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~ ~ ~~~~~~ ~~~~~~~ ~`~~~ ~~~~~~ ~~~~ ~~~~~° ~~~~ FtESCAN DIGITAL DATA t7VEftSIZED (Scannable) } ~Color Items: ~ iskettes, No. ~ ^ Maps: Y ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannabie by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ~ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: Q ~S~ " ct Proofin II I II II'I I I II) I' ~II Pro~e g ~ BY: Maria Date: 0 ~S~ ~ Scannin Preparation ~ x 30 =~+~= TOTAL PAGES__CL.~. g (Count does not include cover sheet) ~ BY: Maria Date: ~~~3 ~~ (~ /sl ~ Production Scanning Stage 1 Page Count from Scanned File: D C~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: '/~/ YES _ BY: Maria Date: !~ ~/Q (~ a q~~~- ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO lsl ~ ~ NO /s/ ~II (I~I~I (III) I~ ~II ~esc~~~ed IIIllllillllll IIIII BY: Maria Date: ~S~ Comments about this file: Quality Checked II I II IIII ~I~ I~I) ~II 10/6/2005 Well History File Cover Page.doc ' ` STATE OF ALASKA AL,A OIL AND GAS CONSERVATION COIVOSION REPORT OF SUNDRY WELL OPERATIONS 1 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Ferf orate r Other (— Alter Casing r Pull Tubing 17 Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: - ConocoPhillips Alaska, Inc. Development p Exploratory r 207 - 081 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 23360 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661, 25660, 25663 - — 1J -162L1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 14489 feet Plugs (measured) None true vertical 3144 feet Junk (measured) None Effective Depth measured 14475 feet Packer (measured) none true vertical 3144 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 79 20 120 120 SURFACE 3777 13.375 3820 2201 INTERMEDIATE 9914 10.75 10400 3245 D -SAND LINER 4291 7 14477 3143 RECEIVED OCT 302012 Perforation depth: Measured depth: 10238'- 10281', 10496' 10703', 10872' 14432' w ®� (� ^� True Vertical Depth: 3208'- 3210', 3197'- 3177', 3178' -3143' /� Tubing (size, grade, MD, and TVD) tbg in main wellbore SCANNED JAN 0 2013 Packers & SSSV (type, MD, and TVD) NO PACKER NO SSSV 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 - in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development f Service r Stratigraphic r 16. Well Status after work: • Oil p` Gas r WDSPL r Daily Report of Well Operations _XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt none Contact Brett Packer 265 -6845 Email J .Brett.Packer @conocophillips.com Printed Name Brett Packer Title Staff Wells Engineer Signature 3---e- 77c-e'l_ Phone: 265-6845 Date (0/ ?(r( R EWS OCT 31 1012 e I '1 k''' , 1 d // z-- Form 10-404 Revised 12/2012 \ \ Submit Original Only KUP • 1J -162L1 ConocoPhillips ) Well Attributes Max Angle & MD TD Alaska, 111. Wellbore API /UWI Field Name Well Status Inc! ( °) MD (kKB) Act Btm (ftKB) _ 500292336060 WEST SAK PROD 96.76 10,498.05 14,489.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV NIPPLE 0 7/10/2009 Last WO: 9/30/2012 43.81 8/16/2007 Wen confiq.- ct 10/14,2012 9.17.26AM Schematic -AUU2I Annotation Depth ( ftKB ) End Date Annotation Last Mod ... End Date -r - - 162L Last Tag. Rev Reason. ADD SLEEVE ninam 10/14/2012 Casing Strings Casing Description String 0... Str ng ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd D SAND LINER 4 1;'2 4 000 10 185.2 14,476.6 3.143.6 11.60 L BTC HANGER, 36 Liner Details Top Depth )TVD) Top Incl Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 10,185.2 3,206.0 86.30 SLEEVE HR Liner Setting Sleeve w/ 6' TBR 7.00" 6.240 1.11111111 10,193.8 3,206.7 86.51 XO 7 x 5.5 XO Sub 7" HYD 521 X5 -1/2" Hyd 521 (7.05" OD x 4.91 "ID) 4.910 10,194.8 3,206.7 86.54 SBR Receptacle Jt 5.5" 15.5# L80 5.5" Hdy 521 ( 5,73" OD xID 4.91") 4.910 10,236.6 3,207.4 88.14 XO XO Sub 5.5 "Hyd 521 X 4.5 "BTC (5.73 "OD X 3.97' ID) 3.970 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens CONDUCTOR Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date HO Type Comment Insulated. 10,238 10,281 3,207.5 3,209.6 WS D, 1J - 162L1 8/9/2007 32.0 SLOTS ALL PERFS: Alternating solid /slotted 42 - 120 p i pe 2.5"x..125" 4 circumferential NIPPLE, 522 ME rows/ft 10,496 10,703 3,196.7 3,177.2 WS D, 1J -162L1 8/9/2007 32.0 SLOTS 10,872 14,432 3,178.2 3,142.9 WS D, 1J -162L1 8/9/2007 32.0 SLOTS Notes: General & Safety End Date Annotation 8/16/2007 NOTE: MULTI - LATERAL WELL - 1J - 162 (B SAND), 1J1 - 62L1 (D - SAND) GAS LIFT, 2.325 1 SURFACE. 4 1 a 43 -3.820 SLEEVE -C, 9,688 NIPPLE, 9,688 NI alf alli SENSOR, ' 9.738 Illr it g - t LOCATOR, 8,783 SLEEVE, 9,778 SEAL ASSY, 16 ,. 9,784 1 � -1 SBR, 9,791 AUll it II IL lit NIPPLE, 9,881�� WLEG, 9,924 D -SAND LINER HH, - \ at, 9,949 - 10,226 'I SLOTS, 10.238 - 10.281 INTERMEDIATE 10.75 8 9 825, - 40- - 10,400 1 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (poi) Run Date Com... 1 2,324.7 1,854.4 69.03 CAMCO KBMG 1 GAS LIFT SOV BK 0.000 0.0 9/29/2012 SLOTS, 10,496. 10,703 11 SLOTS, 10,872 - 14,432 D -BAND 10,185- 1 INER, TD(1J- 162L1), 14,489 • ConocoPnillips Time Log & Summary We!Mew Web Reporting Report Well Name: 1J - 162 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 9/9/2012 7:00:00 AM Rig Release: 9/30/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/08/2012 24 hr Summary Freeze protect and secure well. Move off 1J -174 and spot rig over 1J -162 18:00 21:00 3.00 0 0 MIRU MOVE MOB P PJSM, Prep rig for move, move pipe sheds, Rock washer, Power pack & stage clear for sub. 21:00 00:00 3.00 0 0 MIRU MOVE MOB P Pull sub off 1J -174, Crab down well row and spot over 1J -162. 09/09/2012 Prep and move over 1J -162 spot complexes, rig accepted @ 0700 well killing operations, N/D wellhead. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Level sub, lay matting boards, set pit, pump, motor & boiler complexs. 02:00 03:30 1.50 0 0 MIRU MOVE MOB P Set rock washer, spot pipe sheds. 03:30 07:00 3.50 0 0 MIRU MOVE MOB P Connect service lines air, steam, electrical. Test all gas & H2S detectors. Rig accepted @ 0700 07:00 10:45 3.75 0 0 MIRU WELCTL RURD P Take on 8.6 brine, R/U circ. lines t/ tree & tiger tank. R/U scaffolding. 10:45 12:00 1.25 0 0 MIRU WHDBO RURD P R/U lubricator, test t/ 1000 psi, pull BPV, R.D lubricator 12:00 13:00 1.00 0 0 MIRU WELCTL PRTS P Flood surface Tines w/ H2O test t/ 3500 psi 13:00 16:15 3.25 0 0 MIRU WELCTL CIRC P Break circ. w/ 120° sea water w/ 3% KCL @ 168 gpm 300 psi ICP, Circ. until clean 600 bbls, 16:15 18:15 2.00 0 0 MIRU WELCTL CIRC P Bull head do IA @ 126 gpm 400 psi ICP 275 bbls fcp 625 psi 18:15 19:30 1.25 0 0 MIRU WELCTL OWFF P Monitor well 450 psi on both sides bleed pressure to zero monitor well, well still flowing back 1.5 BPH. 19:30 21:00 1.50 0 0 MIRU WELCTL CIRC P Rev circ 1 tubing volume Tight diesel returns, dump to rock. 21:00 21:30 0.50 0 0 MIRU WELCTL OWFF P Observe well for flow well static. 21:30 22:00 0.50 0 0 MIRU WHDBO OTHR P Set BPV, blow down & rig down lines to tiger tank. 22:00 00:00 2.00 0 0 MIRU WHDBO NUND P PJSM, N/D tree, prep TBG spool and install blanking plug as per Vetco rep. 09/10/2012 Test BOP's, Unseat hanger pull to floor, POOH standing back tubing in derrick, UD ESP assembly. 00:00 02:30 2.50 0 0 MIRU WHDBO NUND P N/U BOP stack 02:30 03:00 0.50 0 0 MIRU WHDBO RURD P R/U t/ test BOP's fill stack with H2O Page 1 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 09:30 6.50 0 0 MIRU WHDBO BOPE P Test BOP, Test upper & blind rams, choke valves 1 -14, Auto & man IBOP HCR & man. choke & kill, 4" Demco, TIW & DART, t/ 250 low 3500 high w/ 4" & 4.5 test jts. Acc. test. Jeff Jones AOGCC waived witness 09:30 10:30 1.00 0 0 MIRU WHDBO RURD P R/D test equip. blow down choke and kill lines Pull blanking plug. 10:30 10:45 0.25 0 0 MIRU WELCTL OTHR P Fill hole w/ 20 bbls brine no returns 10:45 12:15 1.50 0 0 COMPZ RPCOM RURD P P/U & R/U casing & centrilift equipment, M/U landing jt. to T/D and hanger. 12:15 13:00 0.75 0 0 COMPZ RPCOM OTHR P R/U DHD & shoot ck shot fluid level @ 78', simops BOLDS 13:00 15:00 2.00 0 7,513 COMPZ RPCOM PULL P Unseat hanger w/ 175K, 90k overpull, pull hanger t/ floor diconnect ESP cable & penetrator, UD landing jt, hgr & single. 15:00 22:30 7.50 7,513 111 COMPZ RPCOM PULL P Pooh w/ 4.5 completion racking back 78 stands in derrick, UD 2 GLMs, Unique discharge sub, 6 pup joints and 5 joints to shed. Fill for trip= Act. =95.9 bbls, calc.= 34 bbls 22:30 23:00 0.50 111 111 COMPZ RPCOM OTHR P R/D ESP cable. 23:00 00:00 1.00 111 0 COMPZ RPCOM PULD P P/U ESP assembly with last joint and remove remaining damps, disassemble ESP. (217 Clamps & 3 Protectolizers) Total tour Toss= 140.5 bbls 09/11/2012 RIH P/U singles from shed, CBU © 8052' MD, Milled packer at 8184' MD to 8185' 00:00 00:30 0.50 0 0 COMPZ RPCOM PULD P Finish UD centrilift ESP assembly. 00:30 01:00 0.50 0 0 COMPZ RPCOM OTHR P Clear and clean rig floor. 01:00 02:00 1.00 0 0 COMPZ WELLPF BOPE P Set Test Plug and rig up test equipment. 02:00 04:45 2.75 0 0 COMPZ WELLPF BOPE P Test lower 2 -7/8" X 5" ram and annulur with 4" & 4.5" test joints, 250 low / 3500 high and record on chart. 04:45 05:15 0.50 0 0 COMPZ WELLPF BOPE P R/D test equipment and set 9" ID wear ring. 05:15 05:45 0.50 0 0 COMPZ WELLPF SFTY P PJSM on P/U Baker Packer Mill BHA. 05:45 08:30 2.75 0 0 COMPZ WELLPF PULD P PJSM, M/U Packer Mill BHA 08:30 09:15 0.75 0 500 COMPZ WELLPF TRIP P PJSM, sinlge in the hole with 4" drill pipe T/ 500' well out of balance, flowing out dp. 09:15 09:45 0.50 500 500 COMPZ WELLPF CIRC P Brk circ and pump drill pipe volume, monitor well taking fluid slowly. 09:45 12:00 2.25 500 2,078 COMPZ WELLPF TRIP P Continue RIH with singles from shed T/ 2078' MD, Calc= 23.8 bbls, Act= 1.25 bbls, Total losses for tour= 58.0 bbls. 12:00 18:15 6.25 2,078 8,052 COMPZ WELLPFTRIP P PJSM, continue to RIH F/ 2078' T/ 8052', ran out of down weight. Page 2 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 20:30 2.25 8,052 8,052 COMPZ WELLPF CIRC P M/U Top Drive and brk circ with 3.5 bpm with 100 psi, Observed dies' and gas migration in returnes, Got back 100 bbls of 7.0 ppg diesel and sent to rock washer until 8.6 ppg was attained, conintue to circ surface to surface @ 6.5 bpm with 600 psi. (Loss rate © 12 bph) Obtained SPRs @ 20:15 #1 @ 25 SPM= 110 psi, @ 35 SPM= 180 psi #2 @ 25 SPM= 120 psi, @ 35 SPM= 200 psi 20:30 21:00 0.50 8,052 8,175 COMPZ WELLPF TRIP P Continue RIH while rotating each joint down. F/ 8052' T/ 8175' 21:00 00:00 3.00 8,175 8,185 COMPZ WELLPF MILL P M/U to joint # 248 with top drive, P/U wt= 115K, S/O wt= 35K, Rot wt= 77K, Tq off= 6.5K, pump with= 6.5 bpm= 600 psi, 80 RPM, S/O and tag Packer @ 8180' MD, Mill with 1.5 Wt.,Tg on= 8K for 10 min and I increase to 100 RPM and stage wt up to 15K, Tq on 9 -12K, Mill to 8185' and pump 15 bbl hi -vis sweep. Total tour loss= 72.9 bbls 39/12/2012 POOH and M/U spear assembly, RIH tagged @ 8205' MD, Pushed fish down to 9058' and engage fish, CBU, POOH 00:00 04:30 4.50 8,185 8,188 COMPZ WELLPF MILL P Continue milling on TorqueMaster Packer F/ 8185' T/ 8188' with 6.5 bpm 600 psi, 100 RPM, WOB= 20 -30K, P/U 115K, S /O= 35K, Rot= 77K. 04:30 04:45 0.25 8,188 8,202 COMPZ WELLPF MILL P Push fish T/ 8202' MD with pumps and roatation, set 25K and torque up could not go any futher. 04:45 06:15 1.50 8,202 8,175 COMPZ WELLPF CIRC P CBU had some gas to surface, 6.5 bpm 550 psi @ 8175' MD, Losses= 35.9 bbls. 06:15 06:45 0.50 8,175 8,175 COMPZ WELLPF OWFF P Monitor well, hole taking fluid @ 6 bph 06:45 12:00 5.25 8,175 3,429 COMPZ WELLPF TRIP P UD 2 joints, POOH F/ 8175' T/3429' MD calc= 27 bbls, Actual= 52 bbls, Total losses= 61.0 bbls 12:00 13:00 1.00 3,429 410 COMPZ WELLPF TRIP P PJSM, Continue POOH F/ 3429' T/ 410' MD 13:00 13:15 0.25 410 410 COMPZ WELLPF OWFF P Monitor well, Observed hole taking fluid, 6 bph. 13:15 15:15 2.00 410 0 COMPZ WELLPF PULD P UD 6 DCs & rack back 2 stands off DCs, Break out junk baskets and clean same. (5 Gal of shavings) 15:15 16:15 1.00 0 0 COMPZ WELLPF PULD P Clear rig floor and UD junk baskets and pick up subs for next BHA 16:15 17:30 1.25 0 215 COMPZ WELLPF PULD P PJSM, M/U spear assembly BHA # 2to215'MD 17:30 21:15 3.75 215 7,385 COMPZ WELLPF TRIP P RIH on 4" dp to 7385' P/U and run 9 jts DCs (4.75 ") and 15 jts 4" HWDP to 8120' for push pipe, Displacement Act= 38.74, Calc= 64.27 bbls. Page 3 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 00:00 2.75 7,385 9,058 COMPZ WELLPF FISH P M/U TD on stand 77, P /U= 110K, S /O= 60K, Circ 3 bpm with 350 psi, wash down & tag © 8205' set down 10K on spear, P/U to 125K, 10K O /P, S/O & tag @ 8209' set down with 15K, P/U to 130K when pulled loose, did not see any drag, P/U single RIH to 8243' did not take any wt., UD single and RIH with 5 stand from derrick to 8692', cont. single in F/ 8692' tagged © 9058', set down w/ 15K, P/U 30' no drag, S/O & set down 20K, P/U 10 off btm & kelly up, P /U= 120K, S /O= 55K. Trip= Act= 0.0, Calc= 5.5 bbls. Total for tour= 41.58 bbls. 39/13/2012 Finish CBU, POOH and UD Fish, Perform NOV Derrick inspection, UD 6.1/2" DCs from derrick, M/U clean out BHA 00:00 01:45 1.75 9,029 9,029 COMPZ WELLPF CIRC P CBU at 9029' MD, 5 bpm with 900 psi. 01:45 02:00 0.25 9,029 9,029 COMPZ WELLPF OWFF P Monitor well, fluid dropping slightly. 02:00 08:45 6.75 9,029 215 COMPZ WELLPF TRIP P PJSM, POOH F/ 9029' T/ 215', P /U= 125K, Calc= 66.29, Act= 99.5 08:45 09:00 0.25 215 215 COMPZ WELLPF OWFF P Monitor well, slight loss. 09:00 10:30 1.50 215 0 COMPZ WELLPF TRIP P UD BHA and rack back two stands of DCs. 10:30 11:00 0.50 0 0 COMPZ WELLPF PULD P R/U casing equipment and lay down spear aseembly. 11:00 12:00 1.00 0 0 COMPZ WELLPF PULD P C/O elevators and lay down 4.5" LEM assembly. (Fish) Total Toss for tour= 52.51 bbls 12:00 12:15 0.25 0 0 COMPZ WELLPF PULD P Clear rig floor and rig down casing tools. 12:15 17:00 4.75 0 0 COMPZ WELLPF OTHR P PJSM with SIS and perform NOV Derrick dropped object survey. Work on MP2s, Clean around rig. 17:00 18:30 1.50 0 0 COMPZ WELLPF PULD P Load Shed with MI clean out subs and prep for next run 18:30 20:00 1.50 0 0 COMPZ WELLPF OTHR P PJSM, Lay down 6 -1/2" DCs 20:00 21:30 1.50 0 0 COMPZ WELLPF OTHR T Wrong Thread on Mule shoe, Sent jt of 3.5" TBG to get cut, SIM -OPS Swap out power tongs not biting TBG. 21:30 00:00 2.50 0 370 COMPZ WELLPF PULD P P/U and M/U clean out assembly BHA # 3 to 370' MD, Calc= 8.12 bbls, Act= 2.89 bbls. 09/14/2012 RIH to 6290 with clean out BHA took wt and stalling out, decision to POOH and check magnets, Recovered 184.5 # of debris, M/U baker clean out BHA & RIH to 9847' MD. 00:00 00:30 0.50 370 37 COMPZ WELLPF PULD P PJSM, CIO elevators and R/D casg equipment. Page 4 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 05:00 4.50 370 6,270 COMPZ WELLPF TRIP P RIH picking up 42 joints of dp from shed, Continue RIH from derrick to 4921' MD Took wt. Slack off while rotating & went by spot, Continue RIH and tagged up at 6240' MD (Tagged Junk F/ 4921' T/ 6270') Fill Act= 14.5 bbls, Calc= 32.4 bbls. 05:00 06:00 1.00 6,270 6,290 COMPZ WELLPF REAM P Brk Circ w/ 4bpm 400 psi at 6222' MD, wash and ream to 6240' took wt. increase pump to 7 bpm with 1080 psi attempt to clean up junk, reduce pump to 4 bpm with 15 RPM, Tq= 4K,wash and ream to 6290' MD, stalling out, decision to come out for BHA. 06:00 06:15 0.25 6,290 6,290 COMPZ WELLPF OWFF P Monitor well, Hole taking fluid slightly. 06:15 09:00 2.75 6,290 370 COMPZ WELLPF TRIP P POOH F/ 6290' T/ 370' MD 09:00 09:30 0.50 370 370 COMPZ WELLPF OWFF P Monitor well and Rig up Csg equipment. 09:30 11:15 1.75 370 0 COMPZ WELLPF PULD P Rack back BHA, UD magnets and clean same. ( Recovered 184.5 Ibs of metal) Trip Fill - Act= 55.52 bblss, Calc= 40.5 bbls. 11:15 11:30 0.25 0 0 COMPZ WELLPF PULD P Clear rig floor. 11:30 12:00 0.50 0 0 COMPZ WELLPF SLPC P PJSM, Slip and cut drlg line. Total losses= 51.66 bbls. 12:00 12:15 0.25 0 0 COMPZ WELLPF SLPC P Continue slip and cut drlg line. 12:15 13:00 0.75 0 0 COMPZ WELLPF SVRG P Service TD and Brake linkage, set COM. 13:00 14:00 1.00 0 0 COMPZ WELLPF PULD P Pick up to floor Baker subs for next run. 14:00 15:45 1.75 0 242 COMPZ WELLPF PULD P PJSM, M/U Baker cleanout BHA # 4 to 242' MD 15:45 20:00 4.25 242 6,850 COMPZ WELLPF TRIP P RIH and tag up @ 6234',n P/U 10' kelly up, P /U= 92K, S /0= 42K, Rot with 71K, Tq= 3K, Circ @ 9.5 bpm with 950 psi wash to 6850' MD. 20:00 00:00 4.00 6,850 9,847 COMPZ WELLPF TRIP P Continue RIH F/ 6850' T/ 7510', with less than 5K string wt. RIH with push pipe, continue RIH from derrick to 9132' ran out of down wt. Kelly up and wash and ream to 9847' MD, P /U= 120K, S /0= 35K, Circ with 9.5 bpm, Rot wt= 85K with 20 rpm, Tq= 6K, P/U= 125K, with pump off P /U= 125K. Total losses= 31.66 bbls. 09/15/2012 RIH to 9939' MD, Pump hi -vis sweep around, Monitor well, POOH & UD Baker BHA, (Recovered 1/2 Bucket of metal), P/U MI clean out BHA # 5, RIH to 5560' MD, Wash & ream to 7266' MD. 00:00 00:15 0.25 9,847 9,939 COMPZ WELLPF REAM P continue to wash and ream F/ 9847' T 9939' with 20 RPM, Tq= 7K, 9.5 bpm with 1600 psi, P /U= 130K, Could not slack off, contiue to rotate with 20 RPM. Page 5 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:15 01:30 1.25 9,939 9,939 COMPZ WELLPF CIRC P Pump 25 bbl hi -vis sweep @ 9.5 bpm 1600 psi 20 RPM, Tq= 7K, and work pipe. 01:30 02:00 0.50 9,939 9,939 COMPZ WELLPF OWFF P SPRs # 1 pump @ 25 spm= 140 psi, • @ 35 spm = 240 psi, # 2 pump @ 25 spm= 130 psi, @ 35 spm= 240 psi, Monitor well Fluid dropping slightly. 02:00 06:15 4.25 9,939 242 COMPZ WELLPF TRIP P POOH F/ 9939' MD T/ 8240 MD, P /U= 130K, Rack back 5 stds of HWDP & 3 stds of DCs, Cntinue POOH F/ 7510' T/242' MD, Fill= 87.38 bbis, Calc= 67.05 bbls. 06:15 06:30 0.25 242 58 COMPZ WELLPF TRIP P Rack back 2 stds of DCs. T/ 58' MD 06:30 07:45 1.25 58 0 COMPZ WELLPF PULD P UD BHA # 4 as per Baker, (Retreived 1/2 bucket of metal) 07:45 08:00 0.25 0 0 COMPZ WELLPF PULD P Clear and clean rig floor of Baker tools. 08:00 08:30 0.50 0 0 COMPZ WELLPF PULD P R/U csg equipment to P/U 3.5" tbg. 08:30 08:45 0.25 0 0 COMPZ WELLPF SFTY P PJSM, on M/U MI Clean out BHA # 5 08:45 10:15 1.50 0 370 COMPZ WELLPF PULD P M/U Clean out BHA as per MI Rep. to 370' MD 10:15 12:00 1.75 370 2,823 COMPZ WELLPF TRIP P RIH F/ 370' MDT/ 2823' MD, Fill= 7.82 bbls, Calc= 20.62 bbls. Total losses= 43.3 bbls. 12:00 15:00 3.00 2,823 6,300 COMPZ WELLPF TRIP P RIH F/ 2823' MDT /5560' MD, ran out of dn wt. Kelly up, P /U =92K, S /O= 37K, RT Wt= 75K, 20 RPM, 4K tq, 4 BPM with350 psi, Wash & ream to 6261' MD, stalling out, work through tight spot. 15:00 00:00 9.00 6,300 7,266 COMPZ WELLPF REAM P Work through tight spot 3 times, Increase pump rate to 7 BPM 1100 psi, with 40 RPM, 4 -5 Tq, Wash & ream slowly due to stalling out, increase limiter to 6K, and 50 RPM, ream F/ 6300' T/ 7266' MD, P /U= 120K, S /0= 35K, Rot wt= 75K.Pumped hi -vis sweep @ 7125' MD, (Total losses= 46.19 bbis) 09/16/2012 Cont. Wash & Ream dn to 10024' MD, Could not enter SBE, drop ball, pump sweep, did not see anything back, Monitor well, POOH T/2917' MD. 00:00 12:00 12.00 7,266 9,224 COMPZ WELLPF REAM P Wash & Ream F/ 7266' T/ 9068' MD, 50 RPM with 5 -6K Tq, Increased RPM to 80 with 6 -8 Tq, Pumping 7 bpm with 1100 psi, Wash & Ream F/ 9068' T/ 9224' MD, P /U= 125K, S /O= 35K, Rot wt= 80K. Pumped hi -vis sweep @ 7543' Total losses= 44 bbls. 12:00 15:00 3.00 9,224 9,947 COMPZ WELLPF REAM P Wash & Ream F/ 9224' T/ 9947' MD, with 80 RPM. 7 bpm, 100 psi, Stop rotation and reduced rate to 4 bpm to clean up top of hook hanger. Page 6 of 19 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:00 16:15 1.25 9,947 9,880 COMPZ WELLPF REAM P Attempt to pass throught hook hanger with 1 RPM No go, increase to 10 RPM and penitrated hook hanger, Wash and ream F/ 9959 T/ 10024' MD attempt to slide into SBE No success, pump stand out and rack back 2 stds to 9880'. 16:15 18:15 2.00 9,880 9,880 COMPZ WELLPF CIRC P Drop 1.75" bal, Circ ball down @ 2.5 bpm 150 psi, Shear out ball seat w/ 675 psi, open dual cativation ports, pump 20 bbl hi -vis sweep © 15 bpm 2900 psi, increased to 17 bpm and 3400 psi while rotating 80 RPM & reciprcate string 90', 1.5 hole volumes. Did not see anything back with sweep. 18:15 18:45 0.50 9,880 9,787 COMPZ WELLPF OWFF P Rack back std, Blow down, Monitor well, held PJSM 18:45 21:15 2.50 9,787 6,125 COMPZ WELLPF TRIP P POOH with MI clean out BHA# 5 F/ 9787' T/6125' MD, Fill Act= 29.41 bbls, caic= 23.3 bbls. 21:15 22:15 1.00 6,125 6,125 COMPZ WELLPF SVRG P Serviced Rig and Top Drive, (Monitor well across trip tank) 22:15 00:00 1.75 6,125 2,917 COMPZ WELLPF TRIP P Continue POOH F/ 6125'T/2917' MD, P /U= 67K, S /O= 55K, Total fill Act= 53.21 bbl, caic= 40.1 bbis. Toatl loss tour= 59.15 bbls. 09/17/2012 Finished POOH and found magnets full of shavings (287 lbs) talked to town engineer and decision made to rerun magnets, RIH to 6261' wash & ream down to 10050' MD attempt to enter SBE three times no go, R/U and reverse circ 1.5 times dp volume, POOH, UD MI clean out BHA, R/U and start testing BOPE. 00:00 00:30 0.50 2,917 370 COMPZ WELLPF TRIP P Continue POOH F/ 2921' T/ 370' MD, Fill Act= 32.6 bbis, Calc= 23.32 bbis. 00:30 00:45 0.25 370 370 COMPZ WELLPF OWFF P Monitor well, static. 00:45 01:15 0.50 370 370 COMPZ WELLPF PULD P Rig up csg tongs and equipment. 01:15 01:30 0.25 370 370 COMPZ WELLPF SFTY P PJSM on UD MI clean out BHA # 5. 01:30 03:15 1.75 370 157 COMPZ WELLPF PULD P UD clean out BHA # 5 as per MI Rep. Recovered 287 lbs of metal from magnets. Talked to town engineer and we will make another magnet run. 03:15 04:45 1.50 157 220 COMPZ WELLPF PULD P M/U clean out BHA # 6 with magnets and layed down scraper as per -MI. 04:45 07:45 3.00 220 6,261 COMPZ WELLPF TRIP P RIH F/ 220' T/ 6261' MD, P /U= 115K, S /0= OK, Rot wt= 74K, Act= 23.46 bbls, Calc= 39.32 bbls. 07:45 12:00 4.25 6,261 8,808 COMPZ WELLPF REAM P Wash & Ream F/ 6261.0 T/ 8808' MD 60 RPM 3-4 Tq, P /U =115K, S /0= OK, Rot wt= 74K, Act= 1.19 bbls, Calc= 13.5 bbls. Page 7 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:15 2.25 8,808 10,044 COMPZ WELLPF REAM P Cont. wash & ream F/ 8808' T/ 10044' MD, RPM= 80, to 9945 and reduce RPM to 10 RPM and entered Hook Hanger © 9955' MD, Increase RPM to 60 and continue washing with 2.5 bpm & 100 psi to 10044' MD, P /U= 130K, S /0= OK, Rot wt= 85K. 14:15 15:15 1.00 10,044 10,050 COMPZ WELLPF CIRC P P/U to tool joint, break and blow down T /D, R/U to rev. circ., M/U tool joint & RIH to 10044' MD, Decision made to circ down dp @ 2 bpm with 75 psi, Rot with 10 RPM 7.5K TQ, rot wt= 85K, attempt to wash down into SBE, after 3 attempts made it to 10050', took 30K over pull to come free, P/U to 10044' MD. 15:15 16:00 0.75 10,050 10,044 COMPZ WELLPF CIRC P Close annular and revr. circ @ 4.5 bpm with 250 psi ICP, FCP 350 psi for 1.5 dp volume. 16:00 16:15 0.25 10,044 10,015 COMPZ WELLPF TRIP P POOH to 10015' rack back std and blow down T/D and kill lines. 16:15 16:45 0.50 10,015 10,015 COMPZ WELLPF OWFF P Monitor well, hole taking fluid. PJSM 16:45 20:15 3.50 10,015 270 COMPZ WELLPF TRIP P POOH F/ 10015' T/ 270' MD 20:15 21:15 1.00 270 0 COMPZ WELLPF PULD P L/D MI cleanout BHA and 3.5 tail pipe 21:15 21:30 0.25 0 0 COMPZ WELLPF OTHR P Pull wear ring. 21:30 22:00 0.50 0 0 COMPZ WELLPF OTHR P P/U joint 4" dp & M/U stack washer, flush stack @ 20 bpm 130 psi, L/D same. 22:00 23:00 1.00 0 0 COMPZ WHDBO BOPE P P/U test joint and test plug and install same R/U test equipment. 23:00 00:00 1.00 0 0 COMPZ WHDBO BOPE P Test BOPE with 4" test joint, Test # 1 upper 3.5" x 6" VBR, choke valves 1,12,13,14 & manual kill valve. Test waived by AOGCC Inspector Chuck Scheve 09/18/2012 Cont to test BOPE t/ 250/3500 PSI. Test waived by Chuck Scheve of the AOGCC. L/D MI SWACO tools and M/U Baker mill clean out BHA. RIH w/ clean out BHA t/ 6530' MD, ran out of weight. Washed f/ 6530' MD t/ 10102' MD. Page 8 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 07:45 7.75 0 0 COMPZ WHDBO BOPE P Cont. t/ test BOPE t/ 250/3500 PSI w/ 4" test joint. Test #2: Top pipe rams, manual kill and HCR choke. Test #3: Upper IBOP and HCR kill. Test #4: Lower IBOP. Test #5: Dart valve. Test #6: 4" kill line. Test #7: Annular preventer. Test #8: Lower pipe rams. Change out test joint to 4 -1/2 ". Test #9: Top pipe rams, CV 1,12,13 and 14. Test #10: CV 9 and 11. Test #11: CV 5,8 and 10. Test #12: CV 4,6, and 7. Test # 13: Annular preventer and CV 2. Test #14: Lower pipe rams. Test #15: Blind rams. Accumulator test: system pressure =3000 PSI, pressure after closing= 1800 PSI. 200 PSI attained= 34 sec, full pressure after 193 sec. 5 bottle nitrogen avg= 1950 PSI.Lower IBOP failed- functioned and retested, OK. CV #2 failed, serviced and retested, OK. Test waived by AOGCC Inspector Chuck Scheve 07:45 08:00 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM, HRC and HRW on breaking down MI SWACO tools. 08:00 09:00 1.00 0 0 COMPZ WELLPF PULD P Break apart well scabenger, clean screens and make back up. Break apart sabs tool and UD as per MI SWACO rep. 09:00 09:45 0.75 0 0 COMPZ WHDBO RURD P R/D test equipment, pull test plug and drain stack. Blow down all BOP equipment. Set 9" ID wear bushing. Clean and clear floor. 09:45 10:45 1.00 0 0 COMPZ WELLPF RURD P Change out power tongs, mobilize 2 -7/8" handling tools to rig floor. Rig up to make up BHA. 10:45 11:00 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM, HRW and HRC on making up Baker mill clean out BHA. 11:00 12:00 1.00 0 0 COMPZ WELLPF PULD P Make up Baker mill clean out assy as per Baker rep. Losses for tour= 37 bbls. 12:00 17:30 5.50 0 6,530 COMPZ WELLPF TRIP P PJSM, cont. to make up BHA. RIH t/ 6530' MD, ran out of string weight. P /U =100K, S /O =35K. Actual displacement= 28 bbls, Calculated displacement= 39.4 bbls. 17:30 00:00 6.50 6,530 9,906 COMPZ WELLPF WASH P Wash down at 20 RPM w/ 3K TQ. Pump @ 3 BPM =200 PSI, ROT wt= 70K. f/ 6530' MD t/ 9906' MD. P/U = 130K w/ pumps off, S /0= OK, ROT= 85K, 7.5K TQ, 4 BPM= 375 PSI. Actual displacement= 5.6 bbls, Calculated displacement= 26.6 bbls. Losses for tour= 46.7 bbls, Losses for 24 hrs= 83.7 bbls. Page 9 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 39/19/2012 24 hr Summary POOH from 10095 to 6436. Washed from 6436 back to bottom. Circ Bottoms up, increased lubes to 4 %. POOH, laid down BHA. Slip /Cut drilling line, serviced rig. M/U LEM Assy as per Baker. 00:00 00:30 0.50 9,906 10,102 COMPZ WELLPF WASH P CONT WASH AND REAM F/9906' MD T/10102" MD @ 20 RPM/7.5K TQ, 4 BPM= 375PSI, STOPPED ROTATION AND CIRC SEAL BORE CLEAN @ 8 BPM= 1200PSI FOR 5 MINS 00:30 02:00 1.50 10,102 10,077 COMPZ WELLPFCIRC P POOH F/ 10102' MDT/ 10077" MD, P/U WT. =132K INCREASE PUMP T /10 BPM= 1800 PSI, PUMP AND CIRC OUT 21 BBL HI VIS SWEEP, CONDITION FLUID W/ 13 BLS 776 LUBE, 14 BLS LOTORQ, 3 SCKS FLOWZAN. 11 ADDTL SCKS FLOWZAN ADDED WHILE CIRC. 02:00 02:30 0.50 10,077 10,095 COMPZ WELLPFCIRC P OBTAIN SLOW PUMP RATES, #1 PUMP @ 25 SPM= 170PSI, 35 SPM =280 PSI #2 PUMP @25 SPM= 180PSI, 35 SPM= 280PSI, ROT. BACK DOWN T/10095' MD © 20 RPM =7.5K TQ, 4 BPM =375 PSI and UD SINGLE, MONITOR WELL 02:30 04:45 2.25 10,095 6,436 COMPZ WELLPF WASH P PJSM, POOH F/10095', P/U WT. =132K, MD T/6436, ACT FILL =32.13 BBLS, CALC FILL =23.36 BBLS. 04:45 10:15 5.50 6,436 8,606 COMPZ WELLPFWASH P WASH AND REAM @ 20 RPM =3K TQ, 5 BPM =375 PSI, RT WT =72K F/6436' MD, T/ 8606' MD, WASH DWN W/ NO ROTATION F/8608' MD T /10102'MD@ 5 BPM= 500PSI P/U WT. =100K, S /O =60K, POOH F/ 10102' MD T/10077' MD. ACT FILL 18.5 BBLS, CALC FILL =23.36 BBLS 10:15 11:30 1.25 8,606 10,077 COMPZ WELLPF WASH P WASH NO ROTATION@ 8 BPM =1250 PSI, 56% FLOW. 11:30 12:00 0.50 10,077 10,095 COMPZ WELLPFTRIP P RIH F/1077' MD T/10095' MD AND UD SINGLE, B/D TOP DRIVE NOTE: TOTAL TOUR FLUID LOSS =41 BBLS 12:00 12:15 0.25 10,095 10,095 COMPZ WELLPFOWFF P PJSM, SIMOPS MONITOR WELL (SLOWLY TAKING FLUID) P/U WT 105K, S/O WT 65K 12:15 16:30 4.25 10,095 395 COMPZ WELLPFTRIP P POOH F/ 10095' TO 395' FILL F/ TRIP =ACT 80.34 BBL. CALC 62.22 BBL 16:30 18:00 1.50 395 0 COMPZ WELLPF PULD P UD BHA 18:00 18:45 0.75 0 0 COMPZ WELLPF OTHR P CLEAN AND CLEAR FLOOR, HANG BLOCKS 18:45 19:30 0.75 0 0 COMPZ RIGMNTSVRG P PJSM, CUT DRLG LINE 72' (11 WRAPS) 19:30 20:00 0.50 0 0 COMPZ RIGMNTSVRG P SERVICE AND INSPECT BRAKE LINKAGE, T/D AND CROWN 20:00 20:15 0.25 0 0 COMPZ WELLPFOTHR P PULL WEAR BUSHING Page 10 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 21:00 0.75 0 0 COMPZ RPCOM PULD P P/U BOT SUBS, CHK LEW ASSY AND PREP F/ RUN 21:00 00:00 3.00 0 253 COMPZ RPCOM PULD P PJSM, M/U LEM ASSY & MWD AS PER DETAIL TO 253' DISP F/ TRIP= ACT .34 BBL CALC 2.69 BBL 09/20/2012 Continue RIH with LEM to 10048'. Wash down from 10048' to 10071'. Unable to get past 10071'. After several attempts to •et •ast 10071' a decision was made to POOH and make a clean out run. 00:00 00:45 0.75 253 253 COMPZ RPCOM PULD P Mix Pal mix in setting sleeve and let sit for 30 min as per Baker rep. 00:45 01:00 0.25 253 344 COMPZ RPCOM SRVY P PJSM, RIH t/ 344' MD and shallow hole test MWD tools @ 100 gpm= 300 PSI. Good test, blow down top drive. 01:00 10:00 9.00 344 9,868 COMPZ RPCOM TRIP P RIH f/ 344' MD t/ 9869' MD. P /U= 102K, S /O= 66K. Actual displacement= 34.28 bbls, Calculated displacement= 61.15 bbls. 10:00 10:30 0.50 9,868 10,048 COMPZ RPCOM SRVY P Circulate and pulse test MWD tools. MWD reading 154R. Wash down f/ 9869' MD t/ 9960' MD. RIH t/ 10048' MD on elevators. 