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206-171
Image Projeet Weil 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, mayf be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ ~ ~ Well History File Identifier Qrganizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: ,,~.,ed iiiumuuiiiuu DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Date: L'Jj' ~~ Re,~~~e~~ iuumi~iuiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Loys of various kinds: ^ Other:: /s/ _._ _ __-~ - ~-- -J i Project Proofing III IIII~I VIII II III BY: Maria Date: ~ 1 ~ ~ /s/ Scanning Preparation ~ x 30 = + =TOTAL PAGES~~ ( ount does not include cover sheet) BY: Maria Date: ~, f Q ~ ~ lsl Production Scanning III 11111111111 Stage 7 Page Count from Scanned File: ~ (Count does include cover eet) Page Count Matches Number in Scanning Phreparation: YES NO BY: Maria Date: ~ ~ ~ I ~ /s/ F Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO fl BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II I I III Rescanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III (I'lII III II'I III 10!6/2005 Well History File Cover Page.doc ' STATE OF ALASKA A OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ("" Repair w ell I✓ Aug Perforations I Perforate E Other If Alter Casing j°' Pull Tubing IW Stimulate - Frac i` Waiver r Time Extension r Change Approved Program (""Operat. Shutdow n 1 — Stimulate - Other E Re -enter Suspended Well I- 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ■ ConocoPhillips Alaska, Inc. Development 1,7 Exploratory E _ 206 -171 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ( Service ( • 50 - 029 - 21360 - 60' r Og 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025653 . 2.5 C25 Lk • 2Z - 13AL1 9. Logs (List logs and submit electronic d printed data per . 071): • 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9350 feet Plugs (measured) none true vertical 6058 feet Junk (measured) none Effective Depth measured 9090 feet Packer (measured) 7849, 8151 true vertical 6052 feet (true vertical) 5789, 6010 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 80 80 SURFACE 4167 9.625 4203 3360 RECEIVED PRODUCTION 8118 7 8151 6010 LINER AL1 POST 1209 2.375 9090 6052 FEB 0,3 AOGCC Perforation depth: Measured depth: 7917 -8085, 8306 -9095 SCANNED JUL. ��� True Vertical Depth: 5839 -5963, 6104 -6052 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7828 MD, 5772 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL RETRIEVABLE PACKER @ 7849 MD and 5789 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 8151 MD and 6010 TVD SSSV - CAMCO DS NIPPLE @ 505 MD and 505 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development I✓ r Service r Stratigraphic 16. Well Status after work: . Oil Gas f WDSPL i Daily Report of Well Operations _ XXX GSTOR E WINJ E WAG I GINJ r SUSP I°" SPLUG E 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 Brett Packer to 265 -6845 Email J. Brett .Packer @conocophillips.com Printed Name J. ` Packer i % � � Title Wells Engineer 7/s 3 Signature A Phone: 265 -6845 Date RBDMS FEB 0 6 20130k Form 10 -404 Revised 12/2012 1 F , ..1 , �'/ Submit Original Only 7/3//3 2Z -13A and 2Z -13AL1 PRE -RIG WELL WORK DATE SUMMARY 10/6/12 (PRE -RWO) MITOA- PAD; T POT- PASSED; T PPPOT- PASSED; POT - (HAS SEALTITE) IC PPPOT- RE- ENERGIZED WITH HYDR. FLUID. 11/28/12 SET 2.79" CATCHER SUB ON 2 3/8" LINER @ 7920' RKB. MEASURE BHP @ 7901 RKB (2999 PSI) & 7763' RKB (2965 PSI), IN PROGRESS. 11/29/12 STOOD BY FOR SCAFFOLD TO BE BUILT. SET 1.5 CV ON RM LATCH @ 7888' RKB. PULLED 1" OV @ 7474' RKB, IN PROGRESS 11/30/12 PULLED 1" GLV'S @ 6735', 5702', 4132', & 2010' RKB. IN PROGRESS. 12/1/12 SET 1" DV'S @ 2010', 4132', 5702' & 6735' RKB. DHD SHOT FLUID LEVEL IN IA © —786' , IN PROGRESS. (NOTE: HAD TO SET A BTM LATCH IN STN# 2 @ 4132' RKB, BK WOULD NOT LATCH IN PROFILE) 12/2/12 PULL CATCHER FROM 7920' RKB. SET 2.68" SPECIAL CLEARANCE WRP @ 7870' RKB. CMIT T X IA TO 3000 PSI PASSED, IN PROGRESS. 12/3/12 PULLED 2.68" WRP @ 7870' RKB. ATTEMPT TO DRIFT 2 3/8" LINER W/ 1.85 ", UNABLE TO GET INSIDE LINER TOP. RAN 2.5" LIB, SHOWS A JAGGED CUT (SEE PICTURE IN ATTACHMENTS), IN PROGRESS. 12/4/12 ATTEMPT TO DRIFT LINER FOR UPCOMING JET CUT WITH 1.81" CENT & 1.50" S. BAILER, UNABLE TO WORK PAST 7905FT SLM (31 FT INTO LINER), RDMO 12/7/12 DRIFTED INSIDE 2 -3/8" LINER TO 8180' SLM, EST. 8183' RKB WITH 1.75" x 5' BAILER. TIGHT @ 8146' SLM, —8149' RKB. ABLE TO DRIFT THROUGH TIGHT SPOT @ 140 TO 150 FPM. READY FOR E /L. 12/21/12 CUT 2 3/8" LINER WITH JET CUTTER AT A DEPTH OF 8155'. ((( NORDIC 3 RIG JOB ))) SET 2.78" WRP ON DPU @ 75' SLM. PULLED 2.78 "WRP @ 75' SLM POST -RIG WELL WORK 1/10/13 PULLED BALL & ROD @ 7777' RKB. PULLED & REPLACED DV @ 7722' RKB. PULLED SOV @ 3031' RKB & REPLACED WITH DV. PULLED RHC PLUG BODY @ 7777' RKB. SET CAT SV @ SAME. MIT TBG 2500 PSI ( PASS) PULLED CAT SV. RAN SHIFTING TOOL AND CONFIRMED CMU @ 7777' RKB IS CLOSED, UNABLE TO DRIFT PAST 8124' RKB. DRIFTED TBG WITH 5' x 2" BAILER TO LINER TOP @ 8144' RKB. IN PROGRESS. 1/11/13 MEASURED BHP @ 7953' RKB ( 3056 psi) . DISPLACED TBG WITH 80 BBLS DSL ( 1BBL PER MIN. @ 2300 PSI) . READY FOR E /L. • • Conoct hillips Time Log & Summary Wellview Web Reporting Report Well Name: 2Z - 13 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/29/2012 3:00:00 AM Rig Release: 1/5/2013 4:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/28/2012 24 hr Summary Nordic Rig 3 move from 3S -pad to 1Y turn off towards 2Z -13 04:00 19:00 15.00 MIRU MOVE MOB P Move Nordic Rig 3 from 3S pad to CPF -3, Check tires and equipment while waiting on field change out. 19:00 00:00 5.00 MIRU MOVE MOB P Move Nordic Rig 3 from CPF -3 to Y turn off heading for 2Z pad. 12/29/2012 Nordic Rig 3 move from 1Y turn off to 2Z -13. Prepare location for MIRU. Pull rig over well, Spot support equipment and RU hardline. Pull BPV. Circulate 10.3 ppg brine KWF. 00:00 01:00 1.00 MIRU MOVE MOB P Move Nordic Rig 3 from 1Y turn off traveling towards 2Z pad. 01:00 02:00 1.00 MIRU MOVE MOB P PJSM. Roll up tarps and pull over well. DTH on site and building containment for kill tank. 02:00 05:30 3.50 MIRU MOVE MOB P Spot, level and shim rig, spot cuttings box. 05:30 12:00 6.50 MIRU MOVE MOB P Accepted Nordic Rig 3 at 03:00 hrs on 12 -29 -2012. Berm up Cellar. Warm up Rig. Spot support equipment. Load pits with 10.3 ppg brine. Spot kill tank and rig Up Hard line. RU cellar hoses and fill lines to test. Load BPV lubricator. 12:00 14:30 2.50 MIRU WHDBO P PJSM -RU BPV lubicator. Pull BPV. 940 psi on tbg. Bleed gas off IA to • kill tank 980 psi.. Check tbg , fluid packed. 14:30 18:00 3.50 MIRU WELCTL CIRC P Begin killing the well. Pump 10.3 brine down tbg taking returns up IA to kill tank. Pumping at 4 bpm 200 psi pump pressure. 400 psi on ia. 130 bbls away, still no fluid on ia. Slow rate down to 2 BPM open choke more, still no fluid to surface, @ 170 away, bump back up to 5 BPM. Started getting fluid to surface but still have gas coming back. 18:00 21:00 3.00 MIRU WELCTLOWFF P Shutdown, BDHL, Bleed OA pressure down to 400 psi, 386 bbls pumped, 325 bbls return, Tbg= 70 psi, IA =230 psi, 8.85 ppg water /crude to surface on IA. Empty kill tank. Bring on 290 bbls 10.3 ppg brine to pits. confer with town engineer. Page 1 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:30 1.50 MIRU WELCTL CIRC P Tbg= 210 psi, IA= 270 psi. circulate 100 bbls 4 bpm, ICP 600 psi, 300 psi choke pressure, 95% returns, FCP 590 psi. Bullhead 10 bbls into formation 1 bpm at 1150 psi, resume circulating 4 bpm, ICP 590 psi, 280 psi choke pressure, 180 bbls pumped FCP 460 psi, 160 psi choke pressure, 280 bbls pumped with 280 bbls returned. 22:30 00:00 1.50 MIRU WELCTL OWFF P Tbg /IA = 10 psi, monitor well. BDHL. Empty kill tank. Tbg= 40 psi, IA= 50 psi , Calculate and order up new KWF 10.9 ppg brine. Start load, rack and tally of 3.5" DP while waiting on KWF. 12/30/2012 Monitor well while waiting on new KWF. Circulate 10.9 ppg new KWF. Set BPV. ND Tree. Install blanking plug. NU BOPE. Unable to get shell test. Pull blanking plug and BPV. MIRU Slickline. 00:00 05:30 5.50 MIRU WELCTL OWFF T Continue to wait on new KWF from Prudhoe, call from dispatch at 00:50 truck with KWF stuck behind Doyon rig with problems on Spine road. Continue to load, rack and tally DP, DC's, load Baker equipment. 05:30 08:00 2.50 MIRU WELCTL OWFF T Still waiting on fluid. There is a hang up on the main spine road. 08:00 10:30 2.50 MIRU WELCTL CIRC P PJSM- Going to pump directly off truck. 11.0 heavy brine. Starting pressures T /IA/OA 20/50/300 Pump 10.3 vis pill 20 bbls. Pump at 3 BPM taking returns to the kill tank, some gas and dirty returns. After 20 bbls pill, swap to 11.0 heavy brine, taking returns to the pits. Circulate 290 bbls fully unload the truck. 10:30 11:30 1.00 MIRU WELCTL OWFF P Getting 10.7 brine in returns. shut down pump. well dead, observe well for flow. T /IA/OA= 0/0/350 watch for 45 minutes, good. 11:30 13:00 1.50 MIRU WHDBO NUND P FMC hand on location. PJSM- Set BPV with T -bar. RD hoses in cellar 13:00 16:00 3.00 MIRU WHDBO NUND P PJSM for nipple down. Nipple down tree. Threads on tubing hanger in bad shape, decide to install blanking plug, order up spear for pulling tubing hanger to floor as per FMC rep. 16:00 19:30 3.50 MIRU WHDBO NUND P NU BOPE, test equipment, fill with water. 19:30 22:00 2.50 MIRU WHDBO BOPE T Attempt shell test against blanking plug, eliminate BOP breaks and choke, surge pressure to get blanking plug to hold, no joy, call out for WRP. 22:00 22:30 0.50 MIRU WHDBO BOPE X PJSM- Pull blanking plug and BPV, both in good shape. Page 2 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:30 1.00 MIRU WHDBO BOPE X MU landing joint carefully with pump -in -sub, FOSV and Slick line quick union. 23:30 00:00 0.50 MIRU WHDBO SLKL X Slickline on site, spot equipment and PJSM- hazards associated with rigging up slickline. 12/31/2012 RU Slickline. Set WRP. Stand back Slickline. Test WRP 3000 psi. Funtion and test BOPE 250/3000 psi. RU Slickline. Pull WRD. RD Slickline. Spear tubing hanger and pull to floor. Circulate well clean. Pull 3 -1/2" completion. 00:00 02:00 2.00 MIRU WHDBO SLKL X Continue to RU Slickline. P/T equipment 500 psi. 02:00 03:30 1.50 MIRU WHDBO SLKL X TIH with Weatherford 2.74" OD WRP on Halliburton DPU, set WRP in middle of 2nd full joint down at 78 -ft, POOH and stand back Slickline equipment. 03:30 04:30 1.00 MIRU WHDBO PRTS X RD landing joint and close in blind rams, shell test against WRP 3000 psi. 04:30 10:00 5.50 MIRU WHDBO BOPE P Perform Initial BOP ram, choke manifold and annular test 250/3000 psi with 3 -1/2" test joint. Perform Accumulator draw down test. 10:00 11:30 1.50 MIRU WHDBO BOPE P BOPE test complete. Rig down testing equip. Install landing joint for slickline W/ TIW valve. 11:30 14:30 3.00 MIRU WHDBO SLKL P PJSM -RU up slickline. RIH to 75', pull WRP -POOH. All elements are there. RD slickline. 14:30 17:30 3.00 7,840 7,830 COMPZ RPCOM THGR P PJSM -MU Joints to plant baker spear w/ seal cup. Hook up to top drive. BOLDS. Pull up, 120k, 135k,145k. Still not coming free. Kick on the pump, 4 BPM, work pipe up & down. Pull up to 150k pump still going, came free. Pull up, drag for 15' then pulled smoother. RIH smoothly. Get below bag, circulate a bottoms up prior to pulling hanger to the floor. BDTD. Pull hanger to floor and remove, PU and cut control) line 2 joints down and tie off, position tubing across bag and close. 17:30 18:30 1.00 7,830 7,830 COMPZ RPCOM CIRC P Reverse circulate 2 tubing volumes 6 bpm at 760 psi until) clean. 18:30 19:00 0.50 7,830 7,830 COMPZ RPCOM OWFF P Monitor well for flow, well on slight vac. 19:00 23:00 4.00 7,830 6,010 COMPZ RPCOM PULL P PJSM- tripping pipe. TOOH laying down 3 1/2" EUE tubing from 7,830 -ft, UP wt 95k, spooling control) line recovering 31 SS flat bands to 6,010 -ft, lay down SSSV. 23:00 23:30 0.50 6,010 6,010 COMPZ RPCOM OTHR P PJSM- NORM control line, good, offload spool and spooler. Page 3 of 8 • Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 6,010 5,820 COMPZ RPCOM PULL P Continue to TOOH with 3 1/2" EUE tubing from 6,010 -ft, strapping and off loading as needed to 5,820 -ft, UP wt 75k. 01/01/2013 Continue to pull 3 -1/2" completion. MU and TIH with 2 3/8" liner fishing BHA to 7,825 -ft. 00:00 09:00 9.00 5,820 0 COMPZ RPCOM PULL P Continue to POOH with 3 1/2" EUE tubing from 5,820 -ft, tally and off load as needed, UP wt 75k. 09:00 11:00 2.00 0 0 COMPZ RPCOM OTHR P Clean and clear work area along pipe shed. 11:00 11:15 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM with Rig crew and Baker fishing hand. 11:15 12:00 0.75 0 0 COMPZ WELLPF OTHR P Change over TBG equipment 12:00 15:00. 3.00 0 341 COMPZ WELLPF PULD P PU and MU Itco spear w/ 1.992" Grapple BHA #2 to 341 -ft 15:00 23:00 8.00 341 7,825 COMPZ WELLPF PULD P TIH with BHA #2 on 3 1/2" DP to 7,825 -ft, Up wt 140k, Dn wt 95k. 23:00 00:00 1.00 7,825 7,825 COMPZ WELLPF CIRC P PJSM- Circulating. Establish slow pump rates and circulate 1 DP volume. P1= 20 spm at 350 psi, 40 spm at 1100 psi P2= 20 spm at 360 psi, 40 spm at 1130 psi 01/02/2013 Wash down and engage top of liner fish at 7,906 -ft. Circulate well clean. TOOH with BHA #2 and 237.62 -ft of 2 -3/8" liner, top of cut liner at 8,144 -ft. TIH with clean out BHA to PBR. Reverse circulate well clean. TOOH with BHA #3 laying down DP. 00:00 01:00 1.00 7,825 7,911 COMPZ WELLPF FISH P Wash down from 7,825 -ft, 2 bpm at 110 psi, get Up wt at 7,883 -ft of 143k, SO 3k at 7,911 -ft, PU with 4 -5k drag, TIH SO 4k at 7,911 -ft corrected, no change in pump pressure. 01:00 02:00 1.00 8,144 7,792 COMPZ WELLPF FISH P PUH slowly standing back 2 jts and 3 stands DP, 3 -4k overpull to 7,792 -ft, Up wt 140k. 02:00 04:00 2.00 7,792 7,792 COMPZ WELLPF CIRC P Drop 1 -7/8" dart, pressure up to 2200 psi, pump- out -sub open, pump 20 bbl high -vis sweep 2 bpm at 200 psi, circulate around STS, 8 bpm, ICP 2000 psi until well clean, FCP 2000 psi. 04:00 04:30 0.50 7,792 7,728 COMPZ WELLPF OWFF P Lay down 2 joints, Up wt 145k, monitor well, 04:30 08:30 4.00 7,728 574 COMPZ WELLPF TRIP P PJSM- TOOH with BHA #2 standing back DP from 7,728 -ft, Up wt 138k, to BHA #2. 08:30 09:30 1.00 574 238 COMPZ WELLPF PULL P POOH to spear and 2 3/8 TBG fish. 09:30 10:00 0.50 238 0 COMPZ WELLPF PULL P POOH laying down 237.63 -ft of 2 3/8 liner. Top of fish at 7,906 -ft corrected to ORKB, bottom of fish at 8,144 -ft corrected to ORKB. Page 4 of 8 1 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:45 0.75 0 0 COMPZ WELLPF OTHR P Change over to DP equipment, Clean and Clear work area and pipe shed. 10:45 11:00 0.25 0 0 COMPZ WELLPFSFTY P Held PJSM on PU and MU of BHA #3 with rig crew and Baker Fishing hand. 11:00 12:00 1.00 0 238 COMPZ WELLPF PULD P PU and MU BHA #3 (CSG Scraper) to 238 -ft 12:00 15:00 3.00 238 7,823 COMPZ WELLPF TRIP P RIH w/ BHA #3 from 238 -ft to 7,819 -ft -tag up - locate Top of PBR @ 7,822.5 -ft RKB Corrected depth 15:00 17:30 2.50 7,823 7,819 COMPZ WELLPF CIRC P Reverse circulate 104 bbls @ 4 bpm @ 800 psi. Wash down and No go in bottom of PBR @ 7,835.5 -ft RKB Corrected depth. Spot 35 bbl hi visc sweep at PBR - Pull out of PBR to 7,819 -ft and Reverse circulate @ 4 bpm @ 1,050 psi. - 43 bbl loss to Perfs during circulating. 17:30 18:00 0.50 7,819 7,819 COMPZ WELLPF OWFF P Monitor well for flow - No flow - Static 18:00 18:45 0.75 7,819 7,819 COMPZ WELLPF SFTY P PJSM- laying down DP. Crew change out, check alarms. 18:45 00:00 5.25 7,819 3,915 COMPZ WELLPF TRIP P TOOH laying down DP off loading as needed to 3,915 -ft. 31/03/2013 Continue to TOOH with BHA #3 laying down DP to 722 -ft. MU -RIH and set storm packer, BHA #3 below. test S.P. ND BOPE. ND tbg spool. ND csg spool. Casing grew total of 17 ". Spear and set 7" csg in emergency slips. Change out IC pack -off. Cut off excess 7" csg. NU New tbg spool test pack -offs. Shell Test BOPE. Retrieve BHA #4, continue to lay down DP and BHA #3. Prep to run 3 1/2" EUE gas lift completion. 00:00 02:30 2.50 3,915 733 COMPZ WELLPF TRIP P Continue to TOOH from 3,915 -ft laying down DP off loading qas needed to 835 -ft, stand back 1 stand. 02:30 03:30 1.00 733 803 COMPZ WHDBO MPSP P PJSM- PU MU 7" Model "EA" Retrievamatic storm packer to top of 15 jts of 3 -1/2 ", 13.3# DP and BHA #3. TIH with Top of Storm Packer set at 70 -ft. Stand back 1 stand SP, lay down running tool. 03:30 04:00 0.50 803 803 COMPZ WHDBO PRTS P Pressure test storm packer to 3,000 psi, good, no flow test, good. 04:00 04:15 0.25 803 803 COMPZ WHDBO SFTY P PJSM- discuss hazards associated with ND BOPE, casing head and casing growth. Continue to load, drift and tally 3 -1/2" completion. Page 5 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode _ T Comment 04:15 11:00 6.75 803 803 COMPZ WHDBO NUND P Make breaks at BOPE and tubing head, lossen casing head, csg growing. Stand BOPE back on stump, ND tubing head. RU Hydratight system, Starting pressure was 8,000 psi and ending pressure was 1,600 psi - overall growth was 5 -1/4" Flange to Flange - 11 -1/4" . When lock downs were backed out 7" casing grew another 8" - engage spear and pull 55k over block wt - pack off never moved. Land 7" casing in 50k tension in slips with 4 -1/2" gain for a total of 17.75 ". Break down spear assy. 11:00 16:00 5.00 803 803 COMPZ WHDBO OTHR P Pull old FMC pack off, RU Wach's cutter and cut 16" off 7" casing stub. Install New FMC Gen II/ Gen IV inner casing pack off and NU FMC Gen IV 11" 3M x 7- 1/16" 5M. PT pack off @ 250 / 3,000 psi for 15 minutes - good test. 16:00 18:00 2.00 803 803 COMPZ WHDBO NUND P NU 11" 5M Class III BOPE stack install riser and RU choke and kill line. 18:00 19:00 1.00 803 803 COMPZ WHDBO OTHR Continue to load, drift and tally 3 -1/2" EUE gas lift completion, set wear bushing. 19:00 19:30 0.50 803 803 COMPZ WHDBO BOPE P PJSM- Close blind rams and conduct shell test at 250 / 3,000 psi against Baker Storm packer - good test. 19:30 21:30 2.00 803 0 COMPZ WHDBO PULD P PJSM- TIH with running tool and retrieve Model 'RA' retrievamatic BHA #4/3 from 71 -ft, TOOH lay down storm packer, conting TOOH laying down DP, DC's and BHA #3 used for storm packer BHA. 21:30 00:00 2.50 0 0 COMPZ RPCOM OTHR P PJSM- off load Baker tools, DC's and DP from rig. Clean cellar and floors. Change over floor equipment. Pull wear bushing. Prep to run 3 1/2" EUE gas lift complaetion, confirm running order. 31/04/2013 Run 3 -1/2" EUE gas lift completion. Unable to get IA to pressure up. RU Slickline, pull failed SOV, set DV in GLM #5, test IA to 500 psi. Pull DV, set SOV in GLM #1. RD Slickline. Sace out. load well with corrosion inhibited 10.9 ppg brine. Land completion. Attempt to test tbg. 00:00 05:30 5.50 0 7,768 COMPZ RPCOM RCST P PJSM- PU locator / seal ass'y and TIH with 3 -1/2" EUE gas lift completion as per run order. Up wt 95k, Dn wt 75k. Page 6 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 08:00 2.50 7,768 7,828 COMPZ RPCOM HOSO T PU joints #249, #250 and #251, no -go out with locator at 7828.15 -ft corrected to ORKB. Attempt to Verify seals in place by pressuring up IA to 300 psi - failed - returning up TBG string. Pump down TBG string w/ no returns up IA. Failed SOV. RU for slickline. 08:00 10:30 2.50 7,828 7,828 COMPZ RPCOM OTHR T Call out slick line - spot equipment. 10:30 13:00 2.50 7,828 7,828 COMPZ RPCOM RURD T PJSM - RU slick line - (Stop the job - 4 part shackle failure, nut fell off while picking up lubricator - result dropped object) - double checked all hook up. Finish up RU. 13:00 19:30 6.50 7,828 7,828 COMPZ RPCOM SLKL T RIH and recovered SOV - found to be sheared. RIH w/ DV, failed to set, POOH found small piece of metal in KO arm - caused damage to KO tool. - change out and back in hole w/ DV. PT IA to 500 psi - good test, PT TBG to 500 psi - good test - no communication to IA. POOH and change tools - RIH to GLM #1 and pull DV - failed sheard JD OS, RIH to GLM #1 and pull DV. POOH, dress tools. and Change tools - RIH w/ SOV and set in GLM #1- PT TBG to 500 psi - good test - POOH and RD Slick line. 19:30 21:00 1.50 7,828 7,795 COMPZ RPCOM THGR P PJSM- Pull out of PBR, MU full joint in completion for space out, tubing hanger and landing joint. MU head pin and circulating hoses. 21:00 22:15 1.25 7,795 7,795 COMPZ RPCOM CIRC P Reverse circulate 200 bbls 10.9 ppg corrosion inhibited brine, chase with 45 bbls 10.9 ppg KWF, 3 bpm at 360 psi ICP, 400 psi FCP. monitor well. Drain BOP stack 22:15 22:45 0.50 7,795 7,828 COMPZ RPCOM THGR P Land tubing hanger, RILDS. RD head pin and circulating hoses. 22:45 23:15 0.50 7,828 7,828 COMPZ RPCOM OTHR P Drop Ball & Rod (6' -10" OAL, 1 3/8" fishneck, 1 5/16" OD) RU head pin and circulating hoses. 23:15 00:00 0.75 7,828 7,828 COMPZ RPCOM PRTS P PJSM- Pressure test tubing to 3,000 psi, monitor with casing valve open, pressure started to level out then fell off, Bump up to 3100 psi, leak of same, bleed pressure to 0 psi. 01/05/2013 Continue to Test tbg, RHC plug teaks. Test IA 3,500 psi. Shear SOV. Set BPV and test. ND BOPE. NU tree. Pull BPV, Set TWCV. Test tree and hanger void. Pull TWCV. Freeze protect. Set BPV. RDMO. Page 7 of 8 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 7,828 7,828 COMPZ RPCOM PRTS P Pressure test tubing to 3,000 psi, monitor with casing valve open, same slow leak off 500 psi in 15 minutes with no visible fluids coming from open IA vale, confer with town engineer, bleed tubing to 2,000 psi, Pressure test IA to 3,550 psi, tubing 2600 psi, on chart 15 minutes IA/T= 3450/2250 psi, 30 minutes IA/T= 3425/1900 psi, MIT -IA passed, bleed tubing down to shear SOV, SOV sheared 1500 psi, bleed tubing and casing to 0 psi. 01:00 01:30 0.50 7,828 7,828 COMPZ RPCOM OWFF P Monitor well for flow, static. 01:30 02:00 0.50 7,828 7,828 COMPZ WHDBO MPSP P PJSM- RD landing joint. Install 3 1/2" IS -A BPV. Pressure up under BPV down IA to 1250 psi, good 10 minutes. Barriers in place 02:00 05:30 3.50 COMPZ WHDBO NUND P ND BOPE, NU tree, DSO witness to verify tree orientation. 05:30 06:00 0.50 COMPZ WHDBO MPSP P Pull BPV and set TWCV. 06:00 06:30 0.50 COMPZ WHDBO PRTS P Pressure test tree and tubing hanger voids 250/5000 psi. 06:30 07:00 0.50 COMPZ WHDBO MPSP P Pull TWC 07:00 10:00 3.00 COMPZ WHDBO FRZP P Held PJSM, Spot and RU Little Red Services. PT lines @ 2,000 psi, FP well w/ 80 bbls @ 2 bpm @ 650 psi. RD LRS. Allow well to swap - stablized @ 320 psi. 10:00 14:30 4.50 COMPZ WHDBO MPSP P Lubricate in BPV and secure well. Clean and dress well head. SI pressures 320/320/0. 3" HBPV failed while running - retrieve and install a different one. RD Lubricator. 14:30 16:00 1.50 COMPZ MOVE DMOB P Raise tarps, Jack up rig, and pull off well. Clean cellar with super sucker and Release Nordic 3 @ 16:00 hrs. Page 8 of 8 Kip • 2Z -13AL1 Canocurhillips API/MI Attributes Max Angle & MD TD Alaska. Wellbore API /I Field Name Well Status Incl (°) MD (ftKB) Act Btm (ftKB) � l,to, ■d1 el p, 500292136060 KUPARUK RIVER UNIT PROD 106.03 8,483.66 9,350.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: LOCKED OUT 130 10/11/2007 Last WO: 1/5/2013 42.10 7/7/1985 Well Con10. - 2Z- 13ALI, 1/1672013 1:62:16 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,920.0 9/13/2009 Rev Reason: WORKOVER osborl 1/16/2013 < Casing Strings HANGER 31 - Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER AL1 Post 23/8 1.992 8,155.0 9,107.0 6,052.3 4.40 L -80 STL 2012 Cut Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top(ftKB) Btm(MKS) (ftKB) (ftKB) Zone Date (oh... Type Comment CONDUCTOR, 7,917.4 8,085.0 5,839.0 5,962.9 C-4, C-1, 2/6/2007 32.0 SLOTS Alternating solid/slotted pipe 36 -80 2Z -13AL1 Ill 8,306.0 9,095.3 6,104.2 6,052.0 C-4, C -1, 2/6/2007 32.0 SLOTS Alternating solid/slotted pipe NIPPLE, 505 -- 2Z -13AL1 Ill Notes: General & Safety 111111 End Date Annotation 2 /8!1985 NOTE: GLMs #9 8 #11 blocked by solid pipe portion of Sidetrack Lateral AL1 2/8/2007 NOTE: MULTILATERAL SIDETRACK, 2Z -13A, 2Z -13AL1 (AL1 off main wellbore) GAS LIFT, r_..._ -. 3,031 : 3/18/2008 NOTE: CUT 8 PULLED TOP 41' OF 2Z -134L1 LINER r 9/13/2009 NOTE: WAIVERED WELL T x IA x OA COMMUNICATION 12/21/2012 NOTE: TOP 298' AL1 LINER TOP PULLED FOR 2012 WORKOVER SURFACE, A L. 35 -4.203 i GAS LIFT, 4,801 t GAS LIFT 6114 r GAS LFT.. 7,0 GAS LIFT, 7.722 SLEEVE. 7,777 — { I SEAL ASSY, 7,826 TUBING PUP, 7.828 PM, 7,836 PACKER, 7,849 I PRODUCTION, 7,888 IF PRODUCTION, 7,961 SLOTS, 7,917-8,085 lit I PRODUCTION, 8,131 LOCATOR, 8,150 ...w PACKER, 8,151 ... _ Mandrel Details Top Depth Top Port WHIPSTOCK (TVD) not OD Valve Latch Size TRO Run WINDOW AL Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type PM (PO Run Date Com. -. 8,161 -8,168 1 3,030.9 2,561.1 47.55 Cameo MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 1/4/2013 2 4 ,801.0 3,745.6 51.71 Cameo MMG 1 112 GAS LIFT DMY . RK 0. 0.0 1/4/2013 PUNCH, 8,182.8,192 3 6,114.4 4,603.6 48.43 Cameo MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/4/2013 PRODUCTION, 4 7,086.2 5,258.4 48.56 Cameo MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/4/2013 33-8,507 5 7,721.7 5,696.0 44.19 Cameo MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/4/2013 6 7,887.8 5,817.0 41.99 MERLA TPDX 1 1/2 PROD CV RM 0.000 0.0 11/29/2012 SLOTS, — 7 7,960.6 5,871.2 41.85 MERLA TPDX 1 12 PROD DMY RM 0.000 0.0 12/162006 8.306 -9,095 8 8,130.8 5,995.8 44.60 MERLA TPDX 1 12 PROD DMY RM 0.000 0.0 12/26/1992 LINER AL1 I Post 2012 Cut. 8,144-9,107 \ i i TD (22- 13AL1). \ 9,350 ~J ~:~: .~ e ~.:. ~ ~ +y _ ~~ ~' ~ ~ .. ~ ~* - .;,~ ~ ?': ~.~~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • ~o~o~~~~i~~~p~ ~~as~Ca ~ ~~c~~~~~r~ N~ oth~r dis~ri~uta~~ as allow~d ~v°s~h~~~~ OF! F91VAL OFi FIR~A~ ~nrretten ~pp~o~s~l ~~~or~a Cora~coP~ai61a~~ 9mage files and/oa- ~igital ~a~a coratact: Lisa 1Neight, 907 263~4~~3 "raarclcopy prints , , ~, ~~~ . ~ ~ ~~ ~::~:3 .~--~~;~.~; ~ v. _ . ,,~~_~ ~ ,~'~ ~: . '' ~ r: _ _ ;-~ ~. , . ,,.~ "' . -].. ,,.':J , ~~ uJ ~~~,:b~~_ iY9~{i~m~'~~~~~wg ~~ 56~ ~~ ~i~'; ~~9~~~Le l . _ °. -. . ~~~~s~9ra~ ~ia~~~w~ 1 Graphic image file .. . 