp w/ IoTads (7316.41'), then 20 stands 5" HWDP (1834.71'), 19' left above Rig floor. Baker guide shoe @ 15, 736.14', top of Baker "HR" setting sleeve @ 9612.71'. Circ 29/32" ball down @ 5bpm w/ 800 psi., slow to 3 bpm w/ 340 psi, pressure to 2400 psi to release liner. Pumped total of 152 bbls 8.9+ SFOBM. Pressure to 4080 psi to blow ball seat. PU to verify liner release. PU wt 245k. SO to check liner depth. Top of "D" lateral Baker 7" liner sleeve @ 9612.71'. POOH w/ Baker liner running tools f/ 9612' to 4500'. Monitor well. Continue POOH f/ 4500'. Clear rig floor of tools. PU Baker Whipstock relieving tools to floor, Make up Baker rertieving hook, 1 jt 5" HWDP, Sperry sun float sub, Baker bumper sub, Baker fishing jar. Total Inth of BHA 62.08'. RIH on 5 stands 5" slick dp, 83 stands 5" dp w/ to tads, 8 stands of HWDP. Fill pipe every 25 stands. PU wt 230k, SO wt110K. Slack off to find keyhole in whipstock @ 9418'. Work/ orient and rotate pipe several times, jar @ 290k, pull to 310, work up to 340K to pull free. Pipe movement @ 300k. Pull top of whipstock f/ 9418' to 9388'. Whipstock assembly consists of Whipstock slide, debris sub, ported sub, shear disconnect, bottom trip Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 41 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date I From - To Hours ' Code Sub phase _ Code! 9/4/2005 20:45 - 21:00 ~ 0.25 ~ FISH TRIP ~ CMPLT3 21:00-23:151 2.251 FISH CIRC (CMPLT3 23:15 - 00:00 0.751 FISH TRIP CMPLT3 9/5/2005 00:00 - 06:00 6.00 FISH TRIP CMPLT3 06:00 - 07:00 I 1.001 FISH I TRIP I CMPLT3 07:00 - 07:15 0.251 FISH SFTY CMPLT3 07:15 - 08:00 0.751 FISH PULD CMPLT3 08:00 - 09:00 1.00 FISH PULD CMPLT3 09:00 - 09:15 0.25 CMPLTN SFTY CMPLT3 09:15 - 10:30 1.25 CMPLTN RURD CMPLT3 10:30 - 11:15 0.75 CMPLTN RUNT CMPLT3 11:15 - 11:30 0.25 CMPLTN KURD CMPLT3 11:30 - 12:00 0.50 CMPLTN RUNT CMPLT3 12:00 - 12:45 0.75 CMPLTN RUNT CMPLT3 12:45 - 13:15 0.501 CMPLTN( PULD CMPLT3 13:15 - 18:00 4.751 CMPLTN( RUNT CMPLT3 18:00 - 18:45 0.751 CMPLTN( RUNT CMPLT3 18:45 - 19:30 0.751 CMPLTN( TRIP CMPLT3 19:30 - 20:15 I 0.75 I CMPLTN( TRIP I CMPLT3 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations anchor, blank sub, (8) jts 5" dp, 5" pup jt (4.18', unloader sub, locator sub, seal assembly w/ bull nose. Total length of whipstock assembly 298.06' Circ 2 bottoms up @ 8 bpm w/ 1000 psi. Get slow pump rates. Circ total 997 bbls. Blow down top drive. PU wt 220-260k. POOH slowly (20ft/min) f/ 9684' (bottom offish) to 9136' Continue POOH slowly(30-45 ft/min) with whipstock assembly from 9136' to 1135'. Continue POOH slowly(30-45 ft/min) with whipstock assembly from 9136' to 362'. PJSM w/ Baker rep, rig crew and CPA( rep on laying down whipstock assembly. L/D Jars, bumper sub, float sub, jt of 5" HWDP, hook. Secure whipstock slide @ rotary table. UD Baker whipstock slide, debris sub, ported sub, shear disconnectm bottom trip anchor, blank sub. UD 8 jts 5" dp, 5" pup jt, unloader sub, locator sub, seal assembly w/ bull nose. Clear rig floor of tools. PJSM on running Baker hook Hanger assembly. RU to run Baker hook Hanger assembly. RU to run Baker hook Hanger assembly consisting of: (1) jt 5 1/2" 15.5 ppf L-80 BTCM bent joint, (1) jt 5.5" BTCM 15.5ppf L-80 , (1) 5.5" BTCM 15.5 ppf L-80 pup jt, Baker Pay Zone external casing Packer, (3) 5.5" BTCM 15.5 ppf L-80 pup jt, (2) jts 5 1/2" BTCM 15.5 ppf L-80, (1) 5.5" BTCM 15.5 ppf L-80 pup jt, crossover bushing, Baker 9 5/8" x 7" Model B-1 Hook Hanger f/ LEM. Total length = 250.31' to leave in hole. Torque to 5k, install (2) 5 1/2" x 8 1/4" x 8" straight blade centralizers on pup jt above handling pup on ECP and pup below ECP. PU 2 7/8" handling tools to floor, RU same. MU 2 7/8" inner string per Baker rep. Total length 217'. Change out elevators and MU Baker 9 5/8" x 7" Model B-1 hook hanger. Change out elevators. MU crossover to 5" drill pipe. Clear rig floor of casing tools. RIH w/ hook hanger (70 feet per min) on 5". Run (5) stands slick 476.27', (74) stands 5" DP w! LoTads 7316.41', (8) stands 5" HWDP 739.24'= total depth of 8789'. Continue RIH w/ hook hanger (70 feet per min) on 5". Run (5) stands slick 476.27', (74) stands 5" DP w/ LoTads 7316.41', (19) stands 5" HWDP 1741.95' = 9791.98' w/ 60.6' up = 9731'. Tag upon crossover in "B" lateral. (2.5' deep). POOH 4 stands f/ 9731' to 9412'. Screw into stand #94, PU w/ mule shoe 5' above window. Rotate 4 rounds to right w/ max torque 10k ft/Ib. Hold torque, slack off, hit bottom of window with centralizer 90' in on stand#95. This puts bottom of window 4' deep. PU, work pipe until centralizer went through. Continue in hole, hit top centralizer 35.5' in on stand #96 Work centralizer to get by window. (window 4' deep) Hook window @ 9433 w/ baker hook hanger. PU stand #97. PU wt 255k, SO wt 120k. Slackoff, tag mule shoe60' in on stand #97. Pickup 20', rotate 3 rounds to right, max torque 8k ft/Ibs, work pipe & slack off,tag crossover @ 60' in. Pickup, rotate one round, work pipe, slackoff. Hang hook hanger 55' in on stand #97 w/ 40k down. PU 15', rotate 3 rounds to right, max torque 8k fUlb.Slackoff & tag crossover 60' Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 42 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours ~'I Code 'Code Phase Description of Operations 9/5/2005 19:30 - 20:15 0.751 CMPLTNI TRIP CMPLT3 20:15 - 20:45 I 0.50 I CMPLTNI OTHR I CMPLT3 20:45 - 21:30 I 0.75 I CMPLTNI CIRC I CMPLT3 21:30 - 00:00 2.50 CMPLTN TRIP CMPLT3 9/6/2005 00:00 - 02:00 2.00 CMPLTN TRIP CMPLT3 02:00 - 02:15 0.25 CMPLTN SFTY CMPLT3 02:15 - 02:30 0.25 CMPLTN OTHR CMPLT3 02:30 - 03:30 1.00 CMPLTN PULD CMPLT3 03:30 - 04:30 1.00 CMPLTN PULD CMPLT3 04:30 - 04:45 0.25 CMPLTN SFTY CMPLT3 04:45 - 06:00 1.25 CMPLTN PULD CMPLT3 06:00 - 06:45 0.75 CMPLTN PULD CMPLT3 06:45 - 07:00 0.25 CMPLTN PULD CMPLT3 07:00 - 07:15 0.25 CMPLTN OTHR CMPLT3 07:15 - 12:45 5.50 CMPLTN TRIP CMPLT3 12:45 - 13:00 0.251 CMPLTNI TRIP CMPLT3 13:00 - 13:15 I 0.251 CMPLTNI OTHR I CMPLT3 13:15 - 13:45 I 0.501 CMPLTNI CIRC I CMPLT3 13:45 - 14:00 I 0.251 CMPLTNI PCKR I CMPLT3 14:00 - 14:15 I 0.251 CMPLTNI OTHR I CMPLT3 in. PU 20', rotate 2 rounds to right with max torque 7k fUlb. Work pipe and slackoff, tag crossover 60' in. PU 20', rotate one round, max torque 6k ft/Ib. Work pipe. Slack off, hung hook hanger@ 55' in, set down 40k. PU, took 20k overpull to unhook hanger. Slack off. Hooked @ 55' in w/ 40k down wt. (5' deep) Drop 29/32" ball, fill pipe then pumped 6 bbls & pressured up. Stopped pumping @ 1800 psi. Bleed off, pressure to 1500 psi. Zero stroke counter. Pressure up to 2000 psi w/ 3 strokes. Pressure up to 2500 psi w/ 3 more strokes. pressure to 2800 psiw/ 2 more strokes. Pressure to 2900 psi w/ 2 more strokes and ECP opened. Allow pressure to bleed back to 2700 psi & held pressure. Pressure back up to 2500 psi w/ 3 strokes (.3 bbls to inflate). Pressure up to 4000 psi, bleed off pressure. PU to Free travel @ 250k. Pull 2 stands to 9246'. Circulate @ 5bpm w/ 400 psi, circ 100 bbls. POOH w/ hook hanger running tools f/ 9260' to 4493'. POOH w/ hook hanger running tools f/ 4493' to BHA inner string PJSM on UD inner string 2 7/8" Clean rig floor. UD 2 7/8" inner string. Clear floor of tools. PU tools to PU 4 1/2" LEM. PJSM on running 4 1/2" LEM f/ "D" lateral. PU/MU 4 1/2" LEM consisting of :Baker seal assembly, (1) jt 4 1/2" 12.6 ppg L-80 IBT x STL, (7) jts 4 1/2" 12.6ppf L-80 IBTM tubing, 4 1/2" pup jt, LEM, (3) 4 1/2" pup jts, 4 1/2" casing swivel, crossover bushing 5 1/2 563 x 4 1/2" IBT, 190-47 casing seal bore, crossover 7" x 5 1/2" 563, (1) jt 7" 26 ppf, L80 Hydril 563 casing Make up 2 7/8" inner string to 9 5/8" x 7" ZXP liner top packer. Make up 9 5/8" x7" ZXP liner top packer, Check screws. OK. Clean rig floor, remove csg tools. RIH on 5" dp : 4 1/2" LEM consisting of :Baker seal assembly, (1) jt 4 1!2" 12.6 ppg L-80 IBT x STL, (7) jts 4 1/2" 12.6ppf L-80 IBTM tubing, 4 1/2" pup jt, LEM, (3) 4 1/2" pup jts, 4 1/2" casing swivel, crossover bushing 5 1/2 563 x 4 1/2" IBT, 190-47 casing seal bore, crossover 7" x 5 1/2" 563, (1) jt 7" 26 ppf, L80 Hydril 563 casing, Baker 9 5/8" x 7" ZXP liner top packer = 430.62' then Baker setting tool and 5' dp pup jt. Total of 441.59'. RIH 5 stands 5" slick (476.27', 74 stands 5" dp w/ to-tads (7316.41'), 12 stands 5" HWDP(1105.62') w/ 21.1' up. PU wt 230k, SO wt 120k. Slack off watching top of "D" lateral @ 9412.28' (did not see anything), Continue running stands of HWDP f/derrick. Run stand 92, 93,94,95, and 96. PU wt 245k, SO wt 125k. Continue RIH w/ stand 96 (17th stand of HWDP). Did not see crossover in "B" lateral @ 21' in (9728'),.continue slack off to latch @ 37' in on stand 96 (9739' mule shoe depth) (9412,28' top of LEM in hook hanger of "D" lateral). Top of Casing seal receptacle in "B" lat LEM a 9729.91', bottom of casing seal receptacle @ 9749.31'. PU to 265k to verify latch. Drop 1 3/4" ball, pump down @ 5bpm w/ 500 psi f/ 100 bbls, slow to 3 bpm 300 psi, ball seated @ 120 bbls pumped. Pressure up to 3080 psi, set Baker ZXP packer @ 9308.62', presure to 4000 psi to release. PU, PU wt 240K-245K (verified release). PU 20' f/ 9308' to 9288'. Slack off 40k down w/ dogs to mech set packer as well. PU 20' rotate down w/ 40k on liner top pkr twice. Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 43 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophi{lips.com Rig Name: Doyon 15 Date 'From - To ' Hours I Code i Sub phase Code) 9/6/2005 14:15 - 16:00 1.75 CMPLTN TRIP CMPLT3 16:00 - 22:00 6.00 RIGMNT RGRP CMPLT3 22:00 - 22:30 0.50 CMPLTN TRIP CMPLT3 22:30 - 00:00 1.501 CMPLTNI TRIP CMPLT3 9/7/2005 00:00 - 03:00 3.00 CMPLTN TRIP CMPLT3 03:00 - 03:15 0.25 CMPLTN SFTY CMPLT3 03:15 - 04:00 0.75 CMPLTN PULD CMPLT3 04:00 - 05:00 1.00 CMPLTN OTHR CMPLT3 05:00 - 05:15 0.25 CMPLTN SFTY CMPLT3 05:15 - 06:00 0.751 CMPLTNI PULD CMPLT3 06:00 - 08:45 I 2.751 CMPLTNI PULD I CMPLT3 08:45 - 13:45 I 5.001 RIGMNTI RGRP I CMPLT3 13:45 - 14:45 1.00 RIGMNT RSRV CMPLT3 14:45 - 15:15 0.50 CMPLTN PULD CMPLT3 15:15 - 18:00 I 2.751 CMPLTNI PULD CMPLT3 18:00 - 19:45 1.751 CMPLTNI PULD CMPLT3 19:45 - 20:00 I 0.251 CMPLTNI OTHR I CMPLT3 20:00 - 20:30 0.501 CMPLTNI PCKR CMPLT3 20:30 - 21:00 I 0.501 CMPLTNI PCKR I CMPLT3 21:00 - 23:00 I 2.001 CMPLTNI CIRC I CMPLT3 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Monitor well, POOH w/ running tools f/ LEM f/ 9308' to 8135'. PU wt 245k, SO wt 120k. Attempt to break out 1st stand LoTad. High torque 30k. Broke 1st Lo Tad w/ rig tongs w/ 30K. Repair/ replace top cylinder of iron roughneck breakout. POOH f/ 8135 to 7938'. Check out Iron roughneck by making breaks on stand 78, OK. Break & UD LoTad f/ stand 78. Pull stand 79, break and lay down LoTad f/ stand simulating laying down dp f/derrick and removing LoTads. OK. Continue POOH f/ 7938' to 5964'. 51 stands Lotads in hole @ midnight Continue POOH f/ 5964' to 80' 51 stands Lotads in hole. PJSM on UD LEM tools. UD LEM running tools. Pull Vetco/Gray wear bushing, clear rig floor. PJSM on PU 7" Baker Model WG Bridge plug and Baker Heavy duty Model "EA" retrievamatic, w/ 3 1/2" IF joint and 3 1/2" HT38 DP. MU 7" Baker Model WG Retievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1!2" IF x 3 1/2 HT38, 3 1/2" HT38 DP. One joint made up @ 0600 hrs. Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 1!2" 13.3 dp 3 1!2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 HT38, on 71 joints 3 1/2" 13.3ppf HT38. Rabbit dp to 2 5/16". Torque 3 1/2" IF Conn to 10k, HT38 Conn to 16.5k ft/Ib. Trouble shoot and repair of pipe handling machine. Selonoid valve and spool Slip & cut 136' drilling line. Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 HT38, on 71 joints 3 1/2" 13.3ppf HT38, then start w/ 3 1/2" 15.5 ppf HT38, 44 jts of 15.5 ppf in hole now. Total of 115 jts HT in hole. Rabbit dp to 2 5/16". Torque HT38 Conn to 16.5k ft/Ib. Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 HT38, on 71 joints 3 1/2" 13.3ppf HT38, then start w/ 3 1/2" 15.5 ppf HT38, 167 jts of 15.5 ppf in hole now. Total of 238 jts HT in hole. Continue RIH w/ 7" Baker Model WG Retievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 HT38, on 71 joints 3 1/2" 13.3ppf HT38, then start w/ 3 1/2" 15.5 ppf HT38, 167 jts of 15.5 ppf in hole now. Total of 295 jts HT Picked up. Tag 9.04' in on jt # 295. PU wt 165k, SO wt 75k. MU crossover on jt 295, MU top drive and tag top of liner @ 9308' (9.04' in on jt 295), bottom of bridge plug @ 9354.94'. PU, 8reak off single and drop 1-1/2" ball. MU single, SO tag liner top, PU 6' above tag, circ ball to seat @ 3bpm w/ 700 psi. Pressure up @ 50 bbls pumped. Pressure to 2300 psi. Pick up to 180k, shear off of bridge plug. Bridge plug top @ 9346.24', bottom @ 9348.94". Length of bridge plug 2.70' UD 2 jts, PU jt w/ x-o, MU top drive.Jt # 293 in hole while testing, jt 294 above rig floor. 9308' bottom of tool Circulate bottoms up @ 5bpm w/ 1880 psi. Circ 600 bbls. Printed: 9/30/2005 6:19:05 AM • • ConocoPhiilips Alaska Page 44 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date % From - To I Hours I Code Code I Phase 9!7!2005 123:00 - 23:15 0.25~CMPLTN~DEOT I CMPLT3 23:15 - 00:00 I 0.751 CMPLTNI DEQT CMPLT3 19/8/2005 100:00 - 00:30 0.50.1 CMPLTNI DEOT CMPLT3 00:30 - 02:00 I 1.501 CMPLTNI TRIP I CMPLT3 02:00 - 02:30 I 0.501 CMPLTNI TRIP CMPLT3 02:30 - 03:00 I 0.501 CMPLTNI DEQT CMPLT3 03:00 - 03:45 I 0.751 CMPLTNI DEQT I CMPLT3 03:45 - 04:00 0.25 CMPLTN OTHR CMPLT3 04:00 - 04:30 0.50 CMPLTN TRIP CMPLT3 04:30 - 05:15 0.75 CMPLTN TRIP CMPLT3 05:15 - 07:30 I 2.251 CMPLTNI OTHR CMPLT3 07:30 - 08:00 0.50 CMPLTN SFTY CMPLT3 08:00 - 10:00 2.00 CMPLTN CIRC CMPLT3 10:00 - 13:00 I 3.00 I CMPLTNI OTHR CMPLT3 13:00 - 13:30 0.50 CMPLTN SFTY CMPLT3 13:30 - 14:15 0.75 CMPLTN CIRC CMPLT3 14:15 - 14:30 0.25 CMPLTN TRIP CMPLT3 14:30 - 15:00 0.50 CMPLTN SOHO CMPLT3 15:00 - 15:15 0.25 CMPLTN SOHO CMPLT3 15:15 - 15:45 0.50 CMPLTN DEQT CMPLT3 15:45 - 16:00 0.25 CMPLTN OTHR CMPLT3 16:00 - 16:30 0.50 DRILL SFTY CMPLT3 16:30 - 18:00 1.501 DRILL PULD CMPLT3 18:00 - 19:30 1.50 DRILL PULD CMPLT3 19:30 - 21:30 2.00 DRILL PULD CMPLT3 21:30 - 00:00 9/9/2005 00:00 - 00:30 ~ 00:30 - 06:00 2.50 RIGMNT RGRP CMPLT3 0.50 RIGMNT RGRP CMPLT3 5.50 DRILL PULD CMPLT3 06:00 - 10:30 4.501 DRILL I PULD I CMPLT3 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10!2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations RU to test Baker 7" Model WG Retrievable bridge plug set @ 9346.24' , ZXP liner top packer @ 9308' w/ test pkr @ 9259'. Rotate 5 turns to set packer. Set down 5k. Attempt to test Retrievable bridge plug. No test. PKR depth 9259'. Not enough weight to set test pkr. Circulating to surface. Attempt to test Retrievable bridge plug &ZXP packer. No test. PKR depth 9259'. Not enough weight to set test pkr. Only 5k above block weight. Circulating to surface. POOH L/d 5 jts of 3 1/2" 15.5 ppf XT38 dp. Stand back 11 stands in derrick to 8211' Trip in hole w/ 11 stands 5" HWDP f! 8211' to 9090'. 10 stands HW in hole. PU wt 190k. SO wt 105k. RIH f/ 9090' to 9163' (element center @ 9114'). Apply 5 rounds RH w! 8k torque. Set test packer w/ 35k down wt to 70k block wt. Attempt to test, no test, PU to 9114', set 35k down wt. Test RBP @ 9346', ZXP liner top packer @ 9308' w/ test packer @ 9114'. Test to 2540 psi. Chart test. Held 97.3% of test pressure in 30 min. Pressure lost 68 psi f/ 2540 to 2472 psi. Bleed off pressure, unset packer. POOH f/ 9114' to 8170' w/ 5" HWDP. UD single 3 1/2" DP, TIH 11 stands 3 1/2" dp, PU 4 jts 3 1/2" dp. Total of 293 jts 3 1/2" in hole 27' up.=9308'. Flush surface lines, cement line, geopilot skid, kill and choke lines and manifold. PJSM on displacing f/ 9.0 ppg SFOBM to 9.6 ppg Sodium Chloride. Displace 9.0 ppg SFOBM to 9.6 ppg Sodium Chloride. Pump @ 6 bpm w/ 1540 psi. Pump a total of 6285 strokes (632 bbls). Cleaning on rig floor, transfer mud f/ rock washer while wait on brine to be brought over f/ mud plant in Prudhoe. RU truck of 290 bbls 9.6 brine. PJSM w/ crew. Fluid transfer paperwork. Pump 290 bbls 9.6 ppg Sodium Chloride @ 6 bpm w/ 1540 psi. POOH 3 jt 3 1/2" 15.5 ppf S-135 HT38 dp. 290 jts left in hole total. PU/MU Vetco/Gray 13 3/8" x 4 1/2" MB222, 13 1/2" OD hanger w/ dummy installed as penetrator and two way check installed in hanger. MU to 4 1/2" landing joint w/ 4.909 MCA connection on top of hanger. Drain BOP stack to land kill string w/ running tool f/ 7" retrievalble bridge plug on bottom @ 9287.23' Run in LDS on Vetco Gray hanger. Test lower body seals to 5000 psi f/ 10 min. OK. Test upper body seals to 5000 psi f/ 10 min. OK. Back out landing joint. UD same. PJSM. Install mouse hole. Rig up to L/D 5" dp f/derrick. Have Total 170 stands 5" DP in derrick. 20 stands 5" HWDP, 83 stands w! LoTads, 67 stands slick. Cleaning fluids f/ pits and rock washer. L/D total of 13 stands 5" HWDP. Cleaning fluids f/ pits and rock washer. L/D total of 7 stands 5" HWDP. Cleaning fluids f/ pits and rockwasher. UD 5" DP w! LoTads. Total of 83 to UD. UD 17 stands @ 1930 hrs.. Cleaning fluids f/ pits and rockwasher. Pull Hyd cyl f/ pipe spinner on iron roughneck f/ repair. Pull Hyd cyl f/ pipe spinner on iron roughneck f/ repair. L/D 5" DP w/ LoTads. Total of 83 to UD. UD total of 42 stands @ 0600 hrs. Cleaning fluids f/ pits and rockwasher. UD 5" DP w/ LoTads. Total of 83 to UD. UD total of 53 stands @ 1030 Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING" Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date ;From - To lil Hours ', Code Cade , Phase 9/9/2005 06:00 - 10:30 4.50 DRILL PULD CMPLT3 10:30 - 11:30 1.00 RIGMNT RGRP CMPLT3 11:30 - 12:30 1.00 RIGMNT RSRV CMPLT3 12:30 - 13:00 0.50 DRILL PULD CMPLT3 13:00 - 15:00 2.00 RIGMNT RGRP CMPLT3 15:00 - 18:00 3.00 DRILL PULD CMPLT3 18:00 - 20:00 ~ 2.001 DRILL PULD CMPLT3 20:00 - 00:00 4.00 DRILL PULD CMPLT3 9/10/2005 00:00 - 03:15 3.25 DRILL PULD CMPLT3 03:15 - 05:00 1.75 DRILL ~ PULD CMPLT3 05:00 - 06:00 1.00 WELCT NUND CMPLT3 06:00 - 11:30 5.501 WELCTL NUND CMPLT3 11:30 - 15:00 3.50 WELCT NUND CMPLT3 15:00 - 16:30 1.50 WELCT NUND CMPLT3 16:30 - 18:00 1.50 WELCT EQRP CMPLT3 18:00 - 21:00 3.00 WELCT EQRP CMPLT3 21:00 - 22:30 I 1.501 WELCTU EQRP I CMPLT3 22:30 - 00:00 1.501 DRILL OTHR CMPLT3 Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Page 45 of 45 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations hrs. Cleaning fluids f/ pits and rockwasher. Replace pipe spinners on iron roughneck. Cleaning fluids f/ pits and rockwasher. Service rig. L/D 5" DP w/ LoTads. Total of 83 to UD. UD total of 55 stands @ 1300 hrs. Cleaning fluids f/ pits and rockwasher. Replace lower dies in iron roughneck lower jaw. Could not get die retainer loose f/ iron roughneck easily. L/D 5" DP w/ LoTads. Total of 83 to UD. UD total of 74 stands @ 1800 hrs. Cleaning fluids f/ pits and rockwasher. L/D 5" DP w/ LoTads. Total of 83 to UD. UD total of 83 stands @ 1800 hrs. All LoTads are Layed down. Cleaning fluids f/ pits and rockwasher. Blow down mud lines in pits. Clean rock washer pits. UD 5" DP. Total of 67 to L/D. UD total of 31 stands @ Midnight. Cleaning fluids f/ pits and rockwasher. UD 5" DP. Total of 67 to L/D. UD total of 67 stands @ 0315 hrs. Cleaning fluids f/ pits and rockwasher. UD mousehole, L/D pipe spinners (xtra), UD 8 1/2" ghost reamer, clean and L/D Sperry Sun geo pilot Disconnect kill and choke lines. Prep to nipple down BOPE. Cleaning ng floor. Clean pipe racks, nipple down BOPE. Move rock washer away f/ rig modules, stage on 1E pad. RU and nipple up Vetco Gray tree. Continue nippling up Vetco Gray tree. Test void to 5000 psi f/ 10 min. Leak on bleeder threads on tree cap flange. Test against swab valve to 5000 psi.OK. Note: Disconnect f/ HI LINE power @ 1500 hrs. Switch to rig power Prep rig floor for skidding rig. Rig down all complexes for rig move. Blow down steam to pit module. turn tires & prepare to move pit module. Fold in beaver slide and secure same. Change out 9" Otis tree cap on Vetco Gray 4 1/6" 5m flange. Leak on 1" NPT fitting on flange(galled threads). Use tree cap F/ 1J168 well. Reinstall tree cap, test to 250 psi low f/ 10 min. OK. Test to 5000 psi high f/ 10 min. OK. Secure well. PU tools in cellar. Release rig @ midnight 9/10/2005. f/ 5.1 mile move f/ 1 E-170 to 1 C-28. Move pits off of mats, move mats f/ pit module and spot on road. Blow down steam to sub module. Printed: 9/30/2005 6:19:05 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: WORKOVER/RECOMP Contractor Name: N3SCM@conocophillips.com Rig Name: Nabors 3S Date 10/17/2005 '~ From - To ' Hours ' Code 'Sub ;phase Code ~_ _ _ __ 00:00 - 08:30 08:30 - 11:00 11:00 - 11:30 11:30 - 17:30 17:30 - 18:30 118:30 - 00:00 10/18/2005 00:00 - 01:00 01:00 - 03:00 03:00 - 06:00 106:00 - 12:00 (',12:00 - 19:00 19:00 - 20:00 20:00 - 21:30 21:30 - 00:00 10/19/2005 00:00 - 01:00 01:00 - 02:00 02:00 - 06:30 i 06:30 - 10:30 10!2012005 I 10:30 - 13:00 I 13:00 - 19:00 19:00 - 22:30 22:30 - 00:00 00:00 - 05:30 05:30 - 07:00 8.501 MOVE RURD 2.501 MOVE RURD 0.501 WELCTL( NUND 6.001 WELCTL BOPE 1.00 WELCTLSFTY 5.50' WELCTLIBOPE 1.00' WELCT BOPE 2.00 WELLS PLGM 3.00 WELLSF~ RURD 6.001 FISH PULL 7.00 `FISH PULL i 1.00. WELLSFa RURD 1.501 FISH I, PULL 2.50 FISH PULL 1.00 WELLSR,RURD 1.00 WELLS ~ RURD 4.50,1 WELLS RURD 4.00 WELLS~TRIP I 2.50 ~ WELLSF~ TRIP I 6.00 WELLSF~TRIP it 3.50 LOG RURD 1.50' LOG ~ ELOG 5.50 ~i LOG ELOG 1.50,'LOG PULD MOVE MOVE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Page 1 of 14 Spud Date: 6!26/2005 Start: 10/17/2005 End: 11/13/2005 Rig Release: 11/13/2005 Group: Rig Number: Description of Operations ~, Rig on location, line rig up with well head and locate position for rig mats and containment. Pull rig forward, spot rig mats and layout ~, Herculite for containment. Spot rig over well. Connect modules (pipe 'shed & pits). Raise derrick, connect all lines and secure rig. Accept rig @ 1100 hrs 10/17/2005. Raise derrick, connect all lines and secure rig. Accept rig @ 1100 hrs 10/17/2005. NU BOPE. (13-5/8" stack.)Verify well is dead, Pu-I BPV, install two way check. Held pre-spud meeting with both crews. Test BOP's to 250/3000 psi, annular to to 250/2500 psi. Chuck Sheve with (AOGCC) waived BOP test. Complete BOP test. Drain BOP stack. Pull two way check Make up landing joint to tubing hanger. Back out lock down studs. Unland tubing hanger at 95k up weight. Lay down landing joint, tubing hanger with one joint of 4.5" tubing below hanger. Begin POOH w/ 3.5" HT38 drill pipe with test packer to 5000'. Standing back and strapping drill pipe in derrick to ensure the exact location of leak. :Hunting hole in 9 5/8" casing with test packer and 3.5" HT38 DP. Found two leaks one at 4' out on jt.137 approximate depth 4863' MD. Isolated second leak to be at 20' out on jt 190 or about 4769' MD tested bottom of top leak and found it to be less than 5' lower or 4774' MD. Depths are approximate until we strap out and measure the sealing elements on test packer. Top leak communicated with OA 13 5/8 by 9 5/8 immediately. This means we would need to span 94' of leaks. Lay down head pin Begin POOH w/ 3.5" HT38 drill pipe with test packer. Standing back and strapping drill pipe in derrick to confirm leak depths. Continue OOH w/drill pipe. On surface with drill pipe and test packer. Lay down BHA (test packer assembly) Install wear ring Make up scraper run BHA 'After back strapping out of hole with kill string leak depths where determined to be (bottom leak 4861'-4856' RKB 2 BPM @ 910 PSI top leak 4757'-4752' RKB we could not establish a rate as we where not rigged up to cir). The OA but we could pump @ 2BPM threw the leak) overall length of 109' of bad pipe. BHA made up 217' total length i consisting of 8" Casing Scraper, 8 5/8" String mill, Bit Sub, Bumper Sub, Oil Jar, 6-6" Drill Collars and Drill Pipe to surface. Start running in the hole with Scraper run to 5000' MD with 3.5" HT38 DP. On depth with scraper run. Work threw squeeze depth could not see '.any indications of tightness. Work up and down and Circulate long way i 1.5 bottoms up 4.5 BPM @ 420 psi Bottoms up circulation completed. Pulf out of hole with scraper run 'I standing back Drill Pipe. Rig-up E-line for USIT log to 5500' with wireline tractor. Had trouble (function testing tools on surface. Finally got good function test. RIH w/ USIT log assembly with tractor to 5500' 'i Continue E-line USIT log with tractor to 5500'. Rig DWN Schlumberger and Clear rig floor. Prepare to re-rig return Printed: 11/22/2005 9:48:25 AM ConocoPhillips Alaska Page 2 of 14 Operations Summary Report Legal Well Name: 1E-170 Common Well Name: 1 E-170 Spud Date: 6!26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours ' Code 'Code' Phase Description of Operations _i _ _ _.. _ __ _ __ __ _ __ - ___ __ _ _ - _ __ _- 10/20l2005 05:30 - 07:00 1.50 ~ LOG PULD ~, 07:00 - 09:00 2.00 I WELCTL NUND DECOMP I' lines from OA. I, Re-rig harline to tanks for circulation step rate test from 9 5/8" to 13 3/8" 09:00 - 10:30 10/21 /2005 10:30 - 11:30 11:30 - 12:00 12:00 - 13:30 13:30 - 15:30 15:30 - 18:00 18:00 - 21:30 21:30 - 23:00 23:00 - 00:00 00:00 - 02:00 1.50 1.00 0.50 1.50 2.00 2.50 3.50 1.50 1.00 z.oo CMPL CMPL 02:00 - 05:30 ~ 3.50 05:30 - 07:30 2.00 07:30 - 08:00 '', 0.501 08:00 - 09:30 ~'I 1.501 09:30 - 12:00 I'I 2.501 12:00 - 15:15 ' 3.25 15:15 - 15:45 ~ 0.50'1 15:45 - 16:25 0.67 ~ 50 II 16 25 18 2 42 : - : 18:50 - 19:50 I '1 1.00 ~, 19:50 - 20:20 ' 0.501 20:20 - 22:00 ! 1.67: 'casing. Surrrl up new 70 BBL returns tank. CIRC DECOMP Begin circulation step rate test. 1 BPM 9 5/8" = 50 13 3/8" = 400 2 BPM 9 5/8" = 160 13 3/8" = 400 3 BPM 9 5/8" = 220 13 3/8" = 400 4 BPM 9 5/8" = 270 13 3/8" = 400 Maintained 400 PSI on the OA to stay 75 PSI over ISIP Returns = 1-1 throughout step rate test. Re-freeze protected OA with 65 BBLS diesel. Utilized 41 BBLS during test, and added 24 BBLS for good measure. NUND ' DECOMP Rig up Hot oil for the freeze protect. Pump freeze protect EQIP DECOMP , Change of scope. Call out Baker RBP w/sand plug for isolation of lower wellbore. Clean rig floor. EQIP DECOMP Continue to STBY for Baker. SFTY ' WRKOVR Nabors management meeting with hourly employees to discuss issues ',within the ranks. TRIP WRKOVR Pick up Baker RBP asym with tubing stop. Baker RBP 8.22" OD, :tubing stop @ 8.5" OD aprox 680' above RBP. Begin RIH. TRIP i WRKOVR ' Located liner lap @ 25.5" in on stand number 87 (4850'). Pulled stand .number 87. PLGM i WRKOVR Set Baker RBP. Top of plug @ 5445'. Rig-up head pin. Rig-up ;Schlumberger pump truck to lay sand plug above RBP. PLGM i WRKOVR i Held PJSM. Mix sand for sand plug. PLGM WRKOVR Release from RBP. Pressure test Schlumberger equipment and lines to 13000 psi. Pump 18.5 bbls sandlgelling/antifoam agent followed by 34 bbls brine from pits @ 3 bpm (550 psi). Rig down pump Schlumberger. Remove head pin. Pull four stands. Slight over balance on outside of DP after pumping sand plug. Reverse circulate 40 bbls brine. TRIP WRKOVR I, POOH w! 3.5" DP and Baker retrieving head. Pick up circulating head I and circulate bottoms up due to pulling wet. TRIP WRKOVR !Continue to POOH. Monitoring hole conditions. PULD ~ WRKOVR '~ Lay down running tools for RBP. Clear rig floor and prepare to RBIH for ~ HES cement retainer deployment. PULD I WRKOVR '~ Pick up HES cement retainer and prepare to RBIH. Installed 10ea. 5K ,shear pins into retainer. Tool string data in pipe tally. Hole conditions 'I are stable. TRIP WRKOVR 'Continue to RIH. PLGM WRKOVR Set HES cement retainer @ 4,672' RKB. Rotate 26 turns to the right ,'and witnessed 4 turns of reactive torque. CIRC WRKOVR ~I Pressure test drill pipe by 9 5/8" ann to 1,000 PSI. Pressure test good. Unsting from retainer and circulate. 2 BPM @ 145 PSI. returns 1-1 CIRC WRKOVR 1~ Drill pipe and 9 5/8" ann no longer pressure testing. Returns to surface instantly after pump initiation. Initial test held. Not sure what has happened. CIRC ' WRKOVR jAfter several attempts to reseal HES cement retainer perform injection 'test. 2 BPM @ 970 PSI on the OA while bullheading. Discuss with /Anchorage about continuing program as per plan with extra caution. SFTY ~ WRKOVR ;Discuss with all personal, job issues and safety concerns. Call out little red for a OA injection test. CIRC ~ WRKOVR .Little Red on location. CIRC WRKOVR j Rig-up LRS on IA. PT lines 2500#. Verify if check in retainer is holding. I Printed: 11/22/2005 9:48:25 AM r~ ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: WORKOVER/RECOMP Contractor Name: N3SCM@conocophillips.com Rig Name: Nabors 3S Date 10/21/2005 From - To Hours ' Code 'Sub ', 'Code 20:20 - 22:00 22:00 - 23:00 23:00 - 00:00 10/22/2005 00:00 - 03:00 ' 03:00 - 07:30 07:30 - 12:30 , i 12:30 - 15:30 15:30 - 16:30 ~ 16:30 - 21:30 21:30 - 00:00 10!2312005 ~ 00:00 - 02:00 02:00 - 04:00 04:00 - 05:30 05:30 - 09:00 j 09:00 - 09:15 j 09:15 - 11:30 111:30 - 13:30 13:30 - 14:30 I 1.671 WELL 1.00 CEME CIRC 'PULD Phase WRKOVR WRKOVR 1.00 ~ WELLSR CIRC ' WRKOVR 3.00 ~ WELLS CIRC WRKOVR 4.50 WELLS~TRIP iWRKOVR 5.00; WELLS RURD WRKOVR 3.OO~WELLSf~TRIP 'WRKOVR 1.00 WELLSF~TRIP WRKOVR 5.00 WELLSaTRIP ~~WRKOVR 2.501 WELLSF~ PULD i WRKOVR 2.OO WELLS~TRIP !WRKOVR 2.00 I WELLSF~ MILL 1.501 WELLSF~ MILL 3.50' WELLS CIRC 0.251 WELLSR' DEOT 2.25;1 WELLSf?~MILL 2.00'1 WELLSF~CIRC 1.0011 WELLSf~ CIRC WRKOVR W RKOVR WRKOVR WRKOVR WRKOVR W RKOVR WRKOVR Page 3 of 14 Spud Date: 6/26/2005 Start: 10/17/2005 End: 11/13/2005 Rig Release: 11/13/2005 Group: Rig Number: Description of Operations ~~Able to get return up DP, test failed, Rig down LRS PJSM. PT lines to 4000 psi. Pump 5 bbls water. Stab stinger into cement retainer. Start pumping cement. Pumped ZO bbls initally at 3 ,bpm 540 psi, starting OA pressure 320 psi, then closed bag. Got 'another 15 bbls away, pressure started bluilding. After 37 bbls cement away, pressure spiked to 3700 psi, shut down pump. Appears retainer is plugged, bleed pressure off. Sting out of retainer, open annular, start 'pumping water, sting back into retainer, pump 5 bbls water, pressure spiked to 2000 psi. Bleed off, open pipe rams, sting out of retainer, rig down cement crew. Circulate cement out of DP and well bore. ,Circulate hole clean long way, total of 400 bbls. Rig down head pin. ' POOH w! 3.5" DP and cement retainer stinger Out of hole with cement string bottom hole assemble complete with stinger. Rig up Kelley in preparation to run in the hole and drill out retainer and cement. Cement retainer stinger after being taken apart at HES shop was full of sand. Rig up BHA to drill out cement retainer and cement. BHA consisting of. 8.5" tri cone Bit, two 7" Boot Baskets, One 8.5" Stabilizer, One 6.25" 'Drill Collar, One 6.25" Bumper Sub, One 6.25" 11.58' Oil Jar, Three jts. Of Heavy Wall 3.5" HT38 Drill Pipe. 'BHA picked up and ready to start in the hole with. 56 Stands of 3.5" HT-38 Drill Pipe, 12 jts. of Heavy Wall Drill Pipe, 9 Stands of HT38 Drill ,Pipe, 25 jts of 3.5" HT38 Drill Pipe to be picked up and drilled down with 'the Kelly as singles. RIH w/ 3.5" DP and milling BHA to 4075' Remove bails and elevators, torque all upper kelly connections to 48K. Test two kelly valves 250 psi ! 3000 psi. Reinstall bails and elevatorss, ;blow down lines. Continue in hole with milling BHA. Tag cement above retainer 4650'. Get up and down weight 62UP ! 31 DN. Mill apprxomiately 20 minutes, i made 2' of hole. Make first 20 barrel) sweep, very litt{e cement returns accross shakers. Continue milling operations on retainer, Able to mill through retainer, possibly very small of cement below retainer. Add single joint of DP, No !restriction encountered. Add three additional single joint of tubing, same results, no restrictions. ~! Start pumping second sweep (25 bbls) with rig pump and LRS @ 9 BPM purred a total of 430 bbls until returns cleaned up: ~ Pressure test casing post drilling out retainer and cement to 4800' failed to pressure test OA tracking drill pipe pressure. Increase OA to 800 psi and shut down pressure slowly bleed down to 150 psi in 1 min. 'RIH with drill string to 4900', tagged up on cement stringer or RS nipple ~' @ 4832' went threw with 7000 ibs down wt. continued down to 4900' without seeing any more obstructions. Circulated up solids from bottom with 450 bbls and a 25 bbls Bio gel sweep. Recovered lots of sand and more pieces of the retainer. Rig up for infectivity test down the drill pipe and up the OA to open top tank. Injection test down drill pipe threw top hole back up OA to open top tank. Holding 300-psi back pressure with 9.6 ppg brine. 1.5-bpm = 190-psi DP and 380-psi OA, 2-bpm = 180-psi DP and 400-psi OA, 3-bpm = 340-psi DP and 400 OA, 4-bpm = 480-psi DP and 400-psi OA. Total of 45-bbls of brine was pumped LRS pumped 45-bbls of diesel down Printed: 1112212005 9:A8:25 AM • ConocoPhillips Alaska Page 4 of 14 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVERiRECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11!13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To 10/23/2005 13:30 - 14:30 14:30 - 21:00 21.:00 - 21:30 21:30 - 22:30 122:30 - 00:00 Hours ' Code Sub ', Phase Description of Operations '.:Code _ ___ 1.00 ~! __ _~_ WELLS __ - _ _ _--- _ _ _ ___ _ - _ I _ CIRC WRKOVR ~ the OA to replace the diesel freeze protect. Next we pumped infectivity ~ I test into the bottom hole closing the OA valve and injecting in to the = 880 i DP d 1100 i l i d b 1 bottom ho e. Inject on leave out at 2.2- pm -ps an -ps OA. Conclusion is that both holes are open and do not seem to have 6.50 WELLSR been effected by the prior cement job. TRIP WRKOVR POOH with clean out strn standin back drill i e and la in down 9 9 PP Y 9 0.50 WELLSR PULD !BHA. WRKOVR ~ Pull wear ring 1.00 WELLSF~ RURD WRKOVR I Rig up for weekly BOP test 1.501 WELCTL_ I BOPE ' WRKOVR' Test BOP and choke 250 psi low / 3000 psi high. Lou Grimaldi with 10/24/2005 '~ 00:00 - 02:00 ' 02:00 - 03:00 2.00 1.00 1 03:00 - 07:00 ' 4.00 07:00 - 08:00 1.00 08:00 - 08:30 0.50 08:30 - 10:00 . 1.50 10:00 - 11:00 1.00 11:00 - 11:30 I I 0.50 11:30-11:40 0.17 11:40 - 12:40 12:40 - 13:15 13:15 - 15:30 15:30 - 16:30 16:30 - 18:00 18:00 - 22:00 22:00 - 23:00 WELCT~I BOPE CEMEN PULD CEMENTTRIP CEMEN NFLT CEMEN FIT CEMEN~CIRC CEMEN 1 SFTY CEMEN SEOT CEMENl~PUMP 1.00'1 CEMENl~SOEZ AOGCC waived witness 8:30 PM on 10/23/05 WRKOVR 'Continue with BOP test, Lay down test equipment, install wear ring. WRKOVR .Make up cement retainer BHA (cast iron retainer/setting tool) WRKOVR RIH w/ HES EASYSV retainer and 3.5" HT38 DP with five stands of 3.5" HW DP above 1800' to setting depth of 4645'. WRKOVR ' Set cement retainer with 36 turns to the right. Shear out of retainer- 132,000# and PUH 10'. Pressure test IA to 1,000 PSI for 10 min. Test ,passed. No flow to surface OA. WRKOVR ~ Sting back into retainer and perform injection test. 1 BPM @ 440 PSI DDP. 740 PSl OA WRKOVR I Mix Biozan pills in pits. Blew air through all lines prior to pumping and I or taking returns. Calibrate pressure gauges. Wait on second ASRC hand for assist on remote choke. Clean- rig. Services blocks. WRKOVR Pre-job safety meeting. Discuss all options and contingencies with contractors. WRKOVR ':Pressure test cement line and Schlumberger to 3,500 PSI. Prepare to ll begin cement program. Initial OA pressure = 280 PSI (DPP = 0 WRKOVR ~ Cement to weight!!!!! 2 hours and 45 min to set. Pumps on line at 1 ;BPM to start. 