10:30 12:00 1.50 10,048 10,069 COMPZ RPCOM WASH P Wash down f/ 10048' MD @ 2.5 BPM =375 PSI. Tagged up @ 10056' MD, set down 10K two times to work past. Washed down t/ 10065' MD, tagged up again and worked pipe multiple times. Turned to right 3/4 turn, still no go. Set down 18K observed weight wash off to 16K. Cont. t/ wash down w/ 18 -16K WOB. Increased pump rate to 3 BPM =550 PSI and washed down to 10069' MD. Total losses for tour= 43 bbls. 12:00 16:15 4.25 10,069 10,071 COMPZ RPCOM WASH P Cont to wash down w/ same parameters f/ 10069' MD. P/U and break over w/ 20K overpull after 30-45 min intervals. S/O and tag every 2' high every time w/ 18K max weight on LEM. Avg ROP while washing down= .5 FPH t/ 10071' MD 16:15 17:30 1.25 10,071 10,071 COMPZ RPCOM WASH P Pick up 20'. Shut down pump, close IBOP and annular.Bullhead 50 bbls of fluid down annulus @ 3 BPM =200 PSI ICP and 550 FCP. Pressure broke over @ 550 PSI w/ 40 bbls away. Bleed off 26.2 bbls back to pits and open well up. RIH t/ 10069' MD and attempt to wash down, after several attempts w/ same parameter, no success. Stand back stand, decision made to POOH and make clean out run. 17:30 18:00 0.50 10,071 10,050 COMPZ RPCOM OWFF T Blow down top drive and monitor well., SIMOPS hold PJSM on POOH. Page 11 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 10,050 2,331 COMPZ RPCOM TRIP T POOH w/ LEM assy f/ 10050' MD t/ 2331' MD © 50 FPM. P /U= 60K, S /O= 60K. Actual displacement= 61.61 bbls, Calculated displacement= 46.58 bbls. 09/21/2012 POOH and inspected LEM tool finding a piece of steal in LEM. M/U clean out BHA w/ scraper and rev circ junk basket. RIH t/ 10069' MD and wash hole. POOH and UD BHA. Found three pieces of steel in the rev circ basket. M/U polish mill and casing scraper and RIH. 00:00 01:00 1.00 2,331 253 COMPZ RPCOM PULL T Continued to POOH from 2331' MD to 253' MD. Actual fill =19.89 BBLS, Calc fill= 14.57 BBLS at 50 FPM. 01:00 03:00 2.00 253 253 COMPZ RPCOM PULL T Laid down LEM assembly and MWD as er Baker and Halliburton reps. re p p 03:00 03:30 0.50 253 253 COMPZ RPCOM OTHR T Clean and dear rig floor, set 9" wear bushing. 03:30 04:00 0.50 253 253 COMPZ WELLPF PULD T Mobilize Baker tools to rig floor. 04:00 04:15 0.25 253 253 COMPZ WELLPF PULD T PJSM, HRC and HRW on picking up and racking back 4.75" Drill Collars. 04:15 05:00 0.75 253 253 COMPZ WELLPF PULD T Picked up and racked back 3 stands of 4.75" Drill Collars. 05:00 06:15 1.25 253 0 COMPZ WELLPF PULD T PJSM, M/U Baker BHA #5. Cleaned out assembly as per Baker rep. 06:15 06:30 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor 06:30 07:30 1.00 0 0 COMPZ RIGMN7 SVRG T Service top drive and draworks, greased crown. 07:30 08:15 0.75 0 248 COMPZ WELLPF PULD T Re -dress reverse junk basket assembly and RIH with 2 stands of 4.75" Drill Collars. 08:15 12:00 3.75 248 9,955 COMPZ WELLPF TRIP T RIH f/ 248' MD t/ 9955' MD. Actual displacement= 55.42 bbls, Calculated displacement= 62.56 bbls. 12:00 13:00 1.00 9,955 10,069 COMPZ WELLPF WASH T Wash down f/ 9955' MD t/ 10069' MD, tagged up. Picked up 20' and rotate down @ 20 RPM =4K Tq, pump @ 8 BPM =1500 PSI. Pick up and slide down again, confirm XO bushing @ 10069' MD. 13:00 13:45 0.75 10,069 10,046 COMPZ WELLPF CIRC T Circulate bottoms up at 10046' MD @ 8 BPM =1550 psi. 13:45 14:00 0.25 10,046 10,046 COMPZ WELLPF OWFF T Monitor well, B/D top drive 14:00 18:45 4.75 10,046 300 COMPZ WELLPF TRIP T POOH from 10046' to 300'. Actual displacement= 77.37 bbls, Calculated displacement= 62.56 bbls 18:45 19:00 0.25 300 300 COMPZ WELLPF OWFF T Monitor well (Static) 19:00 19:45 0.75 300 277 COMPZ WELLPF PULD T UD BHA 19:45 20:00 0.25 277 277 COMPZ WELLPFSFTY T PJSM 20:00 20:15 0.25 277 277 COMPZ WELLPF OTHR T Clean and clear rig floor 20:15 22:00 1.75 277 277 COMPZ WELLPF PULD T R/U tongs and M/U BHA 22:00 00:00 2.00 277 5,375 COMPZ WELLPF TRIP T RIH w BHA from 277' MD to 5375' MD Page 12 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/22/2012 24 hr Summary Cont. RIH w/ 4 -11/16 polish mill and 7" scraper t/ 10106' MD. No -Go casing scraper on XO bushing @ 10069' MD. Pump HiVis sweep and circulate hole clean. POOH and UD clean out BHA. M/U LEM and RIH t/ 9870' MD. Wash LEM down, unable to get past 10072' MD. Decision made to POOH and M/U 9 -5/8 casing scraper and clean out down to the hook hanger. 00:00 02:00 2.00 5,375 9,984 COMPZ WELLPF TRIP T Continued to RIH from 5375' MD to 9984' MD (Calculated Displacement 62.56 BBLS Actual 55.4 BBLS) 02:00 02:45 0.75 9,984 10,069 COMPZ WELLPFTRIP T Kelly Up, P/U WT =105K, S /0 =66K, ROT. 85K TQ =4K, Pump at 6 BPM =750 PSI Wash Down from 9984' MD to 10069' MD. Tagged up on top scraper and saw pressuer increase to 900 PSI, pulled up 20' and then washed down again and re- tagged. Shut down and go down and tag up 2 times. 02:45 03:00 0.25 10,069 10,069 COMPZ WELLPFCIRC T Circulated at 11 BPM =1875 PSI, 62% flow. 03:00 04:45 1.75 10,069 9,994 COMPZ WELLPF PULD T POOH from 10069' MD to 9994' MD. Circulated at 12 BPM =2150 PSI, pumped 25 BBL high visc sweep while recipricating pipe slowly. (Observed a 50% increase in sand) 04:45 05:45 1.00 9,994 9,893 COMPZ WELLPF PULD T POOH from 9994' MD to 9893' MD and circulated surface to surface at 12 BPM= 2050 PSI. 05:45 06:00 0.25 9,893 9,893 COMPZ WELLPF OWFF T Monitor well B/D T.D. 06:00 10:00 4.00 9,893 277 COMPZ WELLPF PULD T PJSM, POOH from 9893' MD to 277' MD. Actual fill = 73.78 BBLS, calculated fill= 61.56 BBLS. 10:00 11:15 1.25 277 97 COMPZ WELLPF PULD T Lay down 6 joints of 4.75" Drill Collars and BHA as per baker rep. 11:15 12:00 0.75 97 0 COMPZ WELLPF PULL T R/U casing tongs and continued to lay down BHA. (TOTAL NIGHT TOUR LOSS 30 BBLS) 12:00 12:15 0.25 0 0 COMPZ WELLPF PULD T PJSM, continued to lay down BHA 12:15 13:15 1.00 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor. 13:15 13:45 0.50 0 0 COMPZ RPCOM RURD T Pull wear bushing, and rig up to run LEM 13:45 14:00 0.25 0 0 COMPZ RPCOM PUTB T PJSM, make up (LEM) BHA 14:00 15:45 1.75 0 0 COMPZ RPCOM PULD T M/U BHA 15:45 16:00 0.25 0 253 COMPZ RPCOM SRVY T Shallow hole test MIND pump 100 GPM = 250 PSI P/U 39K S/O 43K (Good test) 16:00 23:00 7.00 253 9,870 COMPZ RPCOM TRIP T Continue to RIH on DP from 253' MD to 9870' MD at 30' per minute. Cal displacement= 59.15 BBLS actual =46.75 BBLS 23:00 00:00 1.00 9,870 9,960 COMPZ RPCOM TRIP T Kelly up at 9870' MD wash down to 9960' MD, pump 100 GPM= 380 PSI P/U 97K S/O 66K orient LEM T/155 L, Continue to RIH to 10051'MD. (Total 29 BBL Loss for Tour) Page 13 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/23/2012 24 hr summary Ran casing scraper down to 9939' MD, Took 5K weight indicating top of hook. Tagged up on junk, washed down to 9934' MD. POOH and UD BHA. Recovered — 40 Ibs of metal off Baker magnets. 00:00 02:00 2.00 9,960 10,700 COMPZ RPCOM WASH T PJSM CONT. RIH W LEM Asseblmy. Started Taking WT @ 10061" MD Continued to S/O to 40K, made it to 10070' MD. Pulled up 117K Pops Free. Pull up w/ 115K then drops off to 100K. Turn String to right to 129 left, same results. Turn string to right 32 left, same results (no change). Look over previous runs, and check depth numbers. Call Town engineer and decision made to POOH. 02:00 02:15 0.25 10,700 253 COMPZ RPCOM OWFF T Monitor well. (SIMOPS prepare to POOH) 02:15 08:00 5.75 253 0 COMPZ RPCOM TRIP T POOH from 10061' MD to 253' MD. Act fill =77.35 BBLS, Calc Fill =61.15 BBLS 08:00 09:30 1.50 0 0 COMPZ RPCOM PULD T Laid down LEM BHA as per Baker rep. 09:30 09:45 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor 09:45 10:15 0.50 0 0 COMPZ WELLPF PULD T PJSM P/U Baker tool from beaver slide for next clean out run. Bring tools in pipe shed. 10:15 10:45 0.50 0 0 COMPZ WELLPF OTHR T Install 9" wear ring. 10:45 12:00 1.25 0 90 COMPZ WELLPF PULD T M/U BHA #7 scraper clean out run as per Baker rep. (Scraper = 9.625) (Total Tour Fluid Loss= 22 BBLS) 12:00 13:45 1.75 90 5,230 COMPZ WELLPFTRIP T RIH from 90' to 5230' 13:45 14:30 0.75 5,230 5,230 COMPZ WELLPF SFTY T PJSM fix spinner on iron rough neck p 9 14:30 15:00 0.50 5,230 5,230 COMPZ RIGMNT SVRG T Lubricate rig. 15:00 16:30 1.50 5,230 9,934 COMPZ WELLPFTRIP T Continued RIH with scraper from 5230' MD to 9934' MD (Calculated dis 60.49BBLS, Actual 53.73 BBLS) 16:30 17:00 0.50 9,934 9,939 COMPZ WELLPF WASH T Kelly up, P/U 100K S/O 66K ROT 82K TQ =4K. Washdown to 9939' MD. Took 5K weight indicating top of hook P/U 10' wash down to 9934' MD. Tagged up on junk P/U and rotate © 15 RPM TQ =4K. Increased pumps to 625 GPM washed down slow to 9934' MD. Took 5K and weight fell off. Cont wash down to 9939' MD worked pipe several times. 17:00 18:00 1.00 9,939 9,939 COMPZ WELLPF CIRC T Pump 30 BBL high visc sweep @ 625 GPM= 2250 PSI saw no cuttings. 18:00 19:00 1.00 9,939 9,906 COMPZ WELLPFTRIP T Laid down single, monitor well pull 10 stands from 9939' MD to 9006' MD 19:00 20:15 1.25 9,906 9,906 COMPZ RIGMNT SLPC T PJSM, Slip and cut drilling line 68'. Page 14 of 19 • e Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 00:00 3.75 9,906 60 COMPZ WELLPF PULD T Continued to POOH from 9906' MD to 60' MD. (Calc Disp= 59 BBLS Actual= 71.06 losses for Tour =36 BBLS) 09/24/2012 RIH w/ 7" scraper and polish mill, tagged up on junk © 9994' MD. Work past junk and run down t/ 10110' MD. POOH t/ 9800' MD and inject 50 bbls. POOH and UD BHA. M/U LEM and RIH. Unable to get past 10073' MD, attempt to work LEM down hole. 00:00 00:30 0.50 60 0 COMPZ WELLPF PULD T PJSM, UD BHA #7 as per Baker Rep 00:30 00:45 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear tools 00:45 01:15 0.50 0 0 COMPZ WELLPF RURD T PJSM, R/U to make up Baker BHA #8. 01:15 03:45 2.50 0 277 COMPZ WELLPF PULD T PJSM, M/U BHA #8 as per Baker rep. 03:45 06:00 2.25 277 9,994 COMPZ WELLPF TRIP T RIH F/ 277' MD, tag junk @ 9994' MD. P/U Weight =100K, S/O Weight =60K, ROT WT =85K. Actual fill= 57.04 BBLS Calc fill= 62.84 BBLS. 06:00 08:00 2.00 9,994 10,110 COMPZ WELLPF WASH T Break circulation @ 8 BPM, 1000 PSI, 55% Flow Rotate 30 RPM, 3.5K torque, tag at 9986' MD stall top drive. P/U rot down several times to 9986' MD top drive staving every time. Stop rotation and slide down to 10110' MD as per baker rep. 08:00 08:30 0.50 10,110 9,800 COMPZ WELLPFTRIP T POOH F/ 10110' MD to 9800' MD. 08:30 09:00 0.50 9,800 9,800 COMPZ WELLPF CIRC T Inject 50 BBLS © 5 BPM= 700 PSI, FCP =900 psi. 09:00 09:45 0.75 9,800 9,800 COMPZ WELLPF OWFF T Slowly bleed pressure and monitor well total flow back 12.5 BBLS. 09:45 10:00 0.25 9,800 9,800 COMPZ WELLPF OTHR T Blow down T.D. 10:00 12:00 2.00 9,800 6,125 COMPZ WELLPFTRIP T POOH from 9800' MD to 6125' MD. Total Tour Loss= 67 BBLS 12:00 14:00 2.00 6,125 279 COMPZ WELLPF TRIP T Continue to POOH from 6125' MD to 279'. 14:00 15:45 1.75 279 0 COMPZ WELLPF PULD T Lay down BHA 15:45 16:00 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor 16:00 16:15 0.25 0 0 COMPZ WELLPF OTHR T Pull wear bushing 16:15 16:30 0.25 0 0 COMPZ RPCOM RURD T R/U to run LEM 16:30 18:15 1.75 0 370 COMPZ RPCOM TRIP T PJSM, Run LEM 18:15 18:45 0.50 370 370 COMPZ RPCOM SRVY T Kelly up on first stand and shallow hole test pump 100 GPM =225 PSI test good 18:45 00:00 5.25 370 9,433 COMPZ RPCOM TRIP T B/D topdrive, RIH with LEM from 370' MD to 9433' MD P/U 100K, S/O 65K. Losses for Tour= 20 BBLS. 09/25/2012 Work string attempt t/ circ. down ann, unable t/ get down work string, observe well for flow static POOH t/ 345' UD BHA, R/U & ins ect derrick w/ 3rd party inspectors, R/U & test BOP. 00:00 00:30 0.50 9,433 9,894 COMPZ RPCOM TRIP T RIH f/ 9433' t/ 9894' Page 15 of 19 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:30 03:00 2.50 9,894 10,074 COMPZ RPCOM OTHR T CIRC @ 1058 gpm 400 psi, Orient MWD tag up @ 10073' work string t/ 10074', work right hand torque in, stage up t/ setting 30k on string, no change tag up @ 10074', pump 40 bbls down ann. @ 126 gpm 375 psi 03:00 06:45 3.75 10,074 10,074 COMPZ RPCOM OTHR T Attempt t/ slack off no change work string with different deflections w/ samer results. 06:45 07:00 0.25 10,074 10,074 COMPZ RPCOM OWFF T Observe well for flow static. 07:00 12:45 5.75 10,074 345 COMPZ RPCOM TRIP T POOH t/ 345' 12:45 13:00 0.25 345 345 COMPZ RPCOM OWFF T Observe well for flow static 13:00 15:30 2.50 345 0 COMPZ RPCOM PULD T UD BHA 15:30 15:45 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor 15:45 19:00 3.25 0 0 COMPZ WELLPF RURD T PJSM, third party derrick inspection (SIMOPS work on iron roughneck 19:00 20:15 1.25 0 0 COMPZ WHDBO RURD T R/U to test BOP 20:15 00:00 3.75 0 0 COMPZ WHDBO BOPE T PJSM test BOP #1 Top pipe rams, valve 1, 12, 13, 14 and manual kill. #2 Upper IBOP, HCR Kill, Valves 9, 11. #3 Lower IBOP, Valaves 5, 8 and 10. #4 Dart valve, Valves 4, 6, 7. #5 Floor valve and valve 2. #6 HCR choke, 4" kill line demco valve. #7 choke valve, HCR kill. 39/26/2012 Cont to test BOPE t/ 250/3500 PSI. Test witnessed by John Crisp, AGOCC. M/U storm packer and RIH. Set packer -100' below table and test. OA had 110 PSI on it, pump seawater down OA t/ kill backside, no success. UD storm packer and RIH the lower packer completion. Set packer w/ WLEG © 9925' MD. 00:00 03:15 3.25 0 0 COMPZ WHDBO BOPE T Continue testing BOP test 4" test jt, lower rams & ann, c/o & test 4.5 test jt. top & bottom rams & ann. t/ 250/3500, test blind rams & valve #3, acc. test, John Crisp witnessed test. 03:15 04:15 1.00 0 0 COMPZ WHDBO OTHR T Blow down choke manifold, top drive and kill line, R/D test equipment, clean & clear floor. 04:15 04:30 0.25 0 0 COMPZ WELLPF SFTY X Pre job safety meeting on running storm packer 04:30 06:15 1.75 0 965 COMPZ WELLPF RURD X R/U & run storm packer w/ 3 stands of 4.75 DC, 5 stands of 5" HWDP 06:15 07:00 0.75 965 0 COMPZ WELLPF PLUG X Set storm packer @ 110' release form packer pooh, UD packer setting tool, test packer t/ 1500 psi f/ 15 min. 07:00 07:15 0.25 0 0 COMPZ WELLPF SFTY X Pre job safety meeting on rigging up and pulling pack off 07:15 07:30 0.25 0 0 COMPZ WELLPF OTHR X P/U and M/U pack off pulling tool. 07:30 09:45 2.25 0 0 COMPZ WELCTL OTHR X Bleed OA down f/ 110 psi t/ 0 psi observe slight flow from OA shut in OA presure built back t/ 110 psi. 09:45 10:00 0.25 0 0 COMPZ WELCTL SFTY XT Pre job safety meeting on bull heading fluid down OA Page 16 of 19 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 10:00 11:15 1.25 0 0 COMPZ WELCTL CIRC XT Line up and bull head 100 bbls of 8.6ppg seawater down OA @ 84 gpm 375 psi. 11:15 13:00 1.75 0 0 COMPZ WELCTL OWFF XT Observe well for flow on trip tank, flow steady @ .34 bbls per 10 min. shut in well. 13:00 15:15 2.25 0 0 COMPZ WELLPF PULD XT UD storm packer BHA 15:15 15:45 0.50 0 0 COMPZ RPCOM RURD X Clean & clear floor, R/U t/ run completion. 15:45 16:00 0.25 0 0 COMPZ RPCOM SFTY X Pre Job safety Meeting on running lower completion. 16:00 17:15 1.25 0 0 COMPZ RPCOM PULD X P/U BHA, Lower completion 17:15 17:45 0.50 0 249 COMPZ RPCOM TRIP X RIH with completion T/ 249' MD, Break CIRC. Pump 2 BPM =50 PSI B/D Topdrive 17:45 22:45 5.00 249 9,913 COMPZ RPCOM TRIP X Continue RIH F/ 249' MD T/9913' MD. 22:45 00:00 1.25 9,913 9,925 COMPZ RPCOM PACK X Kelly Up break circulation @ 2 BPM =50 PSI. Shut down pump break connection drop ball, RIH to set depth @ 9925' MD and pump ball down @ 3 BPM= 225 PSI. P/U 125K, S/O 76K. (Calculated disp= 62.63, Actual disp= 53.04) Losses for Tour= 29 BBLS 09/27/2012 POOH laying down drill pipe t/ 4500' MD. M/U and set storm packer — 112' below table. Bull headed 144 bbls of 9.6 ppg brine down OA to kill OA, OWFF. Change Pack Off assembly and test. Cont POOH laying down drill pipe. UD BHA. R/U and RIH w/ 4 -1/2" upper completion. 00:00 00:15 0.25 9,925 9,822 COMPZ RPCOM PACK X PJSM, Pressure up to 4000 psi, set packer at 9822' MD. 00:15 00:30 0.25 9,822 9,822 COMPZ RPCOM PRTS X Pressure test packer to 2500 psi for 5 minutes. (Good) 00:30 00:45 0.25 9,822 9,822 COMPZ RPCOM RURD P R/D test equipment, blow down T.D. and kill line 00:45 01:00 0.25 9,822 9,822 COMPZ RPCOM SFTY P PJSM on laying down pipe. 01:00 02:00 1.00 9,822 9,102 COMPZ RPCOM PULD P Laydown 5 stands, HWDP. 3 stands of drill collars. Desicion made to UD more pipe due to having too much WT to set packer. 02:00 06:15 4.25 9,102 4,450 COMPZ RPCOM PULD P P/U protectors and continue to lay down drill pipe until we reach 70K string weight. 06:15 07:00 0.75 4,450 4,450 COMPZ WELLPF RURD XT R/U and M/U storm packer as per Baker Rep 07:00 07:45 0.75 4,450 4,450 COMPZ WELLPF PACK XT RIH and set storm packer and test T/1500 PSI for 5 min. (Good) as per Baker Rep. (COE@ 112' MD) 07:45 08:00 0.25 4,450 4,450 COMPZ WELLPF SFTY XT PJSM on R/U and pumping down OA. 08:00 09:15 1.25 4,450 4,450 COMPZ WELLPF KLWL XT Pump 144.5 BBLS 9.6 PPG sea water down OA @ 2 BPM, 500 psi, FCP =300 psi. 09:15 10:15 1.00 4,450 4,450 COMPZ WELLPF OWFF XT Monitor OA through trip tank. (.51 BBL gain) Page 17 of 19 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 10:30 0.25 4,450 4,450 COMPZ WELLPF RURD XT R/D Circulating equipment and drain stack. (No flow through OA). 10:30 11:00 0.50 4,450 4,450 COMPZ WHDBO OTHR X R/U and pull old packoff as per Vetco Grey Rep. (Pulled with 2K overpull). 11:00 12:00 1.00 4,450 4,450 COMPZ WHDBO OTHR X Install new packoff as per Vetco Grey rep. 12:00 13:45 1.75 4,450 4,450 COMPZ WHDBO PRTS X PJSM, Continue to run in lock downs, inject packing and pressure test pack off to 5000 psi for 10 mins (test good). R/D pack off setting tool. 13:45 15:00 ,1.25 4,450 4,450 COMPZ WELLPF RURD X PJSM, R/U and pull storm packer 15:00 15:30 0.50 4,450 4,450 COMPZ WELLPF PULD X UD storm packer. 15:30 16:00 0.50 4,450 4,450 COMPZ RPCOM TRIP P PJSM, RIH with 5 stands in derrick. 16:00 19:30 3.50 4,450 120 COMPZ RPCOM TRIP P PJSM, POOH UD DP 50 stands (Cal Disp= 27 BBLS Act= 35.53 BBLS) 19:30 20:00 0.50 120 0 COMPZ RPCOM PULD P UD BHA 20:00 20:30 0.50 0 0 COMPZ RPCOM OTHR P Clean and Clear rig floor, UD tools 20:30 21:00 0.50 0 0 COMPZ RPCOM RURD P PJSM, R/U to run 4.5" Liner 21:00 23:00 2.00 0 0 COMPZ RPCOM RURD P R/U centerlift 23:00 23:15 0.25 0 0 COMPZ RPCOM PULD P PJSM, P/U BHA 23:15 00:00 0.75 0 30 COMPZ RPCOM PULD P P/U seal assembly, locator and pup losses for Tour= 29 BBLS. 09/28/2012 Run 4.5 comletion line on spool tangled & broke, POOH replace line t/ sensor,run upper completion, rabbiting pipe from derrick and installing canon clamps on jts. 00:00 00:15 0.25 30 30 COMPZ RPCOM SFTY P PJSM on running 4.5 completion 00:15 00:45 0.50 30 66 COMPZ RPCOM RCST P R/U t/ drop rabbit f/ derrick, P/U 1 jt of tubing & sensor housing. 00:45 04:45 4.00 66 66 COMPZ RPCOM OTHR P R/U and M/U control line to sensor as per baker 04:45 06:45 2.00 66 66 COMPZ RPCOM RCST T RIH w/ 5 stands of 4.5 tubing, control line tangled on spool and broke, POOH & repair line. 06:45 09:30 2.75 66 66 COMPZ RPCOM OTHR T Make control line up t/ sensor. 09:30 11:15 1.75 66 66 COMPZ RPCOM OTHR T Repair line spooler. 11:15 00:00 12.75 66 7,756 COMPZ RPCOM RCST P Run upper completion as per detail, installing clamps on every connection, rabbiting pipe from derrick t/ 7756' MD, P /U= 73K, S /O= 55K. Actual displacement= 18.02 bbls, Calculated displacement= 37.67 bbls. 09/29/2012 Cont t/ RIH w/ 4 -1/2" tubing. Space out and land tubing w/ bottom of seals @ 9801' MD. Load IA w/ inhibited brine. Test hanger. Attempt to open SOV, no -go. N/D BOPE and N/U tree. Test tree t/ 5000 PSI. Freeze protest OA w/ 85 bbls of diesel. R/D to move to 2A -08. 00:00 03:00 3.00 7,756 9,490 COMPZ RPCOM RCST P PJSM, Cont to RIH w/ 4 -1/2" tubing t/ 9490' MD. Ran out of control line for sensor. Decision made to cap line. Page 18 of 19 Time Logs • • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 03:00 04:00 1.00 9,490 9,490 COMPZ RPCOM OTHR T Cap control line and clamp with cannon clamp mid joint on # 309. 04:00 06:00 2.00 9,490 9,801 COMPZ RPCOM HOSO P Cont t/ RIH and No -Go @ 9800' MD. Set down 20K. Space out tubing w/ 2 10' pups and 1 2' pup. P /U =79K, S /0= 55K. Bottom of seals @ 9788' MD. Adjusted RKB depth= 9800.94', 7' above located position. 06:00 06:45 0.75 9,801 9,801 COMPZ RPCOM HOSO P M/U Vetco hanger. 06:45 07:15 0.50 9,801 9,801 COMPZ RPCOM RURD P Rig up lines to circulate. 07:15 09:30 2.25 9,801 9,801 COMPZ RPCOM CIRC P PJSM, displace well w/ 430 bbls of 8.6 ppg inhibited seawater @ 6 BPM =500 PSI followed by 130 bbls of 8.6 ppg seawater @ 8 BPM= 750 PSI. 09:30 10:00 0.50 9,801 9,801 COMPZ RPCOM OWFF P Monitor well and flush stack. 10:00 11:15 1.25 9,801 0 COMPZ RPCOM THGR P Land tubing hanger, RILDs and test hanger void /seals t/ 5000 PSI for 10 minutes. 11:15 13:30 2.25 0 0 COMPZ RPCOM PRTS P Pressure test IA in 500 PSI increments to 1500 PSI f/ 10 minutes. Pressured up t/ 2700 PSI to shear SOV, no -go. SOV would not shear. Bled of pressure and pressured back up to 3500 PSI and held for 5 minutes several times. SOV would still not shear, decision made to set two way check and let slick line pull SOV. 13:30 14:15 0.75 0 0 COMPZ WHDBO RURD P Rig down landing joint and set TWC. 14:15 18:00 3.75 0 0 COMPZ WHDBO NUND P PJSM, Nipple down BOPs and nipple up tree. 18:00 18:30 0.50 0 0 COMPZ WHDBO PRTS P Test hanger void pack -offs to 250/5000 PSI f/ 15 minutes, good. 18:30 19:45 1.25 0 0 COMPZ WHDBO PRTS P Test tree t/ 250/5000 PSI f/ 5 minutes. 19:45 21:45 2.00 0 0 COMPZ WELLPF FRZP P PJSM, R/U Little Red to freeze protect OA. PT lines to 2500 PSI. Bull head 85 bbls of 70 °diesel down OA. Pump @ 2 BPM, ICP =700 PSI, FCP =900 PSI. 21:45 00:00 2.25 0 0 DEMOB MOVE RURD P Rig down for rig move to 2A -08. Rig leased © 00:00 hrs on 9 -30 -12 Page 19 of 19 i ~ ~, ~y ~. _~ ~ ~~~~~ ~ ~~''~y ~ .. .. .~,0 ,ti ':_ ~' ~r~ r~ r'ry,~~,, ~ ~ ,~ ~ ~ Ali ,.~.~ t MICROFILMED 6/30/2010 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS FEB 1 9 2010 1. Operations Performed: Abandon ""` Repair w ell ~ Plug Perforations ~"' Stimulate ~'" '~~l ~ ~i 0ni. Alter Casing ~ Pull Tubing F~rforate New Pool Waiver "` Time Extension ~~ ~ (., ce Iw- ~ Change Approved Program Operat. Shutdow n ~ Perforate "" Re-enter Suspended Well ""` 2. Operator Name: 4. Current Well Status: ~. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r' Exploratory "` 207-081 3. Address: Stratigraphic Service API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23360-60 7. Property Designatiot~~ 8. Well Name and jVumber: ADL 25661, 25660, 25663 ` 1J-162L1 9. Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 14489 feet Plugs (measured) None true vertical 3144 feet Junk (measured) None Effective Depth measured 14475' feet Packer (measured) none true vertical 3144' feet (true vertucal) Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 79 20 120 120' SURFACE 3777 13.375 3820 2201' INTERMEDIATE 9914 10.75 10400' 3245' D-SAND LINER 4291 7 14477 X31 d~~t`-,~4$fi~~.- ~-~~ ~ ~(~~~ 6~~..i~ ~4$fi Perforation depth: Measured depth: 10238'-10281', 10496'-10703', 10872'-14432' True Vertical Depth: 3208'-3210', 3197'-3177', 3178'-3150' ~ ~~ ~ S ~ ~ ~ ~ ~~M Se~F' ~~ hw -`~' 1~ ~ '~~ ~ ~ ~ ~^` ~ ~ Tubing (size, grade, MD, and TVD) tbg in main wellbore, , r i r c, Packers &SSSV (type, MD, and TVD) TorqueMaster pkr @ 8185' MD Z../y. ~'a no SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 157 742 6 -- 195 Subsequent to operation 9 0 276 -- 192 13. Attachments 't~. Well Class after proposed work: Copies of Logs and Surveys run E~loratory Develop ent Service 5. Well Status after work: Oi Gas ' WDSPL Daily Report of Well Operations XXX GSTOR ~ WAG " GASINJ "~" WINJ SPLUG ~'°" 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Erik Nelson t~ 263-4693 Printed Name E 'k NelSO Title Wells Engineer Signature '~ Phone: 263-4693 Date !A ~~ ~.c L~ly/O ? ~ ,~j ~~;~~ Form 10-404 Revised 7/2009 RBDMS FEB 19 ?~ ~~~' ' Submi! t Original Only Well Attributes ~~r'11~~}~'1 t1~E1~35 ~ ~' ~ _ _ Max Angle 8 MD TD .1 . "Wellbore APVU WI I Field Name Well Status lncl (°) MD (fi KB) Act Btm (ftK8) ,,. ._ ~~ ~" ~ 500292336060 WEST SAK (PROD ~ 96.76 10,498.05 14,489.0 .. IOOmment H25 {ppiril Date ~An notation End Date KB-Grd (ft) Rig Release Data WeILQu ug 4d?6,2Lt v2a120 uEaa_ -r,M SSSV' NONE ~~~ U 7/1 012 0 0 9 ILast WO' 1/21/2010 1 43.81 8/16/2007 '_'_ _. Sr~.nlal)p gCWol Annotation 'Depth (ftKB) End D'+It Mnotation • (Last Mod ... Entl Date Last Tag Rev Reason: ESP WORKOVER Imosbor 1;24/2010_ ~ HCANGER.S ~rl~ s S~SMi J ID Top (ftKB) Set Depth (f... Set Depth (ND) ... -',String Wt... iStr g String Top Thrtl HANGER, 3s- _ D-SAND HOOK 51/2 1 .l 9,949.0 10,225.7 3206.5 15.50 L80 BTC-M ^ Casing DescriptionString 0... Strinq 11] Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String _. String Top Thrtl D SAND LINER 41/2 4 fINR 10.1852 14,4766 3,143.6 11 60 L-80 BTC Liner Details _- P P ) To(P De th ' (ND) ToP Incl N i... To (ftKB ftK8) (°) Item D .'intiori Comment ID (n) 10,185.2 3,206.0 86.30 SLEEVE IHR Liner Setting Sleeve w/ 6' TBR 7.00" 6.240 ~,a 10,193.8 3,206.7 86.51 XO 7 ~:. 5)~ XO Sub 7" HYD 521 X 5-1/2" Hyd 521 (7.05" OD x 4.91"ID) 4.910 Ireelaled, - '~ SBF; Receptacle Jt S 5' 15.5# L80 5.5" Hdy 521 (5 73' OD zID 4 91 ") 4.910 conlDUCroR ~ 10,236.61 3,2074 8814 ~ - a2-1 z6 ~ -. _ _ _ . XO XO Sub 5.5"Hyd 521 X 4.5"BTC (5.73"OD X 3 9T IDj 3.970 I --. --_. _. __. __ ..__- '~ Perforations & Slots ____ .. ____ DS h 5 ~ .-_ Top (TVD) Bun (T1 41'! Top (ftKB) etrn (ftKB) (ftKB) (NIC6 Zone Date (s T Commend _ _ ESP ' 10,238 10,281 3,207 5 ::. u I a \NS D, 1J-162L7 8/9/2007 32 0!Slots Alternating solid/slotted pipe MANDREL - - 25"x..125" 4 circumferential rows/ft z.oo4 10,496 10,703 3,196.7 i~ 1 ! ~-`t ~h'S D, iJ-162L1 8!9/2007 32.0 Slots Alternating solid/slotted pipe 2.5"x,.125" 4 circumferential rows/H ! 10,872 14,432 3,178.2 °. 14;` si IA'S D, iJ-162L7 8!9/2007 32.0 Slots Alternating solid/slotted pipe 2 5'x..125" 4 arcumferential rows(fl I I I suRFACE. ~~ Notes:. General-& Safety __ 433,820 Entl Date __-- - - Annotation - J .8/1 612 00 7 NOTE: MULTI-L,4I f I rL YdELL- 1J-162 (B-SAND), 1J7-b2L7 (D-SAND) - ' 10/13/2008 NOl"E: VIEW SCIiF I I I If.,' wlAlaska Schematic9.0 ESP - __- ___ MANDREL. ],320 ^ISCHARGE. 7.400 INTAKE, 7,474 - SEAL.7484 ~-..- ~ .-,~ ESP Moor, . 7.as8 ~ Ek ~~-a 7,509 S 10.]5 z 9.625. sa-lo,400 siolz. .IYW ( 10,496-10,]03 '~>'I'i-~ Slon, e 10,872-t4 d32 D-SAND .n ~ ~~. LINER. 10,185'14,477 ~ ~ TD (~ J-t62L t ), . 14.489 • ConocoPhillips Time Log & Summary 1Mellview 4Yeb RepoRing ~~ P O Well Name: 1J-162 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1!11/2010 12:00:00 PM Rig Release: 1/21/2010 12:00:00 PM Time Los Date From To Dur S. De th E. De th Phase Code Subcode T Comment 1/10/2010 24 hr Summary Prepping rig for move 08:00 12:00 4.00 MLRU MOVE MOB P Move Rig F/36 to 10 12:00 15:00 3.00 MIRU MOVE MOB P Move Rig F/1Q to KOC 15:00 16:00 1.00 MIRU MOVE MOB P Grease Planetaries, load agitator 16:00 21:00 5.00 MIRU MOVE MOB P Move Rig F/KOC to 1J Pad 21:00 00:00 3.00 MIRU MOVE RURD P Assemble 13-5/8" BOPE 1/11/2010 Finished prepping 13 5/8" BOPE in cellar. Move rig over well. Accept Nordic 3 rig @ 1200 hrs 1-11-10. 00:00 10:00 10.00 MIRU MOVE RURD P Continue Assembly of 13-5/8" BOPE, Install lifting plate and re-attach annular. 10:00 12:00 2.00 MIRU MOVE MOB P Move rig around and spot over well. Rig containment. Accept Nordic 3 ri 1200 hrs 1-11-10. 12:00 14:30 2.50 MLRU WELCTL RURD P Bearm up (containment). Spot Equipment. PU & RU Lubricator.Pull BPV. 500 si on tb . LD lubricator. 14:30 19:00 4.50 MIRU WELCTL RURD P RU circulating hoses, load pits with seawater w/6% KCL. Thaw-kill line. 19:00 22:30 3.50 MIRU WELCTL RURD P Remove flange from cutting chute, s of cuttin s bin, hook u hi h line. 22:30 00:00 1.50 MLRU WELCTL RURD P Blow through cellar lines, found more blockages, thaw lines, clear all blocks es. 1 /12/2010 Kill well. Set BPV. ND tree. 00:00 01:30 1.50 COMPZ WELCTL RURD P PT circulating and hardline to 2500 si. 01:30 06:00 4.50 COMPZ WELCTL KLWL P Open well. SITP = 400 psi, SICP = 650 psi. Bled tbg & IA to 0. Pump 15 bbls down IA at 3.5 bpm, ICP = 760 psi, FCP = 760 psi. No returns. Pump 120 bbls hot SW w/ 6% KCL down tbg, ICP = 60 psi, FCP = 60 psi. Swap over to IA and pump at 3.5 bpm down IA, seeing +/-50% retums out the tbg. Pumped a total of 480 bbls down IA. ICP = 330 psi, FCP = 550 psi. Shut down and monitor well. Page 1 of 9 • Time Los :.Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:00 09:00 3.00 COMPZ WELCTL KLWL P Take on 580 bbls hot SW w/ 6% KCL, bullhead 300 bbls down the tubing to the formation. Bleed tubing & IA off f/400 psi to 0. Monitor well. - Press 0 but still ettin as. 09:00 12:00 3.00 COMPZ WELCTL KLWL P Bullhead 300 bbls seawater w/6% KCL down tubing. @ 6 BPM ICP = 110 psi .Pump pressure came up to 2000 psi slowed pump rate down to 1 BPM Broke over to 670 psi. Increase pump rate back to 5 BPM @ 670 psi pump rate came up to 6 BPM @ 360 psi. SD monitor well. Same results after 30 min. 0 Press. but still assin . 12:00 14:00 2.00 COMPZ WELCTL KLWL P Circulated with charge pump down tubing 50 psi venting gas to kill tank. Pumped 268 bbls with 20 bbls returns (crude). Blow down lines and minitor well. Let gas bleed to kill tank. Bled down to 0. 