333 i~J~st ~~~ ~~w, ~a~a~~ °~~0 in lieu of sepia** Electronic ~,~echorage, ~~as~ca ~~~0~ CGM / TIFF LIS ~~ ~ ~ ~ , ;~y~r~a~y~^ ^7 :~a ~a~~~ ~yn~~~, ~~~~~~ 1 Graphic image file . _ . ~a~~r°;~ ~~~~~a5 in lieu of sepia"* Electronic ~.i3. ~~x ~~~~1? CGM / TIFF LIS :~~~F~~~a~e, ~ias~a '~~~,`1 ~-~6`3 ~ ~~~~~d~~il4S~lJ ~~~ _ - _ ~9~s~~ ~ry~~;~?~ 1 Graphic image file _ . a~.~.~a~ ~~~~d~7 in lieu of sepia'* Electronic ~r~~hor~ge, A9as~ca ~951~ CGM / TIFF LIS Brandos~ Tu~k~r, lVRT ~~~t~ ~~ s~~1Si{~; ~~~, ~9`9. ~'d' ~9~ ~~3~ ~s~~°s _.. . 550 VV. 7~~ A~re, Suite ~00 Electronic Anch~r~ge, Alaska 99501~3510 LIS 4 ~. ~ ~ 1~~~ a ~ ~c.~ ~~ s°~"~~~~, Fs'`- ,- ~. ~p ~ - t'~' ~ ~~s~j~~ ,-,. ,~ S'lease see page 2 for definition of Reservoir Analysis Logs and Completion Logs (Cased Hole Final Services). "` AOGCC guidelines for Graphical Image File in lieu of reproducible: "The graphical file must contain information equivalent to the hardcopy materials and consist of a separate file for each blueline or sepia. /\ publicly distributable viewer for the graphical format is required." ``"~ ' ~~`'~ ""' ConocoPhillips, Alaska requests a non-proprietary archive format image file (.tiff) to facilitate discontinuation of mylar reproducibles "`' ~iles larger than 20 MB should be hosted on a CD/DVD and be sent by mail. Files less than 20 MB should be sent via FTP site. ^ I~is4< includes Well End Report, LAS files and Graphic Image Files. COP will distribute one hardcopy and disk to DNR, and disks to partners. ConocoPhillips Alaska Greater Kuparuk Area*** Data Distribution P';~s~rnroB~ Analysis Logs: IPROF, PPROF (any Production Profile Log), CNL, TDT, RST, Directional Survey, Temp, Gas Detection (and other logs that evaluate i~rmation or tell relationship between reservoir & depth), spinner surveys open hole evaluation logs ( DIL, GR, etc.) open hole array and specialty logs (dipole/waveform sonic, formation imager, nuclear/magnetic resonance, formation sampler) request dlis digital format and graphic image files - Please contact Well Data Specialist for details cased hole evaluation logs ( CNL, CNTG, TDT, WFL, RST etc.) ~~~ ~~ ~' t,~ j~ (O Page 1 of 2 ~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061710 Well Name/No. KUPARUK RIV UNIT 2Z-13AL1 Operator CONOCOPHILLIPS ALASKA INC MD 9350 TVD 6058 Completion Date 2/8/2007 Completion Status 1-OIL REQUIRED INFORMATION Mud Log No .DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D D Asc Directional Survey ~t Directional Survey L /tD D Asc Directional Survey R L pt Directional Survey ~t 17031 Caliper log I~E`D C 17031 Caliper log Well Cores/Sampl es Information: ~+ Name ADDITIONAL INFORMATION Well Cored? Y I~ Chips Received? ~-M~ Analysis Received? Comments: ~ Ik n i--- 8244 9350 Open 2/26/2007 8244 9350 Open 2/26/2007 8181 9538 Open 2/26/2007 PB 1 8181 9538 Open 2/26/2007 PB 1 0 7898 Case 11/7/2008 Mem Multi Finger Caliper Log Results Summ w/3-D PDS graphcis 0 7898 Case 11/7/2008 Mem Multi Finger Caliper Log Results Summ w/3-D PDS graphcis Samples No API No. 50-029-21360-60-00 Current Status 1-OIL UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments Interval Start Stop Sent Received Daily History Received? Formation Tops Sample Set Number Comments ~N ~/N DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061710 Well NamelNo. KUPARUK RIV UNIT 2Z-13AL1 MD 9350 ND 6058 Completion Date 2/8/2007 Compliance Reviewed By: Operator CONOCOPHILLIPS ALASKA INC APt No. 50-029-21360-50-00 Completion Status 1-OIL Current Status 1-OIL UIC N Date: __~ _ L~ LAG ~~ ~, l T/4.411 ~Sft/I/1 ~1 "AL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing lnspection(Caliper/ NTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907 245-8952 1) Caliper Report 2) 30-Oct-08 2Z-13A 1 Report / EDE 50-029-2136x60 ~oC~-c~ (~ 163 c Si ~i Date: gned: II // _. Print Name: ~iLri-~~uc~ ~;l~tl~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~d~,~~i?~~ar~slensas~s~aa~~~~a~~c~~ WEBSITE:v}r,°u~,~,r~a~css?ilaa.vt~ C:\Documertls and Settings\Owner\Desktop\Tiaz~smit_Conoco.doc~c .~ Memory Multi-Finger Caliper S ~,. Log Results Summary Company: CortocoPhiNips Alaska, Inc. Well: ?Z-13A Log Date: October 30, 2t~8 Field: Kuparuk Log No.: 8718 State: Alaska Run No.: 2 API No.: 50-029-21360-60 Pipet Desc.: 3.5" 9.3 Ib. J-55 8RDEUE Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 7,898 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the top of GLM 8 @ 7,795' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical damage for future patch operation planning. The caliper recordings indicate the 3.5" tubing logged is in good to poor condition with respect to internal corrosive and mechanical damage, with a maximum wall penetration of 41% recorded in an isolated pit in joint 222 (6,874'). Other recorded damage appears in the form of isolated pitting. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the 3.5" tubing logged. This is the second time a PDS caliper has been run on this well. A comparison between the current and previous log (October 18, 2006} indigtes an increase in corrosive damage from 6,800' to 7,898` during the time between logs. A comparison graph illustrating the maximum-recorded penetration on a joint-by joint basis for the current and previous log is included in this report. MAXIMUM RECORDED WALL PENETRATIONS Isolated pitting (41%) Jt. 222 @ 6,874 Ft. (MD) Isolated pitting. (40%) Jt. 223 @ 6,922 Ft. (MD) Isolated pitting (39°~) Jt. 225 @ 6,989 Ft. (MD) Isolated pitting (38%) Jt. 226 @ 7,016 Ft. (MD) Isolated pitting (37%) Jt. 224 @ 6,952 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 6%} are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the 3.5" tubing logged. Field Engineer: K Miller Analyst: C. Waldrop Witness: S. Ferguson ProActive Diagnostic Services, Inc, j P.O. Box: 1369, Stafford, TX 77497 Phone: (281) or (888} 565-9085 Fax: (281) 565-1369 E-mail: PAS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 `„ _ `~ Well: 2Z-13A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Maximum Recorded Penetration Comparison To Previous Survey Date: October 30, 2008 Prev. Date: October 18, 2006 Tool: U W MFC 24 No. 212330 Tubing: 3.5" 9.3 Ib J-55 8RDEUE Overlay Max. R ec. Pen. (mils ) 0 1 00 2 00 0.1 10 20 30 40 SO 59 68 78 88 98 108 _ ,g 118 128 Z e 137 . ^ 147 157 167 177 186 196 205.1 215 224 233 -- 242 = 251 ^ October 30, 2008 ^ October 18, 2006 Difference -100 - Dill. in Max. Pe 50 0 5 n. (mils) 0 1 00 150 i 10 ZO 30 40 50 59 68 78 i 88 98 108 118 ~ 128 Z e 137 .a 147 157 167 177 186 196 205.1 215 224 i 233 242 251 -49 -2 5 0 2 5 4 9 74 Ap prox. Corrosion Rate (m py) • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (-0.3' - 7891.3') Well: 2Z-13A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 30, 2008 A pprox. Tool De viation ^ A pprox. Boreho le Profil e 4 746 1522 GLM 1 2311 3067 3831 ~ GLM 2 ~- t a v 4611 5376 GLM 3 6164 GLM 4 GLM 5 6957 GLM 6 GLM 7 GLM 8 7764 GLM 9 252.1 7891 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 252.1 1 25 50 . 75 100 v E 125 c 'o 150 175 200 - 225 PDS Report Overview ~~, s. Body Region Analysis Well: 2Z-13A Survey Date: October 30, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 8RDEUE 2.992 ins 3.756 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°k wall) ~ penetration body a metal loss body 200 150 100 50 0 0 Io 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 253 pene. 0 189 46 16 2 0 loss 58 195 0 0 0 0 Damage Configuration (body ) 20 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ihle hole Number of 'oints dama ed total = 19 19 0 0 0 0 Damage Profile (°~6 wall) ~ penetration body ;, rnetal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 GLM 9 Bottom of Survey = 252.1 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf )-55 8RDEUE Well: 2Z-13A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 30, 2008 Joint No. )t. Depth (Ft) Pc~n. tJ)~.r~t (Ins.! Pen. Body (lns.) Pen. °/~ V1c~),rl f~xs °~~ Min. LD• (Ins.) Comments Damage Prolilc~ (%wall) 0 50 1(1(1 .1 -0 ~) 0.01 4 1 2.94 PUP 1 4 u 0.02 f3 2.94 2 34 U 0.02 0 2.92 3 65 t) 0.01 .5 2.92 4 95 ~ ~ 0.01 -1 2.93 5 125 a 0.02 is 2.91 6 155 l) 0.01 4 2.93 7 186 O 0.03 11 a 2.90 8 218 U 0.0. 13 ~' 2.90 9 250 n 0.02 7 2.93 10 82 O 0.02 7 2.91 11 314 O 0.03 13 a 2.88 12 346 (~ 0.02 f3 2.93 13 378 O 0.01 6 2.93 14 410 t) 0.03 10 2.90 15 442 U .02 ~> 2.94 16 471 t) 0.01 U ~ 2.90 17 502 l) 0.02 ~) _' 2.92 18 533 a 0.01 5 2.95 19 563 a 0.02 7 ! 2.91 20 593 ~) 0.01 ~ -1 2.91 21 6 U 0.01 v 2.88 22 654 O 0.02 2.90 2 3 686 ~) 0.02 ~~ (~ 2.88 4 716 U 0.03 I U ! 2.89 25 746 U 0.02 - _' 2.91 26 777 U 0. 3 1 U _' 2.90 27 805 ~) 0.01 ~ ~' 2.90 28 837 O 0. 1 r, _' 2.93 29 867 O 0.01 4 2.94 30 898 U 0.01 ~ ~ 2.93 31 926 O 0.02 7 2.92 32 957 O 0.01 4 2.92 33 989 ~7 0.02 ~ 2.92 34 1019 ~) 0.01 5 2.88 35 1051 tr 0.02 ~) _' 2.88 36 1082 U 0.02 ~ 2.89 37 1114 t) 0.01 ~i ~ 2.90 38 1145 O 0.01 4 _' 2.90 39 1176 a 0.02 9 _' 2.91 40 120 lr 0.01 5 -1 2.89 41 1238 ~) 0.02 - ~, 2.92 42 1270 U 0.0 7 i 2.91 43 1302 U 0.02 7 _' 2.92 44 1334 (~ 0.02 7 ; 2.90 45 1366 O 0.02 i ~' 2.91 46 1398 U 0.03 12 2.91 47 142 9 ~ ~ 0.02 y ' 2.88 48 1462 U 0.03 13 O 2.88 49 1493 i ? 0.01 5 _' 2.94 Penetration Body Metal Loss Body Page 1 ! • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 BRDEUE Well: 2Z-13A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 30, 2008 Joint No. Jt. Depth (Ft.) I'c~n. (Ip~c~t (Ins.) Pen. Body (Ins.) Pc~n. %> ~Ic~t,il I oss Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1522 U 0.01 4 2.93 51 1552 ~ ~ 0.01 i ~' 2.92 2 1583 O 0.02 ~) .' 2.91 53 1615 t~ 0.02 t3 ~ 2.90 54 1646 O 0.01 b _' 2.9 55 1677 (~ 0.01 ~ 2.92 56 1708 O 0.01 (, 2.92 57 1738 (~ 0.02 ~~ ~ 2.91 58 1770 (~ 0.01 ~ ? 2.91 58.1 1802 t) 0 U t) 2.81 Baker FVL SSSV 59 1815 (~ 0.03 1 U _' 2.87 60 1845 t) 0.02 7 t 2.92 61 1875 ~) 0.02 7 2.92 62 1905 U 0.01 t~ 2.91 63 1935 t) 0.02 ~ 2.91 64 1965 O 0.02 '~ 5 2.94 64.1 1994 U 0 U U N A GLM 1 Latch @ 5:00 65 2001 U 0.01 6 2.92 66 2031 U 0.02 ~) ? 2.88 67 2059 i ~ 0.0 1 U 3 2.90 68 2091 n 0.01 (> ~ 2.90 69 212 3 U 0.03 l ll ~ 2.91 70 2155 a 0.01 5 _' 2.90 71 2187 t1 0.02 tt ~ 2.91 72 2219 O 0.01 ~~ I 2.91 73 2249 U 0.01 ~ 2.91 74 2281 a 0.02 f3 2.91 75 2311 U 0.01 (~ 2.92 76 2343 (1 0.02 7 2.94 77 2374 U 0.02 ti _' 2.92 78 2404 O 0.02 7 2.89 79 2436 t~ 0.02 t3 2.93 80 2468 (1 0.02 ~> _' 2.92 81 2498 O 0.02 ri I 2.89 82 2529 ll 0.02 r3 2.90 83 2561 U 0.02 i ~~ 2.88 84 2592 O 0.01 b -l 2.93 85 2623 ~~ 0.02 8 ? 2.90 86 2653 (~ 0.02 7 ~ 2.90 87 2685 U 0.01 (~ 2.91 88 2714 ~ i 0.02 7 .91 89 2746 O 0.03 i3 s 2.89 90 778 t) 0.01 ~ 2.92 91 2806 (~ 0.01 t~ 1 2.89 92 2 83 6 (t 0.02 ti ~ 2.90 93 2864 U 0.01 (~ I 2.91 94 2879 (~ 0.01 5 2.90 95 2911 ~) 0.01 ~~ 2.91 96 2942 ~? 0.03 I _~ 2.88 97 2973 ~ ? 0.02 >': 2.89 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf J-55 8RDEUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: iLATION SHEET 2Z-13A Kuparuk ConocoPhillips Alaska, Inc USA October 30, 2008 Joint No. Jt. Depth (Ft.) I'c~n. I llsc~t (Ins.) Pen. Body (Ins.) I't~n. `%, Metal I os5 ';4> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 98 3004 a .02 9 ~' 2.88 99 3035 a 0.02 t3 1 2.88 100 3067 a 0.01 b ~ 2.88 101 309 U 0.03 Imo' ? 2.90 102 3130 t ~ 0.02 I 2.92 103 3161 i ~ 0.0 ~ 1 2.92 104 3192 U 0.02 ~) 2.91 105 3224 a 0.01 ~ .92 106 3255 a 0.0 7 u 2.90 107 3287 U 0.01 (~ 2.91 108 33 8 u 0.01 t~ 2.93 109 3346 t t 0. 2 7 2.91 110 3375 U 0.01 ~ _' 2.88 111 3406 11 0.02 7 2.92 112 3436 It 0.02 8 ~' 2.93 113 3465 U 0.02 7 ' 2.94 114 3495 t ~ 0.01 4 1 2.93 115 3523 tt 0.02 t3 2.94 1 16 3555 t t 0.02 ~) _' 2.91 117 3585 a 0.03 12 t t 2.90 118 3614 t ~ 0.02 ~ _' 2.90 119 645 (1 0.02 ~ t 2.92 120 3677 tt 0.01 4 ~' 2.93 121 3709 a 0.02 7 _' 2.93 12 37 1 O 0.02 7 u 2.90 123 3769 a 0.01 _' _' 2.89 124 3799 (t 0.02 7 2.94 125 3831 t) 0.02 ~) ~ 2.91 126 3860 U 0.01 5 2.94 127 3889 n 0.02 I 2.95 128 3919 t t 0.02 ti I 2.92 129 3950 tt 0.02 ~ 2.93 130 39 1 t ~ 0.01 Z 2.93 131 4014 U 0.01 5 I 2.95 132 4045 tt 0.02 t3 1 2.93 133 4077 U 0.02 t3 i 2.91 133.1 4107 U 0 tt t) N A GL 2 atch ~ 3:00 134 4114 t) 0.01 t~ _' 2.95 135 4146 U 0.01 (> t t 2.91 136 4177 r t 0.01 ~ _' 2.94 137 4207 U 0.01 ? I 2.93 138 4239 U 0.01 b U 2.93 139 4269 l1 0.01 5 I 2.93 140 4301 t) 0.01 a _' 2.91 141 4331 t ~ 0.01 i I 2.94 142 4363 a 0.02 ~ ? 2.94 143 4394 t t 0.01 S ' 2.91 144 442 5 ~ t 0.05 1~ 1 I 2.91 145 4457 0.01 5 2.93 146 4485 0.03 I _' ! 2.93 ®Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf J-55 8RDEUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Cornpany: Norninal I.D.: 2.992 in Country: Survey Date: M ELATION SHEET 2Z-13A Kuparuk ConocoPhillips Alaska, Inc. USA October 30, 2008 Joint No. Jt. Depth (Ft.) Porn. t Il,x~r iln~.~ Pen. Body (Ins.) Nc~n. %, ~;tc~(,rl I ~~s, ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 147 4516 ~ ~ 0.02 - 2.93 148 4547 t ~ 0.03 I 1 ? 2.91 149 4579 U 0.01 I 2.92 150 461 1 O 0.02 - -t 2.9 151 4641 t) 0.02 ~) I 2.94 152 4673 U 0.01 ~> 2 2.92 153 4705 tl 0.04 1 i 5 2.91 154 4734 t ~ 0.02 ti 1 2.94 1 5 4764 a 0.03 I1 ~~ 2.92 156 4794 t? 0.0 ~ I 2.91 157 4826 (~ 0.02 " I 2.95 158 4856 i7 0.02 - 2.92 159 4887 t) 0.01 t~ ~ 2.88 160 4918 (~ 0.01 -1 I 2.90 161 4948 ~ ~ 0.03 I _~ _' 2.93 162 4979 a 0.03 1 u ~ 2.90 163 5011 O 0.0 7 u 2.91 164 5042 (~ 0.03 1 I s 2.88 165 5071 t~ 0.01 Z ~ 2.91 166 5100 r~ 0.02 t3 ? 2.93 167 5131 U 0.03 1 tJ ~l 2.91 168 5164 ti 0.02 t3 I 2.92 169 5194 [? 0.02 ~ U 2.90 170 5223 t~ 0.02 7 2.93 17 252 tl .01 5 1 2.91 172 5285 !) 0.02 ~) 1 2.93 173 5316 ~ 1 0.02 ~) 2.93 174 5345 U 0.03 1 U u 2.89 175 5376 t? 0.02 ~3 _' 2.88 176 5407 t~ 0.01 r, 2.91 177 5439 U 0.02 ti ? 2.88 178 5470 U 0.02 7 1 2.88 179 5499 l? 0.01 4 2.88 180 5531 t ~ 0.04 15 I 2.88 181 5563 t) 0.02 ~ _' 2.88 182 5594 U 0.03 I U ~' 2.87 183 5626 (t 0.01 (~ a 2.89 184 5658 t) 0.03 1 I I 2.89 184.1 5689 t~ 0 U t~ N A GLM 3 Latch ~ 9:30 185 5695 a 0.03 1 _; _' 2.88 186 5727 U 0.02 ~) ; 2.89 187 5759 t) 0.02 7 U 2.87 188 5790 i) 0.02 t3 1 2.87 189 5821 t~ 0.01 ~' I 2.87 190 5852 t~ 0.02 9 _' 2.88 191 5883 i ~ 0.03 ! I 2.87 192 5914 ~~ 0.07 _'~~ i 2.87 Isolated ittin . 193 5945 t ~ 0.03 I ~ a 2.87 194 5978 ~ ! 0.03 I 2.87 195 6010 i ~ 0.02 2.89 Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf J-55 8RDEUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 2Z-13A Kuparuk ConocoPhillips Alaska, Inc. USA October 30, 2008 Joint No. Jt. Depth (Ft.) Pen. I ll~et (Ins.) Pen. Body (Ins.) PErn. % 1c~t.~l I cuss ,~, Min. LD• (Ins.) Comments Damage Profile (%walQ 0 50 100 196 6040 0 0.02 ti 1 2.88 197 6071 0 0.03 10 1 2.87 198 6102 0 0.03 13 ' 2.90 199 6133 U 0.03 12 b 2.88 200 6164 O 0.02 t3 U 2.87 ZO1 6194 0 0.02 ~) i i 2.89 202 6226 U 0.02 ~) _' 2.88 203 6258 0 0.03 11 ~ 2.89 204 6289 0 0.02 t3 2.86 205 6320 0 0.02 + 2.87 205.1 6352 U 0 0 0 N A GLM 4 Latch ~ 8:00 206 6358 i) 0.03 13 2.88 207 6391 U 0.02 ti _' 2.91 208 6421 U 0.03 11 2.88 209 6452 (! 0.03 1 U _' 2.88 210 6483 0 .03 I:~ ~ 2.88 211 6515 i) 0.03 1 Z Z 2.88 212 6545 (! 0.02 ~~ _' 2.88 213 6575 (t 0.02 (! 2.93 214 6606 i i 0.05 I ~i I 2.90 215 6635 (i 0.02 7 2.9 216 6665 (i 0.03 11 n 2.89 217 6698 i i 0.04 1 5 2.96 217.1 6729 n 0 0 i i N A GLM 5 Latch d 5:30 18 736 (~ 0.03 13 t .92 219 6768 ~ ! 0.03 13 2.92 220 6800 a 0.02 9 ! 2.91 221 6832 ~) 0.06 24 I 2.96 Isolated ittin . 222 6864 U 0.10 41 _' 2.88 isolated ittin . 223 6896 ii 0.10 -11) 2.94 Isolated ittin . 224 6928 (i 0.10 ~7 _' 2.93 Isolated ittin . 225 6957 a 0.13 52 2.93 Isolated ittin . 226 6989 0 0.10 3E3 -' 2.92 Isolated ittin . 227 7020 0 0.08 3Z _' 2.92 Isolated ittin . 228 7052 U 0.08 30 2 2.91 Isolated ittin . 229 7085 U 0.08 31 _' 2.89 Isolated ittin . 229.1 7117 0 0 0 i i N A GLM 6 Latch ~ 2:00 230 7123 n 0.03 1 c 2.93 231 7155 U 0.08 >1 2.93 Isolated ittin . 232 7187 ii 0.07 Z~ _' 2.93 Isolated ittin . 233 7219 0 0.06 '-3 I 2.90 Isolated ittin . 234 7251 0 0.05 ZO 2.93 Isolated ittin . 235 7282 0 0.04 16 ~ 2.92 236 7315 U 0.07 ;0 Z 2.94 Isolated ittin . 237 7346 U 0.05 ZO s 2.91 238 7379 t) 0.05 ,' 1 2.95 Isolated ittin . 239 7410 U 0.06 Z~1 _' 2.93 Isolated ittin . 240 7442 U 0.05 1 ~) 1 2.92 240.1 7474 i! 0 0 i ~ N A GLM 7 Latch @ 8:30 241 7480 ii 0.07 <'(~ I 2.91 Isolated ittin . _ Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf )-55 8RDEUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 2Z-13A Kuparuk ConocoPhillips Alaska, Inc USA October 30, 2008 Joint No. Jt. Depth (Ft.) I'c•n. 111„c•i (Irn.) Pen. Body (Ins.) Pc•n. °/, Mc•t.~l I c>ss `;~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 242 7513 I~ 0.06 2 s I 2.88 Isolated ittin . 243 7545 U 0.02 ~) _' 2.93 244 7575 ~~ 0.03 12 I 2.92 245 7607 ~ ~ 0.04 1 7 2.91 246 7640 ~ ~ 0.02 ~~ _' 2.91 247 7672 U 0.03 13 I 2.87 248 7704 ~ ~ 0.04 I ~ 2.92 249 7735 ~) 0.03 13 2.91 250 7764 ~ ~ 0.04 15 2.90 250.1 7795 11 0 U ~t N A GLM 8 Latch ~ 8:00 251 7805 O 0.03 12 _' 2.91 251.1 7838 O 0 l) a 3.00 Baker PBR 251.2 7851 i~ 0 l) l) .00 Baker'FHL' Packer Isolated ittin . 252 7858 ~ ~ 0.02 t3 5 2.91 252.1 7891 ~? O O N A GLM 9 Latch @ 2:00 _ Penetration Body Metal Loss Body Page 6 Well: 2Z-13A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA PDS Report Cross Sections Survey Date: October 30, 2008 Tool Type: UW MFC 24 No. 212330 Tool Size: 1.69 No. of Fingers; 24 Analyst: C. Waldron Cross Section for Joint 222 at depth 6874.01 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 50 ° Finger 19 Penetration = 0.103 ins Isolated pitting 0.10 ins = 41% Wall Penetration HIGH SIDE = UP !I Cross Sections page 1 PDS Report Cross Sections ~~~ _ ~'~ . Well: 2Z-13A Survey Date: October 30, 2008 Field: Kuparuk Tool Type; UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 ppf __ J-55 8RDEUE Analyst: C. Waldrop Cross Section for Joint 223 at depth 6921.54 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 46 ° Finger 15 Penetration = 0.101 ins Isolated pitting 0.10 ins = 40% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ~~ KUP ~ 2Z-13A ~l ConoeoPhillips Well Attributes ,''I~'"'' ~'I wesbare APlNVtlI Fleld Rene Well staurs InWnatlon(') 110 mK~1 Total Depm plKe) 1 1 500292136060 KUPARUK RIVER UNIT PROD 106.03 8.483.66 9,350.0 -.- _ _ ti~ nm6tt SSSV: Lotted Out 2S (PPm) Dale Ertl ate Im<i'tl pq 130 7/12008 Last WO: 42.10 pReleau 7/7/1985 c-Aeval ArarMatlon Mrolatlar BdD last Tag: Rev Reason: GLV C!O 9212008 Casin Strin s CONIXICTOR, S!t ~ j 80 casxrg Drsalptlon OD Pro dnl T pncej 1~ IOW pemq tratle sump Top llae SPFETV p CONDUCTOR 16 15.062 0.0 80.0 80-0 62.50 H~0 vALVE, t ezo SURFACE 9 5l8 8.765 0.0 4,203.0 3,359.1 36.00 J-55 GAS uFr, PRODUCTION 7 6.151 0.0 8,506.0 6,091.1 26.00 J-55 ? ott A LINER 2318 0.100 8,185.0 8,308.0 6,075.4 4.40 L$0 A INER 5L0 D 2318 1. 2 8,308.0 8,629.0 6,098.2 4.40 L-80 GAS LIFT. d 131 A LINER 23!8 1.992 8.629.0 8,634.0 6,096.5 4.40 L-80 , ~R ~ A LINER SLOTTED 2318 1.992 8,634.0 8,729.0 6,104.5 4.40 L$0 e~as ALJNER 2318 1.992 8,729.0 8,822.0 6,109.1 4.40 L$0 GAS LIFT. ALINER SLOTTE 2318 1.992 8,822.0 9.043.0 6,101.0 4.40 L$0 s. roe ALINER 23/8 1.992 9,043.0 9,142.0 6,094.9 4.40 L$0 Tubin grin s GAS LIFT, 6 360 Tubnrp Desolptlon OD Irrl D M Top e) Set Dep91 (fig) set DepSr INDI CBI YY[ 9usllq Se'irrg tratle Tap Ttrd TUBING 3 1/2 2.992 0.0 8,175.0 6,025.2 9.30 J35 8rdEUE GAS61F S Other In Hole All Jewel : Tubfn Run 8 Retrievabl Fish etc. Tap mt~ Dla4YlpUon mmere rm aee PM GAS UFr. 1,820.0 SAFETY BAKER FVL (LOCKED OUT 1990) (WAIVERED 2/16/1997) 7/15/1985 2.810 i.n9 VALVE 2.011.0 GAS UFT MERLA/TMPD/1/GL K/.188/1304/ Comment STA 1 2242007 2.875 GAS uFT 4 132 0 GAS UFT MERLA/TMPD/1/GLV/BK/ 188/1307/ CanmenC A 2 2242007 2.875 Id14 . . . 5,702.0 GAS UFT MERLAliMPD/1/GLVIBICl.188l1303! Comment: STA 3 2242007 2.875 GAS LIFT. 6,360.0 GAS LI MERLA/TMPDl1/DMV/BK///COmnent: STA4 2!12004 2.875 r.r9s 6,735.0 GAS LIFT MERLAITMPD/1/GLVIBK/.188112961 Comment STA 5 9/132008 2.875 7,119.0 GAS LIFT MERLA/TMPDl1lDMY/BK///CamrlenC STA6 2112004 2.875 °~' 7 e36 7,474.0 GAS LJFT MER MPD/1/OV/BK/.25!/ Cortnrerrt: 5 A 7 9/812008 2.875 7,795.0 GAS LIFT MERLAIfPDX/1.5/DMV/RM/// Comment STA 8 7!17/1985 2.875 PACKER. i,eas 7,836.0 PBR KER PBR 7/16/1985 3.000 7,849.0 PACKER BA R'FHL' PACKER 7/15/1985 3. 00 oapby570e+a, 7 et 7.885.0 CATCHER 2.75"AVA CATCH 9/132008 2.750 e 7,888.0 PRODUCTION MER X11 .5/DMV/RM!//Camtent STA 9 9/132008 2.875 CATCHER. 7,910.0 PLl1G 21/8" IBP 5/112008 0.000 Teas 7,961.0 PRODUCTION MERLMPDX//DMY/RMI// Carrrrrerp: STA 10 12/1 006 2.875 PRODUCTION 8.097.0 Blast R'sg BOT BLAST STEEL COLLAR "HAS LEAK" 7/15/1985 2.992 , 7 eae 8,131.0 PRODUCTION MERLAffPDX/I IRMIII Cormrerrl: STA 11 122611992 2.875 8.151.0 PACKER BAKER'FB-1' PACKER 7/15/ 985 3.000 U uNER, 902 8.631.0 SHOE A LINER UNIQUE INDEXING GUIDE SHOE w/CEMF_NTRA117FR 122/2007 0.500 vLUG. 7 sto 9,141.0 SHOE A LINER UNIQUE INDEXING GUIDE SHOE w/CEMENTRALIZER 121/2007 0.500 PROD CT ON Per(oreN OnS U I , 7,961 SLOTS, Top (TVDI Run (TVD) ~~ 79028,068 Tap (itl(g) 06n pucBj (l11(R) pBC~ Zone (~~.• Date CommM u uNER SLOTTED. aw 8,308.0 8,629.0 6,075.4 6,096.2 SLOTS 32.0 1212007 2Z-13A Slotlad Liner a 8 634 0 8 729 0 6 096 5 6 104 5 SLOTS 32 0 12112007 2Z-13A Sbtted Liner BIe4 Rln9 , . . . . . , . . , R.09T 8,822.0 9,043.0 6.109.1 6,101.0 SLOTS 32.0 1212007 2Z-13A SbDed liner Stimulations & T reatment s PROWCtION. Mn TOp MrX Ben 8.131 aPUr Deptlr I~G l~Bl Date eammwR 8.182.0 8,192.0 4/G2007 LINER LINER HOLF PUNCHES 6 SPF w/PJ1606 PACKER. east PUNCH... Notes: General 8 ~~~~ tlDate Arcot n , a.tsa 2/8/2007 NOTE: MULTILAT AL SIDETRACK ZZ-13A & 2Z-13AL1 2182007 NOTE: GLNLs #9 8 q11 bbcked by sold pipe portion of Sidetrad Lateral AL1 DepbYSub, , , 8,185 LINER , PUNCHES, 8,181 L1 LINER 8.290 A LINER, 8,306 SLOTS 8,308$,619 ~ _ _ PRODUCTION,. _ - - _ 8.506 ' A LINER SLOTTED, 8,629 SHOE. 8,631 Depby sub. 8.631 A LINER. 8,834 SLOTS, 8,6348,729 A LINER SLOTTED. 8,729 A LINER, 8.821 SLOTS 8.811-9.063 A LINER SLOTTED, 9,043 O-RNG SUB. 9,106 SHOE, 9,ibt A LINER, 9,161 T012Z-i3A1, 9,300 ~, RECEIVED STATE OF ALASKA APR Q 8 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERQTIOp~~ka oi18 Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other AnC age Alter Casing ^~ - Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ ~ Exploratory ^ 206-171 / 3. Address: Stratigraphic ^ Service ^ 6. APi Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21360-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 32.6' 2Z-13AL1 - 8. Property Designation: 10. Field/Pool(s): ADL 025653 Kuparuk River Field !Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9350' feet true vertical 6058' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 4170' 9-5/8" 4203' 3360' PRODUCTION 8118' 7" 8151' 6010' PRODUCTION 1209' 2-3/8" 9090' 6052' Perforation depth: Measured depth: 7902'-8068', 8290'-9078' true vertical depth: 5828'-5951', 6096'-6052' Tubing (size, grade, and measured depth) 3-1l2" , J-55, 8175' MD. Packers &SSSV (type & measured depth) no packer Baker FVL SSSV= 1820' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable - ~ ~,.T - i' -~ , ~ ~ ~~ 200 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 weN operation 90 790 35 -- 167 Subsequent to operation SI ~ -- 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: OilO 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 N/A if C.O. Exempt: none contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer )r~ ~0 ~ ~ Signature ~ Phone Date j l f Pre ared Sha n A /su Drek 263-4612 `~,., ~ 4/. ~. o~ Form 1 -404 Revised 04/2006 ~ ~ ~ ^ ~ ~ A L f" ~~~ Sub i i~~~~ 2Z-13A Well Events Summary DATE SUMMARY 2/14/08 RIH WITH PBMS/GRADIO/PEGS. UNABLE TO ENTER 2 3/8" LINER TOP AT 7881'. RIH WITH 1 11/16" CHG. UNABLE TO ENTER LINER TOP AT 7881'. 2/18/08 TAG TOP OF 2 3/8"LINER WITH 2.25" SWAGE @ 7881' RKB.WORK 1.875" O.D. AND BLB'S INTO LINER AND BRUSH FROM 8105' SLM TO TOP OF LINER.IN PROGRESS 2/19/08 DRIFTED 1.75" OD OAL=211" BAILER INTO 2 3/8" LINER TO 7979' RKB WITHOUT SITTING DOWN.STIFFEN TOOLSTRING FLATTER BTM WILL SIT DOWN.WORKED 1.85" DRIFT THROUGH 7881' RKB TO 8029' RKB TO DRIFT FREELY. 3/7/08 RAN DUMMY RUN WITH GRADIO AND 1.85" SLICKLINE CENTRALIZER. ABLE TO ENTER LINER TOP WITH 1.85" SLICKLINE CENTRALIZER. DIESEL PRESENT AT CUT DEPTH DEPTH IN 2 3/8" LINER. PUMPED 55 BBLS SEAWATER, 20 BBLS DIESEL, AND 1 BBL METHANOL TO PUT SEAWATER AT CUT DEPTH. CUT 2 3/8" LINER AT 7920'. SUSPECT ANCHORS PICKED UP LINER TOP WHEN THEY EXITED AND DROPPED CUT LINER BACK OFF AT GLM #7. 3/18/08 PULLED DEPLOYMENT SLEEVE AND CHEM CUT 2 3/8" LINER OAL=41' 8.5" FROM 7835' SLM.SET 3 1/2" CATCHERSUB ON CUT LINER @ 7920' RKB.ATTEMPT TO PULL STA #9 DV.IN PROGRESS /`~~` KRU 2Z-13AL1 1 ~pno~oRhilii~s Alaska, nIC. ' 2Z-13AL1 - - _ - _ _ - _ _- APC SOO2y213oGoG Well T :PROD An le TS: d TUBING _ SSSV T e: LOCKED OUT Ori Com letion: 2/8/2007 An le TD: 92 de 9350 (0-8175, Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE OD:3.500, Reference Lo : 32.6' RKB Ref Lo Date: Last U date: 12!28/2007 ID:2.992) ~ ,,,,. T__. Tn. nocn wvo I Last Tag Date: I_ _ __ L Max Hole Angle: 1106 deg (o7 8.484 I _ I _ _Casing String -COMMON STRINGS Descri tton Stze To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 62.50 H-40 WELD SURFACE 9.625 0 4203 3360 36.00 J-55 BTC PRODUCTION 7.000 0 8507 6106 26.00 J-55 BTC Lateral AL1 Solid Liner 2.375 7881 7902 5828 4.40 L-80 STL Lateral AL1 Slotted Liner 2.375 7902 8068 5950 4.40 L-80 STL Lateral AL1 Solid liner 2.375 8068 8290 6096 4.40 L-80 STL Window #2 7.500 8183 8184 6030 0.00 Window #1 3.300 8183 8184 6030 0.00 lateral AL1 Slotted Liner 2.375 8290 9078 6052 4.40 L-80 STL Lateral AL1 Solid Liner 2.375 9078 9090 6052 4.40 L-80 STL 'Tubing String -TUBING Lateral AL1 Solid Liner (7881-7902, OD:2.375, Wt:4.40) Pert (7902-8068) Whipstock (8159-8184, OD:3.500) Lateral AL1 Solid Liner (8068-8290, OD:2.375, Wt:4.40) Size Top -~-- Bottom TVD Wt Grade 3.500 0 8175 G025 9 SU J-5`~ _ Perforations Summary _ - Interval TVD Zone Status Ft SPF Date T 7902 - 8068 5828 - 5950 166 32 2/6/2007 SLOTS 2Z-13AL1 ; ~ 8290 - 9078 6096 - 6052 788 32 2/6/200 1 2Z-13AL1 ' Stimulations 8 Treatments Interval_ Date ~ ~_81h2 E192 4/6/2007 (LIN Type ER PUNCHES LINER HOLE P UNCHES Comment G 5PF w FJ1G06 Thread 8rclEUE l Gas Lift M St MD andte TVD sNalves_ Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2011 1865 Merla TMPD GLV 1.0 BK 0.188 1304 2/24/2007 2 4132 3311 Merla TMPD GLV 1.0 BK 0.188 1307 2/24/2007 3 5702 4324 Merla TMPD GLV 1.0 BK 0.188 1303 2/24/2007 4 6360 4768 Merla TMPD GLV 1.0 BK 0.000 0 7/15/1985 5 6735 5023 Merla TMPD GLV 1.0 BK 0.188 1296 2/24/2007 6 7119 5280 Merla TMPD DMY 1.0 BK 0.000 0 7!15/1985 7 7474 5522 Merla TMPD OV 1.0 BK 0.250 0 2/24/2007 8 Pro St 7795 ductio MD 5749 n Man TVD Merla drels/Va Man Mfr TPDX lves Man Type V Mfr DA4V V Type 1.5 V OD RPA Latch _ 0.000 Port n TRO 7i15/1?R5 Date Run Vlv Cmnt 9 7888 5817 Merla TPDX DMY 1.5 RM 0.000 0 12/24/2007 10 7961 5871 Merla TPDX DMY 1.5 RM 0.000 0 7/15/1985 11. 