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205-140
• Image Project Well History File Gover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a, ©~ ~ ~ ~ Well History File Identifier Organizingcao-,e~ ^ Two-sided IIIII'I~IIIIIIII~~I ^ Rescan Needed IIIII~I~II~IIIIIIN RE CAN DIGITAL DATA OVERSIZED (Scannable} Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: ^ Other:: /s! Project Proofing III II1I~I I~III II III BY: Maria Date: /s/ ~, Scanning Preparation _~ x 30 = _~ + ~~ =TOTAL PAGES__ ~~~ BY: Maria Date: ~/ [~, ~D g (Count does not include cover sheet) /s/ Production Scanning Stage 7 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~ YES NO BY: Maria Date: ~~~~©$ !s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III I) ~I I) I if ll I I III ReScanned III II~I~I I~III II III BY: Maria Date: /s/ Comments about this file:. Quality Checked III II III III Ilf~ ~N 10!6/2005 Well History File Cover Page.doc J ~ e.cs DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051400 Well Name/No. KUPARUK RIV UNIT 1Q-04L1-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21250-61-00 MD 11270 TVD 6734 Completion Date 11/5/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Sur Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments r,`~D D Asc Directional Survey 9185 11270 Open 1Q-04 L1, 1Q-04 L1-01, `-~' 1 Q-04 L1-02, 10-04 L 1-03 on diskette t/ Directional Survey Open 10-04 L1-01 de6g 14333 Gamma Ray 2 Blu 1 9198 11270 Open 1/16/2007 MD GR 1-Nov-2005 !I~g 14333 Gamma Ray 2 Blu 1 9198 11270 Open 1/16/2007 TVD GR 1-Nov-2005 ~~ pt 14333 LIS Verification 9072 11269 Open 1/16/2007 LIS Veri GR, ROP 1-Nov- ~ /~ 2005 } F.,S' C Asc 14333 LIS Verification 9072 11269 Open 1/16/2007 LIS Veri in Ascii Text GR, (a/ ROP 1-Nov-2005 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comme nts ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? Chips Received? Y / N Formation Tops Y ! N `~ Analysis Y / N Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051400 Well Name/No. KUPARUK RIV UNIT 1Q-04L1-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21250-61-00 MD 11270 TVD 6734 Completion Date 11/5/2005 Completion Status 1-OIL Current Status 1-OIL UIC N ) ,~ f ~ ~ Compliance Reviewed By: _ __ _ - __ _ ______ _ Date: _ ~`- t~c~/ ~C~~ _ __ • :~ Transmittal Form ~ BAKER HUCI~#ES I ~~°~ ~ ~~~ - -- - ~ INTEQ Anchorage GEOScience Center . i ., ~_ ~..,.. To: AOGCC 333 West 7t'' Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman - I °••~- i Reference: 1Q-04L1-O1 ~ i ' °~~~ -- Contains the following: 1 LDWG Compact Disc I~° (Includes Graphic Image files) ~- ~' ~`~° 1 LDWG lister summary 1 blueline - GR Measured Depth Log ~ _'_~ 1 blueline - GR TUD Log r r-' --'_ ~~ -- - - -- - ~~.- ~ ~- LAC Job#:.997967 '' ,; _. -- - _ ,. ~r, Sent By: Deepa Joglekar Date: Jan.10, 2007 - ,~, Received By: ~ _.~~~ ; ;~ -~...~_ ; Date: ,_~- , ` ' ~~ ~ - ~-- ``, -~• • i ~ - - - ~-~_ , . _ - _ . --~ ~,~ ,r PLEASE ACKNOWLEDGE RECEIPT BY SIGN ING & RETURNING ~-~= - -- ~ - OR FAXING YOUR COPY `' - - -- FAX: (907) 267-6623 ~- Baker Hughes INTEQ '~~ t 7260 Homer Drive ~~V ~~~ i j Anchorage, Alaska ~ - 99~ 18 ~~ ~~'J•~ Direct: (907) 267-6612 j - ~ FAX: (907) 267-6623 ~• ~`"~ '~:EIVED STATE OF ALASKA ALASK~L AND GAS CONSERVATION CC~IISSION REPORT OF SUNDRY WELL OPERATIONS '~```'„~ ~ 3 Zoos ~lasica C~`~ Gas Cons. Commission 1. Operations Performed: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Other ^ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: Conoco Phillips Alaska Inc. ®Development ^ Exploratory 205-140 - 3. Address: ^ Stratigraphic ^ Service 6. API