14:00 16:00 2.00 COMPZ WELCTL KLWL P Shot fluid level, top of fluid @ 835'. PJSM. Blow down lines. RD lines. Bleed of OA from 100 psi is 30 seconds shut valve and pressure would return to 100 si in 4 min. 16:00 18:00 2.00 COMPZ WELCTL MPSP P Set BPV. ND tree. 18:00 19:00 1.00 COMPZ WELCTL NUND P Nipple down Production tree. Inspect tubin hna er threads. -All ood. 19:00 20:30 1.50 COMPZ WELCTL NUND P Install Blanking plug, Nipple up Double studded ada ter. 20:30 00:00 3.50 COMPZ WELCTL NUND P Nipple up 13 5/8" BOP stack, choke & kill lines. 1 /13/2010 Continue NU BOP stack & Lines. RU & Test BOP's. BOPE test witnessed by J. Chrisp, AOGCC Rep. 00:00 03:30 3.50 COMPZ WHDBO NUND P Continue NU 13 5/8" BOP stack, choke & kill lines.. Function test Blind rams. RU test a ui ment. 03:30 06:00 2.50 COMPZ WHDBO NUND P Observed leak on choke side HCR lines. Rea it HCR line. 06:00 09:00 3.00 COMPZ WHDBO NUND P Funtion test BOPE. verify all Koomey valves/regulators are workin . RU test a ui ment. 09:00 20:30 11.50 COMPZ WHDBO BOPE P PT BOPE and choke maniflold t 250/5000 psi. Shot fluid levels on IA to keep up with top of fluid. 8:OOam 45', 1:OOpm 72', & 5:30 pm 2350. Loaded hole with SW. BOPE test witnessed by J. Chrisp, AOGCC Re . 20:30 21:00 0.50 COMPZ WHDBO MPSP P Pick up Landing Joint and pull Blankin Plu . 21:00 00:00 3.00 COMPZ RPCOM RURD P PJSM. Spot Crane. Remove spreader bar. Lift Guards, Spooling Unit, and Em S ool to ri Floor. 1 /14/2010 Circulate Well. Pull 4 1/2" ESP Completion. Lay down ESP Assembly. Page 2 of 9 Ir~ • Time Lo s .Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 01:30 1.50 COMPZ RPCOM RURD P Complete rigging up Spooling Unit.on Ri Floor. 01:30 04:00 2.50 COMPZ WELCTL CIRC P Attempt to pull Back Pressure Valve. Found trapped gas below BPV. Pump 35 bbls down tubing at 2.0 bpm. Well on vacuum. Pull BPV. La down same. 04:00 06:00 2.00 COMPZ WELCTI CIRC P Pick up Landing Joint. Monitor Well. RU IA to kill tank and bleed 100 psi from I. A. 06:00 08:30 2.50 COMPZ RPCOM RURD P Load centrilift equip. and move up to rig floor. RU circulating lines to IA & tubin for reversin . 08:30 11:30 3.00 COMPZ RPCOM CIRC P Pumped 230 bbls Seawaterw/6% KCL down tubing. Switched lines and reverse circulated 725 bbls taking returns to kill tank. 275 bbls returns. SD well on vacumm. 11:30 14:00 2.50 COMPZ RPCOM RURD P RU extra 20' hose to kill line on tubing. Install mouse hole. RU tools on floor for pulling tubing. RU centrilift a ui ment. 14:00 .15:00 1.00 COMPZ RPCOM PULL P PJSM covering pulling ESP & 4.5" tubing. BOLDS. Pulled hanger free with 150K. Pulled han er to ri floor. 15:00 16:00 1.00 COMPZ RPCOM CIRC P Attempt to fill hole. Pumped 102 bbls SW w/6% KCL but could not catch fluid. Well on vac. 16:00 17:00 1.00 COMPZ RPCOM RURD P Break out penetrator. Cut ESP cable at pigtail. Pick up on .string. Wt = 75K. String cable tru sheave and hang sheave in derrick, thread cable to s ooler. 17:00 00:00 7.00 COMPZ RPCOM PULL P Start pulled completion, drifting 4.5" tubing w/3.833" drift, racking back tubing in derrick and spooling up cable. Lay down GLM Assembly. Have 60 Stands (-5,600-ft) in Derrick at Midni ht. 1 /15/2010 Load and Tally 3 1/2" Drill Pipe and 5" Drill Collars in Pipe Shed. 00:00 02:00 2.00 COMPZ RPCOM PULL P Finish Pulling 4 1/2" Tubing, standing back in Derrick and ESP Com letion. 02:00 06:00 4.00 COMPZ RPCOM PULL P Lay down and inspect ESP Assembly. Found a hole burned in ESP Cable at -70-ft above the Discharge Sub. Recovered all ESP Completion, Clamps, Guards. Lost 4 bands. 06:00 21:00 15.00 COMPZ RPCOM PULD P Clean rig floor and running equipment. Start loading pipe shed with 3 1/2" drillpipe and Snozzlator wash down tools. Clean snow out of drill pipe, strap and number. Total 320 ea 3 1/2" Drill Pi a in Pi a Shed. 21:00 22:00 1.00 COMPZ WELLPF PULD P PJSM. Install Wear Bushing. Page 3 of 9 • • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T .Comment 22:00 00:00 2.00 COMPZ WELLPF PULD P Make up BHA as follows: 4 1/2" Bull Nose Wash Nozzle, 3 1/2" EUE 8rd Pin x 3 1/2" IBTM Box Pup Jt XO, 3 Jts ea 3 1/2"IBTM Tubing, 3 1/2" IBTM Pin x 3 1/2" EUE 8rd Box Pup Jt XO, Lateral Wash Nozzle, 1 Jt ea 3 1/2" EUE 8rd Tubing, 3 1!2" EUE 8rd Pin x 3 1/2" IF Box XO, 4 3/4" Bumper Sub, 4 3/4" OiI Jar, 4 11/16" Pum Out Sub, 1/16/2010 RIH with BHA and Drill Pipe. Wash D-Lateral Hook Hanger down to bottom of Seal Bore at 10,102-ft. 00:00 02:00 2.00 0 441 COMPZ WELLPF PULD P Continue to make up BHA. Change handling equipment to pick up Drill Collars. Finish making up BHA as follows: 3 1/2" IF Pin x 4" XT39 Box, 9 ea 5" Drill Collars, 4" XT39 Boxy 3 1/2" IF Pin. 02:00 07:00 5.00 441 4,452 COMPZ WELLPF PULD P Rig up to handle 3 1/2" Drill Pipe. PU &RIH with 3 1/2" 13.3 Ib/ft, IF, S-135 Drill Pi a from Pi a Shed. 07:00 09:00 2.00 4,452 6,900 COMPZ WELLPF PULD P Load Lateral Entry Module w/ MWD equipment into pipe shed to thaw out. Continue to RIH. UP wt 92K Dwn wt 50K 6900' 09:00 10:00 1.00 6,900 6,900 COMPZ WELLPF CIRC P RU lines, pump DP volume to clear wash out tool. 1750 psi ICP 3270 si FCP. 10:00 11:30 1.50 6,900 8,740 COMPZ WELLPF PULD P Rd lines. Continue to RIH from 6900' to 8740. Pipe falling slowly. Up wt 110K Dwn. 35K. Stopped falling on its own. Screwed in Top Drive, rotate 1 jt down with 4K ft.lbs torque. SD wait on tube. 11:30 13:00 1.50 8,740 COMPZ WELLPF CIRC P Mixed and pumped 150 bbls of Safelube, chased w/125 bbls SW/KCL. Working pipe up and down. 13:00 18:00 5.00 9,352 COMPZ WELLPF PULD P Continue RIH slowely. PUW = 100K. SOW = 40K. RTW = 75K. RPMs = 30. 18:00 22:30 4.50 9,900 COMPZ WELLPF PULD P Continue RIH slowely. PUW = 110K. RTW = 75K. RPMs = 30. Tor ue = 4K. Nozzle at 9,900-ft. 22:30 23:00 0.50 9,900 9,970 COMPZ WELLPF CIRC P Bring Pump #1 and #2 on line at 7.6 bpm/3,200 psi. Begin to wash from 9,900-ft. down to 9,970-ft. IA remains full while washin . 23:00 00:00 1.00. 9,970 COMPZ WELLPF EORP T Repair leak at the Rotary Hose/Goose Neck connection on To Drive. 1 /17/2010 Continue to wash down f/ 9,970' t/ 10,102'. Flush down IA w/ 120 bbls @ 7.5 bpm. POOH with D-Lat C/O BHA. MU BHA for LEM. RIH to 8,375-ft w/ WLEG and PKR 8.184' and ulledti ht. 00:00 02:00 2.00 COMPZ WELLPF EQRP T Complete repairs to Rotary Hose/Goose Neck connection on To Drive. Page 4 of 9 • • Time Lo s -Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:00 03:30 1.50 9,970 10,102 COMPZ WELLPF CIF2C P Continue to wash down from 9,970-ft at 7.5 bpm/3,200 psi. PUW = 110K. ROTW = 75K RPMs = 15. Troque = 4K. Washed through the D-Lateral Hook Hanger and down. to the bottom of the Seal Bore at 10,102-ft. No indication of an fill. 03:30 04:00 0.50 8,375 COMPZ WELLPF SFTY P PJSM. 04:00 04:30 0.50 10,102 9,902 COMPZ WELLPF TRIP P Pu112 stands of 31/2" Drill Pipe. Blow down To Drive. 04:30 05:00 0.50 9,902 9,902 COMPZ WELLPF CIRC P Bullhead 120 bbls down IA at 7.5 bpm/300 psi to flush any fines down hole. 05:00 13:30 8.50 9,902 0 COMPZ WELLPF TRIP P Trip out with the Wash Down BHA, standing back 31/2" Drill Pipe. Laying down 5"drill collars. LD jars; Bum er Sub and Wash Down Tool. 13:30 15:00 1.50 COMPZ WELLPF OTHR P Clean rig floor. Change elevators, o anize i e shed. 15:00 15:30 0.50 8,375 COMPZ WELLPF SFTY P PJSM. 15:30 17:30 2.00 COMPZ WELLPF PULD P Dump 1 drum 776 tube down hole. MU u BHA for LEM w/MWD. 17:30 18:00 0.50 COMPZ WELLPF OTHR P Change out floor equipment. 18:00 18:30 0.50 0 266 COMPZ WELLPF TRIP P Run in with one Stand of Drill Pipe. Perform MWD shallow pulse test at 2.0 bpm/130 - 200 PSI. Pump.#1 @ 42 s m. Pum #2 34 s m. 18:30 23:00 4.50 266 7,171 COMPZ WELLPF TRIP P . Trip in with BHA for LEM with MWD and 3 1/2" Drill Pipe from Derrick. Running speed = 90 seconds per stand. Weight check at 23:00 hrs: Up weight = 75K. Down weight = 60K. 23:00 00:00 1.00 7,171 8,375 COMPZ WELLPF TRIP T Continue run in hole. Attempted weight check at Midnight. Down weight = 55k. However, when attempting 4o get the up weight, saw a bobble just as full string weight was reached at -85K. Total fluid lost to well u to this date = 3,330 bbls 1 /18/2010 Discuss Options w/ town engr. Set PKR @ 8,184' and release off w/ running tool. PT 9 5/8" above PKR @ 2,500 si for 15 min. POOH LD 3 1/2" Drill Pi e. LD MWD and Baker Settin Tool. 00:00 03:30 3.50 8,184 8,184 COMPZ WELLPF TRIP T Attempt to go down hole. Set down to 35K. Packer will not move down hole. Pick back up to 125K. Packer appears to be set. Try one more time to go back down. Pick back up to 150K. Discuss options and plan forward with slope and Anchorage Engineering, Baker slope and Anchorage Engineering, and Day Company Man. fill tubing with 20 bbls. fill IA with 70 bbls. Monitor IA Flluid level remains static at surface. Page 5 of 9 • Time Los -Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:30 07:00 3.50 8,184 8,184 COMPZ WELLPF PACK T Received orders to complete setting the packer per Baker setting procedures. Set packer. Pressure test IA @ 2,500 psi x 15 min. Good test. Record same on chart. Release Settin Tool 07:00 08:00 1.00 8,184 7,000 COMPZ WELLPF TRIP P POOH standing back drill pipe from 8184' to 7000'. 08:00 09:30 1.50 7,000 COMPZ WELLPF RURD P Shut down pulling pipe. Set up crane to remove used spool of cable from s ooler and re lace with news ooL 09:30 11:00 1.50 COMPZ WELLPF OTHR P Loading pipe shed with ESP equipment to warm up before running. Move pipe etc around in pipe shed to accomadate next move. 11:00 .18:00 7.00 4,278 COMPZ WELLPF PULD P Continue to POOH laying down drill pipe. Lay down MWD and setting tools. RIH with remaining 3 1/2" Drill Pi a from Derrick. 18:00 18:30 0.50 COMPZ WELLPF SFTY P PJSM with Crew just rotating back to work. 18:30 23:00 4.50 4,278 0 COMPZ WELLPF PULD P Continue to single down 31/2" Drill Pipe in Pipe Shed. Clear Drill Pipe from Pi a Shed. 23:00 00:00 ..1.00 0 COMPZ RPCOM OTHR P Prep to pick up ESP equipment. Weatherford Servicehand perform checks to the A-Well I-Pum sensor. 1 /19/2010 PU and MU ESP Completion equipment and RIH to 356'. RU HES and set pump and pack off, PT @ 1,000 psig, set slip stop. Continue to RIH w/ completion. Make final splice and land hanger. RILDS and test han er void 5,000 si for 10 minutes.- Set BPV. 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR P Pull Wear Bushing. Clear Floor. Rig u Floor to handle 4 1/2" Tubin . 01:00 01:30 0.50 COMPZ RPCOM SFTY P PJSM. 01:30 06:00 4.50 0 0 COMPZ RPCOM PULD P Pick up and service ESP Assembly as follows: Centralizer, A-Well I-Pump Sensor, Motor, Tandem Seal Section, TTC Crossover. String ESP Cable over sheave. Attach ESP cable motor lead. Install discharge pressure capillary tubing. S of Halliburton S-Line Unit. 06:00 08:00 2.00 107 356 COMPZ RPCOM PULD P Continue with ESP Completion. Run 2 Jts of 4 1/2" Tubing, Make up 4 1/2" Unique Discharge Sub and tie in capillary tubing. Test A-Well I-Pump Sensor. Press/Temp readings good. Test ESP Cable, good. Run 2 Jts, Install GLM assembly w/Dummy Valve.. Run in with Tubing from Derrick. Sto to Ri u Halliburton 08:00 08:30 0.50 COMPZ RPCOM SFTY P PJSM. Page 6 of 9 r-~ U r~ u Time Lo s i Date From To Dur S. De th E. De th .Phase Code Subcode T Comment 08:30 10:30 2.00. 356 356 COMPZ RPCOM SLKL P Rig up Halliburton Slick Line Unit. Make up Pump Assembly with Gas Separator RIH and set. Pick up Pack Off. RIH and set. Pressure test pack off at 1,000 psi x 15 min. Good test. Pick up Slip Stop. RIH and set. Ri down Halliburton. 10:30 19:00 8.50 356 7,475 COMPZ RPCOM RCST P Continue to RIH with ESP Completion to 7,475'. MU hanger and landing jt. and space out for final splice. Used 217 Cannon Clamps 3 Protectolizers Note: There were no Bands used. 19:00 21:00. 2.00 7,475 7,475 COMPZ RPCOM OTHR P Centrilift Service Rep make ESP cable splice to penetrator connector. Test same. Good. 21:00 23:00 2.00 7,475 7,511 COMPZ RPCOM HOSO P Final pick up weight = 85K. Final down weight = 62K. Land Hanger. Final depth 7,511.3-ft ORKB. Visualize orientation through 4" side outlet. Run in lock down pins. Test Hanger pack off seals at 5,000 psi x 10 minutes. Good. 23:00 23:30 0.50 COMPZ RPCOM MPSP P Set BPV. Lay Landing Joint. Clear Floor. 23:30 00:00 0.50 COMPZ WHDBO SFTY P PJSM. Ready Cellar. Prep to nipple down Riser and BOP Stack. 1 /20/2010 ND BOPE, NU Tree. Test adapter seals and failed around penetrator. ND tree and inspect. Hang back tree and NU BOPE and Test @ 2,500/250 psig. Notified AOGCC @ 0700 hrs, John Crisp returned call @ 0805 hrs and-and requested a full BOP Test. Pull Tubing Hanger and inspect. Land Tubing Hanger. RILDS. Test Hanger seals at 5,000 psi x 10 min. Nipple up ROPE. NU Tree. Test Tree void. Leak @ 1,500 psi. Fluid b assin Penetrator. 00:00 04:00 4.00 COMPZ WHDBO NUND P Nipple down Riser and Flow Nipple. Nipple down 13 5/8" BOP Stack. Set back on stump. Nipple down the 13 5/8" Spacer Spool. Test ESP Cable and the A-Well I-Pump Sensor. Both tests ood. 04:00 06:00 2.00 COMPZ WHDBO NUND P Nipple up Tubing Adapter Flange and Production Tree. 06:00 06:30 0.50 COMPZ WHDBO PRTS T Pressure up and attempt to test adapter -failed @ penetrator. Found hanger not properly landing -offset enough to keep penetrator and TBG seal neck out of ali nment. 06:30 07:30 1.00 COMPZ WHDBO NUND T ND Tree and Adapter. Notified AOGCC @ 0700 hrs, John Crisp returned call @ 0805 hrs and and re uested a full BOP Test. 07:30 10:30 3.00 COMPZ WHDBO NUND T NU 13 5/8 5M BOPE 10:30 17:00 6.50 COMPZ WHDBO BOPE T Test BODE to 4 1/2" @ 2,500/250 si . .Page 7 of 9 • Time Lo' s Date From To Dur S. De th E. De th Phase Code Subcode T .Comment 17:00 18:30 1.50 COMPZ WHDBO BOPE T Rig down test equipment. Pull Blanking Plug. Pull Tubing Hanger to floor. Hanger pulled free at 130K and pulled to floor at 85K. Inspect Tubin Han er. 18:30 20:00 1.50 COMPZ RPCOM HOSO T Final pick up weight = 85K. Final down weight = 62K. Land Hanger. Final depth 7,511.3-ft ORKB. Visualize orientation through 4" side outlet. Run in lock down pins. Test Hanger pack off seals at 5,000 psi x 10 minutes. Good. 20:00 20:30 0.50 COMPZ WHDBO SFTY T PJSM. Ready Cellar and prep to Ni le down BOPE. 20:30 23:00 2.50 COMPZ WHDBO NUND T Nipple down Riser and Flow Nipple. Nipple-down BOP Stack and set back on stump. Nipple down 13 5/8" S aver S ool. 23:00 00:00 1.00 COMPZ WHDBO NUND T Nipple up Production Tree. Attempted to test Tree void. However at 1,500 a leak was noticed coming from outside of the Penetrator. Apply additional torque to flange bolts with Hydra-Torque wrench. Re-test Tree void. This time the leak occurred with zero ressure. 1/21/2010 Nipple down Tree. Inspect Penetrator and the inside of the Tubing Bonnet bore. Found a rough spot and a nicked o-ring. Corrected problem and replaced o-ring. Nipple up Tree. Tested Tree void at 5,000 psi x 10 minutes. Good Test. Test Tree at 5,000 psi. Good test. FP well. Set BPV and secure tree. Empty and clean its. Release Nordic Ri 3 1200 hrs. 00:00 03:30 3.50 COMPZ WHDBO NUND T Nipple down Tree. Inspect Penetrator. Saw a small "rolled" area on the lip of the o-ring groove. Pulled o-ring and found a small nick. Inspected the inside of the Penetrator bore in the Tubing Bonnet. Found a small rough area that matched the marks on the Penetrator and the nick in the o-ring. Dressed up the Penetrator o-ring groove and shinned up'the marks with 100 grit sand paper. Also dressed off the inside of the Tubing Bonnet with same. Installed new o-ring from another Penetrator. Nipple up Tree. Tested Tree void @ 5,000 psi x 10 minutes with much 'o .Good test. 03:30 05:00 1.50 COMPZ WELCTL PRTS P Pull BPV. Install Test plug. Pressure test Production Tree at 5,000 si. Good test. 05:00 08:00 3.00 COMPZ RPEOPI FRZP P Spot Lil' Red Hot Oil Unit. PJSM. Pressure test line at 2,500 psi. Freeze protect Tubing with 30 bbls of Diesel and the IA with 200 bbls of Diesel. Page 8 of 9 l Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08:00 10:00 2.00 COMPZ RPEOPI MPSP P Monitor TBG for flow and set 4" HPBV, Secure tree. _10:00 12:00 2.00 COMPZ MOVE OTHR P Empty and clean pits, Release Nordic Ri 3 1200 hrs. Page 9 of 9 1J-162 Pre and Post Rig Summary DATE JOBTYP SUMMARY 7/11/09 ESP /Jet Pum RIH WITH FISHIN~OOLS TO PULL SLIP-STOP AND TAGG FILL @ 7300' CTMD.RIH AGAIN WITH JSN AND CLEAN DOWN TO TOP OF SLIP-STOP @ 7427' CTMD. RIH AGAIN WITH FISHING TOOLS AFTER FCO AND MADE SEVERAL ATTEMPT TO LATCH SS WITH NO SUCCESS.FOUND MORE SAND. PACK AROUND G-SPEAR.RETURN IN AM FOR ANOTHER ATTEMPT. 7/12/09 ESP /Jet Pum PULLED SLIP-STOP, PACKOFF AND INSTALL ESP IN DEPLOYMENT FLANGE. READY FOR SLICK-LINE TO REMOVE PUMP. NOTE: PUMP IS 43.5 FEET LONG.PUMPED THROUGH SOV WHILE PULLING ESP TO WASH OFF ANY SAND.MADE SURE ESP STILL MOVE FREELY @ 100' / 75' AND 50' FROM SURFACE. 7/14/09 ESP /Jet Pum PULLED 47' 3/4" ESP FROM TREE. PULLED SOV @ 2276' RKB AND SET GLV. TESTED TBG WITH HOLEFINDER @ 2288' SLM, GOOD. COMPLETE. 8/7/09 Ice Plug Remc RAN 2" ICE PICK NOZZLE BUT DID NOT TAG UP ICE. ATTEMPTED TO INJECT IN WELL SEVERAL TIMES WHILE RIH BUT TBG PRESSURED UP. STOPPED NOZZLE JUST ABOVE MOTOR SPLINE @ 7476' CTMD WITH OUT TAGGING. SHUT THE WING VALVE. WELL TAKING FLUID NOW 1.2 BPM @ 100 PSI WHP. SUSPECT A SMALL SAND BRIDGE WAS CLEARED-POOH LEAVING WELL FREEZE PROTECTED. DSO PUT WELL ON PRODUCTION. JOB COMPLETE. 10/27/09 Slickline Misc. GAUGE 3.855" TO 2250' SLM, THICK FLUID, IN PROGRESS. 10/28/09 Slickline Misc. DRIFT 2.72" CENT TO 2598' SLM. DRIFT 2.67" G-RING TO 4739' SLM. COMPLETE. 1213/09 Ann-Comm PRE RWO T-POT (PASSED ), T-PPPOT (FAILED ), UT-POT (PASSED ), UT- PPPOT (PASSED ), LT-POT (PASSED ), LT-PPPOT (PASSED ), IC-POT FAILED ), IC- PPPOT (FAILED ), FT-LDS ALL NORMAL. 1/3/10 Ann-Comm IC POT -FAILED. IC PPPOT -FAILED. 1/3/10 Drilling Suppor MEASURED SBHP (714 PSI )@ 7210' SLM, GRADIENT STOPS (634 PSI )@ 6010' SLM & (625 PSI) @ 5910' SLM. COMPLETE 1/19/10 Drilling Suppor NORDIC RIG JOB.SET 4 1/2" ESP OAL=37.42'.SET PACKOFF ASSY OAL=8.39' WITH CHECK AND KOBE K.O.TESTED TO 1000#.SET TBG STOP ON PACKOFF ASSY. 1/23/10 Drilling Suppor SET SLIP STOP CATCHER. SET 2000# TBG>CASING SOV @ 2003' RKB, GOOD TEST. PULL CATCHER. JOB COMPLETE } ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 7/20/2009 Permit to Drill 2070810 Weli Name/No. KUPARUK RIV U WSAK 1J-162L1 Operator CONOCOPHILLIPS ALASKA INC MD 14489 ND 3144 Completion Date 8/16/2007 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-23360-60-00 UIC N REQUIRED INFORMATION c/ Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR / RES Weli Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Weli Data Maint Log Log Run ~nterval OH / 1 pe meairrmt num~er Name ~caie meaia rvo srar[ s[op ~.n rcecervea ~ommenrs ED D Asc Directional Survey 0 14489 Open 9/12/2007 E D Asc irectional Survey 0 10497 Open 9/12/2007 PB 1 D C Lis 15668" Induction/Resistivity 3785 14489 Open 11/12/2007 LIS Veri, GR, RPM, FET, RPS, ROP Rpt 15668 LIS Verification 3785 14489 Open 11/12/2007 LIS Veri, GR, RPM, FET, RPS, ROP D C Lis 15669~nduction/Resistivity 3785 10524 Open 11/12/2007 P61 LIS Veri, GR, RPM, FET, RPS, ROP Rpt 15669 LIS Verification 3785 10524 Open 11/12/2007 PB1 LIS Veri, GR, RPM, FET, RPS, ROP "ED C 18051 ~ee Notes 0 0 Open 5/21/2009 EWR Logs in CGM, EMF and PDS graphics oED C 18052v5ee Notes 0 0 Open 5/21/2009 PB 1 EWR Logs in CGM, EMF and PDS graphics Log ~/ Induction/Resistivity 25 Col 120 3143 Open 5/21/2009 ND DGR, EWR / Log`~ Induction/Resistivity 25 Col 120 3143 Open 5/21/2009 MD DGR, EWR Log '~ Induction/Resistivity 25 Col 120 3190 Open 5/21/2009 P61 ND DGR, EWR Logf Induction/Resistivity 25 Col 120 10524 Open 5/21/2009 P61 ND DGR, EWR i Well Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/20/2009 Permit to Drill 2070810 Well Name/No. KUPARUK RIV U WSAK 1J-162L1 Operator CONOCOPHILLIPS ALASKA INC MD 14489 ND 3144 Completion Date 8/16/2007 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL IPFORMATION Well Cored? Y /~ Chips Received? ~/ N~r Analysis ~TTR Received? Daily History Received? ~ Formation Tops ~~ N API No. 50-029-23360-60-00 UIC N Comments: Compliance Reviewed By: Date: p~ ( 3M~J~ ~.?'~°` ~ ~ ~ , ~ ~ ~~ ~..,~~`~.~~ ~~~~.~ ~ j~s'~, ~ 'a~ r'f~(1'~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~;~ f~~r ~~ E~ ~.<-~ ;_~ ~.~ ~,:~f t~~~~~`-~~_'~ REPORT OF SUNDRY WELL OPERATIONS ~~ R ~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ~ Stimulate ^ Other ~ ' ESP to Gaslift Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhllflps Alaska, InC. Development ~^ • Exploratory ^ 207-081 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23360-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 122' ~ 1J-162L1 • 8. Property Designation: 10. Field/Pool(s): ALK 25661, 25660, 25663 ' Kuparuk River Unit / West Sak Oil Pool . 11. Present Well Condition Summary: Total Depth measured 14489' ~ feet true verticai 3144' • feet Plugs (measured) Effective Depth measured 14475 ~ feet Junk (measured) true vertical 3144 • feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 20" ~20 120' SURFACE 3777' 13-3/8" 3820 2208' iNTERMEDIATE 10360' 10-3/4" x 9-5/8" 10400 3245' B SAND LINER 4426' 5-1/2" 14480 3219' D SAND LINER 4292' 4-1/2" 14477 3144' Perforation depth: Measured depth: 10238 - 10281; 10496 - 10703; 10872 - 14432 true vertical depth: 3208 - 3210; 3197 - 3177; 3178 - 3143 Tubing (size, grade, and measured depth) 4-1/2", L-80, 7512 MD. Packers & SSSV (type & measured depth) SSSV = NONE PACKER = C-2 B-SAND ~INER TOP PKR, D-SAND SBR 10043', 10195' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 431 129 34 199 201 Subsequent to operation 285 ~ 12 12 397 227 14. Attachments 15. Well Class after proposed work: , Copies of Logs and Surveys run _ Exploratory ^ Development ~^ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~^ ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact B. Christensen/ D. Humphrey Printed Name e . Ch is nsen ~ Title Production Engineering Specialist Signature ^~ ~---~_ Phone:659-7535 Date ~/~~ ~ Form 10-404 Revised 04/2004 ~.r l~~~c~~ ~, ~, l ~.. ~~ Submit .~t~~..d~ ~ ~ ~ 1J-162L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/14/09 07/12/09 07/11/09 ,PULLED 47' 3/4" ESP FROM TREE. PULLED SOV @ 2276' RKB AND SET GLV. TESTED '~ TBG WITH HOLEFINDER @ 2288' SLM, GOOD. COMPLETE. ', PULLED SLIP-STOP, PACKOFF AND INSTALL ESP IN DEPLOYMENT FLANGE. READY FOR SLICK-LINE TO REMOVE PUMP. NOTE: PUMP IS 43.5 FEET LONG.PUMPED THROUGH SOV WHILE PULLING ESP TO WASH OFF ANY SAND.MADE SURE ESP STILL MOVE FREELY @ 100' / 75' AND 50' FROM SURFACE. RIH WITH FISHING TOOLS TO PULL SLIP-STOP AND TAGGED FILL @ 7300' CTMD.RIH AGAIN WITH JSN AND CLEAN DOWN TO TOP OF SLIP-STOP @ 7427' CTMD. RIH AGAIN WITH FISHING TOOLS AFTER FCO AND MADE SEVERAL ATTEMPT TO LATCH SS WITH NO SUCCESS.FOUND MORE SAND PACKAROUND G-SPEAR.RETURN IN AM FOR ANOTHER ATTEMPT. .,,, . ConocoPhillips r11:1'~h.f. 11 N HANGER.36 coNOUCroa .~iaiee, ~ ~z.izo ESP MANOREL, z,z~s SURFACE. 03-3,820 DISCHARGE. 7 3~3 INTAKE, 7 4W SEAL,7461 I1 s~oa. 10.872~11,032 o-snrao LINER, 10.185-71,OP TD(7J-162L1), 11.089 KUP ~ 1J-162L1 Well Attributes Max An le & MD TD Wellbore API/UWI Fieltl Nartro Wall SWNa 500292336060 WEST SAK PROD Incl (°) MO (ttKB) 96.76 10,498.05 Act Btm (ItKB) 74,489.0 Commant M]S ~ppm) SSSV: NONE 0 Dab 12/26/2007 Annotatlon Last WO: Entl Date NB{3rtl (k) 43.81 Rig Releasa Date 8/16/2007 MnotaHOn Last Tag: Depth (!tl(B) EnA Dab Mnohtion Rev Reason: PULL PUMP, GLV C/O ~est Mod By Imosbor Entl ~ate 7/15/2009 Casin SVin s Casing Deacription QSAND HOOK HANGER S[rlnp 0... 5 1/2 Strinp ID ... 4.950 iop (ftNB) 9,949.0 Set ~epth (f... S 10,225J et DepM ITVD) ... 3,206.5 Strinp Wt... 15.50 S[ring ... L-80 String Top T~rC BTC-M Casing Dencription 0-SAND LINER String 0... 4 1/2 String ID ... 4.000 Top (RI(8) 10,1852 Set Oepth (~... S 14,476.6 et OepM (TVO) ... 3,743.6 Strlnp Wt... 11.60 S[ring ._ L-80 String Top 7hrG BTC Liner Defails ToD1~B) Top Dept~ (TVD) (RKe) Top Incl (°) I bm Descriptb n Comment ID (in) 10,185.2 3,206.0 86.30 S LEEVE HR Liner Setting Sleeve w/ 6' TBR 7.00" 6240 10,193.8 3,206.7 86.51 X 0 7 x 5.5 XO Sub 7" HYD 521 X 5-1/2" Fiyd 521 ( 7.05" OD x 4.91"ID) 4.9 t 0 10.194.8 3,206J 86.54 S BR Receptade Jt 5.5" 15.51t L80 5.5" Hdy 521 ( 5.73" OD xID 4.91") 4.910 10,236.6 3,207.4 88.14 X O XO Sub 5.5"Hyd 521 X 4.5"BTC (5.73"OD X 3.9T' ID) 3.970 Perfora tions 8 Slots Top(Itl(8) 86n~RK8) Top (TVD) (RKB) Btm ~TVD) ~RN9) Zone Date snoe Dena (a~~~~ Typa _ Comment ~ 10,238 10,281 3,207.5 3,209.6 W S D, 1J-162L7 8/9I2007 32.0 Slots Altemating solid/sloned pipe -~ 2.5"x..125" 4 circumferential rows/ft 10,496 10,703 3,196.7 3,177.2 W S D, 1J-16211 8/9/2007 32.0 Slots Altema6ng solid/slotted pipe 2.5"x..125" 4 circumferential rowsift 10,872 14,432 3,178.2 3,142.9W SD,1J-162L1 8/9/2007 32.O SIots Altemadngsolid/slottedpipe 2.5"x..125" 4 circumferentlal rows/ft Notes: General & Safe Ene Date Annolation 8/16I2007 NOTE MUITI-LATERAL WELL- 1J-162 (B-SAND), 1J1~2L1 (0.SAND) 10I13~2008 NOTE: VIEW SCHEMATIC wlAlaska Schematic9.0 Ma ndre~ Details Stn Top(RI(B) Top Dapth ~TVD) IRKB) Top Incl ~°) Maka Motlel OU (~~) Sarv Valw Type LaRh Type Port Slze I~N TRO Run (p~l) RunData Com... 1 2,276.3 1,836.2 66.92 Carr~co KBMG 1 ESP GLV BEK 5 0250 1,400.0 7/14/2009 ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-162+L1+L1PB1+PB2 May 18, 2009 AK-MW-5034902 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-162+L1+L1PB1+PB2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 360-00,60,71,72 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 3 60-00,60,71, 72 Digital Log Images 3 CD Rom 50-029-23360-00,60,71,72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 F~: 907-273-3535 B i on.com BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 G~ ,y' v ~ -~~ Date: M~~ ~ ~ 20~~ Signed: ~I. ~. RI~ ~ Co~~e ~~mr~~~sm~a~ ~n ~~ a~ ~o~ -o~o ~~os b ~o~-~~~ ~g~~ ~~ ~~~~ ~~~~ ~ ~ ~ • ~ Ct~rtC~C~l~h ~ I I ~ pS May 13, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: • J. Eggemeyer Engineering Leader Drilling 8~ Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 ~ hC.~~~~~ ~ ~~~~1 ~ ~ a~ O ~ ~ ~'~ ~ ~ ~T1 ~ s~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ o 3 ~ ~~ 0 a ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 1A-01, CD4-07, 1 J-122, 1 J-122L1, 1 J-122L2, CD4-322, 1 J-162, 1 J-162L1 you requested. These summaries will replace the shorter summaries alrea y su mitted with the comp(etion reports for these weils. If you have any questions regarding this matter, please contact me at 265-6049. Sincerely, ~. ~~~._._- . Eggemeyer Engineering Team Leader CPAI Drilling JE/skad ~ ~ Maunder, Thomas E (DOA) From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocophillips.com] Sent: Wednesday, January 30, 2008 8:13 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports thanks tom. I am sure we can accommodate. jce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, January 30, 2008 8:07 AM To: Eggemeyer, Jerome C. Cc: Alisup-Drake, Sharon K Subject: RE: Operations Reports Page 1 of 1 Thanks Jerome. These aren't urgently needed. Only other request, is send the reports "single sided". When we get double-sided, we have to shoot additional copies in order to scan. Tom From: Eggemeyer, Jerome C. [mailto:Jerome.C.Eggemeyer@conocophillips.com] Sent: Tuesday, January 29, 2008 10:36 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports thanks tom. As soon as Sharon is able to organize the data it will be sent over (hopefully only a few days depending on other activities). Let us know if it is needed more urgently. jce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, January 29, 2008 4:38 PM To: Eggemeyer, Jerome C. Cc: Allsup-Drake, Sharon K Subject: Operations Reports Jerome and Sharon, Thanks for sending the more detailed operations reports. I have further reviewed the Commission's files regarding 407's submitted since about August and found that more complete reports are needed for a few other wells. The wells are: 1J-162, -162L1 207-080, 207-181 ~at~~,v~~~ `r~ `--~~~ CD4-322 207-101 1 J-122, -122L1, -122L2 207-070, 207-071, 207-072 For the multilateral wells, a complete summary is only needed for the main wellbore with only the specific operations needed for the laterals. Your assistance in making the well records complete is appreciated. I will be reviewing the recently submitted sundry reports shortly and will send another message if necessary. Call or message with any questions. Tom Maunder, PE AOGCC ~~ ~~ ~' gii s/2oo9 ~ ~ ! ~ WELL LOG TRANSMTTTAL To: State of Alaska October 15, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`~ Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-162 Ll AK-MW-5034902 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23360-60 PLEASE ACK'i~10WZEDGE RECEIPT BY SIGNING AND RETUR.~TING A COPY OF THE TRAi~1SM1T"1'AL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Ancharage, Alaska 99518 ~ ~~ ~ ~ ~ .~_~ ~ ~,~ ~ a ~,1 ~~ ~~ F; ~ , ,~,~ _ .,, , ~~~,. ; ~~ r~,~, Date ~` ' ` ., ~ ~ ~ _,. _ z i.a 3F`~. I Signed: ~0'~'~~S ~ ~ 1 S ~~ ~f ~ ~ WELL LOG TRANSMITTAL To: State of Alaska October 15, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-162 L1 PB1 AK-MW-5034902 1 LDWG formatted CD Rom with verification listing. API# : 5 0-029-2 3 3 60-72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 T° ~ j , l ~ t ~.,. ~` ~.c 9 S .