8131 599fi Merla TPDX _____ - Other lu s, e_ou, ip., etc.) -COMPLETION De h TVD T e DMY 1.5 RM _ Descri ion _ 0.000 0 7/15/1985 _ D 1820 1722 SSSV BAKER FVL LOCKED OUT 6/5/1990 WAIVERED 2/16/1997 2.810 7836 5779 PBR BAKER PBR 3.000 7849 5789 PACKER BAKER'FHL'PACKER 3.000 8097 5972 Blast Rin BOT BLAST STEEL COL LAR "HAS LEAK** 2.992 8151 6010 PACKER BAKER'FB-1' PA(`KER 3 nnn Other (plugs, equip., etc.) - AL1 LINER DETAIL De h TVD T e Descri Uon ID 7881 5812 Deploy L1 LINER BTT DEPLOYMENT SLEEVE set 1/21/2007 2.250 _ Sleeve - 8159 6015 Whi stock L1 LINER BTT MECHANICAL WHIPSTOCK set 1/21/2007 0.000 µ.... 9078 6052 O-RING L1 LINER BTT O-RING SUB 1/21/2007 1.000 9080 fi0S2 SHOE L1 LINER UNIOUE INDEXING GUIDE SHOE w/CEMENTRALIZER 0.625 i Generat Notes EI Perf (8290-9078) Page 1 of 2 ~; Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 07, 2008 9:02 AM To: 'Peirce, John W Subject: RE: 2Z-13A (206-170) and 2Z-13AL1 (206-171)-PTD numbers John, Thanks for the reply. I don't wish to increase your load, but it is probably best to send in a 404 for 2Z-13AL1. Any additional work would only need to be reported for 2Z-13A. Call or message with any questions. Tom Maunder, PE AOGCC From: Peirce, John W [mailto:John.W.Peirce@conocophillips.com] Sent: Monday, April 07, 2008 8:50 AM To: Maunder, Thomas E (DOA) Subject: RE: 2Z-13A (206-170) and 2Z-13AL1 (206-171)--PTD numbers Hi Tom, Objective of 2Z-13A liner cut was to cut off a long enough top piece of 2-3/8" slotted liner to regain access to the upper mandrel in the C sand selective. As a result of not getting the liner to bottom during the CTD job, the upper section of finer was left too high up the tubing to allow us access to the mandrels in the C sand selective. We had no way to pull valves to establish C sand flow to the wellbore. With the top liner piece removed, we now have access to the top C sand mandrel, and we're trying to pull the DV from the mandrel. The well does not have enough flow rate as A sand only, and has been continually freezing off. With C sand flow we alleviate that problem and should be able to increase oil production. Slickline attempts to pull the DV have failed so far. We believe the valve is cemented (as a result of Pre-CTD cement job) &/or scaled in the pocket. Next step will be to run a video log, then we'll decide what to try next to remove the valve. We're considering a few possible future work options like acid soak mandrel loose, CT scale blast mandrel, punch holes to set POGLM, cut out more liner sections to get down to next station, etc. I'll be happy to send a 10-404 for the work we've done under well name 2Z-13AL1. Regards, John Peirce Wells Engineer CPAI Drilling & Wells (907}-265-6471 office From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 04, 2008 2:22 PM To: Peirce, John W Subject: itE: 2Z-13A (206-170) and 2Z-13AL1(206-171)--PTD numbers John, Sorry, I messed up on the PTD numbers. Tom From: Maunder, Thomas E (DOA) Sent: Friday, April 04, 2008 2:19 PM To: Peirce, John W 4/9/2008 Page 2 of 2 Subject: 2Z-13A (206-174) and 2Z-13AL1(206-171) John, I am reviewing the 404 you submitted for -13A regarding cutting and evidently removing the top part of the 2-3/$" liner. What was the issue there? It appears that the cut portion was ultimately successfully recovered. Have you also fi~ a 4(}4 for -13AL1 ? From my read of the file, it appears that "#echnically° the cut liner section was run during the -13AL1 opera#ions. Where sections are not acxessible, it gets confusing. Send a message back and we can discuss it. Tom Maunder, PE AOGCC 4/912008 ~' V ~~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSICR 0 ~ 2007 WELL COMPLETION OR RECOMPLETION REPO~~ ~~~ Cons. Commission AOCh01'8a8 (Main Wellbore) 1 a. Well Status: ®Oil ~ ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.,os zoAac zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ~ ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 2/8/2007 -` 12. Permit to Drill Number 206-171 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spuddedy~ ~5 p? 1/2'/2007 3 ?" 13. API Number 50-029-21360-60-00 s 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/6/2007 ~ 14. Well Name and Number: Kuparuk 2Z-13AL1 ~ 1131 FSL, 244 FEL, SEC. 11, T11N, R09E, UM Top of Productive Horizon: 3916' FNL, 1348' FEL, SEC. 14, T11 N, R09E, UM 8. KB Elevation (ft): 109' 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 4932' FNL, 1435' FEL, SEC. 23, T11 N, R09E, UM 9. Plug Back Depth (MD+TVD) 9090 + 6052 Ft River Pool 4b. Location of Well (State Base Ptane Coordinates): Surface: x- 529467 ~ y- 5965890 'Zone- ASP4 10. Total Depth (MD+TVD) ~ 9350 + 6058 Ft 16. Property Designation: ADL 025653 TPI: x- 528386 y- 5960839 Zone- ASP4 Total Depth: x- 528304 y- 5959823 'Zone- ASP4 11. Depth where SSSV set 1820' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1539' (Approx.) 21. Logs Run: MWD DIR, GR, RES /eCP~' gj2~ D/ 6p~q 7-t/,~ 3-'~• a7 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD. HOLE AMOUNT SIZE WT. PER FT. .GRADE TOP BOTTOM ' TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 102' Surface 102' 30" 255 sx Permafrost'C' 9-5/8" 36# J-55 Surf ce 4203' Surface 3360' 12-1/4" 1150 sx Coldset III 450 sx CS II 7" 26# J-55 Surfa rf ce 6010' -1/2" 375 sx Cla s'G' 180 sx PF' ' 2-3l8" 4.4# L-80 7881' 9090' 5812' 6052' 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-3/8" Slotted Section 3-1/2", 9.3#, J-55 8175' 7849' & 8154' MD TVD MD TVD 7902' - 8068' 5828' - 5951' 8290' - 9078' 6096' - 6052' 2rj, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Es KIND OF MATERIAL USED 8182' Aluminum Billet Kick Off for 2Z-13AL1 2500' Freeze Protect w/Diesel 26. PRODUCTION TEST Date First Production: March 3, 2007 Method of Operation (Flowin Gas Lift, etc.): Gas Lift ~~S C~~~ 'C-i~`1~~Src '~/ Date of Test 3/4/2007 Hours Tested 18 PRODUCTION FOR TEST PERIOD OIL-BBL 308 GAS-MCF 507 WATER-BBL 75 CHOKE SIZE 176 GAS-OIL RATIO 165 Flow Tubing Press. 185 Casing Pressure 1214 CALCULATeD 24-HOUR RATE• OIL-BBL 231 GAS-MCF 380 WATER-BBL 56 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach s.sgi',te~ if necessary). ~, Submit core chips; if none, state "none". c ~ -. None t Z r~~ +--`~" ~ ~A~ ~ ~ 20Q7 & v,....` ~. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE [, ~ ,5 J~ , 7 0`~ ~ 1 G I~ A L `'o' l ~,~Q~~!~ 28 GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". a, Base Kuparuk 61 / Top A6 8235' 6059' None Base A6 /Top A5 8242' 6064' Base A5 /Top A4 8265' 6081' Base A5 /Top A4 9120' 6053' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si d ~~/~ Q gne Terrie Hubble Title Technical Assistant Date Kuparuk 2Z-13AL1 206-171 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Aras Worthington, 564-4102 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Irene 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Irene 20: True vertical thickness. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP Page 1 of 28 ~ Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ~ Hours Task ~ Code ~ NPT -- 1/10/2007 00:00 - 00:15 0.25 MOB P 00:15 - 03:00 2.75 MOB P 03:00 - 05:20 ~ 2.33 ~ MOB ~ P 05:20 - 07:00 I 1.671 MOB I P 07:00 - 10:30 3.50 MOB P 10:30 - 11:45 1.25 MOB P 11:45 - 17:00 I 5.25 I M08 I P 17:00 - 23:00 I 6.001 BOPSUR P 23:00 - 00:00 1.00 BOPSU P 1/11/2007 00:00 - 07:00 7.00 BOPSU P 07:00 - 12:00 5.00 BOPSU P 12:00 - 16:15 4.25 BOPSU P 16:15 - 17:30 I 1.251 BOPSUR P 17:30 - 18:30 I 1.001 BOPSUR P 18:30 - 19:45 I 1.251 BOPSUR P 19:45 - 20:00 0.25 BOPSUFj P 20:00 - 00:00 4.00 CLEAN P 11/12/2007 100:00 - 01:00 I 1.001 CLEAN I P Spud Date: 1 /3/2007 Start: 1 /10/2007 End: 2/8/2007 Rig Release: 2/8/2007 Rig Number: Phase ~ Description of Operations PRE Safety mtg re: move off well PRE Move off of 1C-01 after removing ESD from 1C-17 and rewarming rig hydraulics. Move to center of Pad. PU handiberm, plywood and cellar dikes. Post Pad inspection w/ DSO. Safety mtg re: move rig to 2Z-13 PRE Move rig down the Pad and onto 1 C access road. Move to the west end of the KOC pad by 0520 hrs. Set rig down for Kuparuk AM crew change PRE Wait for Nordic crews and Kuparuk Field personnel to change out. PJSM on crew change. PRE Moved rig from Kupuark KOC to DS2Z-13 PRE Held PJSM and RU the handi berb and rig mats around the well. PRE Made ready to move rig ove well and found hydraulic leak on the drive system Spill approximately 10 gal of hydraulic fluid into their containment barrier around the drive motor. Clean up mess and refill w/ hydraulic fluid. Move rig over 2Z-13 tree and set down WEXIT Accept rig for operation at 1700 hrs 1/10/2007 NU BOPE Move office camp, TL camp and rig camp from 1 C Pad Offload KWF and one load of fresh mud in uprights Kup telecom personnel AOL @ 2100 hrs w/dish on trailer along w/ a generator. Before final hookup of Kup comms, decide to try current BP system. Hans from MPU tuned us in to the Z Pad tower and got comms and data! W III need to raise antenna for other half of lines tomorrow. This setup should also work on 2D Pad for the next well WEXIT Fill stack w/ water. Begin BOPE test WEXIT Initial BOPE test. AOGCC waived the right to witness WEXIT Working to unthaw the choke and kill line. Finished RUWorking on SLB's traction motor. RU Vetco Gray to pull BPV with lubricator. Found ice in the SV area WEXIT Worked on removing ice from tree and pulling FMC BPV with Vetco Gray. Unable to pull BPV using Vetco Gray, released them and FMC tec is in route to rig Electrican working on SCR3 WEXIT Working at removing BPV with FMC Unable to get latch on BPV. Trash on top of the BPV. Lost pluck /SCR Silicon Controlled Rectifiers in # 3. Will have to call IPS in Texas to find replacement part. WEXIT RU to jet the trash off BPV. Loading CT with SW, then jet trash off BPV. Recovered a few pieces of rubber over shaker. Set back injector WEXIT RU FMC lubricator and pull BPV first try. No pressure noted on well, LD load out lub and tools WEXIT Safety mtg re: slack management WEXIT PT inner reel valve ~ 4000 psi. Blow CT back w/ air. Cut off CTC. Change packoff. Dress stub/wire to reverse. Reverse slack into reel. Blow CT back w/ air. Cut off 250' of CT and 223' wire. Install CTC. PT 35k, 4000 psi. Head up BHI WEXIT Fin slack management and head up BHI. Resume circ CT over bung hole Printed: 2!12/2007 10:14:15 AM BP Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours ' Task ~ Code NPT 1/12/2007 01:00 - 01:15 0.25 CLEAN P 01:15 - 01:45 0.50 CLEAN P 01:45 - 03:00 1.25 CLEAN P 03:00 - 04:30 1.50 CLEAN P 04:30 - 06:00 1.50 CLEAN P 06:00 - 12:30 6.50 CLEAN P 12:30 - 12:40 0.17 CLEAN P 12:40 - 14:00 1.33 CLEAN P 14:00 - 15:00 15:00 - 17:00 17:00 - 20:00 20:00 - 22:00 22:00 - 23:00 23:00 - 00:00 1/13/2007 100:00 - 03:00 03:00 - 03:30 1.00 CLEAN P 2.00 STWHIP P 3.00 STWHIP P 2.00 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 3.00 STWHIP N 0.501 STWHIPIN 03:30 - 04:15 0.75 STWHIP N 04:15 - 06:35 2.33 STWHIP N Page 2 of 28 ~ Spud Date: 1 /3/2007 Start: 1/10/2007 End: 2/8/2007 Rig Release: 2/8/2007 Rig Number: Phase Description of Operations WEXIT Safety mtg re: MU BHA WEXIT Open up to well and find no pressure. MU milling BHA (2.74" D331 w/ MWD assy) WEXIT Unable to get BHA below 22'. Looks like SSV won't stroke fully open. Steam the tree and cycle SSV. Install fusible cap. GPB Level 1 w/ -60CF. Set BHA in wellbore. Stab on w/ tubs. Check spacing for pressure undeployment at 2.6' WEXIT RIH w/ BHA #1 circ thru mill 0.55/300 while take diesel returns to tiger tank WEXIT Tag at 8000' CTD. PUH 26.6k. Start motor 1.4/1950 and stall two times before getting a pattern established. Drill hard cement from 7998.9' at <20'/hr. Swap returns to pits after disposing of 110 bbls of returns. Drill ~ 1.4/ 1980 w! 3-400 psi dill, 1.2k wob w/ 9.9 ECD WEXIT Drilling Cement HArd at 8130 ft, PM #11 Bad Discriminator Pump 10 bbl biozan pills OA/IA at 700 / 551 psi. RU to blow down to TT. TD mill at 8183 ft MD. Reaming out cement area. WEXIT Stopped at 8,050 ft and PT the casing to 900 psi and pressure curve was straight lined WEXIT POOH chasing cement to surface. Temp = -25f Winds at 35mph and Phase II on roads and Pads in CPF2 Asset area WEXIT OOH, flow check, OK, unstab lubricator and stand back in bung hole LD tool and make ready BHI tool if required to assist in setting the whipstock. Refurbishing MP# 1 WEXIT RU SLB Eline to run tie-in log. Install 7" Otis X 5-1/2" cross-over forpackoff. WEXIT RIH with GR/CCL togging tool to 8173' ELMD. Log up hole to 7700'. POOH WEXIT RU WFT 3-1/2 LSX WS w/ BTT #10 Hyd Setting tool on SWS tool string WEXIT SWS RIH w/ WS to set down at 45'. POOH w/ tool and had ice on bottom. Rig RIH w/ two jts 1"CSH. Steam wellbore. POOH LD CSH. WEXIT RIH w! WS as before and set down at same spot. Found that centralizer at top of tool string was not collapsing because operator was not running in hole fast enough. RIH w/ WS DPRB WEXIT Phz 1/2 -13F, 20-35 mph W, -37CF Continue RIH w/ W FT WS on eline. Hung up at 7884' W LM and couldn't go either direction. Pull 70% of weak point at 1650# after 30 min and came free. POOH w/ WS. LD WS assy complete in pipeshed. SWS a-line personnel out of hours. Wellbore needs cleanout run DPRB WEXIT Steam frozen kill line then blow down while wo string reamer from WFT DPRB WEXIT MU cleanout BHA DPRB WEXIT RIH w/ BHA #2 (2.80" tapered mill + 2.81" string reamer + straight motor) circ thru mill 0.5/370 Saw some wt at 7888 ft while RIH at 0.4 bpm. PU and Washed through at 1.65 bpm. While circulating, lost out returns and out density on micro motion. LEL monitors didn't go off. Circulate well bore and wash to bottom. After 10 minutes, MMin = MMout and same with density Printed: 2/12/2007 10:14:15 AM BP Operations Summary Report Page 3 of 28 Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code ~ NPT ~ Phase Description of Operations 1/13/2007 04:15-06:35 2.33 STWHIP N DPRB WEXIT 06:35-11:05 4.50 STWHIP N DPRB WEXIT 11:05-11:16 0.18 STWHIP N DPRB WEXIT 11:16-12:45 1.48 STWHIP N DPRB WEXIT 12:45 - 13:45 I 1.001 STWHIPI N I DPRB I WEXIT 13:45 - 15:10 1.42 STWHIP N DPRB WEXIT 15:10-15:25 0.25 STWHIP N DPRB WEXIT 15:25 - 16:47 1.37 STWHIP N DPRB WEXIT 16:47-17:10 0.38 STWHIP N DPRB WEXIT 17:10 - 17:30 0.33 STWHIP N DPRB WEXIT 17:30-18:30 1.00 STWHIP N DPRB WEXIT 18:30-21:30 3.00 STWHIP N DPRB WEXIT 21:30-23:00 1.50 STWHIP N DPRB WEXIT 23:00-23;45 0.75 STWHIP N DPRB WEXIT 23:45 - 00:00 0.25 STWHIP N DPRB WEXIT 11/14/2007 00:00 - 01:30 1.50 STWHIP N DPRB WEXIT 01:30-03:15 I 1.751STWHIPIN (DPRB (WEXIT 03:15-03:50 0.58 STWHIP N DPRB WEXIT 03:50 - 05:30 1.67 STWHIP N DPRB WEXIT 05:30-06:40 1.17STWHIPN (DPRB (WEXIT 06:40-08:00 1.33 STWHIP N DPRB WEXIT 08:00 - 08:45 0.75 STWHIP N DPRB WEXIT 08:45 - 08:55 0.17 STWHIP N DPRB WEXIT 08:55-09:301 0.58~STWHIP~N DPRB WEXIT PVT = 149 bbl W/R to bottom at 1.67 bpm still seeing the erratic out flowrate while RIH. Saw some motor work at: Mandel # 9 at 7,888 ft Mandel #10 at 7,961 ft, Leaky blast ring area at 7,999 ft. Stalled twice while cleaning out and final) washed through with some motor work. PU at 8,001ft, clean to 7,993 ft. RIH. Stall at 8,002 ft, Stall at 8,004 ft. Stall at 8,086 ft. Stall at 8,130 ft, 8,131 ft; 8132 ft; 8,135 ft; 8136 ft Prod Mandel #11 (Bent Discriminator). Could be pushing something a head of us. SD pump and RIH, tagged at 8148 ft, PUH and wash down. Stall at 8,155.5 ft (Pert 3-1/2" Pup Jts) Stalled 8161 ft; 8163 ft, 8164 ft Reamed and backed reamed, clean POOH chasing biozan out of hole Held PJSM while POOH to change mills. RIH 1.7 ft to simulate pressure deploying BHA. Close 2-3/8" combi's and set at 3000 psi, Strip off well and check BHA (2.6 ft slack off for pressure deploying BHA. Changed out mills to 2.74" RIH with 2.74" mills Washed from 8164 ft at 1.64 / 1.64 bpm and a CTP = 2165 psi. Tagged 8172 ft with 300 psi motor work and then fell off. . W/R from 8172 ft (lip) to 8184 ft, Back reamed 3 times clean, and left biozan in this section POOH LD BHA PJSM on RU SLB and WFT Whipstock RU SLB RIH w/ WS on a-line. Take +/-15 min each to get by last 3 GLM's and MO Ext. Get bottom of WS to 8152', but need it to be at 8156' otherwise we will mill part of MO Ext and XO below it. Can't determine if tool is setting down at D nipple, or more likely centralizer is hanging up at btm GLM POH to reconfigure tool string Inspect tool string-no marks. Had cement at bottom of the WS. Add 6' of 1-11/16" stem below centralizer and above orientor RIH w/ WS on a-line Continue RIH w/ WS on a-line. Work by same mandrels. Get bottom of WS to same depth as before, 8153'-need 3' more POH. LD toolstring in pipeshed. More cement on the bottom of tools. RD SWS sheaves and send personnel in for rest MU BHA (2.74" tapered mill w/ 2.74" string reamer) RIH w/ BHA #4 circ thru mill 0.44/290 clean to tag at 8184' CTD PUH 30.8k, start pump 1.47bpm 2030 psi . Ream and backream from 8,000' to TD Circulated up gas from bottomhole. Pump bio sweep POOH to rerun WFT WS LD Mill / FCO BHA Held PJSM with Crews and discussed the hazzards associated with RU Eline on Nordic 2 RU Eline, High sided WS to setting tool Printed: 2/12/2007 10:14:15 AM • • BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2Z-13 2Z-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1 /10/2007 Rig Release: 2/8/2007 Rig Number: Date From - To I Hours I! Tas~Code NPT I Phase -- _ _ _ _ -~ 1!14/2007 ~ 09:30 - 13:00 3.50 ! STW HIP! N DPRB !WEXIT 13:00 - 15:45 I 2.751 STWHIPI N I DPRB IWEXIT 15:45 - 16:15 0.50 STWHIP N DPRB WEXIT 16:15-18:30 2.25 STWHIP N DPRB WEXIT 18:30-00:00 I 5.501STWHIPIN I IWEXIT 1/15/2007 100:00 - 02:40 I 2.671 STWHIPI N I DPRB IWEXIT 02:40-04:15 1.58 STWHIP N DPRB WEXIT 04:15 - 05:45 1.50 STWHIP N DPRB WEXIT 05:45 - 08:05 2.33 STWHIP N DPRB WEXIT 08:05-09:10 1.08 STWHIP N DPRB WEXIT 09:10-10:40 1.50STWHIPN DPRB IWEXIT 10:40 - 12:00 1.33 STWHIP N DPRB WEXIT 12:00-14:30 2.50 STWHIP N DPRB WEXIT 14:30 - 15:55 1.42 STWHIP P WEXIT 15:55 - 16:40 0.75 STWHIP P WEXIT 16:40-16:51 I 0.181STWHIPIP I IWEXIT 16:51 - 18:20 1.48 STWHIP P WEXIT 18:20 - 19:25 1.08 STWHIP P WEXIT Page 4 of 28 Spud Date: i /3/2007 End: 2/8/2007 Description of Operations RIH with SLB's WRP tool and WFT Whipstock Logged and tie in. Made corrections. RIH and set down at 8155 ft which is the D Nipple. PUH and tie iin again and tagged at the same place, 8155'. This puts the top of the WS 2 ft into the Mill out Extension below the packer. Tried several things including turning TF around and still was unable to get below the D Nipple. Call HTC fora 2.8" DSM. POOH with WS Stand back loggers Make ready to PU 2.80" mills. MU 2.8" Parabolic Mill and 2.81" string mill RIH with 2.8" mill BHA Tagged at 8,167 ft. PUH Milling up D Nipple slowly Starting at 8,165.66 ft Op = 1.60 / 1.59 bpm at CTP 2,273 psi Stall at 8,165 ft Taking some time to get started 8165.05 ft Continue milling D nipple 1.68/2460. Unable to drill w/dill, wob or time w/o stalling. Drill using 0.01'/10 min. Were at 8165.10' at 1830 hrs, but had numerous early stalls and lost ground to 8164.81'. By midnite were at 8164.90' and actually getting 500# drilloffs in 10 min Continue milling D nipple from 8164.9' making slow hole to 8164.95'. Start pushing too hard and had several stalls. Remill from 8164.31' to 8165.0' 1.5/2000. Had more stalls, total is 30. Assuming the cutrite SR may be too aggressive and is causing the stalls. Time to change motor anyway POOH circ thru mill 1.53/1900 to check mill/motor OOH. Inspect 2.80" D331 and it appears to have cut the nipple and still drifts 2.80". SR shows virtually no wear, except for in a couple spots on the largest OD. HCC does not have another 2.80" D331 (or close). Remove SR, add fresh motor and rerun the 2.80" D331 Adjust gooseneck RIH w/ BHA #6 Started milling at 8.165.40 ft, working down at 0.05 ft and numerous stalls. Loggin Tie-in down from 7980 ft to 8,110 ft. Corrected -10 ft as per the SLB Jewelry Log ran 1/12/2007 Tagged at 8,156ft. TOWS is thertically at 8,147.3 ft, which is the top of the 8 ft 3-1/2" pup joint. POOH Held PJSM while POOH OOH, check for flow, (OK) LD milling BHA and RD SLB Eline. Woody sighting. Loading BOT WS into the pipe shed. Install RA tag in WS at 5.3ft from the top. With EDC open, set counters and RIH with BOT's RWS WS Tied in from 8,000 ft to 8,055 ft and cporrected -10 ft. Confirmed correction WT check at 8,054 ft = 31.5k at 20 fpm Set bottom of WS at 8157 ft TOWS at 8148 ft Working to pressure set WS, Cycled pumps 5 times and finally the WS set at 4600 psi 2LHS Toolface. TOWS at 8,148.3 ft and RA Marker at 8,153.60 ft POOH LD BTT WS setting tool and BHI MWD tool. MU WFT milling assy on BHI MWD assy Printed: 2/72/2007 10:14:15 AM BP Operations Summary Report Page 5 of 28 ~ Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date !From - To Hours Task Code NPT i Phase ; Description of Operations 1/15/2007 19:25 - 20:50 1.42 STWHIP P WEXIT RIH w/ BHA #8 (2.74" WM and SR on WFT motor) circ thru mill 0.59/570 20:50 - 21:50 1.00 STW HIP P WEXIT Log tie-in down from 8000', corr -10' Repeat tie-in and got -2' corr 21:50 - 22:45 0.92 STWHIP P WEXIT RIH and lost wt at 8149.1'. PUH 28.9k, start motor 1.6/2700. Park 1' above WS for 10 min 1.6/2700. Ease in hole and first MW @ 8148.3' which was the tied in setting depth of the TOWS. Flag CT and motor stalled. PUH w/ 4k overpull, then clean. Continue PUH and started getting pressure cycles thru motor and acting like motor is stalled (1.5/3800). More like motor is chunking out ... ? PUH and pressure slowly dropped by 8040' to new press/rate of 1.54/2930 and assume must have been trash. RBIH 22:45 - 23:15 0.50 STWHIP P WEXIT Pressure returned to normal at 1.55/2755 while ease back in hole to stall at 8148.0'. PUH w/ 5k overpull. Ease back in hole to first MW and w/flag at 8148.0' ', 23:15 - 00:00 0.75 STW HIP P WEXIT Mill window from 8148.0' according to W FT rep. At 8149.0' at midnite 1/16/2007 00:00 - 04:15 4.25 STWHIP P WEXIT Continue milling from 8149.0' to 8153.0' 1.55/2400 while pumping 10 bbl biozan pills each hour. Good metal on magnets, milled like textbook. From 8152.0'+ appear to be on 7" 04:15 - 05:15 1.00 STWHIP P WEXIT Pump 10 bbl pill, then ream and backream window area prior to POOH 05:15 - 06:39 1.40 STWHIP P WEXIT POOH for window milling assy #2 (for 2 strings) , Held PJSM on BHA handling 06:39 - 07:55 1.27 STW HIP P WEXIT LD straight motor BHA Gauged at 2.74" (tight). Found stator rubber in jets 07:55 - 09:20 1.42 STWHIP P WEXIT RIH with #2 window ext BHA (2.5 deg motor) 09:20 - 09:45 0.42 STWHIP P WEXIT Logged tie-in and corrected - 10 09:45 - 09:55 0.17 STWHIP P WEXIT Close EDC and RIH and orient TF 15 R HS ~~ 09:55 - 12:30 2.58 STWHIP P WEXIT Milling window as per WFT. Yellow flag at back of counter i Started 8153.60 ft to 8155.12 ft Op = 1.69 / 1.69 bpm at 3000 psi on btm PVT = 140 bbl's 12:30 - 15:00 2.50 STWHIP P WEXIT Milling window at 8155.12 ft to 8157' Started 8153.60 ft to 8155.12 ft Op = 1.69 / 1.68 bpm at 3050 psi on btm 15:00 - 17:30 2.50 STWHIP P WEXIT Drill open hole in B shale from est BOW at 8157.0' 1.7/2760/10L slowly w/ 400 psi dill, 5-7k wob. Swap to used Flo Pro mud. Ream 7" exit area. 17:30 - 18:30 1.00 STW HIP P WEXIT Ream window area some more. Dry run thru window was clean 18:30 - 20:15 1.75 STWHIP P WEXIT Open EDC. POOH circ 1.35/2400 20:15 - 21:00 0.75 STWHIP P WEXIT LD milling BHA. Mill was gauge and had little wear 21:00 - 00:00 3.00 DRILL P PROD1 Displace CT to FW while over bung hole. Stab on, blow CT back w/ air. Cut off CTC. Fill CT then reverse slack back (twice). Cut off 21' CT. Dress stub 1/17/2007 00:00 - 02:00 2.00 DRILL P PROD1 Install CTC and PT CQ3 35k. Head up BHI. PT @ 4000. 