Number: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21250-61-00 ° 7. KB Elevation (ft): 90, 9. Well Name and Number: Kuparuk 1Q-04L1-01 -~ 8. Property Designation: 10. Field /Pool(s): ADL 025634 Kuparuk River Unit /Kuparuk River Pool 11. Present well condition summary Total depth: measured 11270 ~ feet true vertical 6734 "feet Plugs (measured) None Effective depth: measured 11270 feet Junk (measured) None true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate Production Liner Liner 1168' 2-3/8" 10102' - 11270' 6716' - 6734' 11200 11780 Perforation Depth MD (ft); sbned sedbn: 10116' - 10269' Perforation Depth TVD (ft): 6717' - 6734' 3-1/2", 9.3# L-80 / J-55 9085' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Baker'FHL' retrievable packer; Baker'FHL' packer; Baker 8520'; 8504'; 9013' FB-1 packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. well Class after proposed work: ® Daily Report of Well Operations ^ Exploratory ®Development ^ Service ® Well Schematic Diagram 16. Well Status after proposed work: ® Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I ere y certi that t e oregoing is true an correct tot a best o my knowledge. Sundry Numbe or N/A if C.O. Exe t: Contact Steve Mukavitz, 263-4021 ~ WA Printed Name Terrie Hubble Title Technical Assistant i Phone /~ Prepared By Name/Number: v a i gnature S -4628 t Terr e Hubble, 56 564-4628 Date Form 10-404 Revised 04/2004 (~ °° 3~)l06 Submit Original Only tJ ~Q ~F~, `PiA~ ~ 6 100 ~~ ~, ,,r-_ a::~ BP Page 1 of '11; Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date From - To I Hogs Task Code NPT Phase Description of Operations 1/22/2006 06:00 - 07:00 1.00 MOB P PRE Warm up moving system, prep to move off well-weather 07:00 - 09:20 2.33 MOB P PRE worsening Place rig on Standby at 0700 hrs due to inclement weather and forecast for worse Send non essential personnel to KOC Presently -38F, 15-25 mph winds w/ -90 WC, Phz 1 09:20 -00:00 14.67 MOB P PRE Kuparuk start Phz 2 (-34F, 18-32 mph winds) 1/23/2006 00:00 - 10:30 10.50 MOB P PRE Use rig loader for crew changes Continue WOW Phz 2 (-9F, 18-32 mph SW, -40CF Phz 2 ~ 0600 hrs) 10:30 -00:00 13.50 MOB P PRE Kuparuk CPFi, CPF2, GPB go to Phz 3. CPF3 and GPB in Phz 2 1/24/2006 00:00 - 06:00 6 00 MOB P (-11 F, 32-46 mph WSW, -62CF w/ blowing snow, low visibility) . PRE WOW. Diminishing winds past midnight. Phase 1 on Spine Rd and still Phase III on access roads and pads. I 10 pad snowed in. Well Support group plans to clear off this 06:00 - 12:00 6.00 MOB P PRE morning. Clearing snow from around rig and camps also clearing 10 pad. Called AOGCC with 12-24hr BOP notice. 12:00 - 18:45 6.75 MOB P PRE Pull off 3H-14B. Do Post-Pad Inspection with DSO. Move camps to new location and spot. Rig on the road. Made it to CPF 3 at 1700hrs. Waiting for CP changeout. PJSM 18:45 - 20:45 2.00 MOB P PRE Rig arrived on location at 2040 hrs. Spotted near well 20:45 - 21:00 0.25 MOB P PRE Hetd PJSM on backing over well. 21:00 -22:00 1.00 MOB P PRE Move rig over well. Nordic crew change due to flights relays 22:00 -00:00 2.00 RIGU P PRE Rig Accepted at 22:00 hrs 1-23-2006. Leveling rig to pad 1/25/2006 00:00 - 01:15 1.25 RIGU P PRE Finished leveling rig. 01:15 - 01:45 0.50 RIGU P PRE PJSM 01:45 -05:00 3.25 RIGU P PRE RU cellar berm, cutting box, RU tiger tank, hardline to same and PT, off load 290 bb19.6 ppg NaCI brine water, RU to reverse circulate and pull BPV. 05:00 - 05:20 0.33 WHSUR P WHDTRE ' PJSM review hazards assosiated with lubricator and pulling BPV. Review plans for pumping diesel FP from wellbore 05:20 - 07:45 2.42 WHSUR P WHDTRE . PU CIW lubricator and pull BPV. 07:45 - 12:30 4.75 WHSUR P WHDTRE Hook-up circulation hoses to cellar manifold. Pump down IA 25bbls 9.6ppg brine displacing diesel. Switch and pump down tbg displacing diesel to Tiger Tank. 12:30 - 13:00 0.50 WHSUR P WHDTRE Set TWC (dry rod) 13:00 - 15:00 2.00 WHSUR P WHDTRE ND 3-1/8" 5M McEvoy tree. Checked LDS. Test hanger threads, made up 7 full rds. NORM tested tree and hauled to Valve Shop. 15:00 - 18:00 3.00 BOPSU P PRE NU 2' spacer spool and 7-i/16" BOP stack, choke/kill lines, and riser. This could take awhile. Very cold temps inside cellar even witlt heaters going. 18:00 -18:30 0.50 BOPSU P PRE AOGCC previously notified of test and wavied witnessing. Pre Wtxkover Meeting ctxtducted by S. Mukavitz 18:30 -22:30 4.00 BOPSU P PRE Finished NU BOP's and riser. Having problems with adaptor below riser, (rust) 22:30 -00:00 1.50 BOPSU P PRE BOP Test AOGCC Jeff Jones wavered witnessing BOP test Boots on riser failed while hydrostatic testing. Replacing 4 1!26/2006 00:00 -06:00 6.00 BOPSU P PRE boots on riser while testing some of choke manifold BOP testing and repaired riser boots Printed: 2/13/2006 12:02:20 PM BP Page 2 ofi 11 ~pelrations Summary Report Legal Well Name: 1 Q-04 Common Well Name: 1 Q-04 Spud Date: 10!7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date From.- To Hours Task Code NPT Phase Description of Operations 1/26/2006 00:00 - 06:00 6.00 BOPSU P PRE Leaks on Baker choke, bottom variables, top combi's and lock down screws. Lower Combi's tested Retested variables and upper combi and tested ok at accumulator set on L-Side pressure. IA open during testing. 06:00 - 08:00 2.00 WHSUR P DECOMP RU shooting nipple and SLB lubricator sections 08:00 - 08:30 0.50 WHSUR P DECOMP Call town for dispensation for not pulling TWC with lubricator. Granted. AA during BOP testing well was monitored for pressures or flow. None seen. WBP set at 8580'. Well was circulated earlier in the day and no gas was seen at surface. 08:30 - 08:40 0.17 WHSUR P DECOMP Pull TWC with dry rod. 08:40 - 09:20 0.67 PULL P DECOMP Clear rig floor of tools. MU 75t DP elevators. PU 1 jt 3-1/2' DP and TIW XO to 3-112" 8rd tbg. 09:20 - 10:00 0.67 PULL P DECOMP MU to tbg hanger. Clear floor and pull hanger to floor. Hanger unseated easily. After streach in tbg seen seal assembly i pulling through PBR at max pulls of 114k-120k. (blocks weigh 7K included) Control line came 1:1 to this point. 10:00 - 10:30 0.50 PULL P DECOMP LD hanger and pup jt. Change out elevators to 75t flat top tbg elevators. 10:30 - 13:30 3.00 PULL P DECOMP Pull on next jt #2. Should have cleared PBR bui still pulling tight at max pull of 125k. Lost about 8'-10' of control line length based on trying to pull 1:1. Working pipe to try and regain length. RU and circulate. Continue working pipe. Work pipe to next coupling, normal pulls around 90k last 10'. Control line coming freely but almost too freely. May have parted somewhere. LD jt tbg. Start pulling again and tight imediately. Work pipe up in stages another 15' with max pull of 125k (19k net). Pipe parted while pulling at 90k. After fixing catsass on draw works looks like we have 19K of pipe. That puts it close to the SSSV 13:30 - 20:30 7.00 PULL P DECOMP RU air slips. Pull and LD 3-1/2' tbg. Arrange for fishing tools, DP, DC's LD 98 jts (3067 ft) 3-1/2" 9.3#/ft J-55 Tbg, 1 SSSV and DGLM # 1 AN tubulars look good. Recovered all control line and 29 bands. Pulled out of 3-1/2' collar. Top of fish is a 4-1/2' tubing collar at approximately 3100 ft. Fill hole. Tubing displacement was correct on POOH. 1/27/2006 20:30 -00:00 00:00 -10:45 3.50 10.75 PULL PULL C C DECOMP DECOMP Unload 3-1/2' tubing in pipe shed and clean and RU rig floor. Loaded pipe shed with 3-1/2" 15.5#!ft X-95 DP and prep Steamed joints, drift and tally. RU floor tongs etc.. 10:45 - 11:00 0.25 PULL C DECOMP PJSM review pipe handling hazards and procedures. Assign job positons 11:00 -13:00 2.00 PULL C DECOMP PU fishing BHA #1 Finished working ~ change out of coil reel motor. 