~. { £" a r' ~ ~ Date: ~ f ~ Signed: a~~ _~~ r ~ , ~ ~~9 Message ~ • Page 1 of 2 Maunder, Thomas E (DOA) From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocophiliips.com] Sent: Friday, October 12, 2007 12:05 PM To: Maunder, Thomas E (DOA) Cc: Reilly, Patrick J Subject: RE: 1J-162 (207-080) and 1J-162L1 (207-0811 Tom, I just sent a notice to the rigs requesting that they increase the information in the 24 hour summary such that an experienced drilling person should be able to understand what was accomplished, what went wrong and also get reasonable evidence of compliance with basic regulations. I am hoping we can find a good middle ground on the level of detail without ending up with a re-write of the hourly activity. Thanks for the dialogue, pat is out today but he will be available monday and can answer other questions if this does not cover it. Regarding diverter NU and BOP testing, window depth and OH sidetrack questions, following is information from the daily activity report: 7/5/07 0800 Nipple down 20" diverter stack. Flush annular. 7/6/07 0615 Test BOPE. Witness of test waived by AOGCC inspector John Crisp. Test annular w/ 5", Test upper variable rams( 3-1/2"x 6") w/ 5" and 5-1/2". Test lower pipe rams w/ 9-5/8" test joint. Testing all componets to 250 psi low and 3000 psi high. Koomey test: 200 psi build up in 25 seconds, full pressure 3 min 20 sec. Nitrogen BU 2300 psi avg. Valve # 3 in choke manifold leaked, greased and retested OK. 7/19/07 0930 Flush OA with 105 BBLs of water with rig pumps, final circulating pressure = 2 BPM - 200 PSI. Initial injectivity test indicated a 10.7 PPG EMW. Continue dress mud pump with 6" liners. Continue clean mud pits. 7/26/07 0900 Mill window from 9954' - 9972'. Pumps at 450 GPM's - 1750 PSI. TQ on - 12K. WOB = 2-5K. Sweep hole at bottom of slide. Average mill speed through casing = 6.15 ft/hr. TOW = 9954', BOW = 9970'. 7/28/07 1100 Perform OH sidetrack troughing from 10000' - 10035' MD. Thanks, Jerome -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gav] Sent: Friday, October 12, 2007 9:34 AM To: Eggemeyer, lerome C.; Reilly, Patrick ] Subject: i]-162 (207-080} and 1J-162L1 (207-081) 10/12/2007 Message ~ • Page 2 of 2 Jerome and Pat, I am reviewing the compCet`ron report for the sub~ well. i am aware that the namative summary of the drilling operations has been changett and Jerome has asked me if the info~rrtatic~n now presented is sufficient. It is difficult to make a generat statement regarding the sufficiency ather than when some specific work item is accomplished, it is probabty appropriate to include some defiaiL Test BOP, t~sf easing and test tubing seem ta be incamplete when at least a pr~essure vaiue and maybe a 6me are not included. In the case of these wells, the natrrative cfoes have not provide suffic~ent ir~formation on severat i#ems as noted below. 1. There is no mention of NU diverter ar tes6ng it 2. Ali that is mentioned about the initiat BOP test is °NU 13-5/8' B4P stack_ For either the diverter or initiat BOP test, there is no mention if an Inspector was present or if witrtess was waived_ Se~ch ir~formation is incEuc~ in fegafding the test an 8f1. It rrtay be appr+apr~ste to i~cfude the test pressures. 3. On 7 20, it is stated that tf~e OA was ftushed w~th water. Shaukf this re#er to the ~A and what pressures or EMW was de#ermined? 4. I cannot easily tell where the window was cut The d~pth Qf a Hrindc~v is an item that should be include in the narrative_ A comment on 7f31 may indicate that the top of the window is at 9954. 5. Pat and I exchanged a rr~ssage on August 1 regardirtg a si~etrack tttat oceuerecf on 7/28. It appears that prob~ms were er~ur~teeed with the initial sec~an Qf 1.f-162L1. Acxarding to the message 10035 -10524 was "abandaned' to colta{~se_ It ~ very d~tt to discer~ that an OH sidetradc occurred from the narratives of 7l27 - 7/28. Look forward to your reply. Catl or me.ssage with any questians. Tom Maunder, PE AOGCC 10/12/2007 1liV -~ j~ °a~~~~: ! ~ i (l .' . 1 ~f > ~ k N~~~~ 7 ~~~, i~~ ~, , ;~ ~ U~ 1°t+~Mo , , }~ ,,-,' ~ ~ ~ i ~ ConocoPh~il~ps October 2, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-162 and 1 J-162L1 Dear Commissioner: ~ Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 R~,~ElVED pC~ 0 ~ Z007 Alaska Oi! & Gas Cons. Cammissian Anct~orage ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak multi-lateral 1 J-162 and 1 J- 162L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, ~ ~~_, ~ ~ R. Thomas Kuparuk Drillirlg Team Leader CPAI Drilling RT/skad ~ STATE OF ALASKA /O-~7 ~ ~~°:~`:~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~, f~~ ;~ ~~Q~ WELL COMPLETION OR RECOMPLETION REPORT ~~ ~.~~ . 1a. Well Status: Oil O Gas Plugged ~ Abandoned ~ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: v "`{' "~ z Development D ~" ~~~x'ptf,%~atory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~~.~~ orAband.: August 16, 2007 12. Permit to Drill Number: 207-081 / 3. Address: P. 0. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 26, 2007 13. API Number: 50-029-23360-60 4a. Location of Well (Governmental Section): Surface: 1958' FSL, 2527' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: July 30, 2007 14. Well Name and Number: 1J-162L1 Top of Productive Horizon: 723' FSL, 72' FV1/L, Sec. 34, T11 N, R10E, UM 8. KB (ft above MSL): 41' RKB Ground (ft MSL): 121.8' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1414' FSL, 70' FWL, Sec. 3, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 14475' MD / 3144' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558683 y- 5945769 Zone- 4 10. Total Depth (MD + 7~/D): 14489' MD / 3144' ND 16. Property Designation: ALK 25661, 25660, 25663 TPI: x- 550733 y- 5944476 Zone- 4 Total Depth: x- 550772 - 5939888 Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 471, 470, 472 18. Directional Survey: Yes ^/ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 2194' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~ ~op orwindow ssa' MD / 3183~ ND GR/RES ~/,~a~sa ~ .~s'~.~o~.~~~-ry~,~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED 20" x 34" 78.6# H-40 41' 120' 41' 120' 42" 360 sx AS 1 13.375" 68# L-80 41' 3820' 41' 2201' 16" 8a3 sx AS Lite, 223 sx DeepCRETE 10.75" x 9-5/8' 73# / 40# L-80 41' 1536' ! 10400' 41' 3245' 12.25" 735 sx Class G 4.5" 11.6# L-80 9949' 14476' 3182' 3143' 8.5" slotted liner 23. Open to production or injection? Yes No Q If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 10078' 10871'-10703', 10495'-10208' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) ESP oil - shares production with 1J-162 Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-o1L RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes ~ No 0 Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory anaiytical results per 20 AAC 25.071. ti , W : i~i~ ~ i ] ~~ ~~ NONE ` ~ w_ . Form 10-407 Revised 2/2007 aR1~INAL CONTINUED ON REVERSE SIDE ~ ~~ GC~~ ~ ~~ 1dD7 ~~'~ ~ !l~r~ ~ ~ ~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD ND Well tested? Yes ~ No If yes, list intervals and formations tested, PeRnaf~ost - Top gf0und Su~feCe ground surface briefly summarizing test results. Attach separate sheets to this form, if Pe~maf~ost - Bottom 3750' 2194' needed, and submit detailed test information per 20 AAC 25.071. T3 3750' 2194' K15 3750' 2194' Ugnu C 6760' 2693' Ugnu B 7796' 2852' Ugnu A 8330' 2935' K13 8969' 3031' West Sak D 9890' 3174' West Sak C 14489' 3144' West Sak B 14489' 3144' N/A 1 J-162L1 P61 TD 14489' 3142' Forrnation at total depth: West Sak D 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ConteCt: Pat Reilly @ 265-6048 Printed Name"" Ran ~ Title: Drillinq Team Leader ! _ / Signature t ~-~~~~ '°-~~-----Pherie. Date ? V / ~L-,C.~ i ~ , ,. Z ~, SM ~ -~ S ~J , INSTRUCTIONS Sharon Allsu~Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPt (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~ • Halliburton Com an P Y Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/27/2007 Time: 11:21:37 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE)Reference: WeIL' 1J-162, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-162: 122A We1L• 1J-162 Section (VS) Reference: Well (O.OON,O.O OE,180.OOAzi) Wellpath: 1J-182L1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State PIan2 Coorciin~te Systa!?i 1927 Map Zone: Alaska, Zone 4 Ge~n i?~Lcre: NAD27 (ClBtice 1866) C~,o.snate ~ysiem: 1NPIi ~'_~~e~~irP_ ~ ~ys Datum: Mean Sea Level (Ueo~agnetic Model: bggm2007 Well: 1 J-162 Slot Name: AP150-029-23360-00 We11 Position: +N/-S -149.19 ft Northing: 5945769.63 ft Latitude: 70 15 44.790 N +E/-W -107.98 ft Easti ng : 558683.15 ft Longitude: 149 31 32.149 W Position Uncertainty: 0.00 ft Wellpath: 1 J-162L1 Drilled From: 1J-162PB2 I I 50-029-23360-60 Tie-on Depth: 9936.58 ft Current Datum: 1J-162: Height 122.00 ft Above System Datum: Mean SF? _~',;ci .~:.~- Magnetic Data: 6/2&/2007 Declination: 23.3t~' deg Field Strength: 57613 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.00 0.00 0.00 180.00 Survey Program for DeSnitive Wellpath Date: 7/30/2007 Validated: Y~ Version: 4 Actual From To Survey Toolcode Tool Name ft ft 100.00 651.00 1J-162P61 Gyro (100.Od-651.00) CB-GYRO-SS Camera based gyro single shot 713.37 3805.42 1J-162P61 IIFR+MS+Sag (713.37- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 3820.00 9936.58 1J-162P62 IIFR+MS+Sag (3820.00 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 9954.00 14461.92 1J-162L1 IIFR+MS+ Sag (9954.00- MWD+IFR-AK-CAZ-SC MWp+IFR AK CAZ SC C Survey MD Incl Azim TVD Sys TVD N/S E/W 1Y1~N MapE Toal ft deg deg ft ft ft ft R ft 41.00 0.00 0.00 41.00 -81.00 0.00 0.(~1 5945769.63 558683.15 TIE UNE 100.00 0.45 234.36 100.00 -22.00 -0.14 -0.19 5945769.49 558682.96 GS-GYRO-SS 149.00 0.51 214.60 149.00 27.00 -0.43 -0.47 5945769.20 558682.68 t':~-GYRO-SS 200.00 0.30 227.66 200.00 78.00 -OJO -0.70 5945768.92 558~3.+~ ~-GYRO-SS 273.00 1.65 260.52 272.98 150.98 -1.01 -1.87 5945768.61 55~6~1.28 CB-GYRO-SS 367.00 4.51 269.00 366.84 244.84 -1.29 -6.91 5945768.28 538676.26 CB-GYRO-SS 461.00 8.00 273.66 460.27 338.27 -0.94 -17.13 5945768.56 558666.03 CB-GYRO-SS 556.00 10.87 274.86 553.97 431.97 0.24 -32.66 5945769.62 558650.50 CB-GYRO-SS 651.00 13.23 278.48 646.87 524.87 2.60 -52.34 5945771.83 558630.80 CB-GYRO-SS 713.37 15.42 274.60 707.30 585.30 4.32 -67.66 5945773.42 558$15.46 hiWD+IFR-AK-CAZ-SC 780.65 17.90 271.82 771.75 649.75 5.37 -86.92 5945774.32 558596.20 MWD+IFR-AK-CAZ-SC 875.53 19.09 274.68 861.73 739.73 7.10 -116.96 5945775.81 558566.15 MWD+IFR-AK-CAZ-SC 971.53 23.62 270.59 951.12 829.12 8.58 -151.85 5945777.02 558531.25 MWD+IFR-AK-CAZ-SC 1065.93 27.76 267.98 1036.18 914.18 8.00 -192.75 5945776.12 558490.36 MWD+IFR-AK-CAZ-SC 1162.64 30.48 267.25 1120.65 998.65 6.02 -239.77 5945773.79 558443.36 MWD+IFR-AK-CAZ-SC 1256.73 35.19 267.65 1199.69 1077.69 3.77 -290.72 5945771.13 558392.43 MWD+IFR-AK-CAZ-SC 1351.53 36.44 269.48 1276.57 1154.57 2.39 -346.17 5945769.32 558337.00 MWD+IFR-AK-CAZ-SC 1446.88 38.52 270.63 1352.23 1230.23 2.46 -404.19 5945768.94 558278.99 MWD+IFR-AK-CAZ-SC 1542.11 41.52 271.90 1425.15 1303.15 3.83 -465.40 5945769.84 558217.78 MWD+IFR-AK-CAZ-SC 1637.24 46.26 271.68 1493.69 1371.69 5.89 -531.30 5945771.38 558151.87 MWD+IFR-AK-CAZ-SC 1732.33 49.51 271.47 1557.45 1435.45 7.82 -601.80 5945772.76 558081.36 MWD+IFR-AK-CAZ-SC 1827.63 54.06 271.76 1616.39 1494.39 9.94 -676.63 5945774.29 558006.53 MWD+IFR-AK-CAZ-SC 1920.91 57.06 272.59 1669.14 1547.14 12.87 -753.49 5945776.62 557929.65 MWD+IFR-AK-CAZ-SC 2015.25 59.56 272.77 1718.69 1596.69 16.62 -833.67 5945779.75 557849.45 MWD+IFR-AK-CAZ-SC 2113.84 62.11 271.22 1766.74 1644.74 19.60 -919.70 5945782.07 557763.41 MWD+IFR-AK-CAZ-SC 2207.83 64.87 271.31 1808.68 1686.68 21.46 -1003.78 5945783.27 557679.33 MWD+IFR-AK-CAZ-SC 2303.12 68.09 271.35 1846.71 1724.71 23.49 -1091.12 5945784.61 557591.99 MWD+IFR-AK-CP,Z-SC ! • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/27/2007 Time: 11:21:37 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE ) Reference: Welk 1J-162, T rue North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1'J-162: 122.0 Well: 1J-162 Section (VS)Reference: Well (O.OON,O.OOE,T80.OOAzi) Weilpath: 1J-162L1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2397.67 72.20 270.13 1878.81 1756.81 24.63 -1180.02 5945785.06 557503.09 MWD+IFR-AK-CAZ-SC I 2492.72 74.15 269.25 1906.32 1784.32 24.13 -1270.99 5945783.85 557412.13 MWD+IFR-AK-CAZ-SC ~ 2588.87 75.34 270.26 1931.62 1809.62 23.74 -1363.75 5945782.74 557319.38 MWD+IFR-AK-CAZ-SC 2683.19 76.39 271.85 1954.66 1832.66 25.42 -1455.20 5945783.71 557227.94 MWD+IFR-AK-CAZ-SC 2778.52 75.54 271.47 1977.78 1855.78 28.10 -1547.64 5945785.67 557135.49 MWD+IFR-AK-CAZ-SC 2872.79 78.01 270.17 1999.34 1877.34 29.41 -1639.39 5945786.26 557043.74 MWD+IFR-AK-CAZ-SC 2968.90 77.95 271.18 2019.36 1897.36 30.52 -1733.39 5945786.64 556949.74 MWD+IFR-AK-CAZ-SC 3064.56 76.42 270.50 2040.58 1918.58 31.89 -1826.65 5945787.28 556856.48 MWD+IFR-AK-CAZ-SC 3159.86 77.43 271.73 2062.14 1940.14 33.70 -1919.46 5945788.36 556763.67 MWD+IFR-AK-CAZ-SC 3253.23 75.67 273.78 2083.85 1961.85 38.05 -2010.16 5945792.01 556672.95 MWD+IFR-AK-CAZ-SC 3349.74 74.71 275.05 2108.52 1986.52 45.23 -2103.18 5945798.47 556579.88 MWD+IFR-AK-CAZ-SC 3443.93 76.41 273.80 2132.01 2010.01 52.27 -2194.12 5945804.79 556488.90 MWD+IFR-AK-CAZ-SC 3540.57 77.66 270.39 2153.70 2031.70 55.70 -2288.21 5945807.49 556394.79 MWD+IFR-AK-CAZ-SC 3635.13 79.11 268.74 2172.74 2050.74 55.00 -2380.83 5945806.07 556302.19 MWD+IFR-AK-CAZ-SC I 3707.38 79J5 269.81 2185.99 2063.99 54.10 -2451.85 5945804.61 556231:19 MWD+IFR-AK-CAZ-SC ~ 3805.42 78.85 267.67 2204.20 2082.20 51.98 -2548.15 5945801.75 556134.92 MWD+IFR-AK-CAY-SC 3820.00 78.47 267.53 2207.06 2085.06 51.38 -2562.43 5945801.04 556120.64 MWD+IFR-AK-CAZ-SC 3858.15 79.89 267J9 2214.23 2092.23 49.85 -2599.87 5945799.22 556083.22 MWD+IFR-AK-CAZ-SC 3953.80 79.44 266.37 2231.39 2109.39 45.06 -2693.85 6945793.69 555989.29 MWD+IFR-AK-CAZ-SC 4034.80 79.87 266.75 2245.93 2123.93 40.28 -2773.39 5945788.29 555909.80 MWD+IFR-AK-CAZ-SC 4143.86 79.90 266.60 2265.09 2143.09 34.05 -2880.57 594b781.23 555802.68 MWD+lFR-AK.-Cn~-SC 4236.17 77.56 267.10 2283.12 2161.12 29.08 -297Q.96 5945775.55 555712.34 MWD+IFR-AK-CAZ-SC 4333.04 79.39 267.52 2302.~8 2180.48 24.62 -3Q65.76 5345~ 7C.36 555617.58 MWD+IFR-AK-CAZ-SC 4427.98 78.93 269.61 2320.34 2198.34 22.29 3158.98 594SJ?67:~ 555524.40 MWD+IFR-AK-CAZ-SC 4523.16 78.50 270.05 2338.96 2216.96 22.01 -3252.31 594l~~fi.29 Sb5431.08 MWD+IFR-AK-CAZ-SC 4617.91 79.53 270.85 2357.02 2235.02 2274 -3345.32 5945766.30 555338.07 MWD+IFR-AK-CAZ-SC 4713.53 80.27 271.44 2373.78 2251J8 24.62 -3439.44 5945767.45 555243.95 MWD+IFR-AK-CAZ-SC 4808.18 80.75 271.61 2389.39 2267.39 27.11 -3532.76 5945789.20 555150.62 MWD+IFR-AK-CAZ-SC 490320 80.98 271.22 2404.48 2282.48 29.42 3626.55 5945770.79 555056.83 MWD+IFR-AK-CAZ-SC 4998.32 80.51 270.33 2419.77 2297.77 30.70 3720.42 5945771.33 554962.96 MWD+IFR-AK-CAZ-SC 5093.55 81.40 270.36 2434.74 2312.74 31.26 -3814.46 5945771.16 554868.93 MWD+IFR-AK-CAZ-SC 5188.46 81.74 270.44 2448.66 2326.66 31.92 -3908.35 5945771.09 554775.05 MWD+IFR-AK-CAZ-SC 5283.91 80.28 269.58 2463.57 2341.57 31.93 -4002.62 5945770.37 554680.79 MWD+IFR-AK-CAZ-SC 5378.94 81.82 270.19 2478.36 2356.36 31.75 ~ -4096.49 5945769.45 554586.93 MWD+~FR-AK-CA7_-SC 5473.58 80.92 270.67 2492.56 2370.56 32.45 -4190.05 5945769.42 554493.37 MWD+fFR-AK-CAZ-SC 5569.13 80.17 268.84 2508.26 2386.26 32:05 -4284.30 5945768.29 554399.14 MWD+IFR-AK-CAZ-SC 5663.45 81.15 268.92 2523.56 2401.56 30.23 -4377.35 5945765.74 554306.12 MWD+IFR-AK-CAZ-SC 5759.60 80.99 268.63 2538.49 2416.49 28.20 -4472.31 5945762.97 554211.18 MWD+IFR-AK-CAZ-SC 5854.41 80.81 270.25 2553.48 2431.48 27.28 -4565.92 5945761.33 554117.59 MWD+IFR-AK-CAZ-SC 5949.37 81.78 271.07 2567.86 2445.86 28.36 -4659.78 5945761.68 554023.74 MWD+IFR-AK-CAZ-SC 6044.68 81.12 271.30 2582.03 2460.03 30.31 -4754.01 5945762.89 553929.50 MWD+IFR-AK-CAZ-SC 6140.01 81.04 272.45 2596.81 2474.81 33.40 -4848.14 5945765.24 553835.37 MWD+IFR-AK-CAZ-SC 6234.72 81.42 271.28 2611.25 2489.25 36.44 -4941.69 5945767.56 553741.80 MWD+IFR-AK-CAZ-SC 6330.24 81.87 270.30 2625.13 2503.13 37.74 -5036.18 5945768.12 553647.31 MWD+lFR-AK-CAZ-SC 6424.66 79.86 269.83 2640.12 2518.12 37.85 -5129.40 5945767.50 553554.10 MWD+IFR-AK-CAZ-SC 6520.62 80.57 269.88 2656.43 2534.43 37.61 -5223.96 5945766.53 553459.55 MWD+IFR-AK-CAZ-SC 6615.44 80.79 269.92 2671.78 2549.78 37.45 -5317.53 5945765.63 553366.00 MWD+IFR-AK-CAZ-SC 6709.92 81.78 270.34 2686.10 2564.10 37.66 -5410.92 5945765.12 553272.62 MWD+IFR-AK-CAZ-SC 6805.97 82.05 270.29 2699.61 2577.61 38.18 -5506.01 5945764.90 553177.54 MWD+IFR-AK-CAZ-SC 6901.06 81.92 269.80 2712.87 2590.87 38.26 -5600.17 5945764.24 553083.39 MWD+IFR-AK-CAZ-SC 6995.88 80.61 268.52 2727.27 2605.27 36.88 -5693.88 5945762.14 552989.70 MWD+IFR-AK-CAZ-SC 7090.82 79.86 268.10 2743.37 2621.37 34.13 -5787.40 5945758.65 552896.21 MWD+IFR-AK-CAZ-SC 7186.20 51.32 270.64 2758.96 2636.96 33.10 -5881.48 5945756.89 582802.15 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Date: 8/27/2007 Time: 11:21:37 Page: 3 Co-ordinate(NE)'Reference: Well: 1J-162, Ttue North Site: Kuparuk 1J Pad Vertical(TVD)Reference: 1J-162: 122.0 Well: 1J -162 Sectian (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) i Wellpath: 1J -162L1 Survey Calculation Method: Minimum Curvature Db: Or2cle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 7281.60 80.76 271.27 2773.82 2651.82 34.67 -5975.70 5945757.72 552707.93 MWD+IFR AK-CAZ-SC 7376.12 81.45 271.62 2788.44 2666.44 37.02 -6069.06 5945759.35 552614.57 MWD+IFR-AK-CAZ-SC 7470.95 81.74 270.88 2802.30 2680.30 39.07 -6162.85 5945760.67 55252078 MWD+IFR-AK-CAZ-SC 7517.30 81.29 270.24 2809.14 2687.14 39.52 -6208.69 5945760.76 552474.94 MWD+IFR-AK-CAZ-SC 7566.28 81.49 268.04 2816.47 2694.47 38.79 -6257.10 5945759.65 552426.53 MWD+IFFt-AK-CAZ-SG 7661.46 81.30 263.99 2830.72 2708.72 32.25 -6350.97 5945752.38 552332.74 MWD+IFR-AK-CAZ-SC 7757.51 81.00 261.99 2845.50 2723.50 20.67 -6445.16 5945740.07 552238.65 MWD+IFR-AK-CAZ-SC 7852.83 81.43 259.05 2860.06 2738.06 5.15 -6538.06 5945723.83 552145.87 MWD+IFR-AK-CAZ-SC 7947.35 81.24 257.52 2874.30 2752.30 -13.82 -6629.55 5945704.15 552054.54 MWD+IFR-AK-CAZ-SC 8036.06 80.35 255.09 2888.49 2766.49 -34.55 -6714.62 5945682.76 55'l969.64 MWD+IFR-AK-CAZ-SC 8131.09 80.98 250.28 2903.91 2781.91 -62.45 -6804.12 5945654.17 551880.38 MWD+IFR AK-CAZ-SC 8225.86 80.79 246.51 2918.93 2796.93 -96.90 -6891.10 5945619.05 551793.68 MWD+IFR-AK-CAZ-SC 8320.62 81.53 244.17 2933.50 2811.50 -135.96 -6976.19 5945579.32 551708.90 MWD+IFR AK-CAZ-BC 8416.06 81.73 243.97 2947.39 2825.39 -177.25 -7061.11 5945537.38 551624.32 MWD+IFR-AK-CAZ-SC 8511.22 81.72 244.92 2961.09 2839.09 -217.87 -7146.06 5945496.10 - 551539.69 MWD+IFR-AK-CAZ-SC 8606.57 81.91 243.84 2974.66 2852.66 -258.68 -7231.16 5945454.63 551454.92 MWD+IFR AK-CAZ-SG 8700.33 80.79 240.88 2988.77 2866.77 -301.67 -7313.27 5945411.00 551373.16 MWD+IFR AK-CAZ-SG 8797.77 81.66 236.71 3003.64 2881.64 -351.56 -7395.61 5945360.48 551291.21 MWD+IFR-AK-CAZ-S~ 8891.18 80.47 233.11 3018.15 2896.15 -404.59 -7471.10 5945306.87 551216.14 MWD+IFR-AK-CAZ-SC 8986.81 81.29 229.58 3033.31 2911.31 -463.56 -7544.82 5945247.33 551142.89 MWD+IFR-AK-CAZ-S~ 9082.21 81.97 225.12 3047.20 2925.20 -527.49 -7614.22 5945182.87 551074.00 MWD+IFR-AK-CAZ-SC 9176.76 82.41 220.40 3060.06 2938.06 -596.25 -7677.80 5945113.62 551010.97 MWD+IFR-AK-CAZ-SC 9271.96 81.66 216.17 3073.26 2951.26 -670.24 -7736.20 5945039.19 55~953.15 MWD+IFR AK-CAZ-SC 9366.44 80.60 211.70 3087.83 2965.83 -747.66 -7788.31 5944961.37 550901.66 MWD+IFR AK-CAZ-S~ 9461.48 80.35 206.70 3103.57 2981.57 -829.45 -7834.02 5944879.24 550856.59 MWD+IFR-AK-CAZ-S~ 9556.96 80.60 202.63 3119.38 2997.38 -915.00 -7873.30 5944793.39 550817.97 MWD+IFR-AK-CAZ-SC 9651.96 80.41 198.47 3135.05 3013.05 -1002.72 -7906.19 5944705.43 550785.78 MWD+IFR-AK-CAZ-SC 9746.23 80.78 194.17 3150.47 3028.47 -1091.95 -7932.31 5944616,00 550760.35 MWD+IFR-AK-CAZ-SC 9841.65 80.54 190.19 3165.96 3043.96 -1183.97 -7952.18 5944523.84 550741.21 MWD+IFR-AK-CAZ-SC 9936.58 81.76 186.37 3180.57 3058.57 -1276.77 -7965.68 5944430.94 550728.43 MWD+IFR-AK-CAZ-SC 9954.00 81.77 186.27 3183.06 3061.06 -1293.91 -7967.57 5944413.80 5SU726.67 MWD+IFR-AK-CAZ-SG 10035.00 84.31 186.88 3192.88 3070.88 -1373.78 -7976.78 5944333.87 550718.08 MWD+IFR-AK-CAZ-SG 10117.24 84.62 186.73 3200.81 3078.81 -1455.06 -7986.48 5944252.52 550709.02 MWD+IFR-AK-CAZ-SC 10212.79 86.98 186.55 3207.81 3085.81 -1549.70 -7997.50 5944157.80 550698.74 MWD+IFR AK-CAZ-SC 10307.49 90.74 186.37 3209.69 3087.69 -1643.77 -8008.15 5944063.67 550688.82 MWD+IFR AK-CAZ-S~ 10402.88 94.24 186.19 3205.55 3083.55 -1738.48 -8018.57 5943968.88 550679.14 MWD+IFR AK-CAZ-S~ 10498.05 96.76 184.00 3196.43 3074.43 -1832.82 -8026.99 5943874.49 550671.46 MWD+IFR AK-CAZ-SC 10592.61 96.46 181.56 3185.54 3063.54 -1926.64 -$031.54 5943780.65 550667.64 MWD+IFR AK-CAZ-S~ 10687.68 92.88 180.69 3177.80 3055.80 -2021.36 -8033.40 5943685.93 550666.52 MWD+IFR-AK-CAZ-SC 10782.50 89.17 179.11 3176.10 3054.10 -2116.14 -8033.23 5943591.15 550667.42 MWD+IFR-AK-CAZ-SC 10878.06 88.13 180.42 3178.36 3056.36 -2211.67 -8032.84 5943495.64 550668.56 MWD+IFR-AK-CAZ-SC 10972.40 89.37 178.29 3180.41 3058.41 -2305.98 -8031.78 5943401.36 550670.36 MWD+IFR-AK-CAZ-SC 11068.30 89.24 177.24 3181.58 3059.58 -2401.79 -8028.04 594330S.58 550674.84 MWD+IFR-AK-CAZ-SG 11163.07 90.42 179.31 3181.86 3059.86 -2496.51 -8025.19 5943210.89 55~78.43 MWD+IFR-AK-CAZ-SC 11256.99 90.76 179.09 3180.89 3058.89 -2590.42 -8023.88 5943117.01 550680.48 MWD+IFR-AK-CAZ-SG 11354.61 91.19 176.89 3179.23 3057.23 -2687.96 -8020.45 5943019.51 550684.66 MWD+IFR-AK-CAZ-SC 11449.71 91.92 177.06 3176.65 3054.65 -2782.89 -8015.44 5942924.63 550690.41 MWD+IFR-AK-CAZ-SC 11544.65 93.38 176.80 3172.26 3050.26 -2877.59 -8010.36 5942829.98 550696.23 MWD+IFR-AK-CAZ-SG 11639.45 93.43 176.96 3166.63 3044.63 -2972.08 -$005.21 5942735.54 550702.12 MWD+IFR-AK-CAZ-SC 1173426 90.47 176.30 3163.40 3041.40 -3066.66 -7999.64 5942641.02 550708.42 MWD+IFR-AK-CAZ-SG 11829.50 90.82 175.66 3162.33 3040.33 -3161.66 -7992.96 5942546.08 550715.84 I MWD+IFR-AK-CAZ-S~ 11925.07 90.41 174.84 3161.31 3039.31 -3256.90 -7985.05 5942450.92 550724.49 MWD+IFR-AK-CAZ-SC • ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska 1nc. Date: 8/27/2007 Timec 11:21:37 Page: 4 Field: KuparUk RlVer Unit Co-ordinate(NE) Reference: Well: 1;J-162, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-162: 122_0 Well: 1J -162 Sec tion (VS)'Referencec Well {O.OON,O.OOE,180:OOAzi) Wellpath: 1J -162L1 Survey Calculati on Method< Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 12020.05 89.86 175.91 3161.08 3039.0$ -3351.57 -7977.39 5942356.32 550732.89 MWD+IFR-AK-CAZ-SC ~ 12116.36 88.87 175.19 3162.15 3040.'!5 -3447.58 -7969.92 5942260.38 550741.11 MWD+IFR-AK-CAZ-SC 12210.42 89.94 179.84 3163.13 3041.13 -3541.52 -7965.84 5942166.48 550745.92 MWD+IFR-AK-CAZ-SC 12304.97 90.39 179.62 3162.85 3040.85 -3636.07 -7965.39 5342071.95 550747.10 MWD+IFR-AK-CAZ-SC 12400.73 90.64 179.81 3161.99 3039.99 -3731.82 -7964.92 5941976.21 550748.32 MWD+IFR-AK-CAZ-SC 12492.70 89.67 179.96 3161.74 3039.74 -3823.79 -7964.73 5941884.26 55074922 MWD+IFR-AK-CAZ-SC 12590.31 90.92 179.85 3161.24 3039.24 -3921.40 -7964.57 5941786.66 550750.14 MWD+IFR-AK-CAZ-SC 12686.68 90.60 180.67 3159.96 3037.96 -4017.75 -7965.01 5941690.31 550750.46 MWD+IFR-AK-CAZ-SC 12780.85 90.29 178.61 3159.23 3037.23 -4111.91 -7964.42 5941596.17 550751.78 MWD+IFR-AK-CAZ-SC 12875.82 89.61 179.02 3159.31 3037.31 -4206.86 -7962.45 5941501.25 550754.49 MWD+IFR-AK-CAZ-SC 12967.03 90.14 179.03 3159.51 3037.51 -4298.06 -7960.90 5941410.08 550756.75 MWD+IFR-AK-CAZ-SC 13065.46 88.56 179.85 3160.63 3038.63 -4396.48 -7959.94 5941311.68 550758.4$ MWD+IFR-AK-CAZ-SC 13160.49 89.15 181.56 3162.53 3040.53 -4491.48 -7961.11 5941216.68 550758.05 MWD+IFR-AK-CAZ-SC ~ 13255.56 88.75 180J8 3164.27 3042.27 -4586.51 -7963.05 5941121.65 550756.85 MWD+IFR-AK-CAZ-SC 13349.95 91.25 182.98 3164.27 3042.27 -4680.83 -7966.15 5941027.31 550754.49 MWD+IFR-AK-CAZ-SC 13445.46 91.21 182.16 3162.22 3040.22 -4776.23 -7970.43 5940931.90 550750.95 MWD+IFR-AK-CAZ-SC 13540.82 91.21 180.23 3160.21 3038.21 -4871.54 -7972.42 5940836.58 550749.71 MWD+IFR-AK-CAZ-SC ~ 13635.54 91.21 176.74 3158.21 3036.21 -4966.19 -7969.91 5940741.96 550752.95 MWD+IFR-AK-CAZ-SC 13730.16 91.86 176.64 3155.67 3033.67 -5060.62 -7964.45 5940647.59 550759.14 MWD+IFR-AK-CAZ-SC 13826.11 92.60 177.31 3151.94 3029.94 -5156.36 -7959.39 5940551.90 550764.95 MWD+IFR-AK-CAZ-SC 13921.36 90.72 179.56 3149.18 3027.18 -5251:52 -7956.79 5940456.76 550768.29 MWD+IFR-AK-CAZ-SC 14015.50 90.47 179.83 3148.20 3026.20 -5345.66 -7956.29 5940362.65 550769.52 MWD+IFR-AK-CAZ-SC 14110.18 91.00 179.74 3146.99 3024.99 -5440.33 -7955.94 5940267.99 550770.62 MWD+IFR-AK-CAZ-SC 14204.62 90.41 179.33 3145.82 3023.82 -5534.76 -7955.17 5940173.58 550772.12 MWD+IFR-AK-CAZ-SC 14300.65 91.36 180.16 3144.34 3022.34 -5630.77 -7954.74 5940077.58 55077329 MWD+IFR-AK-CAZ-SC 14394.86 90.29 180.82 3142.99 3020.99 -5724.97 -7955.55 5939983.39 550773.22 MWD+IFR-AK-CAZ-SC 14461.92 89.05 180.77 3143.37 3021.37 -5792.02 -7956.48 5939916.34 550772.8~ MWD+IFR-AK-CAZ-SC I 14489.00 89.05 180.77 3143.82 3021.82 -5819.09 -7956.84 5939889.27 550772.66 PROJECTED to TD Y ~ ~ Halliburton Com an P Y Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/28/2007 Time: 09;24:56 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-162, True North Site: Kuparuk 1J Pad Vertical (TUD) Reference: 1J-162: 122:0 Well: 1J-162 Section(VS)Reference: Well(O.OON,O:OOE,180:OOAzi) Wellpath: 1J-162L1 PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 41.00 0.00 0.00 41.00 -81.00 0.00 0.00 5945769.63 558683.15 TIE LINE 100.00 0.45 234.36 100.00 -22.00 -0.14 -0.19 5945769.49 558682.96 CB-GYRO-SS 149.00 0.51 214.60 149.00 27.00 -0.43 -0.47 5945769.20 558682.68 CB-GYRO-SS 200.00 0.30 227.66 200.00 78.00 -0.70 -0.70 5945768.92 558682.46 CB-GYRO-SS 273.00 1.65 260.52 272.98 150.98 -1.01 -1.87 5945768.61 558681.28 CB-GYRO-SS 367.00 4.51 269.00 366.84 244.84 -1.29 -6.91 5945768.28 558676.26 CB-GYRO-SS 461.00 8.00 273.66 460.27 338.27 -0.94 -17.13 5945768.56 558666.03 CB-GYRO-SS 556.00 10.87 274.86 553.97 431.97 0.24 -32.66 5945769.62 558650.50 CB-GYRO-SS 651.00 13.23 278.48 646.87 524.87 2.60 -52.34 5945771.83 558630.80 CB-GYRO-SS 713.37 15.42 274.60 707.30 585.30 4.32 -67.66 5945773.42 558615.46 MWD+IFR-AK-CAZ-SC 780.65 17.90 271.82 771.75 649.75 5.37 -86.92 5945774.32 558596.20 MWD+IFR-AK-CAZ-SC 875.53 19.09 274.68 861.73 739J3 7.10 -116.96 5945775.81 558566.15 MWD+IFR-AK-CAZ-SC 971.53 23.62 270.59 951.12 829.12 8.58 -151.85 5945777.02 558531.25 MWD+IFR-AK-CAZ-SC 1065.93 27.76 267.98 1036.18 914.18 8.00 -192.75 5945776.12 558490.36 MWD+IFR-AK-CAZ-SC 1162.64 30.48 267.25 1120.65 998.65 6.02 -239.77 5945773.79 558443.36 MWD+IFR-AK-CAZ-SC 1256.73 35.19 267.65 1199.69 1077.69 3.77 -290.72 5945771.13 558392.93 MWD+IFR-AK-CAZ-SC 1351.53 36.44 269.48 1276.57 1154.57 2.39 -346.17 5945769.32 558337.00 MWD+IFR-AK-CAZ-SC 1446.88 38.52 270.63 1352.23 1230.23 2.46 -404.19 5945768.94 558278.99 MWD+IFR-AK-CAZ-SC 1542.11 41.52 271.90 1425.15 1303.15 3.83 -465.40 5945769.84 558217.78 MWD+IFR-AK-CAZ-SC 1637.24 46.26 271.68 1493.69 1371.69 5.89 -531.30 5945771.38 558151.87 MWD+IFR-AK-CAZ-SC 1732.33 49.51 271.47 1557.45 1435.45 7.82 -601.80 5945772.76 558081.36 MWD+IFR-AK-CAZ-SC 1827.63 54.06 271.76 1616.39 1494.39 9.94 -676.63 5945774.29 558006.53 MWD+IFR-AK-CAZ-SC 1920.91 57.06 272.59 1669.14 1547.14 12.87 -753.49 5945776.62 557929.65 MWD+IFR-AK-CAZ-SC 2015.25 59.56 272.77 1718.69 1596.69 16.62 -833.67 5945779.75 557849.45 MWD+IFR-AK-CAZ-SC 2113.84 62.11 271.22 1766.74 1644.74 19.60 -919.70 5945782.07 557763.41 MWD+IFR-AK-CAZ-SC 2207.83 64.87 271.31 1808.68 1686.68 21.46 -1003.78 5945783.27 557679.33 MWD+IFR-AK-CAZ-SC 2303.12 68.09 271.35 1846.71 1724.71 23.49 -1091.12 5945784.61 557591.99 MWD+IFR-AK-CAZ-SC Field: Kuparuk River Unit I North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-162 Slot Name: API 50-029-23360-00 Well Position: +N/-S -149.19 ft Northing: 5945769.63 ft Latitude: 70 15 44.790 N +E/-W -107.98 ft Easting : 558683.15 ft Longitude: 149 31 32.149 W Position Uncertainty: 0.00 ft Wellpath: 1J-162L1PB1 Drilled From: 1J-162P62 API 50-029-23360-72 Tie-on Depth: 9936.58 ft Current Datum: 1 J-162: Height 122.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/26/2007 Declination: 23.30 deg Field Strength: 57613 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 8/27/2007 Validated: Yes Version: 5 Actual From To Survey Toolcode Tool Name ft ft 100.00 651.00 1 J-162P61 Gyro (100.00-651.00) CB-GYRO-SS Camera based gyro single shot 713.37 3805.42 1J-162PB1 IIFR+MS+Sag (713.37- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3820.00 9936.58 1J-162P62 IIFR+MS+Sag (3820.00 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9954.00 10497.33 1J-162L1 PB1 IIFR+MS+Sag (9954. MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC • ! Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Date: 8/28/2007 Co-ordinate(NE) Reference: Time: 09:24:56 Page: 2 Well: 1J-162, True North Site: Kuparuk 1J Pad Vertical(TVD)Reference: 1J-162: t22.0 Well: 1J -162 Section (VS) Reference: Well (O.OON,O: OOE,180.OOAzi) Wellpath: 1J -162 L1PB1 Survey Calculati on Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft d eg deg ft ft ft ft ft ft I 2397.67 72 .20 270 .13 1878 .81 1756.81 24. 63 -1180.02 5945785 .06 557503.09 MWD+IFR-AK-CAZ-SC 2492.72 74 .15 269 .25 1906 .32 4784.32 24. 13 -1270.99 5945783 .85 557412.13 MWD+IFR-AK-CAZ-SC I 2588.87 75 .34 270 .26 1931 .62 1809.62 23. 74 -1363.75 5945782 .74 557319.38 MWD+IFR-AK-CAZ-SC 2683.19 76 .39 271 .85 1954 .66 1832.66 25. 42 -1455.20 5945783 .71 557227.94 MWD+IFR-AK-CAZ-SC 2778.52 75 .54 271 .47 1977 .78 1855.78 28. 10 -1547.64 5945785 .67 557135.49 MWD+IFR-AK-CAZ-SC 2872.79 78 .01 270 .17 1999 .34 1877.34 29. 41 -1639.39 5945786 .26 557043.74 MWD+IFR-AK-CAZ-SC 2968.90 77 .95 271 .18 2019 .36 1897.36 30. 52 -1733.39 5945786 .64 556949.74 MWD+IFR-AK-CAZ-SC 3064.56 76 .42 270 .50 2040 .58 1918.58 31. 89 -1826.65 5945787 .28 556856.48 MWD+IFR-AK-CAZ-SC 3159.86 77 .43 271 .73 2062 .14 1940.14 33. 70 -1919.46 5945788 .36 556763.67 MWD+IFR-AK-CAZ-SC 3253.23 75 .67 273 .78 2083 .85 1961.85 38. 05 -2010.16 5945792 .01 556672.95 MWD+IFR-AK-CAZ-SC 3349.74 74 .71 275 .05 2108 .52 1986.52 45. 23 -2103.18 5945798 .47 556579.88 MWD+IFR-AK-CAZ-SC 3443.93 76 .41 273 .80 2132 .01 2010.01 52. 27 -2194.12 5945804 .79 556488.90 MWD+IFR-AK-CAZ-SC 3540.57 77 .66 270 .39 2153 .70 2031.70 55. 70 -2288.21 5945807 .49 556394.79 MWD+IFR-AK-CAZ-SC 3635.13 79 .11 268 .74 2172 .74 2050.74 55. 00 -2380.83 5945806 .07 556302.19 MWD+IFR-AK-CAZ-SC 3707.38 79 .75 269. 81 2185 :99 2063.99 54. 10 -2451.85 5945804 .61 556231.19 MWD+IFR-AK-CAZ-SC 3805.42 78 .85 267 .67 2204 .20 2082.20 51. 98 -2548.15 5945801 .75 556134.92 MWD+IFR-AK-CAZ-SC 3820.00 78 .47 267. 53 2207 .06 2085.06 51. 38 -2562.43 5945801 .04 556120.64 MWD+IFR-AK-CAZ-SC 3858.15 79 .89 267. 79 2214 .23 2092.23 49. 85 -2599.87 5945799 .22 556083.22 MWD+IFR-AK-CAZ-SC 3953.80 79 .44 266. 37 2231 .39 2109.39 45. 06 -2693.85 5945793 .69 555989.29 MWD+IFR-AK-CAZ-SC 4034.80 79 .87 266. 75 2245 .93 2123_93 40. 28 -2773.39 5945788 .29 555909.80 MWD+IFR-AK-CAZ-SC 4143.86 79 .90 266. 60 2265 .09 2143.09 34. 05 -2880.57 5945781 .23 555802.68 MWD+IFR-AK-CAZ-SC 4236.17 77 .56 267. 10 2283 .12 2161.12 29. 08 -2970.96 5945775 .55 555712.34 MWD+IFR-AK-CAZ-SC 4333.04 79 .39 267. 52 2302 .48 2180.48 24. 62 3065.76 5945770 .36 555617.58 MWD+IFR-AK-CAZ-SC 4427.98 78 .93 269. 61 2320 .34 2198.34 22. 29 3168.98 5945767. 30 555524.40 MWD+IFR-AK-CAZ-SC 4523.16 78 .50 270. 05 2338 .96 2216.96 22. 01 -3252.31 5945766 .29 55543'i.08 MWD+IFR-AK-CAZ-SC 4617.91 79 .53 270. 85 2357 .02 2235_02 22. 74 -3345.32 5945766 .30 555338.07 MWD+IFR-AK-CAZ-SC 4713.53 80 .27 271. 44 2373 .78 2251.78 24. 62 -3439.44 5945767 .45 555243.95 MWD+IFR-AK-CAZ-SC 4808.18 80 .75 271. 61 2389 .39 2267_39 27. 11 -3532.76 5945769 20 555150.62 MWD+IFR-AK-CAZ-SC 4903.20 80 .98 271. 22 2404 .48 2282.48 29. 42 -3626.55 5945770. 79 555056.83 MWD+IFR-AK-CAZ-SC 4998.32 80 .51 270. 33 2419 .77 2297.77 30. 70 -3720.42 5945771. 33 554962.96 MWD+IFR-AK-CAZ-SC 5093.55 81 .40 270. 36 2434 .74 2312.74 31. 26 -3814.46 5945771. 16 554868.93 MWD+IFR-AK-CAZ-SC 5188.46 81 .74 270. 44 2448 .66 2326_66 31. 92 -3908.35 5945771. 09 5547a5.05 MWD+IFR-AK-CAZ-SC 5283.91 80 .28 269. 58 2463 .57 2341.57 31. 93 -4002.62 5945770. 37 5546$0.79 MWD+IFR-AK-CAZ-SC 5378.94 81 .82 270. 19 2478 .36 2356.36 31. 75 -4096.49 5945769. 45 554556.93 MWD+IFR-AK-CAZ-SC 5473.58 80 .92 270. 67 2492 .56 2370_56 32. 45 -4190.05 5945769. 42 554493.37 MWD+IFR-AK-CAZ-SC 5569.13 80 .17 268. 84 2508 .26 2386.26 32. 05 -4284.30 5945768. 29 554399.14 MWD+IFR-AK-CAZ-SC 5663.45 81 .15 268. 92 2523 .56 2401.56 30. 23 -4377.35 5945765. 74 5543Q6.12 MWD+IFR-AK-CAZ-SC 5759.60 80 .99 268. 63 2538 .49 2416_49 28. 20 -4472.31 5945762. 97 554211.18 MWD+IFR-AK-CAZ-SC 5854.41 80 .81 270. 25 2553 .48 243t_48 27. 28 -4565.92 5945761. 33 5541'i7.59 MWD+IFR-AK-CAZ-SC 5949.37 81 .78 271. 07 2567 .86 2445_86 28. 36 -4659.78 5945761. 68 554023.74 MWD+IFR-AK-CAZ-SC 6044.68 81 .12 271. 30 2582 .03 2460_03 30. 31 -4754.01 5945762. 89 553929.50 MWD+IFR-AK-CAZ-SC 6140.01 81 .04 272. 45 2596 .81 2474_81 33. 40 -4848.14 5945765. 24 553835.37 MWD+IFR-AK-CAZ-SC 6234J2 81 .42 271. 28 2611 .25 2489_25 36. 44 -4941.69 5945767. 56 5537~1.80 MWD+IFR-AK-CAZ-SC 6330.24 81 .87 270. 30 2625 .13 2503_13 37. 74 -5036.18 5945768. 12 553647.31 MWD+IFR-AK-CAZ-SC 6424.66 79 .86 269. 83 2640 .12 2518_12 37. 85 -5129.40 5945767. 50 553554.10 MWD+IFR-AK-CAZ-SC 6520.62 80 .57 269. 88 2656 .43 2534.43 37. 61 -5223.96 5945766. 53 553459.55 MWD+IFR-AK-CAZ-SC 6615.44 80 .79 269. 92 2671 .78 2543.78 37. 45 -5317.53 5945765. 63 553366.00 MWD+kFR-AK-CAZ-SC 6709.92 81 78 270. 34 2686 .10 2564_10 37. 66 -5410.92 5945765. 12 553272.62 MWD+IFR-AK-CAZ-SC 6805.97 82 .05 270. 29 2699 .61 2577.61 38. 18 -5506.01 5945764. 90 55317'7.54 MWD+IFR-AK-CAZ-SC 6901.06 81 .92 269. 80 2712 .87 2590_87 38. 26 -5600.17 5945764 .24 553083,39 MWD+IFR-AK-CAZ-SC 6995.88 80 .61 268. 52 2727 .27 2605_27 36. 88 -5693.88 5945762 .14 552989.70 MWD+IFR-AK-CAZ-SC 7090.82 79 .86 268 .10 2743 .37 2621.37 34. 13 -5787.40 5945758 .65 5528~5.21 MWD+IFR-AK-CAZ-SC 7186.20 81 .32 270 .64 2758 .96 2636_96 33. 10 -5881.48 5945756 .89 5528~.15 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Date: 8/28l2007 Co-ordinate(NE) Reference: Time: 09:24:56 Page: 3 Well: 1J-162, T~ue North Site: Kuparu k 1J Pad Vertical (TVD) Reference: 1J-162: 122.0 Well: 1J -162 Sec tion (VS) Reference: Well (O.OON,O.O OE,180.OOAzi) Welipath: 1J -162L1PB1 SurveyCalculationMethod: MinimumCurvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Toot ft deg deg ft ft ft R ft ft 7281 .60 80 .76 271. 27 2773. 82 2651. 82 34. 67 -5975. 70 5945757. 72 5527~7.93 MWD+IFR-AK-CAZ-SC 7376. 12 81 .45 271. 62 2788. 44 2666. 44 37. 02 -6069. 06 5945759. 35 552614.57 MWD+IFR-AK-CAZ-SC 7470. 95 81 .74 270. 88 2802. 30 2680. 30 39. 07 -6162. 85 5945760. 67 552520.78 MWD+IFR-AK-CAZ-SC 7517. 30 81 .29 270. 24 2809. 14 2687. 14 39. 52 -6208. 69 5945760. 76 552474.94 MWD+IFR-AK-CAZ-SC 7566. 28 81 .49 268. 04 2816. 47 2694. 47 38. 79 -6257. 10 5945759. 65 552426.53 MWD+IFR-AK-CAZ-SC 7661. 46 81 .30 263. 99 2830. 72 2708. 72 32. 25 -6350. 97 5945752. 38 552332.74 MWD+IFR-AK-CAZ-SC 7757. 51 81 .00 261. 99 2845. 50 2723. 50 20. 67 -6445. 16 5945740. 07 552238.65 MWD+IFR-AK-CAZ-SC 7852. 83 81 .43 259. 05 2860. 06 2738. 06 5. 15 -6538. 06 5945723. 83 552145.87 MWD+IFR-AK-CAZ-SC 7947. 35 81 .24 257. 52 2874. 30 2752. 3d -13. 82 -6629. 55 5945704. 15 552Q54.54 MWD+IFR-AK-CAZ-SC 8036. 06 80 .35 255. 09 2888. 49 2766. 49 -34. 55 -6714. 62 5945682. 76 551369.64 MWD+IFR-AK-CAZ-SC 8131. 09 80 .98 250. 28 2903. 91 2781. 91 -62. 45 -6804. 12 5945654. 17 551880.38 MWD+IFR-AK-CAZ-SC 8225. 86 80 .79 246. 51 2918. 93 2796. 93 -96. 90 -6$91. 10 5945619. 05 551793.68 MWD+IFR-AK-CAZ-SC 8320. 62 81 .53 244. 17 2933. 50 2811. 50 -135. 96 -6976. 19 5945579. 32 551708.90 MWD+IFR-AK-CAZ-SC 8416. 06 81 .73 243. 97 2947. 39 2825. 39 -177. 25 -7061. 11 5945537. 38 551fi24.32 MWD+IFR-AK-CAZ-SC 8511 .22 81 .72 244. 92 2961. 09 2839. 09 -217. 87 -7146. 06 5945496. 10 551539.69 MWD+IFR-AK-CAZ-SC 8606. 57 81 .91 243. 84 2974. 66 2852. 66 -258. 68 -7231. 16 5945454. 63 551454.92 MWD+IFR-AK-CAZ-SC 8700. 33 80 .79 240. 88 2988. 77 2866. 77 -301. 67 -7313. 27 5945411. 00 551373.16 MWD+IFR-AK-CAZ-SC 8797. 77 81 .66 236 J1 3003. 64 2881. 64 -351. 56 -7395. 61 5945360. 48 551291.21 MWD+IFR-AK-CAZ-SC 8891. 18 80 .47 233. 11 3018. 15 2896. 15 -404. 59 -7471. 10 5945306. 87 551216.14 MWD+IFR-AK-CAZ-SC 8986. 81 81 .29 229. 58 3033. 31 2911. 31 -463. 56 -7544. 82 5945247. 33 551142.89 MWD+IFR-AK-CAZ-SC 9082. 21 81 .97 225. 12 3047. 20 2925. 20 -527. 49 -7614. 22 5945182. 87 551074.00 MWD+IFR-AK-CAZ-SC 9176: 76 82 .41 220. 40 3060: 06 2938. 06 -596. 25 -7677. 80 5945113. 62 551010.97 MWD+IFR-AK-CAZ-SC 9271. 96 81 .66 216. 17 3073. 26 2951. 26 -670. 24 -7736. 20 5945039. 19 550953.15 MWD+IFR-AK-CAZ-SC 9366. 44 80 .60 211. 70 3087. 83 2965. 83 -747. 66 -7788. 31 5944961. 37 550901.66 MWD+IFR-AK-CAZ-SC 9461. 48 80 .35 206. 70 3103. 57 2981. 57 -829. 45 -7834. 02 5944879. 24 550856.59 MWD+IFR-AK-CAZ-SC 9556. 96 80 .60 202. 63 3119. 38 2997. 38 -915. 00 -7873. 30 5944793. 39 550$17.97 MWD+IFR-AK-CAZ-SC 9651. 96 80 .41 198. 47 3135 A5 3013. 05 -1002. 72 -7906. 19 5944705. 43 550785J8 MWD+IFR-AK-CAZ-SC 9746. 23 80 .78 194. 17 3150. 47 3028. 47 -1091. 95 -7932. 31 5944616. 00 550760.35 MWD+IFR-AK-CAZ-SC 9841. 65 80 .54 190. 19 3165. 96 3043. 96 -1183. 97 -7952. 18 5944523. 84 55~741.21 MWD+IFR-AK-CAZ-SC 9936. 58 81 .76 186. 37 3180. 57 3058. 57 -1276. 77 -7965. 68 5944430. 94 550728.43 MWD+IFR-AK-CAZ-SC 9954. 00 81 .77 186. 27 3183. 06 3061. 06 -1293. 91 -7967. 57 5944413. 80 550726.67 MWD+IFR-AK-CAZ-SC 10021. 45 84 .12 186. 78 3191. 35 3069. 35 -1360. 41 -7975. 18 5944347. 24 550719.58 MWD+IFR-AK-CAZ-SC 10116. 09 85 .48 187. 49 3199. 92 3077. 92 -1453. 93 -7986. 89 5944253. 65 550708.60 MWD+IFR-AK-CAZ-SC 10211. 80 87 .92 190. 73 3205. 43 3083. 43 -1548. 25 -8002. 02 5944159. 22 550694.21 MWD+IFR-AK-CAZ-SC 10305. 77 92 .81 190. 58 3204. 84 3082. 84 -1640. 57 -8019. 39 5944066. 77 550677.56 MWD+IFR-AK-CAZ-SC 10401. 82 93 .96 190. 83 3199. 16 3077. 16 -1734. 78 -8037. 20 5943972. 43 550660.49 MWD+IFR-AK-CAZ-SC 10497. 33 93 .93 189. 95 3192. 59 3070. 59 -1828. 51 -8054. 38 5943878. 59 550644.04 MWD+IFR-AK-CAZ-SC 10524. 00 93 .93 189. 95 3190. 77 3068. 77 -1854. 71 -8058. 98 5943852. 35 550639.65 PROJECTED to TD • ~ ` .. . . x:: .'fanieLo s q~.~ ~, .,. a,: '.~v~,}.,, rR+.-~'a ~..., ~£ , r, '. ~. : ~ r~~: ~, A~ ,~< ..~~.., . .... . ~ ~~,t, ~~. .. ~~. <. ~~,'~>,Ty.~'~ ...~ 1 ~. x~~ ~~s•, f _~2,~ ~ K ~ R'~ ~~~~..,.. ,x~~~~~,3~„ ~ ~~~..~~~~~_: 3~`Dai ~~~ . ..:From~~ To~. <`~.. ~ Dur'`~' '~5~ De th. E:: De ~fh :'Pliase ;~:Gode ~ `~Subc~de'~.,~ ~~'C~ » .>EOM~~ ~,~~~~...:;. ~'~ .~~; ~~~~ , , ~~ ~ ~ ~ 07/25/2007 20:00 20:30 0.50 0 0 COMPZ CASIN( RUNL T Make service breaks, inspect and lay down running tools. Toois indicated ro er shearin as er BOT rep. 20:30 22:45 2.25 0 398 PROD2 STK PULD P Clean & clear rig floor area of tools and OBM. Pull tools to rig floor. Held PJSM with crew, MWD, and BOT rep. Discuss safety & hazard recogniiton issues, discuss procedure to MU whipstock BHA. Make up 8 1/2" Whipstock BHA as per BOT rep, with double bumper'ars. 22:45 23:30 0.75 398 398 PROD2 STK PULD P Plug in and Upload MWD assembly. 23:30 00:00 0.50 398 398 PROD2 STK PULD P Make up remainng BHA picking up Flex drill collars and HWDP. 07/26/2007 00:00 00:15 0.25 398 398 PROD2 ST1C PULD P Continue MU Whipstock & milling assembl . 00:15 00:30 0.25 398 398 PROD2 STK CIRC P Perform shallow pulse test. Pumps at 550 GPM's - 900 PSI. 00:30 06:00 5.50 398 8,292 PROD2 STK TRIP P Trip in hole with whipstock assembly at running speed of 2 minutes / stand as per BOT rep. Observed proper displacement. Trip to 8292' MD. Crew Chan e 06:00 07:00 1.00 8,292 8,975 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 8292' - 5975' MD. MAke Top drive connection. Fill drill strin . 07:00 07:30 0.50 8,975 9,045 PROD2 STK OTHR P Perform MAD PASS log from 8975' - 9045' MD as per MWD rep. pumps at 665 GPM's - 3000 PSL 07:30 08:15 0.75 9,045 9,988 PROD2 STK TRIP P Continue trip in hole from 9045' - 9988' MD. Tag Top of liner at 10043' MO as planned. Obtain parameters. UP WT = 220K, SO WT = 125K. 08:15 09:00 0.75 9,988 10,043 PROD2 STK WPST P Orient whipstock face to 16 degress left of high side as per DD & Co. Man. Set BTA, pull 10K over upweight to verify set. Slack off and shear bolt at 35K. Pull to neutral position, rotate free with initial torque reading of 10K ft/Ibs. Top of whipstock at 9954' MD as lanned. 09:00 12:00 3.00 9,954 9,972 PROD2 STK WPST P Mill window from 9954' - 9972'. Pumps at 450 GPM's - 1750 PSI. TQ on - 12K. WOB = 2-5K. Sweep hole at bottom of slide. Average mill speed through casing = 6.15 ft/hr. TOW = 9954', BOW = 9970'. 12:00 16:15 4.25 9,972 10,006 PROD2 STK WPST P Continue mill through open hole from 9972' -10006'. Pumps at 450 GPM's - 1750 PSI. TQ on - 12K. WOB = 2-5K. Sweep hole at bottom of hole. Page 32 af 54 • ~ ~ ~ ~ i' ..ir-,^:~ s x ~:~ Time Lo~ ~ 'n4 '}. ~ k ~; ~.: ~ ~ ~ 9 1 _~ ~ ` a `t ~~`~~ li k ~s ~~~ ~ t., C , a .. ~~ .~ ` F ~ ~r _ tix't ~C ~, ~ ~ro- `-:°~i~ - Y~ i.~~ '~f L~; ~ ~~ '~ ,~ > ~ '=t"r" ~~~4.~ ~~mk.~~ ~~ m . 'i ' ~ ~~ x ~ ~~~k'a~~.A e 'G ~ date~~~°~ , . inC"2, ~°F.rom~ . ~. X ~To~~ai~ ~ .. b' X+ ~dur.~~ , ~ VC.f~ S~D"e th"~ ~„ . . T ~E~;De tit . . , . . , r.«A . „ . > +2' ' ~i'$ ~. .,Phase.<~ Code.~~~Suta~ade~ T. , , ., , ....n ~ tl~~ ~ ~~~~ ,~{eA~~'u` .~` @ rat 1'+.a ~.GOM'~;::~ ~°'~~;.,.. *.s`~~.,~~~. ~..~° 07/27/2007 12:00 12:30 0.50 9,950 9,950 PROD2 RIGMN' SVRG P Service top drive & draw works. 12:30 13:00 0.50 9,950 10,006 PROD2 DRILL REAM P Make Top drive connection. Begin wash & ream from 9985' - 10006' MD. observed no issues when going through whipstock face. Pumps at 550 GPM's -1750 PSI. 13:00 15:15 2.25 10,006 10,312 PROD2 DRILL DDRL P Directional drill 8 1!2" hole in the D lateral from 10006' - 10312' MD. TVD = ~ 3267'. ECD = 102 PPG. 15:15 15:30 0.25 10,312 10,312 PROD2 DRILL SRVY P Perform MAD PASS from 10266' - 10307' MD. 555 GPM's - 2350 PSI. 15:30 17:00 1.50 10,312 10,312 PROD2 DRILL REAM P Wash & ream hole for directional correction as per DD. 650 GPM's - 3000 PSI. 17:00 17:30 0.50 10,312 10,524 PROD2 DRILL DDRL P Directional drill 8 1!2" hole in the D laterat from 10312' - 10524' MD. TVD = 3252'. Total ADT = 2.09 HRS. ECD = 10.41 PPG. Observed difficulty in steering with surveys indicating out of zone. 17:30 18:00 0.50 10,524 9,954 PROD2 DRILL TRIP T Decision to POOH. POOH from 10524' - 9954' MD above window. No issues going back through tthe window area. Crew chan e 18:00 18:30 0.50 9,954 9,954 PROD2 DRILL OWFF T Monitor well - static. Pump dry job. Blow down To drive & lines. 18:30 21:30 3.00 9,954 350 PROD2 DRILL TRIP T Trip out of hole from 9954' - 350'. Observed ro er hole fill. 21:30 21:45 0.25 350 350 PROD2 DRILL PULD T Rack back HWDP, drilling jars & flex drill collars. 21:45 22:30 0.75 350 350 PROD2 DRILL OTHR T Pfug in and down ioad MWD assembl . Pre for bit chan e. 22:30 00:00 1.50 350 0 PROD2 DRILL PULD T Breakout & lay down BHA. Inspect & grade bit to 1/1/CT/A/X/I/NO/HP. Observed excessive cutting wear on MWD stabilizers. Obtain pictures. Lay down MWD. Remove battery & install in back u tool. 07/28/2007 00:00 00:30 0.50 0 0 PROD2 DRILL PULD T MU BHA # 13, with 8 1/2" Security FMF3643Z bit with a TFA of 1.66 sq. in. Change out Pulser in MWD assembl . 00:30 01:15 0.75 0 0 PROD2 DRILL OTHR T Plug in and downioad MWD assembl . 01:15 01:45 0.50 0 351 PROD2 DRILL PULD T Make up remaining BHA picking up HWDP, Drilling jars and Flex drill collars. 01:45 02:00 0.25 351 351 PROD2 DRILL CIRC T Make Top drive connection & Perform shallow ulse test. 02:00 05:15 3.25 351 9,861 PROD2 DRILL TRIP T Trip in hole with BHA #13 from 351' - 9861'. Observed proper displacement. Fill drill strin eve 25 stands. '~ Page 3~# af 5U~ ~~,' ~ • .Time,.Lo` s 'F r`z~;`~~~~.~a~. ,,,.t .z:.A. ~~~.~ ~~~>~~`~.~'`; ~~~~.~~~~~~•~~~`.,,. ~.~~,. ~~~s~~r~:A -03. .~,~{. ~~~1ate~°~~ S E y ' W 4Z .' '$p'N ,X ~S :. (~fl , Ero ~Tc~~ ~..~~~ Duk~~~ ~ „ S: D`e th "~ ~ : De th . 4 ~ ~.PYras~~ ..~YCode...~ J 4 `k'...d^' ;.~Sulico~'~:~"f~ ~ f~~L i3~ ~32 f ? t~i'"y~ # '. ~ ~ :. ¢Y ~sd~' EOM . _> ~ ~„ ~ . .~ ~ ~~ ~ ti ~.... ~ ~ ~~'"_~,~ ; 07/28/2007 05:15 06:00 0.75 9,861 9,861 PROD2 RIGMN' SVRG T Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to Slip & cut. Hang blocks, and slip & cut drilling line. Adjust brakes, and service top drive & draw works. Crew Chan e 06:00 08:00 2.00 9,861 9,861 PROD2 RIGMN SVRG T Continue slip & cut drilling line. Adjust brakes, and service top drive & draw works. Lubricate ri . 08:00 10:30 2.50 9,861 9,861 PROD2 RIGMN SVRG T Change out saver sub on top drive. Change out stabilizer bushings, and ad'ust clam s on bales. 10:30 11:00 0.50 9,861 10,000 PROD2 DRILL TRIP T Trip in hole from 9861' - 10000' MD. Make Top drive connection. UP WT = 195K, SO WT = 95K, ROT WT = 112K. Pumps at 610 GPM's - 2750 PSI. 100 RPM's with 8K TQ> 11:00 12:00 1.00 10,000 10,035 PROD2 DRILL DDRL T Perform OH sidetrack troughing from 1000' - 10035' MD. 12:00 17:15 5.25 10,035 10,035 PROD2 DRILL DDRL T Continue perform OH sidetrack from 10000' - 10035' MD. Observed kick off. 17:15 18:00 0.75 10,035 10,240 PROD2 DRILL DDRL T Directional drill 8 1/2" hole in the D lateral from 10035' - 10240' MD. ND = 3211'. ADT =.47 HRS, ECD = 10.0 PPG Crew Chan e 18:00 19:45 1.75 10,240 10,524 PROD2 DRILL DDRL T Directional drill 8 1/2" hole in the D lateral from 10240' -10524' MD. ND = 3193'. ECD = 10.25 PPG 19:45 00:00 4.25 10,524 10,961 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 10524' -10961' MD. ND = 3174'. ADT = 3.18 HRS, ECD = 10.42 PPG 07/29/2007 00:00 06:00 6.00 10,961 11,447 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 10961' - 11447' MD. ND = 3176'. ADT = 4.69 HRS, ECD = 10.87 PPG. Crew Chan e 06:00 12:00 6.00 11,447 12,237 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 19447' - 12237' MD. ND = 3165'. ADT = 376 HRS, ECD = 10.86 PPG 12:00 17:15 5.25 12,237 13,002 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 12237' - 13002' MD. ND = 3161'. ADT = 3.16 HRS, ECD = 11.30 PPG 17:15 18:00 0.75 13,002 13,002 PROD2 RIGMN' RGRP T Observed leak in shock hose from mud pump. No spills. Change out shock hose while reciprocate & rotate drill string utilizing secondary kill line hose for circulatin . Crew Chan e 18:00 20:15 2.25 13,002 13,002 PROD2 RIGMN RGRP T Continue change out shock hose while reciprocate & rotate drill string utilizing seconda kill line hose for circulatin . 20:15 20:45 0.50 13,002 13,002 PROD2 RIGMN' RGRP T Blow down Top drive & lines. Pressure test new shock hose to 4000 PSI. Good test. I Page 35 of SO' ?' • a . _~~ ~~~ ~~~ ~~ ~ ~ ~T~me~L~ ~~° ~ r ~ ..~. ~ ~k~~°~~~~~.~.'~~ ~ ~~,~~~u~~~ ~ t~~,~~~~ ~ - ~ , ~ ~ ~~ ~~ ,~~~ ~~~~~~~~..~.. ~,~ ~ ~ s ~.3~ ~ ~ , „~ ~. : ~w, ..y rf < ~` ~ `K'~'' .~.3 , ~ i P ~'z, < 5 ;~ ~ ~[~a~~ ~~'~~~ .,FromF ~ToR..x;. }°DuFS~~... S~De ~tN E':;De't1i Phase .:Ccsde~'°Sulicode~ «+ ::~ ~' ~~ t d ~. a': i ~ ~' "'~~.,- t~ ~~:COM ..~.; .~~':t ~ ...~~'.~..~~~,:~~r~..3 ~ ,~`~ 07/29/2007 20:45 00:00 3.25 13,002 13,378 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 13002' - 13378' MD. TVD = 3167'. ADT = 2.31 HRS, ECD = 10.81 PPG 07/30/2007 00:00 06:00 6.00 13,378 14,403 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 13378' - 14403' MD. ND = 3150'. ADT = 3.72 NRS, ECD = 11.18 PPG Crew Chan e 06:00 09:00 3.00 14,403 14,489 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 14403' - 14489' MD. TVD = 3143'. ADT = 1.78 HRS, ECD = 11.35 PPG. TD'd the lateral. 09:00 12:00 3.00 14,489 14,489 PROD2 DRILL CIRC P Circulate 40 BBL Hi Visc weighted sweep around while reciprocate & rotate drill string. Pumps @ 635 GPM's - 3260 PSI. Observed little increase in cuttings when sweep returned. Obtain slow pump rates. Monitor well - static. 12:00 18:00 6.00 14,489 11,030 PROD2 DRILL REAM P BROOH from 14489' - 11030' MD. Rotate @ 150 RPM's with 700 GPM's - 3100 PSI. Observed proper displacement. Obtain T&D parameters as er ri en ineer. Crew chan e 18:00 21:30 3.50 11,030 9,954 PROD2 DRILL REAM P Continue BROOH from 19030' - 9954' MD. Rotate @ 150 RPM's with 700 GPM's - 3100 PSI. Observed tight hole at bit depth of 10166'. Work through slowly rotating while pull through. No issues pulling assembly through whipstock face. Observed proper displacement. Obtain T&D arameters as er ri en ineer. 21:30 23:00 1.50 9,954 9,954 PROD2 DRILL CIRC P Circulate 40 BBL Hi Visc weighted sweep around plus 1 bottoms up while reciprocate & rotate drill string. Pumps @ 700 GPM's - 3260 PSI. Observed little increase in cuttings when sweep returned. Monitor well - static. 23:00 00:00 1.00 9,954 9,954 PROD2 DRILL TRIP P Perform short trip back in hole to 10623' MD verifying assembly able to stay in wellbore and not track back into Plug back well bore. POOH. Continue to observe issues with assembly getting in and out of 10166' MD. Suspect stabilizers hanging up on concretion at this de th. 07/31/2007 00:00 03:30 3.50 9,954 9,954 PROD2 DRILL CIRC P Circulate 40 BBL Hi Visc weighted sweep (10.2ppg/ 200 vis) around plus 4 bottoms up while reciprocate & rotate drili string 120 rpm's. Pumps @ 700 GPM's - 2970 PSI. Observed little increase in cuttings when sweep returned. Monitor well - static. Page 36 af Sp • . ~':t~mQ,LO~ ~~? ~~' ...~&~.,a. . , ,., ~.'"~'~.. .: . `p y~.,,.',-i'~'r ,'>,.u.i. /, r!f.t,:: . ..`," : 2. ~...~,. .a ? ~;~'t'2'~ecy.a ~`~ 3- ~ "~~ ~~'. f ~ ~NZ~c. , w..,r.,.=w: ~ ts ,.:~,.,... :a3~ :s.,~,,., , 2+ ar, p ~ F i 'r ~ t `~ `1t . : s - 5 ::" - +E, •'; S D ~ ° ~ ' ~ ' 'd D s ? , , a ~i~.' € 3 7 v ~ ~"` ~ v ~'^ ~ ``~'~ b ~. ` ~~?~ GOM~~~~` ;i' ~ ..?:Fro ~ •.Da e ~~ To _.<=~~Dur.. ~,.. S. ~ab e th.E e t t hase.. ~: Code -: co e, ?. t , s . Y. , . a , ,. . , z ~, „w;.~l G .. ~~.~^„ , r 07/31/2007 03:30 04:30 1.00 9,954 9,954 PROD2 RIGMN SVRG P Service top drive & draw works. Inspect saver sub. Service crown section. Inspect man rider sheave in crown. 04:30 06:00 1.50 9,954 10,812 PROD2 DRILL TRIP P Trip back in hole from 9954' - 10812'. 06:00 07:30 1.50 10,812 12,050 PROD2 DRILL REAM P Wash and ream in the hole. Pumping 3-5 b m. Rotate 30 r m. 07:30 09:00 1.50 12,050 12,050 PROD2 RIGMN' RGRP T Electricain trouble shooting the Varco TDS-8SA to drive electrical s stem. 09:00 10:45 1.75 12,050 9,862 PROD2 DRILL TRIP T Puli out of the hole on elevators. No excessive overpull while pulling throu h the window. 10:45 15:45 5.00 9,862 9,862 PROD2 RIGMN' RGRP T Electrician continues to troubleshoot the electrical s stem of the to drive. 15:45 17:00 1.25 9,862 8,150 PROD2 DRILL TRIP T Pull out of the hole on elevators. Plans to test BOPE with a 9-5/8" storm packer set in the 9-5/8" intermediate casin . 17:00 19:30 2.50 8,150 8,150 PROD2 RIGMN RGRP T Electrician continues to troubleshoot the electrical s stem of the to drive. 19:30 19:45 0.25 8,150 8,150 PROD2 DRILL OWFF T Monitorwell.OK. 19:45 20:00 0.25 8,150 8,150 PROD2 DRILL SFTY T PJSM on POOH. 20:00 20:15 025 8,150 8,055 PROD2 DRILL TRIP T POOH. Decide to lay down BHA #13, then test BOPE. 20:15 20:45 0.50 8,055 8,055 PROD2 DRILL CIRC T Pump a 20 bbis dry job for trip out. 20:45 00:00 3.25 8,055 636 PROD2 DRILL TRIP T POOH to UD BHA# 13. 08/01/2007 00:00 Q1:15 1.25 636 74 PROD2 DRILL TRIP T Continue to POOH to UD BHA # 13. 01:15 02:15 1.00 74 74 PROD2 DRILL OTHR T Download Sperry Sun MWD. 02:15 04:00 1.75 74 0 PROD2 DRILL PULD P Lay down BHA # 13. Calculated fill 107.83 bbis, actual 122.7 bbls. 04:00 04:30 0.50 0 0 PROD2 DRILL OTHR P Clean and clear floor. 04:30 05:45 1.25 0 0 PROD2 WELCT OTHR P Pull wear bushing. Install Vetco Gray test plug. RU to test BOPE. Fill stack with water I ~ Page 3T af 54' ~ ~ ~' t :'~'" .,f x ETmet ra s }~ ~a°' '~v w~ ~ ~ ~ ~ S' _ ~' ~ +~~ i~~~ `~`' . ~j ~ r . t ~ ~ ~~ ~ ~ "'' ~-i & m.~ :.:, :: ~ u' ~ ,a5~- r~ ~ : ~rrv 4 ~ ~ ~+ ~ ~-~~ , ~~~ ~~ ~: ~ ~~ ~ ~ ~~ ~ ~ . .~ '- *~ ~ `~, y*~~~' a~`.~5 ~ ~. ~ ~r#t "4 . %~"„,~' ~..,. ~ .~ ~,~ ~r~E . ~~~~w ~ w ~~~ ~° . _ `Dat~~`~~ ~..m. .: . r ~ ~Frorri~~ ;. ~Ta~'~` . . , . . . _ ~Dur~'~~S,~F]e`~~th~ . u r., ~, , .. ~,. ~e ~, a . r, , . a ~ , _ E~~;De t}i~Phase~Mb=~Code`~~Subcode. T. . , .~.. .. . ... «~. . ~`CO~II*11~~~~~~u~ . ~;~~~~~~ ~:~~ .~ 08/01/2007 05:45 13:00 7.25 0 0 PROD2 WELCT BOPE P Test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Accumulator test: Starting w/ 3000 psi, after closing 1500 psi. 200 psi build up in 45 seconds. Full charge in 3 min. 21 seconds. Five Nitrogen bottles avg 2250 psi. Test Annular to 250 psi low and 3000 psi high w/ a 4-1/2" test joint. Test upper pipe rams (3-1/2" x 6" variable rams) w/ 4-1/2" and 5". Test to 250 psi low and 3000 psi high. Hold each test f/ 5 min. Test top drive manual and automatic IBOP to 250 psi low and 3000 psi high. Test floor safety vlaves to 250 psi and 3000 psi. Test choke manifold valves, kiil line valves and choke line valves to 250 psi low and 3000 psi high. Hold all tests f/ 5 min. Test H2S and methane as alarms. All tests assed. 13:00 13:45 0.75 0 0 PROD2 DRILL OTHR P Doyon employee meeting with the Do on Board of directors. 13:45 15:15 1.50 0 0 PROD2 WELC7 OTHR P Rig down test equipment. Pull test lu . Install wear bushin . 15:15 15:45 0.50 0 0 PROD2 DRILL OTHR T Clean and clear rig floor. 15:45 16:45 1.00 0 0 PROD2 DRILL PULD T Make up BHA # 14 (8-1/2" hole o ener). 16:45 18:00 1.25 0 5,050 PROD2 DRILL TRIP T Trip in the hole. Fill pipe every 25 stands. Record PU and SO wYs. 18:00 19:00 1.00 5,050 5,050 PROD2 DRILL SFTY P Install floor safety valve, secure well (close annular). Hold a safety standup meeting with both crews in the welding shop. 19:00 19:15 0.25 5,050 5,050 PROD2 DRILL SFTY P PJSM on opening up the well after bein secured. 19:15 19:45 0.50 5,050 5,050 PROD2 DRILL OTHR P Open annular, well is static. Remove floor safety valve. Blow down choke manifold. 19:45 00:00 4.25 5,050 9,895 PROD2 DRILL TRIP T Continue trip in the hole w/ BHA #14. Record PU and SO wt's every 10 stands. Fill pi e eve 25 stands. 08/02/2007 00:00 04:00 4.00 9,895 9,895 PROD2 DRILL CIRC T Establish circulation. Stage pumps up to 900 gpm w/ 3420 psi. Recip 60' stroke, up fast, down slow. Before circ: PU 190, SO 80k. After circ: PU 185k, SO 102k. Cire surf to surface then 7 more BU. Initial MW 8.6 ppg, final MW 8.4 Pag~ 38 af 50 ~ ~ ,.~~m~.LQ 5~,~ .", .~.:, a~. t a".1 +~+e , a., ~ `'•., '"~ ~: ~ \..c ~~`F~ t`.~.t ^~:.','~.~ . _ *:-we.a .. <., .~. t.:. "''>~. ~ ~ : .r n'~~,~;,i.d»*'.~_'..'~k ~'~ ,~^~.~w?~~ ,~?, .~ °a~~;'?? ~ ~~Y'~i~&S ~., :+~ ~ .,.'~~ ~ , ~,~ . ,`~`' .rf'~a ,l„~f ,~dA4".YSt~~~ r _ ~ ~;~ ~ a ~ '" Date ; x: . . Frorri. To .. ~ ~~ ~ ~ ,~ ~ ~ Dtlr~ ~. . 4 5. D"e th ~:= De th ., ~ ~~x ~ ~,: sr~,r, ~ ~~~ ~A~ ~~~~ ~~~ .Phase ~.~:~:Code ~.~~~.Subcode~<T~~:, COM `~..~ ~`~ur . ~~~ 08/02/2007 04:00 06:00 2.00 9,895 9,895 PROD2 RIGMN' WOEQ T Continue to wait on parts to fix the Varco TDS-8SA top drive. Monitor well on the trip tank. Loss of 1.5 bbls in 2 hrs. While waiting on parts: Grease crown, PM on the Hook, change valves and seats in # 1 mud pump. cleaning cattle chute, cleaning rig floor. 06:00 18:00 12.00 9,895 9,895 PROD2 RIGMN WOEQ T Continue to wait on parts to fix the Varco TDS-8SA top drive. Monitor well on the trip tank. Loss of 12 bbls in 12 hrs. While waiting on parts: remove electrical service loop from top drive. Cleanin ri floor windwalls. 18:00 21:00 3.00 9,895 9,895 PROD2 RIGMN WOEQ T Continue to wait on parts to fix the Varco TDS-8SA top drive. Monitor well on the trip tank. While waiting on parts: Electricians trouble shooting the variable frequency contoller for the top drive. Cleaning rig floor, cleaning roof of the pipe shed. Inspect the drawworks: Brake pads, rollers, automatic driller, crown o matic. 21:00 00:00 3.00 9,895 9,895 PROD2 RIGMN RGRP T Electrical service loop for the Varco TDS-8SA top drive arrived. Uncrate same, electricians prepare and install ends. Monitor well on the trip tank. Total fluid lost in the last 6 hrs = 1.5 bbls. 08/03/2007 00:00 00:30 0.50 9,895 9,895 PROD2 RIGMN' RGRP T Prepare and install ends to the electrical service loop for the top drive.. Monitor well on the tri tank. 00:30 00:45 0.25 9,895 9,895 PROD2 RIGMN SFTY T PJSM on bringing service loop to the floor and han in it in the derrick. 00:45 06:00 5.25 9,895 9,895 PROD2 RIGMN RGRP T Hang the electrical service loop in the derrick. Prepare to be attatched to the top drive and junction box in the derrick. Cleaning around the rig. Work on PM's. Hole lost 3 bbls over iast 6 hrs. 06:00 12:00 6.00 9,895 9,895 PROD2 RIGMN' RGRP T Continue to work on the Varco TDS-8SA top drive. 12:00 18:00 6.00 9,895 9,895 PROD2 RIGMN RGRP T Electricians continue to work on the Varco TDS-8SA top drive. Circulate two bottom's up @ 1700 hrs. Pumping 500 gpm w/ 1240 psi. Lost a total of 2.5 bblsfor the last 12 hours. 18:00 22:00 4.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning on the rig while waiting on service tech's to arrive. Arranging for arts to arrive as well. PBge 39. of SU ' ~ . °~T~rne.Lo s ~'Date,~~-~:~~~From~ > ~ ~ . ~ .,To~.~;~~' I~ut~~.~,S.~~De th~E.ADe tli=Phase...~ H <, F z,~~~~~ ~~?~~, ~~~,f~~,~~'~r ' `:~~~,~~ ~~ ¢:Code "°~Sut~cb~d~"`4xl'~ .COM~~~~. ~ :, ~~::;~.`°~r,'~€: ~ 08/03/2007 22:00 00:00 2.00 9,895 9,895 PROD2 DRILL SFTY P RLG rep Capt. Kirk-- giving a workshop with the rig crew on the book written by Captain D. Michael Abrashoff. Book's name It's Your Ship. Note: Zero bbls of mud lost f/ the last 6 hours. 08/04/2007 00:00 06:00 6.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig_while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 06:00 12:00 6.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 12:00 18:00 6.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 18:00 21:00 3.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 21:00 23:45 2.75 9,895 9,895 PROD2 RIGMN WOEQ T Circulate 4 BU (18100 strokes). Pum in 725 m w/ 2360 si. 23:45 00:00 0.25 9,895 9,895 PROD2 RIGMN' WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA top drive. 