350 PSI DPP. 2 BPM @ 530 DPP. Allowed 25 BBLS into 9 5/8" pipe below retainer prior to openning up OA. WRKOVR :Begin pressure schedule for OA bleed off to allow cement to run into OA at a 1-1 ratio through known hole at 4,752' after allowing 25 BBLS ~, of 15.7 PPG cement to flow into 9 5/8" casing below cement retainer. 0.5811 CEMENTTRIP WRKOVR 125 BBLS away 600 PSI DPP 1200 PSI OA. 132 BBLS total slurry away. 25 BBLS into 9 518" casing and 97 BBLS into 13 3/8" outer annulus. Estimated top of cement in OA = 3,127 RKB. Roughly 235' 1 TVD difference. Un-sting from cement retainer with 10 BBLS left in ilk drill pipe to lay cement plug on the top. Shut down pumps to perform 1, this stage. More than likely that we only put 5-6 BBLS on top of i retainer, Suspect that over balance of OA to 9 5/8" casing will leach into 1 ',and possibly plug lower hole at 4,852-54' RKB. Final OA pressure = 50 PSI 2.2511 CEMENfCOUT ~ WRKOVR ~ Circulate 1 1/2 times bottoms up while moving pipe up and down to ensure that pipe is free. No cement returns to surface. 1.00 ~ CEMENT RURD WRKOVR I. Rig down circulating system and clear rig floor for POOH. 1.50'1 CEMENTOTHR WRKOVR Go through stand pipe manifold and remove all cement from lines. Ili Clear HCR and blow down all line on rig to ensure that no valves leaked cement through. 4.00 CEMENTTRIP WRKOVR 'POOH w/ 3.5" DP and HES setting tool, Lay down setting tool, Prep rig (floor bit run. 1.00' CEMENT RURD WRKOVR 'Make up bit BHA, Oil jars/Bumper sub/Dril collar/Bit sub/Boot 1 I II basketslMill tooth bit. Printed: 11/22/2005 9:48:25 AM • ConocoPhillips Alaska Page 5 of 14 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To ' Hours Code 'Sub 'Code 10/24/2005 ~ 23:00 - 00:00 ~~ 1.00 CEMENI~ TRIP 10/25/2005 ! 00:00 - 01:30 1.50 CEMENT TRIP 01:30 - 10:30 9.00 CEMENT TRIP 10:30 - 12:00 ' 1.50 CEMENl I ~ LOT 12:00 - 16:00 ; 4.00 I I DSTG 16:00 -19:00 3.00 19:00 - 21:00 2.00 21:00 - 00:00 3.00 10/26/2005 i 00:00 - 01:00 1.00 D1:00 - 07:30 6.50 07:30 - 12:00 ~ 4.50 12:00 - 13:00 i 1.00 MILL MILL MILL MILL MILL MILL Phase !WRKOVR WRKOVR WRKOVR ~ WRKOVR WRKOVR WRKOVR WRKOVR W RKOVR WRKOVR WRKOVR WRKOVR CIRC iWRKOVR 13:00 - 14:00 1.00 WELLSI~ OTHR I WRKOVR II -14:00 - 15:30 1.50! WELLS OTHR ~~ WRKOVR I 15:30 - 18:00 I, 18:00 - 22:30 2.50 j WELLS MILL WRKOVR 4.501 WELLSR MILL WRKOVR i 22:30 - 00:00 i I 1.50 WELLSPo MILL WRKOVR I Description of Operations RIH w/ 3.5" DP and bit BHA Continue in hole with cleanout BHA. Rig on stand by above cement plug, waiting for cement to set up. Crews will use this to perform general maintenance and housekeeping duties. Pressure test OA with little Red. Pumped 2.6 BBLS to pressure up to 1,500 PSI. Initial test failed due to air in the system. Second test passed. Lost 50-70 PSI in 15 MIN. Rig down Little Red and prepare to engage cement. After changing hydraulic filters out last night, system will not pressure up past 100 PSI. Mechanic in route. Not sure what the issues was. Pulled a control valve -reinstalled it and rig works. (((CODE 8))). Hydraulics fixed. Prepare to RIH to begin milling. Pick up Kelly and test. Begin milling cement @4526'; circulating to pits at 4 bpm, sweeping the hole with 3# biozan pills. ROP approx. 30-50'Jhr. Stacking 15k down wgt. Continue to mill 4630'. Tag top of cement retainer at 4658'. Set Sk down, begin slowly milling through. Circulating at 4 pm. Not seeing much cement at shakers; call out Hot Oil for pump to up circ rate. Finished milling up retainer. Continue to RIH to 4,778' prior to testing OA. Hot oli on location. Rlg up and conduct pre job safety meeting. Come online with hot oil and rig pump in tandem circulating hole at 6-7 bpm. Target depth achieved. Prepare to pressure test 9 5/8" X 3 1/2" drill pipe annulus. Note that drilling became very easy after 4,755' RKB. Pump 1 1/2 volume for hole circulation. Begin high rate bottoms circulation with little Red assist. 8.5 BPM @ 1,350 PSI DPP 25 BBL 3# biozan sweep. Returns = 1-1. Pressure test 3 1/2" DP X 9 5/8" casing attempt failed. Able to inject into formation via lower leak at 4,852' at 4 BPM 1,600 PSI DPP. Blow down all lines and prep for OA test with Little Red. Pressure test OA to 1,500 PSI with diesel. Test passed with 1.6 BBL to pressure up. 100 PSI loss at 30 MIN. Blow down all lines and re-rig Little Red to assist rig in pump rates. Continue milling up cement with Kelly. Min torque spikes to 4,500 ft/Ib indicate stringers. Continue RIH, still encountering stringers forcing us to mill through. Circulate bottoms up with rig pump/Hot Oil every so often. Seeing large pieces of rubber element from retainer at the shaker, however, only metal fines -- nothing substantial. Continue in hole, still milling through cement stringers /pumping bio 10/27/2005 ~ 00:00 - 05:00 i 5.00I, WELLSF~ MILL sweeps. ! WRKOVR i, Continue to mill down to RBP. Able to clean out with out rotating on '~, occasion, however, still encountering either cement stringers or parts of I ~' 05:00 - 08:00 !, ~ 3.00 ~, WELLSE~ CIRC ' the cement retainer requiring us to mill through. WRKOVR Work down to tag at 5,423', pump 30 bbl bio sweep around and I circulate out of hole. 08:00 - 09:00 i - 1.00; WELLSI~ CIRC ~~ WRKOVR I~ Finnish circulation. Blow down lines and prepare to release Little Red. ~~ Pump dry job. 09:00 - 13:00 ' 4.00 WELLSF~ TRIP ! WRKOVR 'POOH with drill pipe while monitoring hole conditions. Printed: 11/22/2005 9:48:25 AM • ConocoPhillips Alaska Page 6 of 14 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11!13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code 'Sub 10/27/2005 13:00 - 14:30 ,',14:30-16:00 '16:00-17:00 ~. ',17:00-19:00 19:00 - 22:30 ~, 22:30 - 23:15 j I ' 23:15 - 00:00 10/28/2005 00:00 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 07:15 07:15 - 08:30 ' 08:30 - 09:00 09:00 - 12:30 12:30 - 14:00 1,14:00-14:30 i 14:30 - 16:30 16:30 - 22:00 22:00 - 22:30 22:30 - 23:30 I, I 23:30 - 00:00 II 10/29/2005 100:00 - 01:30 i ~I 01:30 - 05:30 ' 05:30 - 06:30 06:30 - 09:00 ~~ 09:00 - 12:00 '! Code 1.50' WELLSR TRIP 1.50, WELLS PULD 1.00; WELLSRSFTY -I 2.00 WELLS PULD 3.50' WELLS TRIP 0.75' WELLSRSFTY 0.75! WELLSRTRIP 5.00 I WELLSR WASH 1.00 WELLS WASH 1.00 WELLS WASH 0.251 WELCTL~ OBSV 1.25 ~ WELCTLI OBSV 0.50 i WELLSR RURD 3.501 WELLS TRIP 1.50 WELLS PULD 0.501 WELLSR RURD 2.00! WELLSR PULD 5.501 WELLSRTRIP 0.50 WELLSF~TRIP 1.00 WELLSR DEQT 0.50 WELLSR DEQT 1.50 ~ WELLSF~ DEQT 4.00111 WELLSRTRIP 1.001 WELLSR~~ PULD 2.50 RIGMNT-I'! RSRV 3.00 WELLS PULD Phase Description of Operations WRKOVR Continue to POOH with milling string. Discuss with Anchorage the different options with the program. WRKOVR 'Lay down BHA and prepare to RBIH with reverse out BHA WRKOVR Perform safety shut down with rig crew to discuss ConocoPhillips commitment to target 0 and their personal safety!! WRKOVR Pick up reverse out BHA and prepare to RIH. WRKOVR Begin RIH with cleanout BHA. Perform BOP drill. WRKOVR Conduct company-wide safety stand down meeting with night shift rig !personnel. Dlscuss safety issues and heighten awareness of attempt to achieve a zero incident culture. WRKOVR Resume running back in hole with cleanout BHA. WRKOVR 'Starting to see scraper work at at 5100'; losing wgt running in hole, clean pick-ups. Sit down @ 5229 ;begin rigging up kelly. Begin circulating at 3 bpm and rotating in order to make hole (stacking 4-5k#). Appear to be scraping cement sheath from casing walls. it WRKOVR ;Continue to scrape to 5,425'. WRKOVR Begin to POOH with scraper asym. PUH and monitor well. POOH. UP WT = 70K DWN WT = 40K. Rotating = 45K WRKOVR ~ Monitor well for flow. WRKOVR .!;Finish monitoring well. Thaw out air system and POOH. Clean rig floor and prepare to POOH WRKOVR Blow dwn Kelly and rig it back. WRKOVR I OOH with drill pipe begin breaking dwn BHA. WRKOVR ,Break out BHA. Take pictures and inserted into 1 E-170 work folder. Composite bridge plug at about 20% inside wash pipe. Cast iron cement retainer broken up in 2-3" chunks. Small pieces in boot baskets. Clear rig floor and prepare to pick up test PKR. ' WRKOVR Complete clearing rig floor. WRKOVR ,Begin installing Baker retrievamatic packer as per pipe tally. Tubing stop is installed in string to locate ~ 4,850.1 T RKB. We had to steam retrievamatic packer to thaw out and lubricate moving parts. Surface ~ hest passed. Begin running in hole. WRKOVR 'Begin running in hole with test packer assembly. WRKOVR j Sat down on trash at +-4840', slight overpull getting back off of it. No-go ~ out 25' in on stand #78 (tbg stop located with a 1' of where it was suppose to + or - 4850' orig RKB). WRKOVR 'Pull out stand #78, rack back. Install headpin. Set test packer, top of element at 4866' orig RKB. PUW=57k. Have difficulties getting packer ~' set, only able to set do at most 15k. Pick up /set down ~, hard...repeatedly, finally able to get set. Test to 2500 psi...good. WRKOVR pull up hole 5' to 4861' (top of element). Set packer and test. Hold 5 mins at 2500 psi-- good. Bleed off. Pull up hole 2' to 4859'. Set packer li and test....found leak between 4859' and 4861' orig RKB. Leak rate 1 1 bpm at 250 psi. Bleed off. WRKOVR Top of test packer element at 4859' orig RKB. Swap pump around to ', 9-5/8"xdrill pipe annulus and pressure up to 2500 psi. OA=O psi Hold for 30 mins. Good test...lost 30 psi in 30 mins. OA stil reading 0 psi. Bleed 'down. Discuss cleanout run W/O Engineer. WRKOVR 'Begin pulling out of hole with test packer. WRKOVR ~I, Break out and lay down BHA. Little bits of fiberglass in BHA. WRKOVR !,Rig service ,Crown, Blocks Prep to pick up washpipe. Change out handeling gear. WRKOVR '', Make up washpipe BHA. Special care. pieces to small for rig Printed: 11/22/2005 9:48:25 AM • ConocoPhillips Alaska Page 7 of 14 Operations Summary Report Legal Well Name: 1 E-170 Common Wet{ Name: 1 E-170 Spud Date: 6/26/2005 Event Name: VVORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13!2005 Group: Rig Name: Nabors 3S Rig Number: Date 'From - To ''' Hours Code ', Sub Code 10/29/2005 ! 09:00 - 12:00 12:00 - 14:30 14:30 - 16:30 16:30 - 20:00 20:00 - 00:00 10/30/2005 00:00 - 02:30 iil 02:30 - 04:00 04:00 - 06:00 06:00 - 06:15 06:15 - 08:00 08:00 - 10:00 10:00 - 11:00 3.00,' WELLSR PULD ~! 2.50! WELLSR TRIP 2.00 RIGMNT~ RGRP 3.50!. WELLS TRIP 4.00 WELLS WASH 2.50 i WELLSR WASH 1.50'' WELLSPo WASH 2.00 i WELLS TRIP 0.251 WELLS~SFTY 1.75 WELLSR TRIP 2.OO WELLSF~TRIP 1.001 WELLSF~SFTY 1,11:00 - 12:00 1.00', WELLSR PULD 12:00 - 14:30 ~I 14 30 15 00 ' 2.50' RIGMNTI'I RSRV 501 WELLSPo PULD 0 ~ : - : 15:00 - 19:00 , . 4.00 j FISH ;TRIP 19:00 - 20:00 !, 1.00 ~~ FISH FISH 20:00 - 22:00 I~'I 2.00 ~ FISH CIRC 22:00 - 00:00 ''~~ I 2.00 FISH ..CIRC I! ~ 10/31/2005 , 00:00 - 02:30 ~, ~I 2.50' FISH I CIRC ~ 02:30 - 06:00 ~ 3.50 !FISH CIRC 06:00 - 10:00 ' i 10:00 - 11:00 ~ 4.00 FISH TRIP 1.00 FISH RURD I i 11:00 - 15:30 ~1' 4.50 WELCTL BOPE 15:30 - 16:00 ! 16:00 19 00 ' 0.50' WELLSF~ SEQP RURD 00 WELLS 3 - : I 19:00 - 00:00 R . 5.00 ii WELLSF~ TRIP Phase Description of Operations WRKOVR equipment on floor. Contact Baker and have shop make up smaller pieces. Changeout handling equipment. WRKOVR :Begin running in the hole with cleanout BHA. WRKOVR Shut down to cut/slip drill line. WRKOVR Resume trip in the hole. Perform BOP drill. WRKOVR 82 stands in the hole;. begin picking up singles. Rlg up headpin and ,begin reverse circulating while stripping through the bag. Circulating at '4 bpm, begin working pipe in hole, however, having difficulties stripping in due to circ. press/pipe wgt. WRKOVR ;Cont. rev-circulating/washing 4 bpm, 550 psi circ press. Lots of sand, composite, rubber, cement across shaker. Hole out of balance due to !solids; U-tubing unable to make up new jts. Circulate hole around to clean up 2x bottoms up. Wash down to 5438'. Pump 30 bbl 3# bio sweep, circulate around. WRKOVR 'Watch returns at shaker until clean. 38 bbls brine lost while circulating/washing. WRKOVR Begin pulling out of hole. WRKOVR Crew change out. WRKOVR 'Continue to POOH . At 1,880' pipe quit draining and is now pulling wet WRKOVR OOH with all drill pipe. Begin picking up handling equip for 8 1i4" pipe. WRKOVR Flappers are plugged on bottom of 8 1/4" wash pipe. pre-job safety 'meeting. Round up the proper PPE. Banna suites, goggles, rubber gloves. WRKOVR ,Lay down wash pipe. Prepare to clean rig. WRKOVR Clean rig from wash pipe. WRKOVR Begin picking up retrieval head for RBP. WRKOVR !RIH with retrieving head to pull RBP at 5445'. WRKOVR i PUW=66k, do=28k. Wash down 5430 to RBP at 5445'; latch up and ,pick up, see slight drag to 70k. Run back in hole past set depth ensure !RBP is latched. WRKOVR Pull up hole 15' and begin circulating bottoms up to ensure no gas was trapped under RBP. WRKOVR Resume pulling out of hole. At 4980', hanging up on trash/debris. 'PUW=65k, dragging to 100k, breaking back. Rig up to rev-circulate. Circulate 2 bottoms up @ 4 bpm, resume pulling out of hole. Well U-tubing badly due to solids concentration in drill pipe. Move pipe 4-6' j make sure pipe is free; swap to circulating the long way. 50 bbls away, :'shut down and pull up hole 10', still dragging. Resume circulating the '1 long way @ 4 bpm, 420 psi. Pump 25 bbl 3# bio sweep. WRKOVR !Cont. Circulating 25 bbl 3# bio sweep around the long way @ 4 bpm. WRKOVR ~ Begin pulling out of hole. Still dragging heavy in a few spots. WRKOVR ,Trip OOH WRKOVR ~ At surface; break down RBP. Send pictures to Anchorage of missing rubber. 1/2" gouge in gauge ring. Rubber element missing is .1T tall, 8 ~' 3/16" OD, 6 7/16" ID. Prepare to make fish /cleanout run_ Ordered ~ out 8 1i2" wash pipe with flapper bit. Pull wear ring and prep for BOP I test. WRKOVR ~I Conduct BOP test; 250 low test, 3000 high. Test witnessed by state rep, John Spaulding. Also checking for rubber trapped in gates. WRKOVR I, Install wear ring. WRKOVR '. Begin making up rev-circulating junk basket BHA for cleanout run. WRKOVR ', Begin RIH with cleanout BHA. Printed: 11!22!2005 9:48:25 AM • ConocoPhillips Alaska Page 8 of 14 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6!26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date .From - To ' Hours Code 'Code Phase Description of Operations 11/1/2005 ' 00:00 - 01:15 01:15 - 03:00 Ili 03:00 - 05:00 ~! i 105:00 - 07:00 ', ~j 07:00 - 08:00 I j 08:00 - 11:30 I 11:30 - 12:00 12:00 - 15:00 ~ I '115:00 - 16:30 116:30 - 23:30 23:30 - 00:00 11 /2/2005 ' 00:00 - 01:00 01:00 - 02:45 ~ 'I I II 02:45 - 04:30 II 04:30 - 05:00 05:00 - 08:00 '~ 08:00 - 09:00 ',, j 09:00 - 13:00 1.25 ~~I WELLSR TRIP ~i WRKOVR Continue RIH with cleanout BHA. PUH; set down at 3565'. PUH, clean I i pickup. Rig up to rev-circulate. Circulate bottoms up plus @ 4 bpm, ' resume RIH. Obstruction appears gone. RIW 28k, PUW=65k. ' 1.75 WELLSPo TRIP WRKOVR ; Lose wgt again at stand #72 (4600 ) roughly last spot we pulled heavy ~ ~, ~ ' j through last night. Install head pin and rig to rev-circulate. 2.00 WELLSR WASH WRKOVR Begin rev-circulating at 4 bpm; circulate bottoms up plus. Remove head pin and begin running back in hole. Set down 30' deeper. Remove a 'j ~ single and make up head pin again; begin stripping through bag while I running in rev-circulating at 4 bpm. WELLSR WASH 2.00 ' WRKOVR Continue RIH. Still seeing an occasional "bobble", possible pushing something down with us. Stop every 4-5 stands in and circulate bottoms ', ' ! up at 4 bpm @ 420 psi, plus. RIW=25k, PUW=70k. Seeing lots of sand ~i j j at the shaker, CP=650 psi. Continue to circulate until it cleans up, pumping 3# bio sweeps. 1.00 WELLSR WASH ' WRKOVR Resume running in hole, rev-circulating bottoms up plus after every 5 1 stands. Change out shaker screens. I ' ! WELLSF~ WASH 3.50 .,Have RIH to 5460'; continue to rev-circulate at 4 bpm. Pump 25 bbl bio WRKOVR III sweep; pump one in as one exits. Last sweep was clean, nothing back on this sweep. 0.50 ~ WELLSR TRIP ! WRKOVR !, Blow down lines and start POH. 3.00 ~! WELLSFPoTRIP j WRKOVR - Start hanging up @ 4920'. Puled 30K over to keep moving. Dragging up to 4790'. Broke free back down to normal string wt. Lowered back down to 4920' start taking wt. Set all of string wt down. Picked up i dragging back up to 4790'. Pulled free. POOH. 1.501 WELLSPoTRIP , WRKOVR Finish POOH laying down BHA. Cleaned out junk basket. Had several i approximately 1" pieces of cast from retainer. 7.00 WELLSR TRIP ' WRKOVR Remove casing scraper from rev-circ BHA, keep 8-5/8" string mill in .. place for drift. Swap out finger catch back to flapper style. Begin RIH. 0.50 ~ WELLS TRIP ~ WRKOVR 75 stands in hole; Rig up to circulate. 1.00 j WELLS~~ WASH I, WRKOVR I Cont. 75 stands in the hole. Tie in ASRC pump to assist with rate. i ~ begin running in singles stripping through bag while reverse circulating ',,through tie-back area. Having difficulties stripping through bag, no pipe ' I ';wgt. RIW=25k, PUW=70k. ' ' IC 1.75 ; WELLSR~ WASH ) tag up. Begin rev-circulating at 7 '75 stands in and 2 singles (4855 I WRKOVR I bpm, pump 2 bttms up. Bleed off, open bag and make several drift passes through tight spot (trash) with string mill. Resume stripping in ', ', i single #3 while rev-circulating at 3-5 bpm, seems clear. Note: did see ~ II I~ ! hose jump as large piece of debris was washed to surface, unable to ' , find at the shaker. Hole take approx 0.75 bpm while circulating at 7 I bpm, 620 psi. 1.75' WELLSR WASH ' WRKOVR ' Strip down single #4 to 4935' while rev-circulating 3-5 bpm. Pull back !, out of hole through tie-back while rev-circulating at 5-6 bpm, laying the ~ I 1 4 singles back down. WELLSR TRIP 0.50 ' WRKOVR I, Run back in hole, set down (12k) at 5010'. Try to work into pipe. RIH to 5030' without seeing anything else. 3.00' WELLSF~ CIRC ', WRKOVR Rig up head pin and begin reverse-circulating at 7-8 bpm. Pump 25 bbi '1 ' ',high-visc sweep and circulate around. Returns showed approx. 10 gals ', I of sand and metal shavings. Fluid losses increased to approx. 1.25 :. ' BPM. Shut down pumps, blow down lines, prep to POOH. 1.00' WELLSR TRIP j WRKOVR 'Pull out of hole slow {ooking for any drag with ASRC pump on standby. i I ,Pulled up to 3700' no indications of drag or trash. Released ASRC ~ ~ ~~ pump. ' WELLSR TRIP 4.00 WRKOVR ',Continue to pull out of hole. Layed dow BHA, cleaned out reverse junk Printed: 11/22/2005 9:48:25 AM ConocoPhillips Alaska Page 9 of 14 Operations Summary Report Legal Wefl Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26!2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To 'Hours ' Code Code' Phase Description of Operations __ __ 11/2/2005 ~ 09:00 - 13:00 I 4.00 WELLS TRIP WRKOVR ~I basket. Retrieved approx. 1 cup of composite material and small cast '.debris. ~~' 13:00 - 16:30 ' 3.501' WELLS PULD ~ WRKOVR Picked up the EXPatch and running/setting tool .and made up same. 16:30 - 21:30 5.00 WELLS TRIP WRKOVR ! PJSM covering details of running the EXPATCH. RIH with the EXPatch i and setting assembly on the 3-1/2" HT38 drill pipe. 21:30 - 22:00 0.50 WELLSR TRIP WRKOVR 155 stands in the hole; everything looks good, hole appears clean to here. Order out inhibited brine, verify timing of Hot Oil pump. 22:00 - 00:00 ' 2.00 WELLSF~ TRIP WRKOVR ~i 75 stands (plus a single) in the hole. Have pre-job review depths/ ~ I setting procedure with Baker reps/completion engitoolpushedetc. 'I Discuss corrosion inhibtor placement; decide to omit from procedure -- ~! ~ !virtually no way to spot and concern over washing trash back into patch setting area. 11/3/2005 .00:00 - 00:30 0.50 WELLSR SFTY WRKOVR ~, 27k RIW, 57k up. On depth at 25.5' in on stand #75 (single in hole as ;well) placing BHA at 4873.67, top of element on seal jt at 4849'. 'i Conduct pre-job with rig crew /Hot Oil regarding setting procedures, 'pressures, safety. 00:30 - 00:50 i 0.33 WELLSf~ CIRC WRKOVR Drop setting ball and make up headpin. P/T Hot Oil /standpipe to 4500 psi. Come online with Hot Oil @ 1 bpm, 150 psi. 00:50 - 01:00 ~' 0.17: WELLSR CIRC ~ WRKOVR 25 bbls away. Bring rate up to 1.5 bpm. 01:00 - 02:00 1.00 WELLSF~ CIRC WRKOVR ' 30 bbls away, ball on seat, see pressure rise. Drop rate to 0.5 bpm and i begin setting sequence. At 3500 psi, see piston stroking, cont. up to i 4500 psi--movement has stopped. Shut down and bleed off. RIH w/ pipe, verify 11' of travel. Re-attempt to stroke patch further...pressure ' ' up to 5000 psi on drill pipe. No movement. Confer w/ Baker Reps. I~, Appears we are stacked out expanding through RS nipple. At max. pressure for rig equipment and Hot Oil pump. 102:00 - 03:00 ~ 1.001 WELLSR OTHR II WRKOVR Regroup and explore options. Call out cement pumper; find they are ,currently working at Doy 141, but finishing soon. Will attempt to set ~i ,patch at higher pressure (6-7k). 03:00 - 06:30 '' 3.50 WAITON EOIP ~I WRKOVR ! On stanby for cement pumper. Perform rig maintenance. Conduct H2S 'drill. 06:30 - 09:45 I 3.25. WELLSR' RURD WRKOVR ~ RU Schlumberger hardline from pump truck to headpin. Tested lines to 6000 psi 09:45 - 11:15 1.50 ~i WELLSR PLGM WRKOVR 'I Opened valve. Filled lines with 1.5 bbls. Press up to 5500 psi short ' ' 'stroked seal jt thru RS nipple @ 4852' press dropped down to 3300 psi ~, ~, ~, Ito complete the stroke. Bled press off, opened valve, slacked off 8'. Total of 19' has been swedged leaving 10' remaing to swedge. Pulled ~ I ,cone back thru RS nipple and liner hanger. Pulled cone thru RS nipple with 140K. Picked up to upper hanger and first tried with 250K, 190K over pull. Worked up to 280K max. Pulled free approx. 1' still stuck. Slacked off to 240K, pulled free back to string wt of 60K. Decision '.made to POOH, run back with 7.915" cone with jars and collars. ,11:15 - 14:00 ~ 2.751 WELLSR RURD WRKOVR RD hardline and prep to POOH. Closed bag and press test 9-5/8" ' II casing and patch to 1000 psi held for 15 min. ii 14:00 - 18:50 '~ 4.83 j WELLSR TRIP '~ WRKOVR ,POOH with workstring and Baker EXPatch running tool. Pull wet, dropped ball to open circ sub. Continue to POOH. 18:50 - 21:30 I,I 2.67 WELLS RURD ii WRKOVR At surface; break down BHA...swap out swedge with back-up which was turned down 1/100" at BakerMachine. Make up new BHA adding I ~ ' (2) drill collars, jars, and accelerator. 121:30 - 00:00 i 2.50 ~, WELLSf2 TRIP WRKOVR I Begin RBIH with new swedge/BHA. 11/4/2005 1100:00 - 02:00 ' Z.00 WELLSI~TRIP WRKOVR ''Continue tripping in hole with patch setting BHA. Call out SLB i~ cementers for pump support. 02:00 - 03:00 ~ 1.00' WELLSFj PLGM ' WRKOVR ', Tag up 23' in on top joint of stand #74 (plus a single) putting us on Printed: 11/22/2005 9:48:25 AM • ConocoPhillips Afaska Page 10 of 14 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11!13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To 'Hours ' Code 11/4/2005 102:00 - 03:00 ' 03:00 - 04:00 i ~~ 04:00 - 05:00 I~, 05:00 - 06:30 ' I I I' 06:30 - 13:00 13:00 - 00:00 11/5/2005 '00:00-01:00 01:00 - 02:30 i 102:30 - 08:15 108:15 - 14:00 , I 14:00-21:00 !. III 21:00 - 22:00 I 22:00 - 23:00 I ~I 23:00 - 00:00 11 /6/2005 ~ 00:00 - 00:30 100:30 - 02:00 ~I 02:00 - 03:00 ~, 103:00 - 04:30 i 04:30 - 07:00 107:00 - 10:30 Sub phase ' Description of Operations 'Code 1.00' WELLSR' PLGM 1.00 WELLSR PLGM i ' 1.00! WELLSRTRIP 1.50'- WELLSa DEOT I 6.50 WELLSR PULD 11.00 1.00 1.50 5.75 5.75 7.00 1.00 1.00 1.00 0.50 1.50 1.00 1.50 2.50 3.50 WELLSRTRIP WELLSRTRIP WRKOVR 'depth. Note: drifted through top of patch cleanly. Putl mousehole, rlg up cementers through hole in floor. P/T pump line to 6200 psi--good. Conduct pre-job safety meeting. WRKOVR Come online w/SLB cement pumper, pressure up to 2200 psi to 1800 psi.. see expansion too! stroke remainder of the way out of patch- 10'(visually saw it pop through). Bleed off, RIH and bury stand #74 ... appears to be clear. Pick up a single and RIH to 4882' for drift (swedge ,cone OD=7.915"). WRKOVR ,Rig down SLB pumpers; clean up rig floor. Begin POOH. Hang up again with swedge in area of lower hanger. Pull 150k, pop through. POOH above patch, (2) stands and a single, and rig up for MIT. WRKOVR j Close bag; bring up 9-5/8 x drill pipe annulus press to 2500 psi. Monitor and chart OA press= lost 0 psi in 30 min. Bled off press. Dropped ball to open circ. sub, blew out at 1500 psi. WRKOVR i POOH standing back drill pipe. LD EXPatch running tools. Clear rig floor and prep for running retrieving tool for RBP. WRKOVR !Make up retrieving tool on workstring, RIH WRKOVR ~ 145 stands, 3 singles (9275'); PUW=105k, RIW=20k. Make up headpin. WELLSR RURD WRKOVR !Rig up 2" hose to hardline in celler to kill tanks. Line up trucks from displacement. Conduct pre-job safety meeting w/ ARSC, rig crews, i Baker rep. WELLSR CIRC WRKOVR 'Rev-circ 25 bbl visc/caustic sweep chased by new 8.9 brine, circulating 'to kill tanks @ 4.5 bpm. Recip pipe in between truck swaps. Pumped ' until fluid cleaned up, switch last 100 bbls 8.9 ppg to pits. WELLSR TRIP WRKOVR PU to get up wt =120K. Attempted to run in and latch onto RBP, stacked out all of wt and would not go down. PU 5' twice and lost 5' each time, would not go down. Pulled drill pipe out of hole with the ' intention of adding drill collars and heavy wt pipe to push down and 'retrieve RBP. Pulled up to 8170' and attempted to go down but stacked out. WAITON OTHR ~! WRKOVR :Shut down, closed rams and pressured up to 1000 psi test casing. Held OK. Ordered 290 bbls 8.9 ppg Lube. Wait on Lube. WAITONI'I OTHR WRKOVR Brine on location; still waiting on load os "slick" fluid. WELLSfZ SFTY ~ WRKOVR 'Fluid on loc. Spot up trucks. Conduct pre-job safety meeting. WELLSR CIRC I WRKOVR it Come online wl rig pump circulating Flo-Pro w/3% EP Lube Friction reducer around the long way back to the pits. 290 bbls tube pumped, displace with 54 bbls new 8.9 brine. WELLSRI CIRC WRKOVR Continued. Circulating Flo-Pro w/3% EP Lube Friction reducert around to lubricate. 290 bbls pumped, chased with 50 bbls of 8.9 brine (left 5 bbls in dp). Perform BOP drill. WELLSRTRIP WRKOVR ~~ RIH w/ drill pipe...having to work in hole PUW=108k, RIW=15k. Run stand 131 in hole, begin picking up heavy wgt pipe. Run 15 jts of heavy wgt in; back on stands. WELLSf~ CIRC ~!, WRKOVR Drillpipe running over while tripping; stop, rig up head pin and mix up '.dry job. WELLSR TRIP ', WRKOVR ' Resume tripping back in hole. WELLSF~ WASH ' WRKOVR Tag up approx. 30' above RBP. Review tallies, discuss. Rig up to wash down to top of RBP. Begin circulating at 3 bpm, 300 psi .See pipe ~!, ', "drop through" top of 7" liner slack off 10', tag bottom of 7" liner tie back sleeve @ 9326'. Circulated @ 3 bpm w 300 psi tied to work past j several times but would not go. WELLSR PLGM ~', WRKOVR ~, PU Kelly and test. Printed: 11/22/2005 9:48:25 AM ConocoPhiUips Alaska Page 11 of 14 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date 11 /6/2005 11/7!2005 11 /8/2005 From - To Hours Code 10:30 - 11:30 ' 1.00 WELLSR~ PLGM 11:30 - 13:00 1.50 WELLSF~ OBSV 13:00-00:00 III 11.OO,WELLSR TRIP i 00:00 - 03:00 ' 3.00 I WELLS TRIP 03:00 - 04:30 ; 1.50 WELLSR ~ TRIP 04:30 - 15:00 'I 10.50 WELLSa i PULD i 15:00 - 22:00 ~; 7.00 CMPLTN RUNT '~ 22:00 - 00:00 2.00: CMPLTN' RUNT 00:00 - 03:00 3.00 WELLSR i SLIN ii 03:00 - 05:00 2.00!. CMPLTN', TRIP I 05:00 - 18:30 ', i 13.50'i CMPLTN TRIP ~i 18:30 - 20:12 ! II I ~ 1.70 CMPLTNI PULL III ~, 20:12 - 20:31 ~ 0.32 ~'~, CMPLTNI DEQT 20:31 - 22:00 II 1.481 CMPLTN~i CIRC 22:00 - 00:00 ! 2.00 I CMPLTNI PULL Sub ~~ phase Code Description of Operations WRKOVR I Ran down tagged liner top again. Rotate off, ran 10' tagged bottom of tie back sleeve again. Broke circulate @ 3bpm w/ 380 psi. Rotated thru, RIH and tagged RBP @ 9352'. Pressure increased to 440 psi. Shut pump down. PU pulled RBP 5' up hole. Wait 5 min. let plug relax. Slacked off 6' lower than where we picked up plug. i, WRKOVR !Picked up on kelly, monitored well. Fluid dropped. Lost 19 bbls in 5 min. Filled hole, monitored well, losing fluid at approx. 25 bph WRKOVR Began POH laying down workstring. Called state to discuss weekly BOP testing due Monday (tomorrow); state (Chuck Sheve) waived need if running new completion. Fluid loss at midnight approx. 16 bbls/hr. j WRKOVR ~ Cont. Pulling out of hole with RBP, pumping hole fill every 10 jts. WRKOVR Fluid loss has dropped to approx. 10 bbls/hr. WRKOVR 'j At surface with RBP; break out and lay down BHA. Begin running in hole the remaining 5 stands of drill pipe in the derrick and pull back out breaking singles, laying down. Lay down Kelly,pull wear ring, clear rig floor. Unload pipe shed and begin bringing ESP equipment into pipe ~, shed to warm up. Bring in last 41 jts. 4-1/2" IBTM, strap and drift. RU ~', power tongs for 4.5" completion. Change Xover for floor safety valve. WRKOVR Rig up spooling unit, raise cable sheave and string power cable. Pick up ESP completion assembly. Make up per well plan ! Centrilft specifications. Fluid losses approx 3 bbl / hr. ~ WRKOVR Ready to run in hole. Rlg up wireline equipment; prep to run pump and ,packoff assembly in hole. Make up last of pump assembly and run in i hole with pump /packoff on slickline. WRKOVR ,Continued. Running in hole with slickline w/4.5" GS & 38.5'OAL ESP Pump. Set pump. RIH w/ 4.5" Packer stinger assy. 103" OAL, 94" to KOBE Knock off to same tap down shear off beat down more. RIH w/3" ~, I SS & D&D test tool to top of packer shear off POOH. Pressure tested packer to 1000 psi good test. RIH w/3" JDC to 106' WLM, latch test tool, POOH. RIHw/4.5" GS & 4.5" sloip stop to top of packer. POOH I~ 'and rig down Halliburton and resume running in hole with completion. ~I Install clamps per well plan / Centrilift recommendations. WRKOVR', Rig up hose to fill tubing off of charge pump. Well taking approx. 1 bbl/hr. WRKOVR I Continue running in hole with ESP completion. PJSM with day crew. 'Install GLM @ 8669' w/3000 psi SOV & @ 2090' w/Dummy. Filling ', ..tubing with fluid every 1000'.. Ran with cable clamps on every collar of first 4100' of tubing and every other collar on connections above the patch @ +/- 4800' MD. Performed electrical inspection /test on ESP cable and TEC wire every 1000'. Saw a small wt jump when GLM went II thru top of casing patch. Test ESP cable, good test. Continue in hole. WRKOVR I Meg report on ESP cable shows direct ground. POOH to last meg ;depth of 5,372'. We will re-meg cable at this depth to confirm. If cable ;still megs negative. Continue to POOH and monitor cable for physical ~~ damage. Alert wire line for possible pump extraction and GLV change out. WRKOVR Meg test failed. Prepare to shear out valve at GLM #1. Shear out ',pressure is 3,000 PSI. WRKOVR ,Unable to shear the SOV. Several attempts of pressures up to 4,500 ,PSI with no luck. Prepare to POOH wet. New gloves on location to ~ 'I assist in pulling seal rings from tubing. WRKOVR I Continue to POOH with completion string. Wireline on call to assist I, with SOV and pump. Printed: 11/22/2005 9:48:25 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-170 1 E-170 WORKOVER/RECOMP N3SCM@conocophillips.com Nabors 3S Date From - To 11 /9/2005 00:00 - 12:30 12:30 - 14:00 14:00 - 18:00 18:00 - 21:00 21:00 - 23:00 23:00 - 00:00 11/10/2005 00:00 - 02:00 02:00 - 06:00 11 /11 /2005 06:00 - 11:00 11:00 - 18:00 18:00 - 23:00 23:00 - 00:00 00:00 - 02:00 02:00 - 08:00 08:00 - 11:00 11:00 - 23:30 Hours Code Code Phase 12.50 i CMPLTNI PULL 1.50 j CMPLTN PULL WRKOVR WRKOVR 4.00': CMPLTN PULL 3.00' CMPLTN SLIN 2.00! CMPLTN PULL 1.OOI CMPLTNI OTHR Page 12 of 14 Spud Date: 6/26/2005 Start: 10/17/2005 End: 11/13/2005 Rig Release: 11/13/2005 Group: Rig Number: Description of Operations _ _ _ _,_ ~~~ Continue POOH wet. Centrilift hand says that a kink in the ESP control cable at +-3,831' RKB. This will need to be repaired while RBIH. Pulling out of hole, found bad clamp at 1357', cable visually good shape at this point. Continued to pull found camp missing from connection @ 1201', and cable severed. Cable bad in several places and clamps mangled up. Lost 1 clamp only. Layed down GLM. RU Halliburton Pull pack off with wireline. Several issues with pump attempting to pull with pack off. After 35 spang licks was able to pull packoff. Pull pump to surface and dog collar. Release HES. Top stage of pump is seized up.. Pull motor slowly to surface watching for lost clamp. Damage to clamp above handling pup. Lay down motor and ESP cable. OOH. Clean rig floor and prepare for test plug to be inserted for BOPE gate opening. Set plug in landing profile and open gates to visually inspect for lost Cannon clamp. No clamp. Reseal gates and prepare for BOPE test. Test waived witness by Lou Gramaldi. BOPE test. Test Variable boreRams, blinds, and valves to 250/3000 psi and annular to 250 / 2500. Install wear ring. Inspect KIC tent for storage of power swivel and power pack. Waiting on Baker Junk Shoe and Baker KB retrievable packer & Kobel Knock out plug. Pulled wear ring back out. Removed ESP cable from spooler, installed new 7000' ESP cable in Spooler. Continue waiting on Baker Junk Shoe and Baker KB retrievable packer & Kobel Knock out plug. Pre-job safety meeting. Load pipe shed with BHA and confirm straps. Discuss with anchorage issues with junk catcher fluid bypass. Tool is good to go. Begin Centrilift installation procedures. PU 7.5" OD junk catcher on bottom of motor centralizer, pressure sensor and motor. Fill motor with prescribed lubricant and allow for air to pass. Pick up Seal Section and assemble to the motor section. Service Seal Section. Splice in motor lead to new ESP power cable reel. Feed motor lead extension cable through sheave to floor and connect. Lower unit in well, connect pump receptacle assy. to top of seal section. Continue to run assy. in hole installing Cannon single-channel cross coupling cable clamp on each jot. Install the a-well Discharge Sub and connect capillary to pressure sensor. Run 2jt. 4.5" tubing. RU Halliburton Slick line. Fill hole. RIH with pump assembly on slick line and set pump in pump housing. Ran pack off stinger, tubing pack off, press test to 1000 psi and run tubing stop.. RDMO slick line. PU and RIH with 1jt.4.5" tubing w/ 4.5" Baker KB retrievable packer and Kobe knock out plug already installed in jt to allow the tubing to be run dry to decrease drag on tubing clamps. Continue RIH with ESP assembly on 4.5" tubing installing Cannon single-channel cross-coupling cable clamps on each jt. Witnessed no bobbles entering patch at 4,842'. Tagged up at 5,095'. Set 5K dwn wt. on pipe. Pulled up 10' for re-attempt with max wt 5K DWN. Making no hole. Called Anchorage and discuss options. Decided to use 16,000# as max DWN wt. Current pick up wt = 36,000#, free float WT = 26,000#. Blocks = WRKOVR WRKOVR WRKOVR WRKOVR 2.00' WELCT NUND CMPLTN 4.00, WELCT BOPE 'CMPLTN 5.00!. WAITON EOIP :CMPLTN 7.00', CMPLTN I OTHR 'CMPLTN 5.00'' WAITON EOIP 'CMPLTN 1.00' CMPLTN SFTY j CMPLTN 2.00! WAITON ORDR (CMPLTN 6.00' CMPLTN PULD CMPLTN 3.00', CMPLTNI PULD 12.50 ~ CMPLTNI RUNT CMPLTN CMPLTN Printed: 11 /22/2005 9:48:25 AM • ConocoPhillips Alaska Page 13 of 14 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date 11 /11 /2005 11 /12/2005 11 /13/2005 From - To ' Hours ' Code Code Phase ', Description of Operations 11:00 - 23:30 I~ 12.50 ~I CMPLTN RUNT CMPLTN ~' 10K. Two attempts at 16K dwn wt. No movement. Anchorage to 23:30 - 00:00 I 0.50 ~, WAIT( 00:00 - 01:30 1.50 WAIT( 01:30 - 02:00 i 0.50 I CMPL 02:00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 08:00 08:00 - 09:30 0.50 0.50 0.50 4.50 1.50 j discuss with assets. ORDR CMPLTN + Wait on decision from asset. Monitor well. Bring tubing hanger '~ assembly into pipe shed to warm up for inspection. ORDR CMPLTN ' In discussions with Anchorage as to which avenue to pursue. SFTY CMPLTN ;Build new completion tally to reflect discussions with Anchorage as to completing well as-is-where-is. Prepare to POOH above pre-installed ~ !GLM 6 joints away and pull GLM out of original completion string. !