13:00 - 19:15 6.25 PULL C DECOMP PU 85 jts 3-1/2' DP and BHA 19:15 - 19:45 0.50 PULL C DECOMP Circulated welibore vdixne to clean up DP of scale. 19:45 - 21:30 1.75 PULL C DECOMP RIH and tagged the top of the fish at 3,124 ft. Seal Assemby has stabbed into the PBR. Set OS with 20k down and PU. PU wt = 31 k up and 25 k down. PU and fish started moving at 125,000 Ib. Pulled up from 3124 ft, 70 ft and something parted down hole. After enverything settled down, inspected the derrick, crown and rig footing. OK Printed: 2/13/2008 12:02:20 PM BP Page 3 of 11 Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1 Q-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/27/2006 21:30 - 00:00 2.50 PULL C DECOMP PU, string wt at the orginal wt of 30k up. OS grapple probably let loose POOH standing pack DP in the derrick. Ordered of 2.25" ID BS & Jars, alerted SLB to Chem cut. 1/28/2006 00:00 -00:45 0.75 PULL C DECOMP Finish POOH. Recovered some 3-1/2' production tubing 00:45 - 02:00 1.25 PULL C DECOMP LD fish BHA with 2" ID. Removed OS and changed out grapple. Change over to pulling and LD 3-1/2' production tubing. Recoverd 8 jts 3-1/2" tubing, GLM # 2 and 1 jts 3-1/2" below GLM A119 jts layed down were not torqued up. tt only took a 36" pipe wrench and 1 person to back out the threads witout any effort. Pulled out of 3-1/2" tubing collar Top of fish is a collar at approximately 3,386 ft Total out is 108 jts , 2 GLM and SSV with PJ out of hole. 02:00 - 03:00 1.00 PULL C t DECOMP Redress OS, RIH with OS and 6 DC (ID = 2.6" 03:00 - 06:30 3.50 PULL C DECOMP RIH with OS Tagged Fish at 3,381 ft. PU to 50 k and set OS PU TJ to neutral and break off single. PU to 50k set slips, tie-up handles, install safety clamps 06:30 - 07:45 1.25 PULL C DECOMP SWS arrive on location. RU head and string shot. 07:45 -08:00 0.25 PULL C DECOMP PSJM: Review procedures and hazards with stringshot and sheave.. 08:00 - 08:30 0.50 PULL C DECOMP RU sheave. Bring SS to floor, RIH with SS and MU line wiper with side entry sub. 08:30 - 10:20 1.83 PULL C DECOMP RIH w/ SS/CCUgr. Log gr/ccl f/ 6100'-6400'. Position SS 1-1/2 jts below 7th GLM. Fire SS 6264'-6275'. 10:20 - 10:40 0.33 PULL C DECOMP POH w/SS. Shot fired. 10:40 - 11:15 0.58 PULL C DECOMP RU Chemical Cutter on ground. 11:15 - 11:25 0.17 PULL C DECOMP Brief PJSM review hazards again witli all crews concerning chemical cutter. 11:25 - 16:30 5.08 PULL C DECOMP RIH with CC. Unable to enter DC's at 3200'. TOH. Inspect tool. Check OD's 2.120" but tool has upperAower centrilizers that are most likely hanging up. Make a 2.125' gauge run. No problems " through DC's. Remove upper centrilizer from CC and back-off tension on lower set allowing it to collapse easier. RIH w/CC make it though DC's ok, Stopped at 5300' due to angle of well. Pump at 1.8bpm and run CC to 6400'. Get correlated with SS log. Place cutter head at 6275'. That's 1-1/2jts below 7th GLM. Clear floor and fired CC. Good indication that it fired on the line only. TOH and cutter wouldn't come back through the DC's. Played with that for 112hr and made it through. Clear boor and remove chemical cutter from well. Stand back SWS equipment. 