08/05/2007 00:00 10:00 10.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 10:00 11:30 1.50 9,895 9,595 PROD2 RIGMN' WOEQ P RLG rep Capt. Kirk-- giving a workshop with the rig crew on the book written by Captain D. Michael Abrashoff. Book's name It's Your Shi . 11:30 17:30 6.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA top drive. Rig electricians and Varco rep's working to check out Inverter bay of Top drive house. 17:30 20:30 3.00 9,895 9,895 PROD2 RIGMN' WOEQ T Circulate 4 BU (19400 strokes). Pum in 725 m w/ 2360 psi. 20:30 00:00 3.50 9,895 9,895 PROD2 RIGMN' WOEQ T Cleaning and painting on the rig while waiting for parts and service technician to arrive and help to fix the Varco TDS-8SA top drive. Note: Total of 3.5 bbls of fluid lost to the hole for the da . 08/06/2007 00:00 06:00 6.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service technician to arrive and help to fix the Varco TDS-8SA to drive. Page ~0 af 50 ' . ~ ~ 7r~iie`" Loj' s ~ ~ ~ ~ ~ ~~ ,t rK~;; ? ~ ' rr k~~. t • ' ~~~ ~~.~ ~,.~ ~ ~ ~~~ ~ ~ ~ ~~; ~ ".~`~:~~~'~ ~K,, : ~ 2f~~~, ~ ~ . ~~ rDate.~;~.~..~ ,:From'~`To,,,~;;..~,Dur'~ .rS.~De th..E:De~th'~f?hase~•~~:''Coii~..~~$Subcode~ x'1"~k,~COM. ~"~~a~~-`,~. ~~r"J~ ;~~~~`~~~`~a 08/06/2007 06:00 12:00 6.00 9,895 9,895 PROD2 RIGMN' WOEQ T Cieaning and painting on the rig while waiting for parts and service technician to arrive and help to fix the Varco TDS-8SA top drive. Perform a derrick ins ection. 12:00 18:00 6.00 9,895 9,895 PROD2 RIGMN RGRP T Cleaning and painting on the rig while service technician's help to fix the Varco TDS-8SA top drive. Off of hiline @ 1430 hrs. Work on connecting service loo to the to drive. 18:00 18:30 0.50 9,895 9,895 PROD2 RIGMN' RGRP T Service technician's helping to fix the Varco TDS-8SA top drive. Circulate bottom's up. Pumping 700 gpm w/ 2210 si. PU wt 190k, SO wt 100k. 18:30 19:30 1.00 9,895 9,895 PROD2 RIGMN RGRP T Break the top drive off of the drill string usin ton s and chain ton . 19:30 20:30 1.00 9,895 9,895 PROD2 RIGMN RGRP T Run and function top drive, monitoring Variable fre uenc control house. 20:30 21:00 0.50 9,895 9,895 PROD2 RIGMN' RGRP T Finish putting all pieces in place. Top drive a ears to be read to run. 21:00 21:15 025 9,895 9,895 PROD2 RIGMN RGRP T Screw into drill string. Pump and rotate top drive. While letting out the torque of 10k ft Ibs, a capacitor in the control house failed. 21:15 00:00 2.75 9,895 9,895 PROD2 RIGMN' RGRP T Start to re --trouble shoot problems with the top drive controi nouse. Kig crew working on projects: change out shaker screens on scalper shakers f/ next well, inspect mud cleaner, inspect collar clam . 08/07/2007 00:00 03:30 3.50 9,895 9,895 PROD2 RIGMN' RGRP T Start to re --trouble shoot problems with the top drive contro! house. Rig crew working on projects: change out shaker screens on scalper shakers f/ next well, inspect mud cleaner, ins ect collar clam . 03:30 06:00 2.50 9,895 9,895 PROD2 RIGMN' RGRP T Parts installed and checked out. Will _ __ - - --- - check with Siemens and Varco this morning as a conference call to further identi an roblems. 06:00 08:00 2.00 9,895 9,895 PROD2 RIGMN RGRP T Checking with Siemens and Varco to trouble shoot the Varco Top drive s stem. 08:00 17:00 9.00 9,895 9,895 PROD2 RIGMN RGRP T Start testing of Variable control unit and to drive. 17:00 19:15 2.25 9,895 9,895 PROD2 RIGMN' RGRP T Noticed a part in the top drive control , house emmitting sparks. Found problem to be in the computer control module?? 19:15 20:45 1.50 9,895 9,895 PROD2 RIGMN' RGRP T Circulate two bottom's up. Pumping 700 gpm w/ 2190 psi. Checked and found that the computer control unit in ri 141's controls will work. 20:45 21:00 0.25 9,895 PROD2 RIGMN RGRP T Obtain SPR's. Then line up on the trip tank to monitor the well. I : Page 41 of 5U ' ' . • -;Trrie Lo s ~ .?F t'v ~' ,Y . ,~., ..~~, ~ f 'Y~ i ' ,v . ,;~! k ~ n u £ ~ ~ .~s,~ : .el. ~~~ ~ '~ "~ ,.~ ~ ~~ b ~,. ~ k3.~~ Z~ '~ #~ .~"~~S ~~~,~~~. ~,~, E~,~. ~~.:~~~ Dat~=~~~: : Frorri~~`Ta~ ~~ ~. Dur~'~~~;5: De th~. E:?De tli~Phase~~~`.`C~ode~~~ ~Suiicode. .=T~' ~COM.~~~~~~.`~~~ `:° ~~.,.;..~..~~~ ~r `'~ ~ 08/07/2007 21:00 23:00 2.00 9,895 9,895 PROD2 DRILL SFTY P Swap some parts and install controi module in the control house. RLG rep Capt. Kirk-- giving a workshop with the rig crew on the book written by Captain D. Michael Abrashoff. Book's name IYs Your Shi . 23:00 00:00 1.00 9,895 9,895 PROD2 RIGMN' RGRP T Continue installing the computer control unit in the top drive control house. Note: Zero mud lost to the hole toda . 08/08/2007 00:00 01:00 1.00 9,895 9,895 PROD2 RIGMN' RGRP T Continue installing the computer control unit in the top drive control house. 01:00 02:00 1.00 9,895 9,895 PROD2 RIGMN RGRP T Function testing top drive. 02:00 03:30 1.50 9,895 9,895 PROD2 RIGMN' RGRP T Screw top drive into the drill string. Function testing. Rotating 70 rpm w/ 8-12k ft Ibs of torque. Pumping 148 gpm w/ 240 psi. Recip pipe. All appears to be good. Monitoring top drive control house. 03:30 03:45 0.25 9,895 9,895 PROD2 RIGMN SFTY T PJSM on RIH/ Ream in the hole. 03:45 04:15 0.50 9,895 9,895 PROD2 RIGMN RGRP T Unscrew top drive f/ the drill string. Run Top drive up through the derrick to check how service loop runs w/ Kelly hose. Adjust traveling hardware. OK. Note: No ain or loss f/ last 6 hrs. 04:15 05:00 0.75 9,895 10,690 PROD2 DRILL TRIP T RIH. Record PU and SO wt's every 5 stands. Ran out of down wt. 05:00 06:15 1.25 10,690 11,230 PROD2 DRILL REAM T Ream in the hole. Pumping 148 gpm w/ 280 psi, 26% flow. Rotate 30 rpm w/ 10k ft Ibs of tor ue. 06:15 07:00 0.75 11,230 11,421 PROD2 DRILL REAM T Ream in the hole. Pumping 700 gpm w/ 2450 psi, 37% flow. Rotate 30 rpm w/ 10-12k ft Ibs of torque. 07:00 08:15 1.25 11,421 12,050 PROD2 DRILL REAM T Ream in the hole. Pumping 700 gpm w/ 2490 psi, 37% flow. Rotate 120 rpm w/ 12-15k ft Ibs of tor ue. 08:15 14:15 6.00 12,050 14,489 PROD2 DRILL REAM P Continue to ream in the hole. Pumping 700 gpm w/ 2490-3050 psi, 37% flow. Rotate 120 rpm w/ 10-12k ft Ibs of torque. Note: Hole took 25 bbls while runnin /reamin in the hole. 14:15 16:15 2.00 14,489 14,489 PROD2 DRILL CIRC P Displace f/ 8.4+ ppg MOBM to 8.4 ppg SFOBM, Pumping 500 gpm w/ 1740 psi. Rotate 70 rpm w/ 1740 psi. PU wt 225k, SO wt : none, rot wt 125k. 16:15 16:30 0.25 14,489 14,489 PROD2 DRILL OWFF P Monitor well, instaU stripping rubbers. Page 4~ af fU~`' • ~ ~ . ~ . ~ ~ i • z ~ T~me. Lo s ~ " : ° .. :~, , , ,>.,,.. . ~~ t5. . . .4 ~ x. ~ , ~..,_; y. 4 ." , ., "~~.~~~ ~~ , ~~~ ~'~~.m ~.>~~"~'~~~ Date. _ ~~Ftom.,~cTa~.S;'~tDur.z~.~~:5: De th E;.De th~Phase~~~.iCode~; Subcode'~ ~.~~.:;COM,.~,sk ~"~~..x ,? 7,~~ ~.~:`.. ~~~~~:° 08/13/2007 04:15 05:15 1.00 377 2,663 COMPZ CASIN( RUNL P Trip in the hole w/ the Hook Hanger on 5" drill pipe. Record PU and SO wYs eve 10 stands. 05:15 06:15 1.00 2,663 2,663 COMPZ CASINC OTHR P Shallow test MWD. 110 gpm w/ 550 si. 06:15 12:30 6.25 2,663 10,218 COMPZ CASINC RUNL P Continue RIH w/ Hook hanger on 5" drill pipe. Oriented 4-1/2" bent joint to exit the window while @ 9930'. Exit the window @ 9954' -9970'.Record PU and SO wYs every 10 stands, fill pipe every 25 stands. Running speed 120 ft/min. 12:30 14:00 1.50 10,218 10,226 COMPZ CASIN( OTHR P Run stand # 105, PU a single and establish circulation w/ 112 gpm w/ 700 psi. PU wt 240k, SO wt 100k. Orient to 52 deg right, slack off and hook window and set 20k on hook hanger. PU and orient the hook to exit the window, slack off to 10234' (8 1/2' past the window) ( did not ~ocate), PU and orient to hook window, Slack off and set 25k on hook. Final MWD when hooked is 27 ri ht. 14:00 15:15 1.25 10,226 10,027 COMPZ CASIN( CIRC P Drop a 3/4" ball to release and inflate the ECP. Pump down @ 2.5 bpm w/ 630 psi for 1000 strokes, then reduce rate to 2 bpm w/ 450 psi. Ball on seat w/ 1591 strokes. Pressure to 1100 psi (1700 psi w/ 1594 strokes, 2000 psi w/ 1596 strokes, 2170 psi w/ 1597 strokes, 2400 psi w/ 1599 strokes. Began to inflate packer @ 2530 psi. Pressure was 3020 psi w/ 1603 strokes. Bleed off pressure, POOH 2 sfands to clear inner string from the hook hanger. Note: Lost 10 bbls of fluid to the formation on tri in the hole. 15:15 15:30 0.25 10,027 10,027 COMPZ CASINC OTHR P Monitor well. Static. 15:30 15:45 0.25 10,027 10,027 COMPZ CASIN( SFTY P PJSM f/ POOH laying down drill pipe. Monitor well on the tri tank. 15:45 18:00 2.25 10,027 9,203 COMPZ CASINC RUNL P Drop the Haggard Mud Dog ID wiper inside of the drill pipe. POOH w/ Hook Hanger running tool, laying down 5" HWDP and 5" drill pipe. Monitor well on the tri tank. 18:00 00:00 6.00 9,203 3,711 COMPZ CASIN( RUNL P Continue to POOH w/ Hook Hanger running tool, laying down 5" drill pipe. Monitor well on the trip tank. Note: Lost 10 bbls of mud to the formation as of midni ht on the ti out. 08/14/2007 00:00 04:45 4.75 3,711 110 COMPZ CASIN( RUNL P Continue to POOH w/ Hook Hanger running tools, laying down 5" drill pipe. Monitor well on the tri tank. Page 47 of 5p ' ! ~ ~ ~ :nTime Lo~` s~`~" ` " ~ ~, s ' ~ ~ r~ ~~ ,._ . „ 'Date.~..~~~,,,From~~To},y,..`Dur=°=..~S:~De th...E~-De fh~Phase...'='Code~.. -:, ~ .`, ~` ~S~ubcode~ ~ ~~ ~T.;, ~~~~'~5~, kz .~ ~ ~~~. ,<~~.~~~~ s; ~~ ~ A~~. COM .~=~~~~`~,~~~.~~~ .~~. T."':~~~~' ~~ti' 08/14/2007 23:00 23:30 0.50 0 0 COMPZ RPCOti RCST P Rig up test equipment. Pump down tubing to pressure to 1000 PSI - 15 minutes. Observed 40 PSI bleed. Good test. Rig down test equipment & lines. 23:30 00:00 0.50 0 0 COMPZ RPCOh RCST P WLIH & pull test plug. Set tubing stop. WLOH rig down Halliburton slickline unit. 08/15/2007 00:00 01:45 1.75 0 0 COMPZ RPCOh RCST P Make up Unique discharge sub. Pull 2 joints of tubing, and intake with installed pump & rack back in derrick. Make up Centrilift Motor assembly, fill with oil & check rotation. Make up A well pump sensor & centralizer as per Centrilift re & Weatherford re . 01:45 02:15 0.50 0 0 COMPZ RPCOti RCST P Rig up Centrilift sheave & hang off ESP cable. 02:15 05:00 2.75 0 0 COMPZ RPCOti RCST P Make up stainless steel control line & ESP cable. Attach & perform continuity tests. Install cable gaurds on motorassembly. Used 11 SS bands, 1 Cannon Clam . 05:00 06:00 1.00 0 310 COMPZ RPCOti RCST P Run 4 1/2" Tbg insta!ling Can~on clamps on each collar to 310'. Observed proper displacement in hole. Crew chan e 06:00 12:00 6.00 310 4,421 COMPZ RPCOh RCST P Continue run 4 1/2" tbg installing Cannon Clamp on each collar from 310' - 4421'. Perform continuity test every 35 joints ran. Record T& D parameters as per rig engineer. Observed proper displacement. Make u tor ue = 3000 ft/Ibs 12:00 17:30 5.50 4,421 7,440 COMPZ RPCOti RCST P Continue run 4 1/2" tbg installing Cannon Clamp on each collar from 4421' - 7440. Perform continuity test every 35 joints ran. Record T& D parameters as per rig engineer. Observed proper displacement. Make u torque = 3000 ft/Ibs 17:30 18:00 0.50 7,440 7,480 COMPZ RPCOh RCST P Make up tubing hanger with landing joint. Tubing hanger made up with loaded BPV. Crew Chan e 18:00 22:30 4.50 7,480 7,480 COMPZ RPCOti RCST P Rig up and perform ESP cable splice to penetrator in tubing hanger. Rig down ESP cable & sheave. Rig down GBR tubing running equipment. Clean floor of tools and OBM. Perform continui test on splice. Good test. 22:30 23:15 0.75 7,480 7,480 COMPZ RPCOti RCST P Drain BOP stack. Blow down choke & kill lines. Blow down mud pumps. Clamp off ESP cable & perform continuity test on top side of enetrator, ood test. Page 49 of 5Q = ~ ~ .' , y, /~;~. ~Time.L' g Y ,~, ''' i ~ ~^ ~r ~;. 7 ~ ~ . - S Iy,, i ~4 ! i , ~ "X ~ C.. ~ ~ ~~: "i : d 1 „`kU 4 ~k 0,r "~3+b ~ . ~ Y -j~ 4 ~ ~~ ~~'jat ,~~..r1o~~§P . .~..«.,.c~`K, n...~F ~ ~6 ,..~ _r.~si, .b . ,., f.,, , .~ . ,:, ri.~3ffi'+.`a.~9ewr,..`, v~`efi..M.~~~. ~S . ~Date~~`~;~.~ ~From~ Ta~"`~~ Dur~~~~S. De~'th' ~Ei~De"th'~f?hase" :Code~£'<,.Sulie`ode~ ~'F~~`CdM.~°.V:,. w~. ~'~'~_ . ~~,~~~~ 08/15l2007 23:15 00:00 0.75 7,480 7,512 COMPZ RPCOh RCST P Continue RIH to land tubingh hanger on depth at 7512' MD. Verify properly landed as per Vetco Gray rep. RILDS. UP WT = 135K, SO WT = 78K. 08/16/2007 00:00 00:45 0.75 7,512 7,512 COMPZ RPCOh OTHR P Continue RILDS. Rig up and test upper & lower packoff seal in hanger to 5000 PSI - 10 minutes each. Good test. Bleed pressure. Pull and lay down landin 'oint. 00:45 05:00 4.25 0 0 COMPZ WELCT NUND P Nipple down BOP stack & lines. Rig down Choke & kill lines. Install Moving braces in pipe shed. Continue cleaning pits. Clean drip pan under rig floor. Move 20 stands of DP over to drillers side of ri floor for ri move. 05:00 06:00 1.00 0 0 COMPZ WELC7 NUND P Nipple up Tree as per Vetco Gray rep. Make up production valves. Continue cleaning pits. Disconnect flow line to complex. Disconnect manifold lines to com lex. Crew Chan e 06:00 07:00 1.00 0 0 COMPZ WELC7 NUND P Continue nipple up tree. pressure test void to 5000 PSI. Good test. Close all valves & secure tree. 07:00 10:15 3.25 0 0 COMPZ MOVE DMOB P Continue with demobing rig disconnecting lines in between complexes. Disconnect & move rockwasher. Ri down Handi-berms. 10:15 11:00 0.75 0 0 COMPZ MOVE DMOB P Tilt Beaver slide into moving position. Prep rig floor for skid. Lift work latform. 11:00 12:00 1.00 0 COMPZ MOVE DMOB P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuus skidding floor & rig move. Skid rig floor into moving position. Rig released @ 1100 hrs. Note: Set up returns tanks, portable choke manifold, and rigged up lines with Little Red Services to freeze protect 1 J-162 out of the critical path. Pumped a total of 550 BBLS of freeze protect diesel at 1 BPM - 500 PSI observing a 41 BBL loss to the formation. A BPV was not installed as per wells group. Shut in pressures = IA -340 PSI, OA - 140 PSI. All o erations took place on 8/17/07 Page 5D af 50 ; Daily Operations Summary Report 1 J-162 Job: DRILLING ORIGINAL ~ - - __ - 6 28/2007 6/29/2007 Demob from Summer maintenance. Move ng to 1J-162 Rig up ~3~ ~° ~ y, , ~ ~3QiZ0U~ '`~~~~~ ~' P~ck u~ ~" D S~UDP Load~ ~tsvvit3~ spu~i~ nr~~d R1~ Gyr~"un~t MC'T`BJ~~ , ~ ~. .~ ~ , . ~ ~* ~.., .~ .....~.~~~ _... .. .. , , _u.... ~ . ~,,.~ ~'.~3~.... ,,,A~~... ~~.~~, __ 6/30/2007 7/1/2007 Continue MU spud BHA. Spud well @ 0150 HRS. Continue Directional Drill 16" Surface hole to 252' POOH, MU BHA. RIH, Continue drill to 1415' MD. 1328' ND hole as pianned to 346~' MD. TVD = 2131'. Trough hole for excessive doglegs. BROOH f/ 833' to 643', blow down top drive, POOH on elevators f/ 643' to 73', UD BHA @1, clean floor, RU to run 13-3/8" surface sasing, run 13-3/8" casing to 3832', try to work deeper while circulating, POOH 2 jts, install centralizers on jt 88 & 89, RIH, MU hanger, land casing, RU dowell cementing head, circulate while holding PJSM on cementing casing. PU drill pipe and stand back 5 stands of 5" dp w/ swper sliders in the derrick, PU/MU/ standback 13 stands slic 5" dp, then 5 stands of 5" HWDP, remove mousehole, RU to test BOPE, test, R/D, install wear bushing, clear fioor, PJSM, PU/MU BHA #2, upload, con't PU/MU BHA #2, PU/MU/RIH w/ 5" dp to 2360' fiil pipe, circ, shallow tesf MWD, con't PU/MU/RfH w/ 5" dp to 2360' fill pipe, con't R[H to tag @ 3717', circ BU, UD single, RU to test casin9: , - _ 007 ~ Directional drill 12-1/4" f/ 4~58' to 6310', monitor well, short t~ip 5 stands to 57,92', RIH, continue dtilling to 6481'. j 7/10/2007 7/11/2007 ~Obtain SPR's, BROOM f/ 7999` to 3785' (shoe @ 3820'), pump Hi-vis hi-weight sweep to surface + BU, monrtor I well, pull 2 stands, monitor well, pump dry job, POOM, UD Ghost reamer, con't FOOH, work BHA, PU/MU BHA I #~; RIH to 1785', shallow test mwd, continuE RIH to 2235', pipe stopped„ RU 75k-over, slack off, inspectdrilling ~ line, pull free w/ 97k over pull d~agging up hole, UD single, change saver sub ; 7/12/2007 7/1312007 ~MU BHA #5 (12-1/4" hole opener), RIH to 5621', circ; continue RIH to 7991'; pump a sweep-Circ, POOH to 7300', ; pump a dry job, POOH to 3815', pump a sweep-circ, POOH to 3408', pump,a sweep-circ, pump a dry job, POOH ' w/ hole opener, PU~MU/start in the hole w/ Baker impression block an-d HOWCO 13-3/8" RTTS to test the casing ~ an 3407.64'. i ~7/14/2007 7/15/2007 ~Continue CBU Q 5350', RIH to 6216', PU to 6165', Ream to 6261', RIH to 7460', Ream 7400' to 7500', RIH to ~ ~ 7878', Precautionary ream to TD @ 7999', Drill 12-1/4" intermediate hole to 8256', acquire Cassandra survey's, ~ drill to 9300', replace Pressure relief on #1 mp, drill to 9773'. BROOH f/ 7685' to 3880', pull to 3785', pump a 40 bbls hi vis/ high wt sweep, circ, BROOH to 3310', pump a weighted! hi vis sweep, circ, pump a 6% steel lube pill, spot in the casing, displace w/ dry job, slip and cut driiling line, POOH, UD BHA #8, clear floor of toois. 7l19/2007 ~Circulate & condition mud. Load shed with 38 joints of 10 3/4" casing. Continue run 9 5/8" x 10 3/4" casing, ar ~perform 797 BBL cementjob. Did not bump plug. Nipple down BOP's & set emergency slips. i Page 1/3 Report Printed: 9/13/2007; Daily Operations Summary Report 1 J-162 9/2007 17/21/2007 /30/2007 7/31 /2007 . I 8/1 /2007 I I ~ i Job: DRILLING ORIGINAL ,~i~ „.hpiE,., ~,~: u, , , E ... ~'a ~~.~LasR2kfirSum ,..~;._ _~:'.. ~.,..~~.._,.~a .E,.,,~d~.~€€i: et emergency slips & packoff. Test same. NU BOP"S. test BOP"S. Flush OA with water. MU BHA. Directional Drill D MD. ND = 3167'. on rig. to 1 Gomplete circulating 5 bottoms up above the window,c~'il 9954'. Trip back to 10812', washing & r~aming in hole f/ 10812' to 12050', trouble shoot Varco TDS-8SA Top drive. POOH on elevators to 9862'. Continue to troubleshoot the top drive. POOH to 8150'. Continue to work on the top drive. Pump 20 bbl dry job. POOH to test BOFE (14 day test). Nete: Stili working to fix the Varco TDS-8SA top drive. Locating electfiieal parts from Varca Clrculate @ 900 gpm w/ 3420 psi. recip 60': Circulate surtace to surface + 7 BU's. Waiting on parts for the Varco ~ TDS-8SA top dr-ive (capacitocs & electrical service loop). Troubie shooting the top drive adjustable freqwency controllee Prepare and install ends on the new alECtrical service loop. Cleaning on the rig. Gleaning and painting on the rig. Change the liners in both mud pumps to 6-1/2". Circ 4 BU @ 725 gprn w/ Z360 I psi. Preparations are being made fOr service tech's a~d parts to a~rive to fiix top drive. j ~ Cleaning and painting on the rig. Preparations were made for servici: tech's and parts to arrive to fix top d~ive. Function tested top drive on auto checkout, ok. While rotating pipe and then using fhe torque ~elease batton to let the torque out of the string, a capacitor failed in the inverter section of#he top drive house. Re trouble shooting. Install another capacitor. Electricians continue to repair Varco top drive house, function test top drive, RIH f/ 9895' to 10690', ream in the hole f/ 10690' to 14489 ; displace to SFOBM, monitor well, POOH on elevators to 290'. L~y duwn BHA #1~,~ E~ F~i~~r ~~~2 '€}~ i~`~ a~ItneG ~s `t~8~~b~anKs}, RIH ~~ ~"~dr~ll f~fpe~ os~~EOn [€ner art~,~p}~~ " ~f1Q~~ '~~4 ~ .~ ~~ F~t, ~1~~$~) T~~~'~S~ 1!lIB~' PC.~~~~'~~~}YT~IFf~IFtC~ tCf£11~ ` ' a ~ !~~ , ..,..... .. ~ ~ ~:~ .,r.a , „ ,,,,,..~r .~ >'~z`~ ~~ . ...~.., e _........~: .s, . . ` .. ,. ~~ ~~~~.'~~..~., ...,,~`~-...a , x»c..:. , ~v~..-~.r.~:.~~2a~. z . , ,. 8/11 /2007 ! Page 2/3 Report Printed: 9/13l2007I - --- ~ Daily Operations Summary Report 1J-162 , I i i ~ 1 ; ; - --- - - -- i Page 3/3 Report Printed: 9l13l2d07~ ,~ ~ ~ Slofted and Blank LinerDetail weu: 1~-~s2I.1 ConocoPhillips 4-~~2" 11.6# L-80 BTC Date: 8/9(2007 a~as~,ma "p"Iat2C8II~ @I' Rig: Doyonl5 DEPTH Jt Number Num of Jts COMPLETE DES QUIPMENT RUN OD(in) nominal Max OD(in) actual ID(in) actual LENGTH TOPS ireserveGj:: (reserveiij: ~reservsdj jreservedj:: [reserveii]: [fBSeried] < ; "D" Lateral Liner was dropped 215' oUt ill Opeil hole. ;reserved~ : ireservedj. (ceservedi < : < 10972.79 Drill pipe needed 10172.71 Baker Liner setting,tool 5 6.12 372 12.46 10172.71 HR Liner Setting Sleeve w/ 6' TBR 7.U0" ~ a:2s s.2a 8.63 10185.17 XO Sub 7" HYD 521 X 5-1l2" Hyd 521 { 7,05" OD x 4.91"IQ) 7 7.05 4.91 1.02 10193.80 Receptacle Jt 5.5" 15.5# L80 5.5" Hdy 521 ( 5.73" OD xiD 4.91 ") 5.5 5.73 4.99 41 J4 10194.82 XO Sub 5.5''H d 521 X 4.5"BTC (5.73"OD X 3.97" ID) 5.5 5:7s s.s~ 1.45 10236.56 ,its sa to sa ~ ~ts 4-1/2+' BTC w/TQ Rings 11.6 ppf, L~80 Slotted Casing a.s 5 a 42.91 10238.01 ~ts s3 to s~ s Jts 4-1/2" BTC w/TQ Rings 11.6 ppf, L-80 (5 Btanks) a.e 5 a 214.97 10280.92 ~ts ss to s2 s Jts 4-1/2" BTC w/TQ Rings 11.6 ppfi; L-80 Slo~ted Casin a.5 5 a 20774 10495.89 ~ts sa to s7 a ~ts 4-172" BTC w/TQ Rings 11.6 ppf, L-80 (4 Blanks) d:s s a 168.19 10703.63 Jts 56 to 83 28 Jts 4-`f/2" BTC w/TQ Rings 11.6 ppf, L-80 Slotted Casing a.s 5 a 1200.18 10871.82 Jts 1 to 55 55 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing a.s s a 2359.77 12072.00 4-172", 11.6 ppf, L-80, BTC Blank Casing(5.0" OD x 4" ID 4:5 5 4 43.16 14431.77 ROT Silver BulletGuide Shoe ( No float) (5.02" OD) a.s s:o2 a i.67 14474.93 Bttm of Shoe =_> 14476.60 14476.60 Note; Top "D" Lat. window 9,954' MD/ ~,183' ND 14476.6b Bttm of window 9,970' MD / 3,183` TVD 14476.60 Window , 81.77 Deg. ` 14476.60 14476.60 Top ofB lat liner top packer 10,043.55' MD 14476.60 3,19.5' ND 84:3 deg 14476.60 14476.60 B Liner XO sub ID 4.95" 10,080.75' MD 1.4476.60 3,197' TVD 84.4 deg 14476.60 14476.60 TD 8-1/2" hole 14,489' MD / 3,143' TVD 14476.60 4-1/2'' Shoe 14,476.60' MD % 3,143' ND / 89.05 De 14476.60 12.40' 14476.60 144Z6.60 Run 98 hydroforms (80590- 3 rib) 9 Hydroform per jt. 14476.60 on joints #1 thru Jts #98. No stops were run. 44476.60 Run torque rings in the top 43 jts of the BTC-M liner. T4476.60 Jts # 56 thru Jt# 98= 1,833.99' 14476.60 Run Slots: 89 jts BTC = 3810.60'. Run Blanks: 9 jts BTC = 383.16' + shoejt 44.83', U Wt 100K liner onl , TD 260k Slots are 0.125" wide x 2.5" long x 32 slo/ft. w/ (32) 2.5" long x.125" @ 4 Dfl Wf 95K liner onl , TD no down wt Circumferential adjacent rows; 3" Centers staggered 18 tleg. 3' non-slotted ends. BIOCk W1 70K Torqued BTC liner w!o torque rings to 2800 ft-Ibs, w/ torque rings to 5000 ft-Ibs. Used Run-N-Seal thread compountl on all connections. All drifted w/ 3.875" rabbit. Superviso~s: Fred Herbert / Granville Rizek ~ ~ 30-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-162L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,936.58' MD Window / Kickoff Survey 9,954.00' MD (if applicable) Projected Survey: 10,524.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date I o~~~ Signed U~/ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~-- ~ ~ ~ ~ i 30-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-162L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,935.58' MD Window / Kickoff Survey 9,954.00' MD (if applicable) Projected Survey: 14,489.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ao~-o~~ 1J-162 PB3 ~ Page 1 of 1 ~ Maunder, Thomas E (DOA) _ -------- ~ From: Reiity, Patrick J [Patrick.J.Reilty@conocophillips.com] Sent: Wednesday, August 01, 2007 1:18 PM To: Maunder, Thomas E (DOA) Subject: 1 J- 3 ~~o ~-- L~ ~~~~~ Attachments: Patrick.J.Reitly@conocophitfips.com.vcf ~ ~~ Tom, ~f~~"r ~ The detaifs of the sidetrack are as foltows: • Well: 1J-162 . Rig: Doyon 15 • Date: 7/28/07 • Time: 1100 hrs • Last Casing: D Lateral Window ~ 9,972' • MD of abandoned section: 10,035' -10,524' ~-~~ ~- ~~~ ~ ~ ~~ ~ We decided to sidetrack because directional control problems eaused us to drop betow the gc~od pay sand and we were also off of our desired azimuth. We made a low side sidetrack. We are ptanning to isolate the sidetrack by allowing it to callapse. If you need any additional information please contact me. Pat Reifly ConocoPhil{ips Alaska Driiiing & Welts (907) 265-6048 WORK (907) 244-5558 CELLULAR (918} 662-8284 FAX TO E-MAIL Patrick. J. Reil ly@conocoph iltips. com «Patrick.J. Reilly@conocophillips.com.vch> 8/1/2007 ~ ~ ~ ~ Q Q O SARAH PALIN, GOVERNOR ~s~a-7~ Dasl ~`~ ~a7 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA7`I011T COMI-IISSIOIQ ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 Randy Thomas F~c ~so~~ 2~sasa2 Drilling Team Leader ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-162L 1 ConocoPhillips Alaska Inc. Permit No: 207-081 Surface Location: 1958' FSL, 2527' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1612' FSL, 87' FWL, SEC. 3, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well 1J-162, Permit No 207-080, API 50-029-23360-00. Production should continue to be reported as a function of the original API number stated above. 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 in (pager). DATED this ~~ day of June, 20U7 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~~IVED ~ ~ ~ .JUN 4 6 2007 ~Ia~ q~! ~ Gas Cans. Commission Anchorage 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ~ Multiple Zone^ Single Zone ~ 1c. SpeciTy if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 1J-162L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14255' ' ND: 314T ~ 12. Field/P001(sJ: Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1958' FSL, 2527' FEL, Sec, 35, T11N, R10E, UM ~ 7. Property Designation: ADL 25661, 25660, 25663~ West Sak Oil Pool , Top of Productive Horizon: 592' FSL, 64' FWL, Sec. 34, T11 N, R10E, UM 8. Land Use Permit: ALK 471, 470, 472 13. Approximate Spud Date: 7!9/2007 Total Depth: 1612' FSL, 87' FWL, Sec. 3, T10N, R10E, UM j 9. Acres in Property: 2560 14. Distance to ~~ pt~ {p /~~.L~ tM1 Nearest Pr erty: ,Q bc~W~1 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558683 ~ y- 5945769 ~ Zone- 4 10. KB Elevation (Height above GL): 121' AMSL' feet 15. Distance to Nearest Well within Pool: none , 16. Deviated wells: Kickoff depth: ggg~ . ft. Maximum HoleAngle: g2° deg 17. Maximum Anticipated Pressures in psig (see 2o aaC 25.oa5) i,~, ~~~ r Downhole: 1329 psig Surface: ~1~~psig ~(, 18. Casing Program if ti S Setting Depth Quantity of Cement Size peC iCa ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD 7VD MD ND (including stage data) 40" 20" 62.5# H-40 Welded 80' 40' 40' 120' 120' 360 sx AS 1 16" 13-3/8" 68# L-80 BTC 4572' 40' 40' 4612' 2303' 770 sx AS Lite, 220 sx DeepCRETE 12.25" 10.75" 73.2# L-80 BTCM 3405' 40' 40' 3445' 2105' 690 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 7000' 3445' 2105' 10445' 3251' see above 8.5" 4.5" 11.6# L-80 BTC CSG 4263' 9991' 3186' 14254' 3146' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Voiume Ntp ND Conductor/Structural SurFace Intermediate Production Liner Perforation Depth MD (ft): ~, r~/~ ~,i 1 Perforation Depth ND (ft): 20. Attachments: Filing Fee `' BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Q Property Plat ~ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. ~ hereby certify that the foregoing is true and correct to the best of my knowledge. ContBCt Pat Reilly @ 265-6048 Printed Name Randy Thomas Titie Drilling Team Leader Signature i`~ l Phone ~ f`6 a~~ Date (~~S ~O~ ~` haron All D k Commission Use Only Permit to Drill Number: ,Z,,,D? ~v~ ~ API Number: 50- ~ ~- ,~, ~ J~ "~ Permit Approval Date: . (3" a~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to expiore for, test, or produce coalbed, ~m,e/thane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No LJ ud log req'd: Yes ^ No Q' Other: 30~Q ~~` 2~ C-~ ~~` H2S measures: Yes ~ No I svy req'd: Yes ~ No ^ U.3 \ ~T APPROVED BY THE COMMISSION DATE: ~~/ ~D~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~^~ . -~ Submit in Duplicate "..~ t~€'~.,.e° G t~ t4 s 1 i..~. ~D ~' 7' ~l ~~ ~ Appli~ for Permit to Drill, Well 1 J-162 L1 Revision No.O Saved: 4-Jun-07 Permit It - West Sak Well #1J-162L1 Application for Permit to Drill Document Table of Contents 1. Well Name .................................................................................................................. 2 9 .f ~ ............................................................................................................. Re uirements o 20 AAC 25. 005 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 25.050(b) ............................................................................................................. 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.005(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25. 005 (c)(4) ........................................................................................................ 3 5. Procedure for Conducting Formation Integrity Tests .................................................. 3 Requirements of 20 AAC 25. 005 (c)(S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.005(c)(8) .......................................................................:................................. 4 g ~ ) ............................................................................... Lateral Mud Pro ram MI VersaPro Mineral Oil Base 4 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 5 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25. 005 (c) (10) ...................................................................................................... 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25. 