02:00 - 03:30 1.50 DRILL P PROD1 Function test BOP rams as part of bi-weekly BOPE test MU build BHA. Circ CT to mud over bunghole 03:30 - 05:15 1.75 DRILL P PROD1 RIH w/ BHA #10 (2.6 deg motor, used bi bit) circ thru EDC 0.3/800. Set down at 7850' in packer. Orient to get by Printed: 2/12/2007 10:14:75 AM • i BP Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA .Rig Name: NORDIC 2 Date From - To Hours Task ; Code ~ NPT a i -- __ ~ 1/17/2007 05:15 - 05:35 0.33 DRILL P 05:35 - 06:05 0.50 DRILL N Start: 1 /10/2007 Rig Release: 2/8/2007 Rig Number: Page 6 of 28 ~ Spud Date: 1/3/2007 End: 2/8/2007 Phase ~ Description of Operations PROD1 PROD1 06:05 - 07:45 1.67 DRILL N PROD1 07:45 - 08:00 0.25 DRILL N PROD1 08:00 - 09:00 1.00 DRILL P PROD1 09:00 - 10:30 1.50 DRILL P PROD1 10:30 - 10:45 0.25 DRILL P PRODi 10:45 - 13:45 3.00 DRILL P PRODi 13:45 - 15:45 I 2.001 DRILL I P 15:45 - 17:10 1.42 DRILL P 17:10 - 17:45 0.58 DRILL P 17:45 - 18:30 0.75 DRILL P 18:30 - 20:00 1.50 DRILL P 20:00 - 20:20 0.33 DRILL P 20:20 - 20:35 0.25 DRILL P 20:35 - 00:00 3.42 DRILL P 1/18/2007 00:00 - 02:50 2.83 DRILL P 02:50 - 03:15 0.42 DRILL P 03:15 - 05:30 2.25 DRILL P 05:30 - 10:45 5.25 DRILL P 10:45 - 11:05 0.33 DRILL P 11:05 - 13:00 1.92 DRILL P 13:00 - 13:30 13:30 - 14:15 14:15 - 14:40 14:40 - 16:00 16:00 - 16:20 16:20 - 17:30 17:30 - 18:00 0.50 DRILL P 0.75 DRILL P 0.42 DRILL P 1.33 DRILL P 0.33 DRILL P 1.17 DRILL P 0.50 DRILL P 18:00 - 20:15 2.251 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Log tie-in down from 8000', corr -9' RIH to set down at bottom of window at 8157' and could not work by w/multiple attempts Open EDC. POOH for crayola mill PJSM - UD build BHA and P/U crayola mill(BHA #11} VD build BHA. changeout injector packoff. P/U crayola mill. RIH with BHA #11. Tie in around 8000'. Correct -8'. RIH to window depth. Attempt to mill out the bottom of the window. Multiple stalls ~ 8157 with very slow approaches. Progress made using increments of .01' while increasing and decreasing pump rates - 8156.70 - 8158.0. Able to move to bottom of the openhole section 8167'. Backream up thru hole at 2'/hr at various orientations - 45 degrees LOHS, 45 ROHS, 75 ROHS, 75 LOHS, 105 LOHS, 105 RHS. Pass thru dry, max WOB of 500 Ibs going thru. POH to UD BHA #11 and P/U build BHA. PJSM for BHA changeout prior to reaching surface. LD crayola milling assy. Mill looked okay. MU build BHA RIH w/ BHA #12 (2.6 SR motor, used bi bit) circ thru EDC 0.5/1400 Log tie-in down from 8000', corr -9' to PDC. Close EDC RIIH 0.25/1000 thru window, clean to tag at 8166'. PUH 26k, start motor PVT 315 Drill from 8166' 1.60/3150/10L-80L w/ 50-250 psi dill, 1-5k wob w/ 11.0 ECD while concentrate on 180 deg LH turn. See RA pip at 8156.0' and tie all depths to it (ie TOWS -5.3'=8150.7'=-8151'). Drill to 8257' w/ two wipers Continue drilling from 8257' 1.6/3300/85L w/ 100300 psi dill, 1-4k wob w/ 11.2 ECD to 8330' Geowiper was clean both directions PVT 313 Need to build quicker since target is 10' TVD higher due to unexpected faulting PVT 314 Drill from 8330' 1.59/3320/30L and get in a hard spot. Hopefully this is the 5' TVD of Ankerite on top of the target sand. NBI is 88 deg so have cut -2.5' so far. Drill from 8355' 1.56/3300/105L. Fluctuating between ankerite and sand. Very slow ROP's in the ankerites. Drilling break up to 30' per hour at 8389. Drill to 8400' and pull for lateral assembly. POOH to LD build assembly and PU lateral assembly. PJSM to changeout tools just prior to reaching surface. LD build assembly(BHA#12). Bit graded 1-2. Insert resistivity tool and initialize. PU lateral assembly(BHA#13). RIH with lateral assembly. tie-in to depth logs. Correct -8'. MAD pass hole with resistivity, downward at 250'/hr Wiper back to window. Trip gas coming up. Circulate trip gas to surface while perform wiper back to TD at drilling rate PVT 334 Drill from 8400' 1.54/1.5/3270/30L-90L w/ 100-300 psi dill, Printed: 2/12/2007 10:14:15 AM ~ ~ BP Operations Summary Report Page 7 of 28 ~ Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To I Hours Task Code NPT ~ Phase Description of Operations 1/18/2007 18:00 - 20:15 ~ 2.25 ~ DRILL ~ P ~ ~ PROD1 1-3.5k wob w/ 11.1 ECD while level out to stay at 5980' TVD. 20:15 - 20:40 0.42 DRILL P PROD1 20:40 - 00:00 3.33 DRILL P PROD1 1/19/2007 100:00 - 02:20 I 2.331 DRILL I P I I PROD1 02:20 - 03:00 I 0.671 DRILL I P I I PROD1 03:00 - 06:00 3.00 DRILL P PROD1 06:00 - 07:05 1.08 DRILL P PROD1 07:05 - 08:30 1.42 DRILL P PROD1 08:30 - 11:10 I 2.671 DRILL I P I I PROD1 11:10 - 12:20 1.17 DRILL P PROD1 12:20 - 14:50 2.50 DRILL P PROD1 14:50 - 15:00 0.17 DRILL N SFAL PROD1 15:00 - 17:10 2.17 DRILL N PROD1 17:10 - 17:45 0.58 DRILL N PROD1 17:45 - 18:30 0.75 DRILL N PROD1 18:30 - 20:10 1.67 DRILL N PROD1 20:10 - 00:00 3.831 DRILL N 1/20/2007 00:00 - 00:15 0.25 DRILL P 00:15 - 03:50 3.58 DRILL P 03:50 - 05:25 I 1.581 DRILL I P Drill to 8520' and are apparently on an ankerite streak w/ geo wanting to go up Wiper to window while geodecide was clean PVT 324 Drill from 8520' 1.54/1.54/3200/160L w/ 100-250 psi dill, 1-3k wob w/ 11.12 ECD and will point TF down to follow the dip and hold 87 deg. Drill to 8624' in and out of hard streaks w/ GR avg of 58 api in A4 PVT 318 Continue drilling from 8624' 1.63/3250/90L in a hard streak. Break out at 8635' and drill to 8680'. Seem to be bumping up against the ankerite every time TF is pointed above 80L. Consequently, slow progress until TF is pointed down. Drill to 8680' Wiper to window was clean. Wiper back to TD had set downs at 8248' and 8550' w/ TF 60 deg off PVT 187 after take off mud prior to mud swap. Mud has turned dark brown due to the tar zone we are drilling Drill from 8680' 1.53/1.45/3100/80L w/ 100-300 psi dill, 1-3k wob w! 11.09 ECD and appear to have drilled into the A4 shale. Point TF HS @ 0545 hrs at 8800' (5998' TVD). Drill to 8810' Wiper to window Drilling ahead. 1.60/1.56/3340lTF340-285. 11.07 ECD on bottom drilling. 1-1.2k wob. Swapped for new FloPro, 450 bbls. Bled off IA from 650psi down to 140psi. Drilled to 8870'. Drilling ahead. 90-91 degrees inc. 1.60/1.56/3340/TF285. 11.07 ECD. 50' wiper trips. -40'/hr ROP. Progress slowed near end. Drilled to 8945'. W iper trip to window. Drilling ahead. 1.59/1.57/3200/TF300. 10.8 ECD. PVT 319bb1s. Very slow ROP's thru ankerite. Lost power to Inteq computers, and as a result lost data screens at surface. Drilling ahead. 1.60/1.58/3250lrF0285. Very slow drilling through ankerite. Inteq still having problems with UPS(Uniterupted power supply) for computers. Able to drill ahead due to slow ROP's. Drilling ahead. 1.60/1.58/3250/TF0285. Very slow drilling through ankerite. Freespin jumped from 3150psi to 3540psi. Pull to look at motor and bit. Wiper to window. Open EDC at window. POOH circ thru EDC 1.7/3050 while follow pressure schedule to control open shales w/ EMW=11.0 by RP. Safety mtg re: pressure undeploy Tag up w/ 700 psi (11.0 ECD). WHP immediately began slowly bleeding off to formation PVT 277 Close EDC Pressure undeploy by procedure. Final whp was 305 psi and stable for 50 min. Found mousehole frozen so broke down BHA in pieces Safety mtg re: pressure deploy MU BHA and pressure deploy w! 280 psi whp. Replace hose to lubricator packoff after it was found to leak RIH w/ BHA #14 (1.0 deg) circ thru bit 0.5/1700 following PROD1 PROD1 PROD1 PROD1 Printed: 2/12/2007 10:14:15 AM ~ ~ BP Operations Summary Report Page 8 of 28 ~ Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/20/2007 03:50 - 05:25 1.58 DRILL P PROD1 pressure schedule 05:25 - 05:45 0.33 DRILL P PROD1 Log tie-in down from 8000'. Corr -8'. 05:45 - 06:30 0.75 DRILL P PROD1 RIH thru window, clean. RIH to 8310' and set down. RIH at slower speed thru build section, clean. 06:30 - 10:00 3.50 DRILL P PROD1 Drilling ahead. 1.62/1.59/3420lfF0300. FS 3300psi. ECD 11.13. ROP's 5-10'/hr. PVT 306bb1s. 10:00 - 15:00 5.00 DRILL P PROD1 Drilling ahead 1.62/1.58/3320/60L-120LTno high of TF and 15:00 - 17:00 2.00 DRILL P PROD1 17:00 - 18:45 1.75 DRILL P PROD1 18:45 - 19:30 0.75 DRILL P PROD1 19:30 - 23:00 3.50 DRILL P PROD1 23:00 - 23:30 I 0.501 DRILL I P I I PROD1 23:30 -00:00 0.50 DRILL P PROD1 1/21/2007 00:00 - 00:20 0.33 DRILL P PROD1 00:20 - 00:45 I 0.421 DRILL I P I I PROD1 00:45 - 01:25 I 0.671 DRILL I P I I PRODi 01:25 - 03:00 I 1.581 DRILL I N I DPRB I PROD1 03:00 - 05:00 2.00 DRILL N PROD1 05:00 - 05:30 0.50 DRILL N PROD1 05:30 - 06:00 0.50 DRILL N PROD1 06:00 - 06:45 0.75 DRILL N PROD1 06:45 - 07:10 0.42 DRILL N PROD1 07:10 - 09:00 I 1.831 DRILL I N 09:00 - 10:45 I 1.751 DRILL I N can make hole, too low and is slow going. Mostly slow going so we don't blow thru the top of the sand PVT 296 Drill from 9060' and penetration rate has picked up. Drill to 9140' W iper to window was clean at 25'/min. Wiper in hole was clean to set down at stall at 9040' Ream to bottom w/ numerous stalls 9040-9060' PVT 280 Drill from 9140' 1.63/1.59/3340/90L at 92 deg in the A5 shale planning to intersect the next fault at 9300' and enter the A4 sand. Steady 40'/hr progress. See resistivity change +X8 at 9235', but no PR change W iper to window. Overpull and MW at 9070'. RBIH, then slow backream. Got bit stuck at 9050'. Took several tries to get free. Slow backream to 9020' before pulling clean Continue wiper to window Continue wiper to window. Start pulling tite w/ MW at 8258'. RBIH, clean. Wiper to window at 7'/min from 8260' and was real sticky and packing off until past 8230'. Had full returns past 8230', but still sticky w/ MW. Pull thru window, then POH to 8000' Log tie-in down from 5000', Corr +4' Geo's decide to continue building angle once at TD looking for A4 sand RIH clean thru window. Slow wiper back thru build and set down at 8254' at DTF. Red rate to 0.5 bpm and hold 11.5 ECD w/ choke. Spud at various TF's and cannot get by. This is interface of bottom of B shale and A5 shale w/ A6 faulted out. The 1.0 deg motor will not follow the 2.6 deg hole in incompetent formation Pull thru window, open EDC. POOH circ 1.6/3000 for larger bend motor for cleanout run following pressure schedule for 11.0 ECD Safety mtg re: pressure undeploy Pressure undeploy w/ 470 psi Adjust motor, remove res tool Pressure deploy BHA SD for tour change out. Hold PJSM for pressure depoloying BHA. Step thru proceedure. Discuss hazards. Discuss job assignments. Discuss trainee hand expectations, and minimizing extra hands on the rig floor. Pressure Deploy cleanout BHA. Pick up 1.7 deg motor, rebuilt Hughes Bicenter. Deploy with no incidents. First pressure deployment this year for this crew in Kuparuk. Shallow hole test of BHA #15. No problems. RIH with open EDC, pumping at 0.25 BPM. PVT=223 bbls. Order 150 bbls PROD1 PROD1 Printed: 2!12/2007 10:14:15 AM g p Page 9 of 28 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~! Name: 2 ell Name: 2 e: Name: From - To ~ Z-13 Z-13 REENTE NORDIC NORDIC Hours ~ R+COM CALIST 2 Task ~ PLET A Code I E NPT ~ 1/21/2007 09:00 - 10:45 1.75 DRILL N 10:45 - 11:05 0.33 DRILL N 11:05 - 12:15 1.17 DRILL N 12:15 - 12:30 0.25 DRILL N 12:30 - 13:00 0.50 DRILL N I 13:00 - 13:50 0.83 DRILL N 13:50 - 14:40 0.83 DRILL N Spud Date: 1/3/2007 Start: 1/10/2007 End: 2/8/2007 Rig Release: 2/8/2007 Rig Number: Phase Description of Operations PROD1 additional mud. I,O,T=0,265,650. Following pressure schedule while RIH. PRODi Log tie in pass over GR charecter at 8000'. Make -6' correction. PROD1 Shut the EDC, orient to "As drilled" toolface and RIH thru the window. No problems at window. RIH, pumping minimum rate at 0.35 bpm. Holding 560 psi on WHP with choke. Holding "As Drilled" TF in open hole. (90 deg LOHS at 8250') RIH slow, it was slick until tag up at 8255'. PU and tag "dry" several times. No progress. Same depth each time. Clean PU each time. See DHWOB sensor each time. We are definately tagging up with the bit. Tag up and stack weight on it dry several times. 4400 Ibs on DHWOB. No luck. Adjust tool face to 45 deg LOHS. PU, and RIH dry. Tag up several times at the same place. Adjust tool face to 0 deg, high side. RIH dry. Tag up solid. 5600# DHWOB. Repeat set downs several times at high side orientation. DD reports they have been successful previously on this well at 150L. Try it with pumps down. Tag up several times. PU, orient to 45L. RIH dry, tagged up, then fell thru to 8264', then hit with a mushy bottom. PROD1 Bring pumps up to 1.5 bpm, try to work down hole. Weight fell off quickly. It appears that we had a ledge at 8255', then some junk in the hole below that. Wash down, chasing something as seen on DHWOB sensor. Tag at 8277'. PU sticky. Continue trying to wash thru junk. Packing off. 1.5/0.6 bpm. Continue washing down thru junk. Trying not to pickup above ledge at 8255'. Finally made it down thru the junk. Clean down to 8323', then set down again. Returns errattic, but mostly 1.50/1.0. PROD1 Start mixing high vis sweep. Make mini wiper up to chase the debris OOH. Returns errattic on mini wiper. Pull up to 8265', at 8 fpm, staying below ledge. Weight on wiper draggy, but never over 30 klbs. Normal up weight 25 klbs. Able to work up hole, but still packing off, and can't run back down. Decide to continue wiper up past ledge at 8255', chasing debris up to window. Cleaned up as we got the last 50' below the window. Geo reports bottoms up sample is light brown in color and is either from the Bi , or A5 shales. There is no sand present in the sample. PROD1 RBIH, TF 45 LOHS. Pumps at 1.56/1.60. Clean down from the window at 6400 Ibs string wt, 540 Ibs DHWOB. Tag up at 8255', drop pumps to 0 immediately. PU and RIH dry. Tag up hard at 8255'. Repeat 6 times with no success. Clean PU's and solid set downs. PU, bring pumps to 0.35 bpm. RIH, TF=45L, tag up at 8255'. Roll pumps up momentarily. No luck. Orient to 145L, RIH, tag up 2 times, Orient to 45L and RIH. Tag up at 8255'. Repeat, made it thru finally. (Whew!). Kick pumps on to 1.3 bpm, TF as drilled, RIH. PROD1 RIH, Pumping high vis sweep. Seeing ratty weight, looks like debris still. Returns 100%. Run down to end of build at 8400'. Holding "As drilled" tool face. Pump 20 bbls of high vis sweep to clean up debris in build section of hole. Chase it up to 8265'. Printed: 2/12/2007 10:14:15 AM BP Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Start: 1/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code NPT Phase ___- __ 1/21/2007 13:50 - 14:40 0.83 DRILL N PROD1 14:40 - 15:15 0.58 DRILL N PROD1 15:15 - 15:35 I 0.331 DRILL I N I I PROD1 15:35 - 16:00 I 0.421 DRILL I N I I PROD1 16:00 - 18:00 I 2.001 DRILL I N I I PROD1 18:00 - 20:20 I 2.331 DRILL I N I I PROD1 20:20 - 21:40 I 1.331 DRILL I N I I PROD1 21:40 - 22:15 0.58 DRILL N PROD1 22:15 - 23:45 1.50 DRILL N PRODi 23:45 - 00:00 0.25 DRILL N PROD1 1/22/2007 00:00 - 00:45 0.75 DRILL P PROD1 Page 10 of 28 Spud Date: 1 /3/2007 End: 2/8/2007 Description of Operations Clean, with 100% returns. The build section is ok. Bottoms up from sweep had lots of debris; mostly shale. Caught a sample for Geo. Sample was rounded pea gravel sized pieces of shale. It was not shale cuttings from drilling, but was consistent with shale sloughing. Shales look to be coming apart on us. RIH to clean out to TD. Clean from 8275' to 8500', slightly ratty but we washed thru. Clean down to 8790', tagged up hard. Work A4 shale at 8790'. Geo reports that latest bottoms up sample is from the A4 shale, and that some of the materal is shoughings, not cuttings. Note -The A4 shale is open in this lateral at at least 4 locations. It is not possible to identify which is the one that is contributing the sloughings. (Maybe all of them?) Continue to ream A4 clean at 8790'. Clean down to the start of the A4 shale at 9050'. Set down, reaming slowly. PU at 9064', had to pull 20 klbs over to get free. Yuck. Continue to work it. The A4 shale below 9050' is coming apart. We can't make any headway on cleaning it up. Got to 9064' ok, but no go past there. Call town to Cuss and discuss. Got thru 9064', got down to 9123'. Packing off. Heavy overpulls. Just about planted it. This hole is in very poor condition in the A4 shales. Pump 20 bbl high vis sweep. Chase it up hole to 8400'. Pump a 2nd high vis sweep at 9040'. Chase it up hole. hole is very clean up to 8255'. Pulled 44 klbs over at 8255', then ratty up to 8200'. Suspect shale in larger section of hole above ledge. INC at ledge 68 deg. Pump another 20 bbls of high vis sweep. Run back down to ledge to clean cuttings in 68 deg section of hole above dog leg. Did not see ledge, clean back down to 8300', pump 20 bbl sweep. Empty vac trucks for KW F and used mud AOL. PUH thru window, clean. Open EDC. Performed both using pressure schedule (held 11.0+ ECD). Resume circ while reciprocate at 5'/min between bit depths of 8000' and 8120'. Got bottoms up gas back that set off alarms. Continue to get life spots while circ 1.46/1.41/2650 w/ 11.0 ECD. Assume C Sand perfs behind straddle packers are leaking thru blast rings 8000-8097' again (and EDC is above this point). Begin recip between 8110' and 8150' to put EDC below assumed leak point. Take off used mud to make room for KWF while CBU 1.46/1.42/2740 w/ 11.07 ECD and no life spots PVT 177 With concern that the 10.5 ppg KW F may not be heavy enough, decided to lower pump rate to simulate KW F of 10.5 ppg after park CT at 8140' Red rate to 1.31/1.24/2520 and had 11.14 ECD after 27 bbls Red rate to 1.11/1.07/2230 and had 11.02 ECD after 20 bbls Red rate to 0.82/0.78/1820 and had 10.78 ECD after 15 bbls w/ no life spots Swap to KWF. Incr rate to 1.38/1.31/2610 POOH circ thru EDC 1.7/2640 pumping avg 10.35 ppg brine Check for flow/safety mfg LD drilling BHA Printed: 2/12/2007 10:14:15 AM BP Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Start: 1/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours . i Task Code NPT Phase 1/22/2007 00:45 - 01:00 0.25 ------ CASE P RUNPRD 01:00 - 01:30 0.50 CASE P RUNPRD 01:30 - 05:45 4.25 CASE P RUNPRD 05:45 - 07:45 2.00 CASE P RUNPRD 07:45 - 08:15 0.50 CASE P RUNPRD 08:15 - 08:30 0.25 CASE P RUNPRD 08:30 - 09:40 1.17 CASE P RUNPRD - ~ !-3 09:40 - 11:30 1.83 CASE P RUNPRD 11:30 - 12:00 0.50 CASE P RUNPRD 12:00 - 12:20 0.33 CASE P RUNPRD 12:20 - 12:40 0.33 CASE P RUNPRD 12:40 - 13:45 1.08 CASE P RUNPRD 13:45 - 14:10 0.42 CASE P RUNPRD Page 11 of 28 Spud Date: 1/3/2007 End: 2/8/2007 Description of Operations Safety mtg re: liner Bring BTT tools to floor. RU floor to run liner MU Unique indexing guide shoe on BTT 2 deg bent sub on one jt 2-3/8" solid liner w/ O-ring sub. MU a total of 16 jts 2-3/8" 4.44# L-80 STL solid and slotted liner w/o cementralizers. Set 2-3/8" combis. Install false table. RU and run 7 stds of 1" CSH out of derrick and space out. Work on little jerks. MU deployment sleeve and CTLRT. MU MW D assy w/ orientor RIH with liner string #1. Liner length = 509.27', total BHA length with MWD is 562.39'. Wait at window for morning call to complete. PJSM to discuss plan forward for running liner in open hole. Discuss GS operation, circulation proceedure to disconnect, splined GS limitations, etc. Weight check at the window. DHWOB=-2000 Ibs (Liner in tension), RIH wt = 10400 Ibs, PU wt = 29500 Ibs. Orient bent sub to high side. RIH with pumps at 0.2 bpm. RIH thru the window slick. Orient to 45deg LOHS, continue RIH at 15 fpm. 8232, bobble, fell thru. 8258, large wt loss, then fell thru. 8264', ratty weight, then cleaned up. DHWOB=-1000 Ibs. String wt=10400 Ibs. 8300', solid set down, fell thru, but ratty weight. Slow down to 150 fph at 8490' "bit depth", and start tie in log. Make -9' correction. Continue RIH. RIH slick down to 9030', bobble. RIH from 9030', started getting ratty weight all the way to TD. Tagged up solid several times and stacked 4 klbs on DHWOB sensor, finally had final tag at 9142'. Picked up 50'. PU wt = 34000 Ibs, DHWOB=-2800 Ibs. RIH fast. Solid tag up at 9142'. Stack out at surface, 4000 Ibs on DHWOB sensor. Bring on pumps to 3500 psi, 1.6 bpm. PU string wt = 27 klbs, DHWOB=-700 Ibs (CS hydril). (MWD is a wonderful thing). Confirmed liner is in place. Bottom of liner BHA at 9142', Solid liner 9142'-9043', Slotted liner 9043'-8822', Solid liner 8822'-8729', Slotte 872 - 34 . op o ep oymen sleeve at 8632.73'. ` y.~ t bQlpW w~ oW POH with liner running BHA. Pumping enough to maintain positive returns at surface, but not trying to clean the hole. (Don't want to hit it with excessive ECD's as we have KW F in the hole). Talk to town. Decided to modify mud system to try for better shale inhibition. We will weight up the mud to 9.1 ppg, increase the KCL concentration from 3% to 5%, and increase KlaGard from 12 ppg to 14 ppb. Getting gas bubbles and traces of crude back from open C sand perfs. Stop and circulate well taking returns to the tiger tank. Returns cleaned up to 10.3+ ppg. Short flow check. No flow observed. Continue POH. Circulating to get positive returns. Tag up at suface. Flow check well while holding PJSM to discuss standing back CS hydril. Check for flow at end of safety meeting. No flow observed. Rig down BHI MWD too-. Lay down 3 spaceout pups. Stand back 7 stands of 1" CS hydril. PJSM for running 2nd string of liner. Discuss hazards, safety joint, kicks, pinch points and other aspects of operation. Printed: 2/12/2007 10:14:15 AM ~ ~ B P Page 12 of 28 j Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 2 ell Name: 2 e: Name: From - To I Z-13 Z-13 REENTE NORDIC NORDIC Hours R+COM CALiST 2 Task PLET A Code E NPT ~ Start Rig Rig Phase ~ Spud Date: 1/3/2007 : 1/10/2007 End: 2/8/2007 Release: 2/8/2007 Number: Description of Operations 1/22/2007 13:45 - 14:10 0.42 CASE P RUNPRD Discuss job assignments, and hazard mitigation. Check well for flow. No flow observed. 14:10 - 15:45 1.58 CASE P RUNPRD Make up Liner BHA #2. BHA (Top-Bot): BTT Aluminum Deployment Slv 2 Jts - 2-3/8° STL Solid 10' pup joint 3 Jts - 2-3/8" STL Solid finer 10 jts - 2-3/8" STL Slotted liner 1 ea - BTT 1.5 deg bent sub 2 ea - BTT 2-3/8" STL 1' solid pup joints 1 ea -Unique indexing guide shoe (4, 1/2" holes) Total liner length = 447.5'. Total BHA length with MW D tools = 500.84'. 'i 15:45 - 17:15 1.50 CASE P RUNPRD RIH with upper section of liner. 17:15 - 18:45 1.50 CASE N RREP RUNPRD At 7800' while RIH lost communication to MWD tool. Found damaged wire between swivel and junction box inside reel. Stop at window to make repairs. Getting crude and gas back. Apply 200 psi whp and circ to tiger tank at min rate while repair connection After repairs, PUH 20' as wt chk, function orientor and verify tool is receiving signal, etc 18:45 - 19:00 0.25 CASE P RUNPRD Continue RIH w/ liner and went thru window at 40'/min at HS, clean. RIH at 50'/min and 45L to TD. Minor wt loss at prior liner spots verify that we are on depth. RIH to wt loss at 8640.3' CTD which is a normal -9' correction from where the top of the bottom section was left. PUH 30k surface wt, 0.4k ', wob. RIH and stack 6k down on top of bottom liner. Increase pump rate to 1.6 bpm @ 3550 while drop whp to zero. PUH ' 1 (~ and released from top liner w/ GS. TOL @ 8185', Solid liner ' T 4 w 3 ~ ~ ~'s-- . Solid liner to down to 8308'. Slotted liner 8308'-8629 " BOL is 8632.73'. Note -guide shoe does not have the 1" thru ~ ~ o e on the tip of the nose, but does have 4, 1/2" holes on the circumference of the guide shoe 3" up from the nose. j 19:00 - 20:15 1.25 CASE P RUNPRD PUH 50' to put GS C~3 8135' and circ out gas and oil at 0.3/550 w/ 400 psi whp at 11.6 ECD (?) to tiger tank while wo a vac truck to arrive to get more KW F from the upright tank PVT 63 20:15 - 21:45 1.50 CASE P RUNPRD Incr rate to 1.42/3200 and circ out gas/oil to tiger tank. Pumped 40 bbls before registering any density (of 8.9 ppg) on 'out' MM. After one full circ, out density was up to 10.22 ppg w/ 11.44 ECD. After several circ's in/out density is 10.42 ppg while circ 1.42/3550 w/ 11.67 ECD. Took 87 bbls total to tiger tank 21:45 - 23:15 1.50 CASE P RUNPRD POOH circ 1.42/3320 23:15 - 23:30 0.25 CASE P RUNPRD Check for flow 23:30 - 00:00 0.50 CASE P RUNPRD LD MWD assy and liner running tools 1/23/2007 00:00 - 00:30 0.50 CASE P RUNPRD Finish LD and load out liner running tools 00:30 - 01:00 0.50 STKOH P PROD1 Cut off CTC, dress stub. Stab back on well. SI swab 01:00 - 01:15 0.25 STKOH P PROD1 Safety mtg re: pump slack/cut CT 01:15 - 05:45 4.50 STKOH P PROD1 Reverse slack back. Bfow back reel w/ air. RU cutter and cut 290' CT for fatigue management. Dispose of CT. Install CTC and PT at 35k. Head up BHI UOC and test line. Fill CT and PT 4000 psi. Pump slack forward 05:45 - 06:40 0.92 STKOH P PROD1 MU sidetrack assy 06:40 - 09:45 3.08 STKOH N SFAL PROD1 Made up injector, performed shallow hole test, and found an Printed: 2/12/2007 10:14:15 AM ~, BP Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Start: 1/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date 1 /23/2007 From - To i Hours I Task I Code I NPT I Phase 06:40 - 09:45 ~ 3.081 STKOH N 09:45 - 12:30 I 2.751 STKOH I N 12:30 - 12:50 0.33 STKOH N 12:50 - 13:50 1.00 STKOH N 13:50 - 14:10 0.33 STKOH N 14:10 - 18:00 3.83 STKOH N SFAL ~PROD1 SFAL IPRODI SFAL IPRODI SFAL (PROD1 SFAL PROD1 SFAL PRODi 18:00 - 19:40 1.67 STKOH P 19:40 - 20:10 0.50 STKOH P 20:10 - 20:30 0.33 STKOH P 20:30 - 20:50 0.33 STKOH P 20:50 - 00:00 I 3.17 I STKOH I P 1/24/2007 00:00 - 01:15 1.25 STKOH P 01:15 - 02:15 1.00 STKOH P 02:15 - 03:15 1.00 STKOH P 03:15 - 05:00 1.75 STKOH P 05:00 - 06:00 I 1.00 I STKOH I P 06:00 - 08:00 2.00 STKOH P 08:00 - 14:30 6.50 WHSUR P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD2 Page 13 of 28 Spud Date: 1 /3/2007 End: 2/8/2007 Description of Operations electrical short in the corns line to the MWD. Broke off the MWD tools and tested the E-line, and had intermittant short. Troubleshot surface system. Found wire pulled out of Jupiter plug where it goes into the collecter on the reel. Repair same. Surface test. Passed ok. Pickup injector. Stab back onto MW D tools. Surface test MW D tools. Tools not working. Break injector back off. Continue troubleshooting. Lay down MW D tools on catwalk. Check with test cable to MW D cabin to bypass the E-line coil. MWD tool checks ok. Change out flow sub in UOC. Pick up MWD tools. Stab coil. Surface check of entire system. Not working. Leave coil stabbed. Isolate collector. Check from MWD cabin up thru collector. Hold discussion with SLB CTD Cell leader, SLB ET, SLB crew, BHI DD and 2 MWD hands, Nordic electrician to discuss troubleshooting problem. Set plan forward for finding problem. Resume troubleshooting problem with a clear step by step plan forward. Regroup, discuss plan forward. Attach BHA to coil. Test in the slips. No go, change out LOC. No luck. Continue trouble shooting, focusing on BHI equipment. All coil equipment appears to be working properly. Cable passes a meg-ohm and continuiety test. MWD tool works properly with a test jumper directly to the MW D cabin. Use rig electrician to check voltage at the end of the coil. Found polarity reversed. Jumper installed between Junction box and collecter in reel has reversed wires. This is the jumper that was changed for a new one this morning. It passes insulation and continuity checks, but is reversed from what the BHI tool requires. Schlumberger ET will switch it back. RIH with BHA #18 to sidetrack off of aluminum billett. Logged tie-in, corrected (-9 ft). Circulate KW F through open EDC Circulate 9.1 ppg fluid around Closed EDC with 9.1 ppg at surface. RIH and tagged 8182.7 ft without pump. PUH and start pump ai 1.56 bpm. RIH and tagged with Pp at 8142.3 ft. Set TF