16:30 - 17:00 0.50 PULL C DECOMP Pick-up on string. (string wt prior to latching onto fish: 35k/up 30k/dn) Went past PU weight where CC was +/- extra 20K over string wt. Something came apart at 95K. Could have parted at cut. Have additi~al 10k over DP/DC string wt. and moving freely at 45K. LD 1 jt. Standback 1 stand. Note that string wts have never been what they should be. Most likey do to hole geometery. 17:00 - 17:30 0.50 PULL C DECOMP RD SWS. Good indication that the cutter worked. Tool intact. 17:30 -20:45 3.25 PULL C DECOMP TOH with fish.. 20:45 - 23:30 2.75 PULL C DECOMP Released OS and RU to pull & LD completion Most of the 3-1/2" tubing is bent to some degree. Some is Printed: 2/13/2006 12:02:20 PM BP Page 4 of '11 Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: :.Date From - To Hours Task Code NPT Phase Description of Operations i/2812006 20:45 - 23:30 2.75 PULL C DECOMP worst than others but its all bent and corkscrewed and basically not torqued to proper values LD 50 jts with 2 GLM 23:30 - 00:00 0.50 PULL C DECOMP Unloaded 50 jts 3-1/2" from pipe shed 1/29/2006 00:00 -00:30 0.50 PULL C DECOMP Unloading pipe shed of bent 3-1/2" completion tubing 00:30 - 02:00 1.50 PULL C DECOMP LD 3-1/2" Completion Recovered 90 jts of bent and corkscrewed tubing plus 12.5 ft cut off piece 02:00 - 03:00 1.00 PULL C DECOMP RU to run OS with DP 03:00 - 05:00 2.00 PULL C DECOMP RIH with Basket grapple with packoff on 3-1/2" DP 05:00 - 06:00 1.00 PULL C DECOMP Unload Pipe shed of cork screwed3-1/2" tubing 06:00 - 08:45 2.75 PULL C DECOMP RIH with 40 jts DP off pipe racks (4435.50') 08:45 - 10:30 1..75 PULL C DECOMP Bring in another 60jts DP. Clean, drift and strap. 10:30 - 14:30 4.00 PULL C DECOMP Continue RIH with jts from pipe rack to jt #198 (6250.37'). Vis up 9.6ppg brine. Install TIW valve and hook-up to circulate. I Change to 80 mesh shaker screens 14:30 - 15:15 0.75 PULL C DECOMP . Circulate above fish at 6.5bpm 270psi 15:15 - 16:50 1.58 PULL C DECOMP Make connection. String wt 49k up 35k dwn. Tag fish 5' in at 6255' . Workover fish while pumping 3bpm see inc in PP to 1600psi. Pull to 95k fish not moving while pumping. Remove circulation hose. Pull in stages to 130k which is 80k over string wt. Not in the mood to part this again. Call for SWS and chemical cutter 16:50 -22:30 5.67 PULL C DECOMP . Wait for SWS 22:30 - 23:45 1.25 PULL C DECOMP RU SLB 23:45 -00:00 0.25 PULL C DECOMP RIH with string shot and CCL 1/30/2006 00:00 -00:45 0.75 PULL DECOMP RIH and located GLM 8-9-10 and 1-1/2 jts below GLM # 10 Logged up to 7,603 ft and set string shot at 7 616 ft 00:45 - 01:10 0.42 PULL DECOMP , POOH 01:10 - 01:50 0.67 PULL DECOMP RU Chemical Cutter on Eline 01:50 - 02:30 0.67 PULL DECOMP RIH to 7,690 ft and logged up to 7,550 ft. RIH and Chem cut at 7,616 ft ,1-1/2 jts below GLM#10. With 12k pulled on string fired and had good surface indication 02:30 -04:30 2.00 PULL DECOMP POOH with Chemical Cutter. From 3,500 ft up, had to pump on DP side to collaspe the anchor arms on the chemical cutter. The arms were catching in TJ's. After 1,500 ft pulled nomlal 04:30 - 05:00 0.50 PULL DECOMP , RD Eline, PU on DP 50K, +5k over string wt 05:00 - 05:45 0.75 PULL DECOMP PU 30 ft and cir bottoms up at 6 bpm at 650 psi 05:45 - 11:00 5.25 PULL DECOMP POOH to fish. 11:00 -15:00 4.00 PULL DECOMP Service break OS. LD OS and 1/2jt. Unable to back-off OS from tbg. UD 42jts tbg and 3 GLM's. No bent jts. Seeing that 2-4 threads are showing On most connections above box. Did try on 1 jt to make-up to 1200fUlbs and took 5 nis. Rec make-up torque values are 1710 min 2280 optimum. Chemical cut looked normal. 