~ i RBIH and complete well no deeper than 5,076' RKB. Hold pre job !.safety meeting for everybody to be on same page. PULL I CMPLTN POOH, remove GLM and replace with joint number 219 @ 27.82' long. Up wt = 36K. 15K overpull to begin POOH. RUNT 'CMPLTN !Pull out GLM and replace with tubing joint 219. RBIH to 5,043' to begin ',installation of tubing hanger. RURD ',CMPLTN 'Orient tubing hanger and steam for thaw assist. Prepare for ESP pigtail !~ install. RURD ii CMPLTN ~ ,Make final splice of ESP cable to wellhead penetrator. Test cable & I I, penetrato, good test. RURD !,CMPLTN ~! Double check orientation of hanger. Land tubing with extreme caution. !! I RILDS. Back out landing jt. and wash out and drain BOP stack, lay ! RURD I! CMPLTN down landing jt. Test hanger body seals and void to 5000 psi. !, Rig down sheave from derrick and Elephant trunk hose. Spool up cable I~ ~ end into spooler. RU tools to lay down 22 stands of 4.5" tubing out of derrick thru mousehole. PULD !~, CMPLTN RU tools and lay down 22 stands of 4.5" tubing out of derrick thru !~! ! mousehole. Empty pits. Load out trucks with tubing and tools to go I back. Pull mousehole, LD. NUND CMPLTN ~'~, Rig off BOP's and prepare to install production tree. NUND CMPLTN ~I Hold meeting in cellar. Production tree is not lining up with penetrator. !! Notice that looking into casing valve you can see 3/4" of hanger that I has rotated clock ways. Called AOGCC and asked Lou Grimaldi for permission to re-install BOPE and perform a body pressure test along I with a function test of the rams. Permission granted with the exception of, (We are only allowed to pick up and turn the hanger. If further work j is needed we will sit back down RILDS and re-visit the possibility of a CMPL CMPL CMPL CMPL CMPL 09:30 - 11:00 I 1.501 CMPL 11:00 - 18:00 7.00 ~I CMPL i 18:00 - 21:30 3.50 j WELC 21:30 - 22:00 0.50' WELC 22:00 - 00:00 00:00 - 02:10 02:10 - 04:00 04:00 - 04:30 04:30 - 07:00 07:00 - 08:30 08:30 - 15:00 ` ~ ~ Full BOP test.) 2.00 WELCTL NUND CMPLTN Begin to re-install BOP. 2.17 WELCTL NUND CMPLTN Continue to rig up BOP and prepare for test. 1.83:1 WELCTL BOPE CMPLTN . Begin BOP test. 0.50 CMPLTNI, RURD CMPLTN I RIH w/landing joint pick up tubing hanger 4" and inguaged alignment j pin. Land hanger. RILDS. Confirm by looking in casing valve at full I guage hole. Tested upper and lower seals on hanger to 5000 psi. 2.50' CMPLTN', NUND CMPLTN NDBOP. 1.50', CMPLTN'', DEOT CMPLTN Cleaned void area, inspect landing head. Test penetrator and ESP j ~! !, cable, showed 30K OHM to ground. Called out 2nd service hand to I, double check readings determined that Phoenix guage needed to be '~ check with reverse polarity. Retested reversing polarity and tested !! ! ! 6.50', CMPLTN NUND CMPLTN good. NU tree. Test hanger void ! packoff to 250 /5000 psi. Pull BPV install !I I ', 2-way check. Attempt to test tree, press up to 5000 psi and discovered hairline crack in tree bonnet just behind penetrator. Pressured up again II ' ~ ~ to confirm leak, same results. Confirmed with VETCO Gray no ~I !, i replacement on slope. Change out 2-way check valve with BPV. Clean Printed: 11/22/2005 9:48:25 AM Printed: 11/22/2005 9:48:25 AM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 E 1 E-170 Job No. AK ZZ-0003778283, Surveyed: 7 August, 2005 Survey Report 26 September, 2005 Your Ref.• 500292326400 Surface Coordinates: 5959339.91 N, 549889.64E (70° 17' 58.8873" N, 149° 35' 45.4351 " YID Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959339.91 N, 49889.64E (Grid) Surface Coordinates relative fo Structure: 420.32 S, 2.66 W (True) Kelly Bushing Elevation: 111.05ft above Mean Sea Level Kelly Bushing Elevation: 111.05ft above Project V Reference Kelly Bushing Elevation: 111.05ft above Structure Survey Ref.• svy2188 A ttaAihurltar ~am~ray Halliburton Sperry-Sun Survey Report for Kuparuk 1 E -1E-170 Your Ref.•500292328400 Job No. AK-ZZ-0003778283, Surveyed: 7 August 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 13686.65 91.790 181.530 3302.95 3414.00 12191.17 S 872.00E 5947154.80 N 550842.56E 12191.17 Tie-On Point 13768.00 91.410 180.400 3300.68 3411.73 12272.48 S 870.63E 5947073.49 N 550841.73E 1.465 12272.48 Window Point 13833.81 91.110 179.480 3299.24 3410.29 12338.27 S 870.70E 5947007.69 N 550842.23E 1.470 12338.27 13932.27 88.930 179.380 3299.20 3410.25 12436.72 S 871.68E 5946909.25 N 550843.87E 2.216 12436.72 14024.21 90.810 178.230 3299.41 3410.46 12528.63 S 873.60E 5946817.35 N 550846.40E 2.397 12528.63 14115.75 89.450 177.690 3299.20 3410.25 12620.11 S 876.85E 5946725.90 N 550850.26E 1.599 12620.11 14207.32 90.770 178.840 3299.03 3410.08 12711.64 S 879.63E 5946634.39 N 550853.64E 1.912 12711.64 14299.03 93.270 180.980 3295.79 3406.84 12803.28 S 879.77E 5946542.76 N 550854.39E 3.587 12803.28 14393.09 94.490 180.530 3289.43 3400.48 12897.11 S 878.53E 5946448.92 N 550853.78E 1.382 12897.11 14485.27 91.770 180.280 3284.40 3395.45 12989.14 S 877.88E 5946356.88 N 550853.74E 2.963 12989.14 14576.50 91.690 180.220 3281.64 3392.69 13080.33 S 877.49E 5946265.70 N 550853.95E 0.110 13080.33 14668.13 90.790 180.580 3279.66 3390.71 13171.93 S 876.85E 5946174.09 N 550853.92E 1.058 13171.93 14759.52 91.240 180.890 3278.04 3389.09 13263.30 S 875.67E 5946082.71 N 550853.35E 0.598 13263.30 14850.55 92.440 181.090 3275.12 3386.17 13354.27 S 874.10E 5945991.74 N 550852.38E 1.336 13354.27 14940.19 91.710 181.420 3271.87 3382.92 13443.83 S 872.14E 5945902.17 N 550851.02E 0.894 13443.83 15045.79 91.090 181.470 3269.29 3380.34 13549.36 S 869.48E 5945796.62 N 550849.06E 0.589 13549.36 15076.44 91.400 180.850 3268.63 3379.68 13580.00 S 868.86E 5945765.98 N 550848.64E 2.261 13580.00 15171.68 90.540 181.140 3267.01 3378.06 13675.21 S 867.20E 5945670.76 N 550847.62E 0.953 13675.21 15262.59 90.030 180.210 3266.56 3377.61 13766.11 S 866.13E 5945579.85 N 550847.15E 1.167 13766.11 15355.29 89.720 180.970 3266.76 3377.81 13858.81 S 865.18E 5945487.15 N 550846.81E 0.885 13858.81 15449.09 90.130 180.530 3266.89 3377.94 13952.60 S 863.95E 5945393.36 N 550846.21E 0.641 13952.60 15535.69 90.560 181.960 3266.37 3377.42 14039.17 S 862.07E 5945306.77 N 550844.90E 1.724 14039.17 15629.48 91.350 182.340 3264.80 3375.85 14132.88 S 858.55E 5945213.04 N 550842.00E 0.935 14132.88 15722.00 94.770 182.990 3259.86 3370.91 14225.16 S 854.26E 5945120.74 N 550838.32E 3.762 14225.16 15816.78 94.720 183.100 3252.02 3363.07 14319.48 S 849.24E 5945026.39 N 550833.93E 0.127 14319.48 15907.95 93.640 182.970 3245.38 3356.43 14410.28 S 844.43E 5944935.56 N 550829.72E 1.193 14410.28 15940.00 93.640 182.970 3243.34 3354.39 - 14442.22 S 842.77E 594.4,903.60 N 550828.27E 0.000 14442.22 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15940.OOft., The Bottom Hole Displacement is 14466.79ft., in the Direction of 176.660° (True). C] 26 September, 2005 -10:29 Page 2 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for KuparuK 1 E - 1E-170 Your Ref.• 500292326400 Job No. AK 2Z-0003778283, Surveyed: 7 Augusf, 2005 Western North Slope Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 13686.65 3414.00 12191.17 S 872.00E Tie-On Point 13768.00 3411.73 12272.48 S 15940.00 3354.39 14442.22 S 870.63E Window Point 842.77E Projected Survey ConocoPhillips Survey tool program for 1E-170 From Measured Vertical Depth Depth (ft) (ft! 0.00 0.00 826.00 815.65 To Measured Vertical Depth Depth (ft) (ft) 826.00 815.65 15940.00 3354.39 Survey Tool Description CB-SS-Gyro (1E-170PB1) MWD+IIFR+MS+SAG (1E-170PB1) CJ 26 September, 2005 - 10:29 Page 3 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Western North Slope ConocoPhillips . Kuparuk 1 E 1 E-170PB 1 Job No. AK-ZZ-0003778283, Surveyed: 25 July, 2005 Survey Report 26 September, 2005 Your Ref: 500292326470 Surface Coordinates: 5959339.91 N, 549889.64E (70° 17' 58.8873" N, 149° 35' 45.4351 " VIA Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959339.91 N, 49889.64E (Grid) Surface Coordinates relative to Structure: 420.32 S, 2.66 W (True) Kelly Bushing Elevation: 111.05ft above Mean Sea Level Kelly Bushing Elevation: 111.05ft above Project V Reference Kelly Bushing Elevation: 111.05ft above Structure 5~E1'~t""~~-5tJ1'l DRIt_[_iN~ ~ERVtCES SurveyRef.-svy2164 A Halliburton Company Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-170P81 Your Ref.•500292326470 Job No. AK-ZZ-0003778283, Surveyed: 25 July, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -111.05 0.00 0.00 N 0.00E 5959339.91 N 549889.64E 0.00 CB-SS-Gyro 85.00 0.500 106.400 -26.05 85.00 0.10 S 0.36E 5959339.81 N 549890.00E 0.588 0.10 118.00 0.490 115.000 6.95 118.00 0.21 S 0.62E 5959339.71 N 549890.26E 0.227 0.21 200.00 0.640 121.790 88.94 199.99 0.59 S 1.33E 5959339.32 N 549890.97E 0.200 0.59 271.00 1.880 129.360 159.93 270.98 1.54 S 2.57E 5959338.39 N 549892.22E 1.758 1.54 364.00 4.280 139.540 252.78 363.83 5.15 S 6.00E 5959334.80 N 549895.67E 2.637 5.15 455.00 7.150 142.020 343.32 454.37 12.20 S 11.69E 5959327.79 N 549901.41E 3.165 12.20 546.00 10.550 147.270 433.23 544.28 23.68 S 19.68E 5959316.37 N 549909.48E 3.836 23.68 639.00 10.620 152.560 524.65 635.70 38.44 S 28.23E 5959301.66 N 549918.13E 1.047 38.44 723.00 15.270 159.100 606.49 717.54 55.66 S 35.75E 5959284.49 N 549925.76E 5.795 55.66 826.00 20.320 175.870 704.60 815.65 86.20 S 41.88E 5959253.99 N 549932.10E 6.940 86.20 MWD+IIFR+MS+SAG 862.30 21.960 178.640 738.46 849.51 99.28 S 42.50E 5959240.92 N 549932.80E 5.289 99.28 955.07 23.960 177.500 823.87 934.92 135.44 S 43.73E 5959204.76 N 549934.27E 2.208 135.44 1045.95 26.390 178.510 906.11 1017.16 174.07 S 45.06E 5959166.14 N 549935.86E 2.715 174.07 1140.46 31.330 177.410 988.86 1099.91 219.65 S 46.72E 5959120.58 N 549937.82E 5.257 219.65 1237.80 31.050 173.940 1072.14 1183.19 269.89 S 50.52E 5959070.36 N 549941.95E 1.868 269.89 1331.59 30.220 174.770 1152.84 1263.89 317.45 S 55.22E 5959022.83 N 549946.97E 0.993 317.45 1426.76 32.020 174.380 1234.31 1345.36 366.42 S 59.87E 5958973.90 N 549951.95E 1.903 366.42 1521.14 34.200 174.380 1313.36 1424.41 417.72 S 64.92E 5958922.63 N 549957.33E 2.310 417.72 1615.92 35.170 173.640 1391.29 1502.34 471.36 S 70.56E 5958869.03 N 549963.32E 1.116 471.36 1709.96 39.730 168.980 1465.95 1577.00 527.82 S 79.31E 5958812.63 N 549972.45E 5.706 527.82 1805.78 47.990 170.100 1534.98 1646.03 593.06 S 91.30E 5958747.47 N 549984.88E 8.658 593.06 1901.55 52.160 172.810 1596.43 1707.48 665.67 S 102.16E 5958674.94 N 549996.22E 4.864 665.67 1997.05 59.230 175.050 1650.23 1761.28 744.06 S 110.43E 5958596.60 N 550005.01E 7.652 744.06 2092.01 64.970 174.710 1694.64 1805.69 827.61 S 117.92E 5958513.10 N 550013.05E 6.053 827.61 2188.98 73.150 173.900 1729.27 1840.32 917.65 S 126.92E 5958423.12 N 550022.65E 8.472 917.65 2282.26 76.010 173.720 1754.07 1865.12 1007.04 S 136.61E 5958333.80 N 550032.94E 3.072 1007.04 2347.76 76.970 173.560 1769.37 1880.42 1070.34 S 143.67E 5958270.55 N 550040.41E 1.485 1070.34 2398.70 78.920 174.730 1780.01 1891.06 1119.89 S 148.75E 5958221.03 N 550045.82E 4.438 1119.89 2489.04 78.010 173.410 1798.08 1909.13 1207.93 S 157.89E 5958133.06 N 550055.55E 1.750 1207.93 2583.90 81.470 172.130 1814.97 1926.02 1300.51 S 169.64E 5958040.55 N 550067.91E 3.882 1300.51 2678.38 80.160 173.110 1830.05 1941.10 1393.00 S 181.62E 5957948.14 N 550080.51E 1.724 1393.00 2775.20 79.660 173.490 1847.01 1958.06 1487.68 S 192.75E 5957853.55 N 550092.26E 0.645 1487.68 2871.51 84.590 172.780 1860.21 1971.26 1582.36 S 204.15E 5957758.94 N 550104.29E 5.171 1582.36 2966.25 84.460 173.580 1869.25 1980.30 1676.00 S 215.35E 5957665.37 N 550116.11E 0.852 1676.00 C7 • 26 September, 2005 - 90:07 Page 2 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1 E - 1 E-170P81 Your Ref: 500292326470 Job No. AK-ZZ-0003778283, Surveyed: 25 July, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 3060.64 85.030 173.790 1877.89 1988.94 1769.43 S 225.69E 5957572.02 N 550127.07E 0.643 1769.43 3155.25 85.970 174.600 1885.31 1996.36 1863.26 S 235.23E 5957478.25 N 550137.23E 1.310 1863.26 3248.90 85.350 175.240 1892.40 2003.45 1956.27 S 243.50E 5957385.30 N 550146.12E 0.950 1956.27 3347.65 84.660 175.650 1901.00 2012.05 2054.34 S 251.31E 5957287.29 N 550154.58E 0.812 2054.34 3442.19 85.670 175.850 1908.97 2020.02 2148.28 S 258.29E 5957193.39 N 550162.19E 1.089 2148.28 3536.66 84.540 176.080 1917.03 2028.08 2242.17 S 264.91E 5957099.55 N 550169.43E 1.220 2242.17 3631.29 83.350 174.990 1927.01 2038.06 2335.98 S 272.24E 5957005.79 N 550177.38E 1.701 2335.98 3726.97 83.300 174.450 1938.13 2049.18 2430.61 S 280.98E 5956911.22 N 550186.75E 0.563 2430.61 3820.43 84.290 174.160 1948.23 2059.28 2523.06 S 290.20E 5956818.83 N 550196.59E 1.103 2523.06 3917.60 84.630 173.590 1957.61 2068.66 2619.23 S 300.52E 5956722.74 N 550207.54E 0.681 2619.23 4011.37 83.610 170.980 1967.22 2078.27 2711.65 S 313.04E 5956630.40 N 550220.68E 2.975 2711.65 4105.85 80.750 172.150 1980.08 2091.13 2804.23 S 326.77E 5956537.91 N 550235.02E 3.266 2804.23 4200.08 77.060 172.610 1998.21 2109.26 2895.86 S 339.03E 5956446.36 N 550247.89E 3.945 2895.86 4294.95 74.870 174.110 2021.21 2132.26 2987.27 S 349.68E 5956355.02 N 550259.15E 2.772 2987.27 4390.80 74.040 175.780 2046.90 2157.95 3079.25 S 357.82E 5956263.10 N 550267.90E 1.889 3079.25 4485.42 76.180 175.290 2071.22 2182.27 3170.41 S' 364.94E 5956171.99 N 550275.62E 2.316 3170.41 4580.61 76.860 175.100 2093.40 2204.45 3262.65 S 372.69E 5956079.80 N 550283.99E 0.740 3262.65 4674.30 73.820 175.250 2117.11 2228.16 3352.96 S 380.32E 5955989.55 N 550292.21E 3.248 3352.96 4765.08 76.860 174.140 2140.09 2251.14 3440.40 S 388.44E 5955902.17 N 550300.92E 3.551 3440.40 4865.79 77.900 174.970 2162.09 2273.14 3538.23 S 397.77E 5955804.40 N 550310.89E 1.309 3538.23 4960.05 78.090 174.900 2181.70 2292.75 3630.07 S 405.91E 5955712.62 N 550319.64E 0.214 3630.07 5044.36 78.420 175.660 2198.86 2309.91 3712.33 S 412.70E 5955630.40 N 550326.98E 0.965 3712.33 5089.56 78.460 175.300 2207.92 2318.97 3756.48 S 416.19E 5955586.28 N 550330.76E 0.785 3756.48 5180.32 78.310 176.260 2226.19 2337.24 3845.14 S 422.73E 5955497.66 N 550337.89E 1.049 3845.14 5275.52 78.580 175.420 2245.26 2356.31 3938.16 S 429.50E 5955404.69 N 550345.27E 0.910 3938.16 5370.88 77.750 174.580 2264.82 2375.87 4031.14 S 437.63E 5955311.77 N 550354.02E 1.225 4031.14 5465.60 80.200 175.250 2282.93 2393.98 4123.74 S 445.87E 5955219.23 N 550362.88E 2.678 4123.74 5561.57 82.650 172.850 2297.24 2408.29 4218.11 S 455.71E 5955124.92 N 550373.34E 3.554 4218.11 5655.20 81.510 171.930 2310.14 2421.19 4310.02 S 467.99E 5955033.09 N 550386.23E 1.559 4310.02 5750.32 80.250 173.520 2325.22 2436.27 4403.18 S 479.88E 5954940.01 N 550398.75E 2.116 4403.18 5844.84 79.960 172.710 2341.46 2452.51 4495.62 S 491.05E 5954847.65 N 550410.52E 0.898 4495.62 5940.62 80.440 172.070 2357.76 2468.81 4589.17 S 503.54E 5954754.18 N 550423.64E 0.827 4589.17 6035.64 79.510 169.730 2374.31 2485.36 4681.56 S 518.34E 5954661.90 N 550439.05E 2.615 4681.56 6131.29 79.110 169.800 2392.05 2503.10 4774.05 S 535.04E 5954569.52 N 550456.36E 0.424 4774.05 6226.29 78.480 169.880 2410.51 2521.56 4865.78 S 551.48E 5954477.90 N 550473.41E 0.668 4865.78 26 September, 2005 - 10:07 Page 3 of 6 DrillQuest 3.03.06.008 Hatliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-170PB1 Your Ref: 500292326470 Job No. AK-ZZ-0003778283, Surveyed: 25 July, 2005 Western North Slope Measured Depth Incl. (ft) 6321.50 77.890 6416.10 77.280 6511.83 77.090 6608.42 76.240 6702.76 75.980 6798.00 75.320 6892.34 75.220 6987.82 74.820 7082.68 75.080 7177.65 75.430 7272.91 76.350 7367.81 75.980 7462.18 76.580 7558.61 76.780 7653.06 76.380 7748.78 76.000 7843.25 75.780 7938.59 75.680 8033.32 74.540 8129.40 74.230 8224.07 75.090 8319.00 75.890 8413.39 76.160 8508.88 74.940 8604.73 74.490 8699.66 75.670 8794.14 75.600 8888.96 75.900 8983.99 75.900 9066.43 77.690 9114.84 79.050 9208.74 80.420 9304.33 80.020 9398.24 81.360 9492.49 81.510 True Azim 170.210 170.460 169.220 169.190 170.310 171.580 173.500 175.190 176.470 174.910 175.700 176.460 175.050 175.700 175.830 174.930 175.550 173.820 174.780 173.860 174.930 173.180 173.340 173.010 172.280 173.190 173.250 172.050 171.520 174.320 175.490 176.610 179.260 181.100 181.520 Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 2430.00 2541.05 4957.57 S 567.59E 5954386.22 N 550490.13E 0.706 2450.34 2561.39 5048.64 S 583.10E 5954295.25 N 550506.25E 0.695 2471.58 2582.63 5140.52 S 599.57E 5954203.48 N 550523.32E 1.279 2493.85 2604.90 5232.84 S 617.17E 5954111.28 N 550541.54E 0.881 2516.50 2627.55 5322.96 S 633.46E 5954021.27 N 550558.43E 1.185 2540.11 2651.16 5414.08 S 647.99E 5953930.25 N 550573.56E 1.466 2564.10 2675.15 5504.54 S 659.83E 5953839.87 N 550586.00E 1.971 2588.78 2699.83 5596.32 S 668.92E 5953748.15 N 550595.70E 1.760 2613.41 2724.46 5687.68 S 675.58E 5953656.84 N 550602.97E 1.332 2637.58 2748.63 5779.26 S 682.49E 5953565.30 N 550610.48E 1.631 2660.81 2771.86 5871.34 S 690.05E 5953473.28 N 550618.65E 1.257 2683.50 2794.55 5963.27 S 696.35E 5953381.40 N 550625.56E 0.870 2705.88 2816.93 6054.69 S 703.13E 5953290.02 N 550632.96E 1.585 2728.10 2839.15 6148.22 S 710.70E 5953196.54 N 550641.14E 0.688 2750.02 2861.07 6239.84 S 717.48E 5953104.97 N 550648.54E 0.444 2772.87 2883.92 6332.49 S 724.97E 5953012.37 N 550656.64E 0.996 2795.90 2906.95 6423.79 S 732.57E 5952921.12 N 550664.85E 0.678 2819.40 2930.45 6515.79 S 741.13E 5952829.18 N 550674.02E 1.762 2843.75 2954.80 6606.88 S 750.23E 5952738.15 N 550683.71E 1.552 2869.61 2980.66 6698.96 S 759.38E 5952646.14 N 550693.48E 0.977 2894.65 3005.70 6789.82 S 768.30E 5952555.34 N 550703.00E 1.419 2918.44 3029.49 6881.22 S 777.82E 5952464.00 N 550713.13E 1.974 2941.23 3052.28 6972.19 S 788.57E 5952373.11 N 550724.48E 0.330 2965.06 3076.11 7064.00 S 799.56E 5952281.37 N 550736.08E 1.321 2990.33 3101.38 7155.70 S 811.39E 5952189.76 N 550748.52E 0.872 3014.77 3125.82 7246.69 S 822.99E 5952098.85 N 550760.72E 1.550 3038.21 3149.26 7337.57 S 833.80E 5952008.03 N 550772.13E 0.096 3061.55 3172.60 7428.72 S 845.55E 5951916.97 N 550784.50E 1.267 3084.70 3195.75 7519.94 S 858.72E 5951825.84 N 550798.27E 0.541 3103.54 3214.59 7599.58 S 868.61E 5951746.27 N 550808.68E 3.956 3113.30 3224.35 7646.80 S 872.82E 5951699.07 N 550813.21E 3.674 3130.03 3241.08 7738.98 S 879.18E 5951606.94 N 550820.18E 1.872 3146.27 3257.32 7833.11 S 882.57E 5951512.83 N 550824.20E 2.764 3161.46 3272.51 7925.78 S 882.28E 5951420.17 N 550824.52E 2.403 3175.50 3286.55 8018.95 S 880.15E 5951326.98 N 550823.01E 0.469 Vertical Section 4957.57 5048.64 5140.52 5232.84 5322.96 5414.08 5504.54 5596.32 5687.68 5779.26 5871.34 5963.27 6054.69 6148.22 6239.84 6332.49 6423.79 6515.79 6606.88 6698.96 6789.82 6881.22 6972.19 7064.00 7155.70 7246.69 7337.57 7428.72 7519.94 7599.58 7646.80 7738.98 7833.11 7925.78 8018.95 ConocoPhillips Comment • 2S September, 2005 - 10:07 Page 4 of 6 Dril/Quest 3.03.06.008 Naliiburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-170P61 Your Ref.• 500292326470 Job No. AK-ZZ-0003778283, Surveyed: 25 July, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordi nates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9588.45 80.480 182.130 3190.52 3301.57 8113.68 S 877.13E 5951232.24 N 550820.62 E 9683.31 81.420 182.350 3205.44 3316.49 8207.28 S 873.47E 5951138.61 N 550817.58 E 9777.64 80.350 181.520 3220.39 3331.44 8300.37 S 870.32E 5951045.50 N 550815.05 E 9873.92 79.780 181.540 3237.00 3348.05 8395.17 S 867.79E 5950950.69 N 550813.15 E 9969.14 80.240 179.420 3253.52 3364.57 8488.94 S 867.01E 5950856.92 N 550812.99 E 10063.88 79.650 178.420 3270.06 3381.11 8582.20 S 868.77E 5950763.66 N 550815.37 E 10159.17 78.280 178.610 3288.30 3399.35 8675.70 S 871.19E 5950670.19 N 550818.41 E 10254.54 78.700 179.640 3307.33 3418.38 8769.14 S 872.62E 5950576.76 N 550820.46 E 10347.95 77.720 179.620 3326.41 3437.46 8860.57 S 873.21E 5950485.33 N 550821.65 E 10387.29 77.910 179.940 3334.72 3445.77 8899.03 S 873.35E 5950446.88 N 550822.06 E 10463.57 78.240 180.750 3350.48 3461.53 8973.66 S 872.90E 5950372.25 N 550822.10 E 10512.90 78.640 181.270 3360.36 3471.41 9021.98 S 872.05E 5950323.92 N 550821.57 E 10611.88 77.940 185.490 3380.46 3491.51 9118.71 S 866.34E 5950227.16 N 550816.51 E 10710.81 79.770 187.080 3399.58 3510.63 9215.18 S 855.72E 5950130.61 N 550806.52 E 10808.48 81.970 189.980 3415.08 3526.13 9310.53 S 841.41E 5950035.17 N 550792.84 E 10904.46 83.710 191.300 3427.05 3538.10 9404.12 S 823.82E 5949941.47 N 550775.88 E 11006.72 87.740 193.250 3434.67 3545.72 9503.73 S 802.14E 5949841.71 N 550754.86 E 11105.58 88.280 192.480 3438.10 3549.15 9600.05 S 780.14E 5949745.25 N 550733.50 E 11198.60 89.400 192.720 3439.99 3551.04 9690.81 S 759.86E 5949654.36 N 550713.82 E 11230.00 89.400 192.720 3440.31 3551.36 9721.44 S 752.94E 5949623.68 N 550707.11 E Ali data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. N orthings and Eastings are re lative to Well. Global Northings and Eas tings are relative to NAD2 7 Alaska State Planes, Zone 4. The Dogleg Se verity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along a n Azimuth of 180.000° (True). Based upon Mi nimum Cu rvature type calculations, at a Measured Depth of 11230.OOft., The Bottom Hole Displacement is 9750.56ft., in the Direction of 17 5.571° (True). ConocoPhillips Dogleg Vertical Rate Section Comment (°/100ft) 1.243 8113.68 1.017 8207.28 1.429 8300.37 0.592 8395.17 2.245 8488.94 1.212 8582.20 1.451 8675.70 1.146 8769.14 1.049 8860.57 0.930 8899.03 1.125 8973.66 1.313 9021.98 4.234 9118.71 2.431 921.5.18 3.697 9310.53 2.269 9404.12 4.376 9503.73 0.951 9600.05 1.231 9690.81 0.000 9721.44 Projected Survey • • 26 September, 2005 - 10:07 Page 5 of 6 DrillQuesf 3.03.06.008 Ha(itiiburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-170P81 Your Ref: 500292326470 Job No. AK-ZZ-0003778283, Surveyed: 25 July, 2005 Western North Slope ~.....,..,.,....~ s.. Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11230.00 3551.36 9721.44 S 752.94E Projected Survey Survey tool program for 1E-170PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 826.00 815.65 CB-SS-Gyro 826.00 815.65 11230.00 3551.36 MWD+IIFR+MS+SAG ConocoPhillips • • 26 September, 2005 - 10:07 Page 6 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Western North Slope ConocoPhillips • Kuparuk 1 E 1 E-170PB2 Job No. AK-ZZ-0003778283, Surveyed: 28 July, 2005 Survey Report 26 September, 2005 Your Ref: 500292326471 Surface Coordinates: 5959339.91 N, 549889.64E (70° 17' 58.8873" N, 149° 35' 45.4351" V1~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959339.91 N, 49889.64E (Grid) Surface Coordinates relative to Structure: 420.32 S, 2.66 W (True) Kelly Bushing Elevation: 111.05ft above Mean Sea Level Kelly Bushing Elevation: 111.05ft above Project V Reference Kelly Bushing Elevation: 111.05ft above Structure t~1WL~IAIG SERRl1CE5 Survey Ref: svy2186 A Halliburton Company Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-170P82 Your Ref.• 500292326471 Job No. AK-ZZ-0003778283, Surveyed: 28 July, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth In cl. Azim. Depth Depth Northings Eastings Northings Eastin gs (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10387.29 77. 910 179. 940 3334.72 3445.77 8899.03 S 873. 35E 5950446.88 N 550822. 06 E 10420.00 78. 050 180. 290 3341.53 3452.58 8931.02 S 873. 29E 5950414.89 N 550822. 21 E 10510.14 81. 700 178. 320 3357.37 3468.42 9019.73 S 874. 38E 5950326.19 N 550823. 88 E 10582.75 82. 520 178. 570 3367.34 3478.39 9091.62 S 876. 33E 5950254.30 N 550826. 31 E 10679.10 85. 100 178. 910 3377.73 3488.78 9187.38 S 878. 43E 5950158.56 N 550829. 05 E 10778.78 87. 290 177. 910 3384.34 3495.39 9286.80 S 881. 19E 5950059.17 N 550832. 47 E 10877.53 90. 970 178. 480 3385.84 3496.89 9385.47 S 884. 30E 5949960.52 N 550836. 23 E 10969.91 90. 760 177. 850 3384.45 3495.50 9477.79 S 887. 26E 5949868.22 N 550839. 80 E 11067.41 88. 900 177. 720 3384.74 3495.79 9575.21 S 891. 03E 5949770.82 N 550844. 22 E 11155.13 90. 730 179. 700 3385.02 3496.07 9662.90 S 893. 00E 5949683.15 N 550846. 78 E 11243.36 92. 550 180 .760 3382.50 3493.55 9751.09 S 892. 65E 5949594.96 N 550847. 01 E 11336.09 92. 110 181 .130 3378.73 3489.78 9843.73 S 891. 12E 5949502.31 N 550846. 09 E 11422.94 97. 840 182 .010 3371.20 3482.25 9930.18 S 888. 75E 5949415.85 N 550844. 30 E 11520.88 93. 720 179 .040 3361.33 3472.38 10027.59 S 887. 87E 5949318.44 N 550844. 07 E 11616.73 89. 610 179 .020 3358.55 3469.60 10123.36 S 889. 49E 5949222.67 N 550846. 32 E 11709.32 84 .760 179 .310 3363.10 3474.15 10215.81 S 890 .84E 5949130.24 N 550848. 28 E 11799.87 87 .650 181 .400 3369.09 3480.14 10306.14 S 890 .28E 5949039.91 N 550848. 32 E 11887.00 87 .650 181 .400 3372.66 3483.71 10393.17 S 888 .15E 5948952.86 N 550846. 77 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11887.OOft., The Bottom Nole Displacement is 10431.05ft., in the Direction of 175.116° (True). Dogleg Vertical Rate Section (°/100ft) 8899.03 1.131 8931.02 4.585 9019.73 1.180 9091.62 2.701 9187.38 2.414 9286.80 3.771 9385.47 0.719 9477.79 1.912 9575.21 3.074 9662.90 2.387 9751.09 0.620 9843.73 6.674 .9930.18 5.176 10027.59 4.288 10123.36 5.247 10215.81 3.936 10306.14 0.000 10393.17 ConocoPhillips Comment Tie-On Point Window Point • Projected Survey • 26 September, 2005 - 10:15 Page 2 of 3 L7rillQuesf 3.03.06.008 - - - Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-170PB2 Your Ref.• 500292326471 Job No. AK-ZZ-0003778283, Surveyed: 28 July, 2005 Western North Slope Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 10387.29 3445.77 8899.03 S 873.35E Tie-On Point 10420.00 3452.58 8931.02 S 873.29E Window Point 11887.00 3483.71 10393.17 S 888.15E Projected Survey Survev tool program for 1E-170PB2 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 826.00 815.65 CB-SS-Gyro (1E-170PB1) 826.00 815.65 11887.00 3483.71 MWD+IIFR+MS+SAG (1E-170P61) ConocoPhillips • r~ 26 September, 2005 - 10:15 Page 3 of 3 DriflQuest 3.03.06.008 DEFi~dTIVE Halliburton Sperry-Sun Western North Slope ConocoPhillips • Kuparuk 1 E 1 E-170PB3 Job No. AK-ZZ-0003778283, Surveyed: 3 August, 2005 Survey Report 26 September, 2005 Your Ref.•500292326472 Surface Coordinates: 5959339.91 N, 549889.64E (70° 17' 58.8873" N, 149° 35' 45.4351 " Vy) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959339.91 N, 49889.64E (Grid) Surface Coordinates relative to Structure: 420.32 S, 2.66 W (True) Kelly Bushing Elevation: 111.05ft above Mean Sea Level Kelly Bushing Elevation: 111.05ft above Project V Reference Kelly Bushing Elevation: 111.05ft above Structure S~el'~1'~~-S1..1-i o~i~~tN6 SERVICES Survey Ref:svy2187 A Halliburton Company Hatliburton Sperry-Sun Survey Report for Kuparuk 1 E - 1 E-170P83 Your Ref: 500292326472 Job No. AK-ZZ-0003778283, Surveyed: 3 August, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 11336.09 92.110 181.130 3378.73 3489.78 9843.73 S 891.12E 5949502.31 N 550846.09E 9843.73 Tie-On Point 11342.00 92.215 181.185 3378.50 3489.55 9849.63 S 891.00E 5949496.41 N 550846.01E 2.007 9849.63 Window Point 11370.41 92.720 181.450 3377.28 3488.33 9878.01 S 890.35E 5949468.03 N 550845.55E 2.007 9878.01 11408.94 92.540 180.750 3375.51 3486.56 9916.49 S 889.61E 5949429.54 N 550845.07E 1.874 9916.49 11503.76 94.400 179.240 3369.77 3480.82 10011.13 S 889.62E 5949334.91 N 550845.70E 2.525 10011.13 11597.21 94.530 177.980 3362.50 3473.55 10104.27 S 891.88E 5949241.79 N 550848.58E 1.351 10104.27 11690.60 92.920 178.590 3356.43 3467.48 10197.42 S 894.67E 5949148.66 N 550851.99E 1.843 10197.42 11786.24 90.900 176.900 3353.24 3464.29 10292.92 S 898.43E 5949053.18 N 550856.38E 2.753 10292.92 11878.54 88.800 176.360 3353.48 3464.53 10385.06 S 903.85E 5948961.08 N 550862.42E 2.349 10385.06 11972.80 90.100 178.110 3354.39 3465.44 10479.20 S 908.40E 5948866.98 N 550867.59E 2.313 10479.20 12073.00 92.900 178.730 3351.77 3462.82 10579.31 S 911.16E 5948766.88 N 550871.02E 2.862 10579.31 12102.12 94.140 179.560 3349.98 3461.03 10608.37 S 911.59E 5948737.82 N 550871.64E 5.121 10608.37 12166.38 94.280 180.300 3345.26 3456.31 10672.46 S 911.67E 5948673.74 N 550872.15E 1.169 10672.46 12263.10 93.320 180.700 3338.85 3449.90 10768.96 S 910.83E 5948577.23 N 550871.95E 1.075 10768.96 12358.57 92.870 180.310 3333.70 3444.75 10864.29 S 909.99E 5948481.90 N 550871.74E 0.623 10864.29 12455.33 91.960 180.180 3329.62 3440.67 10960.96 S 909.58E 5948385.23 N 550871.97E 0.950 10960.96 12549.53 92.110 180.070 3326.27 3437.32 11055.10 S 909.37E 5948291.09 N 550872.39E 0.197 11055.10 12644.14 89.550 181.950 3324.90 3435.95 11149.67 S 907.70E 5948196.51 N 550871.35E 3.357 11149.67 12739.36 90.780 182.360 3324.63 3435.68 11244.82 S 904.12E 5948101.34 N 550868.40E 1.362 11244.82 12834.42 89.990 181.710 3323.99 3435.04 11339.82 S 900.75E 5948006.32 N 550865.65E 1.076 11339.82 12927.83 89.600 182.140 3324.32 3435.37 11433.18 S 897.61E 5947912.94 N 550863.14E 0.621 11433.18 13021.63 90.720 182.400 3324.06 3435.11 11526.90 S 893.89E 5947819.20 N 550860.04E 1.226 11526.90 13116.35 91.000 182.770 3322.64 3433.69 11621.51 S 889.62E 5947724.56 N 550856.40E 0.490 11621.51 13210.45 91.490 182.150 3320.60 3431.65 11715.50 S 885.59E 5947630.54 N 550852.99E 0.840 11715.50 13305.63 92.630 181.800 3317.18 3428.23 11810.57 S 882.31E 5947535.46 N 550850.34E 1.253 11810.57 13401.26 91.960 181.470 3313.35 3424.40 11906.08 S 879.58E 5947439.93 N 550848.25E 0.781 11906.08 13497.17 91.400 181.580 3310.53 3421.58 12001.91 S 877.03E 5947344.08 N 550846.33E 0.595 12001.91 13591.81 92.990 181.490 3306.91 3417.96 12096.45 S 874.50E 5947249.54 N 550844.43E 1.683 12096.45 13686.65 91.790 181.530 3302.95 3414.00 12191.17 S 872.00E 5947154.80 N 550842.56E 1.266 12191.17 13782.29 90.800 179.930 3300.79 3411.84 12286.77 S 870.78E 5947059.19 N 550841.98E 1.967 12286.77 13932.61 94.270 181.340 3294.15 3405.20 12436.91 S 869.12E 5946909.04 N 550841.31E 2.491 12436.91 14024.21 96.140 181.990 3285.84 3396.89 12528.09 S 866.47E 5946817.85 N 550839.27E 2.160 12528.09 14116.06 94.580 182.920 3277.26 3388.31 12619.45 S 862.55E 5946726.46 N 550835.96E 1.975 12619.45 14208.27 94.710 182.090 3269.79 3380.84 12711.27 S 858.54E 5946634.62 N 550832.55E 0.908 12711.27 14301.30 93.920 181.820 3262.79 3373.84 12803.98 S 855.37E 5946541.89 N 550830.00E 0.897 12803.98 • 26 September, 2005 - 10:24 Page 2 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-170P63 Your Ref.•500292326472 Job No. AK-ZZ-0003778283, Surveyed: 3 August, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 14397.00 93.920 181.820 3256.25 3367.30 12899.41 S 852.34E 5946446.45 N 550827.60 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14397.OOft., The Bottom Hole Displacement is 12927.54ft., in the Direction of 176.220° (True). Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11336.09 3489.78 9843.73 S 891.12E Tie-On Point 11342.00 3489.55 9849.63 S 891.00E Window Point 14397.00 3367.30 12899.41 S 852.34E Projected Survey Survey tool program for 1E-170PB3 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 826.00 815.65 CB-SS-Gyro (1E-170PB1) 826.00 815.65 14397.00 3367.30 MWD+IIFR+MS+SAG (1E-170PB1) ConocoPhillips Dogleg Vertical Rate Section Comment (°/100ft) 0.000 12899.41 Projected Survey • • 26 September, 2005 - 10:24 Page 3 of 3 ©riNQuest 3.03.06.008 10/31 /05 ~~ill~~mil~~,~~i~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 3513 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 1R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 1Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16105 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 26-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 2C-04 11022934 INJECTION PROFILE 10/14/05 1 M-07 REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01A 11072922 INJECTION PROFILE 10I26I05 1 1R-10 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1E-170 11015750 USIT 10/19105 1 1J-154 11022931 USIT 10/12105 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 v SIGNED: v~~~~"'C~~4 DATE: ~~ IU 6 V ~ a n ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • dos'- e~y RE: FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Bond... • • Subject: RE: FW: Kuparukl E-170 West Sak Producer - Casing Repair (Sundries 305-? 5 3, 305-284, and 305-285) From: "Mukavitz; Steve J" <Steve.J.Mukavitz@conoeophillips.com> Date: Mon, 07 Nov 2005 14:3L'3(i -0900 To: l~hon~as l~~iaunder ~~=ti~m maunder(rr~adn~in.state.ak.us:=~ We're hypothesizing that the bottom leak is due to over-torqueing the 9-5/8" liner in the liner hanger area while running the string and rotating to get it in the hole. The upper leak is in a 4-5` interval with 25-35% wall loss in the casing, probably associated with casing wear. We`re sti{{ boking at trying to determine what or when the wear imay have occurred. {t was isolated to just this one spot. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 O ~ r,~^ ~ ~.~. ~~~ ~01~ -----Original Message----- From: Thomas Maunder [rriailto:tom_maunder@admin.state.ak.us] Sent: Monday, November 07, 2005 9:30 AM To: Mukavitz, Steve J Subject: Re: FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Sundries 305-283, 305-284, and 305-285) Good news. Any determination as to the cause of the leaks?? Tom Maunder, PE AOGCC Mukavitz, Steve J wrote, On 11/7/2005 9:21 AM: Tom, Update on 1 E-170 for your info. We squeezed the upper {eak from 4752' - 4757' MD and tested to 2500 psi last week. We then ran the Baker expandable casing patch over the weekend and successfu{ly patched the {over leak fram 4856' - 4861' MD. We then tested the entire 9-518'" string to 2500 psi and it held great. We're current{y preparing to run the 4-112" completion. Let me know if you have questions. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501. 907-263-4021 1 of 3 11/7/2005 2:49 PM • Subject: FVF~: Kuparuk 1E-17(} West Sak Producer -Casing Repair (Sundries 305-283, 305-284, and 305-285) From: "IVfukavitz, Steve J" <Steve.3.Mukavitz~conocophillips.com> Date: Mon, 07 Nov 2005 09:21:29 -0900 ~~~~J~ - ~j ~ ~ ~'_'" To: Thomas Maunder <tom_~aunder~a~admn.state.ak.us> CG "Gober~ Howard" <Howard.Gaber~u conocophiilips.com> V Tom, ~V Update on 1 E-170 for your info. We squeezed the upper leak from 4752' - 4757' M© and tested to 2500 psi last week. We then ran the Baker expandable casing patch over the weekend and successfully patched the lower leak from 4856' - 4861' MD. We then tested the entire 9-518" string to 2500 psi and it held great. We're currently preparing to run the 4-112" completion. Let me know if you have questions. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 -----Original Message----- From: Mukavitr, Steve J Sent: Thursday, October 20, 2005 8:32 AM To: 'tom maunder@admin.state.ak.us' Subject: FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Sundries 305-283, 305-284, and 305-285) Tom, We rigged up on 1 E-170 in Kuparuk (tri-lateral West Sak producer) over the weekend and are proceeding with our diagnostics and repair of the 9-5/8" production casing. Further testing on Tuesday indicates a second leak in the 9-518" casing, 100' above the first. We have a 30' Saker expandable casing patch on location, but this obviously won't cover both leaks. Lead time on additional patch cladding to extend the patch is 8 weeks. 1 talked to Winton yesterday about squeezing the upper leak and attempting to get a pressure test prior to running the patch over the lower leak. The upper leak is in the 9-5i8" tie-back string (we ran the 9-518" tieback after the 9-5i8" liner was set, and the upper leak is above the 13-3i8" x 9-518" packer at the bottom of the tieback string). We'll essentially be circulating cement into the annulus {plan is 1000' of cement). We'll pressure test to 2500 psi when finished with the cement and patch. Winton indicated to continue under our current Sundry Approvals for the well. Please call if you have questions or need more information. Regards, Steve Mukavitz 1 oft 11/7/2005 11:08 AM ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 -----Original Message----- From: Nabors 3S Company M Sent: Wednesday, October 19, 2005 7:58 AM To: Mukavitz, Steve J Subject: Leaks Steve After back strapping out of hole with kill string leak depths where determined to be (bottom leak 4861'-4856' RKB top leak 4757'-4752' RKB) overall length of 109' of bad pipe. Just wanted to make sure you had the right depths and length for patch design. I put an update in Dims Nabors 3S Rig Supervisor (907) 659-7639 Office (907) 659-7295 Fax 2 oft 11/7/2005 11:08 AM • ~ ~~~ ~, n~~~ "'~'~ ,, AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-170 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. 'fi::isn 05ct'0~ Tie-on Survey: 13,686.65' MD Window /Kickoff Survey: 13,768.00' MD (if applicable) Projected Survey: 15,940.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~7 ~~~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~ ` ~~ • AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-170 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the .PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,230.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Si ned ~1 • ~-c ~ g Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • ,.,n 05-Oct-05 ;:a~4;~:~;is~~~n ~~~ -~ • ~~ ~ ~ ` ~, 05-Oct-05 ` AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-170 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and ~.PDF files. Tie-on Survey: 10,387.29' MD Window /Kickoff Survey: 10,420.00' MD (if applicable) Projected Survey: 11,887.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Si ned Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-170 PB3 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,336.09' MD ti k i~^ fit-. ~` ~ ~17~5 ~, - 05 Window /Kickoff Survey: 11,342.00' MD (if applicable) Projected Survey: 14,397.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~~ ~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~5 -a?y • AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 • Re: Distribution of Survey Data for Well 1 E-170 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 13,686.65' MD Window /Kickoff Survey: 13,768.00' MD (if applicable) Projected Survey: 15,940.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date oC.~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~ 1 ~~`, 5~ 05-Oct-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 E-170 PB1 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,230.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~J Re: Distribution of Survey Data for Well 1 E-170 PB2 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,387.29' MD Window /Kickoff Survey: 10,420.00' MD (if applicable) Projected Survey: 11,887.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. ~~ Anchorage, AK 99518 , /~ _„ / ~ , Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ a~ - oz~l C, AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 E-170 PB3 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,336.09' MD Window /Kickoff Survey: 11,342.00' MD (if applicable) Projected Survey: 14,397.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~~ ~~~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~...... .. .~»t..».».. .~. .... .. ...,~ .........vuuvv ~.~uab a~vruu ~v uiiu... • Subject: RE: FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Sundries 305-283, 305-284, and 305-285) From:. "Mukavitz, Strive J" <Steve.J.Mukavitz a~conocophillips.com> Date: Thu, 20 Oct 2005 11:31:09 -0800 To: Thomas Maunder <tom riiaunder@admin.state.ak_us> ~ - C~ ~ ~( Tom, ~l ~ Sorry far the late reply. Been chasing things all morning. _~~~ The 13-3/8" x 9-518" annulus is full of diesel right now.... we're actually pumping some additional diesel down the backside as we speak to ensure it`s foil after doing some injection testing this morning. We're going to pump our normal Arctic Set 1 cement we use for surface casing since we're so shallow {2000 - 2300' TVDj and ensure we spot cement across the leaks prior to circulating cement to minimize any brine in the annulus (we have 9.6 in there now). We've been working an a plan where we actually squeeze the upper and lower leaks together... figure it can't hurt to get cement in the bottom leak as well and this will save us a drill out of a plug. This will also help get cement across the upper leak before opening up the backside and taking returns to bring the cement into the annulus. The upper leak takes fluid much easier than the lower as expected (the tower's already been squeezed a couple times as you probably recall) which is fine since it's our primary focus. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, October 20, 2005 8:42 AM To: Mukavitz, Steve J Subject: Re: FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Sundries 305-283, 305-284, and 305-285) Steve, Your plan does sound appropriate, unfortunately. Will placing the cement give any problems with freeze protection?? Tom Maunder, PE AOGCC Mukavitz, Steve J wrote, On 10/20/2005 8:31 AM: Tom. We rigged up on 1 E-170 in Kuparuk (tri-lateral West Sak producer) over the weekend and are proceeding with our diagnostics and repair of the 9-5I8" production casing. Further testing on Tuesday indicates a second Peak in the 9-518°' casing, 100` above the first. We have a 30' Baker expandable casing patch on location, but this obviously won't cover both leaks. Lead 1 of 2 11/7/2005 11:09 AM Time on additional patch cladding to extend the patch is 8 weeks. I talked to 11Vinton yesterday about squeezing the upper leak and attempting to get a pressure test prior to running the patch over the lower {eak. The upper leak is in the 9-5/8"' tie-back string (we ran the 9-518" tieback after the 9-518" liner was set, and the upper leak is above the 13-3/8" x 9-518" packer at the bottom of the tieback string}. l1Ve'll essentially be circulating cement into the annulus (plan is 1000' of cement}, We`ll pressure test to 2500 psi when finished with the cement and patch. 1Ninton indicated to continue under our current Sundry Approvals for the well. Please call if you have questions or need more information. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 -----Original Message----- ... From: Nabors 3S Company M Sent: Wednesday, October 19, 2005 7:58 AM To: Mukavitz, Steve J Subject: Leaks Steve After back strapping out of hole with kill string leak depths where determined to be (bottom leak 4861'-4856' RKB top leak 4757'-4752' RKB) overall length of 109' of bad pipe. Just wanted to make sure you had the right depths and length for patch design. I put an update in Dims Nabors 3S Rig Supervisor (907) 659-7639 Office (907) 659-7295 Fax 2 of 2 11!7/2005 11:09 AM • j E ~ ~ ' ~ '~ ` ? ~ . a ~ ~ ~ '' a l t ~ ~ ~ ~ ~ j ~ .~LASSA OII, A1~TD GAS COI~SER~ATIOi`T COMI~IISSIOI~T Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: 1 E-170 Sundry Number: 305-285 Dear Mr. Thomas: • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~o~, ti 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this l~ day of September, 2005 Encl. • ConocoPhillips September 23, 2005 Randy Thomas GKA Drilling Team Leader Drilling ~ Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RE~E~V~E SEP 2 6 2D~5 Commissioner Alaska Oil & Gas Cpns. Commission State of Alaska Alaska Oil & Gas Conservation Commission Anchorage 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 1 E-170, 1 E-170L1, 1 E-170L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk multilateral 1 E-170, 1 E-170L1 and 1 E-170L2. We are planning to re- enterthis well, do a workover and run tubing according to the attached procedure. The Nabors 3S rig is scheduled to perform this work. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, l R. Thomas GKA Drilling Team Leader CPAI Drilling and Wells RT/skad • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION `~~~ ~~~~ APPLICATION FOR SUNDRY APPROVAL ~~P ~ ~ ~~~~ 20 AAC 25.280 ~c/'1 1. Type of Request: Abandon ^ Suspend ^ Operational Shyklown ^ Perforate ~~ I aver " ' ifter ^ ~ln~~~f~ Alter casin Re air well Plu Perforations g ^ p ^ g ^ Stimulate ^ Time Extension Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: ~ 5. Per Drill Number: ConocoPhillips Alaska, Inc. Development ^/ Exploratory ^ 205-074 / 305-271 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23264-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' 1 E-170 8. Property Designation: 10. Field/Pool(s): ADL 25660, ALK 470 Kuparuk River Field /West Sak 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): 15940' 3354' Casing Length Size MD TVD Burst Collapse Conductor g0' 20" x 34" 120' 120' Surface 5011' 13-3/8" 5054' 2311' Intermediate 10371' 9-5/8" 10414' 3451' Liner 6049' 5.5" 15919' 3355' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none none Packers and SSSV Type: Packers and SSSV MD (ft) HRD ZXP liner pkr @ 9870' no SSSV no SSSV 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 3, 2005 Oil ~ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Mukavitz @ 263-4021 Printed Name Rand Thomas Title: GKA Drilling Team Leader Signature ~'~ ~ Phone z~rdi~3o Date `j ~~ has Commission Use Onl Conditions of a roval: Notif Commission so that a re resentative ma witness Sundry Numb ~~~ pp y p y Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~~~ PS `. ~i~-~ ~ V'-~ ~~~ '~C `~~ 1~6./Itll~7 ~I•~ ~~~ ~ ~ 2Q~~J Subsequent F eq APPROVED BY D Appra COMMISSIONER THE COMMISSION Date: Form 10-403 ed 7/2005 ~ ` Submit in Duplicate . « ~ Rig Workover Procedure • Well 1E-170 West Sak Producer The objectives of the rig workover are as follows: ^ Re-locate and confirm the presence of a single leak in the 9-5/8" casing from approximately 4858' - 4860' MD using the 3-1/2" work string and test packer. While setting and testing the "B" lateral LEM and ZXP packer, communication was suspected between the 9-5/8".casing and 13-3/8" x 9-5/8" annulus. This could be the result of a second leak in the 9-5/8" tieback string above the 13-3/8" x 9-5/8" packer, or the result of the 13-3/8" x 9-5/8" tieback string packer leaking and allowing communication from the production casing through the existing leak to the 13-3/8"' x 9-5/8" annulus. ^ Make a casing scraper run with a gauge ring to ensure clean casing across the patch interval. ^ Install a Baker expandable casing patch (approximately 32' long) over the suspected 9- 5/8" casing leak from 4858' - 4860' MD. Test the production casing to 2500 psi. ^ Retrieve the 7" RBP in the "D" lateral LEM • Run the 4-1/2" production tubing and ESP, and nipple up the tree • ~a ~ as , 4 '=°i +~' t } a 1 ' ~'~ l~ , ,~ : ~ ~ ~ ~ ~ ~ ' ' ' ; a ~ ; ~~ ~ ; ~, ~ "®' ~ ~"' ' ~ ~ ' ~ ~'°~'~ ~.~ FRANK H. MURKOWSKI, GOVERNOR a` ~1 ~ ~+ ~+ ~~ ~~ ~ ~ ~~~ 333 W. T" AVENUE, SUITE 100 C0~-7ERQ~ii01s CQ~IISSj~~ ji'Y ANCHORAGE, ALASKA 99501-3539 PHONE (907} 279-1433 FAX (907) 276-7542 Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk 1 E-170 Sundry Number: 305-271 Dear Mr. Thomas: ~~~. 01 ~' 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 1 John K. Norman Chairman DATED this~~'day of September, 2005 Encl. ~~~~ STATE OF ALASKA ~ t~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^~ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 205-074 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-2321;4-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' 1 E-170 8. Property Designation: 10. Field/Pool(s): ADL 25660, ALK 470 Kuparuk River Field /West Sak 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): 15940' 3354' Casing Length Size MD TVD Burst Collapse Conductor g0' 20" x 34" 120' 120' Surface 5011' 13-3/8" 5054' 2311' Intermediate 10371' 9-518" 10414' 3451' Liner 6049' 5.5" 15919' 3355' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none none Packers and SSSV Type: Packers and SSSV MD (ft) HRD 2XP liner pkr @ 9870' no SSSV no SSSV 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 9, 2005 Oil Q Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: at /9/05 ~ WAG [] GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve McKeever @ 265-6826 Printed Name Randy Thomas Title: GKA Drilling Team Leader t Signature ~-\ ,ti..`;, Phone ~'f'~6~3~ Date ~ ~t 3 ~p ~` Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -~a.. Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ aran Location Cle ce ^ Other. I~®~Mla~ bTFL SEA ~ ~ ~Q~~ ' ' '~.••'"' ~ °' r ; %'i05 Subsequent Form Required: t.~Q'? J ~~~ ~~ ~~~ ~~ ~ S~ ~..~C~ ~ ~~ ~ ~~F"''t'~ ~~5~~ ~ 1 _ ~ APPROVED BY ~~ CC''- -~ '' W Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revi~ d 7/2005 ~ ~ ~ ~ ~~ ~ ~ Submit in Duplicate Re: 1E-170 (L1 and L2) Suspension Operations~Plan Subject: kc: 1E-170 (L1 and L2) Suspen~ionOperations and Plan ~ aos-o~y ~-- -o~ S From: Thom ~~ ~~Iaunder<tom marinderrcr~~admin.state.ak.us> , ~~ Date: Fri, 09 Scp ?OUP 11:(?:l4 -(100 To: "~~1cKeevcr_ Steve" <__Steve.ti~IcKecvcr~cl?conocophillips.com% CC: "(;reener, !~1il:c R." <=Ittike.R.Grc~ncr~ci?coni~cophillips.com=. "A~lukavitz. Steve J'• °=Steve.J.iVlukavit~<<i:conocophillips.com> ";'~llsup-Drake, Sharon K" ~~~Sharon.K.~11Isup-Drakc'~rconocophillips.com==, I_ou Grimaldi ~lou«rinlaldi'a;~adi~~in.state.ak.u5=> Steve, et al: Thanks for the information. As we discussed this morning, I was able to find some prior messages regarding the leak at/near the liner hanger and the remaining work of drilling and equipping the laterals was conducted according to the plans transmitted in those messages. At this point, it is probably appropriate to designate this as an "operational SD" and a sundry is necessary. My reasoning is that the rig will be changed and there is a some amount of new work that will be planned for 3 S to accomplish. Starting the 3 S work will also require submitting a sundry to transmit the work plan. Based on the information you have provided, you may continue with the work to secure the well and move off the rig. I will look forward to receiving the sundries. Sharon, just send in the 4~forms. I will attach this message as back up. Tom Maunder, PE et~-3 AOGCC McKeever, Steve wrote, On 9/9/2005 10:50 AM: Tom- As we discussed this morning, we are in the process of suspension operations on our well 1E-170, in anticipation of moving off Doyon 15 and completing the work with Nabors 3S later this month.. I have attached a summary of our recent Doyon 15 operations on this well. Summarizing those operations, we successfully ran a liner into the upper lateral and ran the LEM assembly into the upper hook hanger. This LEM assembly had a joint of 7" casing just below the ZXP packer, allowing us to set and test a retrievable bridge plug in that joint of 7", providing full hydraulic isolation from all three laterals. Following the test of the bridge plug with a retrievable test packer, the wellbore above the plug was displaced to 9.6 ppg NaCI brine, and the 3-1/2" work string and test packer were hung off from the tubing hanger. Currently we are preparing to nipple down the BOP, nipple up and test the tree, and move off the well. Nabors 3s will move onto the well later this month. Once they have nippled up and tested their BOP stack the plan is to: • Re-locate and confirm the presence of a single leak in the 9-5/8" casing from approximately 4858' - 4860' MD (x-over below the 9-5/8" liner hanger) using the 3-1/2" work string and test packer currently hung off in the well as a kill string. 1 of 2 9/9/2005 1:55 PM Re: IE-170 (LI and L2) Suspension Operations~Plan • • Install a Baker expandable casing patch over the 9-5/8" casing leak from 4858' - 4860' MD. Test the production casing to 2500 psi. '' Retrieve 7" retrievable bridge plug in "D" sand Lateral Entry Module. • Run the 4-1/2" production tubing and ESP completion and nipple up the tree. Please let me know if you approve this plan of operations, and if any further paper work in required. Thanks kindly. «1E-170 Suspension Operations.pdf» Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. 700 "G" Street Anchorage, Alaska 99501 steve.ckeeverC conocophi Ilps.com office: 907/265-6826 fax: 907/265-1535 pager: 907/275-0369 "The short fortune-teller who escaped from prison was a small medium at large." 2 of 2 9/9/2005 1:55 PM • • Legal Well Name: 1 E-170 Common Well Name: 1 E-170 ConocoPhillips Alaska Page 42 of 44 Operations Summary Report Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Phase Code 9/5/2005 21:30 - 00:00 2.50 CMPLTN TRIP CMPLT3 9/6/2005 00:00 - 02:00 2.00 CMPLTN TRIP CMPLT3 02:00 - 02:15 0.25 CMPLTN SFTY CMPLT3 02:15 - 02:30 0.25 CMPLTN OTHR CMPLT3 02:30 - 03:30 1.00 CMPLTN PULD CMPLT3 03:30 - 04:30 1.00 CMPLTN PULD CMPLT3 04:30 - 04:45 0.25 CMPLTN SFTY CMPLT3 04:45 - 06:00 1.25 CMPLTN PULD CMPLT3 06:00 - 06:45 06:45 - 07:00 07:00 - 07:15 07:15 -12:45 0.75 0.25 0.25 5.50 CMPLTN PULD CMPLTN PULD CMPLTN OTHR CMPLTN TRIP CMPLT3 CMPLT3 CMPLT3 CMPLT3 12:45 - 13:00 0.25 13:00 -13:15 0.25 13:15 -13:45 0.50 13:45 - 14:00 0.251 14:00 - 14:15 0.25 14:15 -16:00 1.751 16:00 - 22:00 6.00 22:00 - 22:30 0.50 22:30 - 00:00 1.50 9/7/2005 00:00 - 03:00 3.00 03:00 - 03:15 0.25 03:15 - 04;00 0.75 04:00 - 05;00 1.00 05:00 - 05:15 0.25 CMPLTN TRIP CMPLT3 CMPLTN OTHR CMPLT3 CMPLTN CIRC CMPLT3 CMPLT PCKR ~ CMPLTN OTHR CMPLT3 CMPLT3 CMPLTN~TRIP CMPLT3 RIGMNT RGRP CMPLT3 CMPLTN TRIP CMPLT3 CMPLTN TRIP CMPLT3 CMPLTN TRIP CMPLT3 CMPLTN SFTY CMPLT3 CMPLTN PULD CMPLT3 CMPLTN OTHR CMPLT3 CMPLT SFTY CMPiT3 Spud Date: 6/26/2005 Start: 6/21/2005 End: Rig Release: Group: Rig Number: 15 Description of Operations POOH w/ hook hanger running tools f/ 9260' to 4493'. POOH w/ hook hanger running tools f! 4493' to BHA inner string PJSM on UD inner string 2 7/8" Clean rig floor. UD 2 7/8" inner string. Clear floor of tools. PU tools to PU 4 1/2" LEM. PJSM on running 4 1/2" LEM f/ "D" lateral. PU/MU 4 1/2" LEM consisting of :Baker seal assembly, (1) jt 4 1/2" 12.6 ppg L-80 IBT x STL, (7) jts 4 1/2" 12.6ppf L-80 IBTM tubing, 4 1/2" pup jt, LEM, (3) 4 1/2" pup jts, 4 1/2" casing swivel, crossover bushing 5 1/2 563 x 4 1/2" IBT, 190-47 casing seal bore, crossover 7" x 5 1/2" 563, (1) jt 7" 26 ppf, L80 Hydril 563 casing Make up 2 7/8" inner string to 9 5/8" x 7" ZXP liner top packer. Make up 9 5/8" x7" ZXP liner top packer, Check screws. OK. Clean rig floor, remove csg tools. RIH on 5" dp : 4 1/2" LEM consisting of :Baker seal assembly, (1) jt 4 1/2" 12.6 ppg L-80 IBT x STL, (7) jts 4 1/2" 12.6ppf L-80 IBTM tubing, 4 1/2" pup jt, LEM, (3) 4 1/2" pup jts, 4 1/2" casing swivel, crossover bushing 5 1/2 563 x 4 1/2" IBT, 190-47 casing seal bore, crossover 7" x 5 1/2" 563, (1) jt 7" 26 ppf, L80 Hydril 563 casing, Baker 9 5/8" x 7" ZXP liner top packer = 430.62' then Baker setting tool and 5' dp pup jt. Total of 441.59'. RIH 5 stands 5" slick (476.27', 74 stands 5" dp w/ to-tads (7316.41'), 12 stands 5" HWDP(1105.62') w/ 21.1' up. PU wt 230k, SO wt 120k. Slack off watching top of "D" lateral @ 9412.28' (did not see anything), Continue running stands of HWDP f/derrick. Run stand 92, 93,94,95, and 96. PU wt 245k, SO wt 125k. Continue RIH w/ stand 96 (17th stand of HWDP). Did not see crossover in "B" lateral @ 21' in (9728'), continue slack off to latch @ 37' in on stand 96 (9739' mule shoe depth) (9412,28' top of LEM in hook hanger of "D" lateral). Top of Casing seal receptacle in "B" lat LEM a 9729.91', bottom of casing seal receptacle @ 9749.31'. PU to 265k to verify latch. Drop 1 3/4" ball, pump down @ 5bpm w/ 500 psi f/ 100 bbls, slow to 3 bpm 300 psi, ball seated @ 120 bbls pumped. Pressure up to 3080 psi, set Baker ZXP packer @ 9308.62', presure to 4000 psi to release. PU, PU wt 240K-245K (verified release). PU 20' f/ 9308' to 9288'. Slack off 40k down w/ dogs to meth set packer as well. PU 20' rotate down w! 40k on liner top pkr twice. Monitor well, POOH w/ running tools f/ LEM f/ 9308' to 8135'. PU wt 245k, SO wt 120k. Attempt to break out 1st stand LoTad. High torque 30k. Broke 1st Lo Tad w/ rig tongs w! 30K. Repair/ replace top cylinder of iron roughneck breakout. POOH f/ 8135 to 7938'. Check out Iron roughneck by making breaks on stand 78, OK. Break & UD LoTad f/ stand 78. Pull stand 79, break and lay down LoTad f/ stand simulating laying down dp f/ derrick and removing LoTads. OK. Continue POOH f/ 7938' to 5964'. 51 stands Lotads in hole @ midnight Continue POOH f/ 5964' to 80' 51 stands Lotads in hole. PJSM on UD LEM tools. L/D LEM running tools. Pull Vetco/Gray wear bushing, clear rig floor. PJSM on PU 7" Baker Model WG Bridge plug and Baker Heavy duty Printed: 9/92005 10:19:09 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Code Phase Page 43 of 44 Spud Date: 6/26/2005 Start: 6/21/2005 End: Rig Release: Group: Rig Number: 15 Description of Operations 9/7/2005 05:00 - 05:15 0.25 CMPLTN SFTY CMPLT3 Model "EA" retrievamatic, w/ 3 1/2" IF joint and 3 1/2" XT38 DP. 05:15 - 06:00 0.75 CMPLTN PULD CMPLT3 MU 7" Baker Model WG Retievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 XT38, 3 1/2" XT38 DP. One joint made up @ 0600 hrs. 06:00 - 08:45 2.75 CMPLTN PULD CMPLT3 Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 XT38, on 71 joints 3 1/2" 13.3ppf XT38. Rabbit dp to 2 5/16". Torque 3 1/2" IF conn to 10k, XT38 Conn to 16.5k fUlb. 08:45 - 13:45 5.00 RIGMNT RGRP CMPLT3 Trouble shoot and repair of pipe handling machine. Selonoid valve and spool. 13:45 - 14:45 1.00 RIGMNT RSRV CMPLT3 Slip & cut 136' drilling line. 14:45 - 15:15 0.50 CMPLTN PULD CMPLT3 Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 XT38, on 71 joints 3 1/2" 13.3ppf XT38, then start w/ 3 1 /2" 15.5 ppf XT38, 44 jts of 15.5 ppf in hole now. Totaf of 115 jts XT in hole. Rabbit dp to 2 5/16". Torque XT38 conn to 16.5k ft/Ib. 15:15 - 18:00 2.75 CMPLTN PULD CMPLT3 Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 XT38, on 71 joints 3 1/2" 13.3ppf XT38, then start w/ 3 1 /2" 15.5 ppf XT38, 167 jts of 15.5 ppf in hole now. Total of 238 jts XT in hole. 18:00 -19:45 1.75 CMPLTN PULD CMPLT3 Continue RIH w/ 7" Baker Model WG Retievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 XT38, on 71 joints 3 1/2" 13.3ppf XT38, then start w/ 3 1/2" 15.5 ppf XT38, 167 jts of 15.5 ppf in hole now. Total of 295 jts XT Picked up. Tag 9.04' in on jt # 295. PU wt 165k, SO wt 75k. 19:45 - 20:00 0.25 CMPLTN OTHR CMPLT3 MU crossover on jt 295, MU top drive and tag top of liner @ 9308' (9.04' in on jt 295), bottom of bridge plug @ 9354.94'. PU, Break off single and drop 1-1/2" ball. 20:00 - 20:30 0.50 CMPLTN PCKR CMPLT3 MU single, SO tag liner top, PU 6' above tag, circ ball to seat @ 3bpm w/ 700 psi. Pressure up @ 50 bbls pumped. Pressure to 2300 psi. Pick up to 180k, shear off of bridge plug. Bridge plug top @ 9346.24', bottom @ 9348.94". Length of bridge plug 2.70' 20:30 - 21:00 0.50 CMPLTN PCKR CMPLT3 UD 2 jts, PU jt w/ x-o, MU top drive.Jt # 293 in hole while testing, jt 294 above rig floor. 9308' bottom of tool 21:00 - 23:00 2.00 CMPLT CIRC CMPLT3 Circulate bottoms up @ 5bpm w/ 1880 psi. Circ 600 bbls. 23:00 - 23:15 0.25 CMPLTN DEQT CMPLT3 RU to test Baker 7" Model WG Retrievable bridge plug set @ 9346.24' , ZXP liner top packer @ 9308' w/ test pkr @ 9259'. 23:15 - 00:00 0.75 CMPLTN DEQT CMPLT3 Rotate 5 turns to set packer. Set down 5k. Attempt to test Retrievable bridge plug. No test. PKR depth 9259'. Not enough weight to set test pkr. Circulating to surface. 9/8/2005 00:00 - 00:30 0.50 CMPLTN DEQT CMPLT3 Attempt to test Retrievable bridge plug &ZXP packer. No test. PKR depth 9259'. Not enough weight to set test pkr. Only 5k above block weight. Circulating to surface. 00:30 - 02:00 1.50 CMPLTN TRIP CMPLT3 POOH Ud 5 jts of 3 1/2" 15.5 ppf XT38 dp. Stand back 11 stands in derrick to 8211' 02:00 - 02:30 0.50 CMPLTN TRIP CMPLT3 Trip in hole w/ 11 stands 5" HWDP f/ 8211' to 9090'. 10 stands HW in hole. PU wt 190k. SO wt 105k. 02:30 - 03:00 0.50 CMPLTN DEQT CMPLT3 RIH f/ 9090' to 9163' (element center @ 9114'). Apply 5 rounds RH w/ 8k torque. Set test packer w/ 35k down wt to 70k block wt. Attempt to test, no test, PU to 9114', set 35k down wt. Printed: 9/9/2005 10:19:09 AM • ConocoPhllllps Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Code Phase Page 44 of 44 ~' ~, Spud Date: 6/26/2005 Start: 6/21/2005 End: Rig Release: Group: Rig Number: 15 Description of Operations 9/8/2005 03:00 - 03:45 0.75 CMPLTN DEOT CMPLT3 Test RBP @ 9346', ZXP liner top packer @ 9308' w/ test packer @ 9114'. Test to 2540 psi. Chart test. Held 97.3% of test pressure in 30 min. Pressure lost 68 psi f/ 2540 to 2472 psi. 03:45 - 04:00 0.25 CMPLTN OTHR CMPLT3 Bleed off pressure, unset packer. 04:00 - 04:30 0.50 CMPLTN TRIP CMPLT3 POOH f/ 9114' to 8170' w/ 5" HWDP. 04:30 - 05:15 0.75 CMPLTN TRIP CMPLT3 UD single 3 1/2" DP, TIH 11 stands 3 1/2" dp, PU 4 jts 3 1/2" dp. Total of 293 jts 3 1/2" in hole 27' up.=9308'. 05:15 - 07:30 2.25 CMPLTN OTHR CMPLT3 Flush surface lines, cement line, geopilot skid, kill and choke lines and manifold. 07:30 - 08:00 0.50 CMPLT SFTY CMPLT3 PJSM on displacing f/ 9.0 ppg SFOBM to 9.6 ppg Sodium Chloride. 08:00 - 10:00 2.00 CMPLTN CIRC CMPLT3 Displace 9.0 ppg SFOBM to 9.6 ppg Sodium Chloride. Pump @ 6 bpm w/ 1540 psi. Pump a total of 6285 strokes (632 bbls). 10:00 - 13:00 3.00 CMPLT OTHR CMPLT3 Cleaning on rig floor, transfer mud f/ rock washer while wait on brine to be brought over f/ mud plant in Prudhoe. 13;00 - 13:30 0.50 CMPLTN SFTY CMPLT3 RU truck of 290 bbls 9.6 brine. PJSM w/ crew. Fluid transfer paperwork. 13:30 - 14:15 0.75 CMPLT CIRC CMPLT3 Pump 290 bbls 9.6 ppg Sodium Chloride @ 6 bpm w/ 1540 psi. 14:15 - 14:30 0.25 CMPLTN TRIP CMPLT3 POOH 3 jt 3 1/2" 15.5 ppf S-135 XT38 dp. 290 jts left in hole total. 14:30 - 15:00 0.50 CMPLTN SOHO CMPLT3 PU/MU Vetco/Gray 13 3/8" x 4 1/2" M6222, 13 1/2" OD hanger w/ dummy installed as penetrator and two way check installed in hanger. MU to 4 1/2" landing joint w/ 4.909 MCA connection on top of hanger. 15:00 - 15:15 0.25 CMPLTN SOHO CMPLT3 Drain BOP stack to land kill string w/ running tool f/ 7" retrievalble bridge plug on bottom @ 9287.23' 15:15 - 15:45 0.50 CMPLTN DEOT CMPLT3 Run in LDS on Vetco Gray hanger. Test lower body seals to 5000 psi f/ 10 min. OK. Test upper body seals to 5000 psi f/ 10 min. OK. 15:45 -16:00 0.25 CMPLT OTHR CMPLT3 Back out landing joint. UD same. 16:00 -16:30 0.50 DRILL SFTY CMPLT3 PJSM. Install mouse hole. Rig up to UD 5" dp f/derrick. Have Total 170 stands 5" DP in derrick. 20 stands 5" HWDP, 83 stands w/ LoTads, 67 stands slick. Cleaning fluids f/pits and rock washer. 16:30 -18:00 1.50 DRILL PULD CMPLT3 UD total of 13 stands 5" HWDP. Cleaning fluids f/ pits and rock washer. 18:00 -19:30 1.50 DRILL PULD CMPLT3 UD total of 7 stands 5" HWDP. Cleaning fluids f/ pits and rockwasher. 19:30 - 21:30 2.00 DRILL PULD CMPLT3 UD 5" DP w/ LoTads. Total of 83 to UD. UD 17 stands @ 1930 hrs. Cleaning fluids f/ pits and rockwasher. I 21:30 - 00:00 2.50 RIGMNT RGRP CMPLT3 Pull Hyd cyl f/ pipe spinner on iron roughneck f/ repair. ~, I Printed: 9/92005 10:19:09 AM Re: 1E-170 Plug Back Subject: Re: 1E-170 Plug Back From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Mon, 25 Ju12005 15:25:08 -0800 ~O ~„_„~.~~ To: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com> Pat, Thanks for the information. Since the wellbore section is being plugged back for geological reasons and the ultimate BHL is not being changed, no further paperwork is needed. I will place a copy of this message in the well file. Good luck with your directional work. Tom Maunder, PE AOGCC Reilly, Patrick J wrote: Tom, We were not able to achieve our desired build rates on this well. We would like to plug back to the shoe and kick off the high side of the plug. The 9 5!8" shoe is at 10,414'. The 8'/2" TD is 11,248'. (834' Open Hole) We plan on pumping a 900-1000' balanced plug from TD to inside the 9 5/8" shoe. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reill~@,conocophillips.com «Patrick.J.Reilly(c~r.conocophillips.com.vcf» 1 of 1 7/25/2005 3:25 PM Re: 1E-170 Intermediate Cement ~ ~ Subject: Re: 1E-170 Intermediate Cement From: STMaunder@aol.com Date: Sat, 23 Ju12005 18:13:12 -0400 (EDT) ~~ To: Patrick.J.Reilly@conocophillips.com > ~!~ +~ CC: D15CM@conocophillips.com, tom_maunder@admin.state.ak.us 'y Pat and Fred, It appears that you all have clearly identified where the leak is and pumped serveral barrels of cement. The latest test is 690 psi on top of the mud column you have in the hole. When Pat and I talked, it was indicated that the EMW calculated with that pressure and the mud column 14.8 if I remember correctly. That was better than 2 ppg greater than the LOT at the 13-3/8" shoe and (assuming 9.0 ppg mud) better than 5 ppg greater than the MW. It is not likely that further applications of cement will improve the pressure tollerance. The plan to ultimately set a patch across the leak is a sound one. You are proposing to continue drilling the laterals as planned and then install the patch when the laterals are complete. Since your 12-1/4" hole penetrated all the sands of the West Sak without experiencing any pressure problems, there is little risk that drilling the laterals will result in encountering higher pressures than previously experienced. Your plan to proceed is acceptable. Pat, please contact me on Monday for an update. Feel free to call if there are additional developments. Tom Maunder, PE AOGCC I of 1 7/25/2005 9:05 AM 1E-170 Intermediate Cement • Subject: 1E-170 Intermediate Cement From: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com> Date: Sat, 23 Jul 2005 13:03:49 -0800 To: <stmaunder@aol.com> CC: "Doyon 15 Company Man" <D15CM@conocophillips.com> Tom, We would like to proceed with drilling the laterals on this well patch after running the lateral completion equipment. r ~~ y~~ We will install a casing The following is the chronology of events on the 1E-170 intermediate casing tests: INITIAL CASING TEST After running the tie back string - Pressured up to 3000 psi, pressure immediately dropped to 300 psi. Tested surface equipment to 3000 psi - OK. 1ST RTTS RUN Tested from 5059' - 10306' for 15 minutes at 3000 psi. - OK Tested from Surface to 4812' for 15 minutes at 3000 psi. - OK Tested 13 3/8" x 9 5/8" annulus from the surface to the ZXP for 10 minutes at 1000 psi. - OK Performed infectivity test with oil based mud in the hole 1.0 BPM @ 1080 psi 1.5 BPM @ 1370 psi 2.0 BPM @ 1710 psi - Shut in, pressure dropped to 475 psi in 1 minutes 1ST CEMENT SQUEEZE - 20 BBLS - NO HESITATION Placed high vis pill just below the leak point Pumped 18 bbls out of the casing leaving 2 bbls inside the casing (assuming no cement running on the low side below the pill) Pressured up to 2400 psi ilast 2 bbls) Bled off Waited on cement (CIP 2345 hrs, 20 July) TOOH for drilling assembly 1ST CEMENT CLEAN OUT AND SQUEEZE TEST RIH with drilling assy. Pressured up to 1000 psi, shut in, pressure dropped to 430 psi in 5 minutes. TOOH for RTTS. 2ND RTTS RUN & 2ND CEMENT SQUEEZE 20 BBLS - HESITATION RIH wjRTTS and reconfirmed leak location Pumped second cement squeeze Squeezed 10 bbls @ 1.0 bpm, STOP, pressure @ 1240 psi Pressure dropped to 1029 in 5 minutes Squeezed 5 bbls @ 1.0 bpm, STOP, pressure @ 1794 psi Pressure dropped to 1258 in 15 minutes Squeezed 1 bbl @ 0.5 bpm, STOP, pressure at 1551psi Pressure dropped to 905 psi in 30 minutes (CIP 1105 hrs, 21 July) 2ND CEMENT CLEAN OUT AND SQUEEZE TEST RIH with clean out assembly 0630 hrs, 22 July (20 hours since batch mix) Pressure up to 1050, shut in. Pressure dropped to 950 psi immediately 900 psi @ 1.0 min 875 psi @ 1.5 min 825 psi @ 2 min 750 psi @ 4 min 750 psi @ 5 min 725 psi @ 10 min 700 psi @ 15 min 700 psi @ 20 min 690 psi @ 25 min 1 of 2 7125!2005 9:06 AM 1E-170 Intermediate Cement • 690 psi @ 30 min Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly~~.conocophillips.com «Patrick.J.Rei11y4conocophillips.cam.vcf» Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reillv'~conocophillips.com 1E-170 Intermediate Cement.eml 4 C~ ~~ _- ®~ V 2 of 2 7/25/2005 4:06 AM Re: Information for 9 5/8" Pipe Repair on 1E-170 • Subject: Re: Information for 9 518" Pipe Repair on 1E-170 From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Thu, 21 Ju12005 11:23:59 -0800 To: NSK Fld Drlg Supv <n1335@conocophillips.com> CC: Mike.R.Greener@conocophillips.com ---x X05 -c~~~ ~~ aos-v'~ 5 La aos-o`er ~ Steve and Mike, Thanks for the additional information. From the pressure response, it appears that the leak was successfully squeezed. 2400 psi at 2 bpm isn't bad at all. I agree that testing the casing/squeeze to a lower pressure due to the potential to damage the tieback is appropriate at recommended by your equipment provider. The MASP lies between the 1000 and 1500 psi test pressures that have been proposed. The MASP is calculated with a gas gradient of (0.1 psi/ft) making the calculated pressure high and therefore conservative. In normal drilling operations well pressures should not approach this value even when a well control situation is considered. The ultimate test pressure value is CPAI's to determine, but I agree with what appears to the minimum of 1000 psi. Tom Maunder, PE AOGCC NSK Fld Drlg Supv wrote: Tom, Mike has called the rig and they have agreed to pressure testing the 9 5/8" casing to 1000 psi in order to prevent any further damage to the suspect crossover. The squeeze operations took 20 bbls of cement with all that volume going into the 13 3/8" X 9 518" annulus as calculated from the displacement. At 2 bpm the pressure stepped up progressively to +/-2400 psi making it appear that a good squeeze was obtained on the lap area. The leakoff tests in this area of the West Sak have normally been in the range of 450 to 600 psi surface pressure with a 9.0 ppg mud, which is what they should be drilling out with. Once the three laterals have been drilled and all the liners are run a 9 5/8" casing patch will be run across the area of the damaged crossover for improving casing integrity in the future. Upon the successful execution of that procedure the ESP completion will be run. Thanks Steve 1 of 1 7/21/2005 2:43 PM FW: IE-170 Intermediate casing leak Subject: FW: 1E-170 Intermediate casing leak From: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> Date: Thu, 21 Jul 2005 10:09:58 -0800 To: Tom Maunder <tom maunder@admin.state.ak.us> -----Original Message----- From: Greener, Mike R. Sent: Thursday, July 21, 2005 9:49 AM To: Tom Maunder' Cc: Thomas, Randy L Subject: 1E-170 Intermediate casing leak S~ ~Z ~'-~ Q ~ `.