at 60deg R HS Time dr'Jl-affgfAl billet starting at 8,182 ft at 5 min / 0.1 ft. Op = 1.54 / 1.47 bpm CTP = 3325 psi BHP = 3,880 psi at 11.65 ppg ECD Finished time drilling 8,187.2 ft Drill slowly from 8,187 ft to 8,197 ft Reaming sidetrack at +/-30 deg from 65 deg RHS. POOH with open EDC following pressure schedule. Held PJSM. OOH, trapped 700 psi on well. RIH 2.6 ft and closed EDC. Tourpusher directing pressure undeploying BHA Crew change and PJSM to discuss remainder of undeployment of BHA. Weekly BOP pressure test witnessed by AOGCC, Lou Grimaldi. Had a leaking pressure test hose on 2-3/8" ram test. Repaired same. Had to grease choke valves to get pressure test. L~ r- Printed: 2/12/2007 10:14:15 AM • • BP Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task ;Code NPT -- ~_ i__ 1/24/2007 14:30 - 14:50 ~ 0.33 ~ DRILL ~ P 14:50 - 17:30 I 2.671 DRILL I P 17:30 - 19:00 I 1.501 DRILL I P 19:00 - 19:45 I 0.751 DRILL I P 19:45 - 23:50 ~ 4.08 ~ DRILL ~ P 23:50 - 00:00 0.17 DRILL P 1/25/2007 00:00 - 01:55 1.92 DRILL P 01:55 - 05:00 ~ 3.081 DRILL I P Start: 1 /10/2007 Rig Release: 2/8/2007 Rig Number: Phase PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 05:00 - 06:00 1.00 DRILL N RREP PROD2 06:00 - 06:30 0.50 DRILL N RREP PROD2 06:30 - 06:45 0.25 DRILL N RREP PROD2 06:45 - 07:00 0.25 DRILL P PROD2 07:00 - 09:10 2.17 DRILL P PROD2 09:10 - 10:30 1.33 DRILL P PROD2 10:30 - 10:45 0.25 DRILL P PROD2 10:45 - 11:45 1.00 DRILL N DPRB PROD2 Page 14 of 28 Spud Date: 1/3/2007 End: 2/8/2007 Description of Operations PJSM prior to pressure deploying BHA. Safety meeting conducted by trainee Schlumberger hand, Jack Hougtafing. Discussed procedure in detail. Made job assignments. Discussed hazards and mitigations. Pressure deploy build section BHA. 2.6 deg motor, rebuilt Hycalog Bi-center bit. No Res tool. RIH with BHA #19 to drill build section of L2 lateral. Following revised pressure schedule. Tagged TPDX Valve at 7,961 ft PU hole orient TF tp HS RIH and stopped at 8000 ft to tie-in Tie in Corrected (-8 ft) RIH wo pimp and correct TF past WS and billet. Drlling Build section from 8,202 ft to w/ 180 TF Hydrocarbons to surface from bottoms ups. 9.1 ppg flo-pro gas cut. Circulated 26 bbl gas cut flow-pro to tiger tank. Turned TF to HS at 8245 ft Op = 1.55 / 1.55 bpm at 3,750 psi Vp=284 bbl DHWOB = 1 to 4 klb' ROP = 40-60 fph. WHP = 175 psi, BHP = 3.700 psi w/ 11.8 ppg ECD NOTE: No fault was cut in this leg, formation tops as in the parent wellbore After landing as per programme at 8371 ft, PUH, close well in, SD pump and trap 700 psi on wellhead. PUH, at 8,029 ft open EDC and POOH circulating at 1.70 bpm following pressure schedule Held PJSM on Pressure Undeploying BHA. Review PJSM on prevoius trip out of hole using pressure undeploying techniques. OOOH, RIH 2.6 ft and pressure undeploy BHA with 700 psi on wellhead. WHP stablized at 64 psi while undeploying BHA which equates to 9.3 ppg EMW at 6,000 ft TVD. Change out DGS due to wet connect failure. PU USMPR (Res Tool). No comms in top half of tool. Trouble shoot communications in upper coiltrac BHA. Shut down for crew change out. Sort out BHI problem. Tools working ok: It was a bad test jumper. PJSM Re: Pressure Deploying Lateral section BHA. Pressure deploy L1 lateral section BHA #1. Had 264 psi on WHP when we opened up to the well. RIH with BHA #20, first L1 lateral section BHA. HCC 2.7 x 3.0 Bicenter bit, 1.1 deg motor, RES tool. Appear to be losing fluid a bit. About 0.1 bbl/min, 6 bbl /hr. Log tie in pass down over GR charecter at 8000'. Make -7' correction. Shut EDC. RIH dry thru window and top of whipstock holding "as drilled" toolface. No bobbles. Kick pumps on to 1.6 bpm. RIH. Tag up at 8331'. Work thru it. Tag up at 8354'. Heavy pick up at 40 klbs. Cleaned up at 8315'. Ream back up to 8300. RIH, set down and stall at 8328'. Pick up at 27 klbs, better, but still ratty. RIH with pumps at 0.25 bpm, TF = 0. Made it slick down to 8363'. Pumps on. Clean PU. Pump pressure ratty. May have debris above us packing off. 1.5 Printed: 2/12/2007 10:14:15 AM ~ ~ g p Page 15 of 28 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date '~ Name: 2 ell Name: 2 e: Name: From - To Z-13 Z-13 REENTE NORDIC NORDIC Hours R+COM CALIST 2 I Task ~ PLET A Code , E NPT Start Rig Rig Phase Spud Date: 1/3/2007 : 1/10/2007 End: 2/8/2007 Release: 2/8/2007 Number: Description of Operations 1/25/2007 10:45 - 11:45 1.00 DRILL N DPRB PROD2 bpm, 4000 psi. Pressure fell off as we got up to 8300'. RBIH dry to 8369'. PU slightly ratty, but better. RIH at 0.25 bpm, 30 tpm. Ran to bottom slick. 11:45 - 13:00 1.25 DRILL P PROD2 log MAD pass up from TD to acquire RES data in the build section. 150 fph. Pumping 1.5 bpm. No problems on MAD pass. Lots of pumping and slow pulling. Probably really cleaned the hole. 13:00 - 13:10 0.17 DRILL P PROD2 Run back in hole at 0.25 bpm, slick with no problems. 13:10 - 14:10 1.00 DRILL P PROD2 Free spin 3500 psi at 1.65 bpm. Begin drilling at 1.65/1.58 3700 psi. PVT=246 bbls. Bringing on 200 bbls of new mud from the tank farm. I/O 234/298. String wt = 5600 lbs. DHWOB=1600 lbs. 50-60 fph. 14:10 - 14:20 0.17 DRILL P PROD2 Finished taking on mud. PVT=351 bbls. Make a precautionary wiper trip. PU off bottom at 26 klbs clean. Free spin of bottom is 3420 psi at 1.6 bpm. Clean up to 8300. 14:20 - 14:25 0.08 DRILL P PROD2 RIH, TF=90R, set down at 8360'. PU, orient to 20L, "As drilled". Pumps off, RIH. Slick to bottom. 14:25 - 16:30 2.08 DRILL P PROD2 Free spin 3450 psi ~ 1.62 bpm. Resume drilling. ROP 50 fph drilling A4 shale. Trying to drill up into the A4 sand. 16:30 - 17:45 1.25 DRILL P PROD2 Continued to drill ahead. Held Parted/Pinholed coil tubing, Spill and H2S drills. 17:45 - 18:00 0.25 DRILL P PROD2 Pump 10 bbl high vis sweep. Wiper trip to window as sweep ', exited bit. Smooth trip. Droped pumps to 0.25 bpm when ~ running down past 8300', made it to bottom slick. 18:00 - 20:00 2.00 DRILL P PROD2 Resume drilling. PVT=346 bbls. I/0=159/181 psi. Free spin = 3300 psi ~ 1.6 bpm. Drilling at 1.59/1.58/3700 psi. Still drilling shale. Geo wants to increase INC to 95+ (from 94) to get up out of the shale. 20:00 - 21:10 1.17 DRILL P PROD2 Drilling break, ROP up to 120 fph. 21:10 - 22:55 1.75 DRILL P PROD2 Wiper trip. Clean PU off bottom at 24 klbs. Free spin 3435 psi at 1.59 bpm. Clean up to 8190'. Ran down past 8300' at 0.25 bpm. Pumps back up at 8500'. Set down at 8630 with motor work. Picked up shut down pumps and got thru ok. 22:55 - 00:00 1.08 DRILL P PROD2 Resume drilling lateral section. 11/26/2007 00:00 - 01:00 1.00 DRILL P PROD2 Continue drilling ahead. 01:00 - 01:40 0.67 DRILL P PROD2 Make wiper trip to the window. Note that last 10' drilled very slowly. Log tie in pass, correction -0.5'. Ran back in the hole with pumps at 1.0 bpm thru 8300', and had no problems getting to bottom. 01:40 - 06:00 4.33 DRILL P PROD2 ROP very slow on bottom. Drilling ahead at -10 fph. Geo confirms we are in the Ankorite. Plan is to drill up thru it, then level off. 06:00 - 06:30 0.50 DRILL P PROD2 Continue drilling while holding crew change. 06:30 - 13:15 6.75 DRILL P PROD2 Drill ahead. PVT=393 bbls. IAP/OAP=363/199 psi. Drilling at 1.56/1.52/3440 psi. 13:15 - 14:20 1.08 DRILL P PROD2 Pump 10 bbl high vis sweep. Make wiper trip to the window. Overpulls and MW at 8922', 8682', 8350. The sweep seemed to bring up more cuttings than usual when it got to surface. RIH at 0.6 bpm, and went slick to bottom. One set down at 8935'. 14:20 - 18:30 4.17 DRILL P PROD2 Resume drilling. Free Spin 1.59 3480 psi. PVT=378 bbls. Appear to be losing a couple of bbls of mud an hour. Drilling at 1.62/1.56/3900 psi. DHWOB=1200 lbs. String wt = 4000 lbs. Printed: 2/12/2007 10:14:15 AM gp Page 16 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ~ Hours Task Code 1 /26/2007 14:20 - 18:30 18:30 - 19:50 19:50 - 22:45 22:45 - 23:50 23:50 - 00:00 1 /27/2007 00:00 - 01:00 01:00 - 03:30 03:30 - 05:20 05:20 - 06:00 06:00 - 06:15 06:15 - 07:15 07:15 - 08:30 4.17 DRILL P 1.33 DRILL P 2.92 DRILL P 1.08 DRILL P 0.17 DRILL P 1.00 DRILL P 2.50 DRILL P 1.83 DRILL P 0.67 DRILL P 0.25 DRILL P 1.00 DRILL P 1.25 DRILL P 08:30 - 10:30 10:30 - 12:00 2.001 DRILL I P 1.501 DRILL I P Spud Date: 1 /3/2007 Start: 1 /10/2007 End: 2/8/2007 Rig Release: 2/8/2007 Rig Number: NPT ~ Phase '~, Description of Operations PROD2 Start pumping sweeps at 1, 10 bbl sweep per hour. Seeing more cuttings in returned sweeps. PROD2 Wiper trip back to 8200'. Motor work and increased weight pulling up from 8920' thru 8850' and at 8680'. PVT = 354bb1s. Set down once at each of 8910', 8940', 9025', 9110 -slowed pump to .2 bbl/min and used as drilled tool face to pass thru. PROD2 Resume drilling. Free spin 3500psi. Drilling at 1.59 3950 TFO 100 degrees. ECD 12.63ppg. PVT=354 bbls. DHWOB 10001bs. Instantaneous ROP 26-60'/hr. Some weight transfer issues. PROD2 Wiper trip back to the 8010' for tie-in. Overpull at 8940', and 8350'. Pumps shut down passing TOL and thru window. Open EDC inside casing. PROD2 Log down at 150'/hr to tie in. Correct -1'. PROD2 RIH back to bottom after tie in. set down at 8937'. PROD2 Resume drilling. FS 3850 ~ 1.56bpm. Drilling 1.47/1.43/4100psi, DHWOB 14001bs, TFO 195, ECD 12.4ppg. Pumped 30bbls high vis sweep to use up pill when swapping to new mud. Large amount of cuttings came to surface, ECD as high as 13.5ppg. New mud in hole at 2:40. Increased ROP's to 120'/hr once in the hole. PROD2 Wiper trip back to 8200'. Overpull at 8350' while POOH and set down at 9160' RIH. Fairly clean trip. PROD2 Resume drilling. Drilling 1.54/1.48/3660, DHWOB 11001bs, TFO 270, ECD 12.33ppg. Pumping hourly 10bb1 high vis sweeps. PROD2 Tour crew change. Continue drilling. PROD2 Continue drilling. PVT=354 bbls. IAP/OAP=458/222. PROD2 Drilling ROP slowed way down, and having difficulty getting back to bottom. Pump 10 bbl sweep. As sweep exits bit, make wiper trip to window. Clean PU off bottom and clean pulling up to 8960'. Started pulling heavy and packing off. PLF. Work it up slow. Pump another 20 bbls of high vis sweep. Very heavy overpulls, packing off up to 8850'. Suspect poor hole cleaning. Continue up hole. Overpull at 8660', 8350. 2nd sweep had lots of cuttings. Hole cleaning is the issue. PROD2 Run back in hole. Holding "as drilled" tool face. Ran it at 1.0 bpm past 8350', and didn't see a bobble. Raise rate to 1.3 bpm at 8750'. RIH smooth to 8930'. Started seeing weight. Pumps to 0.25 bpm, slid right thru. Kick pumps on to full rate, pump another 20 bbl sweep. Run to 8960', wash back up thru it with sweep. Looking much better than last time. Virtually no overpulls, and no motor work or packing off. Caught a sample from the last sweep. Geo reports it looks Ilike cuttings, and not cavings. Shale 70% and sand 30%. Probably not cleaning the hole as good as we need to. Increase high vis sweep viscosity from 100 k to 150 k Isrv. PROD2 Tag bottom. Resume drilling. Free spin 3560 psi at 1.55 bpm. ECD=12.1 ppg, BHP=3729 psi. Higher than yesterday. Probably from viscosity of new mud + sweeps. Drill ahead at 60 fph. 1.55/1.51/3650 psi. String wt=2800 Ibs, DHWOB=1200 Ibs. Plan to pump 20 bbl sweep of higher vis sweep 1 per hour. Printed: 2/12/2007 10:14:15 AM a BP Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date i From - To ~ Hours Task ~ Code ~ NPT - ~ ---- 1/27/2007 ~ 12:00 - 12:50 ~ 0.83 DRILL ~ P 12:50 - 13:10 I 0.331 DRILL I P 13:10 - 14:15 I 1.081 DRILL I P 14:15 - 15:30 I 1251 DRILL I P Start: 1 /10/2007 Rig Release: 2/8/2007 Rig Number: Page 17 of 28 ~ Spud Date: 1 /3/2007 End: 2/8/2007 Phase Description of Operations PROD2 Hit hard streak at 9532'. Stack -8500 Ibs string wt. 1200 Ibs DHWOB. Hard hard hard. PROD2 PJSM for confined space entry into pit #1. Continue drilling on hard spot. PROD2 Continue trying to drill. Getting 1500 Ibs to DHWOB sensor, but not making any ROP. PROD2 Not making any progress except 3' of stacked pipe. 1.55/1.52/3630 psi. About 40 Ibs of motor work. 2000 Ibs DHWOB should be enough to drill with. Pump 20 bbl of Jesus sweep to clean hole again. Sweep to bit and start POH. Going to pull OOH for a new bit and to check the BHA. Note - 1166' on this bit. 15:30 - 16:50 I 1.331 DRILL I P I I PROD2 16:50 - 17:10 I 0.331 DRILL I P t I PROD2 17:10 - 19:15 2.08 DRILL P PROD2 19:15 - 19:20 0.08 DRILL P PROD2 19:20 - 19:50 I 0.501 DRILL I P I I PROD2 19:50 - 22:45 2.92 DRILL P PROD2 22:45 - 23:00 0.25 DRILL P PROD2 23:00 - 00:00 1.00 DRILL P PROD2 1/28/2007 00:00 - 01:10 1.17 DRILL P PROD2 01:10 - 06:00 4.83 DRILL N SFAL PROD2 06:00 - 06:30 0.50 DRILL N SFAL PROD2 06:30 - 07:50 1.33 DRILL N SFAL PROD2 07:50 - 08:15 I 0.421 DRILL I N I SFAL I PROD2 08:15 - 09:20 1.08 DRILL N SFAL PROD2 09:20 - 14:45 5.42 DRILL N SFAL PROD2 8950, minor bobble on wt. 8330' overpull and motor work. Got thru is ok. Hole is in better shape than last trip OOH. Pull past L1 billet and window slick with no problems, POOH pumping at full rate. Hold PJSM Re: Undeploying while POH. EDC gave error message when closing. Discussed checking for flow very carefully when undeploying to ensure that EDC is not leaking. Pressure undeploy BHA #20. SL parted during undeploying. BHA(68' long) dropped 15' to land on swab valve. Well was secured and dog collars set. Stop job. Gather team in doghouse and develop procedure to safely lay down tools without SL. ID and review hazards associated with the new procedure. Ensure all members comfortable with new plan, and proceed to execute. Finish undeploying and lay down tools. BHI swapping entire string due to dropped BHA when SL parted. Slipped and cut 70' off of SL unit, twist tested new section to 30 turns(pass is 17 turns). Thread SL through lubricator and re-head SL on rope socket. PJSM prior to picking up BHA and pressure deploying. Pressure deploy BHA. Continue to pressure deploy BHA and connect injector. BHI testing tools. No communicataions to BHI tools. Troubleshoot same. Shut down for crew change out. Continue troubleshooting corns problems. WSL's are in camp sorting out slickline failure of the previous evening. Group up with all hands on rig. Discuss where we are, and the best plan forward for sorting out problems. Resume troubleshooting corns problems. BHA works fine with test jumper. Problem is in the coil/eline system somewhere. With the assistance of the rig electrician, Mike Shic, we quickly identified the problem as the SLB collector. Discuss plan forward with SLB hands. Need to replace collector with the spare. To do this we can not circulate, and will need to swap the coil to water, then blow it back. Swap from mud to 9.1 ppg. Circulate brine from pit 1, takiing mud to active system. Blow brine back after getting coil loaded with brine to give us a void space to avoid freeze up. Change out Printed: 2/12/2007 10:14:15 AM gp Page 18 of 28 ~ Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date ;From - To Hours Task I Code NPT Phase -_ _ _--1 1/28/2007 ~ 09:20 - 14:45 ~ 5.42 ~ DRILL ~ N ~ SFAL PROD2 14:45 - 15:10 ~ 0.42 ~ DRILL ~ P ~ ~ PROD2 15:10 - 16:10 I 1.001 DRILL I P I I PROD2 16:10 - 18:50 2.671 DRILL P PROD2 18:50 - 19:05 I 0.251 DRILL I N I SFAL I PROD2 19:05 - 21:45 I 2.671 DRILL N ~ SFAL PROD2 21:45 - 23:55 2.17 DRILL N SFAL PROD2 23:55 - 00:00 0.08 DRILL N SFAL PROD2 11/29/2007 00:00 - 01:00 1.00 DRILL N SFAL PROD2 01:00 - 01:15 0.25 DRILL N SFAL PROD2 01:15 - 03:20 2.08 DRILL N SFAL PROD2 03:20 - 03:40 0.33 DRILL N SFAL PROD2 03:40 - 04:05 0.42 DRILL N SFAL PROD2 04:05 - 05:30 1.42 DRILL N SFAL PROD2 05:30 - 05:45 0.25 DRILL N SFAL PROD2 05:45 - 06:00 0.25 DRILL N SFAL PROD2 06:00 - 06:30 0.50 DRILL N SFAL PROD2 06:30 - 11:00 I 4.501 DRILL I N I SFAL I PROD2 11:00 - 11:30 I 0.501 DRILL I N I SFAL I PROD2 11:30 - 13:00 I 1.501 DRILL I N I SFAL I PROD2 13:00 - 16:40 I 3.671 DRILL I N I SFAL I PROD2 16:40 - 18:00 1.33 DRILL N SFAL PROD2 18:00 - 19:00 1.00 DRILL N SFAL PROD2 19:00 - 19:20 0.33 DRILL N SFAL PROD2 19:20 - 21:20 2.00 DRILL N SFAL PROD2 21:20 - 21:35 0.25 DRILL N SFAL PROD2 21:35 - 23:15 1.67 DRILL N SFAL PROD2 Description of Operations collector. Inspect old collerctor. Found burned wire inside electrical connection. Tested new collector and coil. Perfect insulation. PJSM about deploying lateral section BHA. Discuss hazards of resuming a job that has been half way completed. Discuss double checking status of all valves and equipment prior to being deployment. Open inner reel valve. Check eline 1 last time. Checks ok. Resume deployment proceedure from step 26. MWD BHA checks good! Continue with deployment. RIH with BHA #21.1.1 deg motor, Hycalog Bicenter bit, Andergauge Agitator. Following pressure schedule as we RIH. Noted pinhole in coil with bit @7979. PJSM prior to reeling the pinhoied coil back from injector to reel. POOH to surface for pressure undeploy. Stop to check roof for fluid once the pinhole was safely under a wrap of coil, no fluid noted. PJSM for pressure undeploy prior to reaching surface. Pressure undeploy BHA. Prepping for N2 displacement. Continue prep for N2. PJSM prior to blowing down the reel with N2. Blow down coil with N2. Take first 30 bbls to pits, remainder directed to tiger tank. PJSM to unstab CT and reel swap. Unstab CT and lock down for moving. Lower CT from reel house to trailer. Lift new CT reel from trailer to reel house. Start rigging up hardline inside reel. Shut down operations for tour crew change. Hold PJSM to discuss plan forward. Continue rigging up hardline in reel (inner reel valve, pressure bulkhead, etc.). Hold PJSM to discuss stabbing pipe. Review proceedure. Discuss hazards. Discuss mitigations. Make job assignments, and review expectations. All unnecessary personnel to remain off the rig during this operation. Pull coil off reel and stab pipe into injector. Change out packoffs. Dress end of coil. Install boot on end of eline. Stab on well. Circulate to load the reel with fluid. Pump slack management. Heard good movement of eline inside coil. Reverse in 10 bbls of methanol inside end of coil. SD pumps. Unstab lubricator. Pick up hydraulic pipe cutter. Cut 20' of pipe and found end of elilne. Cut a total of 300' of pipe for coil management. Attach CTC. Pulltest. Attach eline UOC. PT. Circulate methanol through coil followed by water and pressure test CTC. PJSM to PU BHA and pressure deploy. Pressure deploy BHA. Troubleshoot BHI tools. RIH to tie-in depth of 8015. Intial returns mixed with crude and gas sent to tiger tank. Printed: 2/12/2007 10:14:15 AM gp Page 19 of 28 Operations Summary Report Legal Well Name: 2 Z-13 Common W ell Name: 2 Z-13 Spud Date: 1/3/2007 Event Nam e: REENTE R+COM PLET E Start : 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALIST A Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ', Task Code NPT~ Phase Description of Operations 1/29/2007 23:15 - 23:30 0.25 DRILL P PROD2 Tie-in to log at depth of 8015. 23:30 - 00:00 0.50 DRILL P PROD2 Circulate until returns are full density prior to entering openhole. 1/30/2007 00:00 - 00:05 0.08 DRILL PROD2 Circulate until returns are full density prior to entering openhole. 00:05 - 00:55 0.83 DRILL PROD2 RIH circulating at 1.25bbls/min and set down at 8332 -start of shales. ECD rose to 15.5. Short wiper. Tried again at 0.4bbls/min and saw ECD of 17. Assuming packing off, but ECD remained high once pulled back to the aluminum billet. Cuttings over the shakers. 00:55 - 01:45 0.83 DRILL PROD2 Pull into casing to circulate and monitor ECD. ~I 01:45 - 02:30 0.75 DRILL N PROD2 BHI screens down in ops cab. 02:30 - 03:20 0.83 DRILL PROD2 Attempt to run to bottom again. ECD 11.70 at 8200' and 1.6bbls/min. sat down at 8323' at .75 bbls, passed thru at .5 ~~ bbls/min. Sat down again at 8393. Overpulls when pulling back, wiper to below aluminum billet. RIH at .45bbls/min, sat down at 8434'. Max overpull of 53klbs with pump rates of ~ 1.4bbls/min. 03:20 - 04:05 0.75 DRILL PROD2 Wiper trip back to casing and circulate. 04:05 - 05:15 1.17 DRILL PROD2 Continue to attempt to run to bottom. Low rates of .4bbls/min seem to be working for moving down and up. Sat down twice at 8461. 05:15 - 06:00 0.75 DRILL PROD2 Wiper trip back to below aluminum billet. 06:00 - 06:40 0.67 DRILL PROD2 Continue to ream and backream. Making progress in 25' bites. Hole is pretty sticky and it looks as if the shales have started to come apart a bit in the past 48 hours while we were OOH. PVT=303 bbls. IA/OAP=7/127. 06:40 - 08:15 1.58 DRILL N DPRB PROD2 Take bite to 8679', wash back up and stuck with bit at 8665'. Packed off. pumping 1.0 bpm, 4000 psi. Returns 0.1 bpm. Work pipe down hole. No luck. Returns go to 0, completely packed off. Can't go up or down. Pull 46 k lbs. No luck. Put in coil at neutral weight. Try to open EDC, try to circulate thru it. No luck. The EDC is not functioning, and BHI hands on the rig can't get it to work. (Note -May not be able to disconnect if we need to). Pull to max. 58 klbs. Bring on pumps. Slight trickle of returns. DHWOB=-1170 lbs. Shut choke, pressure up wellhead. Stops pressuring up at 520 psi. Pull again to max. Got -747 Ibs tension on DHWOB sensor. Bit is rotating. Orienter turns. W e appear to be stuck between the orienter and the DPS. Hold pull on coil. DHWOB bleeding off slowly. Bled off to -700 Ibs, then stopped. 08:15 - 08:40 0.42 DRILL N DPRB PROD2 Pressure up backside to 1500 psi. 500 psi inside coil. -700 on DHWOB. Pull 60 klbs. DHWOB=-700 psi. ANN pressure=4769 psi, Bore pressure = 3971 psi. Dump backside pressure. DHWOB=-800 Ibs, ANN pressure =4785 psi, Bore pressure = 3800 psi. Stack wt. Start alternately pumping down the coil for 5 minutes, then down the backside for 5 minutes. Trying to wash the stuff out around the BHA. 08:40 - 14:00 5.33 DRILL N DPRB PROD2 Start alternately pumping down the coil for 5 minutes, then down the backside for 5 mintues. Trying to wash the cuttings out from around the BHA. Orienter free to turn. Stuck above orienter and motor. DHWOB and Ann Pressure sensor not reactive when pulling, or pumping down the backside. No returns when pumping down the coil. Down the coil WHP=640 psi. DHWOB=-1350 Ibs, AP=4958, Printed: 2/12/2007 10:14:15 AM r ~ gp Page 20 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date i From - To ~~ Hours Task Code NPT --- _ 1_ 1/30/2007 08:40 - 14:00 ~ 5.33 DRILL N ~ DPRB 14:00 - 15:30 I 1.501 DRILL I N I DPRB 15:30 - 17:12 ~ 1.70 ~ DRILL ~ N ~ DPRB 17:12 - 18:30 1.30 DRILL N DPRB 18:30 - 20:30 2.00 DRILL N DPRB 20:30 - 22:00 1.50 DRILL N DPRB 22:00 - 00:00 2.00 DRILL N DPRB 1/31/2007 00:00 - 00:30 0.50 DRILL N DPRB 00:30 - 02:15 1.75 DRILL N DPRB 02:15 - 02:30 0.25 DRILL N DPRB 02:30 - 04:30 2.00 DRILL N DPRB 04:30 - 05:30 I 1.001 DRILL I N I DPRB 05:30 - 06:00 0.50 DRILL N DPRB 06:00 - 08:00 2.00 DRILL N DPRB 08:00 - 18:00 I 10.001 DRILL I N I WAIT Spud Date: 1 /3/2007 Start: 1/10/2007 End: 2/8/2007 Rig Release: 2/8/2007 Rig Number: Phase ; Description of Operations PROD2 Bore Pressure=5289 psi. No returns. Down the backside WHP=1500 psi. DHWOB=-700 Ibs, AP=4744 psi, BP=4085 psi. Injecting at 0.6 bpm. Down the coil C~ 0.74 bpm. WHP=400 psi. DHWOB=-1000 Ibs, AP=4913 psi, BP=5176 psi Slight returns. Down the backside 0.5 bpm. WHP=1670 psi. DHWOB=-1100 Ibs, AP=4874 psi, BP=3895 psi. Continue cycling pressure both ways. Trying to get some sore of movement at the BHA. HOT and DPS seem to be working. Oriented TF around while working the CT CT at 8660 ft is 38 fatique PROD2 Pumped 15 bbl of Kupuark Slick diesel down CT (Vct = 38.7 bbls) Placed CT in neutral CTW. Located Dead crude at WOA GC1. With 36 bbls diesel pumped, motor stall at 4300 psi. Op = 0.67 / 1/2" stream. MM not working at these lower Op Pumped 43 bbl. (5 bbl diesel out) SD and moved TF from 90L to 270 deg. Saw some movement PUH from 8,658 ft to 8,393 ft PROD2 Placed CT in neutral at 11 k and moved TF from 90R to 90 L while pumping 20 bbl diesel down CT. INTEO building new tool string minus agitator and USMPR (res tool) With 3 bbl diesel out worked CT and started moving again Worked BHA into 3-1/2" tubing. Gas/oil to surface. Take returns to tiger tank while working CT. PROD2 Circulate wellbore clean taking returns to tiger tank. Returns slowly increasing. Mud weight also increasing. PROD2 Circulate out of hole with drilling assembly. Maintain WHP as per schedule. Hold PJSM in Ops cab before getting to surface. PROD2 Pressure undeploy BHA. PROD2 MU 1.1 deg motor with re-run Hyc bi center ibt. PROD2 Continue to deploy lateral clean out assembly. Stab coil and test tools. Get on well. PROD2 Run in hole. Maintain WHP as per pressure schedule. PROD2 Log GR tie in from 7990'. Subtract 8' correction. PROD2 Run into open hole. 3420 psi fs at 1.52 in/1.59 out. Set down at 8300'. Back ream. Set down at 8316'. PU to back ream. Pulled 44k#. Varypump rate and tool face to left and right. 