15:00 - 16:00 1.00 PULL DECOMP Re-dress OS 16:00 - 21:15 5.25 PULL DECOMP RIH with 8HA #4 21:15 -23:15 2.00 PULL DECOMP PU and RIH with DP off pipe rack Total DP ~ 242 jts in hole up wt 76k dwn wt 48k 23:15 -00:00 0.75 PULL DECOMP Tagged the top of fish at 7633.5 ft with 23.5 ft in on jt# 242. RU circulating head and ar bottom ups at 6.0 bpm P = 626 psi 1/31/2006 0 0:00 -00:40 0.67 PULL C DECOMP Small amount of scale coming across shaker Grculating and cleaning wellbore Printed: 2/13/2006 12:02:20 PM rBP Page 5 of 11 Operations Summary Report Legal Well Name: 1 Q-04 Common Well Name: 10-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: ,, . Date From - To Hours Task Cotle NPT ..Phase Description of Operations- 1/31/2006 00:40 - 01:00 0.33 PULL C DECOMP Red Op to 3 bpm at 280 psi, worked over fish at 7,633 ft, pump pressure increased 100 psi. Set down with 10k Latched OS and pulled 10 k to confirm (OK) 01:00 - 01:15 0.25 PULL C DECOMP Circulated and held PJSM on RU Eline to run CCL conformation log. 01:15 - 03:00 1.75 PULL C DECOMP RU Eline to 8570 ft. Ran collar log 03;00 -04:15 1.25 PULL C DECOMP RIH with CCL to 8570 ft. PU ran collar log. Found all jewelry in tack. Same log as orginal log. 04:15 - 08:40 4.42 PULL C DECOMP POOH to re-position the aline sheave in the derrick. Get 15 ft bails from Rig 3 because our 8 ft bails are to short for eline hookup. 08:40 - 09:00 0.33 PULL C DECOMP PJSM with all crews. Review plan forward and hazards. Plan to PU on fish to max 90k wo CCL in string. Remove line wiper assembly from DP and secure e-line/sheave off to A leg drillers side. 09:00 - 10:00 1.00 PULL C 1 DECOMP Pull on fish to 125k several times - no movement. Pull to 150k have 1' of movement. Work pipe 6 times at this weight. No further movement. Pull to 158k and fish moving. Work several times and see seal assembly clear PBR. Continues to move 145-150k another 50' then tight. Pull very slowly and fish pops free of tight area, gained 3k over normal string wt. Continue pulling laying down total 5 jts. Fish pulling 78k to 130k range. Fluid not dropping from DP nor is the well swabbing, not loosing fluid either on backside. Strange. Bottom of fish (w/ 11' seal assembly) at 8400'. 10:00 - 11:30 1.50 PULL C DECOMP CBU at 3.1bpm 510 psi. Call town. Will RU SWS and run CCL after good circulation. Will look to see if packer is coming with fish. Could also have pulled lower seal assembly from packer at 9011'. Nothing over shaker after CBU. 11:30 - 12:30 1.00 PULL C DECOMP RU SWS line wiper and pump-in sub. RIH w/ CCL no gr tagged upon WRP. Results show we have the packer assembly and at least the 1st jt below it that the W PR is set in. Call town. POH with CCL. 12:30 -14:30 2.00 PULL C DECOMP Conference call with town on way forward 14:30 - 15:00 0.50 PULL C DECOMP RD SLB Eline and change out 188" bails 15:00 - 15:30 0.50 PULL C DECOMP PU on siring, started to move at 85k. Pull OOH between 85 to 100 k and sometime pull up to 120k (DP string wt's 75 k up) PUH with OS from 7482 ft to 7,415 ft. Stood stand in derrick Well not being swabbed only rise a few inches when pulling tighter 15:30 - 15:45 0.25 PULL C DECOMP PJSM with Halco WL on RU to conduct Drift and shift BP sleeve 15:45 - 17:00 1.25 PULL C DECOMP RU Halliburton WL. Install and test slickline lubricator. 