--• '_ ~ ~ Cv This is an update on the casing leak that I visited with. you about the other night an the phone. The. leak was determined to be in a caller an a crossover pup joint directly below the liner hanger. bast night we squeezed the leak with 20 bbls of Class "G'" cement. We pumped 1$ bbls thraugh the leak and left 2 bbls inside the 9-~l8" casing. The volume below the RTTS packer to the leak. was slightly over 4 bbls. The 9-5i8" ~ 13-3!F`" annulus volume from the .leak to the 1.3-318" shae was 11.9 bbls. We are currently picking up our I3H~, to go in and drill out tivhat cement is left inside the 9-S18" casing. Casing movement caleulatians from Baker indicate that if we pressure to 3,Q00 psi we will be putting the Ina~imuln load all the tieback. string paclzel•. I am recommending that we anly pressure to 1,00 psi tvitl~l the plan to place a casing patch across the leak. area. aFter use have f Wished placing ila:to the well. a1] the liner hook equipment and :lateral entry equipment that `ve have to run in the t~rell. The casing patch is to ensure fil,ture casing integrity as a back up to the cement squeeze. Mike Greener Senior Drilling Engineer 907.263.4820 1 of 1 7/21/2005 2:42 PM • }} ~ l ~ _ { l ~ 1 ? ~ s i ~ ' ~ _ i~3~ ~d ~j 3 ~»m.~J "~ ..r ~ ~.aa ~>s.s v s s..a+.- .va ~.e~ _m ALASgiA OIL A1QD GAS COI~TSERQATIOI~T CO1rI1-IISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk 1 E-170 ConocoPhillips Alaska, Inc. Permit No: 205-074 Surface Location: 247' FNL, 641' FEL, SEC. 21, T11N, R10E, UM Bottomhole Location: 1166' FSL, 172' FWL, SEC. 34, T11N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to 'tn~ss any required test. Contact the Commission's petroleum field inspector at (9659-36 (p~ger). DATED this day of May, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips ~ Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com May 4, 2005 MAY (~ 2Q05 ASasic~ ut~ ~ ~s Gs~r~s. Cammissi~n nch~ra~e Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1E-170, 1E-170 L1 and 1E-170 L2 Dear Commissioners: i ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a multilateral horizontal well in the West Sak "A", "B"and ~~D" sands. The main bore of the well will be designated 1E-170, and the lateral bore of the well will be designated 1E-170 Li ("B" Sand) and 1E-170 L2 ~~D" Sand) Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1E-170 is 6/4/2005. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, -~~ `r Randy Thomas Greater Kuparuk Area Drilling Team Leader • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED MaY o s 2oa5 ~ ~ 1 a. Type of Work: Drill / Redrill 1 b. Current Well Class: Exploratory Develo d Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service ^ Development Gas ^ Af~Ch®f a~QSingle Zone ^/ 2.Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1 E-170 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15819' ~ TVD: 3431' ~ Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 247' FNL, 641' FEL, Sec. 21, T11 N, R10E, UM ADL 25660 West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4029' FNL, 5057' FEL, Sec. 27, T11N, R10E, UM ALK 470 6/4/2005 Total Depth: 9. Acres in Property: 14. Distance to 1166' FSL, 172' FWL, Sec. 34, T11 N, R10E, UM 2560 Nearest Property: 4639' at surtace 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest r ~ //~ /S~ Surface: x- 549890 ~ y- 5959340 Zone- 4 (Height aboveGL): 28' RKB feet Well within Pool: 1E-2 16. Deviated wells: Kickoff depth: 312 ~ ft. 17. Maximum Anticipated Pressures in psig (see 20 Ao,C 25.035) $°~O'US Maximum Hole Angle: 92.5° deg Downhole: 1544 psig Surface: 1167 psig ° 18. Casing Program cif tio S Setting Depth Quantity of Cement Size ica ns pe Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 16" 13-3/8" 68# L-80 BTC 5086' 28' 28' 5086' 2317' 980 sx ASLite, 260 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 10433' 28' 28' 10433' ~ 3447' 790 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 5386' 10433' 3447' 15819' 3431' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be com pleted 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 ND Structural Conductor Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee 0 BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` r Phone -~~ ~~ SO Date ~ (Y/off Pr a n A/ D k Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~Qj `(~~! ~ q ^7 -~/ / 50- vZ J' G..~ c..~j~-/- ~ Date: for other requirements Conditions of approval S pies re uired Yes ^ No ~ Mud log required Yes ^ No ydrogen uifide measures Yes ~' No ^ Directional survey required Yes ~ No ^ Other: ~ ~ ~Y~ ' ~ a ~. S • APPROVED SY / O~ ~ Approve THE COMMISSION Date: f r,,..,,, an ens o....:..., innn• ~ }~~j //~~" AAA !( t l F lJ ~ 1 tl c~..~.y:. :_ r~.._r.__`_ application for Permit to Drill, Well 1 E-170 Revision No.O May 4, 2005 Permit It -West Sak Well #1 E-170 ("A" Sand) .,,,~ r.~ +'~ Application for Permit to Drill Document, I~It~xWell M~xirAiz~ 1ME11 Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c) (4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Gasing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 ORIGINAL 1E-170 PERMIT IT.doc Page 1 of 8 Printed: May 4, 2005 • application for Permit to Drill, Well 1 E-170 Revision No.0 May 4, 2005 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 Requirements of 20 AAC 25.005 (c}(14} ................................................................................................ 7 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ............................................................................................................... 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cementng Dafa ................................................................................................................ 8 Attachment 4 Well Schematic ............................................................................................................... 8 1. Well Name Requirements of 20 AAC 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with mu/trple well branches, each branch must Simi/arty be identified by a unique name and API number by adding a suffix to the name designated far the weal by the operator and to the number assigned to the we// by the commission. The well for which this Application is submitted will be designated as 1E-170. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) An application for a Permit to Dnl/ must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (2) a p/at identifying the property and the property's owners and showing (A)the coordinates of the proposed Location of the welf at the surface, at the top of each objective formation, and at total depth, referenced to govemmenta/ section lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Admmistratlon,• (C) the proposed depth of the well at the top of each objective formation and at tots/ depth; Location at Surtace FNL:246.91' FEL:640.83' Sec 21 T11N/R10E UM ~ ASP Zone 4 NAD 27 Coordinates RKB Elevation 98.8' AMSL Northings: 5,959,340 Eastings: 549,890 Pad Elevation 70.8' AMSL Location at Top of Productive Interval West Sak "A" Sand FNL:4029', FEL:5057', Sec 27, T11N/R10E, UM ASP Zone 4 NAD 27 Coordinates Measured De th RKB; 10 433' Northings~5,950,284 Eastings: 550,833 Totall/erticalDe th RKB: 3,447' Total I/ertica/ De th, SS.• 3 337' Location at Total De th FSL:1166' FWL:172' Sec 34 T11NJR10E UM ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 15 819' Northings:5,944,920 Eastings: 550,830 Total 1/ertica/ De th RKB,• 3 431' Total I/ertica/ De th, SS.• 3 321' and (DJ other information required by 20 AAC 25.050(b); 1E-170 PERMIT IT.doc Page 2 of 8 Printed: May 4, 2005 ORIGINAL application for Permit to Drill, Well 1 E-170 Revision No.O May 4, 2005 Requirements of 20 AAC 25.050(b) Ifa well is to be intentiona//y deviated, the app/ication for a Hermit to Dri// (Form 10-401) must (I) include a plat, drawn to a suitable sca/e, showing the path of the proposed wel/bore, including all adjacent we//bores within 200 feet ofany portion of the proposed wel% Please see Attachment 1: Directional Plan and (2) for all wel/s within 200 feet of the proposed wel/bore (A) list the names of the operators of those we//s, to the extent that those names are known or discoverable in public records, and show that each named operator has been fumisheo' a copy of the application by certified mail, or (B) state that the app/icant is the on/y affected owner: The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Dnll must be accompanied by each of the fo/lowing items,. except for an item already on file with the commission and identified in the application: (3J a diagram and description of the blowout prevention equipment (BPPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable,• ~ GS `~ ~~** b\~+. An API 13-5/8" x 5,000 psi BOP stack (RSRRA will be utilized to drill and complete well 1E-170. Please see information on Doyon 141 blowout preven i~r~~quipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the app/ication: (4) information on drilling hazards, including (A) the maximum downho% pressure that may be encountered, criteria used to determine /t, and maximum potentia/surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1E-170 area vary from 0.0.42 to 0.0.45 psi/ft, or 8.1 to 8.6 ppg EMW (equivalent mud weight). These pressures are predicted based on actual , bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 1166.54 psi, calculated thusly: MPSP =(3,431' ft)(0.45 - 0.11 psi/ft) =1166.54 psi (B) data on potential gas zones,• The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia/ causes of ho% problems such as abnormal/y geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dnl1 must be accompanied by each of the fotlowing items, except for an item already on file with the commission and identified in the applicalion: (S) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); The parent wellbore, 1E-170, will be completed with 9 5/8" intermediate casing landed in the West Sak A-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance 1E-170 PERMIT /T.doc Page 3 of 8 Printed: May 4, 2005 ORIGINAL • application for Permit to Drill, Well 1 E-170 Revision No.0 May 4, 2005 with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. C 6. Casing and Cementing Program Requirements of 20 AAC 25.OO5(c)(6) An app/ication far a Permit to ©ril/ must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (6) a camp/ete proposed casing and cementing program as required by 20 AAC 26.030, and a description of any slotted liner, pre- perforated liner, or screen to be insta/led, Casing and Cementing Program See also Attachment 3 APD for 1E-170: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in in) Ib/ft Grade Connection ft (ft (ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE 13 3/8 16 68 L-80 BTC 5,086 28 / 28 5,086 / Cemented to Surface with 2,317 980 sx ASLite Lead, 260 sx Dee CRETE Tail 9 5/8 12 1/4 40 L-80 BTCM 10,433 28 / 28 10,433 / Cement Top planned @ 3,447 6,000' MD / 2,439' TVD. Cemented w/ 5 1/2 8 1/2" 15.5 L-80 BTCM 5,386 10,433 / 15,819 / Slotted- no cement slotted "A" Lateral 3,447 3,431 - 70 8 1/2" 15.5 L-80 BTCM 6,127 9,523 / 15,650 / Slotted- no cement slotted "B" Lateral 3,305 3,258 1E-170 Ll 5 1/2 8 1/2 15.5 L-80 BTCM 7,396 9,193 / 15,646 / Slotted-no cement slotted "D" Lateral 3,243 3,184 1E-170 L2 7. Diverter System Information Requirements of 20 AAC 25.OO5(c)(7) An app/ication for a Permit to Drill must be accompanied by each of the fv/lowing items, except for an item a/ready on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1 E-170. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 1E-170 PERMIT /T.doc Page 4 of 8 Printed: May 4, 2005 ORIGINAL • Drilling Fluid Program application for Permit to Drill, Well 1 E-170 Revision No.0 May 4, 2005 Requirements of 20 AAC 25.005(c)(8) An app/icafron for a Permit to ©ril/ must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the app/ication: (8) a dr1/ling fluid program, including a diagram and description of the driiiing fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Surface Intermediate Production Density (ppg) 8.9 - 9.6 9.0 - 9.1 9.0 Funnel Viscosity (seconds) 150 - 300 45 - 60 30 Yield Point (cP) 30 - 70 26 - 35 18 - 28 Electric Stability NA NA 650 - 900 Chlorides (mg/I) <500 <500 40000 pH 8.5-9.0 9.0-9.5 NJA API filtrate (cc / 30 min) 5.0 - 8.0 4 - 6 NA *'"HTHP filtrate (cc / 30 min) NA NA <4 MBT (Ib /gal) NA <20 NA Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the application: (9) for an exp/oratory or stratigraphic test well, atabu/atlan setting out the depths ofpredicted abnorma/iy geo pressured strata as required by 20 AAC 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 8. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Drill must be accompanied try each of the fo/%wing items, except for an item a/ready on file with the commission and identifed in the application: (10) for an exploratory or stratigraphic test Weil, a seismic refraction or reflectr'on analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied try each of the fol%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (11) for a well dulled from an alfshore p<atform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed conditions as required by 2Q AAC25.061(b); Not applicable: Application is not for an offshore well. 10. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dri/1 must be accompanied by each of the fo/lowing items, except for an item already on B/e with the commission and identified in the application: (I2) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. ORIGINAL 1E-170 PERMIT /T.doc Page 5 of 8 Printed: May 4, 2005 J application for Permit to Drill, Well 1 E-170 Revision No.O May 4, 2005 11. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fallowing items, except for an item already on file with the commission and identified in the application: The proposed drilling program for 1E-170 is listed below. 1. 6ccavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon 141. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 5,086' MD / 2,317' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13 3/8", 68#, L-80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 his before test. 6. PU 12 i/4" bit and drilling assembly, with MWD, LWD & PWD RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 9 5/8" casing point at 10,433' MD j 3,447' TVD. ` 9. Run 9 5/8", 40# L-80, BTCM Mod casing as a liner. Pump cement and displace with mud. Tie back casing to surface with seal assembly and packer, pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead 9 5/8" packoff and test to 5000 psi. 11. Flush 13 3/8" x 9 5/8"annulus with water, followed by diesel. 12. PU 8 i/2" Bit and drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. ~~~14. Directionally drill 8 1/2" hole to TD at +/- 15,819' MD / 3,431' TVD as per directional plan. ~UU ~ 15. POOH, back reaming out of lateral. RIH and spot solids free OBM. POOH. 16. Run USIT (cement bond) fog across intermediate interval. 17. PU and run 5 1/2" slotted liner. 18. Land liner, set liner hanger. POOH. _~-~-~ Note: Remaining operations are covered under the 1E-170 Ll Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 9,523' MD / 3,305' TVD, the top of the B sand. 20. Mill 8 1/2" window. POOH. 21. Pick up drilling assembly with LWD and MWD and PWD. RIH. 22. Displace to new drilling mud at ppg. Drill to TD of B sand lateral at 15,650' MD / 3,258' TVD, as per directional plan. 1E-170 PERMIT IT.doc Page 6 of 8 Printed: May 4, 2005 ORIGINAL u application for Permit to Drill, Well 1 E-170 Revision No.O May 4, 2005 23. POOH, back reaming out of lateral. RIH and spot solids free OBM. POOH. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 5 1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool, POOH. 28. PU Lateral Entry Module "LEM", RIH and latch unit into hook hanger, shear off POOH Note: Remaining operations are covered under the 1E-170 L2 Application for Permit to Drill, and are provided here for information only. 29. Run and set Baker WindowMaster whipstock system, at window point of 9,193' MD / 3,243' TVD, the top of the D sand. 30. Mill 8 1/2" window. POOH. 31. Pick up drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of D sand lateral at 15,646' MD / 3,184' TVD, as per directional plan. 33. POOH, back reaming out of lateral. RIH and spot solids free OBM. POOH. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 5 i/2" slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool, POOH. 38. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing, Set BPV. 39. Nipple down BOPE, nipple up tree and test. 40. Pull BPV and move rig off. 41. Freeze protect well with diesel by pumping into 4 1/2"" x 9 5/8"annulus, taking returns from tubing and allowing to equalize. 42. Rig up wire line unit. 43. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. 44. Replace gas lift valves with blank dummy valves. 45. Run ESP through tubing. 46. Operate well with ESP 12. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drr/l mustc tre accompanied try each of the fol%wing items, except for an item already on fi/e with the commission and identifred in the application: (19) a genera/ description of how the operator p/ans to dispose of dri//ing mud and cuttings and a statement of whether the operator intends to request authorization under 10 AAC 15.080 for an annu/ar disposal operation in the we/%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1E Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1E Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved 1E-170 PERMIT /T.doc Page 7 of 8 Printed: May 4, 2005 ORIGINAL • application for Permit to Drill, Well 1 E-170 Revision No.O May 4, 2005 disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 13. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic 1E-170 PERMIT IT.doc Page 8 of 8 Printed: May 4, 2005 ORIGINAL • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-170 Plan: 1 E-170 (wp0~) Proposal Report 02 May, 2005 t~ALLIBl.1RTQlV Sperry Drilling Services ORIGINAL ~°A~^,. . ~VI M~IIII~ .J~_. tir -60 0 MALLIB pprrrry Drt West(-)/East(+) (2000 ft/in) -5000 -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 5000 60 URTON lllnp Srrvler 00 as ~ i 312ftND Bulld(~3°HOOR KOP~312ftMD R10E SHL~247RFNL641RFEL-Sec2 ' y 1000 1000 ~ ~ \ ~~ ue Build ~ 4°/1008 , 64611 MD, 644ft ND -. 0 0 170° Continue Build ~ 5°/1008 , 803ft MD, 892 ft ND.... ' Sail ~ 76°Inc 6173°A7J : 2007tt MD,1610R N~ -1000 17 ~ - -1000 Sail ~ 76.86Wnc 6173.94°Azi _ 2276ft MD,1679ft ND ~ '. Co un enG Build ~ 3°/100ft , 220M MD,1662R ND -2000 -2000 Project: Kuparuk River Uni -3000 ?3 3/8" Casing ~ 5086ft MD, 23178 ND - Ddll Out 121/4" Hole Site: Kuparuk 1 E Pad 3000 ~~ Well: Plan 1 E-170 ~~ Wellbore: Plan 1 E-170 ~~ ~-__ ~ Plan: 1E-170 (wp04) -aooo -aooo 17a° -5000 -5000 CoMlnue Build ~ 3°/1008, 88918 MD, 3182ft ND -6000 Sail ~ 79°Inc 6179.77°Azi : 9093ft MD, 3224ft ND X000 C , ~ O _- c o o N -7000 \~~ _ -:-~-~ ._ _. -7000 0 `_ + ' Intersect DSand ~ 791nc, 9193ft MD, 3243ft ND - - ~ _- _ -- ---~-- ~ 3 -~ 1E-170DWDIwDOq O Z -8000 ~ ~ 180° '\ \ 1E•170T1(wp04) -8000 0 ~ BuIW ~ 3°11008 to 81° Ilnc - 9456ft MD, 3294ft ND --- --- O L - 1E-170 T2(wp04) + ~ _ 180a O ~ -9000 1 ' I, Interaed BSand ~ 81Wnc , 9525ft MD, 33058 ND i ! l \ -9000 v. ` - - Begin UnduWtlons in A-Sand. 107708 MD. 34788 ND ~I . --~ ~ 1 E 170 T3 (wp04)~ g ~ 10433ft MD, 34488 ND -Drill Out 81/T' Hole ~i ~ _ ~ ~ -10000 ~ 180° 1E-170 T4 (wP04) -10000 -11000 / -11000 180° Build ~ 3°/1008 to 89.76° int - 104768 MD, 3455ft ND -12000 -12000 1 1° p 1E-170 T5 (wp04) ~j II - - ' r -13000 ~ -13000 BHL~1165ftFSL172ftFWL-Sec 34-T11N-R10E 181° i tE-170 Tce (w1~04) -14000 -14000 T I 161°-'~ __- ~ ~_ M AzvnuNS to True North -15000 Magnetic Nortn: u.49° l -15000 Magnetic Field ~~ Strength: 67580.3nT ~~~ Dip Angle: 80.74° ~ 1~„ " Date: 12/16/2004 ~ _- __. -- - -16000 Motlel: BGGM2004 .. - _ _ _ _ - ~ ~ __- _--~ - ' -16000 -60 00 -5000 X000 -3000 -2000 -1000 0 1000 2000 3000 4000 5000 60 00 West(-)/East(+) (2000 ft/in) UKIUINI~L ~ KU nik River Unit I HALLIBURTON Project: Pa ~CK'1000~1~~~fpSr ~ Site: Kuparuk 1 E Pad i sP..ry oriiii~ s.rrie.. Well: Plan 1 E-170 -4500 iSHL @ 247ft FNL 641ft FEL -Sec 21 - T11 N - R10E Wellbore: Plan 1 E-170 -_- ~ Plan: 1E-170 (wp04) KOP @ 312ft MD, 312ft ND -Build @ 3°/t00ft l ----------- -3600 Continue Build @ 4°/100ft , 645ft MD, 644ft ND ~ LContinue Build @ 5°/100ft , 903ft MD, 892 ft ND - - ~ _ - ~~ Sail @ 75°Inc 8 173°Azi : 2007ft MD, 1610ft ND -2700 Continue Build @ 3°I100ft , 2207ft MD, 1662ft ND - _ I /' Sail @ 76.86°Inc & 173.94°Azi : 2276ft MD, 1679ft ND I -900 0 - / I Intersect D-Sand @ 79 Inc, 9193ft MD, 3243ft ND J 'Base of Permatrost~ 0° T3 c 10° ~'~ Sail @ 79°Inc & 179.77°Azi : 9093ft MD, 3224ft ND -- '~ 900 ° - ~ -- ~rBuild @ 3°/100ft to 81 ° lint - 9456ft MD, 3294ft ND j o i / , K15I ~~4p ° _ - ~~`~ ~ ~ /Continue Build @ 3°/100ft , 8891ft MD, 3182ft ND J ~ -- - T3 +675, / - -- -- - - --- a _ '\ - - / ~ ,Intersect B-Sand @ 81°Inc , 9525ft MD, 3305ft ND p 1800 ~_ -- ~ __. - --- --- - - - Ugnu C - - - - ~~ - - ~ Ugnu rte. C - _ - - -- - Ugnu A ~~ ~Kt3 _.- - - - __ - -. 7 2700 - _ _ _ - F- __ _ _ -gyp /o - ~ - au - _ - __._ - _- - _ __ ~ ,13 3/B" Casing @ 5086ft MD, 2317ft ND -Drill Out 12 1l4" Hole ~~ -. - -_ 9 51~" =, - °D 5 1/2" - 4500 Dlop (wp04) 1E-170 T7 ~ tE-170 T2 (wp04) ~ VYest Sek 1E-170 T4 (wp04) ~ 9 5/8" Casing @ 10433ft MD, 3448ft ND -Drill Out 8 1/2" Hole / Build @ 3°/100ft to 89.76° Inc - 10478ft MD, 3455ft ND BHL @ 1165ft FSL 172ft FWL -Sec 34 - T11 N - R10E 7200 begin Undulations in A-Sand. 10770ft MD. 3478ft ND J -900 0 900 1800 2700 3600 4500 5400 6300 7200 8100 9000 9900 10800 11700 12600 13500 14400 15300 Vertical Section at 180.00° (1800 ft/in) ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: Plan 1 E-170 Wellbore: Plan 1 E-170 Design: 1E-170 (wp04) • Halliburton Company HALLIBURTON Planning Report -Geographic Sperry Drilling Services Local Coordinate Reference: Well Plan 1 E-170 TVD References 70.4 GL + 40 RT @ 110.40ft (Doyon 15) MD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) North Reference: True Survey Calculation Method: `' Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1 E-170 Well Position +N/S 0.00 ft Northing: 5,959,339.91 ft Latitude: 70° 17' 58.887" N +E/-W 0.00 ft Easting: 549,889.64 ft Longitude: 149° 35' 45.435" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.40 ft Wellbore Plan 1 E-170 Magnetics Model Name Sample Date Declination Dip Angle Field Strength {°) (°) (nT) ~ bggm2004 12/18/2004 24.49 80.74 57,580 I _, Design -_ 1E-170 (wp04) Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 .Vertical Section: Depth from (ND} +NI-S +EI-W Direction (fC) (~) 1ft) (') 40.00 0.00 0.00 180.00 5/2/2005 7:49:45PM Paye 2 of 10 COMPASS 2003.11 Build 48 o~~~~L ~-' • ConocoPhillips Alaska Database:: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: Plan 1 E-170 Wellbore: Plan 1E-170 `:Design. 1E-170 (wp04) Halliburton Company HALLIBURTON Planning Report -Geographic Sperry Drilling Services Local Co-oMinate Reference: Weil Plan 1 E-170 ND Reference: ' 70.4 GL + 40 RT @ 110.40ft (Doyon 15) MD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) North Reference: True :Survey Calculation Method: Minimum Curvature Pian Summary Measured vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NI-S +E/-W Rate Rate Rate TFO (~ (°) (o) ({~) (ft) (~) (°/100ft) (°1100ft) (°1100ft) (°) 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 0.00 312.00 0.00 0.00 312.00 0.00 0.00 0.00 0.00 0.00 0.00 645.33 10.00 155.00 643.64 -26.30 12.26 3.00 3.00 0.00 155.00 902.67 20.00 165.00 891.93 -89.22 33.15 4.00 3.89 3.89 19.41 2,007.16 75.00 173.00 1,610.30 -861.88 156.77 5.00 4.98 0.72 9.42 2,207.16 75.00 173.00 1,662.07 -1,053.63 180.31 0.00 0.00 0.00 0.00 2,276.45 76.87 173.95 1,678.91 -1,120.40 187.95 3.00 2.69 1.36 26.30 8,890.67 76.87 173.95 3,181.90 -7,525.66 867.32 0.00 0.00 0.00 0.00 9,093.40 79.00 179.77 3,224.32 -7,723.51 878.15 3.00 1.05 2.87 70.08 9,193.40 79.00 179.77 3,243.40 -7,821.67 678.54 0.00 0.00 0.00 0.00 9,456.40 79.00 179.77 3,293.58 -8,079.84 879.58 0.00 0.00 0.00 0.00 9,523.07 81.00 179.77 3,305.16 -8,145.49 879.84 3.00 3.00 0.00 0.00 10,478.07 81.00 179.77 3,454.55 -9,088.73 883.63 0.00 0.00 0.00 0.00 10,770.07 89.76 179.78 3,478.05 -9,379.49 884.78 3.00 3.00 0.00 0.03 11,270.07 92.00 179.97 3,470.37 -9,879.40 885.89 0.45 0.45 0.04 5.00 11,470.07 92.00 179.97 3,463.38 -10,079.28 885.99 0.00 0.00 0.00 0.00 11,970.07 90.26 180.12 3,453.52 -10,579.16 885.57 0.35 -0.35 0.03 175.00 12,470.07 89.01 180.23 3,456.70 -11,079.14 884.02 0.25 -0.25 0.02 175.00 12,670.07 89.01 180.23 3,460.15 -11,279.11 883.21 0.00 0.00 0.00 0.00 13,170.07 90.51 180.36 3,462.24 -11,779.08 880.61 0.30 0.30 0.03 5.00 13,670.07 92.50 180.54 3,449.13 -12,278.87 876.68 0.40 0.40 0.03 5.00 13,870.07 92.50 180.54 3,440.40 -12,478.67 874.80 0.00 0.00 0.00 0.00 14,370.07 91.25 180.65 3,424.03 -12,978.36 869.64 0.25 -0.25 0.02 175.00 14,870.07 88.02 180.93 3,427.21 -13,478.24 862.76 0.65 -0.65 0.06 175.00 15,070.07 88.02 180.93 3,434.13 -13,678.09 859.51 0.00 0.00 0.00 0.00 15,570.07 91.25 181.21 3,437.31 -14,177.93 850.16 0.65 0.65 0.06 5.00 15,819.49 91.25 181.21 3,431.85 -14,427.24 844.88 0.00 0.00 0.00 0.00 5/2/2005 7:49:45PM Page 3 of 10 COMPASS 2003.11 Build 48 ~~NAL ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company:. ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1 E Pad "Well: Plan 1 E-170 We-tborec Plan 1E-170 Design: 1 E-170 (wp04) Halliburton Company HALLIBURTON Planning Report -Geographic Sperry Drilling Services Local Co-ordinate Reference: Well Plan 1 E-170 TVD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) MD Reference; 70.4 GL + 40 RT @ 110.40ft (Doyon 15) North.. Reference: True Survey Calculation Method: Minimum Curvature Prognosed Casing Poiirts Measured Vertical Casing Hole Depth Depth. Diameter Diameter l~) t~l t'9 t"1 5,086.26 2,317.40 13-3!8 18 10,433.00 3,447.50 9-6/8 12-1/4 15,819.48 3,431.85 6-112 8-112 Prognosed Eormation,Itrtersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (~) !°) (°) (tt) (@) (ft) 1,732.70 61.30 172.10 1,508.40 -609.88 123.91 2,335.83 76.87 173.95 1,692.40 -1,177.91 194.05 3,449.21 76.87 173.95 1,945.40 -2,256.11 308.41 5,086.26 76.87 173.95 2,317.40 -3,841.44 476.56 6,450.47 76.87 173.95 2,627.40 -5,162.56 616.68 7,436.23 76.87 173.95 2,851.40 -6,117.17 717.93 7,612.26 76.87 173.95 2,891.40 -6,287.63 736.01 8,347.17 76.87 173.95 3,058.40 -6,999.33 811.50 9,193.40 79.00 179.77 3,243.40 -7,821.67 878.54 9,408.28 79.00 179.77 3,284.40 -8,032.60 879.39 9,524.61 81.00 179.77 3,305.40 -8,147.01 879.85 9,729.17 81.00 179.77 3,337.40 -8,349.05 880.66 10,010.44 81.00 179.77 3,381.40 -8,626.86 881.77 10,425.95 81.00 179.77 3,446.40 -9,037.25 883.42 Name Base of Permafrost T3 K15 T3 +675 Ugnu C Ugnu B Ugnu A K13 West Sak D West Sak C West Sak B West Sak A4 West Sak A3 West Sak A2 5l2t2005 7:49:45PM Page 10 of 10 COMPASS 2003.11 Build 48 ~R~~AL • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-170 Anticollision Summary 02 May, 2005 • HALLIBlJRT`QN Sperry Drilling Services ORIGINAL ..4... V l ....~. SURVEY PROGRAM Date: 200504-26700:00:00 Validated: Yes Version: Depth FromDepth To Survey/Plan Tool 40.00 812.00 IE-170(wp04) CB-GYRO-SS 812.0015819.49 1E-170 (wp04) MWD+IFR-AK-CA<rSC zoo ieo ConocoPhlllips Alaska (Kuparuk) Engineering West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Waming Method: Rules Based Travelling Cylinder Azimuth (TFt?+AZI) ~°~ vs Centre to Centre Separation X100 ftrn NAD27ASPZone4:WELLDETAILS: Plan 1E-170 Ground Level: 70.40 +WS +EI-W Northing Easting Latitiude Lorgitude Slot 0.00 0.00 5959339.91 549859.64 70°1T56.a87N 149°35'45.435W REFERENCE INFtxtMAT10N Co-ordinate (NIE) Reference: Well Plan 1 E-170, True North Vertical (TVD) Reference: 70.4 GL+ 40 RT ~ 110.408 (Doyon 15) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depfh Reference: 70.4 GL+ 40 RT ~ 110AOR (Doyon 15) Calculation MetF3od: Minimum Curvature From Colour To MD 40 112 112 212 212 462 462 712 712 962 962 1462 1462 1962 1962 2462 2462 2962 2962 3462 3462 4962 4962 6462 6462 _---- 7962 7962 9462 9462 10962 10962 12462 12462 13962 13962 16660 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 40.00 To 15819.49 Maximum Range:5000 Reference: Plan: 1E-170 (wp04) 0 180 Travelling Cylinder Azimuth (TFO+AZI) )°) vs Centre to Cen[re Separafion 115 ~ni 6ec MD Ye Aa ND ~WS ~E/-W DL TFace VSec Ta,9a1 ' S 1 w.ao oo0 000 40.00 0.00 eao ao 2 312.00 0.00 0.00 312.00 000 000 0.00 o.ae 000 0.00 000 3 615.33 1000 155.00 643.84 -28.30 1228 3.00 155.00 26.30 9026) 20.00 185.00 09183 4932 33.15 4.00 5 200].18 15.00 1]3.00 1610.Y1 -88188 158.]] 5.00 8 220]16 ]500 1)000 1fifi30] -t 053.83 18031 000 1801 89.22 842 861.88 0.00 105363 ] 22]80.5 )80] 1]395 18]891 -1120.40 16)95 3.00 28.30 112000 8 88906) )8 B] 1]395 318190 -)525.86 88].32 0.00 8 909300 ]8.00 t]9.]] 3224.32 -]]2351 8]8.15 3.00 0.00 ]525 fib )O.OB ])2351 10 9193.40 ]9.00 119.]] 324300 -]8218] 8]8.51 0.00 00 1]9.]] 329358 80]9.84 8)858 000 11 815600 19 0.00 ]0216) tE-1)0 Db0 (wp04) 0.00 BO]984 . t2 9523.0] 81.00 ti9.]] 330516 -814509 8]B.Bd J00 000 8145.49 13104]60] 81.00 1]8.]) 345455 -9088.]3 68363 O.OD 1410]]00] 88.)8 1]9.]8 31]8.05 53]849 884.]8 3.00 0.00 9068.]3 003 93]94.9 tE-1]0 T3 (wp04) 15112]00] 9200 1]8.8] 31]03) -98]940 885.E 045 5.00 98]940 16 nno.o) az oo n9.9) 346338-1ao]9ze 665.99 000 1] 119]08] 9028 18012 345352-105]916 885.5) 035 om 1oo19za 1]500 105)816 1e 12oom ae of 1eoz3 3456 ]o-nm9.u eeloz o.zs nsao nm9.14 19128]00> 88.01 180.13 3480.15-112)9.11 883.21 0.00 20131]00] 90.51 180.% 346224-11]]900 88081 030 000112]9.11 50011])908 21136100] 9250 180.51 3449.13-122]8.8) 8]668 0.40 22138]0.01 92.50 180.54 3440 d0 -124]66] 8]460 000 500122]86] 0.00124]8 B) 2314310.0] 9125 180.65 342403 129]836 869.84 025 24140)00] 8802 180.93 342]21-131]824 862]6 065 1]S OD 129]836 1]5.00134]821 25150)00] 88.02 180.9] 3434.13-13fi]609 858.51 0.00 26155100] 91.25 18121 343]]1-141]193 850.16 0.65 0.00136]609 500141]193 2) 15019 d9 9125 181.21 343165-1412124 81488 000 0001442124 tE-110 TOa (wpW) ,~ i ConocoPhillips Alaska Company:. ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1 E Pad Site Error: O.OOft Reference Weli: Plan 1 E-170 We11 Error: O.OOft Reference Wellbore Plan 1 E-170 Reference Design: 1 E-170 (wp04} • Halliburton Company NALLIBURTON Anticollision Report Spent' Drilling Services Local Co-ordinate Reference: Well Plan 1 E-170 TVD-Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) MD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) North Reference: i True Survey Calculation Method: Minimum Curvature Output snore are at 2.00 sigma Database:, ; ; EDM 2003.11 Single User Db Offset TVD Reference: ` Offset Datum Reference 1 E-170 (wp04) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-Center distance of 5,000.OOft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey TookProgram Date 5/2/2005 ^~ From , To (~ (ft) Survey (Wellbore) ' TooiNeme Description 40.00 812.00 1 E-170 (wp04) (Plan 1 E-170) CB-GYRO-SS Camera based gyro single shot 812.00 15,819.49 1E-170 (wp04) (Plan 1E-170) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary .Reference Offset. Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth ' Depth Distance (ft) from Plan Offset Weli - Weiltton3 -Design {fk) (ft) (ft) (ft) Kuparuk 1E Pad 1 E-119 - 1 E-119 - 1 E-119 3,242.63 3,300.00 408.54 138.55 269.99 Pass -Major Risk 1 E-166 - 1 E-166 - 1 E-166 430.76 425.00 99.25 7.77 91.48 Pass -Major Risk 1 E-166 - 1 E-166L1 - 1 E-166L1 430.76 425.00 99.25 7.77 91.48 Pass -Major Risk 1 E-166 - 1 E-166L1 PB1 - 1 E-166L1 P61 430.76 425.00 99.25 7.77 91.48 Pass -Major Risk 1 E-166 - 1 E-166L2 - 1 E-166L2 430.76 425.00 99.25 7.77 91.48 Pass -Major Risk 1 E-168 - 1 E-168 - 1 E-168 385.46 375.00 40.88 7.77 33.11 Pass -Major Risk 1 E-168 - 1 E-168L1 - 1 E-168L1 385.46 375.00 40.88 7.80 33.08 Pass -Major Risk 1 E-168 - 1 E-168L2 - 1E-168L2 385.46 375.00 40.88 7.77 33.11 Pass -Major Risk 1 E-168 - 1 E-168L2P61 - 1 E-168L2P61 385.46 375.00 40.88 7.80 33.08 Pass -Major Risk 1 E-168 - 1 E-168P81 - 1 E-168PB1 385.46 375.00 40.88 8.03 32.84 Pass -Major Risk 1 E-27 - 1 E-27 - 1 E-27 784.44 775.00 25.76 14.52 11.25 Pass -Major Risk 1 E-28 - 1 E-28 - 1 E-28 329.21 325.00 60.48 6.24 54.24 Pass -Major Risk 1 E-29 - 1 E-29 - 1 E-29 351.32 350.00 180.33 6.30 174.03 Pass -Major Risk 1 E-35 - 1 E-35 - 1 E-35 1,010.98 1,125.00 242.57 19.35 223.22 Pass -Major Risk 1 E-35 - 1 E-35A - 1 E-35A (wp02) 1, 011.99 1,125.00 242.35 19.22 223.12 Pass -Major Risk Plan 1 E-117 - 1 E-117 - 1 E-117 (wp05) 828.13 850.00 487.27 18.69 468.57 Pass -Major Risk Plan 1 E-117 - 1 E-117 L1 - 1 E-117 L1 (wp05) 828.13 850.00 487.27 18.69 468.57 Pass -Major Risk Plan 1 E-117 - 1 E-117 L2 - 1 E-117 L2 (wp05) 828.13 850.00 487.27 18.69 468.57 Pass -Major Risk Kuparuk 1J Pad Plan 1J-160 (M2) -Plan 1J-M2 Lat A -Plan 1J-M2 Lat A 15,808.56 7,875.00 1,556.16 248.27 1,307.89 Pass -Major Risk Plan 1J-162 (M1) - 1J-162 - 1J-162 (wp03.1-North Heel 15,803.65 9,075.00 485.02 156.37 328.65 Pass -Major Risk Plan 1J-162 (M1) - 1J-162 L1 - 1J-162 L1 (wp3.1) 15,803.65 9,075.00 485.02 156.27 328.75 Pass -Major Risk Plan 1J-162 (M1) - 1J-162 L2 - 1J-162 L2 (wp3.1) 15,803.65 9,075.00 485.02 156.27 328.75 Pass -Major Risk Kuparuk River Unit Non Pad Kup-34-11-10-1 - 34-11-10 - 34-11-10 14,729.95 3,825.00 318.84 262.90 55.94 Pass -Major Risk CC -Min centre to center distance or oovergent point, SF -min separation factor, ES -min ellipse separation 5/2/2005 7:58:51PM Page 2 of 2 COMPASS 2003.118ui1d 48 ,~,RIGINAL ` ~ ~ ~- P l Halliburton Company HALLIBUgTON Conoco hi lips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Refarencac Well Plan 1 E-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 70.4 GL + 40 RT @ 110.40ft (DOyon 15) Project: Kuparuk River Unit MD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Sitei ' Kuparuk 1E Pad .North Reference:. .True :Well: Plan 1 E-170 'Survey Calculation Method: Minimum Curvature Wellbore: Plan 1 E-170 Design: 1 E-170 (wp04) Pi na red Survey 1E-170 (wp04) i Map Map MD Inclination Azimuth TYD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ftl (°) (°) (ftl `(itl (ft) {$) (ft) (ft) (°/100ft) (ftl 40.00 0.00 0.00 40.00 -70.40 0.00 0.00 5,959,339.91 549,889.64 0.00 0.00 SHL ~ 247ft FNL 641ft FEL -Sec 21 - T17 N - R10E 100.00 0.00 0.00 100.00 -10.40 0.00 0.00 5,959,339.91 549,889.64 0.00 0.00 200.00 0.00 0.00 200.00 89.60 0.00 0.00 5,959,339.91 549,889.64 0.00 0.00 300.00 0.00 0.00 300.00 189.60 0.00 0.00 5,959,339.91 549,889.64 0.00 0.00 312.00 0.00 0.00 312.00 201.60 0.00 0.00 5,959,339.91 549,889.64 0.00 0.00 KOP (d1312ft MD, 312ft TVD - Build ~ 3°/100ft 400.00 2.64 155.00 399.97 289.57 -1.84 0.86 5,959,338.08 549,890.51 3.00 1.84 500.00 5.64 155.00 499.70 389.30 -8.38 3.91 5,959,331.56 549,893.60 3.00 8.38 600.00 8.64 155.00 598.91 488.51 -19.64 9.16 5,959,320.33 549,898.93 3.00 19.64 645.33 10.00 155.00 643.64 533.24 -26.30 12.26 5,959,313.70 549,902.08 3.00 26.30 Continue Build @ 4°/100ft , 6458 MD, 644ft TVD 700.00 12.08 158.47 697.30 586.90 -35.92 16.37 5,959,304.10 549,906.24 4.00 35.92 800.00 15.97 162.48 794.30 683.90 -58.78 24.35 5,959,281.29 549,914.38 4.00 58.78 900.00 19.89 164.95 889.42 779.02 -88.34 32.91 5,959,251.80 549,923.14 4.00 88.34 902.67 20.00 165.00 891.93 781.53 -89.22 33.15 5,959,250.92 549,923.38 4.00 89.22 Continue Build ~ 5°/100ft ,9038 MD, 692 ft TVD 1,000.00 24.81 166.90 981.89 871.49 -125.21 42.09 5,959,214.99 549,932.56 5.00 125.21 1,100.00 29.78 168.24 1,070.73 960.33 -169.99 51.92 5,959,170.29 549,942.68 5.00 169.99 1,200.00 34.75 169.22 1,155.27 1,044.87 -222.32 62.32 5,959,118.03 549,953.42 5.00 222.32 1,300.00 39.73 169.99 1,234.86 1,124.46 -281.83 73.20 5,959,058.60 549,964.71 5.00 281.83 1,400.00 44.71 170.61 1,308.89 1,198.49 -348.04 84.50 5,958,992.47 549,976.44 5.00 348.04 1,500.00 49.69 171.13 1,376.81 1,266.41 -420.47 96.12 5,958,920.13 549,988.54 5.00 420.47 1,600.00 54.68 171.58 1,438.10 1,327.70 -498.55 107.98 5,958,842.13 550,000.91 5.00 498.55 1,700.00 59.67 171.98 1,492.29 1,381.89 -581.70 119.97 5,958,759.08 550,013.46 5.00 581.70 1,732.70 61.30 172.10 1,508.40 1,398.00 -609.88 123.91 5,958,730.92 550,017.59 5.00 609.88 Base of Pentiafrost 1,800.00 64.66 172.34 1,538.97 1,428.57 -669.27 132.03 5,958,671.59 550,026.09 5.00 669.27 1,900.00 69.65 172.67 1,577.78 1,467.38 -760.61 144.04 5,958,580.34 550,038.71 5.00 760.61 2,000.00 74.64 172.98 1,608.43 1,498.03 -855.02 155.92 5,958,486.02 550,051.22 5.00 855.02 2,007.16 75.00 173.00 1,610.30 1,499.90 -861.88 156.77 5,958,479.17 550,052.11 5.00 861.88 Sail ~ 75°Inc 8173°Azi : 2007ft MD, 1610ft TVO 2,100.00 75.00 173.00 1,634.33 1,523.93 -950.89 167.70 5,958,390.25 550,063.63 0.00 950.89 2,200.00 75.00 173.00 1,660.21 1,549.81 -1,046.76 179.47 5,958,294.46 550,076.03 0.00 1,046.76 2,207.16 75.00 173.00 1,662.07 1,551.67 -1,053.63 180.31 5,958,287.60 550,076.92 0.00 1,053.63 Continue Build @ 3°/t00ft , 2207ft MD, 1662ft TVD 2,276.17 76.86 173.94 1,678.84 1,568.44 -1,120.13 187.92 5,958,221.16 550,084.97 3.00 1,120.13 Sail ~ 76.86°Inc 8173.94°Azi : 2276ft MD,1679ft ND 2,276.45 76.87 173.95 1,678.91 1,568.51 -1,120.40 187.95 5,958,220.89 550,085.00 3.00 1,120.40 2,300.00 76.87 173.95 1,684.26 1,573.86 -1,143.21 190.37 5, 958,198.10 550, 087.57 0.00 1,143.21 2,335.83 76.87 173.95 1,692.40 1,582.00 -1,177.91 194.05 5,958,163.43 550,091.48 0.00 1,177.91 T3 2,400.00 76.87 173.95 1,706.98 1,596.58 -1,240.05 200.64 5,958,101.34 550,098.49 0.00 1,240.05 2,500.00 76.87 173.95 1,729.71 1,619.31 -1,336.89 210.91 5,958,004.58 550,109.40 0.00 1,336.89 2,600.00 76.87 173.95 1,752.43 1,642.03 -1,433.73 221.18 5,957,907.82 550,120.31 0.00 1,433.73 2,700.00 76.87 173.95 1,775.15 1,664.75 -1,530.57 231.45 5,957,811.06 550,131.23 0.00 1,530.57 5J2f2005 7:49:45PM Page 4 of 10 COMPASS 2003.11 Build 48 ~~I~~~ / • ConocoPhilli s p Alaska Database: EDM 2003.11 Single User Db Company:.. ConocoPhillips Alaska {Kuparuk} Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: Plan 1 E-170 Wellbore: Plan 1E-170 Design: 1E-170(wp04) Hallibutton Company Planning Report -Geographic :Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ~ H L 1 RTON a ` Bu Sperry Drilling Services Well Plan 1 E-170 70.4 GL + 40 RT @ 110.40ft (Doyon 15) 70.4 GL + 40 RT @ 110.40ft (Doyon 15) True Minimum Curvature - - ~Planned Survey 1E-170 (wp04} ` Map Map MD Inclination Azimuth TYD SSTVD +Nf-Sr +p/.W Northing Easting DLSEV Vert Section (ftl (°) (°) (ft) ' {ft) (ft) , (ft) (ft) lft) (°/100ft) (ftl 2,800.00 76.87 173.95 1,797.88 1,687.48 -1,627.41 241.72 5,957,714.30 550,142.14 0.00 1,627.41 2,900.00 76.87 173.95 1,820.60 1,710.20 -1,724.25 252.00 5,957,617.54 550,153.05 0.00 1,724.25 3,000.00 76.87 173.95 1,843.32 1,732.92 -1,821.09 262.27 5,957,520.78 550,163.96 0.00 1,821.09 3,100.00 76.87 173.95 1,866.05 1,755.65 -1,917.93 272.54 5,957,424.02 550,174.88 0.00 1,917.93 3,200.00 76.87 173.95 1,888.77 1,778.37 -2,014.77 282.81 5,957,327.25 550,185.79 0.00 2,014.77 3,300.00 76.87 173.95 1,911.49 1,801.09 -2,111.61 293.08 5,957,230.49 550,196.70 0.00 2,111.61 3,400.00 76.87 173.95 1,934.22 1,823.82 -2,208.45 303.35 5,957,133.73 550,207.62 0.00 2,208.45 3,449.21 76.87 173.95 1,945.40 1,835.00 -2,256.11 308.41 5,957,086.12 550,212.99 0.00 2,256.11 K15 3,500.00 76.87 173.95 1,956.94 1,846.54 -2,305.30 313.62 5,957,036.97 550,218.53 0.00 2,305.30 3,600.00 76.87 173.95 1,979.67 1,869.27 -2,402.14 323.90 5,956,940.21 550,229.44 0.00 2,402.14 3,700.00 76.87 173.95 2,002.39 1,891.99 -2,498.98 334.17 5,956,843.45 550,240.36 0.00 2,498.98 3,800.00 76.87 173.95 2,025.11 1,914.71 -2,595.82 344.44 5,956,746.69 550,251.27 0.00 2,595.82 3,900.00 76.87 173.95 2,047.84 1,937.44 -2,692.66 354.71 5,956,649.93 550,262.18 ;0.00 2,692.66 4,000.00 76.87 173.95 2,070.56 1,960.16 -2,789.50 364.98 5,956,553.17 550,273.10 0.00 2,789.50 4,100.00 76.87 173.95 2,093.28 1,982.88 -2,886.34 375.25 5,956,456.41 550,284.01 0.00 2,886.34 4,200.00 76.87 173.95 2,116.01 2,005.61 -2,983.18 385.52 5,956,359.64 550,294.92 0.00 2,983.18 4,300.00 76.87 173.95 2,138.73 2,028.33 -3,080.02 395.80 5,956,262.88 550,305.84 0.00 3,080.02 4,400.00 76.87 173.95 2,161.46 2,051.06 -3,176.86 406.07 5,956,166.12 550,316.75 0.00 3,176.86 4,500.00 76.87 173.95 2,184.18 2,073.78 -3,273.70 416.34 5,956,069.36 550,327.66 0.00 3,273.70 4,600.00 76.87 173.95 2,206.90 2,096.50 -3,370.54 426.61 5,955,972.60 550,338.57 0.00 3,370.54 4,700.00 76.87 173.95 2,229.63 2,119.23 -3,467.38 436.88 5,955,875.84 550,349.49 0.00 3,467.38 4,800.00 76.87 173.95 2,252.35 2,141.95 -3,564.22 447.15 5,955,779.08 550,360.40 0.00 3,564.22 4,900.00 76.87 173.95 2,275.07 2,164.67 -3,661.07 457.42 5,955,682.32 550,371.31 0.00 3,661.07 5,000.00 76.87 173.95 2,297.80 2,187.40 -3,757.91 467.70 5,955,585.56 550,382.23 0.00 3,757.91 5,086.26 76.87 173.95 2,317.40 2,207.00 -3,841.44 476.56 5,955,502.09 550,391.64 0.00 3,841.44 13 3113" Casing ~ 508bYt MD, 2317f1 TVD - Dill Out 12114" Hole - T3 +875 5,100.00 76.87 173.95 2,320.52 2,210.12 -3,854.75 477.97 5,955,488.80 550,393.14 0.00 3,854.75 5,200.00 76.87 173.95 2,343.25 2,232.85 -3,951.59 488.24 5,955,392.03 550,404.05 0.00 3,951.59 5,300.00 76.87 173.95 2,365.97 2,255.57 -4,048.43 498.51 5,955,295.27 550,414.97 0.00 4,048.43 5,400.00 76.87 173.95 2,388.69 2,278.29 -4,145.27 508.78 5,955,198.51 550,425.88 0.00 4,145.27 5,500.00 76.87 173.95 2,411.42 2,301.02 -4,242.11 519.05 5,955,101.75 550,436.79 0.00 4,242.11 5,600.00 76.87 173.95 2,434.14 2,323.74 -4,338.95 529.32 5,955,004.99 550,447.71 .0.00 4,338.95 5,700.00 76.87 173.95 2,456.86 2,346.46 -4,435.79 539.60 5,954,908.23 550,458.62 0.00 4,435.79 5,800.00 76.87 173.95 2,479.59 2,369.19 -4,532.63 549.87 5,954,811.47 550,469.53 0.00 4,532.63 5,900.00 76.87 173.95 2,502.31 2,391.91 -4,629.47 560.14 5,954,714.71 550,480.45 0.00 4,629.47 6,000.00 76.87 173.95 2,525.04 2,414.64 -4,726.31 570.41 5,954,617.95 550,491.36 0.00 4,726.31 6,100.00 76.87 173.95 2,547.76 2,437.36 -4,823.15 580.68 5,954,521.19 550,502.27 0.00 4,823.15 6,200.00 76.87 173.95 2,570.48 2,460.08 -4,920.00 590.95 5,954,424.42 550,513.18 0.00 4,920.00 6,300.00 76.87 173.95 2,593.21 2,482.81 -5,016.84 601.22 5,954,327.66 550,524.10 0.00 5,016.84 6,400.00 76.87 173.95 2,615.93 2,505.53 -5,113.68 611.50 5,954,230.90 550,535.01 0.00 5,113.68 6,450.47 76.87 173.95 2,627.40 2,517.00 -5,162.56 616.68 5,954,182.06 550,540.52 0.00 5,162.56 Ugnu C 6,500.00 76.87 173.95 2,638.65 2,528.25 -5,210.52 621.77 5,954,134.14 550,545.92 0.00 5,210.52 6,600.00 76.87 173.95 2,661.38 2,550.98 -5,307.36 632.04 5,954,037.38 550,556.84 0.00 5,307.36 6,700.00 76.87 173.95 2,684.10 2,573.70 -5,404.20 642.31 5,953,940.62 550,567.75 0.00 5,404.20 6,800.00 76.87 173.95 2,706.83 2,596.43 -5,501.04 652.58 5,953,843.86 550,578.66 0.00 5,501.04 6,900.00 76.87 173.95 2,729.55 2,619.15 -5,597.88 662.85 5,953,747.10 550,589.58 0.00 5,597.88 7,000.00 76.87 173.95 2,752.27 2,641.87 -5,694.72 673.13 5,953,650.34 550,600.49 0.00 5,694.72 5/2(2005 7:49:45PM Page 5 of 10 COMPASS 2003.11 Build 48 OR'~~Nnl ~ • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: Plan 1E-170 Weitbore: Plan 1E-170 ;Design: 1E-170 (wp04) Halliburton Company • HALLiBUF4TON Planning Report -Geographic Sperry Drilling Services Local Co-0rdinate Reference: Well Plan 1E-170 TVD Reference: 70.4 GL + 40 RT @ 11-0.40ft {Doyon 15) MD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1E-170 (wpOA) Map Map MD Inclination Azimuth ' T1lD SSTW +N/.S +E/-W Northing Easting DLSEV Vert Section i (ftl (°) (`) (ft1 fft} (ft) (ft) (ft) (ft) (°I100ft) Ift) 7,100.00 76.87 173.95 2,775.00 2,664.60 -5,791.56 683.40 5,953,553.58 550,611.40 0.00 5,791.56 7,200.00 76.87 173.95 2,797.72 2,687.32 -5,888.40 693.67 5,953,456.81 550,622.32 0.00 5,888.40 7,300.00 76.87 173.95 2,820.44 2,710.04 -5,985.24 703.94 5,953,360.05 550,633.23 0.00 5,985.24 7,400.00 76.87 173.95 2,843.17 2,732.77 -6,082.08 714.21 5,953,263.29 550,644.14 0.00 6,082.08 7,436.23 76.87 173.95 2,851.40 2,741.00 -6,117.17 717.93 5,953,228.24 550,648.10 0.00 6,117.17 Ugnu B 7,500.00 76.87 173.95 2,865.89 2,755.49 -6,178.92 724.48 5,953,166.53 550,655.06 0.00 6,178.92 7,600.00 76.87 173.95 2,888.62 2,778.22 -6,275.77 734.75 5,953,069.77 550,665.97 0.00 6,275.77 7,612.26 76.87 173.95 2,891.40 2,781.00 -6,287.63 736.01 5,953,057.91 550,667.31 0.00 6,287.63 Ugnu A 7,700.00 76.87 173.95 2,911.34 2,800.94 -6,372.61 745.03 5,952,973.01 550,676.88 0.00 6,372.61 7,800.00 76.87 173.95 2,934.06 2,823.66 -6,469.45 755.30 5,952,876.25 550,687.79 0.00 6,469.45 7,900.00 76.87 173.95 2,956.79 2,846.39 -6,566.29 765.57 5,952,779.49 550,698.71 0.00 6,566.29 8,000.00 76.87 173.95 2,979.51 2,869.11 -6,663.13 775.84 5,952,682.73 550,709.62 0.00 6,663.13 8,100.00 76.87 173.95 3,002.23 2,891.83 -6,759.97 786.11 5,952,585.97 550,720.53 0.00 6,759.97 8,200.00 76.87 173.95 3,024.96 2,914.56 -6,856.81 796.38 5,952,489.20 550,731.45 0.00 6,856.81 8,300.00 76.87 173.95 3,047.68 2,937.28 -6,953.65 806.65 5,952,392.44 550,742.36 0.00 6,953.65 8,347.17 76.87 173.95 3,058.40 2,948.00 -6,999.33 811.50 5,952,346.80 550,747.51 0.00 6,999.33 K13 8,400.00 76.87 173.95 3,070.41 2,960.01 -7,050.49 816.93 5,952,295.68 550,753.27 0.00 7,050.49 8,500.00 76.87 173.95 3,093.13 2,982.73 -7,147.33 827.20 5,952,198.92 550,764.19 0.00 7,147.33 8,600.00 76.87 173.95 3,115.85 3,005.45 -7,244.17 837.47 5,952,102.16 550,775.10 0.00 7,244.17 8,700.00 76.87 173.95 3,138.58 3,028.18 -7,341.01 847.74 5,952,005.40 550,786.01 0.00 7,341.01 8,800.00 76.87 173.95 3,161.30 3,050.90 -7,437.85 858.01 5,951,908.64 550,796.93 0.00 7,437.85 8,890.67 76.87 173.95 3,181.90 3,071.50 -7,525.66 867.32 5,951,820.91 550,806.82 0.00 7,525.66 Continue Build (~ 3°/100ft , 8891ft MD , 31828 TVD 8,900.00 76.96 174.21 3,184.02 3,073.62 -7,534.70 868.26 5,951,811.87 550,807.82 2.99 7,534.70 9,000.00 78.00 177.10 3,205.70 3,095.30 -7,632.03 875.65 5,951,714.60 550,815.85 3.00 7,632.03 9,093.40 79.00 179.77 3,224.32 3,113.92 -7,723.51 878.15 5,951,623.15 550,818.95 3.00 7,723.51 Sail ~ 79°Inc & 179.77°Azi : 9093ft MD, 3224ft TVD 9,100.00 79.00 179.77 3,225.58 3,115.18 -7,729.99 878.17 5,951,616.67 550,819.02 0.00 7,729.99 9,193.40 79.00 179.77 3,243.40 3,133.00 -7,821.67 878.54 5,951,525.00 550,820.00 0.00 7,821.67 Intersect D.Sand ~ 791nc, 9193ft MD, 3243ft TVD -West Sak D -1 E-170 Dtop (wp04) 9,200.00 79.00 179.77 3,244.66 3,134.26 -7,828.15 878.57 5,951,518.52 550,820.07 0.00 7,828.15 9,300.00 79.00 179.77 3,263.74 3,153.34 -7,926.31 878.96 5,951,420.38 550,821.11 0.00 7,926.31 9,400.00 79.00 179.77 3,282.82 3,172.42 -8,024.47 879.35 5,951,322.23 550,822.16 0.00 8,024.47 9,408.28 79.00 179.77 3,284.40 3,174.00 -8,032.60 879.39 5,951,314.11 550,822.25 0.00 8,032.60 West Sak C 9,456.40 79.00 179.77 3,293.58 3,183.18 -8,079.84 879.58 5,951,266.87 550,822.75 0.00 8,079.84 Build ~ 3°NOOft to 81° Ilnc - 9458ft MD, 3294ft TVD 9,500.00 80.31 179.77 3,301.41 3,191.01 -8,122.73 879.75 5,951,223.99 550,823.21 3.00 8,122.73 9,523.07 81.00 179.77 3,305.16 3,194.76 -8,145.49 879.84 5,951,201.23 550,823.45 3.00 8,145.49 9,524.61 81.00 179.77 3,305.40 3,195.00 -8,147.01 879.85 5,951,199.71 550,823.47 0.00 8,147.01 Intersect BSand ~ 81°Inc , 9525ft MD, 3305ft ND -West Sak B 9,600.00 81.00 179.77 3,317.19 3,206.79 -8,221.47 880.14 5,951,125.26 550,824.26 0.00 8,221.47 9,700.00 81.00 179.77 3,332.84 3,222.44 -8,320.24 880.54 5,951,026.51 550,825.31 0.00 8,320.24 5x1/2005 7:49:45PM Page 6 of 10 OR'~!NAI_ COMPASS 2003.11 Build 48 S • ~ ll Ph Halliburton Company HALLIBURTON Conoco i ips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Coordinate Reference: Well Plan 1 E-170 Company: , ConocoPhillips Alaska (Kuparuk) TVD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Project: Kuparuk River Unit NID Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Site: Kuparuk 1 E Pad North Reference: True Well: Plan 1 E-170 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1 E-170 Design: 1 E-170 (wp04) Planned Survey 1 E-170 (wp04) Map Map i MD Inclination Azimuth TVD S$TVD +IdhS +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft1 Iftl 9,729.17 81.00 179.77 3,337.40 3,227.00 -8,349.05 880.66 5,950,997.70 550,825.62 0.00 8,349.05 West Sak A4 9,800.00 81.00 179.77 3,348.48 3,238.08 -8,419.01 880.94 5,950,927.75 550,826.36 0.00 8,419.01 9,900.00 81.00 179.77 3,364.12 3,253.72 -8,517.78 881.33 5,950,829.00 550,827.42 0.00 8,517.78 10,000.00 81.00 179.77 3,379.77 3,269.37 -8,616.55 881.73 5,950,730.25 550,828.47 0.00 8,616.55 10,010.44 81.00 179.77 3,381.40 3,271.00 -8,626.86 881.77 5,950,719.94 550,828.58 0.00 8,626.86 West Sak A3 10,100.00 81.00 179.77 3,395.41 3,285.01 -8,715.31 882.13 5,950,631.49 550,829.52 0.00 8,715.31 10,200.00 81.00 179.77 3,411.05 3,300.65 -8,814.08 882.52 5,950,532.74 550,830.57 0.00 8,814.08 10,300.00 81.00 179.77 3,426.70 3,316.30 -8,912.85 882.92 5,950,433.98 550,831.62 0.00 8,912.85 10,400.00 81.00 179.77 3,442.34 3,331.94 -9,011.62 883.32 5,950,335.23 550,832.68 0.00 9,011.62 10,425.95 81.00 179.77 3,446.40 3,336.00 -9,037.25 883.42 5,950,309.61 550,832.95 0.00 9,037.25 West Sak A2 10,433.00 81.00 179.77 3,447.50 3,337.10 -9,044.21 883.45 5,950,302.64 550,833.02 0.00 9,044.21 9 5/8" Casing @ 10433ft MD, 3448ft TVD - Drill Out 81/2" Hole 10,451.52 81.00 179.77 3,450.40 3,340.00 -9,062.50 883.52 5,950,284.36 550,833.22 0.00 9,062.50 1 E-170 T5 (wp04) 10,478.07 81.00 179.77 3,454.55 3,344.15 -9,088.73 883.63 5,950,258.13 550,833.50 0.00 9,088.73 Build @ 3°I100ft to 89.76° inc - 10478ft MD, 3455ft TVD 10,500.00 81.66 179,77 3,457.86 3,347.46 -9,110.40 883.71 5,950,236.46 550,833.73 2.99 9,110.40 10,600.00 84.66 179.77 3,469.77 3,359.37 -9,209.68 884.11 5,950,137.20 550,834.78 3.00 9,209.68 10,698.26 87.61 179.77 3,476.40 3,366.00 -9,307.71 884.50 5,950,039.18 550,835.82 3.00 9,307.71 1 E-170 T2 (wp04) 10,700.00 87.66 179.77 3,476.47 3,366.07 -9,309.44 884.50 5,950,037.45 550,835.84 2.93 9,309.44 10,770.07 89.76 179.78 3,478.05 3,367.65 -9,379.49 884.78 5,949,967.41 550,836.58 3.00 9,379.49 Begin Undulations in ASand. 10770ft MD. 347tift TVD - 1 E-170 T3 (wp04) 10,800.00 89.89 179.79 3,478.14 3,367.74 -9,409.42 884.89 5,949,937.49 550,836.89 0.45 9,409.42 10,900.00 90.34 179.83 3,477.93 3,367.53 -9,509.42 885.23 5,949,837.50 550,837.90 0.45 9,509.42 11,000.00 90.79 179.87 3,476.95 3,366.55 -9,609.41 885.50 5,949,737.52 550,838.83 0.45 9,609.41 11,100.00 91.24 179.90 3,475.17 3,364.77 -9,709.40 885.70 5,949,637.55 550,839.69 0.45 9,709.40 11,200.00 91.69 179.94 3,472.62 3,362.22 -9,809.37 885.84 5,949,537.59 550,840.49 0.45 9,809.37 11,270.07 92.00 179.97 3,470.37 3,359.97 -9,879.40 885.89 5,949,467.57 550,841.01 0.45 9,879.40 Sail @ 92° Inc : 11270ft MD, 3470ft TVD 11,300.00 92.00 179.97 3,469.32 3,358.92 -9,909.31 885.90 5,949,437.66 550,841.22 0.00 9,909.31 11,400.00 92.00 179.97 3,465.83 3,355.43 -10,009.25 885.95 5,949,337.73 550,841.94 0.00 10,009.25 11,470.07 92.00 179.97 3,463.38 3,352.98 -10,079.28 885.99 5,949,267.72 550,842.44 0.00 10,079.28 Drop @ 0.35°f100ft to 90.28°Inc : 11470ft MD, 3483ft TVD 11,500.00 91.90 179.98 3,462.36 3,351.96 -10,109.19 886.00 5,949,237.81 550,842.65 0.35 10,109.19 11,600.00 91.55 180.01 3,459.36 3,348.96 -10,209.14 886.01 5,949,137.86 550,843.32 0.35 10,209.14 11,700.00 91.20 180.04 3,456.96 3,346.56 -10,309.12 885.96 5,949,037.91 550,843.94 0.35 10,309.12 11,800.00 90.85 180.07 3,455.17 3,344.77 -10,409.10 885.86 5,948,937.93 550,844.50 0.35 10,409.10 11,900.00 90.50 180.10 3,453.99 3,343.59 -10,509.09 885.71 5,948,837.95 550,845.01 0.35 10,509.09 11,970.07 90.26 180.12 3,453.52 3,343.12 -10,579.16 885.57 5,948,767.89 550,845.34 0.35 10,579.16 Continue Drop @ 0.25°/100ft to 89°Inc : 11970ft MD, 3454ft TVD 5/2/2005 7:49:45PM Page 7 of 10 COMPASS 2003.118ui1d 48 OR!~!NAI ~ • / Halliburton Company NALLIBURTON ConOCO Phill~ps Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db :Local Co-ordinate Reference: Well Plarr 1 E-170 Company; ConocoPhillips Alaska (Kuparuk) TVDReference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Project: Kuparuk River Unit MD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Site: Kuparuk 1 E Pad North Reference: True Well: Plan 1 E-170 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1E-170 Design: 1 E-170 (wp04) Planned Survey 1 E-170 (wp04) Map Map MD Inclination Azimuth TVD SSTYD +N/S +E!-W Northing Easting DLSEV Vert Section i81 (°) (°) i81 (81 (ffl (ff) (8) (ft) (°l100ft1 Ift1 ii 12,000.00 90.18 180.13 3,453.41 3,343.01 -10,609.09 885.51 5,948,737.96 550,845.47 0.25 10,609.09 12,100.00 89.93 180.15 3,453.30 3,342.90 -10,709.09 885.26 5,948,637.97 550,845.89 0.25 10,709.09 12,200.00 89.69 180.17 3,453.64 3,343.24 -10,809.09 884.98 5,948,537.99 550,846.27 0.25 10,809.09 12,300.00 89.44 180.20 3,454.40 3,344.00 -10,909.08 884.66 5,948,438.00 550,846.61 0.25 10,909.08 12,400.00 i 89.19 180.22 3,455.60 3,345.20 -11,009.08 884.30 5,948,338.02 550,846.91 0.25 11,009.08 12,470.07 89.01 180.23 3,456.70 3,346.30 -11,079.14 884.02 5,948,267.96 550,847.10 0.25 - - 11,079.14 Sail ~ 89° Inc :124708 MD, 34678 TVD 12,500.00 89.01 180.23 3,457.22 3,346.82 12,600.00 89.01 180.23 3,458.94 3,348.54 12,670.07 89.01 180.23 3,460.15 3,349.75 Build ~ 0.30°!1008 to 90.6° Inc - 126708 MD, 34608 TVD 12,700.00 89.10 180.24 3,460.64 3,350.24 12,800.00 89.40 180.27 3,461.95 3,351.55 12,900.00 89.70 180.29 3,462.73 3,352.33 13,000.00 90.00 180.32 3,462.99 3,352.59 ' 13,100.00 90.30 180.35 3,462.74 3,352.34 13,170.07 90.51 180.36 3,462.24 3,351.84 Continue Build ~ 0.40°I1 008 to 90.6° lint - 131708 MD, 34628 TVD 13,200.00 90.63 180.37 3,461.95 3,351.55 13,300.00 91.02 180.41 3,460.51 3,350.11 13,400.00 91.42 180.44 3,458.37 3,347.97 ' 13,500.00 91.82 180.48 3,455.54 3,345.14 '~ 13,600.00 92.22 180.51 3,452.01 3,341.61 13,670.07 92.50 180.54 3,449.13 3,338.73 Sail ~ 92.5° Inc : 136708 MD, 34498 TYD ' 13,700.00 92.50 180.54 3,447.82 3,337.42 13,800.00 92.50 180.54 3,443.46 3,333.06 13,870.07 92.50 180.54 3,440.40 3,330.00 Drop ~ 0.26°N008 to 91.26°Inc :138708 MD, 34408 TVD 13,900.00 92.43 180.54 3,439.12 3,328.72 14,000.00 92.18 180.57 3,435.10 3,324.70 14,100.00 91.93 180.59 3,431.53 3,321.13 14,200.00 91.68 180.61 3,428.38 3,317.98 14,300.00 91.43 180.63 3,425.67 3,315.27 14,370.07 91.25 180.65 3,424.03 3,313.63 Continue Drop ~ 0.6b°!1008 to 88°Inc : i 143708 MD, 34248 TVD ~, 14,400.00 91.06 180.66 3,423.42 3,313.02 14,500.00 90.41 180.72 3,422.14 3,311.74 14,600.00 89.77 180.78 3,421.98 3,311.58 14,700.00 89.12 180.83 3,422.96 3,372.56 14,800.00 88.47 180.89 3,425.06 3,314.66 14,870.07 88.02 180.93 3,427.21 3,316.81 Sail ~ 88° inc :148708 MD, 34278 TVD 14,900.00 88.02 180.93 3,428.25 3,317.85 15,000.00 88.02 180.93 3,431.71 3,321.31 -11,109.06 883.90 5,948,238.04 550,847.18 0.00 11,109.06 -11,209.05 883.49 5,948,138.06 550,847.44 0.00 11,209.05 -11,279.11 883.21 5,948,068.01 550,847.62 0.00 11,279.11 -11,309.03 883.08 5,948,038.09 550,847.70 0.30 11,309.03 -11,409.02 882.64 5,947,938.11 550,847.92 0.30 11,409.02 -11,509.02 882.15 5,947,838.12 550,848.09 0.30 11,509.02 -11,609.02 881.62 5,947,738.13 550,848.22 0.30 11,609.02 -11,709.01 881.04 5,947,638.14 550,848.31 0.30 11,709.01 -11,779.08 880.61 5,947,568.08 550,848.34 0.30 11,779.08 -11,809.01 880.42 5,947,538.15 550,848.35 0.40 11,809.01 -11,909.00 879.73 5,947,438.17 550,848.33 0.40 11,909.00 -12,008.97 878.99 5,947,338.21 550,848.25 0.40 12,008.97 -12,108.93 878.18 5,947,238.26 550,848.11 0.40 12,108.93 -12,208.86 877.32 5,947,138.33 550,847.91 0.40 12,208.86 -12,278.87 876.68 5,947,068.33 550,847.73 0.40 12,278.87 -12,308.77 876.40 5,947,038.43 550,847.65 0.00 12,308.77 -12,408.67 875.46 5,946,938.53 550,847.37 0.00 12,408.67 -12,478.67 874.80 5,946,868.54 550,847.18 0.00 12,478.67 -12,508.57 874.52 5,946,838.64 550,847.10 0.25 12,508.57 -12,608.48 873.55 5,946,738.73 550,846.79 0.25 12,608.48 -12,708.42 872.55 5,946,638.80 550,846.45 0.25 12,708.42 -12,808.36 871.50 5,946,538.86 550,846.07 0.25 12,808.36 -12,908.32 870.42 5,946,438.91 550,845.65 0.25 12,908.32 -12,978.36 869.64 5,946,368.87 550,845.33 0.25 12,978.36 -13,008.29 869.29 5,946,338.95 550,845.19 0.65 13,008.29 -13,108.27 868.09 5,946,238.97 550,844.64 0.65 13,108.27 -13,208.26 866.78 5,946,138.98 550,844.00 0.65 13,208.26 -13,308.25 865.37 5,946,039.00 550,843.26 0.65 13,308.25 -13,408.21 863.87 5,945,939.03 550,842.42 0.65 13,408.21 -13,478.24 862.76 5,945,869.01 550,841.77 0.65 13,478.24 -13,508.15 862.27 5,945,839.10 550,841.48 0.00 13,508.15 -13,608.07 860.65 5,945,739.17 550,840.53 0.00 13,608.07 5/2/2005 7:49:45PM Page 8 of 10 COMPASS 2003.11 Build 48 o~~~~~~~ ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: Pian 1E-170 Wellbore: Plan 1E-170 Design: 1E-170 (wp04) ~ Halliburton Company HALLIBUFiTON Planning Report -Geographic Sperry Drilling Services Local.Coordinate Reference: Well Plan 1 E-170 TVD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) M17 References: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) North References True :Survey Calculation Method: Minimum Curvature Planned Survey 1 E-170 (wp04) Map Map MD Inclination Azimuth TVD SSTVD tNf.S +EI•V1l Northing Easting DLSEV Vert Section (ft- (°) {°) (ft} (ft) (ft) (ft) (ft) (ft) 1°I100ft) Ift) 15,070.07 88.02 180.93 3,434.13 3,323.73 -13,678.09 859.51 5,945,669.15 550,839.85 0.00 13,678.09 Build ~ 0.65°f100ft to 91.25° line - 15070ft MD, 3434tt TVD 15,100.00 88.21 180.95 3,435.12 3,324.72 -13,708.00 859.02 5,945,639.24 550,839.56 0.65 13,708.00 15,200.00 88.86 181.00 3,437.67 3,327.27 -13,807.96 857.32 5,945,539.29 550,838.53 0.65 13,807.96 15,300.00 89.51 181.06 3,439.10 3,328.70 -13,907.93 855.52 5,945,439.32 550,837.39 0.65 13,907.93 15,400.00 90.15 181.12 3,439.40 3,329.00 -14,007.91 853.62 5,945,339.34 550,836.15 0.65 14,007.91 15,500.00 90.80 181.17 3,438.57 3,328.17 -14,107.89 851.62 5,945,239.36 550,834.82 0.65 14,107.89 15,570.07 91.25 181.21 3,437.31 3,326.91 -14,177.93 850.16 5,945,169.32 550,833.82 0.65 14,177.93 Sail [(~ 91.25° ins : 1557011 MD, 3437ft TVD 15,600.00 91.25 181.21 3,436.66 3,326.26 -14,207.85 849.53 5,945,139.40 550,833.39 0.00 14,207.85 15,700.00 91.25 181.21 3,434.47 3,324.07 -14,307.80 847.41 5,945,039.44 550,831.94 0.00 14,307.80 15,800.00 91.25 181.21 3,432.28 3,321.88 -14,407.75 845.30 5,944,939.49 550,830.48 0.00 14,407.75 15,819.49 91.25 181.21 3,431.85 3,321.45 -14,427.24 844.88 5,944,920.00 550,830.20 0.00 14,427.24 BHL (~ 1165ft FSL 172ft FWL • Sec 34 • T11 N - R10E - 5 112" -1 E-170 Toe (wp04) Geologic Targets Plan 1E-170 TVD Target Name +W-S +EI-W (ft) `' -Shape ft ` ' ft 3,481.40 1E-170 T3 (wp04) -9,986.99 887.17 -Circle (radius 100.00) Northing Easting (ft) (ft) 5,949,360.00 550,843.00 3,479.40 1E-1 TO T1 (wp64) -8,386.76 880.79 5,950,960.00 -Circle (radius 100.00) 3,478.40 1E-170 T4 (wp04) -10,797.11 890.79 5,948,550.00 -Circle (radius 100.00) 3,243.40 1E-170 Dtop (wp04) -7,821.67 878.54 5,951,525.00 -Circle (radius 100.00) 3,450.40 1 E-170 TS (wp04) -13,044.28 875.87 5,946,303.00 -Circle (radius 100.00) 3,476.40 1E-170 T2 (wp04) -8,786.81 882.13 5,950,560.00 -Circle (radius 100.00) 3,438.40 1E-170 Toe (wp04) -14,427.24 844.68 5,944,920.00 -Circle (radius 100.00) 550,826.00 550,852.00 550,820.00 550,852.00 550,830.00 550,830.00 5/2/2005 T:49:45PM ORIGINAL COMPASS 2003.11 Build 48 • • 1E-170 Drilling Hazards Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole / 13 3/8" Casino Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets , um in out 12 1/4" Open Hole / 9 5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Stuck Pipe Low Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets , um in out 8 1/2" Open Hole ! 5 i!2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, Shut-in drills, Increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD Tools, Hole 0 ener, Decreased mud wei ht Lost Circulation Moderate Reduced um rates, Mud rheolo LCM Hole Swabbing on Trips High Trip speeds, Proper hole filling (use of trip sheets , Pum in out 1E-126 Drilling Hazards Summary prepared by Steve Shultz 4/20/2005 11:17 AM CemCADE Preliminary Job Design 13 3/8" Surface Preliminary Job Design basetl on Vimited input data. For estimate purposes only. Rig: DOYON 141 Location: WEST SAK Client: CPAI Revision Date: 4/23/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 Email: cakwukwaegbu@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 120' MD .,.i l +:~7 < Base of Permafrost at ( 2,052' MD (1,407 TV D) ~~ '~ ~..,.~ < Top of Tail at 4,500' MD < 13 3/8", 72.0# casing in 16" OH TD at 5,500' MD (2,308' TV D) Mark of Schlumberger Schlumberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 4,500' MD. Lead Slurry Minimum pump time: 340 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (120') x 1.00 (no excess) = 122.3 ft3 0.4206 ft3/ft x (2052' -120'} x 3.50 (250% excess) = 2844.1 ft3 0.4206 ft3/ft x (4500' - 2052') x 1.35 (35% excess) = 1390 ft3 122.3 ft3 + 2844.1 ft3+ 1390 ft3 = 4356.4 ft3 4356.4 ft3 / 4.45 ft3/sk = 979 sks Round up to 980 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 230 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.4206 ft3/ft x (5500' - 4500') x 1.35 (35% excess) = 567.8 ft3 0.8315 ft3lft x 80' (Shoe Joint) = 66.5 ft3 567.8 ft3 + 66.5 ft3 = 634.3 ft3 634.3 ft3/ 2.52 ft3/sk = 251.7 sks Round up to 260 sks BHST = 53°F, Estimated BHCT = 67°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5 10 2.0 2.0 Pressure Test Lines 10.0 12.0 CW 100 5 40 8.0 20.0 MudPUSH II 6 50 8.3 28.3 Drop Bottom Plug 5.0 33.3 Lead Slurry 7 777 111.0 144.3 Tail Slurry 6 117 19.5 163.8 Drop Top Plug 5.0 168.8 Water 5 20.0 4.0 172.8 Switch to Rig 5.0 177.8 Mud 7 768 109.7 287.5 Slow & bump plug 3 15 5.0 292.5 MUD REMOVAL Recommended Mud Properties: 8.8 ppg. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv~ 17-21, TY ~ 20-25 Centralizers: Recommend 2 per joint on the shoe track, and 1 per joint through the tail slurry, ORIGINAL CemCADE Preliminary Job Design 9.625" Intermediate Casin Preliminary Job Design based on limited input data. For estimate purposes only. Rig: DOYON 141 Location: WEST SAK Client: CPAI Revision Date: 4/23/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 Email: cakwukwaegbu@slb.com Previous Csg. < 13 3/8", 72.0# casing at 5,500' MD < Top of Tail at 6,000' MD < 9 518", 40.0# casing in 12 114" OH TD at 10,300' MD (3,464' ND) Mark of Schlumberger Schlumberger Volume Calculations and Cement Systems Volumes are based on 30% excess. Tail slurry is designed for 500' MD above Top of the Ugnu C - 4300' MD annular length. Tail Slurry Minimum thickening time: 270 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.3132 ft3fft x 4300' x 1.30 (30% excess) = 1750.8 ft3 0.4257 ft3Jft x 80' (Shoe Joint) = 34.1 ft3 1750.8 ft3 + 34.1 ft3 = 1784.9 ft3 1784.9 ft3/ 2.26 ft3lsk = 789.8 sks Round up to 790 sks BHST = 83°F, Estimated BHCT = 72°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5 10 2.0 2.0 Drop Bottom Plug 10.0 12.0 CW100 5 30 6.0 18.0 Drop bottom plug 5.0 23.0 MudPUSH II 6 40 6.7 29.7 Tail Slurry 6 318 53.0 82.7 Drop Top Plug 10.0 92.7 Displacement 7 755 107.9 200.6 Slow Rate 3 20 6.7 207.3 MUD REMOVAL Recommended Mud Properties: 9 ppg. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ~ 19-22, TY ~ 22-29 Centralizers: Recommend 2 tandem rise bow centralizers per joint on the shoe track and 1 tandem rise through the lateral areas. o~islr,a~ TO N V oas.e 7 Q Insulated Conducts /1 Casing, 20", 94#, K55 x Q ~ 34", 0.312" WT @ v +/- 80' MD ~~ rn ~7 ~ 7P"o ,~fD, w c ~ ~ -'s c ~' 3 ~~~ n ~ en J O 13-3/8", 68#, L-80, BTC, R3 @ +/- 5,086' MD / 2,317' TVD @ 77 degrees TD 16" hole Top of Ugnu C @ _ ~ 6,450' MD / 2,627' TVD Lateral Entry Module #2 (LEM), Baker, with seal bore and ZXP packer above. Wellhead /Tubing Head /Tree, 13-5/8" x 4-'/", 5,000 ksi Tubing String: 4- I /2", 12 6 #, L-80, 1 BTM (1) 3.875" DB nipple set @ 500' Top of West Sak D (a~ _ _ ~ 9,193' MD / 3,243' TVD Lateral Entry Module #I (LEM), Baker, with seal bore and ZXP packer above. Top of West Sak B @ ~ 9,523' MD / 3,305' TVD Tubing, 4-''/x" IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. ~° ~~ s~ ~. 3 Seal bore and ZXP packer for A2 liner +/_ q0' below "B" window 9-5/8", 40#, L-80, BTCM, R3 Csg @+/- 10,433' MD / 3,447' TVD @ 81 degrees TD I2-1/4" hole (I)Gas Lift Mandrels, CAMCO 4-I/2"x I" Model KBG-2, one (I) set at <72 deg, one at 2400' T V D. _ (I) Sliding Sleeve, with 3.812" nipple, one (1)joint above packer. 105 L2 "D" Sand Window @ +/- 9,193' M D / 3,243' T VD 79 degrees "D" Liner, 5-I/2", 15.5#, L80, BTCM, R3 Y slotted and '/:blank (0.125" x 2.5" slots, 32 per foot, 5 9%open area) 105 LI"B" Sand Window @ +/- 9,523' MD / 3,305' TVD SI degrees "B" Liner, 5-1/2", 15.5#, L80, BTCM, R3 '/z slotted and Yz blank, (0.125" x 2.5" slots, 32 per foot, 5.9 0 open area) 1~;_ ~_ A2 Sand Liner, 5-'/", 15.5#, L80, BTCM, R3'/: slotted and'/x blank, cnnsvicrors ju i.crdalion IE-170 Planned: AxP NAI) 27 F:aalinH.- 54'/,N%9 ASP NM 27 Nonhingx Syi9,739 I'ad I~:kvetion: lG.I' AMtiI. Doyon Rig 15 Rig Floor (RF) ~. 0' Elevatan: 94.1' AMSL IE-170 L2 8-I/2" D sand lateral TD 15,646' MD/ 3,184' TVD 1 E-170 L 1: 8-I/2" "B" sand lateral TD 15,650' MD / 3 258' TVD t E-170: 8-1/2 A2 sand Iateml TD 15,819' MD / 3,431' T VD • • ~ -------- Original Message -------- Subject:RE: 1E-170 Date:Tue, 10 May 2005 15:57:21 -0800 From:Greener, Mike R. <Mike.R.Greener@conocophillips.com> To:Thomas Maunder <tom maunder@admin.state.ak.us> The sclzeane is: The 1E-170 is a sister well to the 1E-117. Both are nearly identical except for the method of running file intermediate casing. ~n the 1E-117 we will only be able to reciprocate the casing while ce;mc~nting. C)n the 1E-170 we are planning on reciprocating and rotating the casing while cementing. The objective is to see ~x~•hich procedure gi~res us the best cement job. We will run a USI'1' log in both wells and compare them. This procedure is not required on all wells but, these ones that have such a long reach and high angle, the liner approach. may give us the best chance of getting a complete cement bond. So, I guess I would sa_y we are doing this for science. ~s much as a drilling person. hates to say it. Mike Greener z)0'7.2b3.4820 {office) 907.440.5333 (cel]) -----Original Message----- From: Thomas Maunder [mailto:tom maunders-admin.state.ak.us] Sent: Tuesday, May 10, 2005 3:03 PM To: Greener, Mike R. Subject: 1E-170 Mike, I was reading your detailed procedure (step 9) and it says you plan to run the 9-5/8" as a liner, but I don't find anything else that indicates setting the string as a liner and then tieing back with a seal assembly and packer. Could you enlighten me a bit on this. Thanks, Tom Maunder, PE 1 oft 5/10!2005 4:06 PM ~ • 1E-170 BB TLP Two-Trip Intermediate Liner Procedure 9-5/8" X 13-3/8" Liner System 1. Make up shoe track with float equipment and RIH. Check floats. 2. Make up and RIH with liner string filling every 5 joints. 3. Make up liner hanger equipment to liner and place gel debris barrier in liner tieback receptacle. 4. RIH one stand and circulate liner volume to ensure clear flowpath. 5. RIH with DP filling every 10 stands. 6. At shoe, circulate liner and DP volume, condition mud. Record P/LJ and S/O weights. 7. RIH to TD. 8. P/U TD plug dropping head on one joint DP and wash to bottom. 9. Circulate and reciprocate to condition mud. 10. Pump cement and spacer as required. 11. Drop pump down plug and displace with mud. 12. Stop reciprocating and set on depth approximately three barrels before pump down plug latches liner wiper plug. 13. Continue reciprocating during liner displacement. 14. Slow pumps to three barrels per minute before plug bumps and place liner at setting depth. 15. Bump plugs and pressure to +/- 2500 psi to set liner hanger. 16. Slack off all liner weight and an addition 20K lb to verify liner set and prepare running tool for release. 17. Continue to increase pressure to +/- 4000 psi to release HR running tool. 18. Bleed off pressure and check floats. Pick up to verify release of running tool. 19. Pressure DP to approximately 500 psi max and pick up to release R5 packoff from nipple. 20. Circulate out debris and excess cement. 9-5/8" X 13-3/8" Liner Tieback 1. Pick up JMXZP liner tieback packer, verify proper number of shear pins, check slips and ZX element. 2. Make up and RIH with 9-5/8" 40# liner to lower liner hanger. Record pick up and slack off weights. 3. Break circulation and idle pumps. Slack off to engage the seal stem into liner tieback sleeve on lower liner hanger. Note pressure increase as seals engage and stop pumps. Mark pipe. Pressure test annulus to verify seal integrity if required. 4. Pick up above tieback sleeve and circulate freeze protection as required. 5. Ensure liner is open at surface and slack off to engage seal stem into liner tieback sleeve. Continue to slack off approximately 10 feet and set 28K lb on setting shoulder to initiate setting process. 6. Slack off to 42K lb to initiate setting the ZX packer. Continue to slack off to 68K lb to complete the ZX set and actuate hold-down slips. Hold this weight for at least 5 minutes. 