005 (c)(11) ...................................................................................................... 5 12. Evidence of Bonding ................................................................................................... 5 1J-162 L1 PERMIT /T Page 1 of 6 Pnnted: 4-Jun-07 ~~~~~~~L ~ Appli~ for Permit to Drill, Well 1 J-162 L1 Revision No.O Saved: 4-Jun-07 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25. 005 (c)(13) ...................................................................................................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 6 Requirements of 20 AAC 25. 005 (c)(14) ...................................................................................................... 6 15. Attachments ............................................................................................................... 6 Attachment 1 Directional Plan .................................................................................................................. 6 Attachment 2 Drilling Hazards Summary ................................................................................................... 6 Attachment 3 Well Schematic .................................................................................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each irell must be ident~ed by a:~nique name designa~ed by the operator and a unique API number assigned by the co»vnisszon under 20 AAC 25.040(b). For a well i~~ith multiple i~~ell branches, each branch must similar7y be ident~ed by a unrque name and API number by addi~zg a suffrz to the name designated for the well by the operator and to the nun2ber assigned to tlie icell by the commission. The well for which this Application is submitted will be designated as 1J-162 L1. 2. Location Summary Requirements of 20 AAC 25.005(c) (2) An application for a Permit fo Drill nzust be accompa~aied by each of the folloia~ing iten~s, except for an item already on frle il~ith t&e commission and identrfied in the ap~licatio~a: (2) a plat ident~ing the property and the properry's owners and shoiring (AJt1~e coordinates of the proposed locatio~~ of the i~~ell at the su~face, at tlae top of each objective formation, and at total depth, refereiaced to governniental secfion li~zes. (B) the coordinates of the proposed locatiorz of tlie ti~~ell at the surface, referenced to the state plane coordinate system for thas state as maintazned by tHe ~~ational Geodetic Su~vey in the National Oceanic and AtntosphericAdministration; (C) the pr•oposed depth of the ~vell at the top of each objective formcztion and at total depth; Location at Surface 1958' FSL, 2526' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB El2vation 121' AMSL Northings: 5,945,769 Eastings: 558,683 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 592' FSL, 64' FWL, Section 34, T11N, R10E Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 9,991 Northings: 5,944,346 Eastings: 550,727 Total Vertical Depth, RKB: 3,186 Total Vertical Depth, SS: 3,065 Location at Total De th 1612' FSL, 87' FWL, Section 3, T10N, R10E ASP Zone 4 NAD 27 Coordinates MeasuNed Depth, RKB: 14,255 Northings: 5,940,086 Eastings: 550,787 Total Vertical De th, RKB: 3,147 Total Vertical Depth, SS: 3,025 and (D) other infamatio~a required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be inte~~tionally deviated, the application for a Permit to Drill (Fo~•m 10-401) niust 1J-162 L1 PERMIT IT Page 2 of 6 Printed: 4-Jun-07 ''~' i i ~ ~~~d~~ L ~ Appli~ for Permit to Drill, Well 1 J-162 L1 Revision No.O Saved: 4-Jun-07 (I) include a plat, draivn to a suitable scale, showing the path of the proposed wellbore, including all adjaceizt ivellbores ~~ithiia 200 feet of any portion of tlae proposed ivell; Please see Attachment 1: Directional Plan and (2) for all wells x~ithii~ 200 feet of the proposed ti~~ellbore (A) list the names of the operators of tJzose ia~ells, to the extent t1~at those ~aames are knotia~n o~• discoverable in publdc records, and show that each rramed operator has been furnished a copy of tlae application by certifred ~mail; or (BJ state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c) (3) An applicafiion for a Permit to Drill must be accorrapanied by each of the following items, except for an iten: already on file with the commission med ident~ed in the application: (3) a dragram and description of the blowout preventlorr equiprnent (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 2~.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-162. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. If required, 10 3/4" and 9 5/8" rams will be installed while running the tapered intermediate string. 4. Drilling Hazards Information Requirements of 20 AAC 25. 005 (c)(4) An application for a Perinit to Drill must be acconzpanied by each of the folloiving items, except for an item already on file ~vith the co~nmission and ident~ed in the application: (4) info~matiorr orr drilling ha~ards, includi~ag (A) the maximum doi+~nhole pressure that ~nay be encountered, crite~•ia used to determine it, and maximum poteratial surface pressure based on a methane gradie~at; ~ The expected reservoir pressure in the West Sak sands in the 1J-162 L1 is 0.44 psi/ft, or 8.4 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) Based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,056 PSI, calculated as follows: The MPSP is: MPSP = (3,021 ft)(0.44 - 0.11 psi/ft) 3 ``~~ <~`-t`-~- ,1,~~ = 1~ ~~' ~~~~~~ =1,056 psi (B) data on potential gas _ones; The well bore is not expected to penetrate any gas zones. And (C) data concerning poter~tial causes of hole proble~ns such as abnor~nally geo pressured strata, lost circu/ation _ones, and ~ones that have a propensity for d~erential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) A~a applicatiora for a Permit to D~~ill must be accompanied by each of the following items, except for an item already on file with the commission and ident~ed i~a the applicatiorz: ~ (S) a descriptio~z of the procedure for conductingformatio~a integrity tests, as reguired under 20 AAC 25.030(fl; No formation integrity test will be performed in the drilling of 1J-162 L1 ~~~~~~`~~~~,.~~ 1J-162 L1 PERMIT IT Page 3 of 6 Printed: 4-Jun-07 ~ Appli~ for Permit to Drill, Well 1 J-162 L1 Revision No.O Saved: 4-Jun-07 6. Casing and Cementing Program Requirements of 20 AAC 25. 005(c) (6) An application for a Permit to Drill must be accompanied by each of the follrncing iterns, exceptfor an item already on file with the commissioia and ident:fied in the application: (6) a cornplete proposed casing and cemer~ting prograrn as required by 20.4AC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed; Casing and Cementing Program See alcn Attachment 3: Cement SummarV Hole - - - ---- - - - Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) ([b/ft) Grade Connection (ft) (ft) t) Cement Program 2Q" 40" 62.5 H-40 Welded 80 40' / 40' 120' / 120' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 4,572 40' / 40' 4,612' / 2,303' 770 sx ArcticSet Lite Lead, 220 sx Dee CRETE Tail 10-3/4" 12-1/4" 73.2 L-80 BTCM 3,405 40' / 40' 3,445' / 2,105' Top oftapered 10 3/4" x 9 5/8" See 9 5/8" Program in next row Cement Top planned @ 6,600' 9-5/8" 12-1/4" 40 L-80 BTCM 7,000 3,445' / 2,105' 10,445' / 3,251' MD / 2,640' TVD. Cemented w/ 690 sx DeepCRETE 5-1/2 8-1/2" B Sand Lateral 15.5 L-80 BTCM 4,167 10,091 / 3,251' 14,258' / 3,218' Slotted-no cement _ sl (17-162) 4-1/2 8-1/2" D Sand Lateral 11.6 L-80 BTC CSG 4,263 9,991' / 3,186' 14,254' / 3,146' Slotted-no cement slotted (1J-162L1> 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application fo~~ a Permit to Drill must be accompanied by each of d~e fol/oi+ ing iterns, except for an item already oiz file ivith the conamisszon and ident~ed ri~ the applreation: (7) a diagrmn ar~d description of the diverter systern as required by ?0 AAC 2~. 03.i, u~zless tbis requirerne~~t is u-aived by the conunission under 20 ~lAC 25. 035(h) (2); No diverter system will be used during operations on 1J-162 L1 8. Drilling Fluid Program Requirements of 20 AAC 25.OOS(c)(8) An applicatiorr for a Pernzit to Drill must be accompanied by each of the foDoiring items, except for an item ab•eady on f le with the con7missioia and identrfied in the a~plication: (8) a drilling fluidprogram, includirig a diagranz arrd description of the drilli~~gfluid s~~stem, as required by 20 AAC 2~.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Densi (pp~ 9.0 Plastic Viscostiy 15-25 (Ib/100 s~ Yield Point 1 g_2g (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 1 SO° / 1J-162 L1 PERMIT IT Page 4 of 6 ~ ("~ ~ ~ ~ ~~~ ~~ ~ Printed: 4-Jun-07 f~ ~ Oil / Water Ratio 80:20 Electrical >600 Stability Appli~ for Permit to Drill, Well 1J-162 L1 Revision No.O Saved: 4-Jun-07 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25. 005 (c)(9) An application for a Permit to Drill must be accompanied by each of the follrn+~ing items, except for an item already on fzle with the commission and idenzifi~ed in the application: (9) for a~~ ezploratory or stratia aphic test ivell, a tabzdation setting out the depths of predicted abnornsally geo pressured strata as required by 20 AAC 25. 033 ~; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(1 D) An application for a Permit to Drill niust be accompanied by each of the folloi~~ing items, except for an itenz already on file ~rith the commission a~ad ident~ed in the application: ~ (10J fo~~ an exploratory or sb~atigraphic test ~+~ell, a seisnaic refi~action or reflectioi~ analysis as required by 20 AAC 2~.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Di~ill must be accompanied by each of the folloi~~ing items, exceptfor an i~errc already on file ia~itlz tTie conzmission and identified in the applicadon: (11) for a ivell drilled fi~om an offshore platform, ~nobile bottom founded sn-ucture, jack-up rig, o~• floating d~~illing vessel, arr analysis of seabed conditions as required by 20 AAC 2~.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applicafion for a Permit to Drill must be accompai~ied by each of the folloa4~ing items, except for an item already on fi7e wit]z the commission and identified in the application: (12) evider~ce shoiring that tlie requirements of 20 AAC 25.025 {Bo~adi»g}have been rnet; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25. 005 (c)(13) An applicatiorr for a Permit to Drill nn~rst be accompanied by each of the following items, ezcept for an item already on file ivith the commissioia and identrfied in the applicatiort: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. Note: Previous operations are covered under the 1 J-162 Application for Permit to DrilL~ 1. Run and set Baker WindowMaster whipstock system, at window point of 9,991' MD / 3,186' TVD, the top of the "D" sand. 2. Mi118-1/2" window. POOH. 3. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 14,254' MD / 3,146' TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 1J-162 L1 PERMIT IT Page 5 of 6 Printed: 4-Jun-07 ~~~r~~~~~ ~ , e ~ 9. Release hanger running tool. POOH. 10. POOH, laying down drill pipe as required. 11. PU ESP completion as required and RIH to depth. Land tubing. Set BPV. Appli~ for Permit to Drill, Well 1 J-162 L1 Revision No.O Saved: 4-Jun-07 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 13. Freeze protect well with diesel by pumping into 4-1/2" x(10-3/4" x 9-5/8" tapered) annulus, taking returns from tubing and allowing to equalize. 14. Set BPV and move rig off. 15. Rig up wire line unit. Pull BPV. 16. Flowback well with ESP to cleanup. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the follo~ving items, exceptfor an ite~n already on file with the commission ai~d idenXified i~~ the applicafio~~: ~ (I4) u generad descriptio~~ of hoiv the operator plans to dispose of drilling mud and cutti~vgs and a statement of ivhefiher the operator inte~ads to r~equest authori=ation under 20 AAC 25.080 for arr annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a ~ permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal ~ operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-162 L1 PERMIT IT Page 6 of 6 Printed: 4-Jun-07 ~~~~~~~~ ~ ~ • • ConacoPh ~ I I ~ ps Alaska ~ _~ Plan: 1J-162 L1 (wp09) Sperry Drilling Services Proposal Report - Geographic 17 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-162 - Slot 1J-162 1J-162 L1 Local Coordinate Origin: Centered on Well Plan 1J-162 - Slot 1J-162 Viewing Datum: Doyon 15 @ 121.OOft (Doyon 15 (40+81)) - TVDs to System: N North Reference: True Unit System: API - US Survey Feet L ~ ~ To~ Sperry ~rilling Servlaea ~ ~ ~ ~~~ ~~~ .~#~~ri Project: Kuparuk River Unit WEU. DETAILS: Plan U-1G2 NAD 1927 (NADCON CONUS) Alaska Zone 04 HALLIBURTOIV Site: KuparuklJPad Well: Plan 1J-162 GoundLevel: g~ pp WellbOte: 1J-162 L1 +N/-S +FJ-W Northmg F~sting letittude Longitude Slot Sperry Orilling Bervices Plan: 1J-162 L1 (wp09) 0.00 0.00 594576963 558683.15 70°IS'44J9N 149°31'32149W I1-I62 ~ ~ FORMATION TOP DETAILS No. NDPath NDSS MDPath Formation 1 1525.44 1404.44 1720.56 Pfrost 2 1650.95 1529.95 1965.66 T3 3 1935.72 1814.72 2845.28 K15 4 2148.15 2027.15 3695.40 Casing Pt 5 2726.40 2605.4 7109.94 Ugnu C 6 2906.21 2785.21 8180.13 Ugnu B 7 2949.83 2828.83 8448.51 Ugnu A 8 3108.79 2987 79 9468.30 K 13 9 3186.14 3065.14 9991.33 W Sak D ~11/ ~ i ~ CASING DETAILS ~ No MD TVD TVDss Name Size 1 4612.00 2303.382182.38 13 3/8" 13-3/8 2 9991.35 3186.153065.19 5/8" TOW 9-5/8 3 14254.78 3146.70 3025.7 5 1l2" 5-1/2 ~ 2500 L1: 9 5/B" TOW @ 9991' MD, 3186' TVD: 592' FSL, 64' FWL - Sec34-T11 N-R10E L1: BHL @ 14255' MD, 3147' ND: 1612' FSL, 87' FWL - Sec03-T10N-R10E 2750 -------------------- -------------- ------------------------------ ~ ~ rn - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - 3000 0 - - - ~ f ° /' ------------- ~ -- _ ~ -------- -m- ------0--/-0---------------------------------------------------------- ~ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ - _ - _6 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ ~ _ _ _ ~ _ _ _ _ _ _ _ - - - ~ ~ i 3250 W Sak D p i o N i o °o ~~ ~ rn ~°,~ i i~O ~i o vl c: o ~ ~ o ~ ° i ~ ~ ~ ~ ~ rn ~ ~ I ~ 1 1 ~ ~ N I ~ I~ ~ I ~ I I~ ~ 9 ~ I ~ I O 3500 ~ ~~ I i ~ i ~ ~ ~o ~ i ~ i ~ ~ ~i ~ i i1 i i ~ ~ i i 1J-162 L1 T1 (wp08) 04/18/07 ~~ 1J-162 L1 T3 (wp08) 04/16/07 ~i ~ 1J-162 L1 T6 (wp08) 04/18/07 '~ 1J-162 Lt D-Toe (wp09) 04/18l 3750 ~ ~ 1J-162 L1 T2 (wp08) 04/18/07 1J-162 L1 T4 (wp08) 04/18/07 ~~_~62 L1 TS (wp08) 04/18/07 1J-162 L1 T7 (wp08) 04/18/07 4000 4250 4500 -I i i i i I i i i i I i i i i I i i i i ~ i i ~ ~ I ~ ~~ ~ I ~ ~ ~~ ~ ~ ~~ ~ ~,,, ~ ~. 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 COI'IOCOP~'11~~Ip5 aaska HALLIBURTON Sperry Orflling 8ervices -500 Project: Kuparuk River Unit WELL DETAIL 1J-162NAD 1927 (NADCON CONUS) Alaska Zone 04 Site: Kuparuk 1J Pad GroundLevel: 81.00 Well: Plan 1J-162 +N/-S +E/-W Northing Easting Latittude Longitude Slot ° ' ° ' Wellbore: 1J-162 L1 44.79N149 32.149W 1J-162 0.00 0.00 5945769.63 558683.15 70 15 31 Plan: 1 J-162 L1 (wp09) REFERENCE INFORMATION Co-ordinate(N/E)Reference: wenpiani~-~s2-sioi~~asz,rn,eNortn Vertical (TVD) Reference: ooyon ~s ~ iz~.oon ~ooyon ~s ~ao+ei~> Measured Depth Reference: ooyon is ~~zi.oon ~ooyo~ ~s ~ao+e~» Calculation Method: Minimum Curvature CASING DETAILS No MD ND NDss Name Size 1 4612.00 2303.38 2182.38 13 3/8" 133/8 2 9991.35 3186.15 306'9'WS" TOW 9-5/8 / 314254.78 3146.70 3025.7 5 1/2" 5-1/2 Ll: 9 5/8" TOW @ 9991' MD, 3186' 7VD: 592' FS4 ~~ FN'~-- Sec34T11 N-RlOE 95/8"TOW_ --------- '---_.~~_---------_ -1500 -2000 -2500 .. -3000 C c~L O ~ r + s -3500 ~ 0 ~ t 7 O ~ -4000 -4500 U-Iti'_LITI(«p0R)04,~18.'0 -------- I1J6'_LIT~I~~p08104,'IS/0 -------' U-16?UT3(wp08)04,'18/0 --------- U-I62L1T4(w~OS)04;1&/0 -------- U-162 LI TS (wp08) 04/I8i0 - - - - - - - - U-16? Ll T6 (wp08) W/18/0 - - - - - - - - IJ-162LIT7(wp08)04i18/0 -------- T M Azimuths to True NoRh Magnetic North: 24.46° Magnetic Field Strength: 57584.SnT Dip Angle: 80.72° Date: 1/25/2005 Model: BGGM2004 _ Ll: BHL ~u 14255' MD, 314T TVD: 1612' FS4 87' FWL - Sec03-TION-RI OE ------- , 1 J-16^_ LI D-Tce (~~p09) 03~18'0 - - - - - - - % i 3147 5 I /2"' ' IJ-162 LI (wp09) -10000 -9500 -9000 -8500 -8000 -7500 -7000 -6500 -6000 _acnn West(-)/East(+) (750 ft/in) ~ ConocoPhillips ~~~ ~ ~ Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Audit Notes: Version: Phase: PLAN Tie On Depth: 9,991.33 ~ ~ ~~ ~ ~~ __ e 40.00 0.00 0.00 180.00 5/17/2007 9:22:13AM Page 2 of 7 COMPASS 2003.11 Build 31 ~~~~~~~~~~. ~ Halliburton Company HALLISURTQN ~~Q~~,~~ Compass Proposal Report - Geographic ~psrry Dritling 8ervia~s Well Position +N/-S 0.00 ft Northing: 5,945,769.63 ft Latitude: 70° 15' 44.790" N +E/-W 0.00 ft Easting: 558,683.15 ft Longitude: 149° 31' 32.149" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft ~ ConocoPhillips Alaska 9,991.33 81.65 187.55 3,186.14 3,065.14 -1,361.71 -7,967.69 0.00 0.00 0.00 0.00 10,007.83 83.89 187.55 3,188.22 3,067.22 -1,377.94 -7,969.84 13.60 13.60 0.00 0.00 10,037.83 83.89 187.55 3,191.41 3,070.41 -1,407.51 -7,973.76 0.00 0.00 0.00 0.00 10,310.30 92.36 176.86 3,200.33 3,079.33 -1,679.00 -7,984.13 5.00 3.11 -3.92 -51.89 10,476.25 92.36 176.86 3,193.50 3,072.50 -1,844.55 -7,975.04 0.00 0.00 0.00 0.00 10,550.55 91.00 179.50 3,191.32 3,070.32 -1,918.78 -7,972.68 4.00 -1.83 3.56 117.20 10,700.55 91.00 179.50 3,188.70 3,067.70 -2,068.75 -7,971.37 0.00 0.00 0.00 0.00 10,772.28 88.18 180.05 3,189.21 3,06821 -2,140.47 -7,971.09 4.00 -3.93 0.77 168.90 10,881.68 88.18 180.05 3,192.68 3,071.68 -2,249.82 -7,971.19 0.00 0.00 0.00 0.00 10,979.94 92.09 179.61 3,192.44 3,071.44 -2,348.06 -7,970.90 4.00 3.97 -0.45 -6.46 11,279.94 92.09 179.61 3,181.50 3,060.50 -2,647.85 -7,968.86 0.00 0.00 0.00 0.00 11,366.30 91.23 179.52 3,179.00 3,058.00 -2,734.16 -7,968.21 1.00 -0.99 -0.10 -174.10 12,092.32 91.23 179.52 3,163.40 3,042.40 -3,460.00 -7,962.14 0.00 0.00 0.00 0.00 12,247.28 89.69 179.34 3,162.15 3,041.15 -3,614.94 -7,960.61 1.00 -0.99 -0.11 -173.46 13,147.64 89.69 179.34 3,167.00 3,046.00 -4,515.23 -7,950.31 0.00 0.00 0.00 0.00 13,244.96 90.27 180.68 3,167.03 3,046.03 -4,612.54 -7,950.34 1.50 0.60 1.38 66.55 13,419.68 90.27 180.68 3,166.20 3,045.20 -4,78725 -7,952.42 0.00 0.00 0.00 0.00 13,579.97 91.40 178.56 3,163.86 3,042.86 -4,947.51 -7,951.37 1.50 0.71 -1.32 -61.95 13,753.90 91.40 178.56 3,159.60 3,038.60 -5,121.33 -7,947.00 0.00 0.00 0.00 0.00 13,832.48 91.48 179.34 3,157.62 3,036.62 -5,199.88 -7,945.57 1.00 0.10 1.00 84.18 14,254.79 91.48 179.34 3,146.70 3,025.70 -5,622.01 -7,940.73 0.00 0.00 0.00 0.00 Halliburton Company Compass Proposal Report - Geographic ~ HALLIBURT N Sp~rry Drilling 8ervica~s 5/17/2007 9:22:13AM Page 3 of 7 COMPASS 2003.11 Build 31 ~ ~` ~ #~~; ~ ~• ~ ,~ ~.., ~ ~ •% Halliburton Company COt10C0~'ll~~ p~5 Compass Proposal Report - Geographic HA-LLIBURTON Sperry Dr111Ir~y Bervlcsee _ - _ ~ ~ _ - ';1,i-162~L1 w 09 ~~ - - -- - ~ ~ / 9,991.33 ~ 81.65 187.55 „a 3,186.14 3065.14 -1,361.71 -7,967.69 5,944,346.00 550,727.07 0.00 1,361.71 L7 : 9 5/8" TOW @ 9991' M D, 3186' TVD: 592' FS L, 64' FWL - Sec34-T11 N- R10E - W Sak D- 9 5/8" TOW 9,999.98 82.83 187.55 3,187.31 3066.31 -1,370.21 -7,968.82 5,944,337.49 550,726.02 13.60 1,37021 10,007.83 83.89 187.55 3,188.22 3067.22 -1,377.94 -7,969.84 5,944,329.76 550,725.05 13.60 1,377.94 10,037.83 83.89 187.55 3,191.41 3070.41 -1,407.51 -7,973.76 5,944,300.16 550,721.37 0.00 1,407.51 10,099.98 85.82 185.09 3,196.98 3075.98 -1,469.03 -7,980.57 5,944,238.60 550,715.03 5.00 1,469.03 10,131.25 86.79 183.87 3,199.00 3078.00 -1,500.14 -7,983.01 5,944,207.47 550,712.84 5.00 1,500.14 1J-162 L1 T2 (wp08) 04/18/07 10,199.98 88.93 181.17 3,201.57 3080.57 -1,568.74 -7,986.03 5,944,138.85 550,710.36 5.00 1,568.74 10,299.98 92.04 177.26 3,200.73 3079.73 -1,668.70 -7,984.66 5,944,038.92 550,712.50 5.00 1,668.70 10,310.30 92.36 176.86 3,200.33 3079.33 -1,679.00 -7,984.13 5,944,028.63 550,713.11 5.00 1,679.00 10,399.98 92.36 176.86 3,196.64 3075.64 -1,768.46 -7,979.22 5,943,93921 550,718.72 0.00 1,768.46 10,476.25 92.36 176.86 3,193.50 3072.50 -1,844.55 -7,975.04 5,943,863.16 550,723.49 0.00 1,844.55 10,499.98 91.93 177.70 3,192.61 3071.61 -1,868.24 -7,973.92 5,943,839.49 550,724.80 4.00 1,868.24 10,550.55 91.00 179.50 3,191.32 3070.32 -1,918.78 -7,972.68 5,943,788.97 550,726.43 4.00 1,918.78 10,599.98 91.00 179.50 3,190.46 3069.46 -1,968.20 -7,972.25 5,943,739.56 550,727.25 0.00 1,968.20 10,699.98 91.00 179.50 3,188.71 3067.71 -2,068.18 -7,971.38 5,943,639.59 550,728.90 0.00 2,068.18 10,700.55 91.00 179.50 3,188.70 3067.70 -2,068.75 -7,971.37 5,943,639.02 550,728.91 0.00 2,068.75 1J-162 L1 T 1 (wp08) 04/18/07 10,772.28 88.18 180.05 3,189.21 3068.21 -2,140.47 -7,971.09 5,943,567.32 550,729.75 4.00 2,140.47 10,799.98 88.18 180.05 3,190.09 3069.09 -2,168.15 -7,971.12 5,943,539.63 550,729.94 0.00 2,168.15 10,881.68 88.18 180.05 3,192.68 3071.68 -2,249.82 -7,971.19 5,943,457.98 550,730.50 0.00 2,249.82 10,899.98 88.91 179.97 3,193.14 3072.14 -2,268.11 -7,971.20 5,9~43,439.69 550,730.64 4.00 2,268.11 10,979.94 92.09 179.61 3,192.44 3071.44 -2,348.06 -7,970.90 5,943,359.76 550,731.55 4.00 2,348.06 10,999.98 92.09 179.61 3,191.71 3070.71 -2,368.08 -7,970.77 5,943,339.74 550,731.84 0.00 2,368.08 11,099.98 92.09 179.61 3,188.06 3067.06 -2,468.01 -7,970.09 5,943,239.82 550,733.30 0.00 2,468.01 11,199.98 92.09 179.61 3,184.42 3063.42 -2,567.94 -7,969.41 5,943,139.91 550,734.76 0.00 2,567.94 11,279.94 92.09 179.61 3,181.50 3060.50 -2,647.85 -7,968.86 5,943,060.02 550,735.93 0.00 2,647.85 1J-162 L1 T3 (wp08) 04l18/07 11,299.98 91.89 179.59 3,180.80 3059.80 -2,667.87 -7,968.72 5,943,040.00 550,736.22 1.00 2,667.87 11,366.30 91.23 179.52 3,179.00 3058.00 -2,734.16 -7,968.21 5,942,973.72 550,737.26 1.00 2,734.16 11,399.98 91.23 179.52 3,178.27 3057.27 -2,767.84 -7,967.93 5,942,940.05 550,737.80 0.00 2,767.84 11,499.98 91.23 179.52 3,176.13 3055.13 -2,867.81 -7,967.09 5,942,840.10 550,739.41 0.00 2,867.81 11,599.98 91.23 179.52 3,173.98 3052.98 -2,967.78 -7,966.26 5,942,740.14 550,741.03 0.00 2,967.78 11,699.98 91.23 179.52 3,171.83 3050.83 -3,067.76 -7,965.42 5,942,640.19 550,742.64 0.00 3,067.76 11,799.98 91.23 179.52 3,169.68 3048.68 -3,167.73 -7,964.59 5,942,540.24 550,744.26 0.00 3,167.73 11,899.98 91.23 179.52 3,167.53 3046.53 -3,267.70 -7,963.75 5,942,440.28 550,745.87 0.00 3,267.70 11,999.98 91.23 179.52 3,165.38 3044.38 -3,367.68 -7,962.91 5,942,340.33 550,747.49 0.00 3,367.68 12,092.32 91.23 179.52 3,163.40 3042.40 -3,460.00 -7,962.14 5,942,248.02 550,748.98 0.00 3,460.00 1J-162 L1 T4 (wp08) 04/18t07 12,099.98 91.15 179.51 3,163.24 3042.24 -3,467.65 -7,962.08 5,942,240.37 550,749.10 1.00 3,467.65 12,199.98 90.16 179.40 3,162.09 3041.09 -3,567.64 -7,961.13 5,942,140.41 550,750.83 1.00 3,567.64 12,247.28 89.69 179.34 3,162.15 3041.15 -3,614.94 -7,960.61 5,942,093.11 550,751.72 1.00 3,614.94 12,299.98 89.69 179.34 3,162.44 3041.44 -3,667.63 -7,960.01 5,942,040.43 550,752.73 0.00 3,667.63 12,399.98 89.69 179.34 3,162.97 3041.97 -3,767.62 -7,958.86 5,941,940.46 550,754.65 0.00 3,767.62 12,499.98 89.69 179.34 3,163.51 3042.51 -3,867.61 -7,957.72 5,941,840.49 550,756.58 0.00 3,867.61 5/17/2007 9:22:13AM Page 4 of 7 ~~~~~~~~~~ COMPASS 2003.11 Build 31 . ~ 12,599.97 89.69 179.34 3,164.05 3043.05 -3,967.60 -7,956.58 5,941,740.52 550,758.50 0.00 3,967.60 12,699.97 89.69 179.34 3,164.59 3043.59 -4,067.60 -7,955.43 5,941,640.55 550,760.42 0.00 4,067.60 12,799.97 89.69 179.34 3,165.13 3044.13 -4,167.59 -7,954.29 5,941,540.58 550,762.34 0.00 4,167.59 12,899.97 89.69 179.34 3,165.67 3044.67 -4,267.58 -7,953.15 5,941,440.61 550,764.27 0.00 4,267.58 12,999.97 89.69 179.34 3,166.20 3045.20 -4,367.57 -7,952.00 5,941,340.64 550,766.19 0.00 4,367.57 13,099.97 89.69 179.34 3,166.74 3045.74 -4,467.56 -7,950.86 5,941,240.67 550,768.11 0.00 4,467.56 13,147.64 89.69 179.34 3,167.00 3046.00 -4,515.23 -7,950.31 5,941,193.02 550,769.03 0.00 4,515.23 1J-162 L1 T 5 (wp08) 04118/07 13,199.97 90.00 180.06 3,167.14 3046.14 -4,567.56 -7,950.04 5,941,140.70 550,769.71 1.50 4,567.56 13,244.96 90.27 180.68 3,167.03 3046.03 -4,612.54 -7,950.34 5,941,095.71 550,769.76 1.50 4,612.54 13,299.97 90.27 180.68 3,166.77 3045.77 -4,667.55 -7,950.99 5,941,040.71 550,769.53 0.00 4,667.55 13,399.97 90.27 180.68 3,166.29 3045.29 -4,767.54 -7,952.19 5,940,940.72 550,769.12 0.00 4,767.54 13,419.68 90.27 180.68 3,166.20 3045.20 -4,787.25 -7,952.42 5,940,921.02 550,769.04 0.00 4,78725 1J-162 L1 T 6 (wp08) 04/18l07 13,499.97 90.84 179.62 3,165.42 3044.42 -4,867.54 -7,952.64 5,940,840.74 550,769.45 1.50 4,867.54 13,579.97 91.40 178.56 3,163.86 3042.86 -4,947.51 -7,951.37 5,940,760.78 550,771.34 1.50 4,947.51 13,599.97 91.40 178.56 3,163.37 3042.37 -4,967.50 -7,950.87 5,940,740.80 550,772.00 0.00 4,967.50 13,699.97 91.40 178.56 3,160.92 3039.92 -5,067.44 -7,948.36 5,940,640.90 550,775.29 0.00 5,067.44 13,753.90 91.40 178.56 3,159.60 3038.60 -5,121.33 -7,947.00 5,940,587.02 550,777.06 0.00 5,121.33 1J-162 L1 T7 (wp08) 04/18t07 13,799.97 91.45 179.02 3,158.45 3037.45 -5,167.38 -7,946.03 5,940,540.98 550,778.39 1.00 5,167.38 13,832.48 91.48 179.34 3,157.62 3036.62 -5,199.88 -7,945.57 5,940,508.49 550,779.11 1.00 5,199.88 13,899.97 91.48 179.34 3,155.88 3034.88 -5,267.34 -7,944.79 5,940,441.05 550,780.41 0.00 5,267.34 13,999.97 91.48 179.34 3,153.29 3032.29 -5,367.30 -7,943.65 5,940,341.11 550,782.33 0.00 5,367.30 14,099.97 91.48 179.34 3,150.70 3029.70 -5,467.26 -7,942.50 5,940,241.17 550,784.26 0.00 5,467.26 14,199.97 91.48 179.34 3,148.12 3027.12 -5,567.22 -7,941.36 5,940,141.23 550,786.18 0.00 5,567.22 . 14,254.79 91.48 179.34 3,146.70 - 3025.70 -5,622.01 -7,940.73 5,940,086.45 550,787.24 0.00 5,622.01 L1: BHL @ 14255' MD, 3747' TVD: 1612' FSL, 87' FWL - Sec03-T10N-R10 E - 5 1/2" -1J-162 L1 D-Toe (wp09) 04/18/07 5/17/2007 9:22:13AM Page 5 of 7 COMPASS 2003.11 Build 31 ~ ! 1 ~ ~ ~ ~ ~ ~ C0110C0~11~~Ip5 Halliburton Company HALLi URTON ~~ Compass Proposal Report - Geographic gpsrry Driliing Servfoes ^ ~ / Halliburton Company HALLIBURTON ~~~~~'~~~ Compass Proposal Report - Geographic gperry Drilii~g Sdervic~,s 3,167.00 1J-162 L1 T5 (wp08) 04/18/07 -4,51523 -7,950.31 5,941,193.02 550,769.03 - Point 3,166.20 1J-162 L1 T6 (wp08) 0411$!07 -4,78725 -7,952.42 5,940,921.02 550,769.04 - Point 3,181.50 1J-162 L1 T3 (wp08- 04118/07 -2,647.85 -7,968.86 5,943,060.02 550,735.93 - Point 3,159.60 1J-162 L1 T7 (wp08) 04/18/07 -5,121.33 -7,947.00 5,940,587.02 550,777.06 - Point 3,141.50 1J-162 L1 T8 (wp08) 04/18/07 -6,165.56 -7,935.09 5,939,543.01 550,797.11 - PoiM 3,146.70 1J-162 L7 D-Toe (wp09) 04/78/07 -5,622.01 -7,940.73 5,940,086.45 550,78724 - Point 3,188.70 1J-162 L1 T1 (wp08) 04/18/07 -2,068.75 -7,971.37 5,943,639.02 550,728.91 - Point 3,163.40 1J-162 L1 T4 (wp08) 04/18/07 -3,460.00 -7,962.14 5,942,248.02 550,748.98 - Point 3,199.00 1J-162 L1 T2 (wp08) 04/18/07 -2,168.76 -7,972.15 5,943,539.02 550,728.91 - Point 5/17/2007 9:22:13AM Page 6 of 7 r~ ~ ~ ~~ ~~~ COMPASS 2003.11 Build 31 ~ • 1,720.56 54.27 270.61 1,525.44 5.97 -609.51 Pfrost 1,965.66 64.04 269.68 1,650.95 6.42 -819.69 T3 2,845.28 72.00 269.04 1,935.72 -6.51 -1,651.27 K15 3,695.40 80.25 270.51 2,148.15 -11.16 -2,472.57 Casing Pt 7,109.94 80.25 270.51 2,726.40 18.76 -5,837.65 Ugnu C 8,180.13 80.57 251.84 2,906.21 -55.65 -6,884.21 Ugnu B 8,448.51 80.73 242.32 2,949.83 -158.67 -7,127.83 Ugnu A 9,468.30 81.34 206.11 3,108.79 -868.76 -7,818.59 K 13 9,991.33 81.65 187.55 3,186.14 -1,361.71 -7,967.69 W Sak D 5/17C1007 9:22:13AM Page 7 of 7 COMPASS 2003.11 Build 31 ~~~'~~~,~~~ ~ . . . e ~4 p ~..... ~. e 4wt ~ . .-..,.,. C0110C0~'ti~~IpS Halliburton Company H~4-LL1BtJRTON Alaska Compass Proposal Report - Geographic gperry Driiling 8erviaes ~ ° • ~ ConocoPh i 1 I ~ ps Alaska ~ Plan: 1 J-162 L1 (wp09) Sperry Drilling Services Anticollision Summary 18 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-162 1J-162 L1 Local Coordinate Origin: Centered on Well Plan 1J-162 - Slot 1J-162 Viewing Datum: Doyon 15 cQ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet HQr:.L~BrV~iT ,V Sperry ~rilUng ~ervic~~ ~~.~~~~~~~~ 0 ~ ~ .~..-.. ~ ~ I SURVEY PROGRAM Date: 2007-OS03T00:00:00 Validated: Yes Version: Depth From Depth To Survey/I'lan Tool 40.0 900.0 C&GYRO-SS 900.0 9991.3 M1IWD+IFR-AK-CAZSC 999t.3 14254.8 1J-162 Ll (wp09) MWD+IFR-AK-C.1~SC 1E-170 KUP3411-10-1 1E-170 L1 ~ Q C z~o 180 COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based so p06) From Colour To MD I 0 13 13 113 113 213 213 413 413 - - - --- 613 613 813 813 1813 1813 . 2813 2813 3813 3813 '- -- 4813 4813 5813 5813 7313 7313 --- -- 8813 8813 10313 10313 11813 11813 13313 13313 14813 14813 0 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation ~300 ft/in~ REFERENCEINFORMATION Co•ordinate (N/E) Reference: Well Plan 1J-762 - Slot 1J-162, True North VeRical (ND) Reference: Doyon 75 ~ 121.Oft (Doyon 15 (40+81~) Section (VS) Reference: Slot - 1 J-162~O.ON, O.OE) Measured Depth Reference: Doyon 15 @ 121.Oft (Doyon 15 (40+81~) Calculation Method: Minimum Curvature NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-162 Ground Level: 81.0 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 100Stations Depth Range From: 9991.3 To 14254.8 Maximum Range:1621.48165930563 Reference: Plan: 1J-162 L1(wp09) 0 180 90 Travelling Cylinder:lzimuth (TFO+AZI) ~°~ vs Centre to CenMe Separafion ~30 fUin~ Sec MD Inc Pzl ND +WS ~E/-W DLep TFaro VSac Targe~ 1 99913 81.G5 18].55 3186.3 -1361.] -19fi).) 