17:00 -19:30 2.50 PULL C DECOMP Run in hole with drift. Tag WRP at 8376'. POOH. 19:30 -22:30 3.00 PULL C DECOMP Run WRP opening sleeve on slickline. Tag WRP at 8375'. Attempt to hold 100-200 psi pressure on tbg, then open WRP. Repeat several times. Nothing definitve as to whether valve opened or not. POOH. Tell tales on shifting tool indicate opening prong not engaged. Suspect fill. 22:30 -00:00 1.50 PULL C DECOMP Make up drive down bailer. Run in hole on slick line. Recover 1+ gallon of frac sand. 2/1/2006 00:00 - 01:00 1.00 PULL C DECOMP Make second run with slickline 2.25' bailer. Work down to Printed: 2/13/2008 12:02:20 PM BP Page 6 of 11. Operations Summary Report Legal Well Name: 1 Q-04 Common Well Name: 1404 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/1/2006 00:00 - 01:00 1.00 PULL C DECOMP 8379'. Recover another 1/2 gallon of sand and scale. No marks on baiter nose. 01:00 - 03:00 2.00 PULL C DECOMP Run a 2.25" od pump bailer, run #3. Recovered only scale from a depth of 8378'. 03:00 - 05:00 2.00 PULL C DECOMP Run #4 with bailer. Recovered scale ,sand and small keeper pin ? 05:00 - 07:30 2.50 PULL C DECOMP Run # 5 using 2" drive down bailer Tagged at 8,382 WLMD and worked down to 8,383 ft. POOH, recovered 1/2 gal scale. Had indication of WRP plug from tattle tale and marks on bailer 07:30 - 10:15 2.75 PULL C DECOMP Run #6 2-114 Pump bailer Tagged at 8383 ft. Worked several times POOH 10:15 - 11:45 1.50 PULL C DECOMP RIH # 7with tool to shift WRP sleeve. Tagged high at 8,378 ft. Pounded down several times. No indication at surface. POOH No indication from tattletales in shifting tool 11:45 - 13:30 1.75 PULL C DECOMP RIH run #8 with 2.25" pump bailer to clean up on top of WRP Tagged again at 8,379 ft WLMD. Working several times. Got to 8,380 ft WLMD. POOH Recovered < 1 pint of scale, frac sand and couple pieces of metal. 13:30 - 15:41 2.18 PULL C DECOMP RIH Run # 9 w/ 2" drive down bailer tagged at ~ 8378 ft (3 to 4 ft high) Something fell in when running the shifting tool. SLB is reheading to the small line in their Kuparuk Shop Recovered >1 pint of solid materal (scale, frac sand and small pieces of metal) Redressed (indicators) on 2" drive down bailer. 15:41 - 16:40 0.98 PULL C DECOMP RIH Run #10 w/ 2° drive down bailer, SLB been mobilized from Kuparuk. Tagged at 8,379 ft. Worked bailer several times. POOH 16:40 - 16:52 0.20 PULL C DECOMP Check bailer, flapper spring failed because the WRP stem was wedge up inside the drive down bailer. PU 2.27' shifting tool. SLB on location ready to RU if the WRP can't be equalized. 16:52 - 18:00 1.13 PULL C DECOMP RIH with shifting tool. Work down over WRP prong (we hope). POOH. Telltales indicate WRP should be equalized. 18:00 - 19:00 1.00 PULL C DECOMP Rig down Halibur slickline. Discuss cold weather operations and concerns. 19:00 - 19:45 0.75 PULL C DECOGAP Rig up to circulate. DP taking 1 bpm at 30-40 psi. Assume WRP is open. 19:45 - 20:45 1.00 PULL C DECOMP Begin to pull on fish. Able to move up hole at at 125k# up wt. Drops back to 30k#, then pull again to 120-125k#. Pull two stands, fish became stuck, unable to move up or down. Pull to 150k#. Fish moved up hole a few feet. Unable to to move again. 20:45 - 21:15 0.50 PULL C DECOMP Adjust draworks brakes. Discuss situation with town. Request SLB round up a chemical cutter. Hole began taking fluid, up to 20 bph. Order more brine from MI. 21:15 -22:00 0.75 PULL C DECOMP Pull up to 160k# several times. Pulling at 155k# when something came loose. Weight indicator came loose off dead line. 22:00 -22:30 0.50 PULL C DECOMP Repair weight indicator. 22:30 -00:00 1.50 PULL C DECOMP Pult out of hole with fish. 115k# up weight, with drag fluctuations of +/- 5k#. 2/2/2006 00:00 -04:30 4.50. PULL C DECOMP Continue to pull out of hole. Hole fill normal. Pipe pulling smoothly. Pull 118 stands and one single. 