8316'. Not able to get past. Drill ahead 2'-3'. PU to back ream. Pulled 56k# to get free. This section is very sticky. Decide not to risk BHA. PROD2 Circulate out of hole. Maintain WHP as per schedule. Hold PJSM in Ops cab to discuss undeplying the BHA. PROD2 PJSM Pressure undeploy BHA with 600 psi on wellhead PROD2 Crew change, PJSM on BHA handling while pressure undeploying Pressure Undeploying BHA with 500 psi on wellhead. PROD2 Turned Phase II in the GPB and Kup field. Talked through proposed ST options with Town and decided on plan forward. Waiting on BOT convey from Deadhorse. Working on removing huge drift at entrance to 2Z Pad Kupuark tuned to Phase III at 10:30 hrs. Recoverd all field personnel and setup in mancamp. Hunkered down and make 30 minutes walk arounds. Called in fuel and water numbers to GPB Field Engineers Printed: 2/12/2007 10:14:15 AM ~ ~ gp Page 21 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From -To Hours ~ Task Code' NPT Phase 1/31/2007 18:00 - 00:00 6.00 DRILL N WAIT PROD2 2/1/2007 00:00 - 00:30 0.50 DRILL N WAIT PROD2 00:30 - 02:00 1.50 DRILL N WAIT PROD2 02:00 - 02:30 0.50 BOPSU P PROD2 02:30 - 03:00 0.50 DRILL N DPRB PROD2 03:00 - 05:00 I 2.001 DRILL I N I DPRB I PROD2 05:00 - 06:20 I 1.331 DRILL I N I DPRB I PROD2 06:20 - 06:45 ~ 0.42 ~ DRILL ~ N ~ DPRB ~ PROD2 06:45 - 07:15 I 0.501 STWHIPI N I DPRB I PROD2 07:15 - 09:05 I 1.831 STWHIPI N I DPRB I PROD2 09:05 - 09:50 ~ 0.75 ~ STWHIP~ N ~ DPRB ~ PROD2 09:50 - 13:00 I 3.171 STWHIPI N I DPRB I PROD2 13:00 - 14:45 I 1.751 STWHIPI N I DPRB I PROD2 14:45 - 15:00 ~ 0.25 ~ STWHIP~ N ~ DPRB ~ PROD2 15:00 - 16:00 ~ 1.00 ~ STWHIP~ N ~ DPRB ~ PROD2 16:00 - 17:15 I 1.251 STW HIPI N I DPRB I PROD2 17:15 - 19:00 1.75 STWHIP N DPRB PROD2 19:00 - 21:00 2.00 STWHIP N DPRB PROD2 21:00 - 23:00 I 2.001 STWHIPI N I DPRB I PROD2 23:00 - 23:30 0.50 STWHIP N DPRB PROD2 23:30 - 00:00 0.50 STWHIP N PROD2 Description of Operations Cotniue to wait on weather (Phase 3). Discuss buddy system for periodic outside walk arounds. Establish water & fuel conservation measures on rig and in camps. Winds calming but roads still not passable. Continue to wait on Phase Three weather condtiions. Main roads now phase two. Pads remain phase three. Clear a path to Spine Road with loader. Fuel truck on location. Function test BOP equipment. Hold PJSM with all crew. Discuss making up Baker billet assembly. Review pressure deployment highlights. Bring Baker tools to pipe shed. Heat same. MU slim hole billet assembly (11.1' x 2.625") with Model J setting tool and full Inteq MWD. Found 450 psi on well. Run in hole. Maintain WHP as per schedule. Snubbing wt high -6k running in the hole. Mud thick from inactivity (thick) and having trouble getting displacement. Stopped and unable to open EDC due to dell P on the EDC tool. PUH to reduce the delta P on the BHA from 600 psi to 50 psi. Stopped at 4,264 ft and open EDC with 30 psi differential RIH slowly at 0.25 bpm down CT. Nordic's out MM is still not working correctly. Using WHP to try an achieve some circulation Unable to get any returns to surface due to high yield /gel muds. RIH to 4,965 ft. POOH slowly due to tool OD, high yields and gel strengths mud. Order trucks for mud swap flollowing cleanout. Held PJSM and review new Hydraulic Winch /slickline RP with crews. BHI setting up 1.1 motor for cleanout Tagged up, bleed CTP down to 250 psi to keep delta P on the billet setting tool. Pressure up on wellhead to 500 psi, open EDC and pressures equalize to 250 psi. Pressure undeploy BHA / BOT Billet Set billet in pipe shed and pressure deploy cleanout BHA Crew change. RIH. open EDC at 125 ft, RIH as per pressure schedule. At 5000 ft started taking returns to tiger tank due to hydrocarbons Tie-in at 8000 ft, corrected -6 ft. Started new flo pro down CT SD pump, SWI and closed EDC RIH with correct TF and cleaned out to 8,300 ft MD Hole clean to 8300 ft PUH chasing new Flo-pro to surface. PUH with correct TF. open EDC POOH chasing new flo-pro to surface. Held PJSM and review new RP for operating the slickline unit used in pressure deploying or undeployment of BHA's Pressure undeploy BHA. 485 psi on wellhead. MU Baker TT aluminum billet and Model J setting tool on Inteq MWD. Test tools. Get on well. Open EDC. Run in hole. Maintain 500 psi WHP. Circ at min rate. Log gr tie in from 8000'. Subtract 8' correction. Run in hole. CT wt: 8.4k# dn, 22.5k# up. Run to 8285'. PU to up weight. Close EDC. Pressure up coil to 4500 psi. Pull to 35k# on coil. Slips set, tool not sheared. Pull to 50k#. Set down -5k# on billet. PU again. Toll sheared at 52k# up wt. Pressure bled off J tool too. 3500 psi at 0.55 bpm. Something not quite right. Printed: 2/12/2007 10:14:15 AM ~ ~ gp Page 22 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: i Date From - To Hour~ask Code I NPT Phase -- - - _ - 1' 2/1/2007 23:30 - 00:00 0.50 STWHIP N PROD2 2/2/2007 00:00 - 01:45 1.75 STWHIP N DPRB PROD2 01:45 - 03:15 I 1.251 STWHIPI N I DPRB I PROD2 03:15 - 06:00 I 2.751 STWHIPI N I WAIT I PROD2 06:00 - 10:30 I 4.501 STWHIPI N I WAIT I PROD2 10:30 - 11:15 0.75 STWHIP N WAIT PROD2 11:15 - 11:30 0.25 STWHIP N DPRB PROD2 11:30 - 15:00 3.50 STWHIP N SFAL PROD2 15:00 - 17:00 I 2.001 STWHIPI N I WAIT I PROD2 17:00 - 19:30 I 2.501 STWHIPI N I STUC I PROD2 19:30 - 20:00 I 0.50 I STW HIP I N I STUC I PROD2 20:00 - 21:00 I 1.001 STWHIPI N I STUC I PROD2 21:00 - 21:45 I 0.751 STW HIPI N I STUC I PROD2 21:45 - 22:30 I 0.751 STWHIPI N I STUC I PROD2 Description of Operations Pull into casing. Bleed off coil and open EDC. Pull out of hole. Fill hole and maintain WHP as per schedule. Hold PJSM to review undeploy. Pressure undeploy billet BHA. LD tools. Left setting rod inside billet, 2' down inside of billet. LD BHA components. Request Baker put together another billet assembly. BOT is testing the setting rod on the billet. BHI found their shipment at the Deadhorse yard Trying to track down EDC tool enroute to slope from Anchorage. Having trouble finding anyone on the slope with Lynden. Unable to locate the BHI shipment. BHI needs to start their repair shop back up in Deadhorse. Lots of times has been spent waiting on tools from Anchorage and it will increase with both rigs using BHI Coiltrac. Research on the operations of the BOT's AI billet at BOT Deadhorse faculities. Waiting on the replacemenmt EDC from Lynden's yard. BHI tools arrived at 10:30 hrs Pre EDC tool after shipment MU to string and ckeck (OK). Hold PJSM on pressure deploying BHA Pressure Deploy BHA as per procedure. WHP at 470 psi While pressure deploying BHA (AKO 2.5 deg) at 450 psi, the BHA became stuck in the well head. The counter on the wireline machine is not working correctly and the correct position/depth of the BHA in the wellhead is difficult to determine at this time. Unable to closed MV and SV. Measured the distance and found it to be 35 ft, this places the bit at the top of the tubing hanger. Open well and after 1 bbl the well is flowing at 100 psi with 9.1 ppg fluid in the well. SW I, WHP increased to 350 psi which equates to 10.3 ppg. We presently have 240 bbl of 10.5 ppg brine KW F on location. Ordered vac truck from Kupuark to assist in fluid packing wellbore. Closed Annular and bled pressure down above annular. Phase III was called at CPF2 area by Kupuark Security. KW F truck and stick diesel truck on location on standby. Security took 2Z Pad on Phase II Fluid pack CT with 40 bbl of slick diesel. low flowrate due to plug in bung hole. Displace pump suction with water. Spot KW F vac truck. RU equalization line to lubricator. Hold planning meeting with Nordic, SLB, WSL leaders. Review plan steps, hazards, contingencies. Document same. Hold PJSM with all crew members. Discuss plan steps, roles, hazards. Equalize pressure across annular. (400 psi). Pump up packoff to 500 psi. Open annular. SITP: 395 psi. Begin pumping 10.5 brine down tubing. Formation taking fluid at 1750 psi, at 3.0 bpm. Monitor lubricator for leaks etc while circulating. 1505 psi at 3.0 bpm with 1 tubing volume (70 bbls) away. Pump 140 bbls. Bleed pressure off well. Monitor well for pressure /flow. Well flowing at 0.75 bpm with well open. Shut in well. WHP increased up to 455 psi and stabilzed. This is 60 psi higher than before killing well. Printed: 2/12/2007 10:14:15 AM ~ ~ g p Page 23 of 28 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 2 ell Name: 2 e: Name: From - To Z-13 Z-13 REENTE NORDIC NORDIC Hours R+COM CALIST 2 ~ Task PLET A Code E NPT 2/2/2007 22:30 - 00:00 1.50 STWHIP N STUC 2/3/2007 00:00 - 00:15 0.25 STWHIP N STUC 00:15 - 01:15 1.00 STWHIP N STUC 01:15 - 03:00 1.75 STWHIP N DFAL 03:00 - 05:00 2.00 STWHIP N DFAL 05:00 - 06:15 1.25 STWHIP N DFAL 06:15 - 08:45 2.50 STWHIP N DPRB 08:45 - 09:00 0.25 STWHIP N DPRB 09:00 - 09:30 0.50 STWHIP N DPRB 09:30 - 09:50 0.33 STWHIP N DPRB 09:50 - 13:50 4.00 TWHIP S P /~ ~-~ g 13:50 - 16:40 2.83 STWHIP P 16:40 - 18:00 1.33 STWHIP P 18:00 - 20:30 2.50 STWHIP P 20:30 - 22:15 1.75 STWHIP P 22:15 - 00:00 1.75 STWHIP P 2/4/2007 00:00 - 01:00 1.00 STW H I P P 01:00 - 03:30 2.50 FISH N DFAL 03:30 - 05:00 1.50 FISH N DFAL 05:00 - 06:30 1.50 FISH N DFAL Spud Date: 1/3/2007 Start: 1 /10/2007 End: 2/8/2007 Rig Release: 2/8/2007 Rig Number: Phase ~ Description of Operations PROD2 SITP: 450 psi. Bleed 2.5 bbls. Shut in. Build up to 234 psi. Bleed 2.5 bbls. Build up to 165 psi. Shut in. Repeat several more times until WHP remains zero. PROD2 Continue to bleed and monitor well. Very slight flow from well. PROD2 Lift lubricator. Attempt to turn and lower BHA with pipe wrenchs. No downward progress. Pull BHA free with tugger. Re-run. No go. PU BHA. Grind edges off kick pad on motor. Grease bit & motor. Run in hole to no go. Continue to MU BHA using open hole procedure. PROD2 Calibrate Inteq tools. Problems communicating with the EDC. PROD2 Undeploy BHA. Lay down Inteq tools. Trouble shoot same on catwalk. PROD2 Deployed BHA, well still static PROD2 RIH to 200 ft, open EDC and displaced diesel out of CT to flow-pro. BHI's EDC ready in the Anchorage shop. BHI needs to setup to have it flow to the slope as soon as possible. PROD2 Tie-in from 80000 ft down at 150 fph, Corrected -7 ft PROD2 PUH working at regaining circulation. with the 9.1 ppb mud PROD2 Closed well in and shut EDC at 8,135 ft RIH and tagged the top of the AI billet at 8274 ft MD. PUH 5 ft to start ST PROD2 Start trough at 8,269 ft at 0.1 ft / 5 min at 90-96deg RTF Took WOB Op = 1.50 / 1.5 bpm w/ CTP of 2,800 / 3240 psi Density = 9.23 / 9.1 ppg BHP = 3407 psi at 11.02 ppg ECD. PROD2 Backed reamed trough, then reamed trough 2nd time at 3min/ 0.10 ft Op = 1.50 / 1.55 bpm w/ CTP of 2,800 / 3295 psi Density = 9.27 / 9.12 ppg BHP = 3660 psi at 11.84 ppg ECD. WHP = 153 psi PROD2 ST off the AI billet top at 8273.9 ft w/ 90 R TF Op = 1.59 / 1.58 bpm w/ CTP of 2,800 / 3274 psi Density = 9.24 / 9.12 ppg BHP = 3660 psi at 11.83 ppg ECD. WHP = 190 psi PROD2 Begin stacking a lot of weight at 8278'. 3-4.2k# DHWOB. Not making much progress. PU and RIH several times. Wear pad on motor may be hanging up on top of billet ? Working to bottom ok. WOB lower and able to get on btm. Drill to 8794'. PROD2 Back ream from 8280 to 8270 two times each at 60R and 120 R. Dry drift. Hole and kick off area smooth. PROD2 Open EDC. Circulate out of hole. 3000 psi at 1.75 bpm. Maintain WHP as per schedule. PROD2 PJSM with crew in Ops Cab. Pressure undeploy sidetrack BHA. Inteq motor and float sub left in hole. 1-1/2" MT box looking up on fish. Saw no evidence of this while drilling and reaming. 1-1/2" MT pin on btm of HOT shows good threads and evidence of blue loctite. PROD2 Call for Baker fishing hand and tools (motor with 1-1/2" MT pin down sub). PROD2 PU Baker tools. PJSM. MU and pressure deploy fishing BHA. Found 460 psi on well. PROD2 Run in hole. Follow WHP schedule. 300 psi inc in Pp at 769 ft while RIH Printed: 2/12/2007 70:14:15 AM gp Page 24 of 28 Operations Summary Report '.Legal Well Name: 2Z-13 '...Common Well Name: 2Z-13 Spud Date: 1/3/2007 ~~Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 (Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date ;From - To `Hours Task Code ~ NPT Phase Description of Operations ~ ' 2/4/2007 06:30 - 07:00 0.50 FISH N DFAL PROD2 Tie-in at 8000 ft. Corrected -7 ft 07:00 - 07:25 0.42 FISH N DFAL PROD2 RIH and tagged the top of the fish at 8,283 ft (bottom of fish at 8,294 ft TD) Inc. Op to 1.25 bpm, RIH, stalled motor 6 times at 8,283 ft. PUH and at 8120 ft open EDC j 07:25 - 09:15 1.83 FISH N DFAL PROD2 POOH as per pressure schedule. Held PJSM in the Ops Cab while POOH. Spoke of possible Hazards and how to mitigate them safety. 09:15 - 15:45 6.50 DRILL N DFAL PROD2 Tagged up, RIH 3.00 ft and trap 600 psi on wellhead Closed EDC and power down tool. Pressure undeploy BHA and fis? became stuck in the BOP. Worked several things and fish came free of BOP'. LD BHA and fishing tool. LD fish.. BHI RU Coiltrac and 2.5 AKO setting for build section. Grinding down wear pad on the next motor in the hole. Worked at getting the 2.5 AKO setting motor in the hole. Turned the wear pad to the inside of the AKO /bend and working the slickline to get BHA in the hole. Finally after 3 hrs, got the 2.5 deg motor in the hole. Finish pressure deploying the BHA in the hole. 15:45 - 17:15 1.50 DRILL P PROD2 RIH with EDC open following pressure schedule 17:15 - 17:30 0.25 DRILL P PROD2 Tied in and corrected -8 ft, closed EDC. 17:30 - 18:15 0.75 DRILL P PROD2 RIH using correct TF at 8150 ft, 8183 and 8274 ft. Tagged at 8294 ft. BHP high with a low ECD. PUH working on the BHP numbers. Reboot computer. Mud thinning. 18:15 - 00:00 5.75 DRILL P PROD2 Drill ahead. 3650 psi fs at 1.65 in/1.62 out. 300 dpsi. DHWOB: 1k#. WHP/BHP/ECD: 205/3746/12.07 ppg. IA/OA/PVT: 156/186/345 bbls. INC/AZM/TF: 53.2/186-187 / 15R. Drill ahead in build section. ROP: 40-60 fph. Getting 30 deg dog legs instead of the 45 planned. Not able to get a higher angle motor through BOPS based on deployment experience, so drill ahead. W III build to 105 deg to help get out of shale section as soon as possible. 2/5/2007 00:00 - 02:15 2.25 DRILL P PROD2 Drill ahead from 8420'. 3400 psi fs at 1.55 in/1.53 out. 200 dpsi. DHWOB: 4.3k#. WHP/BHP/ECD: 210/3744/11.97 ppg. IA/OA/PVT: 520/210/377 bbls. INC/AZM/TF: 97.5/205.9/15L. ROP: 10-20 fph. Complete build and turn. Projected inc at bit: 105 deg. 02:15 - 03:45 1.50 DRILL P PROD2 Wiper trip to window. Open EDC. Circulate out of hole. Maintain WHP as per schedule. Hold PJSM in Ops Cab while POH. 03:45 - 08:30 4.75 DRILL P PROD2 Pressure undeploy BHA. Chabged out BHA, crew change and PJSM on pressure deploying BHA 08:30 - 10:05 1.58 DRILL P PROD2 RIH with EDC open 10:05 - 10:25 0.33 DRILL P PROD2 Tied-in a from 8,000 ft (Corrected -8.5 ft) 10:25 - 12:00 1.58 DRILL P PROD2 RIH with correct TF. At 8,183 ft having trouble getting TF to 65 R. Got TF to 65R, RIH, MAD pass down from 8250 ft and checking survey points. Set down at 8,362 ft PU. RIH Having trouble getting in the hole at 8380 ft 70 ft into the A4 Shale. Working up through shales using low flowrates and slow running speeds. Set TF to 90L at 8,434 ft. WHP = 300 to 350 psi Tagged bottom, PUH and working way back to bottom after zeroing the BHI WOB. Final back on bottom, stalled Working to get back to bottom using negative CTW. Took 60 min to get back to bottom 12:00 - 12:30 0.50 DRILL P PROD2 Finally on bottom but that not any improvement, TF at 90 L HS. Printed: 272/'2007 10:14:15 AM ~ ~ gp Page 25 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date !From - To Hours Task Code ~ NPT I Phase Description of Operations 12/5/2007 ~ 12:00 - 12:30 ~ 0.50 ~ DRILL ~ P ~ PROD2 Drilling at 3 fph 12:30 - 13:00 0.50 DRILL P 13:00 - 16:40 3.67 DRILL P 16:40 - 17:05 I 0.421 DRILL I P 17:05 - 19:00 I 1.921 DRILL I P 19:00 - 20:00 1.00 DRILL P 20:00 - 22:00 2.00 DRILL P 22:00 - 23:30 I 1.501 DRILL I P 23:30 - 00:00 0.50 DRILL P 2/6/2007 00:00 - 01:15 1.25 DRILL P 01:15 - 02:45 1.50 DRILL P 02:45 - 05:00 2.25 DRILL P 05:00 - 06:55 I 1.921 DRILL I P 06:55 - 08:20 I 1.421 DRILL I P 08:20 - 10:15 I 1.921 DRILL I P Drilling up in A4 Shale. Op = 1.50 / 1.52 bpm Density = 9.24 / 9.20 ppg CTP 3,666 psi Vp = 350 bbls at 12:00 hrs WOB =negative CT weight (-2000 Ib). DHWOB = 1.5 - 2.5 klb BHP = 3,920 psi (12.53 ppg ECD) PROD2 Unable to drill, PUH to 8,350 ft. W/R back to bottom. PROD2 Drilling A4 Shale with 90-100L L TF PU hole at 8,466 ft and was able to get back to bottom wo/ much trouble. Turned TF down to 170E TF at 8,548 ft. Op = 1.58 / 1.54 bpm CTP = 3,790 psi Vp = 349 bbl at 13:00 hrs DHWOB = 2.65 klb. CTW / WOB = -3,6001bf. BHP = 3,715 psi w/ EDC of 11.70 ppg PROD2 Wipoer trip to clean the hole and check the shale stability. Trip out of hole was clean to 8,280 ft RIH and tagged at 8,390 ft, PU and worked through with low flowrate. Set down at 8,460 ft PUH reduced Op. RIH and tagged bottom at 8,600 ft PROD2 Drilling A4 Sand with 170E TF. Op = 1.52 / 1.52 bpm CTP = 3,450 psi Vp = 350 bbl at 17:00 hrs DHWOB = 1.5 klb. CTW / WOB = 30001bf. BHP = 3,799 psi w/ EDC of 12.2 ppg PROD2 Wiper trip to window. Smooth out. Set down at 8400', 8450', 8490'. Got through with reduced pump rate. PROD2 Drill ahead. 3380 psi fs at 1.50 in/1.51 out. 200 dpsi. DHWOB: 1.5k#. WHP/BHP/ECD: 205/3900/12.35 ppg. IA/OA/PVT: 181/220/346 bbls. INC/AZM/TF: 92.8/159.1/808. ROP: 75- 125 fph. Continue to drill at +/- 94 deg inc. PROD2 Wiper trip to window. Log GR tie in. Add 2' correction. RIH. Sat down at 8480' and 8460'. Rreduce circ rate and get past ok. PROD2 Drill ahead from 8900'. PROD2 Drill ahead. 3200 psi fs at 1.50 in/1.48 out. 250 dpsi. DHWOB: 0.75 - 1.5k#, WHP/BHP/ECD: 205/3766/12.17 ppg. IA/OA/PVT: 205/220/333 bbls. INC/AZM/TF: 96.4/181.7/1058. ROP: 50-100 fph. Drilling sand. PROD2 Wiper trip to window. Smooth in up direction. A few minor set downs from 8400' to 8500'. PROD2 Drill ahead from 9050'. LSRV at 30,000. Add flo vis to bring LSRV up to 35-40k. ROP slowing in shale section. INC/AZ M/T F : 90.8/ 197.3/ 165 R. PROD2 Drilling A4 Sand at 90 L TF Op = 1.55 / 1.51 bpm at CTP C~ 3050 / 3655 psi BHP 3790 psi at 12.27 ppg ECD DHWOB = 1.50 to 2.0 klb. CTW 2700 Ibf PROD2 Wiper trip to base of Billet # 2 at 8274 ft Small set downs at 9030 ft and 9150 ft. Used low flow rates to get through trouble shale PROD2 Drilling A4 Sand at 90-105 L TF Printed: 2/12/2007 10:14:15 AM • gp Page 26 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours ~ Task Code ~ NPT 2/6/2007 ~ 08:20 - 10:15 1.92 ~ DRILL ~ P Spud Date: 1/3/2007 Start: 1 /10/2007 End: 2/8/2007 Rig Release: 2/8/2007 Rig Number: Phase Description of Operations PROD2 10:15 - 14:45 I 4.501 DRILL I P I I PROD2 14:45 - 15:30 I 0.751 DRILL I P I I PROD2 15:30 - 19:00 ~ 3.50 ~ DRILL ~ P ~ ~ PROD2 19:00 - 20:00 1.00 DRILL P PROD2 20:00 - 21:15 1.25 DRILL P PROD2 21:15 - 21:40 I 0.421 DRILL I P I I PROD2 21:40 - 22:25 I 0.751 DRILL I P I I PROD2 22:25 - 23:00 I 0.581 DRILL I P I I PROD2 23:00 - 00:00 1.00 DRILL P PROD2 2/7/2007 00:00 - 00:30 0.50 DRILL P PROD2 00:30 - 01:15 0.751 DRILL P PROD2 01:15 - 01:30 0.25 CASE P RUNPRD 01:30 - 02:00 0.50 CASE P RUNPRD 02:00 - 06:30 4.50 CASE P RUNPRD Op = 1.55 / 1.51 bpm at CTP ~ 3,050 / 3,655 psi BHP 3790 psi at 12.16 ppg ECD DHWOB = 0.50 to 2.0 klb. CTW 3,200 Ibf Constant ROP of 60-65 fph to 9,244 ft Tagged possible fault at 9,244 ft ROP doppped down to 7 fph Possibel ankerite) Drilling A4 Sand at 150 L TF Op = 1.55 / 1.51 bpm at CTP @ 3,050 / 3,655 psi BHP 3790 psi at 12.16 ppg ECD DHWOB = 0.50 to 2.0 klb. CTW 3,200 Ibf Turned TF to 150 L to get out of ankerite and then will level out in sand at 88 deg Started mud swap at 1255 hrs at 9,273 ft Drilling A4 Sand at 90 L NBI at 86 deg After drill through the ankerite, made 100 ft wiper trip. OK Op = 1.55 / 1.51 bpm at CTP ~ 3,050 / 3,655 psi BHP 3790 psi at 12.16 ppg ECD DHWOB = 0.50 to 2.0 klb. CTW 3,200 Ibf Finally drilled through the ankerite at 9283 ft ROP increased from 5 fpm to 87 fph. Wiper trip to window. Got hung up at 8370'. Worked pipe and pull to 48k# to get free. Ream and back ream. Continue with wiper. Several other shale spots. Set down, reduce pump rate, then run in hole ok. Set down at 9038'. Work past. Continue in hole. Having trouble getting past 9080'. Reduce pump rate and WHP from 300 to 200 psi. Work to bottom. Orienter has locked up. Repower. re-boot, try all surface options. Orienter still not working. Call Town Team to discuss. Call TD. Mix 70 bbl bead pill while continue slow wiper. RBIH to 9350' POOH from TD while perform 30'/min wiper back to window while leaving 2 ppb beads in open hole 1.43/3000 w/ 200 psi whp. Had 10k overpull w/ MW at 8375', and couldn't go back in hole. Pull free at 58k w/ red pump rate. Continue wiper to window seeing other shales. Pull thru window, open EDC. Resume circ 1.55/2670 w! 200 psi whp Log tie-in down from 8000'. Corr +5' (this will not change 'official' TD) Park w/ EDC at 8100' and circ 1.56/2670 w/ 200 psi whp while wo vac truck to deliver KW F Start 10.6 ppg brine down CT 1.58/2500 to displace 9.1 ppg mud POOH for liner while fin displace wellbore to 10.6 ppg brine Finish POOH w/ drilling assy while fin displace wellbore to 10.6 ppg brine. Flow check, dead LD drilling BHA. Bit was 1-1-I. The bottom section of the BHI HOT had seperated -3" at an assumed internal keeper-got lucky in not leaving a fish Safety mtg re: liner RU floor tools to run liner. Perform kick drill w/ safety jt MU Unique Indexing Guide shoe + BTT O-ring sub on 30 slotted and 7 solid joints of 2-3/8" 4.44# L-80 STL liner (1209'). Install false table. Run CSH from derrick. MU singles and Printed: 2/122007 10:14:15 AM • gp Page 27 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 I ~ Task Code ~ NPT Date From - To ,Hours ~ i 2/7/2007 02:00 - 06:30 4.50 CASE P 06:30 - 07:15 0.75 CASE P 07:15 - 14:30 I 7.25 I CASE I P 14:30 - 15:00 I 0.501 CASE I P 15:00 - 16:30 I 1.501 CASE I P 16:30 - 16:45 0.25 CASE P 16:45 - 18:45 2.00 CASE P 18:45 - 19:30 I 0.751 RIGD I P 19:30 - 21:00 1 1.501 RIGD I P 21:00 - 22:45 I 1.751 RIGD I P 22:45 - 23:20 ~ 0.58 ~ RIGD ~ P 23:20 - 00:00 0.67 RIGD P 2/8/2007 00:00 - 00:45 0.75 RIGD P 00:45 - 03:00 2.25 RIGD P 03:00 - 04:00 I 1.001 BOPSUFi P 04:00 - 04:45 I 0.75 I BOPSUp P 04:45 - 05:45 I 1.001 BOPSUFt P Spud Date: 1 /3/2007 Start: 1 /10/2007 End: 2/8/2007 Rig Release: 2/8/2007 Rig Number: Phase 'I Description of Operations RUNPRD space out with pups. RUNPRD MU Inteq MW D tools. Stab coil. Get on well. Circulate to get air out of BHA before running in hole. RUNPRD Run in hole with liner assy. Getting gas and crude back. Circulate to try and clean up rtns. Weight check: 30K # up, 10k# do at 8000'. Run in open hole. Set down at 9092'. PU and makes several runs at it. Break circulation and make several runs, slow and fast. Pressure well to 300 psi. Make sevaeral attempts. Pressure well to 500 psi. Make several more attempts. Pressure up coil and well to 450 psi. Dump pressure quickly and run in hole. No progess. Wait on decisionfrom Town Team to release. Consider possible trip for orientor/agitator, but BTT indicates low probability of reentering splined deployment sub and risk of breaking off a spline RUNPRD Release from TOL at 7880'. Liner bottom at 9092'. Pull CSH to 8149'. Circulate 10.5 ppg KW ack to surface holding 300 psi WHP to re-kill well. RUNPRD Circulate out of hole holding 300 psi WHP. Get 10.5 ppg brine back to surface. Hold PJSM before tagging up. RUNPRD Bleed off WHP. Monitor well for flow. RUNPRD Get off well. Unstab coil. LD BHA tools. Stand back CSH in derrick. Load out CTLRT and false table. MU 2.25" nozzle assy. Stab onto well POST Oncoming crew found a leak at SWS pressure bulkhead. Safety mtg. Tighten and PT at 3000 psi POST RIH w/ nozzle assy while circ KWF 0.55/300. Swap to SW, incr rate 1.6/3000 and take returns to tiger tank while RIH. Got gas and crude back to surface by 7200'. Continue to circ 1.6/3050 w/ 300 psi whp and took 80 bbls of gas/crude cut KW F before returns were clean SW while parked at 7850' POST POOH while circ SW getting good SW returns back and following pressure schedule. Swap to diesel while POOH to FP the top 2500' of wellbore. Tag up, close swab and master valves SITP 640, IA 20, OA 200 POST Circ over swab while MIRU SWS N2 Safety mtg re: N2 POST Pump 10 bbls McOH followed by N2 and blow down reel POST Finish reel blowdown and bleed off to tiger tank POST LD BHA. Cut off CTC. Install internal grapple. Pull CT back to reel and secure, Set injector on legs and prep for move POST Begin ND ROPE (since Kuparuk valve shop won't set BPV thru rig BOP's). However, determine that stack is too high to use bridge crane to move BOP's out of the way. Then, Kuparuk valve shop determines they can set a BPV thru rig BOP's. NU BOPE. Find diesel leak on wellhead at flange below MV. Tighten all nuts and avg 3/4 tum each POST Fin clean pits, vac and supersuck cuttings box while wo valve crew to bring lubricator and extensions to BPV POST RU Kuparuk BPV crew w/ 24' of extensions and HP lubricator w/ 3" FMC BPV. PT lub at 650 psi. Open tree valves to 550 psi whp. Set BPV and PT from below w/ whp. Secure tree Printed: 2/72/2007 10:14:15 AM • i gp Page 28 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - T~ Hours ' Task Code NPT Phase Description of Operations __ - 2/8/2007 04:45 - 05:45 1.00 BOPSU P POST valves. RDMO Kuparuk BPV crew 05:45 - 10:30 4.75 BOPSU P POST ND BOPE. NU tree cap. Fill tree with diesel. Pressure test treee cap to 5000 psi. Continue to prep for move. Load out trailers, extra liner, misc equipment. Release tanks and hard line. Release rig at 1030 hrs on 2/8/07. Printed: 2/12/2007 10:14:15 AM bP ~ BP Alaska Baker Hu hes INTE Surve Re ort g Q Y P s~ INTEQ Company: BP Amoco Datc: 2/15/2007 Time: 08:39:11 Page: 1 Field: Kuparuk Co-ordinate(NE) Reference: Well: 13, True North Site: KRU 2Z Pad Vertical (TVD) Reference: ZZ Orig Datum1 109.0 Well: 13 Section (VS) Reference: Well (O.OON,O.OOE,191.07Azi) i Wellpath: 22-13AL1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: KRU 2Z Pad Site Position: Northing: 5964759.45 ft Latitude: 70 18 53.244 N From: Map Easting: 529716.16 ft Longitude: 149 45 32.972 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 13 Slot Name: Well Position: +N/-S 1131.45 ft Northing: 5965889.81 ft Latitude: 70 19 4.372 N +E/-W -244.55 ft Easting : 529467.16 ft Longitude: 149 45 40.107 W Position Uncertainty: 0.00 ft Wellpath: 2Z-13AL1 Drilled From: 2Z-13AL1 PB1 Tie-on Depth: 8244.30 ft Current Datum: 2Z Orig Datum1 Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/31/2007 Declination: 23.54 deg Field Strength: 57611 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 109.00 0.00 0.00 191.07 Survey Program for Definitive Wellpath Date: 1/31/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 0.00 8100.00 Gyro (0.00-8525.00) (0) GCT-MS Schlumberger GCT muftishot 8150.70 8181.73 MWD (8150.70-9300.00) (5) MWD MWD -Standard 8199.60 8244.30 MWD (8199.60-9538.00) (6) MWD MWD -Standard 8274.00 9350.00 MWD (8274.00-9350.00) MWD MWD -Standard Annotation NfD TVD ft ft 8244.30 6066.15 TIP 8274.00 6086.49 KOP 9350.00 6057.53 TD Survey: MWD Start Date: 2/5/2007 Company: Baker Hughes tNTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ~qG-r7~ by ~ BP Alaska Baker Hu hes INTE Surve Re ort g Q Y P s INTEQ Company: BP Amoco Date: 2/15/2007 Time: 08:39:11 Page: 2 Field: Kuparuk Co-ordinate(NE) Reference: Well: 13, True North Site: KR U 2Z Pad Verti cal (TVD) Reference: 2Z Orig Datum1 109.0 Well: 13 Section (VS) Reference: Well (O.OON,O. OOE,191.07Azi) Wellpath: 2Z- 13AL1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Aaim TVD Sys T<~ N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft $244.30 40.15 183.00 6066.15 5957.15 -5033.26 -1099.35 5960852.77 528387.68 5150.69 0.00 MWD 8274.00 53.15 183.50 6086.49 5977.49 -5054.78 -1100.58 5960831.25 528386.54 5172.04 43.79 MWD 8300.09 57.43 209.43 6101.52 5992.52 -5075.02 -1106.69 5960810.99 528380.50 5193.07 83.06 MWD 8320.41 64.23 210.07 6111.42 6002.42 -5090.41 -1115.50 5960795.57 528371.76 5209.87 33.58 MWD 8340.47 69.90 209.94 6119.23 6010.23 -5106.40 -1124.73 5960779.54 528362.59 5227.34 28.27 MWD 8360.57 75.68 209.76 6125.17 6016.17 -5123.05 -1134.28 5960762.86 528353.11 5245.50 28.77 MWD 8380.25 82.38 207.61 6128.92 6019.92 -5139.99 -1143.55 5960745.88 528343.91 5263.91 35.69 MWD 8400.74 90.14 205.94 6130.25 6021.25 -5158.23 -1152.75 5960727.61 528334.78 5283.58 38.73 MWD 8420.19 98.02 206.04 6128.87 6019.87 -5175.65 -1161.24 5960710.15 528326.35 5302.31 40.52 MWD 8435.11 104.76 200.78 6125.92 6016.92 -5189.06 -1167.06 5960696.72 528320.60 5316.58 56.86 MWD 8453.20 105.85 195.78 6121.15 6012.15 -5205.62 -1172.53 5960680.14 528315.19 5333.88 27.33 MWD 8483.65 106.03 190.40 6112.78 6003.78 -5234.13 -1179.16 5960651.61 528308.67 5363.13 17.00 MWD 8513.65 105.79 185.71 6104.55 5995.55 -5262.68 -1183.20 5960623.04 528304.74 5391.93 15.06 MWD 8543.99 104.92 181.04 6096.51 5987.51 -5291.88 -1184.92 5960593.84 528303.14 5420.92 15.12 MWD 8573.30 100.80 178.17 6089.99 5980.99 -5320.44 -1184.72 5960565.28 528303.45 5448.91 16.99 MWD 8603.30 95.56 174.99 6085.72 5976.72 -5350.07 -1182.94 5960535.67 528305.35 5477.65 20.37 MWD 8633.41 93.40 169.99 6083.37 5974.37 -5379.82 -1179.02 5960505.94 528309.39 5506.09 18.04 MWD 8660.26 92.47 165.25 6081.99 5972.99 -5406.00 -1173.27 5960479.78 528315.24 5530.68 17.97 MWD 8690.02 91.80 159.06 6080.88 5971.88 -5434.30 -1164.16 5960451.52 528324.46 5556.70 20.91 MWD 8723.74 92.81 153.25 6079.52 5970.52 -5465.10 -1150.54 5960420.78 528338.19 5584.32 17.47 MWD 8752.67 93.67 149.78 6077.89 5968.89 -5490.49 -1136.77 5960395.45 528352.06 5606.59 12.34 MWD 8780.16 94.04 155.51 6076.04 5967.04 -5514.84 -1124.17 5960371.15 528364.75 5628.07 20.84 MWD 8810.31 94.90 161.42 6073.69 5964.69 -5542.78 -1113.14 5960343.25 528375.89 5653.38 19.75 MWD 8840.73 94.59 167.29 6071.17 5962.17 -5571.96 -1104.97 5960314.11 528384.18 5680.45 19.26 MWD 8870.09 94.78 172.52 6068.77 5959.77 -5600.76 -1099.85 5960285.33 528389.42 5707.73 17.77 MWD 8900.15 95.42 176.87 6066.10 5957.10 -5630.57 -1097.08 5960255.54 528392.30 5736.45 14.57 MWD 8930.36 96.41 181.75 6062.98 5953.98 -5660.60 -1096.71 5960225.51 528392.78 5765.86 16.40 MWD 8960.52 96.35 187.32 6059.63 5950.63 -5690.47 -1099.08 5960195.63 528390.53 5795.62 18.35 MWD 9000.84 94.04 192.97 6055.97 5946.97 -5729.98 -1106.16 5960156.10 528383.61 5835.75 15.08 MWD 9030.17 93.02 197.34 6054.17 5945.17 -5758.23 -1113.81 5960127.83 528376.07 5864.95 15.27 MWD 9062.38 92.84 202.49 6052.52 5943.52 -5788.46 -1124.76 5960097.55 528365.24 5896.72 15.98 MWD 9093.80 89.19 204.82 6051.96 5942.96 -5817.23 -1137.36 5960068.74 528352.75 5927.37 13.78 MWD 9122.82 87.50 208.87 6052.80 5943.80 -5843.10 -1150.46 5960042.81 528339.76 5955.28 15.12 MWD 9153.77 88.57 203.49 6053.86 5944.86 -5870.85 -1164.10 5960015.01 528326.23 5985.13 17.71 MWD 9183.03 88.82 197.73 6054.53 5945.53 -5898.22 -1174.39 5959987.61 528316.04 6013.97 19.70 MWD 9216.43 89.25 191.37 6055.09 5946.09 -5930.53 -1182.78 5959955.27 528307.79 6047.28 19.08 MWD 9246.08 89.22 185.69 6055.49 5946.49 -5959.84 -1187.17 5959925.95 528303.50 6076.89 19.16 MWD 9276.58 86.48 182.25 6056.63 5947.63 -5990.23 -1189.28 5959895.55 528301.51 6107.13 14.41 MWD 9306.49 88.85 178.37 6057.85 5948.85 -6020.11 -1189.45 5959865.67 528301.47 6136.48 15.19 MWD 9350.00 92.00 172.00 6057.53 5948.53 -6063.44 -1185.80 5959822.36 528305.29 6178.30 16.33 MWD z ,~' by BP Alaska Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 2/15/2007 Time: 08:36:48 Page: 1 Field: Kuparuk Co-ordinate(NE) Reference: Well: 13, True North Site: KRU 2Z Pad Vertical (TVD) Reference: 2Z Orig Datum1 109.0 We11: 13 Section (VS) Reference: Well (O.OON,O.OOE,191.27Azi) Wellpath: 2Z-13AL1 P61 Survey Calculation Method: Minimum Curvature Db: Orade Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: KRU 2Z Pad Site Position: Northing: 5964759.45 ft Latitude: 70 18 53.244 N From: Map Easting: 529716.16 ft Longitude: 149 45 32.972 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 13 Slot Name: Well Position: +N/-S 1131.45 ft Northing: 5965889.81 ft Latitude: 70 19 4.372 N +E/-W -244.55 ft Easting : 529467.16 ft Longitude: 149 45 40.107 W Position Uncertainty: 0.00 ft Wellpath: 2Z-13AL1 PB1 Drilled From: 2Z-13A Tie-on Depth: 8181.73 ft Current Datum: 2Z Orig Datuml Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 12/14/2006 Declination: 23.59 deg Field Strength: 57609 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 109.00 0.00 0.00 191.27 Survey Program for Definitive Wellpath Date: 12/14/2006 Validated: No Version: 5 Actual From To Survey Toolcode Tool Name ft ft 0.00 8100.00 Gyro (0.00-8525.00) (0) GCT-MS Schlumberger GCT multishot 8150.70 8181.73 MWD (8150.70-9300.00) (5) MWD MWD -Standard 8199.60 9538.00 MWD (8199.60-9538.00) MWD MWD -Standard Annotafion Mn Tw ft ft 8181.73 6028.63 TIP/KOP 9538.00 6040.42 TD Survey: MWD Start Date: 1/26/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD Sys TVD N!S E/W MapN i11apE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 8181.73 61.13 170.31 6028.63 5919.63 -4983.85 -1099.60 5960902.18 528387.24 5102.65 0.00 MWD 8199.60 60.01 180.00 6037.43 5928.43 -4999.33 -1098.28 5960886.71 528388.62 5117.57 47.63 MWD 8221.77 49.56 182.32 6050.19 5941.19 -5017.41 -1098.62 5960868.63 528388.35 5135.37 47.90 MWD 8244.30 40.15 183.00 6066.15 5957.15 -5033.26 -1099.35 5960852.77 528387.68 5151.06 41.82 MWD 8274.02 53.16 183.50 6086.50 5977.50 -5054.80 -1100.58 5960831.23 528386.53 5172.42 43.79 MWD 8301.00 66.79 183.00 6099.97 5990.97 -5078.06 -1101.90 5960807.96 528385.31 5195.50 50.54 MWD 8331.05 78.14 180.71 6109.01 6000.01 -5106.65 -1102.80 5960779.37 528384.52 5223.71 38.46 MWD 8369.80 92.47 171.31 6112.18 6003.18 -5145.03 -1100.10 5960741.01 528387.38 5260.82 44.15 MWD 8400.42 92.72 175.33 6110.80 6001.80 -5175.41 -1096.54 5960710.65 528391.05 5289.91 13.14 MWD 8430.32 93.09 179.72 6109.28 6000.28 -5205.23 -1095.25 5960680.83 528392.46 5318.91 14.72 MWD 8460.53 93.30 184.12 6107.60 5998.60 -5235.37 -1096.26 5960650.69 528391.57 5348.67 14.56 MWD ~~6-r 1/ bP ~ BP Alaska Baker Hu hes INTE Surve Re ort g Q Y P INTEQ Company: BP Amoco Date: 2/15/2007 Time: 08:36:48 Page: 2 Field: Kuparuk Caordinate(NE) Reference: Well: 13, True North Site: KR U 2Z Pad Ver tical (TVD) Reference: 2Z Orig Datuml 109.0 Well: 13 Section (VS) Reference: Well (O.OON,O.OOE,19L27Azi) Wellpath: 2Z-13AL1 P61 Survey Calculation Method: Minimum Curv ature Db: Oracle Survey MD Incl Azim TVD Sys 1'VD N/S E/W MapN MapE VS DIS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 8488.86 92.93 188.65 6106.05 5997.05 -5263.48 -1099.40 5960622.58 528388.53 5376.85 16.02 MWD 8528.60 93.36 193.82 6103.87 5994.87 -5302.38 -1107.13 5960583.65 528380.96 5416.51 13.03 MWD 8560.15 93.98 197.79 6101.85 5992.85 -5332.67 -1115.70 5960553.33 528372.50 5447.89 12.71 MWD 8590.93 93.95 199.50 6099.72 5990.72 -5361.77 -1125.52 5960524.20 528362.80 5478.34 5.54 MWD 8620.05 95.21 196.45 6097.40 5988.40 -5389.37 -1134.48 5960496.56 528353.96 5507.17 11.30 MWD 8650.57 94.32 192.05 6094.86 5985.86 -5418.84 -1141.96 5960467.06 528346.59 5537.53 14.66 MWD 8681.83 94.50 188.58 6092.46 5983.46 -5449.50 -1147.54 5960436.38 528341.13 5568.69 11.08 MWD 8711.77 95.24 185.05 6089.92 5980.92 -5479.12 -1151.08 5960406.76 528337.71 5598.43 12.00 MWD 8741.07 95.34 179.50 6087.21 5978.21 -5508.26 -115224 5960377.62 528336.66 5627.23 18.86 MWD 8780.21 96.54 173.32 6083.16 5974.16 -5547.09 -1149.81 5960338.80 528339.25 5664.84 16.00 MWD 8810.25 95.49 169.67 6080.01 5971.01 -5576.63 -1145.39 5960309.28 528343.78 5692.95 12.58 MWD 8840.28 93.80 165.17 6077.58 5968.58 -5605.84 -1138.87 5960280.10 528350.42 5720.31 15.96 MWD 8874.70 92.41 162.57 6075.71 5966.71 -5638.85 -1129.32 5960247.13 528360.09. 5750.82 8.56 MWD 8905.49 93.52 166.29 6074.12 5965.12 -5668.47 -1121.07 5960217.55 528368.46 5778.25 12.59 MWD 8937.75 94.17 171.62 6071.95 5962.95 -5700.04 -1114.90 5960186.00 528374.75 5808.02 16.61 MWD 8970.41 96.79 175.60 6068.83 5959.83 -5732.34 -1111.28 5960153.72 528378.49 5838.99 14.54 MWD 9002.92 95.18 178.34 6065.44 5956.44 -5764.63 -1109.58 5960121.44 528380.33 5870.31 9.74 MWD 9031.22 96.94 180.16 6062.45 5953.45 -5792.76 -1109.21 5960093.31 528380.81 5897.84 8.92 MWD 9060.86 96.38 183.89 6059.02 5950.02 -5822.18 -1110.25 5960063.89 528379.88 5926.89 12.64 MWD 9092.16 95.05 186.00 6055.90 5946.90 -5853.21 -1112.93 5960032.86 528377.32 5957.84 7.94 MWD 9120.03 94.81 187.46 6053.50 5944.50 -5880.78 -1116.19 5960005.28 528374.17 5985.52 5.29 MWD 9152.18 91.37 189.83 6051.77 5942.77 -5912.51 -1121.01 5959973.53 528369.47 6017.58 12.99 MWD 9180.28 92.38 192.95 6050.85 5941.85 -5940.04 -1126.56 5959945.98 528364.04 6045.66 11.66 MWD 9213.81 92.53 196.68 6049.41 5940.41 -5972.42 -1135.12 5959913.57 528355.60 6079.09 11.12 MWD 9240.89 92.78 198.98 6048.16 5939.16 -5998.17 -1143.40 5959887.79 528347.42 6105.96 8.53 MWD 9270.86 92.87 202.30 6046.68 5937.68 -6026.18 -1153.95 5959859.75 528336.98 6135.49 11.07 MWD 9301.66 93.54 203.22 6044.96 5935.96 -6054.54 -1165.85 5959831.34 528325.20 6165.63 3.69 MWD 9335.02 93.51 204.03 6042.91 5933.91 -6085.04 -1179.19 5959800.79 528311.97 6198.16 2.43 MWD 9373.59 91.06 204.74 6041.37 5932.37 -6120.14 -1195.11 5959765.63 528296.20 6235.69 6.61 MWD 9401.83 91.15 202.36 6040.83 5931.83 -6146.02 -1206.39 5959739.71 528285.03 6263.27 8.43 MWD 9434.91 90.17 199.96 6040.45 5931.45 -6176.87 -1218.32 5959708.82 528273.21 6295.86 7.84 MWD 9469.65 89.98 198.03 6040.40 5931.40 -6209.71 -1229.63 5959675.93 528262.03 6330.28 5.58 MWD 9538.00 89.98 198.03 6040.42 5931.42 -6274.71 -1250.79 5959610.86 528241.13 6398.16 0.00 MWD Well Name: 2Z-13 Wellbore Diagram Tree: FMC Gen III 3-1/2" 5k psi o API# 50-029-213600 Conoc Phil li s PTD: A~aska 2Z-13A 206-170 50-029-21360-01-00 2Z-13AL1 206-171 50-029-21360-60-00 Conductor 80.0 ft 16" 62#ft H-40 Baker FVL SSSV 2.81 " ID 1820.00 ft Locked out Surface #1 Merla GLM TMPD w! Dummy 2010.00 ft 9-5/8" 36#/ft J-55 #2 Merla GLM TMPD w/ Dummy 4132.00 ft 4203.0 ft ® ~~-Calista 3-112" 9.30#/ft J-55 EUE 8rd ID = 2.995" Cleaned out to 8164 ft 2.80" 1 Perforations 8010 ft 8060 -4-2-1 Sand BHP = 2600 Psi 7') d 1115/2006 ft 8096 ft '9e TOWS @ 8,150.7 ff RA Marker @ 8,156.00 ft BOWS @ 8,159.40 ft TD 9350' w/ shoe at 9090' #3 Merla GLM TMPD w/ Dummy 5702.00 ft #4 Merla GLM TMPD w/ Dummy 6360.00 ft #5 Merla GLM TMPD w/ Dummy 6735.00 ft #6 Merla GLM TMPD w/ Dummy 7119.00 ft #7 Merla GLM TMPD w/ Dummy 7474.00 ft #8 Merla TPDX w/ Dummy 7794.61 ft Baker PBR 7835.64 ft Baker FHL Packer 7849.00 ft ~ #9 Merla TPDX w/ Dummy 7888.00 ft Top of 2-3/8" Liner is at 7881' #10 Merla TPDX w/ Dummy 7961.00 ft 3-1/2" FL4S Blast Joint 7999.51 ft Leak In Blast Rings BOT Blast Steel Collar 8097.08 ft #11 Merla TPDX w/ Dummy 8130.84 ft GLM 11 bad Discriminator ~ Locator Sub 8150.28 ft bent Baker FB-1 Packer 8151.13 ft 4.33 ftMill-Out Extension 8154.43 ft 4 toooo Billet #1 @ 8,183 ft 65RHS Billet #2 @ 8,274 ft 90RHS 2Z-13A 2Z-13AL1 PBTD 7" 26#/ft K-55 Prepared by Dave Hildreth Orbis Engineering Inc Houston, Texas Shoe 8506.0 ft 8,418 ft WLMD 1 3/1 /2007 TD at ALASKA OIL AND GAS CONSERVATION COMMISSION Aras Worthington CT Drilling Engnieer ConocoPhillips Alaska Inc. C/o PO Box 196612 Anchorage, AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7`" AVENtiE, StiITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Re: Kuparuk River Field, Kuparuk River Oil Pool, Kuparuk 2Z-13AL 1 ConocoPhillips Alaska Inc. Permit No: 206-171 Surface Location: 1131' FSL, 244' FEL, SEC. 11, Tl 1N, R09E, UM Bottomhole Location: 590' FNL, 1475', FEL, SEC. 23, T11N, R09E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this,S/day of December, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~~~EI V EV STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI N DEC 0 6 2006 PERMIT TO DRILL n:. o. r__ r...a r+.,,v,n,~cc~nn 20 AAC 25.005 ~~I 1 a. Type ee 1 b. rrent Well Class ^ Exploratory ^ Development Gas ^ Drill ®Redy1~C 01'8~~ ^ Service ^ Multiple Zone ^ Re-Entry ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shaie Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180. 11. Well Name and Number: Kuparuk 2Z-13AL1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10250 • TVD 5894ss" 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 1131' FSL 244' FEL SEC 11 T11N R09E UM 7. Property Designation: ADL 025653 ' River Pool , , . , , , Top of Productive Horizon: 3731' FNL, 1353' FEL, SEC. 14, T11 N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 25,2006 Total Depth: 590' FNL, 1475' FEL, SEC. 23, T11N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 24,700' 4b. Location of Well (State Base Plane Coordinates): Surface: x-529467. y-5965890 Zone-ASP4 10. KB Elevation (Height above GL): 109' feet 15. Distance to Nearest Well Within Pool: 750' 16. Deviated Wells: Kickoff Depth: 8250 ~ feet Maximum Hole An le: 98 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2616 Surface: 2026 18. Casin Pr m: S cifi tion T - S De th - Bo om u nti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2090' 8160' 5908' 10250' 894' Uncem n ed lotted Liner 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11350 Total Depth TVD (ft): 6013 Plugs (measured): None Effective Depth MD (ft): 11350 Effective Depth TVD (ft): 6013 Junk (measured): None acing 'Length ize Cement Volume D TVD Conductor/Structural 102' 16" 255 xP rmafrost' 10 ' 102' Surface 4203' 9-5/8" 1150 x Coldset III 450 sx CS II 42 3' 3360' Intermediate Pr u tion 8 7' 7" 375 x I 'G' 1 0 x PF 'C' 07' 249' Liner Liner 3100' 2-318" Uncemented Slotted Liner 8250' - 11350' 5970' - 6013' Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Aras Worthington, 564-4102 Printed Name Ar s Worthingto Title CT Drilling Engineer Prepared By Name/Number: Si nature .S' a'~C~~ Phone 564-4102 Date Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill ,,~, Number: ~- ~c " API Number: 50-029-21360-60-00 Permit Appro al Da e: ' ~ ~' (] See cover letter for ther re uir m nts Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me~tha/ne, gas hydrates, or gas contained shales: ,_,/ ~~Q ~ ~ ~'~ "~'t-5`~` ~~, ~~ ~~~ Samples Req'd: ^ Yes L~ No Mud Log Req'd: ^ Yes L~ No /~,~5'+~ft~.~ ~~;~ ~ ~~~~~~ ~ A~~~~ ~~.C..t,~~S Measures: Yes ^ N Directional Survey Req'd: I~Yes ^ No Other: `~ L/~, APPROVED BY THE COMMISSION Date ~~j O v ,COMMISSIONER Form 10-401 Revised 12/2005 vV ~ / ~ Submit In Duplicate !~ ~ ~?~ is/Y/o6 ~RU 2Z-13A 8~ AL1 Sidetrack - Coile4ti'ubing Drilling Summary of Operations• A coiled tubing drilling unit will drill two laterals in KRU 2Z-13 using the managed pressure drilling technique (MPD, see description below). 2Z-13A and 2Z-13AL1 horizontal laterals will target Kuparuk A4 sand reserves for production. - CTD Drill and Comulete 2Z-13A & AL1• Planned for December 25 2006 Pre-Rig Work 1. S Obtain pressure data (SBHPS) from A&C sand reservoirs via tbg-tail plug 2. S DGLVS, pull Station #9 (production valve) 3. DHD MIT-IA and OA 4. E Shoot holes in tbg tail w/ tbg puncher, 10' interval (8165' - 8175') 5. C or F Pump CaC03 pill into C-sands through straddle to plug off C-sand 6. S Tag Top of CaC03 and correct depth to RKB 7. C FCO through CaC03 plug & PT/drawdown test to see if plug holds 8. C Cement P&A 9. 10. O S PT cement plug to 500 psi •~ ~ Tag TOC 11. DHD PT Master & Swab to 4500 psi (Done, passed, 11/5/2006) 12. DHD Drawdown test on Master & Swab to 0 psi (Done, passed, 11/5/2006) 13. S Drift & tag to PBTD 14. O Torque wellhead flange-bolts to spec. 15. O Set BPV. Bleed OAP and IAP to 0 psi 16. O Bleed gas lift and production flowlines down to zero and blind flange 17. O Remove wellhouse, drill mouse hole, level pad 1. MIRU Nor is -1/16" BOPE, test 2. Mi112.74" window off of cem The planned KOP is at 8185' in the B shale. 3. Drill northern 3" bicenter hole horizontal later A from window ' Note: If ankerite la er is 8 uparuk A4 sands. a a o erite rather than undulate through the ankerite. 4• e e wit 2 3/8" slotted liner and Aluminu ~ 5. Kick off from 2Z-13A @ 8250' MD and drill southern 3" bicenter hole horizontal lateral (2Z-13AL1) from window to 10,250' TD targeting Kuparuk A4 sands. ~~,., Note: If ankerite layer is thick, may add a lateral above the ankerite rather than undulate through the ankerite. !~ ° ' 6. Kill well & complete with 2 3/8" slotted liner from TD to 8160' md. <{"~ 7. ND BOPE. RDMO Nordic 2. Post RiQ work 8. Post CTD rig -Run GLVs. Mud Program: • Step 1-3 & 5: chloride-based flo-pro (8.6 ppg) • Steps 4 & 6: chloride-based brine or flo-pro (8.8 ppg) Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 2Z-13A: 2 3/8", 4.6#, L-80, STL o Slotted liner from 8,250' and - 11,350' and w/ Aluminum billet top • 2Z-13AL1: 2 3/8", 4.6#, L-80, STL o Slotted liner from 8160' and -10,250' and ~U 2Z-13A ~ AL1 Sidetrack - Coiled~bing Drilling Casing/Liner Information 9 5/8", J-55, 36#, Burst 3520; collapse 2020 psi. 7", J-55, 26#, Burst 4980; collapse 4320 psi 3-1/2", J-55, 9.3#, Burst 6980; collapse 7400 psi Well Control: • Two well bore volumes (250 bbls) of KWF will mixed and in the Kuparuk field during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 2Z-13A and 2Z-13AL1. ' • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ' • The nearest well to 2Z-13A is 2Z-O1 which is offset by 500'. The KPA boundary is 25,600' away. • The nearest well to 2Z-13AL1 is 2D-03 which is offset by 750'. The KPA boundary is 24,700' away. Logging • MWD directional, Gamma Ray, and resistivity will be run over all of the open hole section. ° Hazards • 2Z-13A and 2Z-13AL1 laterals will cross several mapped faults. Lost circulation risk is moderate. • We112Z-13 has an H2S level of 50 ppm. All H2S monitoring equipment will be operational. Reservoir Pressure • The most recent SBHP survey (11-15-06) was gauged at 2616 psi after a short term shut-in. The EMW is 8.6 ppg at 5900' TVD. Max. surface pressure with gas (0.1 psi/ft) to surface is 2026 psi. Variance request • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 2Z-13A and 2Z-13AL1 it will be routine to close the 2" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at the 2Z-13A and 2Z- 13AL1 at TD: ~RU 2Z-13A & AL1 Sidetrack - Coile~ubing Drilling • Estimated reservoir pressure: 2600 psi at 5900' TVD, 8.6 ppg EMW. ' • Expected annular friction losses while circulating: 740 psi (based on 90 psi/1000 ft) • Planned mud density: 8.6 ppg equates to 2640 psi hydrostatic bottom hole pressure. • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3380 psi or 11.0 ppg ECD • When circulation is stopped, a minimum of 740 psi surface pressure will be applied to maintain constant BHP. KRU 2Z-13 CTD Sidetrack A4-sand CTD Completion Total Proposed Footage = 6000' 9-5/8" shoe C-sand perfs (isolated w/ CaCO3 and/or cement) Leak in straddle @ ~~ 8082' RKB 2-3/8" liner top @ 8160' 1000' 2Z-13AL2 north lateral (contingency for ankerite) 2Z-13A North lateral TD a@ 11350' and (agitator limit 300# wob) 2-3/8" slotted liner Optional ~ Aluminum billet (ankerite contingency) Wrxbw in T' 26# J55 casing A5 sanc perfs A4 sand perfs 7" shoe ~~~ G. 3-'/2" SSSV set at 1820' (locked out) F. 3-1/2" 9.3# J-55 EUE 8rd Mod tubing w/ 3-1/2" x 1"gas lift mandrels E. 3-'/2" x 7" packer at 7849' D. 3-1 /2" production mandrels C. 3-'/Z° x 7" packer at 8151' B. 3-'/z" nipple with 2.75" ID at 8167' A. 3-1/2" tubing tail at 8175' Cement KOP at 8185' MD luminum bill t $Z50-'--- ~` ~ .~ ~ . a Optional Aluminum billet (ankerite contingency) 2Z-13AL1 sou lateral, TD @ 10 0' ----- ------ 2-3/8" slotted liner ~~ai ~rrr ~~~~ ~~ { 1000' 2Z-13AL3 south lateral (contingency for ankerite) ConocoPhilli s Alaska Inc. p 2Z-13 API: sssv SSSV Type: I ! (1820-1821, ~~3•~0) Annular Fluid: OUT ~ Orig KRU Last Strip -ALL STRING on ONDUCTOR 1 UR. CASING ! tOD. CASING ' Strinn - TI 1RIN(; PBR (7836-7837, ! OD:3.500) PKR (7849-7850, OD:6.151) PKR (8151$152, 00:6.151) NIP (8167-8168, OD:3.500) TUBING (0$175, OD:3.500, x:2.992) PeR (82288238) Pert (8255-8285) 2Z-13 42 deg @ 8009 49 deg @ 8525 ov w - ouvv 8090 - 8096 aavo - oy4w 5966 - 5971 -w,t,-c,l,- i UNIT B vv 6 IG 12 ii Iii IyBJ 7/15/1985 Irtnr IPERF o Irz- xnwmcer er 5 1/2" Schlumber er 8228 - 8238 6064 - 6070 A-5 10 4 7/15/1985 IPERF 4" HP Jet II 8255 - 8285 6082 - 6103 A-4 30 4 7/15/1985 IPERF 4" HP Jet II Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD latch Port TRO Date Run Vlv Cmnt 1 2011 1865 Merla TMPD GLV 1.0 BK 0.156 1263 2/2/2004 2 4132 3311 Merla TMPD GLV 1.0 BK 0.250 1418 2/2/2004 3 5702 4324 Meda TMPD OV 1.0 BK 0.250 0 2/1/2004 4 6360 4768 Mena TMPD DMY 1.0 BK 0.000 0 2!1/2004 5 6735 5023 Meda TMPD DMY 1.0 BK 0.000 0 7/15/1985 6 7119 5280 Meda TMPD DMY 1.0 BK 0.000 0 2/1/2004 7 7474 5522 Meda TMPD DMY 1.0 BK 0.000 0 7/15/1985 8 7795 5749 Mena TPDX DMY 1.5 RM 0.000 0 2/1/2004 Production MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 9 7888 5817 Meda TPDX CV 1.5 RM 0.250 0 1/7/2005 O n 10 7961 5871 Meda TPDX CV 1.5 RM 0.000 0 1/8/2005 O n 11 8131 5996 Merla TPDX DMY 1.5 RM 0.000 0 2/26/199 Closed Other lu s e ui ., etc. -JEWELRY De th TVD T e Descri lion ID 1820 1722 SSSV Baker'FVL' Locked Out 6/5/90 Waivered 2/16/97 2.810 7836 5779 PBR Baker 3.000 7849 oic~ 5789 cn~n PKR nvo Baker'FHL' o..i...-pro ,.. 3.000 .,,.,.,, rwn - r~.~n De th Descri lion Comment 8297 1"GLV No Latch Fell Downhole 8297 1 1/2" CV on RM Fell Down in Rathole 8303 1 1/2" CV on RM Lost runnin in hole General Notes Date Note 0/10/199 Found LEAK in Blast Rings @ 8047' (WLM) (10/10/97) GLM # 11 Bad Ca) 8131': Discriminator Bent Over -SEE WSR 4/27/93) • by BP Alaska ~ Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 11130/2006 Time: 10:37:52 Page: 1 "Field: Kupatuk Co-ordinate(NE) Refereace: WeII: 13, True North Site: KRU 2Z Pad Vertical (TVD) Reference: 2Z-13 109.0 Well: 13 Section (VS) Reference: Well (O.OON,O.OOE,185. OOAzi) Wellpath: Plan 4, 2Z-13AL1 Sdrvey Calculation Method: Minimum Curvature Db: OraGe Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: WeII Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: KRU 2Z Pad Site Position: Northing: 5964759 .45 ft Latitude: 70 18 53.244 N From: Map Fasting: 529716 .16 ft Longitude: 149 45 32.972 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg WeII: 13 Slot Name: Well Position: +N/-S 1131.45 ft Northing: 5965889.81 ft Latitade: 70 19 4.372 N +E/-W -244.55 ft Fasting : 529467.16 ft - Longitude: 149 45 40.107 W Position Uncertainty: 0.00 ft Wellpath: Plan 4, 2Z-13AL1 Drilled From: Plan 3, 2Z-13A Tie-on Depth: 8250.00 ft Current Datnm: 2Z-13 Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/30/2006 Declination: 23.61 deg Field Streegth: 57608 nT Mag Dip Angle: 80.82 deg Vertical Sectioa: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 109.00 0.00 0.00 185.00 Plan: Plan #4 Date Composed: 11/30/2006 copy Lamar's plan 4 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Map Map ' <----' :Latitude ---> <-- Longitude ---> Name Description TVD +N/-S +E/-W Northing Fasting Deg Miu Sec Deg fin Sec Dip. Dir. ft ft ft ft ft 2Z-13A Polygon 109.00 -5213.68 -1449.78 5960671.00 528038.00 70 18 1.3.094 N 149 46 22.380 W -Polygon 1 109.00 -5213.68 -1449.78 5960671.00 528038.00 70 18 13.094 N 149 46 22.380 W -Polygon 2 109.00 -5331.07 -587.15 5960557.00 528901.00 70 18 11.941 N 149 45 57.227 W -Polygon 3 109.00 -4661.94 -348.49 5961227.00 529137.00 70 18 18.522 N 149 45 50.270 W -Polygon 4 109.00 -3832.46 -702.28 5962055.00 528780.00 70 18 26.679 N 149 46 0.588 W -Polygon 5 109.00 -2567.81 -833.33 5963319.00 528644.00 70 18 39.117 N 149 46 4.414 W -Polygon 6 109.00 -2530.02 -1289.23 5963355.00 528188.00 70 18 39.488 N 149 46 17.712 W -Polygon 7 109.00 -5177.84 -1407.63 5960707.00 528080.00 70 18 13.447 N 149 46 21.152 W 2Z-13AL1 Polygon 109.00 -4928.87 -1391.65 5960956.00 528095.00 70 18 15.895 N 149 46 20.687 W -Polygon 1 109.00 -4928.87 -1391.65 5960956.00 528095.00 70 18 15.895 N 149 46 20.687 W -Polygon 2 109.00 -6955.50 -1542.62 5958929.00 527952.00 70 17 55.963 N 149 46 25.077 W -Polygon 3 109.00 -7044.08 -885.90 5958843.00 528609.00 70 17 55.093 N 149 46 5.932 W -Polygon 4 109.00 -4995.62 -692.84 5960892.00 528794.00 70 18 15.240 N 149 46 0.310 W -Polygon 5 109.00 -4957.93 -1377.77 5960927.00 528109.00 70 18 15.609 N 149 46 20.282 W -Polygon 6 109.00 -4928.87 -1391.65 5960956.00 528095.00 70 18 15.895 N 149 46 20.687 W 2Z-13AL1 Target? 6003.00 -6995.66 -1247.75 5958890.00 528247.00 70 17 55.569 N 149 46 16.481 W 2Z-13AL1 Target6 6015.00 -6773.68 -1236.88 5959112.00 528257.00 70 17 57.752 N 149 46 16.165 W 2Z-13AL1 Targets 6034.00 -6552.78 -1205.01 5959333.00 528288.00 70 17 59.925 N 149 46 15.237 W 2Z-13AL1 Target4 6058.00 -6306.60 -1243.04 5959579.00 528249.00 70 18 2.346 N 149 46 16.347 W 2Z-13AL1 Target3 6069.00 -5970.91 -1155.72 5959915.00 528335.00 70 18 5.647 N 149 46 13.803 W 2Z-13AL1 Target2 6080.00 -5725.01 -1123.75 5960161.00 528366.00 70 18 8.066 N 149 46 12.872 W • • by BP Alaska S Baker Hughes INTEQ Planning Report INTE Q `Company: BP AmoCA Date: 11/30/2006 Time: 10 :37:52 Page: 2 Field: Kuparuk Co-ordioate(NE) Reference: WeII: 13, True North Site: KRU 2Z Pad Vertical (TVD) Reference: 2Z-13 109.0 Nell: 1 3 Section(VS)Itefereuce: Well (O.OON,O. OOE,185.OOAzi) 'Wellpath: Plan 4, 2Z-13AL1 Survey Cakalation Method: Minimum Curvature Db: O racle Targets Map Map ~--- Latitude --> ~- Longitude --> Name Description TVD +N/-5 +E/-W Northing Fasting Deg Mie Sec Deg Ntin Sec Dip. Dir. ft ft ' ft ft ft 2Z-13AL1 Targetl 6091. 