7. Pick up on string to verify set. 8. Pressure test annulus as required 9. Pull desired tension on liner string and set emergency slips. Note: Tension not to exceed 200K lbs. Re: [Fwd: Diverter Contingency on Production Pads] Subject: Re: [Fwd: Diverter Contingency on Production Pads] From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Tue, 10 May 2005 14:37:56 -0800 To: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> CC: "Thomas, Randy L" <Randy.L.Thomas@conocophillips.com> Thanks Mike, Your situation appears different than Doyon 14 at Milne Point where their line actually winds up pointing at the lines and cables. Being able to get the line underneath any production lines/cables goes a long way to eliminating the concerns the arrangement at Milne presents. Shortening the line to avoid "hanging out" into open space to about 60', running it under the production lines and securely anchoring it is acceptable. I will place a copy of this message in the 1E-170 well file. I suggest that a copy of this message be kept at the rigs and that a statement be made in the well plans when it is necessary to deviate from the established diverter regulations. Tom Maunder, PE AOGCC Greener, Mike R. wrote: We are using 60' diverter line on rig 141.. This tine goes t0 the edge of the pit in the center of the pad. The tine travels underneath. the producti«n tines by about 2 feet. Rig 1 S will. require the same setup. The short length. of the diverter line allows us to 4~nchor the end of the tine securer instead of the end. hanging out in open space as it would with. a Langer line. tiny modifications will. have to be made when. the rig atTives on the pad in about 30 days. Ivtike Greener 907.263.4820 (office} 907.440.5333 (cell) -----Original Message----- From: Thomas Maunder [mailtoaom maunder@admin.state.ak.us] Sent: Tuesday, May 10, 2005 2:07 PM To: Greener, Mike R. Subject: [Fwd: Diverter Contingency on Production Pads] Mike, I am starting to look at 1E-170. Will the diverter line need to be shortened and pointed at lines or cables?? I had sent this message to Randy, et al last week. This may apply. Tom ------- Original Message -------- Subject:Diverter Contingency on Production Pads Date:Tue, 03 May 2005 15:33:47 -0800 From:Thomas Maunder <torn maunder(e~,admin.state.ak.us> Organization:State of Alaska To:Randy Thomas Randy.L,Thomas;~;conocophillips.com>, Chip Alvord <C'hip.Alvord@conocophillips.com> CC:Jerome Eggemeyer <Jerome.C.Egg_eme~er(a?co~:~.ocophilliRs.com> Gentlemen, On several occasions, I have received requests to "shorten" the diverter 1 of 2 5/10/2005 3:12 PM Re: [Fwd: Diverter Contingency on Production Pads] • • line due to the presence of production lines and electric cables "ahead" of the rig. A similar situation has been encountered at Milne Point. I am curious if there are any established contingency plans for contacting your production counterparts should it be necessary to divert a well so that a pad can be SI or SD. If such plans are available, I would appreciate your sending me a copy. If such plans do not exist, I request that a protocol/procedure be developed. Milne has developed a process that is in place for their current drilling on E pad. Please call or message back to me with any questions. My assessment is that establishing such a protocol shouldn't be difficult. Please let me know if this is not the case. Tom Maunder, PE AOGCC 2 oft 5/10/2005 3:12 PM z~ ~ ~ .r;~ \ `0 ~1 ~2 • ~;. `~/ ~\ '~~~~ ~M ~ ,. ., ~\ ~~'~ ~' ........ _ .._._,... ._• A ,, _. 1 ~\ ,E / ~Zg~\ `v ~~~ \ 5 00 ~ ~~ 3 ~.. o ~~'Z ,~~ ,: ~, ~ Q n0 .~ 1 Q •. _.__. ........... v t ~~, .. 0 _. _. ~~ . _...... ~~ ~ 33 ~ooo ~'~~~~~~ ,., ~~~~~ ~~ / \~~y __. L ~~ o ,~, SHARON K, ALLSUP-DRAKE ~~ _ _ CONOCOPHILLIPS ~'--.~'-'-,._.~.~..._..~,-.~._?..,,.~'_"..~..,._" ATO 1530 goo G sr. 1102 ANCHORAGE AK 99501 (/~ _ FAY TO 7HE DATE v C ORDER OF 5~~~~ O` ~/ ,A~~ ~ ~"~ 62-14/311 -' i /~O~ ~~ CHASE Chase Manhattan Bank USA S ~~ /tea ~-" ~Q ,,,,, aoownnoaaycom~r .ro.a. DOLLARS L'f ,, ,,, of Dr., NewarF, DC 19111 Valid Up ro 5000 Dollars MEMO , y~ ~:0 3 l L00 14 4~; --__ -- 2184719079276u^ i102 -- _. _____ --..-.~.....~.,~M.___ • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~'~2GC~ /~ ' ~ ~~ PTD# ~ ~` d ~ r`' CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (pig records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & pool KUPARUK RIVER, WEST SAKOIL - 490150 Well Name: KUPARUK RIV U WSAK 1 E-170 Program DEV Well bore seg ^ PTD#:2050740 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11160 ONOff Shore On Annular Disposal ^ Administration 1 Petmitfeeattached - - - - - - - .Yes - - - - - - - - - - - - 2 Lease number appropriate- _ _ _ - - _ _ - - - - - - Yes - _ _ _ . Surface location in ADL 025651; top productive interval and_TD in ADL 025.660. - _ - _ - _ _ - 3 llrigpewell-natneandnumbet ............... Yes___-__ -___-__-__------_.----_--_-----,---_. 4 Well located in a_defnedpool--__-----_____-____-___-__- _,--___Yes_--__- _KRUWest_$ak Oil Pool,governed-byCanservation-Order No,4068--__-_-------------- ------ 5 Well located proper distance_from drilling unit.boundary_ - - - Yes _ _ - _ Well is morethan_ 500 feet from an external property line.. .. - . - _ . - - - - _ _ - - - - .. . _ _ 6 Well located proper distance from other wells_ _ _ _ . - - - - - - . _ - - - - - - - - . -Yes _ - . No restrictions as_to well spacing in CO.406B._ _ _ - - _ - - - . _ - _ _ _ - - - - ------------ 7 Sufficient acreage available in drilling unit_ - - - - _ - - - . - Yes _ - - _ _ - No restrictions as_to well spacing except that no_p_ay shall be opened in a well closer _ _ - _ - - 8 If deviated, is-wellkore plat_inoluded _ _ - _ _ - _ - - - _ _ - - - - , _ Yes _ _ _ than 5Q0 feet to_an external-property line.- _ - ------------------------------------- 9 Operator only affected party - - - - - - - Yes - - - - - - - - - - - - - - - - - - 10 Opetatorbas-appr-opriate.kondinforCe----------- --- -------- ---- ----Yes--•--- ------ ---- ------ ----------------• --------------------------- ---- 11 Permitcanbeissuedwithouiconservation4rder____-------------- -- _---Yes----- ------------------------------------------------------------- Appr Date 12 Permit_canbeissuedwithoutadministrative_appr_oval__--___________ _________Yes__-__ ._-___-_-_-__-_.__---_--_--_ ---------------------------------------- SFD 5/10/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorizedky-InjectionOtder#(putlO#in-comments).(For-NA_-____ ._____--------___.._.-_.__-._._.___-_-._--_-_---_--.__---_--_ 15 All wells-withinll4-mile area ofreyiewidentified(Forservieewell4nly)______ _________-JA-__.___ -._-__-._-__.___._.-__-___-__--_-__--__-__--_-_-___--__-__-__-____-__ 16 Pre-produced injector: dur_ation.of preproduction I_essthan.3 months_(For service well only) - NA- - - - - - - - - - - - - - 17 ACMP_Finding of Consistency_has been issued_fo[this pro]ect_ _ _ - - _ _ - NA_ - - - _ _ . _ _ - - --------------------------------------------------------- Engineering 18 Conducto~st[in9_p_rovided.-________________________--_ -_------Yes-_-_- -_-_---_-___- ------------------------------------------------------ 19 Surface easing_protectsallknawnU$DWs________________-_-_ ___-_--_-NA_-.__._ Allaqurfersexempted,40CFR-147.1Q2(bJ(3)._._.__._____-___._----_-__-___._--_-- 20 CM_T-vol_adequatetocircul_ate-on conductor_~surf_csg__-__-___--_- __-_--__.Yes______ ______________________-__--_--__-----__-___-_--_-_---_--_-_-_ - 21 CMT_vol_adeguate_tgrie-in long string to_surf rsg. - - - - _ . - - . - No_ _ - _ _ All hydrocarbons intended-to be coveted._ _ _ _ - _ _ _ . _ - - _ _ _ ----------------------- 22 CMT will cover all known-productive horizons. - - _ _ _ - _ - _ _ _ _ _ - _ - - - No_ - _ - - -Slotted liner completion planned, _ ----------------------------------------- 23 Casing designs adequate for C,T,B&,permafcost---------------- ---. -.--Yes------ ---------------------------------------------------------- ---- 24 Adequate tankage-or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes Rig isequipped with steel-pits. _No- reserve_p_itplanned, All waste to approved annulus.or Class II well. _ - - - - 25 Ifa-re•drill,has-a_10-403 for abandonment been approved_.__.__.___ _-__-_-_NA_______ _______________--_-__---__-_---_---_---_--_---_-----___--___--_ _ 26 Adequatewellbore separationproposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ - _ _ _ .Proximity analysis p@rf_ormed, Tray@ling cylinder path calculated, _ _ . _ _ - _ _ --------------------- 27 Ifdiverterrequired,doesitmeetregulations__-________________ _________ Yes_--___ _----_--- ------------------------------------------------------------ Appr Date 28 Dulling flu]d-program schematic-& equip list adequate- - - - - _ - _ - _ - Yes _ - - -Maximum expected formation pressure 8.6_EMW._ planned-MW in WS Q Oppg-- - - - - - - - - - - - - - - - - - TEM 5/1012005 29 BOPEs, do they meet regulation - - - - - - - - - - - - - _ - - _ - . _ - - Yes _ - - - _ - 5K Q ram, hydril_stack in_use.- CPAI suthgrized told run 1 DP- ram_ and 1 csg ram_ based on MASP < 30Q0_psi, 30 BOPE-press rating appropriate; test to-(put prig fn comments)- _ - - _ _ - _ _ Yes _ _ _ _ MASp caleuiated at 1 t67psi, 3000_psi_test appropriate.- CPAI_usually tests to 500Q psi.- , _ _ , _ 31 Choke-manifold complieswlAPl-Rp-53 (May $4_) - - - - Yes - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown--_-_-_______________ _________Yes_-.___ .__.__.-_-____-___-.-__._-._-.--.-_.-_-___-_--__-__._.---__-_- 33 Is presence_of H2S gas probakle- - - - - - - - - - - - - - - - - -- - - - - - - -- Yes _ . - - - . H2S has been reported in-1 E-WS p[oducfion. -Mud should preclude H2S op rig. _ Rig has-sensors and alarms. _ - 34 Mechanical condition of wells withinAORverifed(Forserviceweltonly)_____ _____-_NA___---_ --_--_----------------------------------------- - - - - - Geology 35 Permit-can be issued w!o hydtogen_sulfiderneasures - - - - - - - - - - - - - - - - - - No- _ - - - - . KRU 1E-pad West Sak wells measured from 22-to 76 ppm H2$ in 20Q4. R~-h_as sensors and. aiarms._ - - - - _ - _ 36 Data.presented on potential overpressure zones - - - - - - - - - - - - - Yes _ _ _ _ -Expected r_eservoirpressure fs 8,1_- 8,6_ppg EMW; will_be drilled with 9.0 ppg oil-base mud. Appr Date 37 Sefsmicanalysis_ ofshallow gas zones . . . . . . .. . . . . . _ _ - - _ . _ - _ NA_ _ _ - . _ _ - . _ - . - - _ _ - None expected._ . _ - _ . _ SFD 5!1012005 38 Seabed condition survey_(if off-shore) - _ - - - NA- - - -- - - - - - - - - - 39 -Contact namelphone for weekly progress_reports [exploratory only]_ . - - - _ - - . _ - - NA_ - _ - Geologic Engineering P lic Commissioner: Date: Commissioner: Date 'oner Date Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made 1o chronologically organize this category of information. • • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jan 06 16:25:32 2006 Reel Header Service name .............LISTPE Date .....................06/01/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Technical Services Tape Header Service name .............LISTPE Date .....................06/01/06 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: Scientific i3~~' Scientific 1E-170 500292326400 ConocoPhillips Alaska, Inc. Sperry Drilling Services 06-JAN-06 MWD RUN 3 MWD RUN 4 MWD RUN 8 MW0003778283 MW0003778283 MW0003778283 B. HENNINGSE B. HENNINGSE P. SMITH G. RIZEK G. RIZEK G. RIZEK MWD RUN 10 MWD RUN 11 MWD RUN 12 MW0003778283 MW0003778283 MW0003778283 P. SMITH P. SMITH B. HENNINGSE G. RIZEK G. RIZNEK G. RIZNEK 21 11N l0E 247 ~~~ ~-oz~ • FEE: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: • 641 111.05 70.40 WELL CASING RECORD OPEN HOLE BIT SIZE {IN) 1ST STRING 12.250 2ND STRING 8.500 3RD STRING PRODUCTION STRING REMARKS: CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 5054.0 9.625 10412.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. THIS WELLBORE WAS EFFECTED BY MEANS OF AN OPEN-HOLE SIDETRACK AT 13768'MD/ 3411'TVD, WITHIN THE RUN 10 INTERVAL OF THE 1E-170 PB3 WELLBORE. 5. MWD RUNS 3,4,8,10-12 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE-WHILE-DRILLING (PWD) RUNS 3,4,10 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUNS 8 & 10 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY {CTN), AZIMUTHAL STABILIZED LITHO-DENSITY (ABED), AND ACOUSTIC CALIPER {ACAL) NO PROGRESS WAS MADE ON RUNS 5 & 6 DUE TO CASING LEAKS; NO PROGRESS WAS MADE ON RUN 9 DUE TO A TOOL FAILURE. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. HOWEVER, RUN 8 DATA WERE CORRECTED (SHIFTED) TO RUN 7 DATA. THIS CORRECTION RESULTED IN A 6' UPHOLE SHIFT OF RUN 8 DATA. AN ADDITIONAL 2' UPHOLE CORRECTION WAS NEEDED FOR THIS SIDETRACK (TO CORRECT RUN 11 TO RUN 10) HEADER DATA RETAIN DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4,8,10-12 REPRESENT WELL 1E-170 WITH API#: 50-029-23264-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15940'MD/3354'TVD. • • SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0 PPG MUD SALINITY: 3000 - 44000 PPM CHLORIDES FORMATION WATER SALINITY: 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 $# FILE SUMMARY PBU TOOL CODE START DEPTH FET 5046.5 RPX 5046.5 RPS 5046.5 RPM 5046.5 RPD 5046.5 all bit runs merged. STOP DEPTH 15892.5 15892.5 15892.5 15892.5 15892.5 `~ GR 5054.0 15900.0 ROP 5090.5 15938.0 CALA 10395.0 15851.0 NPHI 10395.0 15846.0 FCNT 10395.0 15846.0 NCNT 10395.0 15846.0 RHOB 10395.0 15859.5 PEF 10395.0 15859.5 DRHO 10395.0 15859.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 5046.5 9108.0 4 9108.0 10420.0 8 10420.0 11342.0 10 11342.5 13768.0 11 13768.5 14433.0 12 14433.0 15938.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 CALA MWD INCH 4 1 68 56 15 • First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 15938 10492.3 21784 5046.5 15938 ROP MWD FT/H 0.09 4432.63 230.884 21696 5090.5 15938 GR MWD API 24.43 138.57 69.4662 21693 5054 15900 RPX MWD OHMM 2.1 1702.67 20.7731 21693 5046.5 15892.5 RPS MWD OHMM 3.85 2000 23.1191 21693 5046.5 15892.5 RPM MWD OHMM 3.83 1835.59 24.5372 21693 5046.5 15892.5 RPD MWD OHMM 4.26 2000 30.1071 21693 5046.5 15892.5 FET MWD HOUR 0.06 346.28 3.26568 21693 5046.5 15892.5 NPHI MWD PU-S 8.17 48.38 36.5555 10903 10395 15846 FCNT MWD CNTS 570.36 3803.51 894.226 10903 10395 15846 NCNT MWD CNTS 101643 194682 129361 10903 10395 15846 RHOB MWD G/CM 0.201 2.746 2.17085 10930 10395 15859.5 DRHO MWD G/CM -3.034 0.307 0.0284896 10930 10395 15859.5 PEF MWD BARN 0.82 12.46 2.04896 10930 10395 15859.5 CALA MWD INCH 8.43 10.26 8.84846 10350 10395 15851 First Reading For Entire File..........5046.5 Last Reading For Entire File...........15938 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 • Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5046.5 9064.0 FET 5046.5 9064.0 RPS 5046.5 9064.0 RPM 5046.5 9064.0 RPD 5046.5 9064.0 GR 5054.0 9071.5 ROP 5090.5 9108.0 LOG HEADER DATA DATE LOGGED: 06-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9108.0 TOP LOG INTERVAL (FT) 5090.0 BOTTOM LOG INTERVAL (FT) 9108.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.2 MAXIMUM ANGLE: 82.7 TOOL STRING (TOP TO $OTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 59672 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 5054.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 50.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 7.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.380 93.2 MUD FILTRATE AT MT: 5.000 65.0 MUD CAKE AT MT: 2.300 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): ~ s TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ....... ...... .....0 Data Specification Bloc k Type .....0 Logging Direction ...... ...... .....Down Optical log depth units ...... .....Feet Data Reference Point ... ...... .....Undefined Frame Spacing .......... ...... .....60 .lIN Max frames per record .. ...... .....Undefined Absent value ........... ...... .....-999 Depth Units ............ ...... ..... Datum Specification Blo ck sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 9108 7077.25 8124 5046.5 9108 ROP MWD030 FT/H 1.06 2345.03 329.886 8036 5090.5 9108 GR MWD030 API 24.43 138.57 65.8909 8036 5054 9071.5 RPX MWD030 OHMM 2.1 84.28 14.8458 8036 5046.5 9064 RPS MWD030 OHMM 4.74 2000 17.3313 8036 5046.5 9064 RPM MWD030 OHMM 5.09 1835.59 18.6538 8036 5046.5 9064 RPD MWD030 OHMM 5.01 2000 20.1687 8036 5046.5 9064 FET MWD030 HOUR 0.06 122.75 1.70767 8036 5046.5 9064 First Reading For Entire File..........5046.5 Last Reading For Entire File...........9108 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 • • Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 9064.5 10375.5 RPX 9064.5 10375.5 RPD 9064.5 10375.5 FET 9064.5 10375.5 RPM 9064.5 10375.5 GR 9072.0 10383.5 ROP 9108.5 10420.0 LOG HEADER DATA DATE LOGGED: 13-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10420.0 TOP LOG INTERVAL (FT) 9108.0 BOTTOM LOG INTERVAL (FT) 10420.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.7 MAXIMUM ANGLE: 81.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 5054.0 • BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 65.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.500 MUD AT MAX CIRCULATING TERMPERATURE: 1.490 MUD FILTRATE AT MT: 1.950 MUD CAKE AT MT: 1.980 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ....... ...... .....0 Data Specification Bloc k Type .....0 Logging Direction ...... ...... .....Down Optical log depth units ...... .....Feet Data Reference Point ... ...... .....Undefined Frame Spacing .......... ...... .....60 .lIN Max frames per record .. ...... .... .Undefined Absent value ........... ...... .... .-999 Depth Units ............ ...... ..... Datum Specification Blo ck sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 67.0 116.6 67.0 67.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9064.5 10420 9742.25 2712 9064.5 10420 ROP MWD040 FT/H 0.64 483.99 201.852 2624 9108.5 10420 GR MWD040 API 36.81 119.21 82.6243 2624 9072 10383.5 RPX MWD040 OHMM 3.15 55.4 13.0643 2623 9064.5 10375.5 RPS MWD040 OHMM 3.85. 102.95 17.9528 2623 9064.5 • 10375.5 RPM MWD040 OHMM 4.28 127.78 20.073 2623 9064.5 10375.5 RPD MWD040 OHMM 4.87 173.61 24.1989 2623 9064.5 10375.5 FET MWD040 HOUR 0.11 153.21 5.90547 2623 9064.5 10375.5 First Reading For Entire File..........9064.5 Last Reading For Entire File...........10420 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 10376.0 11342.0 RPX 10376.0 11342.0 RPS 10376.0 11342.0 RPD 10376.0 11342.0 RPM 10376.0 11342.0 GR 10384.0 11342.0 PEF 10395.0 11342.0 NPHI 10395.0 11342.0 FCNT 10395.0 11342.0 NCNT 10395.0 11342.0 RHOB 10395.0 11342.0 DRHO 10395.0 11342.0 CALA 10395.0 11342.0 ROP 10420.5 11342.0 • LOG HEADER DATA DATE LOGGED: 28-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11887.0 TOP LOG INTERVAL (FT) 10420.0 BOTTOM LOG INTERVAL (FT) 11887.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.8 MAXIMUM ANGLE: 97.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 66259 CTN COMP THERMAL NEUTRON 181190 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 727424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 10412.0 BOREHOLE CONDITIONS MUD TYPE: Versa Flo MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 99.0 MUD PH: .0 MUD CHLORIDES (PPM): 34500 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 120.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... • • Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 NPHI MWD080 PU-S 4 1 68 32 9 FCNT MWD080 CNTS 4 1 68 36 10 NCNT MWD080 CNTS 4 1 68 40 11 RHOB MWD080 G/CM 4 1 68 44 12 DRHO MWD080 G/CM 4 1 68 48 13 PEF MWD080 BARN 4 1 68 52 14 CALA MWD080 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10376 11342 10859 1933 10376 11342 ROP MWD080 FT/H 1.51 681.48 207.015 1844 10420.5 11342 GR MWD080 API 36.83 108.99 77.7795 1917 10384 11342 RPX MWD080 OHMM 5.7 1702.67 20.0173 1933 10376 11342 RPS MWD080 OHMM 5.67 1980.06 24.0165 1933 10376 11342 RPM MWD080 OHMM 3.83 1787.07 30.055 1933 10376 11342 RPD MWD080 OHMM 4.26 2000 79.805 1933 10376 11342 FET MWD080 HOUR 0.11 346.28 14.8962 1933 10376 11342 NPHI MWD080 PU-S 12.14 47.8 33.6859 1895 10395 11342 FCNT MWD080 CNTS 570.36 2501.56 775.959 1895 10395 11342 NCNT MWD080 CNTS 101643 166845 118078 1895 10395 11342 RHOB MWD080 GjCM 0.201 2.727 2.20377 1895 10395 11342 DRHO MWD080 G/CM -3.034 0.307 0.0144 1895 10395 11342 PEF MWD080 BARN 1.01 12.46 2.45808 1895 10395 11342 CALA MWD080 INCH 8.52 10.26 9.3589 1363 10395 11342 First Reading For Entire File..........10376 Last Reading For Entire File...........11342 • File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06j01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DRHO 11342.5 GR 11342.5 RPX 11342.5 RPS 11342.5 RPM 11342.5 RPD 11342.5 FET 11342.5 NPHI 11342.5 FCNT 11342.5 RHOB 11342.5 PEF 11342.5 CALA 11342.5 ROP 11342.5 NCNT 11342.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13768.0 13768.0 13768.0 13768.0 13768.0 13768.0 13768.0 13768.0 13768.0 13768.0 13768.0 13768.0 13768.0 13768.0 03-AUG-05 Insite 66.37 Memory 13768.0 11887.0 13768.0 88.9 96.1 • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 134758 CTN COMP THERMAL NEUTRON 179954 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 727424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 10412.0 BOREHOLE CONDITIONS MUD TYPE: Versa Pro NT MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 75.0 MUD PH: .0 MUD CHLORIDES (PPM): 50000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 155.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HOUR 4 1 68 28 8 NPHI MWD100 PU-S 4 1 68 32 9 FCNT MWD100 CNTS 4 1 68 36 10 • NCNT MWD100 CNTS 4 1 68 40 11 RHOB MWD100 G/CM 4 1 68 44 12 DRHO MWD100 G/CM 4 1 68 48 13 PEF MWD100 BARN 4 1 68 52 14 CALA MWD100 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11342.5 13768 12555.3 4852 11342.5 13768 ROP MWD100 FT/H 0.09 483.03 147.507 4852 11342.5 13768 GR MWD100 API 40.19 94.7 66.9313 4852 11342.5 13768 RPX MWD100 OHMM 6.16 130.45 29.0419 4852 11342.5 13768 RPS MWD100 OHMM 6.69 93.03 30.2045 4852 11342.5 13768 RPM MWD100 OHMM 7.15 156.59 31.0569 4852 11342.5 13768 RPD MWD100 OHMM 7.88 155.34 31.4266 4852 11342.5 13768 FET MWD100 HOUR 0.2 74.92 0.989998 4852 11342.5 13768 NPHI MWD100 PU-S 8.17 46.3 35.5877 4852 11342.5 13768 FCNT MWD100 CNTS 660 3803.51 939.905 4852 11342.5 13768 NCNT MWD100 CNTS 113765 194682 132180 4852 11342.5 13768 RHOB MWD100 GfCM 2.049 2.746 2.18474 4852 11342.5 13768 DRHO MWD100 GfCM -0.102 0.207 0.0312922 4852 11342.5 13768 PEF MWD100 BARN 0.82 5.8 2.04379 4852 11342.5 13768 CALA MWD100 INCH 8.47 9.89 8.75342 4852 11342.5 13768 First Reading For Entire File..........11342.5 Last Reading For Entire File...........13768 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF • File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 13768.5 ROP 13768.5 GR 13768.5 RPX 13768.5 RPS 13768.5 RPM 13768.5 RPD 13768.5 NCNT 13768.5 RHOB 13768.5 DRHO 13768.5 PEF 13768.5 CALA 13768.5 NPHI 13768.5 FET 13768.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 14341.5 14433.0 14395.0 14387.5 14387.5 14387.5 14387.5 14341.5 14354.5 14354.5 14354.5 14344.0 14341.5 14387.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den ACAL Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 03-AUG-05 Insite 66.37 Memory 14435.0 13768.0 14435.0 88.9 94.5 TOOL NUMBER 103770 134758 179954 10507541 727424 8.500 10412.0 • BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Versa Pro NT 9.00 75.0 .0 40000 .0 000 .0 000 155.0 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD110 FT/H 4 1 68 4 2 GR MWD110 API 4 1 68 8 3 RPX MWD110 OHMM 4 1 68 12 4 RPS MWD110 OHMM 4 1 68 16 5 RPM MWD110 OHMM 4 1 68 20 6 RPD MWD110 OHMM 4 1 68 24 7 FET MWD110 HOUR 4 1 68 28 8 NPHI MWD110 PU-S 4 1 68 32 9 FCNT MWD110 CNTS 4 1 68 36 10 NCNT MWD110 CNTS 4 1 68 40 11 RHOB MWD110 G/CM 4 1 68 44 12 DRHO MWD110 G/CM 4 1 68 48 13 PEF MWD110 BARN 4 1 68 52 14 CALA MWD110 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13768.5 14433 14100.8 1330 13768.5 • 14433 ROP MWD110 FT/H 2.85 2986.53 174.59 1330 13768.5 14433 GR MWD110 API 47.98 91.76 66.4715 1254 13768.5 14395 RPX MWD110 OHMM 7.81 77.9 23.9272 1239 13768.5 14387.5 RPS MWD110 OHMM 9.18 1360.63 27.0297 1239 13768.5 14387.5 RPM MWD110 OHMM 11.21 208.95 26.5496 1239 13768.5 14387.5 RPD MWD110 OHMM 13.03 78.15 27.3507 1239 13768.5 14387.5 FET MWD110 HOUR 0.19 3.99 0.916602 1239 13768.5 14387.5 NPHI MWD110 PU-S 18.25 48.38 37.4097 1147 13768.5 14341.5 FCNT MWD110 CNTS 671.4 2155.19 866.153 1147 13768.5 14341.5 NCNT MWD110 CNTS 115090 176053 130219 1147 13768.5 14341.5 RHOB MWD110 G/CM 2.05 2.636 2.13106 1173 13768.5 14354.5 DRHO MWD110 G/CM -0.025 0.153 0.028653 1173 13768.5 14354.5 PEF MWD110 BARN 0.95 5.54 1.8893 1173 13768.5 14354.5 CALA MWD110 INCH 8.43 9.89 8.82426 1152 13768.5 14344 First Reading For Entire File..........13768.5 Last Reading For Entire File...........14433 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD • Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 14342.0 FCNT 14342.0 NCNT 14342.0 CALA 14344.5 RHOB 14355.0 DRHO 14355.0. PEF 14355.0 RPM 14388.0 RPS 14388.0 RPD 14388.0 FET 14388.0 RPX 14388.0 GR 14395.5 ROP 14433.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 15846.0 15846.0 15848.0 15851.0 15859.5 15859.5 15859.5 15892.5 15892.5 15892.5 15892.5 15892.5 15902.0 15938.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den ACAL Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 07-AUG-05 Insite 66.37 Memory 15940.0 14435.0 15940.0 89.7 94.8 TOOL NUMBER 103770 134758 179954 10507541 727424 8.500 10412.0 Versa Pro NT 9.00 76.0 .0 41000 .0 000 .0 000 133.1 000 .0 000 .0 • • NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Re cord Data Record Type ......... .... ..... 0 Data Specification Block Type ..... 0 Logging Direction ........ .... ..... Down Optical log depth units.. .... ..... Feet Data Reference Point ..... .... ..... Undefined Frame Spacing ............ .... ..... 60 .lIN Max frames per record .... .... ..... Undefined Absent value ............. .... ..... -999 Depth Units .............. .... ..... Datum Specification Block sub -type...0 Name Service Order Units Si ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD120 FT/H 4 1 68 4 2 GR MWD120 API 4 1 68 8 3 RPX MWD120 OHMM 4 1 68 12 4 RPS MWD120 OHMM 4 1 68 16 5 RPM MWD120 OHMM 4 1 68 20 6 RPD MWD120 OHMM 4 1 68 24 7 FET MWD120 HOUR 4 1 68 28 8 NPHI MWD120 PU-S 4 1 68 32 9 FCNT MWD120 CNTS 4 1 68 36 10 NCNT MWD120 CNTS 4 1 68 40 11 RHOB MWD120 G/CM 4 1 68 44 12 DRHO MWD120 G/CM 4 1 68 48 13 PEF MWD120 BARN 4 1 68 52 14 CALA MWD120 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14342 15938 15140 3193 14342 15938 ROP MWD120 FT/H 0.61 4432.63 165.778 3010 14433.5 15938 GR MWD120 API 49.11 93.19 67.5816 3014 14395.5 15902 RPX MWD120 OHMM 7.21 58.77 29.173 3010 14388 15892.5 RPS MWD120 OHMM 8.1 55.86 29.4661 3010 14388 15892.5 RPM MWD120 OHMM 8.96 83.19 29.2532 3010 14388 15892.5 RPD MWD120 OHMM 9.26 214.8 28.8806 3010 14388 15892.5 • .7 FET MWD120 HOUR 0.23 43.35 2.29102 3010 14388 15892.5 NPHI MWD120 PU-S 13.25 48.24 39.5976 3009 14342 15846 FCNT MWD120 CNTS 633.43 3026.37 905.752 3009 14342 15846 NCNT MWD120 CNTS 112359 185382 131594 3013 14342 15848 RHOB MWD120 GjCM 2.034 2.661 2.14324 3010 14355 15859.5 DRHO MWD120 G/CM -0.072 0.219 0.0327784 3010 14355 15859.5 PEF MWD120 BARN 1.04 4.54 1.86194 3010 14355 15859.5 CALA MWD120 INCH 8.53 9.73 8.77915 2983 14344.5 15851 First Reading For Entire File..........14342 Last Reading For Entire File...........15938 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/01/06 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/01/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF • Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jan 06 16:25:32 2006 Reel Header Service name .............LISTPE Date .....................06/01/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/01/06 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. • I ~~~ ~~ Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1E-170 API NUMBER: 500292326400 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 06-JAN-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 8 JOB NUMBER: MW0003778283 MW0003778283 MW0003778283 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE P. SMITH OPERATOR WITNESS: G. RIZEK G. RIZEK G. RIZEK MWD RUN 10 MWD RUN 11 MWD RUN 12 JOB NUMBER: MW0003778283 MW0003778283 MW0003778283 LOGGING ENGINEER: P. SMITH P. SMITH B. HENNINGSE OPERATOR WITNESS: G. RIZEK G. RIZNEK G. RIZNEK SURFACE LOCATION SECTION: 21 TOWNSHIP: 11N RANGE: l0E FNL: 247 FSL: FEL: 641 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 111.05 GROUND LEVEL: 70.40 WELL CASING RECORD OPEN HOLE CASING DRILLER S I ' 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 5054.0 8.500 9.625 10412.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. THIS WELLBORE WAS EFFECTED BY MEANS OF AN OPEN-HOLE SIDETRACK AT 13768'MD/ 3411'TVD, WITHIN THE RUN 10 INTERVAL OF THE 1E-170 PB3 WELLBORE. 5. MWD RUNS 3,4,8,10-12 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE-WHILE-DRILLING (PWD) RUNS 3,4,10 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUNS 8 & 10 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL STABILIZED LITHO-DENSITY (ABED), AND ACOUSTIC CALIPER (ACAL) NO PROGRESS WAS MADE ON RUNS 5 & 6 DUE TO CASING LEAKS; NO PROGRESS WAS MADE ON RUN 9 DUE TO A TOOL FAILURE. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. HOWEVER, RUN 8 DATA WERE CORRECTED (SHIFTED) TO RUN 7 DATA. THIS CORRECTION RESULTED IN A 6' UPHOLE SHIFT OF RUN 8 DATA. AN ADDITIONAL 2' UPHOLE CORRECTION WAS NEEDED FOR THIS SIDETRACK (TO CORRECT RUN 11 TO RUN 10). HEADER DATA RETAIN DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4,8,10-12 REPRESENT WELL 1E-170 WITH API#: 50-029-23264-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15940'MD/3354'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. i ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0 PPG MUD SALINITY: 3000 - 44000 PPM CHLORIDES FORMATION WATER SALINITY: 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 5046.5 15892.5 RPX 5046.5 15892.5 RPS 5046.5 15892.5 RPM 5046.5 15892.5 RPD 5046.5 15892.5 GR 5054.0 15900.0 ROP 5090.5 15938.0 CALA 10395.0 15851.0 NPHI 10395.0 15846.0 FONT 10395.0 15846.0 NCNT 10395.0 15846.0 RHOB 10395.0 15859.5 PEF 10395.0 15859.5 DRHO 10395.0 15859.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 5046.5 4 9108.0 8 10420.0 10 11342.5 MERGE BASE 9108.0 10420.0 11342.0 13768.0 • MWD 11 13768.5 14433.0 MWD 12 14433.0 15938.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD GALA MWD Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU-S FCNT MWD CNTS NCNT MWD CNTS RHOB MWD G/CM DRHO MWD G/CM PEF MWD BARN CALA MWD INCH Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU-S 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 G/CM 4 1 68 44 12 G/CM 4 1 68 48 13 BARN 4 1 68 52 14 INCH 4 1 68 56 15 First Last Min Max Mean Nsam Reading Reading 5046.5 15938 10492.3 21784 5046.5 15938 0.09 4432.63 230.884 21696 5090.5 15938 24.43 138.57 69.4662 21693 5054 15900 2.1 1702.67 20.7731 21693 5046.5 15892.5 3.85 2000 23.1191 21693 5046.5 15892.5 3.83 1835.59 24.5372 21693 5046.5 15892.5 4.26 2000 30.1071 21693 5046.5 15892.5 0.06 346.28 3.26568 21693 5046.5 15892.5 8.17 48.38 36.5555 10903 10395 15846 570.36 3803.51 894.226 10903 10395 15846 101643 194682 129361 10903 10395 15846 0.201 2.746 2.17085 10930 10395 15859.5 -3.034 0.307 0.0284896 10930 10395 15859.5 0.82 12.46 2.04896 10930 10395 15859.5 8.43 10.26 8.84846 10350 10395 15851 First Reading For Entire File..........5046.5 Last Reading For Entire File...........15938 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5046.5 9064.0 FET 5046.5 9064.0 RPS 5046.5 9064.0 RPM 5046.5 9064.0 RPD 5046.5 9064.0 GR 5054.0 9071.5 ROP 5090.5 9108.0 LOG HEADER DATA DATE LOGGED: 06-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9108.0 TOP LOG INTERVAL (FT) 5090.0 BOTTOM LOG INTERVAL (FT) 9108.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.2 MAXIMUM ANGLE: 82.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 59672 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT): 5054.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 50.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 7.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.380 93.2 MUD FILTRATE AT MT: 5.0 00 6 MUD CAKE AT MT: 2.3 00 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 6$ 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 9108 7077.25 8124 5046.5 9108 ROP MWD030 FT/H 1.06 2345.03 329.886 8036 5090.5 9108 GR MWD030 API 24.43 138.57 65.8909 8036 5054 9071.5 RPX MWD030 OHMM 2.1 84.28 14.8458 8036 5046.5 9064 RPS MWD030 OHMM 4.74 2000 17.3313 8036 5046.5 9064 RPM MWD030 OHMM 5.09 1835.59 18.6538 8036 5046.5 9064 RPD MWD030 OHMM 5.01 2000 20.1687 8036 5046.5 9064 FET MWD030 HOUR 0.06 122.75 1.70767 8036 5046.5 9064 First Reading For Entire File..........5046.5 Last Reading For Entire File...........9108 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header • Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 9064.5 10375.5 RPX 9064.5 10375.5 RPD 9064.5 10375.5 FET 9064.5 10375.5 RPM 9064.5 10375.5 GR 9072.0 10383.5 ROP 9108.5 10420.0 LOG HEADER DATA DATE LOGGED: 13-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10420.0 TOP LOG INTERVAL (FT) 9108.0 BOTTOM LOG INTERVAL (FT) 10420.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.7 MAXIMUM ANGLE: 81.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 5054.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): LSND 9.30 65.0 8.5 800 4.0 2.500 67,0 1.490 116.6 1.950 67.0 1.980 67.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9064.5 10420 9742.25 2712 9064.5 10420 ROP MWD040 FT/H 0.64 483.99 201.852 2624 9108.5 10420 GR MWD040 API 36.81 119.21 82.6243 2624 9072 10383.5 RPX MWD040 OHMM 3.15 55.4 13.0643 2623 9064.5 10375.5 RPS MWD040 OHMM 3.85 102.95 17.9528 2623 9064.5 10375.5 RPM MWD040 OHMM 4.28 127.78 20.073 2623 9064.5 10375.5 RPD MWD040 OHMM 4.87 173.61 24.1989 2623 9064.5 10375.5 FET MWD040 HOUR 0.11 153.21 5.90547 2623 9064.5 10375.5 First Reading For Entire File..........9064.5 Last Reading For Entire File...........10420 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.,....,06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 • • Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 10376.0 11342.0 RPX 10376.0 11342.0 RPS 10376.0 11342.0 RPD 10376.0 11342.0 RPM 10376.0 11342.0 GR 10384.0 11342.0 PEF 10395.0 11342.0 NPHI 10395.0 11342.0 FCNT 10395.0 11342.0 NCNT 10395.0 11342.0 RHOB 10395.0 11342.0 DRHO 10395.0 11342.0 CALA 10395.0 11342.0 ROP 10420.5 11342.0 LOG HEADER DATA DATE LOGGED: 28-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11887.0 TOP LOG INTERVAL (FT) 10420.0 BOTTOM LOG INTERVAL (FT) 11887.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.8 MAXIMUM ANGLE: 97.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 66259 CTN COMP THERMAL NEUTRON 181190 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 727424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 10412.0 BOREHOLE CONDITIONS MUD TYPE: Versa Flo MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S) 99.0 MUD PH: •0 MUD CHLORIDES (PPM): 34500 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 120.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. Down Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type ...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 ROP MWDO80 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWDO80 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 NPHI MWD080 PU-S 4 1 68 32 9 FCNT MWDO80 CNTS 4 1 68 36 10 NCNT MWD080 CNTS 4 1 68 40 11 RHOB MWDO80 G/CM 4 1 68 44 12 DRHO MWD080 G/CM 4 1 68 48 13 PEF MWDO80 BARN 4 1 68 52 14 CALA MWDO80 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10376 11342 10859 1933 10376 11342 ROP MWDO80 FT/H 1.51 681.48 207.015 1844 10420.5 11342 GR MWD080 API 36.83 108.99 77.7795 1917 10384 11342 RPX MWDO80 OHMM 5.7 1702.67 20.0173 1933 10376 11342 RPS MWD080 OHMM 5.67 1980.06 24.0165 1933 10376 11342 RPM MWDO80 OHMM 3.83 1787.07 30.055 1933 10376 11342 RPD MWDOSO OHMM 4.26 2000 79.805 1933 10376 11342 FET MWD080 HOUR 0.11 346.28 14.8962 1933 10376 11342 NPHI MWD080 PU-S 12.14 47.8 33.6859 1895 10395 11342 FCNT MWD080 CNTS 570.36 2501.56 775.959 1895 10395 11342 NCNT MWD080 CNTS 101643 166845 118078 1895 10395 11342 RHOB MWD080 G/CM 0.201 2.727 2.20377 1895 10395 11342 DRHO MWDO80 G/CM -3.034 0.307 0.0144 1895 10395 11342 PEF MWD080 BARN 1.01 12.46 2.45808 1895 10395 11342 CALA MWDO80 INCH 8.52 10.26 9.3589 1363 10395 11342 First Reading For Entire File..........10376 Last Reading For Entire File...........11342 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number.........,,1.0.0 • Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH DRHO 11342.5 13768.0 GR 11342.5 13768.0 RPX 11342.5 13768.0 RPS 11342.5 13768.0 RPM 11342.5 13768.0 RPD 11342.5 13768.0 FET 11342.5 13768.0 NPHI 11342.5 13768.0 FCNT 11342.5 13768.0 RHOB 11342.5 13768.0 PEF 11342.5 13768.0 CALA 11342.5 13768.0 ROP 11342.5 13768.0 NCNT 11342.5 13768.0 LOG HEADER DATA DATE LOGGED: 03-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13768.0 TOP LOG INTERVAL (FT) 11887.0 BOTTOM LOG INTERVAL (FT) 13768.