0.00 0.00 1]61.] ] 10001.9 83.&9 18155 3 100319 83.89 18) 55 3108.3 3191 4 -13]).9 -1969.9 -14p].5 -]8)3.B 13.60 0.00 0.00 0.00 1]]~.9 1d0].5 4 103103 9i.38 1t8.ee 3200.] -tfi]9.0 ~I984] 50p -51.89 18I9.0 5 100]6.3 9l.% 1)6.86 319].5 -1BM.6 -]9]5.1 OW O.OJ 18M.6 6 1055~.6 8100 1]8.50 3191.3 -1918.8 -]9)3.1 d00 11].20 181E.8 10](l06 9100 1)950 8 10~/]3.3 88.18 180.05 1108) 31E82 -]9)14 -I1C0.5 -]811.i U00 4.00 UOU 168.90 ?0688 IJ-I62L1T1(v.p06)0411&0] 3190.5 9 tO8B1.] 88.18 180.p5 319].] -2]0.9.8 -18I1.3 000 0.00 2349.8 10 I09B~0 91.08 /18.61 919]A -33CB.1 -l9la.B dW E.96 25C8.1 il 113800 tt961 B15 ~164].9 ~]%B9 000 000 169"I.9 1J~163L1T](xpOB)ONf8~0i 12 113883 8113 ti9.52 3179.0 .]]34.2 -T8882 1.00 .11A.10 ]]3,1 1] 1Z093.] 91.23 I]9.`a.' 316J.4 ~J4600 -]%2.2 OW D00 3W0.0 1J-ifilL1T0(xy06)01IINOi 1d 11141~ 89.89 1]B.]0 IS I]1C].) 8969 1]9.3d 318]2 316]0 -]81~.9 -1880.8 ~4515.3 ~19503 100 000 .113.~8 000 ~811.8 C515.] 1J-162L1T5(Mp08)OM1G01 16 132450 9p2] 1C0.68 ]18].0 J61].8 .R50.4 1.50 G6.55 q8138 1] 13419.] 90.]1 180.68 18 1JSE9.0 91.~0 1]8.56 ]1662 ~1&t9 -4)B].J .i95]C ~81].5 -i951.~ ~p0 1.50 pOp E1.95 C18].] 1J.16]LiTB(MpOB)0418I0] ~BII.S 19 13]SJ9 91.C0 11856 ]1598 ~131J ~i9C10 000 4W S1I1] 1}~82L1P(vqOB)OM18~OT M /303]5 91.C8 1]8.31 11 1<254.8 91.C8 1]9.J4 ~15].6 J1Cfi.] 5188.8 .iB15.8 -5622.0 .]940] 1.OD 000 81.1! 000 S18B.8 56330 iJ-1fi2L16Twlw-~)~'1&Ol ~ Halliburton Company ~ Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 1 J-162 L1 (wp09) & NOT PLANNE Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 9991.33 to 14254.80 ft Scan Method: Trav Cylinder North Maximum Radius: 1621.48 ft Error Surface: EllipSe + CaSing Casing Points 9991.33 3186.25 9.625 12.250 9 5/8" TOW 14254.80 3146.70 5.500 8.500 51/2" Plan: 1J-162 L1 (wp09) Date Composed: 5/14/2007 Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary Kuparuk 1 E Pad 1 E-170 1 E-170 L1 V8 Out of range Kuparuk 1 E Pad 1 E-170 1 E-170 L2 V3 Out of range Kuparuk 1 E Pad 1 E-170 1 E-170 V3 Out of range Kuparuk 1J Pad Plan 1J-162 Plan 1J-162 V5 Plan: 1 10000.00 10000.00 0.09 0.00 0.09 Pass: No Errors Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174 V1 Plan: Out of range Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174L1 VO Plan Out of range Kuparuk River Unit N KUP 34-11-10-1 KUP 34-11-10-1 V1 Out of range r~~~~' ~~,~ ~, ~ ~ F \ 6 ~ ~ ~ ~~t: s ~ '1 ~..... 1~-162Li~rilling Hazard~ummarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low ' Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin ~ ~""~j ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 1J-162L1 Drilling Hazards Summary i ~ . ; ~ $ , `?,' ;_ ~> 6/4/2007 3: 24: 00 PM . . . fi ~.... . ~ O ~ ~ ~ Y r+ Insulated Conductor, 20" 94# K-55 x 34" 0.312 N!f +/- 80' Wellhead / Tubing / Tree: 133/8" x 4-112", 5,000 psi Camco, 41/2" x 1" KBMG 13-3/8' Casing GLM, Camco, 4112" x 1" KBMG Shoe, 8#, L-80, BTC et @ 4612' MD, 303' ND ConocoPhi I li ps West Sak Hybrid Producer 1 J-162 ~-'~ Dual Lateral Completion ---/l~,°lanned / Bottom of Motor Centralizer Tubing String Centralift 418 HP KMHFER with FC6000 Pump " 12.6#, L-80, IBTM ~8" ID, 3.833" Drift D-sand Window at 9991' MD, 3186' ND 7" x 9-5/8" Model B HOOK Hanger 7" X 9-518" ZXP / `~ Liner Top Packer 7" X 9-SIS" Flex Lock Liner Hanger I Packer Assembly Liner Hanger ~ +/- ~ 0100' M D Casing Sealbore R 4.75" I~ mBak<rHUghls2W~.ThisGOCllMntmay~p~Celepoducetlwtli5tributeC 1 k r i~ 1 yf~ Ly y I t I I Jiii~~ plwtocopying, rccordi~g, a by any infomu~ion sbrage antl retreval syAm k ii o I ~~(' tl 1~'1 e~1 ~ n 9 k H~ zs liic. ~ 4112" Guide Shce ~ 4-1/2" Casin Shoe, 11.6#, L-80 BTCM avz•'nentiointsnoe 14254' MD, 3146' ND Tieback Sleeve 'B' Sand Lateral 5-712" 15.5 #, BTC, L-80 Slotted Liner 5-1/2" Eccentric Guide Shoe k _~,;- 5-112" Casing Shoe, 15.5 #, L-80 BTCM 10-3/4" X 9-5/8" Casing Shoe, Set @ 14258' MD, 3218' ND 40.0#, L-80 BTC @ 10445' MD, 3251' TVD (84 deg inc) ~ar~. ,_,w__.~_".._„y_.,..,_~..__om.._., a.. 'D' Sand Lateral .... B~ Baker Oil Tools ,Equinment Soecifications 7"" X 9-5/8" HOOK Hanger Mainbore Drift: 7.00" Mainbore Drift, with diverter: 6.25" Lateral Dritt, no diverter or LEM: 6.15" Late~al Dritt, wl diverter, no LEM: 5.13" LaterallMainbore Diverter OD: 8.50" 4112" 17.6#, BTC, S1IT' PayZone ECP L-80 Slotted Liner ~ ~ ~ ~'RAiYSIO~iI~'~'A~. L~T'~'Eta C'lEi.~CKLIST ~VEL,L N;~iytE ~~-'~~ I ~ _- \ ~ ~- L ~ PTD# _ ~~i'-'( -• '0 ~ ~ ~ Developmeat Service Ex forato lYon-Conventiona[ We!( P ~'~ Srratigraphic Test Cercfe Appropriate Letter / Paragraphs to be Iaciud~d in Transmittal Getter ' CE~CK ; 1~'E~AT APPL[ES ADD-O~IS (OPT[ONS) ~ T'EXT FOR APPROVAL LETTER i ~ ~ MT_iLTI LATERAL i , i i (If [ast two digits ~ ~P[ number ,' between 60-69) ~ P[LOT E{OLE I i i ~ The perrnit i; for a new well6ore segment of exisring I wetl 1 c~ -\(p ~--.. ~ in I Permit Y `1-~C) are °~ ~ ~ , AP[ No. ~0-0~`=i- a33to~ _ ~ ~ ~ Production should continue to be repocred as a funcriva of the ~~ ,' oci$inal 4Pt number srated above. ;[n accordance with 20 AAC 23.OU~ ~ ~ acquired for the pilot hole must be Cclearty different~iatedann both ' ; wel! name ( ' (~0- Pt-n and API ~umber ~ - acquired for we(t =1 from recards, data and lo~s ~ The permit is approved sub'ect to full c I 1 ompltazecc wtth 20 AAC ~ ; 2~.4». Apprqvat to perforate and produce / in~ec~ is contingent ; ! upon issuance of a conservation order approving a spacing j ; exception. i liabi(rty of any protest [o the spacing exception that may oc urs ~e j ~ SPACIIYG EXCEPTION ; uKY D[TCH ~ All dry ditch sample sets subrnitted to th~~ommission must be in ;' ' i SA.~IPLE i no greater than 30' sampte intecvals &om betow~ the perntafrost or ; ~ ( from whece samples are fint ca~g6t and 10' samp[e intervals j ' ~ ~ through target zones. , ~ i ~ ~ ~ j Please note the fotlowiag. speciat condition oF thi; ;, i W!1 Conventionat i production or productioa testing of coal bed methane is not a! ow ~t. ~ ~ for (riame of weih until after Corn anv Name has designed d i I j ~~mplemented a water well testing program to provide baseline data I ~ ; vn water quality and quantity. (Comnany 1Vame) must contact the ~ ; ~ Commission to obtain advance approval of such water well testing ! 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To improve the readability of the We~l History file and to sim.plify i'inding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organiz.e this category of information. ., , ~ 1j-16211.tapx sperry-sun Drillin services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Fri oct 12 10:13:14 2007 Reel Header Service name .............LISTPE Date . ...................07/10/12 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................5T5 LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/10/12 Origin ...................5T5 Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA . scientific Technical services Scientific Technical Services 17-162 L1 500292336060 conocoPhillips Alaska Inc. sperry Drilling Services 12-OCT-07 MWD RUN 2 MWD RUN 4 MWD RUN 7 ~og NUMBER: w-0005034902 w-0005034902 w-0005034902 LOGGING ENGINEER: R. FRENCH B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: M. THORNTON F. HERBERT M. THORNTON MWD RUN 8 MWD RUN 9 ~06 NUMBER: W-0005034902 w-0005034902 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE OPERATOR WITNE55: M. THORNTON M. THORNTON # SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: lOE FNL: Fs~: 1958 FEL: 2527 FWL: Page 1 ~a"~-c~s~ ~~S'6~~ ~ • ~ 1j-16211.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 122.00 GROUND LEVEL: 81.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 15T STRING 12.250 13.375 3820.0 2N~ STRING 8.500 9.625 9954.0 3RD STRING PRODUCTION STRING # REMARKS: l. ALL DEPTHS ARE MEASURED DEPTHS UNLE55 OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (ND). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK EXITING THE 1J-162 L1PB1 WELLBORE AT 10035~MD/3192~ ND, WITHIN THE MWD RUN 8 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,4,8,9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUNS 8,9 AL50 INCLUDED AT-BIT GAMMA (ABG). NO PROGRE55 WAS MADE ON MWD RUN 3. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,4,7-9 REPRESENT WELL 1J-162 L1 WITH API#: 50-029-23360-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14489'MD/3144' ND. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). $ File Header Service name .............STSLIB.001 Page 2 • ~ 1j-16211.tapx Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3785.0 14455.0 RPM 3805.0 14447.0 RPX 3805.0 14447.0 FET 3805.0 14447.0 RPD 3805.0 14447.0 RPS 3805.0 14447.0 RoP 3820.5 14489.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 3785.0 7994.0 MWD 4 7994.0 9954.0 MwD 7 9954.5 10006.0 MwD 8 10006.0 10035.0 MwD 9 10035.5 14489.0 $ # REMARKS: MERGED MAIN PA55. $ # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................Down Opt~cal log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. . .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 Page 3 ~ ~ ~ 1j-16211.tapx ROP MWD FT/H 4 1 68 28 8 Fi rst Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3785 14489 9137 21409 3785 14489 RPD Mw~ OHMM 7.34 2000 31.9552 21285 3805 14447 RPM MwD OHMM 6.73 2000 28.2079 21285 3805 14447 RPS MwD OHMM 5.35 2000 26.4198 21285 3805 14447 RPx MwD OHMM 3.22 2000 25.9137 21285 3805 14447 FET MwD HOUR 0.08 299.43 1.38735 21285 3805 14447 GR Mw~ API 22.14 132.14 67.9134 21341 3785 14455 RoP Mw~ FT/H 0.06 4216.38 269.888 21338 3820.5 14489 First Reading For Entire File..........3785 ~ast Reading For Entire File...........14489 File Trail~ service service version Date of Maximum Fi 1 e Tyl Next Fi =_r name... .......STSLIB.001 Sub Level Name... Number. ........1.0.0 Generation.... .07/10/12 Physical Record..65535 ~e ................LO le Name...........5T5LIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3785.0 7963.5 RPD 3805.0 7950.0 FET 3805.0 7950.0 rtPS 3805.0 7950.0 RPx 3805.0 7950.0 RPM 3805.0 7950.0 RoP 3820.5 7994.0 $ # LOG HEADER DATA DATE LOGGED: 09-JUL-07 Page 4 ~ SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # # # # # # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ 1j-16211.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RE5I5. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER~S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LO55 (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 ~ Insite 74.11 Memory 7994.0 3820.0 7994.0 77.6 82.1 TOOL NUMBER 132482 77613 12.250 3820.0 Fresh Water Gel 8.95 52.0 9.6 500 6.0 2.200 72.0 1.220 135.3 2.600 72.0 2.200 72.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 Page 5 ~ ~ 1j-16211.tapx RPX MWD020 OHMM 4 1 68 16 5 FET MwD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3785 7994 5889.5 8419 3785 7994 RPD MWD020 OHMM 7.34 2000 16.241 8291 3805 7950 RPM Mw~020 OHMM 6.73 2000 15.3346 8291 3805 7950 RPS MwD020 OHMM 5.35 1746.89 13.6384 8291 3805 7950 RPx MwD020 OHMM 3.22 1293.21 11.1603 8291 3805 7950 FET Mw~020 HOUR 0.11 101.2 1.02325 8291 3805 7950 GR Mw~020 API 22.14 132.14 61.1613 8358 3785 7963.5 ROP MwD020 FT/H 0.06 943.37 228.861 8348 3820.5 7994 First Reading For Entire File..........3785 ~ast Reading For Entire File...........7994 File Trail~ service service version Date of Maximum Fi 1 e Tyl Next Fi er name... .......STSLIB.002 Sub Level Name... Number. ........1.0.0 Generation.... .07/10/12 Physical Record..65535 ~e ................LO le Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub ~evel Name... version Number. ........1.0.0 Date of ~eneration.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7950.5 9954.0 RPD 7950.5 9954.0 RPS 7950.5 9954.0 RPX 7950.5 9954.0 RPM 7950.5 9954.0 GR 7964.0 9954.0 RoP 7994.5 9954.0 $ Page 6 ~ ~ 1j-16211.tapx # LOG HEADER DATA DATE LOGGED: 15-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9954.0 TOP LOG INTERVAL (FT): 7994.0 BOTTOM LOG INTERVAL (FT): 9954.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.4 MAXIMUM ANGLE: 82.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 EWR4 ELECTROMAG. RESIS. 4 222163 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER~S CASING DEPTH (FT): 3820.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (5): 52.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 200 FLUID LO55 (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.500 85.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.070 122.0 MUD FILTRATE AT MT: 1.600 85.0 MUD CAKE AT MT: 1.900 85.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record ~ata Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth units ......... .. ......... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 7 ~ ~I 1j-16211.tapx RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7950.5 9954 8952.25 4008 7950.5 9954 RPD MwD040 OHMM 7.44 39.14 12.8285 4008 7950.5 9954 RPM MwD040 OHMM 6.91 34.45 11.748 4008 7950.5 9954 RP5 Mw~040 OHMM 6.66 32.18 10.98 4008 7950.5 9954 RPx Mw~040 OHMM 5.71 23.11 9.07808 4008 7950.5 9954 FET MwD040 HouR 0.08 100.77 2.7794 4008 7950.5 9954 GR MwD040 API 22.54 120.53 75.2405 3981 7964 9954 ROP MwD040 FT/H 0.09 981.13 285.964 3920 7994.5 9954 First Reading For Entire File..........7950.5 ~ast Reading For Entire File...........9954 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 oate of ~eneration.......07/10/12 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........5T5LIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of ~eneration.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RoP 9954.5 10006.0 $ # LOG HEADER DATA DATE LOGGED: 26-JUL-07 Page 8 ~ SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # # # # # # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER~S CASING DEPTH (FT): 1j-16211.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction.. ............Down optical log depth units...........Feet ~ata Reference Point ..............undefined Frame 5pacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... ~atum specification Block sub-type...0 ~' Insite 72.13 Memory 10006.0 9954.0 10006.0 81.8 81.8 TOOL NUMBER 8.500 9954.0 Mineral Oil Base 8.40 55.0 .0 23000 .0 .000 .0 .000 98.6 .000 .0 .000 .0 -vame service order units size -vsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 Fi rst Last Page 9 C~ 1j-16211.tapx Name Service Unit Min Max Mean DEPT FT 9954.5 10006 9980.25 RoP MwD070 FT/H 0.79 47.98 14.3531 First Reading For Entire File ..........9954.5 Last Reading For Entire File. ..........10006 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER ~ Nsam Reading Reading 104 9954.5 1000b 104 9954.5 10006 FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 9954.5 10035.0 FET 9954.5 10035.0 GR 9954.5 10035.0 RPx 9954.5 10035.0 RPD 9954.5 10035.0 RPM 9954.5 10035.0 RoP 10006.5 10035.0 $ # LOG HEADER DATA DATE LOGGED: 27-]UL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10035.0 TOP LOG INTERVAL (FT): 10006.0 BOTTOM LOG INTERVAL (FT): 10035.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.8 MAXIMUM ANGLE: 94.0 Page 10 ~ ~ 1j-16211.tapx # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 097054 EWR4 ELECTROMAG. RESIS. 4 228269 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER~S CASING DEPTH (FT): 9954.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (5): 61.0 MUD PH: .O MUD CHLORIDES (PPM): 23000 FLUID LO55 (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 98.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................Down Optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 -vame service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MwD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 Fi rst Name Service Unit Min Max Mean Nsam Reading DEPT FT 9954.5 10035 9994.75 162 9954.5 RPD MwD080 OHMM 11.24 1845.76 96.8735 162 9954.5 Page 11 Last Reading 10035 10035 • ~ ~' 1j-1621 1.tapx RPM MwD080 OHMM 12.98 1763.29 78.3614 162 9954.5 10035 RPS MwD080 OHMM 15.86 162.59 69.0972 162 9954.5 10035 RPx MwD080 OHMM 11.78 1853.87 91.7466 162 9954.5 10035 FET MwD080 HOUR 0.27 299.43 39.85 162 9954.5 10035 GR Mw~080 API 40.58 75.46 55.8936 162 9954.5 10035 RoP MwD080 FT/H 12.71 272.15 166.042 58 10006.5 10035 First Reading For Entire File..........9954.5 Last Reading For Entire File...........10035 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10035.5 14447.0 RPX 10035.5 14447.0 RPS 10035.5 14447.0 RPD 10035.5 14447.0 GR 10035.5 14455.0 FET 10035.5 14447.0 RoP 10035.5 14489.0 $ # LOG HEADER DATA DATE LOGGED: 30-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14489.0 TOP LOG INTERVAL (FT): 10035.0 BOTTOM LOG INTERVAL (FT): 14489.0 BIT ROTATING SPEED (RPM): Page 12 . ~ 1j-16211.tapx HOLE INCLINATION (DEG MINIMUM ANGLE: 84.6 MAXIMUM ANGLE: 96.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 66259 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER~S CASING DEPTH (FT): 9954.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (5): 55.0 MUD PH: .0 MUD CHLORIDES (PPM): 20000 FLUID LO55 (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 .O MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet Data Reference Po~nt ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 ~epth units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size tvsam Rep Code offset Channel DE~T FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 Fi rst Last Page 13 ~ ~ ~ 1j-16211.tapx Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10035.5 14489 12262.3 8908 10035.5 14489 RPD MwD090 OHMM 10.57 129.06 54.2159 8824 10035.5 14447 RPM Mw~090 OHMM 9.96 136.92 46.8591 8824 10035.5 14447 RPS MwD090 OHMM 9.79 2000 44.6586 8824 10035.5 14447 RPx MwD090 OHMM 9.61 2000 46.2143 8824 10035.5 14447 FET MWD090 HOUR 0.08 28.05 0.391022 8824 10035.5 14447 GR MWD090 API 40.24 115.54 71.218 8840 10035.5 14455 RoP MwD090 FT/H 3.55 4216.38 304.921 8908 10035.5 14489 First Reading For Entire File..........10035.5 ~ast Reading For Entire File...........14489 File Trail~ service service version Date of Maximum Fi 1 e Tyl Next Fi er name... .......STSLIB.006 Sub Level Name... Number. ........1.0.0 Generation.... .07/10/12 Physical Record..65535 ~e ................LO le Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/10/12 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................07/10/12 Ori 9in ...................5T5 Reel Name. .... ........UNKNOWN continuation -vumber......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Scientific Technical Services scientific Technical services Page 14 ~ 1j-16211pbl.tapx Sperry-Sun ~rilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri oct 12 13:20:08 2007 Reel Header Service name .............LISTPE Date . ...................07/10/12 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation rvumber......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape header Service name .............LISTPE Date . ...................07/10/12 Origin ...................5T5 Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER Kuparuk River unit west Sak MWD/MAD LOGS # WELL NAME: API NUMBER; OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ~ scientific Technical services ~ibrary. scientific Technical services 1J-162 L1 PB1 500292336072 ConocoPhillips ,4laska znc. Sperry Drilling Services 12-OCT-07 MWD RUN 2 MWD RUN 4 MWD RUN 7 w-0005034902 w-0005034902 w-0005034902 R. FRENCH B. HENNINGSE B. HENNINGSE M. THORNTON F. HERBERT M. THORNTON MWD RUN 8 w-0005034902 B. HENNINGSE M. THORNTON 35 11N lOE 1958 2527 Page 1 ~o'~--O~l ~ ~ 65`(0~ ~ , ~ ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1j-16211pbl.tapx 122.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3820.0 2N~ STRING 8.500 9.625 9954.0 3RD STRING PRODUCTION STRING # REMARKS: ~ 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (ND). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9954'MD/3183~ND, WITHIN THE RUN 4 INTERVAL OF THE 1~-162 PB2 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 7. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WA5 DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,4,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHTLE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 8 ALSO INCLUDED AT-BIT GAMMA (ABG). NO PROGRESS WAS MADE ON MWD RUN 3. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,4,7,8 REPRESENT WELL 1J-162 L1PB1 WITH API#: 50-029-23360-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10524'MD/3191'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP Page 2 ~ SPACING). SFXE = SMOOTHED $ 1j-16211pbl.tapx ~ FORMATION EXPOSURE TIME (DEEP SPACING). File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type. ............1.0 Previous File Name.......5T5LIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD ~epth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM FET RPD ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 3785.0 3805.0 3805.0 3805.0 3805.0 3805.0 3820.5 STOP DEPTH 10490.5 10483.0 10483.0 10483.0 10483.0 10483.0 10524.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO MERGE TOP 2 3785.0 4 7994.0 7 9954.5 8 10006.0 # REMARKS: MERGED MAIN PASS. $ MERGE BASE 7994.0 9954.0 10006.0 10524.0 # ~ata Format specification Record Data Record Type... ..........0 ~ata specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 ~epth units. . .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 Page 3 ~ ~ 1j-16211pbl.tapx RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3785 10524 7154.5 13479 3785 10524 RPD Mw~ OHMM 7.34 2000 17.3732 13357 3805 10483 RPM MwD OHMM 6.73 2000 15.9791 13357 3805 20483 RPS Mw~ OHMM 5.35 1746.89 14.6494 13357 3805 10483 RPx Mw~ OHMM 3.22 1853.87 12.8438 13357 3805 10483 FET Mw~ HOUR 0.08 299.43 1.97223 13357 3805 10483 GR MwD API 22.14 132.14 65.8881 13412 3785 10490.5 RoP MwD FT/H 0.06 981.13 248.418 13408 3820.5 10524 First Reading For Entire File..........3785 ~ast Reading For Entire File...........10524 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type ................~o Next File Name...........5T5LIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/12 Maximum Physical ttecord..65535 File Type. ............LO Previ0u5 File Ndme.......STSLIB.001 comment ttecord FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3785.0 7963.5 RPD 3805.0 7950.0 RPM 3805.0 7950.0 RPx 3805.0 7950.0 FET 3805.0 7950.0 RP5 3805.0 7950.0 ROP 3820.5 7994.0 Page 4 • ~ 1j-16211pbl.tapx $ # LOG HEADER DATA DATE LOGGED: 09-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION; 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7994.0 TOP LOG INTERVAL (FT): 3820.0 BOTTOM LOG INTERVAL (FT): 7994.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.6 MAXIMUM ANGLE: 82.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 77613 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3820.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.95 MUD VISCOSITY (S): 52.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.200 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.220 135.3 MUD FILTRATE AT MT: 2.600 72.0 MUD CAKE AT MT: 2.200 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined absent value ......................-999 ~epth units. . .. .. ..... ~atum specification Block sub-type...0 wame service order units size Nsam Rep Code offset Channel Page 5 i • 1j-16211pbl.tapx DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3785 7994 5889.5 8419 3785 7994 RPD MWD020 OHMM 7.34 2000 16.241 8291 3805 7950 RPM MWD020 OHMM 6.73 2000 15.3346 8291 3805 7950 RPS MWD020 OHMM 5.35 1746.89 13.6384 8291 3805 7950 RPx MWD020 OHMM 3.22 1293.21 11.1603 8291 3805 7950 FET MwD020 HOUR 0.11 101.2 1.02325 8291 3805 7950 GR Mw~020 aPI 22.14 132.14 61.1613 8358 3785 7963.5 ROP MwD020 FT/H 0.06 943.37 228.861 8348 3820.5 7994 First Reading For Entire File..........3785 ~ast Reading For Entire File...........7994 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/12 Maximum Physical ttecord..65535 File Type ................LO NeXt Fi12 Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/12 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......5T5LIB.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 7950.5 RPx 7950.5 RPM 7950.5 RPS 7950.5 STOP DEPTH 9954.0 9954.0 9954.0 9954.0 Page 6 ~ + 1j-16211pbl.tapx RPD 7950.5 9954.0 GR 7964.0 9954.0 ROP 7994.5 9954.0 $ # LOG HEADER DATA DATE LOGGED: 15-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9954.0 TOP LOG INTERVAL (FT): 7994.0 BOTfOM LOG INTERVAL (FT): 9954.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE; $0.4 MAXIMUM ANGLE: $Z,$ # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 EWR4 ELECTROMAG. RESIS. 4 222163 $ # BOREHOLE AND G4SING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3820.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 52.0 MUD PH: 9,5 MUD CHLORIDES (PPM): 200 FLUID LO55 (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.500 85.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.070 122.0 MUD FILTRATE AT MT: 1.600 85.0 MUD CAKE AT MT: 1.900 85.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................Down Optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ....................... Page 7 ~ u 1j-16211pbl.tapx Datum specificat ion Block sub-type...0 Name service order units size -vsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP r~w~040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7950.5 9954 8952.25 4008 7950.5 9954 RPD MwD040 OHMM 7.44 39.14 12.8285 4008 7950.5 9954 RPM MWD040 OHMM 6.91 34.45 Z1.748 4008 7950.5 9954 RPS MwD040 OHMM 6.66 32.18 10.98 4008 7950.5 9954 RPx MWD040 OHMM 5.71 23.11 9.07808 4008 7950.5 9954 FET MwD040 HOUR 0.08 100.77 2.7794 4008 7950.5 9954 GR MWD040 API 22.54 120.53 75.2405 3981 7964 9954 ROP Mw~040 FT/H 0.09 981.13 285.964 3920 7994.5 9954 First rteading For Entire File..........7950.5 ~ast Reading For Entire File...........9954 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File TyL~ e ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/12 Maximum Physical rtecord..65535 File Type.. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9954.5 10006.0 Page 8 . ~ 1j-16211pbl.tapx $ # LOG HEADER DATA DATE LOGGED: 26-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10006.0 TOP LOG INTERVAL (FT): 9954.0 BOTTOM LOG INTERVAL (FT): 10006.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.8 MAXIMUM ANGLE: 81.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER`S CASING DEPTH (FT): 9954.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MuD vISCO52TY (S): 55.0 MUD PH: .O MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 98.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 ~ata specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined absent value ......................-999 ~epth units. . .. .. ..... ~atum specification glock sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 Page 9 u ~ 1j-16211pbl.tapx First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 9954.5 10006 9980.25 104 9954.5 10006 ROP MwD070 FT/H 0.79 47.98 14.3531 104 9954.5 10006 First Reading For Entire File..........9954.5 ~ast Reading For Entire File...........10006 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 9954.5 10483.0 RPD 9954.5 10483.0 GR 9954.5 10490.5 FET 9954.5 10483.0 RPM 9954.5 10483.0 RPS 9954.5 10483.0 ROP 10006.5 10524.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWA RE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): Page 10 27-JUL-07 znsite 72.13 Memory 10524.0 10006.0 10524.0 i • 1j-16211pbl.tapx BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.8 MAXIMUM ANGLE: 94.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 097054 EWR4 ELECTROMAG. RESIS. 4 228269 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 9954.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 61.0 MUD PH: .O MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 98.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata tteference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 Page 11 ~ . 1j-16211pbl.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9954.5 10524 10239.3 1140 9954.5 10524 RPD MWD080 OHMM 11.24 1845.76 43.4626 1058 9954.5 10483 RPM MWD080 OHMM 12.98 1763.29 37.0586 1058 9954.5 10483 RPS MWD080 OHMM 15.86 162.59 36.4724 1058 9954.5 10483 RPx MWD080 OHMM 11.78 1853.87 40.3017 1058 9954.5 10483 FET MwD080 HOUR 0.09 299.43 6.35112 1058 9954.5 10483 GR MWD080 API 40.58 92.16 68.0083 1073 9954.5 10490.5 ROP MwD080 FT/H 12.71 489.87 287.436 1036 10006.5 10524 First Reading For Entire File..........9954.5 ~ast rteading For Entire File...........10524 File Trailer Service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........5T5LIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/10/12 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comment5 .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................07/10/12 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comment5 .................STS LIS Writing Physical EOF Physical EoF End Of LIS File ~ibrary. Scientific Technical Services ~ibrary. scientific Technical services Page 12