00 -5433.00 -1117.60 5960453.00 528371.00 70 18 10 .938 N 149 46 12 .694 W Annotation MD TVD ft ft 8250.00 6067.95 KOP -tie to 2Z-13A PIan3 ---- 8300.00 6082.81 2 8392.98 6092.88 End of 25 Deg/10' DLS 8667.98 6091.06 4 8717.98 6090.31 5 8992.98 6080.05 6 9212.98 6069.04 7 9312.98 6065.10 8 9487.98 6059.63 9 9527.98 6057.87 10 9777.98 6033.96 11 10027.98 6015.02 12 10250.00 0.00 TD Plan Section Infor~rration MD Incl Azim TVD +N! S +E/-W DIS Build Turn TFO -Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8250.00 68.19 173.43 6067.95 -5038.10 -1106.50 0.00 0.00 0.00 0.00 8300.00 77.26 182.46 6082.81 -5085.71 -1104.89 25.00 18.13 18.06 45.00 8392.98 90.40 201.79 6092.88 -5175.41 -1124.36 25.00 14.14 20.79 57.00 8667.98 90.34 168.79 6091.06 -5445.47 -1149.37 12.00 -0.02 -12.00 270.00 8717.98 91.37 162.88 6090.31 -5493.92 -1137.14 12.00 2.08 -11.82 280.00 8992.98 92.79 195.87 6080.05 -5764.92 -1134.15 12.00 0.51 12.00 87.00 9212.98 92.85 169.44 6069.04 -5982.47 -1144.25 12.00 0.03 -12.01 270.80 9312.98 91.65 181.39 6065.10 -6081.89 -1136.28 12.00 -1.20 11.95 95.50 9487.98 91.90 202.40 6059.63 -6252.09 -1172.12 12.00 0.14 12.00 89.00 9527.98 93.13 197.75 6057.87 -6289.61 -1185.84 12.00 3.09 -11.61 285.00 9777.98 97.60 167.95 6033.96 -6535.29 -1198.31 12.00 1.79 -11.92 279.80 10027.98 90.90 197.29 6015.02 -6781.45 -1209.86 12.00 -2.68 11.74 101.50 10250.00 95.27 170.96 6002.85 -7000.56 -1225.77 12.00 1.97 -11.86 280.00 Survey MD Inel Azim SSTVD N/S- E/W MapN MapE DLS VS TFO Toal ft deg deg ft ft ft ft ft deg/100ft ft deg 8250.00 68.19 173.43 5958.95 -5038.10 -1106.50 5960847.90 528380.55 0.00 5115.37 0.00 MWD 8252.86 68.70 173.98 5960.00 -5040.75 -1106.21 5960845.26 528380.85 25.00 5117.98 45.00 2Z-13A 8260.00 69.97 175.31 5962.52 -5047.40 -1105.59 5960838.61 528381.50 25.00 5124.55 44.80 MWD 8280.00 73.58 178.95 5968.77 -5066.36 -1104.65 5960819.65 528382.52 25.00 5143.36 44.33 MWD 8288.25 75.09 180.42 5971.00 -5074.30 -1104.60 5960811.71 528382.59 25.00 5151.27 43.19 2Z-13A 8300.00 77.26 182.46 5973.81 -5085.71 -1104.89 5960800.31 528382.35 25.00 5162.65 42.79 MWD 8320.00 80.01 186.72 5977.75 -5105.25 -1106.46 5960780.76 528380.86 25.00 5182.26 57.00 MWD 8340.00 82.82 190.90 5980.74 -5124.78 -1109.49 5960761.22 528377.90 25.00 5201.98 56.16 MWD 8360.00 85.67 195.03 5982.74 -5144.17 -1113.96 5960741.82 528373.51 25.00 5221.68 55.54 MWD 8380.00 88.53 199.14 5983.76 -5163.25 -1119.82 5960722.71 528367.72 25.00 5241.21 55.12 MWD 8392.98 90.40 201.79 5983.88 -5175.41 -1124.36 5960710.54 528363.23 25.00 5253.71 54.91 MWD 8400.00 90.40 200.95 5983.83 -5181.95 -1126.92 5960703.99 528360.70 12.00 5260.45 270.00 MWD 8425.00 90.40 197.95 5983.65 -5205.52 -1135.24 5960680.39 528352.47 12.00 5284.66 269.99 MWD 8450.00 90.40 194.95 5983.48 -5229.49 -1142.32 5960656.39 528345.49 12.00 5309.15 269.97 MWD 8475.00 90.39 191.95 5983.31 -5253.81 -1148.13 5960632.06 528339.77 12.00 5333.88 269.95 MWD 8500.00 90.39 188.95 5983.14 -5278.39 -1152.67 5960607.46 528335.33 12.00 5358.76 269.93 MWD • • by BP Alaska ~ Baker Hughes INTEQ Planning Report 1NTEQ Gompaoy: BP Amoco Date: 11/30/2006 Time: 10 :37:52 Page: 3 Field: Kuparuk Co•ordiuate(P1EjReference: Well: 13, True North Site: KRU 2Z Pad Vtrticai (TVD) Reference: 2Z-13 109.0 Well; 13 Section (VS}Reference: Well (O.OON,O. OOE,185.OOAzi) Wellpatb: Plan 4, 2Z-13AL1 Sarvey Calcnlatiou Method: Minimum Curvature Db: OraGe Survey MD Incl Azim SS TVD Pi1S E/W MapN MapE DLS VS TFO Tool ft. deg deg ft ft' ft tT ft - deg/100ft ft deg 8525.00 90.38 185.95 5982.97 -5303.17 -1155.91 5960582.67 528332.19 12.00 5383.74 269.91 MWD 8550.00 90.38 182.95 5982.80 -5328.10 -1157.84 5960557.74 528330.35 12.00 5408.73 269.89 MWD 8575.00 90.37 179.95 5982.64 -5353.08 -1158.48 5960532.75 528329.82 12.00 5433.68 269.87 MWD 8600.00 90.36 176.95 5982.48 -5378.07 -1157.80 5960507.77 528330.59 12.00 5458.51 269.85 MWD 8625.00 90.35 173.95 5982.32 -5402.99 -1155.81 5960482.86 528332.68 12.00 5483.16 269.83 MWD 8650.00 90.34 170.95 5982.17 -5427.77 -1152.53 5960458.10 528336.06 12.00 5507.56 269.81 MWD 8667.98 90.34 168.79 5982.06 -5445.47 -1149.37 5960440.41 528339.29 12.00 5524.92 269.79 MWD 8675.00 90.48 167.96 5982.01 -5452.34 -1147.95 5960433.54 528340.73 12.00 5531.65 280.00 MWD 8700.00 91.00 165.01 5981.69 -5476.65 -1142.11 5960409.27 528346.67 12.00 5555.35 279.99 MWD 8717.98 91.37 162.88 5981.31 -5493.92 -1137.14 5960392.01 528351.71 12.00 5572.12 279.96 MWD 8725.00 91.42 163.72 5981.14 -5500.64 -1135.12 5960385.30 528353.75 12.00 5578.64 87.00 MWD 8750.00 91.57 166.72 5980.49 -5524.80 -1128.75 5960361.17 528360.22 12.00 5602.16 87.02 MWD 8775.00 91.72 169.72 5979.77 -5549.26 -1123.64 5960336.73 528365.42 12.00 5626.08 87.10 MWD 8800.00 91.87 172.71 5978.99 -5573.96 -1119.83 5960312.05 528369.33 12.00 5650.34 87.18 MWD 8825.00 92.01 175.71 5978.15 -5598.81 -1117.31 5960287.21 528371.95 12.00 5674.89 87.28 MWD 8850.00 92.14 178.71 5977.24 -5623.76 -1116.09 5960262.27 528373.26 12.00 5699.64 87.38 MWD 8875.00 92.27 181.71 5976.28 -5648.74 -1116.19 5960237.29 528373.26 12.00 5724.53 87.49 MWD 8900.00 92.39 184.71 5975.26 -5673.68 -1117.58 5960212.35 528371.96 12.00 5749.49 87.60 MWD 8925.00 92.51 187.71 5974.19 -5698.51 -1120.29 5960187.52 528369.36 12.00 5774.46 87.73 MWD 8950.00 92.62 190.71 5973.08 -5723.16 -1124.28 5960162.85 528365.46 12.00 5799.36 87.85 MWD 8975.00 92.72 193.71 5971.91 -5747.56 -1129.57 5960138.43 528360.27 12.00 5824.14 87.99 MWD 8992.98 92.79 195.87 5971.05 -5764.92 -1134.15 5960121.05 528355.76 12.00 5841.83 88.13 MWD 9000.00 92.80 195.03 5970.71 -5771.68 -1136.02 5960114.29 528353.91 12.00 5848.73 270.80 MWD 9025.00 92.83 192.03 5969.48 -5795.96 -1141.86 5960089.99 528348.17 12.00 5873.42 270.76 MWD 9050.00 92.86 189.02 5968.24 -5820.50 -1146.42 5960065.43 528343.71 12.00 5898.27 270.61 MWD 9075.00 92.88 186.02 5966.99 -5845.25 -1149.69 5960040.67 528340.54 12.00 5923.21 270.46 MWD 9100.00 92.89 183.01 5965.73 -5870.14 -1151.65 5960015.78 528338.67 12.00 5948.18 270.31 MWD 9125.00 92.90 180.01 5964.46 -5895.10 -1152.31 5959990.82 528338.11 12.00 5973.10 270.16 MWD 9150.00 92.89 177.01 5963.20 -5920.05 -1151.66 5959965.87 528338.86 12.00 5997.90 270.01 MWD 9175.00 92.88 174.00 5961.94 -5944.94 -1149.71 5959940.99 528340.91 12.00 6022.52 269.86 MWD 9200.00 92.86 171.00 5960.68 -5969.69 -1146.45 5959916.25 528344.26 12.00 6046.90 269.71 MWD 9212.98 92.85 169.44 5960.04 -5982.47 -1144.25 5959903.49 528346.52 12.00 6059.43 269.55 MWD 9225.00 92.71 170.88 5959.45 -5994.30 -1142.19 5959891.67 528348.61 12.00 6071.04 95.50 MWD 9250.00 92.42 173.87 5958.34 -6019.05 -1138.88 5959866.93 528352.03 12.00 6095.41 95.57 MWD 9275.00 92.12 176.85 5957.35 -6043.95 -1136.86 5959842.05 528354.14 12.00 6120.03 95.70 MWD 9300.00 91.81 179.84 5956.49 -6068.92 -1136.14 5959817.08 528354.96 12.00 6144.84 95.82 MWD 9312.98 91.65 181.39 5956.10 -6081.89 -1136.28 5959804.11 528354.87 12.00 6157.78 95.92 MWD 9325.00 91.67 182.83 5955.75 -6093.90 -1136.72 5959792.10 528354.48 12.00 6169.78 89.00 MWD 9350.00 91.72 185.83 5955.01 -6118.81 -1138.61 5959767.18 528352.69 12.00 6194.76 89.04 MWD 9375.00 91.76 188.83 5954.25 -6143.59 -1141.80 5959742.39 528349.60 12.00 6219.73 89.13 MWD 9400.00 91.80 191.84 5953.47 -6168.17 -1146.28 5959717.80 528345.21 12.00 6244.61 89.22 MWD 9425.00 91.83 194.84 5952.68 -6192.48 -1152.04 5959693.47 528339.55 12.00 6269.33 89.32 MWD 9450.00 91.86 197.84 5951.87 -6216.46 -1159.07 5959669.47 528332.61 12.00 6293.82 89.41 MWD 9475.00 91.89 200.84 5951.06 -6240.03 -1167.34 5959645.86 528324.43 12.00 6318.03 89.51 MWD 9487.98 91.90 202.40 5950.63 -6252.09 -1172.12 5959633.78 528319.70 12.00 6330.46 89.61 MWD 9500.00 92.27 201.00 5950.19 -6263.25 -1176.56 5959622.61 528315.30 12.00 6341.96 285.00 MWD 9525.00 93.04 198.10 5949.03 -6286.78 -1184.92 5859599.05 528307.04 12.00 6366.13 284.95 MWD 9527.98 93.13 197.75 5948.87 -6289.61 -1185.84 5959596.21 528306.14 12.00 6369.03 284.81 MWD 9550.00 93.58 195.15 5947.58 -6310.70 -1192.06 5959575.11 528299.99 12.00 6390.58 279.80 MWD 9575.00 94.07 192.18 5945.92 -6334.93 -1197.95 5959550.85 528294.20 12.00 6415.23 279.65 MWD 9600.00 94.56 189.21 5944.03 -6359.42 -1202.58 5959526.34 528289.67 12.00 6440.04 279.45 MWD 9625.00 95.04 186.24 5941.94 -6384.11 -1205.93 5959501.65 528286.42 12.00 6464.92 279.23 MWD 9650.00 95.50 183.26 5939.65 -6408.91 -1207.99 5959476.84 528284.45 12.00 6489.81 278.98 MWD • • by BP Alaska ~ Baker Hughes INTEQ Planning Report 1NTE Q 'Gompauy: BP Amoco Date: 11/31)/2006 Time: 10 :37:52 Page: 4 Field[ Kupacuk Co-ordiuate(lYE) Reference: Wetl: 13, True North Site: KR U 2Z Pad Vertical (TVD) Reference: 2Z-13 109.0 We1L 13 Section (VS) Reference: Well (O.OON,O. OOE,185.OOAzi) Weltpatb: Plan 4, 2Z-13A11 Sarvey Calcxlatio® Method: Minimum Curvature Db: OraGe Survey MD' Iacl Azim SS TVD N/$ FJN' MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9675.00 95.94 180.28 5937.15 -6433.77 -1208.76 5959451.98 528283.78 12.00 6514.64 278.70 MWD 9700.00 96.37 177.29 5934.47 -6458.62 -1208.23 5959427.14 528284.40 12.00 6539.35 278.41 MWD 9725.00 96.79 174.30 5931.60 -6483.39 -1206.42 5959402.38 528286.32 12.00 6563.86 278.09 MWD 9750.00 97.18 171.31 5928.56 -6508.00 -1203.31 5959377.78 528289.52 12.00 6588.11 277.74 MWD 9775.00 97.56 168.31 5925.36 -6532.40 -1198.92 5959353.40 528294.00 12.00 6612.04 277.38 MWD 9777.98 97.60 167.95 5924.96 -6535.29 -1198.31 5959350.51 528294.62 12.00 6614.86 276.99 MWD 9800.00 97.07 170.56 5922.15 -6556.75 -1194.24 5959329.07 528298.78 12.00 6635.88 101.50 MWD 9825.00 96.44 173.51 5919.21 -6581.33 -1190.80 5959304.51 528302.32 12.00 6660.07 101.83 MWD 9850.00 95.80 176.46 5916.54 -6606.09 -1188.63 5959279.76 528304.58 12.00 6684.55 102.18 MWD 9875.00 95.14 179.40 5914.16 -6630.96 -1187.73 5959254.90 528305.58 12.00 6709.24 102.50 MWD 9900.00 94.48 182.34 5912.06 -6655.86 -1188.11 5959229.99 528305.30 12.00 6734.09 102.78 MWD 9925.00 93.79 185.26 5910.26 -6680.74 -1189.76 5959205.11 528303.74 12.00 6759.01 103.02 MWD 9950.00 93.10 188.19 5908.75 -6705.52 -1192.69 5959180.32 528300.92 12.00 6783.95 103.23 MWD 9975.00 92.40 191.11 5907.55 -6730.14 -1196.87 5959155.69 528296.83 12.00 6808.84 103.41 MWD 10000.00 91.70 194.03 5906.66 -6754.52 -1202.31 5959131.29 528291.49 12.00 6833.60 103.55 MWD 10025.00 90.99 196.94 5906.07 -6778.60 -1208.98 5959107.19 528284.91 12.00 6858.18 103.65 MWD 10027.98 90.90 197.29 5906.02 -6781.45 -1209.86 5959104.34 528284.05 12.00 6861.09 103.72 MWD 10050.00 91.36 194.69 5905.59 -6802.61 -1215.92 5959083.15 528278.07 12.00 6882.70 280.00 MWD 10075.00 91.88 191.73 5904.88 -6826.94 -1221.63 5959058.81 528272.45 12.00 6907.43 279.95 MWD 10100.00 92.39 188.77 5903.95 -6851.52 -1226.08 5959034.21 528268.11 12.00 6932.31 279.87 MWD 10125.00 92.89 185.81 5902.80 -6876.29 -1229.25 5959009.43 528265.03 12.00 6957.26 279.76 MWD 10150.00 83.39 182.85 5901.43 -6901.18 -1231.13 5958984.54 528263.25 12.00 6982.22 279.62 MWD 10175.00 93.88 179.88 5899.85 -6926.12 -1231.73 5958959.60 528262.75 12.00 7007.11 279.46 MWD 10200.00 94.36 176.91 5898.05 -6951.04 -1231.03 5958934.68 528263.54 12.00 7031.88 279.27 MWD 10225.00 94.82 173.94 5896.05 -6975.88 -1229.04 5958909.85 528265.63 12.00 7056.45 279.06 MWD 10250.00 95.27 170.96 5893.85 ~ -7000.56 -1225.77 5958885.19 528268.99 12.00 7080.75 278.82 2 3/8" • a ~ ~ f ttl` r rrt} ,;a tI~-t i I ~,~~' i 'i1-~1 ail ~ ~ +++~} +,;, f.~ I '' i ~ ~ ~ ~ ?aE~ rl} ~I~j I}I{ i1t ,~ ~l ~-ri# ~~~ i~~t` IE,~ `cif ~I I~t k~,' ~~'' ` k '{ : ~ ~~--. ~~l tIt ~~~ I[1f. 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I ~~'' i ~Q ~ 3; ~ ::ss•s••sz::: 3~.~~'s~ ~ 1kr i I i T T 't IC II ~:i ~Ilf I!~ I~f ~~ i " ~ 8 z '~~ ~ ~ •=:::::d:::i= ~7 °97 AsxsaS I li - t r f l 1 ~ I ~ ~ fl ~~`_ 4 S:T::x:a::~ {{{{ I r ~L r t Ir,. _ a _~ ~f~ I~-I I i! I ~ s: s t~ t ~ I I. ~ t f ~~ a P '~ ;~ ~~"~~ t '. f 4 t Q 1J}' % r t~ _ j:: •:^:~ ~ I. 1 /~ ~ I~ I t r r I t 1 I -j ' =cs:.:?.::::: € asaua:aua ~ t.weo~l w.u F~~:'a "'. by BP Alaska Anticollision Report ~.r s 1NTEQ Company: BP Amoco Date: 11/30/2006 Time: 21:44:13 Page: 1 -Reid: ' ' Kuparuk Reference Site: KRU 2Z Pad Co-ordiaate(NE) Reference: Well: 13, True North Reference WeU: 13 Vertical(TVD) Reference: 2Z Orig Datum1 109. 0 Refereece Wellpath: Plan 4, 2Z-13A11 Db: OraGe NO GLOBAL SCAN: Using user deTined selection & seas criteria Reference: Principal Plan & PLANNED PROGRAM Ieterpolatioe Method : MD Inte rval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 8250.00 to 10250.00 ft Scau Method: Trav Cylinder North Maximum Radius: 3000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/30/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 109.00 8100.00 Gyro (0.00-8525. 00) (0) GCT-MS Schlumberger GCT multishot 8100.00 8250.00 Planned: Plan #3 V5 (1) MWD MWD -Standard 8250.00 10250.00 Planned: Plan #4 V6 MWD MWD -Standard Casing Points - - MD TVD Diameter Hok Size Name ft ft in in 10250.00 6002.85 2.375 3.000 2 3/8" Summary <- Offset Wellpath -- -----> Reference Offset Ctr-Ctr No-Co Allowable. ` Site Well WeOpath MD MD Distance Area Deviation Warning ft ft ft ft ft --- KRU 2D Pad 2D-03 2D-03 VO Out of range KRU 2D Pad 2D-04 2D-04 VO Out of range KRU 2D Pad 2D-05 2D-05 VO Out of range KRU 2D Pad 2D-05 Plan 3, 2D-05L1 VO Pla 8267.65 10933.00 1882.82 286.09 1596.73 Pass: Major Risk KRU 2D Pad 2D-05 Plan 3, 2D-05L2 VO Pla 9900.00 10100.00 2134.75 250.02 1884.73 Pass: Major Risk KRU 2Z Pad 01 2Z-01 VO Out of range KRU 2Z Pad 02 2Z-02 VO 8461.22 9200.00 2111.81 1117.58 994.23 Pass: Major Risk KRU 2Z Pad 03 2Z-03 VO Out of range KRU 2Z Pad 04 2Z-04 VO Out of range KRU 2Z Pad 05 2Z-05 VO Out of range KRU 2Z Pad 06 2Z-06 VO Out of range KRU 2Z Pad 07 2Z-07 VO Out of range KRU 2Z Pad 08 2Z-O8 VO 8260.00 8800.00 2913.071099.00 1814.07 Pass: Major Risk KRU 2Z Pad 09 2Z-09 VO Out of range KRU ZZ Pad 10 2Z-10 VO Out of range KRU 2Z Pad 11 2Z-11 VO Out of range KRU 2Z Pad 12 2Z-12 V1 Out of range KRU 2Z Pad 12 2Z-12A VO Out of range KRU 2Z Pad 13 2Z-13 V1 8289.05 8300.00 35.58 170.88 -135.30 FAIL: Major Risk KRU 2Z Pad 14 2Z-14 VO Out of range KRU 2Z Pad 15 2Z-15 VO Out of range KRU 2Z Pad 16 2Z-16 VO Out of range KRU 2Z Pad 18 2Z-18 VO Out of range KRU 2Z Pad 19 2Z-19 VO Out of range KRU 2Z Pad 20 2Z-20 VO Out of range KRU 2Z Pad 21 2Z-21 VO Out of range KRU 2Z Pad 22 2Z-22 VO Out of range KRU 2Z Pad 23 2Z-23 VO Out of range KRU 2Z Pad 29 2Z-29 VO Out of range KRU 2Z Pad WS-1 WS-1 VO Out of range Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2D-05L1 VO Plan: Plan #3 V5 Inter-Site Error: 0.00 ft Reference Offset Semi-MBjjor Aais Ctr-Ctr No-Ga Allowable MD TVD MD TVD Ref Onset TFO+AZI TF0.HS Casiag/HSDistaace Area : Deviation Wareing ft ft ft ft ft ft deg deg in ft ft ft 9360.17 6063.70 9000.00 6104.06 37.90 32.84 96.26 269.21 3.125 2924.21 244.90 2679.31 Pass 9350.00 6064.01 9100.00 6101.29 37.82 33.10 95.07 269.23 3.125 2837.40 245.41 2591.98 Pass 9350.00 6064.01 9200.00 6099.76 37.82 33.38 95.09 269.26 3.125 2744.11 246.25 2497.86 Pass 9340.32 6064.30 9300.00 6097.81 37.72 33.69 93.95 269.28 3.125 2658.17 246.81 2411.36 Pass 9325.00 6064.75 9400.00 6093.22 37.55 34.11 92.18 269.35 3.125 2585.90 247.51 2338.39 Pass • by BP Alaska Anticollision Report • mar s 1NTEQ Company: BP AmocA Date: 11/30/2006 Time: 21:44:13 Page: 2 Field: Kupartak Reference Site: KRU 2Z Pad Co-ordiuatt(NE) Reference: Well: 13, True North Reference ~~'ell: 13 Vertical ('f VD) Rekrence: 2Z Orig Datuml 109. 0 .Reference Wellpath: Plan 4, 2Z-13AL1 Db: OraGe Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2 D-05L1 VO Plan: Plan #3 V5 Inter-Site Error: 0.00 ft Reference Otfset Semi-Major Axis : Ctr-Ctt•' No-Go A{lovable MIl TVD MD TVD Ref' Offset TFO+AZI TFO-HS CasiogRiSDistadce Area Deviation Warning ft ft ft ft ft ft deg deg. in' ft ft ft 9316.65 6064.99 9500.00 6089.39 37.44 34.73 91.28 269.45 3.125 2531.22 249.01 2282.21 Pass 9300.00 6065.49 9600.00 6090.08 37.20 35.38 89.27 269.43 3.125 2497.42 250.40 2247.01 Pass 8915.97 6083.59 9700.00 6093.45 36.04 36.46 96.40 269.77 3.125 2473.81 252.34 2221.48 Pass 8900.00 6084.26 9800.00 6096.84 35.92 37.29 94.40 269.69 3.125 2423.49 254.60 2168.89 Pass 8889.28 6084.70 9900.00 6100.02 35.80 38.07 93.05 269.63 3.125 2358.43 256.89 2101.54 Pass 8875.00 6085.28 10000.00 6104.09 35.64 38.77 91.22 269.51 3.125 2280.63 258.73 2021.90 Pass 8875.00 6085.28 10100.00 6108.80 35.64 39.45 91.14 269.43 3.125 2203.82 261.10 1942.72 Pass 8850.00 6086.24 10200.00 6113.31 35.31 40.37 87.97 269.26 3.125 2143.89 263.05 1880.84 Pass 8836.18 6086.75 10300.00 6117.42 35.09 41.39 86.22 269.16 3.125 2104.87 265.65 1839.22 Pass 8825.00 6087.15 10400.00 6120.75 34.91 42.43 84.83 269.11 3.125 2089.47 268.40 1821.06 Pass 8320.00 6086.75 10500.00 6121.96 34.86 42.62 95.56 268.84 3.125 2076.52 271.61 1804.90 Pass 8300.00 6082.81 10600.00 6122.27 34.57 44.09 91.59 269.13 3.125 2057.46 275.31 1782.15 Pass 8300.00 6082.81 10700.00 6122.35 34.57 45.17 90.99 268.53 3.125 2022.30 278.75 1743.55 Pass 8280.00 6077.77 10800.00 6121.89 34.22 46.55 87.69 268.73 3.125 1971.66 282.11 1689.54 Pass 8270.76 6075.03 10900.00 6120.63 34.01 47.67 85.85 268.56 3.125 1906.98 285.17 1621.81 Pass 8267.65 6074.05 10933.00 6120.04 33.94 48.02 85.25 268.52 3.125 1882.82 286.09 1596.73 Pass Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2D-05L2 VO Plan: Plan #3 V4 Inter-Site Error: 0.00 ft Reference.. Offset Semi-Major Axis Ctr-Ctr No-Go Allowable NII) TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/IiSi)istance Area Deviation Warning tt ft ft ft ft ft deg deg in ft ft ft 9360.17 6063.70 9000.00 6104.06 37.90 32.84 96.26 269.21 3.125 2924.21 244.90 2679.31 Pass 9350.00 6064.01 9100.00 6101.29 37.82 33.10 95.07 269.23 3.125 2837.40 245.41 2591.98 Pass 9350.00 6064.01 9200.00 6099.76 37.82 33.38 95.09 269.26 3.125 2744.11 246.25 2497.86 Pass 9340.42 6064.30 9300.00 6097.49 37.72 33.65 93.97 269.28 3.125_ 2657.74 246.69 2411.05 Pass 9335.38 6064.45 9400.00 6093.19 37.66 33.80 93.44 269.36 3.125 2564.12 246.96 2317.17 Pass 9336.87 6064.40 9500.00 6091.61 37.68 33.76 93.62 269.37 3.125 2465.32 246.88 2218.44 Pass 9350.00 6064.01 9600.00 6092.63 37.82 33.61 95.17 269.34 3.125 2373.40 246.92 2126.48 Pass 9350.00 6064.01 9700.00 6095.24 37.82 33.31 95.04 269.21 3.125 2292.42 245.99 2046.43 Pass 9366.25 6063.52 9800.00 6098.08 37.95 33.01 96.89 269.11 3.125 2227.15 245.52 1981.63 Pass 9375.00 6063.25 9900.00 6099.04 38.02 32.67 97.86 269.03 3.125 2181.62 244.72 1936.90 Pass 9875.00 6023.16 10000.00 6096.92 40.44 31.88 87.44 268.04 3.125 2155.43 249.14 1906.29 Pass 9900.00 6021.06 10100.00 6090.05 40.84 31.73 90.56 268.23 3.125 2134.75 250.02 1884.73 Pass 9910.95 6020.24 10200.00 6078.77 40.97 31.54 92.05 268.43 3.125 2137.82 249.92 1887.90 Pass 9925.00 6019.26 10300.00 6069.01 41.15 31.43 93.91 268.64 3.125 2164.78 250.19 1914.59 Pass 9950.00 6017.75 10400.00 6064.67 41.38 31.46 97.01 268.82 3.125 2213.75 251.08 1962.66 Pass 9959.82 6017.25 10500.00 6063.74 41.43 31.33 98.16 268.82 3.125 2269.39 250.89 2018.49 Pass Site: KRU 2Z Pad Well: 02 Rule Assigned: Major Risk Wellpath: 2Z-02 VO Inter-Site Error: 0.00 ft Reterence Offset Semi-Major Aais Ctr-Ctr No-Go Allowable NID TVD MD TVD Ref Offset. TFO~AZI TFO-HS Casieg/HSflistaoce Area Deviation Warning ft` ft ft ft ft ft deg deg in ft _ft ft 8461.22 6092.40 9200.00 6223.56 35.11 327.05 287.16 93.56 2111.811117.58 994.23 Pass 8475.00 6092.31 9300.00 6308.67 35.14 326.95 287.73 95.78 2146.141114.09 1032.05 Pass 8475.00 6092.31 9394.00 6388.67 35.14 329.25 289.76 97.81 2181.891116.65 1065.23 Pass • ~~_,~ by BP Alaska Anticollision Report • ~t~ ~tiEs 1NTEQ Compaay: BP Amoco Date: 11/30/2006 Time: 21:44:13 Page: 3 :Field: Kupanak Reference Ske: KRU 2Z Pad : Co-ordi®Ate(NE) Reference: Well: 13, True North Reference Well: 13 Verdcal(TYIl) Reference: 2Z Orig Datuml 109.0 '.Reference Wellpath: Plan 4; 2Z-13AL1 Db: OraGe Site: KRU 2Z Pad Well: 08 Rule Assigued: Major Risk Wellpath: 2Z-08 VO Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr' No-Go Allowable MD TVD MD TVD Ref OtfseE TFO+AZI TFO-HS Casiog/HSDistaece Area Deviation Warning ft ft ft ft ft ft deg deg _ in ft ft ft 8255.61 6069.99 8700.00 5799.90 33.64 322.92 90.20 275.70 2908.261088.49 1819.77 Pass 8260.00 6071.52 8800.00 5881.68 33.76 325.16 89.59 274.28 2913.071099.00 1814.07 Pass 8280.00 6077.77 8900.00 5963.59 34.22 323.27 90.91 271.96 2921.431099.19 1822.23 Pass 8280.00 6077.77 9000.00 6045.65 34.22 326.38 89.68 270.72 2932.751110.68 1822.07 Pass 8288.87 6080.16 9100.00 6128.07 34.37 326.79 89.56 269.04 2946.871114.60 1832.27 Pass 8300.00 6082.81 9200.00 6211.10 34.57 326.07 89.74 267.28 2963.341114.49 1848.85 Pass 8300.00 6082.81 9300.00 6294.60 34.57 329.04 88.42 265.96 2982.271123.71 1858.56 Pass 8300.00 6082.81 9378.00 6359.74 34.57 331.36 87.40 264.94 2999.261130.54 1868.72 Pass Site: KRU 2Z Pad Well: 13 Rule Assigned: Major Risk Wellpath: 2Z-13 V1 Iuter-Site Error: 0.00 ft Reference Offset Semi-MajorAais Ctr-Ctr No-Go AIIowAble NID TVD MD TVD Ref Offsef TFO+AZI TFO-HS Casiag/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft- ft ft 8289.05 6080.21 8300.00 6112.77 34.38 35.17 341.73 161.17 35.58 170.88 -135.30 FAIL 8365.54 6092.12 8400.00 6178.98 34.96 36.24 7.20 171.02 88.10 150.32 -62.22 FAIL 8434.17 6092.59 8500.00 6244.48 35.01 36.78 16.72 179.88 151.89 140.63 11.26 Pass 8452.84 6092.46 8525.00 6260.85 35.10 36.99 15.26 180.66 168.41 140.78 27.63 Pass • a RE: 2Z-13 A, et al • • Subject: RE: 2Z-13 A,etal From:"Worthington, Aras J" <Aras.Worthtnglon~bp.com> Date: Thu, 14 Dec 2006 1 ~ :09:30 -0900 To: Thomas ~~launder ~ tom maun~lcr<<cadmin.state.ak.us=~ Roger that, Tom. If it looks like we need to add a lateral I'll be on the phone with you asking for a verbal and sending paperwork your way for the added lateral. Cheers, Aras -----Original Message----- From: Thomas Maunder [mai.ltc : tarr maunder;d~a.c3min .state . ak . t.s Sent: Thursday, December 14, 2006 12:19 PM To: Worthington, Aras (ConocoPhillips) Cc: Worthington, Aras J; Dave Roby; Steve Davies Subject: 2Z-13 A, et al Aras, In the permit applications for 2Z-13A and -ALl it mentioned that additional laterals may be added if the ankerite proves to be too difficult to undulate through. If this becomes the chosen path, additional permits may be necessary. Please stay in touch. Call or message with any questions. / Tom Maunder, PE C AOGCC 1 of 1 12/14/2006 1:31 PM • • From: "~`enhaus, Dan E" <Dan.E.Venhaus~~conocophillips.com> Date: Thu, 07 Sep 2006 09:~~:20 -0800 To: Thomas Maunder <tarn_maunder@,admin.state.ak.us> CC: HubbleTL@BP_com, "Allsup-Drake, Sharon K" <Sharon.K.A~lsup-Drake@.conocophillps.com>, "Eller, 1 Gary" <J_Gary.Eller~conocophtllips.com>, GanttLL~BP.com Torn. +~tre are currently planning on bringing Nordic 2 to Kuparuk for an 8 well CTD program starting October 1 with and completing around February 2047. The candidate list thus far is 1 C- E 4, 1 C-25, 1 C-2d, ~1 Cy~, 1 L-28. 2Z-13, 30-02, 30-01. 1 C-01 wii! have a wforkover prior to the CTD sidetrack, ------ As in the past, BP's CT dri!4ing services are being provided to the operator ConocoPhil!ips ~fia a Shared Service operation. ,As such, BP wii! submit the drilling permits and ConocoPhiliips authorizes the delivery of said permits to BP {Terry Hubb!ej. ConocoPhil'ips does request that BP provide a copy of the approved permits. Thanks, Dan Venhaus Wells/CTD Engineer ConocoPhillips AK, Inc. 907-263-4372 office 907-230-0188 cell l of 1 I O/ 16.3006 12: ~2 Pit • ~ • PERMIT TO DRILL 20 AAC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. • • ®evelopment Seto~ice Expdoa-atoa-~~ Stt-atigraphic Vest Ion-Conventional i~"ell Circle Appropriate Letter /Paragraphs to be Included in Transmittal ~.etter CHECK ADD-ONS WHAT ~ (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER iVtULTI LATERAL !~~ The permit is for a new wellbore segment of existing well K~2GC Z ~- /3 (If last two digits in API number are ~ Permit No. D(o - /7C~API tio. ~0-p~' - Z, ',~ _~ (, between 60-69) ,Production should continue to be reported as a function of the original API number stated above. PLOT HOLE In accordance with ZO A.~C 'S.00~(f), all records. data and logs: acquired for the pilot hole must be clearly differentiated in both i well name ( PH) and API number t i (~0- - -_~ from records, data and logs ;acquired for well i SPACING i' The permit is approved subject to full compliance with 20 AAC EXCEPTION 2~.0>j. Approval to perforate and roduce in'ect is contingent upon issuance of a conservation order approving a spacing , exception. assumes the liability of any protest to the spacing exception that may occur. DRY D[TCH Alf dry ditch sample sets submitted to the Commission must be in SAYIPLE ~~ no greater than 30' sample intervals from below the permafrost or !from where samples are first caught and 10' sample intervals J through target zones. Please note the following special condition of this permit: Non-Conventional ;production or production testing of coal bed methane is not allowed ', 'Well ;for (name of well) until after (Company Name) has designed and ~ implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water welt testing proffram. Rev: l 2~: 06 C jody`transmiral checklist ~ ~ CI ^ ~ y ~ : : rn o a~ ~ ~ ~ ~ ~ ~ ~ ~ : ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ o~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ¢ ~ c ~ ! c' I s ~ ~ : ~ ~ ~ a c o ~ 3 O ~ ~ m. :? c ~) n _ v`. 3 ~ '~ ~ v. rn ~ m'. ~ a ~ c O ~ o o. 'v, a °O' ~ m ~ ' CO V ~ N O tf )~ O ~ ~ N. ~~ ~ i; N. ~ U~ ~~ vi ~ ~ ~ ~ ~ ~ ~ ~ ~ f0 ~ O. p, ~ 'O ~ t' O: ~ N N: ~ MI d No; o rNi 3. o, a ~ ~ ~ N ~, 3. ° O o; t ~ ~ J. o. ~ y. ~~ ~~ U• ~ o' o ~ ~ ~ ~ ~ N. 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