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.9 MAXIMUM ANGLE: 96.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 134758 CTN COMP THERMAL NEUTRON 179954 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 727424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT ROP MWD100 GR MWD100 RPX MWD100 RPS MWD100 RPM MWD100 RPD MWD100 FET MWD100 NPHI MWD100 FCNT MWD100 NCNT MWD100 RHOB MWD100 DRHO MWD100 PEF MWD100 GALA MWD100 Name Service Unit DEPT FT ROP MWD100 FT/H GR MWD100 API RPX MWD100 OHMM RPS MWD100 OHMM RPM MWD100 OHMM RPD MWD100 OHMM FET MWD100 HOUR • 8.500 10412.0 Versa Pro NT 9.00 75.0 .0 50000 .0 .000 .0 .000 155.0 .000 .0 .000 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU-S 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 G/CM 4 1 68 44 12 G/CM 4 1 68 48 13 BARN 4 1 68 52 14 INCH 4 1 68 56 15 First Last Min Max Mean Nsam Reading Reading 11342.5 13768 12555.3 4852 11342.5 13768 0.09 483.03 147.507 4852 11342.5 13768 40.19 94.7 66.9313 4852 11342.5 13768 6.16 130.45 29.0419 4852 11342.5 13768 6.69 93.03 30.2045 4852 11342.5 13768 7.15 156.59 31.0569 4852 11342.5 13768 7.88 155.34 31.4266 4852 11342.5 13768 0.2 74.92 0.989998 4852 11342.5 13768 ~~ NPHI MWD100 PU-S 8.17 46.3 35.5877 4852 FCNT MWD100 CNTS 660 3803.51 939.905 4852 NCNT MWD100 CNTS 113765 194682 132180 4852 RHOB MWD100 G/CM 2.049 2.746 2.18474 4852 DRHO MWD100 G/CM -0.102 0.207 0.0312922 4852 PEF MWD100 BARN 0.82 5.8 2.04379 4852 GALA MWD100 INCH 8.47 9.89 8.75342 4852 First Reading For Entire File..........11342.5 Last Reading For Entire File...........13768 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06j01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD 342.5 13768 11342.5 13768 11342.5 13768 11342.5 13768 11342.5 13768 11342.5 13768 11342.5 13768 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 #~ FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 13768.5 14341.5 ROP 13768.5 14433.0 GR 13768.5 14395.0 RPX 13768.5 14387.5 RPS 13768.5 14387.5 RPM 13768.5 14387.5 RPD 13768.5 14387.5 NCNT 13768.5 14341.5 RHOB 13768.5 14354.5 DRHO 13768.5 14354.5 PEF 13768.5 14354.5 CALA 13768.5 14344.0 NPHI 13768.5 14341.5 FET 13768.5 14387.5 LOG HEADER DATA DATE LOGGED: 03-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14435.0 • TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL {FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den ACAL Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT ROP MWD110 GR MWD110 RPX MWD110 RPS MWD110 RPM MWD110 RPD MWD110 FET MWD110 NPHI MWD110 FCNT MWD110 NCNT MWD110 13768.0 14435.0 88.9 94.5 TOOL NUMBER 103770 134758 179954 10507541 727424 8.500 10412.0 Versa Pro NT 9.00 75.0 .0 40000 .0 .000 .0 .000 155.0 .000 .0 .000 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU-S 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 ~ i RHOB MWD110 G/CM 4 1 68 44 12 DRHO MWD110 G/CM 4 1 68 48 13 PEF MWD110 BARN 4 1 68 52 14 CALA MWD110 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13768.5 14433 14100.8 1330 13768.5 14433 ROP MWD110 FT/H 2.85 2986.53 174.59 1330 13768.5 14433 GR MWD110 API 47.98 91.76 66.4715 1254 13768.5 14395 RPX MWD110 OHMM 7.81 77.9 23.9272 1239 13768.5 14387.5 RPS MWD110 OHMM 9.18 1360.63 27.0297 1239 13768.5 14387.5 RPM MWD110 OHMM 11.21 208.95 26.5496 1239 13768.5 14387.5 RPD MWD110 OHMM 13.03 78.15 27.3507 1239 13768.5 14387.5 FET MWD110 HOUR 0.19 3.99 0.916602 1239 13768.5 14387.5 NPHI MWD110 PU-S 18.25 48.38 37.4097 1147 13768.5 14341.5 FCNT MWD110 CNTS 671.4 2155.19 866.153 1147 13768.5 14341.5 NCNT MWD110 CNTS 115090 176053 130219 1147 13768.5 14341.5 RHOB MWD110 G/CM 2.05 2.636 2.13106 1173 13768.5 14354.5 DRHO MWD110 G/CM -0.025 0.153 0.028653 1173 13768.5 14354.5 PEF MWD110 BARN 0.95 5.54 1.8893 1173 13768.5 14354.5 CALA MWD110 INCH 8.43 9.89 8.82426 1152 13768.5 14344 First Reading For Entire File..........13768.5 Last Reading For Entire File...........14433 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 14342.0 15846.0 FCNT 14342.0 15846.0 NCNT 14342.0 15848.0 CALA 14344.5 15851.0 RHOB 14355.0 15859.5 DRHO 14355.0 15859.5 PEF 14355.0 15859.5 RPM 14388.0 15892.5 RPS 14388.0 15892.5 RPD 14388.0 15892.5 FET 14388.0 15892.5 RPX 14388.0 15892.5 GR 14395.5 15902.0 ROP 14433.5 15938.0 LOG HEADER DATA DATE LOGGED: 07-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15940.0 TOP LOG INTERVAL (FT) 14435.0 BOTTOM LOG INTERVAL (FT) 15940.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.7 MAXIMUM ANGLE: 94.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 134758 CTN COMP THERMAL NEUTRON 179954 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 727424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 10412.0 BOREHOLE CONDITIONS MUD TYPE: Versa Pro NT MUD DENSITY (LBjG) 9.00 MUD VISCOSITY (S) 76.0 MUD PH: .0 MUD CHLORIDES (PPM): 41000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 133.1 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Uni ts ..... .......... ........ Datum Spe cificat ion Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD120 FT/H 4 1 68 4 2 GR MWD120 API 4 1 68 8 3 RPX MWD120 OHMM 4 1 68 12 4 RPS MWD120 OHMM 4 1 68 16 5 RPM MWD120 OHMM 4 1 68 20 6 RPD MWD120 OHMM 4 1 68 24 7 FET MWD120 HOUR 4 1 68 28 8 NPHI MWD120 PU-S 4 1 68 32 9 FONT MWD120 CNTS 4 1 68 36 10 NCNT MWD120 CNTS 4 1 68 40 11 RHOB MWD120 G/CM 4 1 68 44 12 DRHO MWD120 G/CM 4 1 68 48 13 PEF MWD120 BARN 4 1 68 52 14 CALA MWD120 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14342 15938 15140 3193 14342 15938 ROP MWD120 FT/H 0.61 4432.63 165.778 3010 14433.5 15938 GR MWD120 API 49.11 93.19 67.5816 3014 14395.5 15902 RPX MWD120 OHMM 7.21 58.77 29.173 3010 14388 15892.5 RPS MWD120 OHMM 8.1 55.86 29.4661 3010 14388 15892.5 RPM MWD120 OHMM 8.96 83.19 29.2532 3010 14388 15892.5 RPD MWD120 OHMM 9.26 214.8 28.8806 3010 14388 15892.5 FET MWD120 HOUR 0.23 43.35 2.29102 3010 14388 15892.5 NPHI MWD120 PU-S 13.25 48.24 39.5976 3009 14342 15846 FCNT MWD120 CNTS 633.43 3026.37 905.752 3009 14342 15846 NCNT MWD120 CNTS 112359 185382 131594 3013 14342 15848 RHOB MWD120 G/CM 2.034 2.661 2.14324 3010 14355 15859.5 DRHO MWD120 G/CM -0.072 0.219 0 .0327784 3010 14355 15859.5 PEF MWD120 BARN 1.04 4.54 1.86194 3010 14355 15859.5 CALA MWD120 INCH 8.53 9.73 8.77915 2983 14344.5 15851 First Reading For Entire File..........14342 Last Reading For Entire File...........15938 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/01/06 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services • Reel Trailer Service name .............LISTPE Date .....................06/01/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF C Writing Library. Scientific Technical Services End Of LIS File i Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jan 09 16:39:34 2006 Reel Header Service name .............LISTPE Date .....................06/01/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/01/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0003778283 B. HENNINGSE G. RIZEK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 8.500 3RD STRING PRODUCTION STRING ~~~ ~~ ~~g- Scientific Technical Services Scientific Technical Services 1E-170 PB1 500292326470 ConocoPhillips Alaska, Inc. Sperry Drilling Services 09-JAN-06 MWD RUN 4 MWD RUN 7 MW0003778283 MW0003778283 B. HENNINGSE B. HENNINGSE G. RIZEK F. HERBERT 21 11N l0E 247 641 111.05 70.40 CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 5054.0 9.625 10412.0 • REMARKS: • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 3, 4, & 7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE-WHILE-DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUN 7 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL STABILIZED LITHO-DENSITY (ASLD), AND ACOUSTIC CALIPER (ACAL). NO PROGRESS WAS MADE ON RUNS 5 & 6 DUE TO CASING LEAKS. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4,7 REPRESENT WELL 1E-170 PB1 WITH API#: 50-029-23264-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11230'MD/3551'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0 PPG MUD SALINITY: 44500 PPM CHLORIDES FORMATION WATER SALINITY: 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPX 5046.5 11184.5 RPS 5046.5 11184.5 RPM 5046.5 11184.5 RPD 5046.5 11184.5 FET 5046.5 11184.5 GR 5054.0 11192.0 ROP 5090.5 11230.0 NPHI 10329.5 11137.5 FCNT 10329.5 11137.5 NCNT 10329.5 11137.5 CALA 10332.0 11141.0 DRHO 10342.0 11151.5 RHOB 10342.0 11151.5 PEF 10400.0 11151.5 $ASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 5046.5 9108.0 MWD 4 9108.0 10420.0 MWD 7 10420.0 11230.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 • • FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 CALA MWD INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 11230 8138.25 12368 5046.5 11230 ROP MWD FT/H 0.64 2345.03 284.577 12280 5090.5 11230 GR MWD API 24.43 138.57 71.9605 12277 5054 11192 RPX MWD OHMM 2.1 1426.84 14.2693 12277 5046.5 11184.5 RPS MWD OHMM 3.43 2000 20.2188 12277 5046.5 11184.5 RPM MWD OHMM 3.58 1835.59 26.4731 12277 5046.5 11184.5 RPD MWD OHMM 3.65 2000 31.4339 12277 5046.5 11184.5 FET MWD HOUR 0.06 276.22 4.55486 12277 5046.5 11184.5 NPHI MWD PU-S 15.45 49.35 36.471 1617 10329.5 11137.5 FCNT MWD CNTS 655.05 2527.81 866.791 1617 10329.5 11137.5 NCNT MWD CNTS 111722 170960 124160 1617 10329.5 11137.5 RHOB MWD G/CM 0.565 2.856 2.17617 1620 10342 11151.5 DRHO MWD G/CM -3.676 0.148 -0.0970599 1620 10342 11151.5 PEF MWD BARN 1.56 12.77 2.53422 1504 10400 11151.5 GALA MWD INCH 8.49 9.29 8.78566 1619 10332 11141 First Reading For Entire File..........5046.5 Last Reading For Entire File...........11230 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 5046.5 9064.0 RPS 5046.5 9064.0 ~ i RPX 5046.5 9064.0 RPD 5046.5 9064.0 FET 5046.5 9064.0 GR 5054.0 9071.5 ROP 5090.5 9108.0 LO G HEADER DATA DATE LOGGED: 06-JUL-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9108.0 TOP LOG INTERVAL (FT) 5090.0 BOTTOM LOG INTERVAL (FT) 9108.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.2 MAXIMUM ANGLE: 82.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 59672 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 5054.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 50.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 7.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.380 93.2 MUD FILTRATE AT MT: 5.000 65.0 MUD CAKE AT MT: 2.300 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing........m............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • • DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 9108 7077.25 8124 5046.5 9108 ROP MWD030 FT/H 1.06 2345.03 329.886 8036 5090.5 9108 GR MWD030 API 24.43 138.57 65.8909 8036 5054 9071.5 RPX MWD030 OHMM 2.1 84.28 14.8458 8036 5046.5 9064 RPS MWD030 OHMM 4.74 2000 17.3313 8036 5046.5 9064 RPM MWD030 OHMM 5.09 1835.59 18.6538 8036 5046.5 9064 RPD MWD030 OHMM 5.01 2000 20.1687 8036 5046.5 9064 FET MWD030 HOUR 0.06 122.75 1.70767 8036 5046.5 9064 First Reading For Entire File..........5046.5 Last Reading For Entire File...........9108 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9064.5 10375.5 RPD 9064.5 10375.5 RPM 9064.5 10375.5 RPS 9064.5 10375.5 RPX 9064.5 10375.5 GR 9072.0 10383.5 ROP 9108.5 10420.0 i ~ LO G HEADER DATA DATE LOGGED: 13-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10420.0 TOP LOG INTERVAL (FT) 9108.0 BOTTOM LOG INTERVAL (FT) 10420.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.7 MAXIMUM ANGLE: 81.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 5054.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 65.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.500 67.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.490 116.6 MUD FILTRATE AT MT: 1.950 67.0 MUD CAKE AT MT: 1.980 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9064.5 10420 9742.25 2712 9064.5 10420 ROP MWD040 FT/H 0.64 483.99 201.852 2624 9108.5 10420 GR MWD040 API 36.81 119.21 82.6243 2624 9072 10383.5 RPX MWD040 OHMM 3.15 55.4 13.0643 2623 9064.5 10375.5 RPS MWD040 OHMM 3.85 102.95 17.9528 2623 9064.5 10375.5 RPM MWD040 OHMM 4.28 127.78 20.073 2623 9064.5 10375.5 RPD MWD040 OHMM 4.87 173.61 24.1989 2623 9064.5 10375.5 FET MWD040 HOUR 0.11 153.21 5.90547 2623 9064.5 10375.5 First Reading For Entire File..........9064.5 Last Reading For Entire File...........10420 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 10329.5 11137.5 FCNT 10329.5 11137.5 NCNT 10329.5 11137.5 GALA 10332.0 11141.0 RHOB 10342.0 11151.5 DRHO 10342.0 11151.5 RPM 10376.0 11184.5 RPS 10376.0 11184.5 RPD 10376.0 11184.5 FET 10376.0 11184.5 RPX 10376.0 11184.5 GR 10384.0 11192.0 PEF 10400.0 11151.5 ROP 10420.5 11230.0 • LO G HEADER DATA DATE LOGGED: 25-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11230.0 TOP LOG INTERVAL (FT) 10420.0 BOTTOM LOG INTERVAL (FT) 11230.0 BIT ROTATING SPEED (RPM}; HOLE INCLINATION (DEG MINIMUM ANGLE: 77.9 MAXIMUM ANGLE: 79.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 134758 CTN COMP THERMAL NEUTRON 181190 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 727424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 10412.0 BOREHOLE CONDITIONS MUD TYPE: Versa Pro MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 92.0 MUD PH: .0 MUD CHLORIDES (PPM): 44500 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 .. RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 NPHI MWD070 PU-S 4 1 68 32 9 FCNT MWD070 CNTS 4 1 68 36 10 NCNT MWD070 CNTS 4 1 68 40 11 RHOB MWD070 G/CM 4 1 68 44 12 DRHO MWD070 G/CM 4 1 68 48 13 PEF MWD070 BARN 4 1 68 52 14 GALA MWD070 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10329.5 11230 10779.8 1802 10329.5 11230 ROP MWD070 FT/H 1.01 898.53 193.815 1620 10420.5 11230 GR MWD070 API 39.56 112.39 84.8193 1617 10384 11192 RPX MWD070 OHMM 2.92 1426.84 13.3592 1618 10376 11184.5 RPS MWD070 OHMM 3.43 2000 38.233 1618 10376 11184.5 RPM MWD070 OHMM 3.58 1809.23 75.684 1618 10376 11184.5 RPD MWD070 OHMM 3.65 2000 99.1126 1618 10376 11184.5 FET MWD070 HOUR 0.16 276.22 16.5063 1618 10376 11184.5 NPHI MWD070 PU-S 15.45 49.35 36.471 1617 10329.5 11137.5 FCNT MWD070 CNTS 655.05 2527.81 866.791 1617 10329.5 11137.5 NCNT MWD070 CNTS 111722 170960 124160 1617 10329.5 11137.5 RHOB MWD070 G/CM 0.565 2.856 2.17617 1620 10342 11151.5 DRHO MWD070 G/CM -3.676 0.148 -0.0970599 1620 10342 11151.5 PEF MWD070 BARN 1.56 12.77 2.53422 1504 10400 11151.5 CALA MWD070 INCH 8.49 9.29 8.78566 1619 10332 11141 First Reading For Entire File..........10329.5 Last Reading For Entire File...........11230 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/01/09 Origin ...................STS Tape Name ................UNKNOWN Continuation hTumber......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/01/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Scientific Technical Services • Physical EOF Physical EOF End Of LIS File ti • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 10 08:17:04 2006 Reel Header Service name .............LISTPE Date .....................06/O1/10 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06(01/10 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0003778283 B. HENNINGSE G. RIZEK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 8.500 3RD STRING PRODUCTION STRING l~~ ~~`~ ` Scientific Technical Services Scientific Technical Services 1E-170 PB2 500292326471 ConocoPhillips Alaska, Inc. Sperry Drilling Services 10-JAN-06 MWD RUN 4 MWD RUN 8 MW0003778283 MW0003778283 B. HENNINGSE P. SMITH G. RIZEK G. RIZEK 21 11N l0E 247 641 111.05 70.40 CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 5054.0 9.625 10412.0 • REMARKS: • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. THIS WELLBORE WAS DRILLED OFF OF A CEMENT PLUG SPOTTED JUST ABOVE THE 9 5/8" CASING SHOE IN THE 1E-170 PB1 WELLBORE. 5. MWD RUNS 3, 4, & 8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE-WHILE-DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUN 7 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL STABILIZED LITHO-DENSITY (ASLD), AND ACOUSTIC CALIPER (ACAL). NO PROGRESS WAS MADE ON RUNS 5 & 6 DUE TO CASING LEAKS. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. HOWEVER, RUN 8 DATA WERE CORRECTED (SHIFTED) TO RUN 7 DATA. THIS CORRECTION RESULTED IN A 6' UPHOLE SHIFT OF RUN 8 DATA. HEADER DATA RETAIN DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4,8 REPRESENT WELL 1E-170 PB2 WITH API#~ 50-029-23264-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11887'MD/3484'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR°S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. • • PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0 - 9.2 PPG MUD SALINITY: 3000 - 44000 PPM CHLORIDES FORMATION WATER SALINITY: 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPX 5046.5 11841.0 RPS 5046.5 11841.0 RPM 5046.5 11841.0 RPD 5046.5 11841.0 FET 5046.5 11841.0 GR 5054.0 11848.0 ROP 5090.5 11881.0 DRHO 10395.0 11804.0 NPHI 10395.0 11790.5 FCNT 10395.0 11790.5 RHOB 10395.0 11804.0 PEF 10395.0 11804.0 CALA 10395.0 11792.5 NCNT 10395.0 11790.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 4 MWD 8 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 5046.5 9108.0 9108.0 10420.0 10420.0 11881.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record ....... ......Undefin ed Absent value ... ............. ......-999 Depth Units .... ............. ...... Datum Specifica tion Block su b-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 CALA MWD INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 11881 8463.75 13670 5046.5 11881 ROP MWD FT/H 0.64 2345.03 277.039 13582 5090.5 11881 GR MWD API 24.43 138.57 71.2554 13589 5054 11848 RPX MWD OHMM 2.1 1702.67 16.3602 13590 5046.5 11841 RPS MWD OHMM 3.85 2000 19.2884 13590 5046.5 11841 RPM MWD OHMM 3.83 1835.59 21.2958 13590 5046.5 11841 RPD MWD OHMM 4.26 2000 30.0259 13590 5046.5 11841 FET MWD HOUR 0.06 346.28 4.31273 13590 5046.5 11841 NPHI MWD PU-S 12.14 47.8 34.1342 2792 10395 11790.5 FCNT MWD CNTS 547.85 2501.56 769.071 2792 10395 11790.5 NCNT MWD CNTS 101643 166845 118120 2792 10395 11790.5 RHOB MWD G/CM 0.201 2.727 2.17198 2819 10395 11804 DRHO MWD G/CM -3.034 0.307 0.027486 2819 10395 11804 PEF MWD BARN 0.77 12.46 2.32359 2819 10395 11804 GALA MWD INCH 8.49 10.26 9.33826 1565 10395 11792.5 First Reading For Entire File..........5046.5 Last Reading For Entire File...........11881 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/Ol/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 • • Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 5046.5 9064.0 RPM 5046.5 9064.0 RPX 5046.5 9064.0 FET 5046.5 9064.0 RPS 5046.5 9064.0 GR 5054.0 9071.5 ROP 5090.5 9108.0 LOG HEADER DATA DATE LOGGED: 06-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9108.0 TOP LOG INTERVAL (FT) 5090.0 BOTTOM LOG INTERVAL (FT) 9108.0 BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 74.2 MAXIMUM ANGLE: 82.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 59672 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 5054.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S) 50.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 7.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.380 93.2 MUD FILTRATE AT MT: 5.000 65.0 MUD CAKE AT MT: 2.300 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION {IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPM MWD030 OHMM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 FET MWD030 HOUR 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 9108 7077.25 8124 5046.5 9108 ROP MWD030 FT/H 1.06 2345.03 329.886 8036 5090.5 9108 GR MWD030 API 24.43 138.57 65.8909 8036 5054 9071.5 RPX MWD030 OHMM 2.1 84.28 14.8458 8036 5046.5 9064 RPM MWD030 OHMM 5.09 1835.59 18.6538 8036 5046.5 9064 RPD MWD030 OHMM 5.01 2000 20.1687 8036 5046.5 9064 FET MWD030 HOUR 0.06 122.75 1.70767 8036 5046.5 9064 RPS MWD030 OHMM 4.74 2000 17.3313 8036 5046.5 9064 First Reading For Entire File..........5046.5 Last Reading For Entire File...........9108 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/Ol/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 • DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 9064.5 RPD 9064.5 RPM 9064.5 RPS 9064.5 RPX 9064.5 GR 9072.0 ROP 9108.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 13-JUL-05 Insite 66.37 Memory 10420.0 9108.0 10420.0 77.7 81.5 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVTTY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN STOP DEPTH 10375.5 10375.5 10375.5 10375.5 10375.5 10383.5 10420.0 12.250 5054.0 LSND 9.30 65.0 8.5 800 4.0 • 2.500 67.0 1.490 116.6 1.950 67.0 1.980 67.0 Max frames per record ....... ......Undefined Absent value ... ............. ......-999 Depth Units .... ............. ...... Datum Specifica tion Block su b-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9064.5 10420 9742.25 2712 9064.5 10420 ROP MWD040 FT/H 0.64 483.99 201.852 2624 9108.5 10420 GR MWD040 API 36.81 119.21 82.6243 2624 9072 10383.5 RPX MWD040 OHMM 3.15 55.4 13.0643 2623 9064.5 10375.5 RPS MWD040 OHMM 3.85 102.95 17.9528 2623 9064.5 10375.5 RPM MWD040 OHMM 4.28 127.78 20.073 2623 9064.5 10375.5 RPD MWD040 OHMM 4.87 173.61 24.1989 2623 9064.5 10375.5 FET MWD040 HOUR 0.11 153.21 5.90547 2623 9064.5 10375.5 First Reading For Entire File..........9064.5 Last Reading For Entire File...........10420 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10376.0 11841.0 RPS 10376.0 11841.0 RPD 10376.0 11841.0 r1 \,..J FET 10376.0 11841.0 RPX 10376.0 11841.0 GR 10384.0 11848.0 CALA 10395.0 11792.5 NPHI 10395.0 11790.5 FCNT 10395.0 11790.5 NCNT 10395.0 11790.5 RHOB 10395.0 11804.0 DRHO 10395.0 11804.0 PEF 10395.0 11804.0 ROP 10420.5 11881.0 LO G HEADER DATA DATE LOGGED: 28-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11887.0 TOP LOG INTERVAL (FT) 10420.0 BOTTOM LOG INTERVAL (FT) 11887.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.8 MAXIMUM ANGLE: 97.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 66259 CTN COMP THERMAL NEUTRON 181190 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 727424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 10412.0 • BOREHOLE CONDITIONS MUD TYPE: Versa Flo MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S): 99.0 MUD PH: .0 MUD CHLORIDES (PPM): 34500 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 120.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down • Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWDO80 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 NPHI MWD080 PU-S 4 1 68 32 9 FONT MWD080 CNTS 4 1 68 36 10 NCNT MWD080 CNTS 4 1 68 40 11 RHOB MWD080 G/CM 4 1 68 44 12 DRHO MWD080 G/CM 4 1 68 48 13 PEF MWD080 BARN 4 1 68 52 14 CALA MWD080 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10376 11881 11128.5 3011 10376 11881 ROP MWD080 FT/H 1.51 921.49 199.221 2922 10420.5 11881 GR MWD080 API 36.83 108.99 75.7882 2929 10384 11848 RPX MWD080 OHMM 5.7 1702.67 23.4615 2931 10376 11841 RPS MWD080 OHMM 5.67 1980.06 25.8495 2931 10376 11841 RPM MWD080 OHMM 3.83 1787.07 29.6336 2931 10376 11841 RPD MWD080 OHMM 4.26 2000 62.2661 2931 10376 11841 FET MWD080 HOUR 0.11 346.28 10.0297 2931 10376 11841 NPHI MWD080 PU-S 12.14 47.8 34.1342 2792 10395 11790.5 FCNT MWD080 CNTS 547.85 2501.56 769.071 2792 10395 11790.5 NCNT MWD080 CNTS 101643 166845 118120 2792 10395 11790.5 RHOB MWD080 G/CM 0.201 2.727 2.17198 2819 10395 11804 DRHO MWD080 G/CM -3.034 0.307 0.027486 2819 10395 11804 PEF MWD080 BARN 0.77 12.46 2.32359 2819 10395 11804 CALA MWD080 INCH 8.49 10.26 9.33826 1565 10395 11792.5 First Reading For Entire File..........10376 Last Reading For Entire File...........11881 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06jO1j10 Origin ...................STS Tape Name ................UNKNOWN ., Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................ST5 LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/O1/10 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF C Scientific Technical Services Scientific Technical Services End Of LIS File r } Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 10 09:00:38 2006 Reel Header Service name .............LISTPE Date .....................06/O1/10 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/O1/10 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF • l~~~U ao5~o~ ~----- Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1E-170 PB3 API NUMBER: 500292326472 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 10-JAN-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 8 JOB NUMBER: MW0003778283 MW0003778283 MW0003778283 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE P. SMITH OPERATOR WITNESS: G. RIZEK G. RIZEK G. RIZEK MWD RUN 10 JOB NUMBER: MW0003778283 LOGGING ENGINEER: P. SMITH OPERATOR WITNESS: G, RIZEK SURFACE LOCATION SECTION: 21 TOWNSHIP: 11N RANGE: l0E FNL: 247 FSL: FEL: 641 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 111.05 GROUND LEVEL: 70.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 5054.0 2ND STRING 8.500 9.625 10412.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. THIS WELLBORE WAS EFFECTED BY MEANS OF AN OPEN-HOLE SIDETRACK AT 11342'MD/ 3490'TVD, WITHIN THE RUN 8 INTERVAL OF THE 1E-170 PB2 WELLBORE. 5. MWD RUNS 3,4,8 & 10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR} UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE-WHILE-DRILLING (PWD) RUNS 3,4,10 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUNS 8 & 10 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL STABILIZED LITHO-DENSITY (ASLD), AND ACOUSTIC CALIPER (ACAL). NO PROGRESS WAS MADE ON RUNS 5 & 6 DUE TO CASING LEAKS; NO PROGRESS WAS MADE ON RUN 9 DUE TO A TOOL FAILURE. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. HOWEVER, RUN 8 DATA WERE CORRECTED (SHIFTED) TO RUN 7 DATA. THIS CORRECTION RESULTED IN A 6' UPHOLE SHIFT OF RUN 8 DATA. NO ADDITIONAL CORRECTION WAS NEEDED FOR THIS SIDETRACK. HEADER DATA RETAIN DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4,8,10 REPRESENT WELL 1E-170 PB3 WITH API#: 50-029-23264-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14397'MD/3367'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. • SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0 - 9.2 PPG MUD SALINITY: 3000 - 44000 PPM CHLORIDES FORMATION WATER SALINITY: 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPX 5046.5 14351.5 RPS 5046.5 14351.5 RPM 5046.5 14351.5 RPD 5046.5 14351.5 FET 5046.5 14351.5 GR 5054.0 14359.5 ROP 5090.5 14397.0 NCNT 10395.0 14305.5 CALA 10395.0 14308.0 FCNT 10395.0 14305.5 RHOB 10395.0 14318.5 DRHO 10395.0 14318.5 PEF 10395.0 14318.5 NPHI 10395.0 14305.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 5046.5 9108.0 4 9108.0 10420.0 8 10420.0 11342.0 10 11342.5 14397.0 • REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 GALA MWD INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 14397 9721.75 18702 5046.5 14397 ROP MWD FT/H 0.09 2345.03 237.611 18614 5090.5 14397 GR MWD API 24.43 138.57 70.9613 18612 5054 14359.5 RPX MWD OHMM 2.1 1702.67 18.49 18611 5046.5 14351.5 RPS MWD OHMM 3.85 2000 21.1135 18611 5046.5 14351.5 RPM MWD OHMM 3.83 1835.59 22.9661 18611 5046.5 14351.5 RPD MWD OHMM 4.26 2000 29.577 18611 5046.5 14351.5 FET MWD HOUR 0.06 346.28 3.50866 18611 5046.5 14351.5 NPHI MWD PU-S 8.17 47.8 34.9529 7822 10395 14305.5 FCNT MWD CNTS 570.36 3803.51 903.106 7822 10395 14305.5 NCNT MWD CNTS 101643 194682 128923 7822 10395 14305.5 RHOB MWD G/CM 0.201 2.746 2.20201 7848 10395 14318.5 DRHO MWD G/CM -3.034 0.307 0.0273043 7848 10395 14318.5 PEF MWD BARN 0.82 12.46 2.1702 7848 10395 14318.5 CALA MWD INCH 8.47 10.26 8.87903 7126 10395 14308 First Reading For Entire File..........5046.5 Last Reading For Entire File...........14397 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 • Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5046.5 9064.0 RPS 5046.5 9064.0 RPD 5046.5 9064.0 FET 5046.5 9064.0 RPM 5046.5 9064.0 GR 5054.0 9071.5 ROP 5090.5 9108.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 06-JUL-05 Insite 66.37 Memory 9108.0 5090.0 9108.0 74.2 82.7 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 59672 for each bit run in separate files. BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER°S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 12.250 5054.0 LSND 9.10 50.0 9.0 1000 4.5 7.500 65.0 5.380 93.2 5.000 65.0 2.300 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 9108 7077.25 8124 5046.5 9108 ROP MWD030 FTjH 1.06 2345.03 329.886 8036 5090.5 9108 GR MWD030 API 24.43 138.57 65.8909 8036 5054 9071.5 RPX MWD030 OHMM 2.1 84.28 14.8458 8036 5046.5 9064 RPS MWD030 OHMM 4.74 2000 17.3313 8036 5046.5 9064 RPM MWD030 OHMM 5.09 1835.59 18.6538 8036 5046.5 9064 RPD MWD030 OHMM 5.01 2000 20.1687 8036 5046.5 9064 FET MWD030 HOUR 0.06 122.75 1.70767 8036 5046.5 9064 First Reading For Entire File..........5046.5 Last Reading For Entire File...........9108 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06jO1j10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9064.5 10375.5 RPM 9064.5 10375.5 RPS 9064.5 10375.5 RPX 9064.5 10375,5 RPD 9064.5 10375.5 GR 9072.0 10383.5 ROP 9108.5 10420.0 LOG HEADER DATA DATE LOGGED: 13-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10420.0 TOP LOG INTERVAL (FT) 9108.0 BOTTOM LOG INTERVAL (FT) 10420.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.7 MAXIMUM ANGLE: 81.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 5054.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): LSND 9.30 65.0 8.5 800 4.0 2.500 67.0 1,490 116.6 1.950 67.0 1.980 67.0 ~ i REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9064.5 10420 9742.25 2712 9064.5 10420 ROP MWD040 FT/H 0.64 483.99 201.852 2624 9108.5 10420 GR MWD040 API 36.81 119.21 82.6243 2624 9072 10383.5 RPX MWD040 OHMM 3.15 55.4 13.0643 2623 9064.5 10375.5 RPS MWD040 OHMM 3.85 102.95 17.9528 2623 9064.5 10375.5 RPM MWD040 OHMM 4.28 127.78 20.073 2623 9064.5 10375.5 RPD MWD040 OHMM 4.87 173.61 24.1989 2623 9064.5 10375.5 FET MWD040 HOUR 0.11 153.21 5.90547 2623 9064.5 10375.5 First Reading For Entire File..........9064.5 Last Reading For Entire File...........10420 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/OL/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX 10376.0 RPS 10376.0 RPM 10376.0 RPD 10376.0 FET 10376.0 GR 10384.0 DRHO 10395.0 NPHI 10395.0 FCNT 10395.0 CALA 10395.0 RHOB 10395.0 PEF 10395.0 NCNT 10395.0 ROP 10420.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD ACAL STOP DEPTH 11342.0 11342.0 11342.0 11342.0 11342.0 11342.0 11342.0 11342.0 11342.0 11342.0 11342.0 11342.0 11342.0 11342.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuth. Litho-Den Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 28-JUL-05 Insite 66.37 Memory 11342.0 10420.0 11342.0 84.8 97.8 TOOL NUMBER 103770 66259 181190 10507541 727424 8.500 10412.0 Versa Flo 9.00 99.0 .0 34500 .0 .000 .0 .000 120.0 .000 .0 .000 .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 NPHI MWD080 PU-S 4 1 68 32 9 FCNT MWD080 CNTS 4 1 68 36 10 NCNT MWD080 CNTS 4 1 68 40 11 RHOB MWD080 G/CM 4 1 68 44 12 DRHO MWD080 G/CM 4 1 68 48 13 PEF MWD080 BARN 4 1 68 52 14 CALA MWD080 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10376 11342 10859 1933 10376 11342 ROP MWD080 FT/H 1.51 681.48 207.015 1844 10420.5 11342 GR MWD080 API 36.83 108.99 77.7795 1917 10384 11342 RPX MWD080 OHMM 5.7 1702.67 20.0173 1933 10376 11342 RPS MWD080 OHMM 5.67 1980.06 24.0165 1933 10376 11342 RPM MWD080 OHMM 3.83 1787.07 30.055 1933 10376 11342 RPD MWD080 OHMM 4.26 2000 79.805 1933 10376 11342 FET MWD080 HOUR 0.11 346.28 14.8962 1933 10376 11342 NPHI MWD080 PU-S 12.14 47.8 33.6859 1895 10395 11342 FCNT MWD080 CNTS 570.36 2501.56 775.959 1895 10395 11342 NCNT MWD080 CNTS 101643 166845 118078 1895 10395 11342 RHOB MWD080 G/CM 0.201 2.727 2.20377 1895 10395 11342 DRHO MWD080 G/CM -3.034 0.307 0.0144 1895 10395 11342 PEF MWD080 BARN 1.01 12.46 2.45808 1895 10395 11342 CALA MWD080 INCH 8.52 10.26 9.36111 1194 10395 11342 First Reading For Entire File..........10376 Last Reading For Entire File...........11342 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO _ ., Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11342.5 14359.5 CALA 11342.5 14308.0 ROP 11342.5 14397.0 RPX 11342.5 14351.5 RPS 11342.5 14351.5 RPM 11342.5 14351.5 RPD 11342.5 14351.5 FET 11342.5 14351.5 FCNT 11342.5 14305.5 NCNT 11342.5 14305.5 RHOB 11342.5 14318.5 DRHO 11342.5 14318.5 PEF 11342.5 14318.5 NPHI 11342.5 14305.5 LOG HEADER DATA DATE LOGGED: 03-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14397.0 TOP LOG INTERVAL (FT) 11342.0 BOTTOM LOG INTERVAL (FT): 14397.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.9 MAXIMUM ANGLE: 96.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 134758 CTN COMP THERMAL NEUTRON 179954 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 727424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER°S CASING DEPTH (FT) 10412.0 • BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Versa Pro NT 9.00 75.0 .0 50000 .0 000 .0 000 155.0 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HOUR 4 1 68 28 8 NPHI MWD100 PU-S 4 1 68 32 9 FCNT MWD100 CNTS 4 1 68 36 10 NCNT MWD100 CNTS 4 1 68 40 11 RHOB MWD100 G/CM 4 1 68 44 12 DRHO MWD100 G/CM 4 1 68 48 13 PEF MWD100 BARN 4 1 68 52 14 GALA MWD100 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11342.5 14397 12869.8 6110 11342.5 14397 ROP MWD100 FT/H 0.09 483.03 140.84 6110 11342.5 14397 GR MWD100 API 40.19 106.23 70.4759 6035 11342.5 14359.5 RPX MWD100 OHMM 4.68 833.61 25.2295 6019 11342.5 14351.5 RPS MWD100 OHMM 4.57 1159.46 26.6083 6019 11342.5 14351.5 RPM MWD100 OHMM 4.56 1553.29 27.7078 6019 11342.5 14351.5 RPD MWD100 OHMM 4.65 1852.47 28.3509 6019 11342.5 14351.5 FET MWD100 HOUR 0.2 74.92 1.21154 6019 11342.5 14351.5 NPHI MWD100 PU-S 8.17 46.3 35.3579 5927 11342.5 14305.5 FCNT MWD100 CNTS 660 3803.51 943.757 5927 11342.5 14305.5 NCNT MWD100 CNTS 113765 194682 132390 5927 11342.5 14305.5 RHOB MWD100 G/CM 2.049 2.746 2.20145 DRHO MWD100 G/CM -0.102 0.207 0.0314121 PEF MWD100 BARN 0.82 5.8 2.07855 CALA MWD100 INCH 8.47 9.89 8.78199 First Reading For Entire File.... ......11342.5 Last Reading For Entire File..... ......14397 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation......,06/01/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/O1/10 Origin ...................STS Tape Name ................LTNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/O1/10 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF 5953 1342.5 14318.5 5953 11342.5 14318.5 5953 11342.5 14318.5 5932 11342.5 14308 Scientific Technical Services Scientific Technical Services End Of LIS File