04:30 -06:45 2.25 PULL C DECOMP Rig up floor to handle recovered tubing. Release from overshot. LD 3-1/2" tbg fish. Printed: 2/13/2006 12:02:20 PM BP Page 7 of 11 Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date.... From - To Hours Task Code NPT Phase Description of Operations 2/2/2006 06:45 - 08:00 1.25 PULL C DECOMP POOH and LD 1 3-1/2" cut off section 14 jts 3-1/2" tubing GLM # 11 9 jts 3-1/2" tubing Total length lay down = 742.31 ft Top of fish is a 3-1/2' collar. 4 jts 3-1/2" tubing on top of GLM # 12. Approximately top of fish at 8,381 ft, if stung back into packer at 9,012 ft 08:00 - 09:30 1.50 PULL C DECOMP Slip and cut 49.75 ft drlg line 09:30 - 12:00 2.50 WHSUR C DECOMP RU hose to IA with transducer to keep hole full and monitor pressure while conducting BOP test. 12:00 - 15:00 3.00 WHSUR X SFAL DECOMP BOP Test Mcevoy Gen III test plug leaked. Call for replace from Drilling Stores. PT to 250/3500 psi wittnessed by John Crisp AOGCC. Test other surface equipment while waiting for l test plug. 15:00 - 19:30 4.50 WHSUR C DECOMP Test BOP stack. No failures. Test witnessed by Hildreth & Goodrich. 19:30 - 20:30 1.00 PULL C DECOMP Rig up Halliburton slickline unit. 20:30 - 21:00 0.50 PULL C DECOMP Hold PJSM mtg with SLB, Nordic, and Halliburton hands. Discuss jog, assignments, contingencies, well control, and hazards. Also discuss cold weather operations. 21:00 - 23:30 2.50 PULL C DECOMP MU impression block tool assemby (2.70" od lib). Run in hole. Set down at 8186', then continue and tag solid at 8265'. POOH. Found evidence of fill on LIB. Did not tag WRP stem. Fish has not fallen back down hole. It is +/- two stands of DP or 124' further up hole than during previous slickline tags on WRP. WRP was at +/-8380' on previous tags, is now at +/-8265'/ 23:30 -00:00 0.50 PULL C DECOMP Make up bailing assembly. Run in hole. 2/3/2006 00:00 - 01:15 1.25 PULL C DECOMP Run in hole witl12"drive bailer assembly. Tag again at 8265'. Pull out of hole. Found several cups of flat metal pieces. 01:15 - 02:30 1.25 PULL C DECOMP Run 5` LIB. Tag tubing fish top at 805T. Pull out of hole. Clear evidence of 3-/1/2` tbg collar impact. 02:30 -04:00 1.50 PULL C DECOMP Run 2-1/2" pump bailer. Tag at 8263'. work bailer. Pull out of hole. Recovered several cups of metal and debris. 04:00 -08:00 4.00 PULL C DECOMP Run 2-1/2' pump bailer. Set down at 8265'. Work bailer. Worked bailer down to 8266 ft. POOH and recovered scale, small pieces of brass. 08:00 - 09:00 1.00 PULL C DECOMP RIH and bailed sveral times without gaining any footage. POOH Recovered small amount scale and damaged the flapper (over the WRP stem) 09:00 - 10:45 1.75 PULL C DECOMP RIH w/ 2-1/4" pump bailer 10:45 - 11:00 0.25 PULL C DECOMP R1H with Equalizing Prong and set down at 8,265 ft. Worked down several time 11:00 - 12:45 1.75 PULL C DECOMP POOH 12:45 - 13:30 0.75 PULL C DECOMP RIH with WRP retrieving tool and latched up at 8,265 ft. Jarred on for 20 min up to 1500 Ib. Sheared off GD bait sub (22") and left in the hole Didn't see much movement on WRP plug 13:30 - 15:30 2.00 PULL C DECOMP POOH and redressed GD pulling tool and PU 5 ft wt bar, RIH and latched up at 8265 ft. Jarred on for 10 min and JD tool sheared. POOH 15:30 - 16:00 0.50 PULL C DECOMP Dress GS retrieving tool and redress oil jars Printed: 2/13/2006 12:02:20 PM BP Page 8 of 11 Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1 Q-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date Frorn - To Hours Task Code NPT Phase Description of Operations 2/3/2006 16:00 - 16:30 0.50 PULL C DECOMP RIH with "GS" Latched GS on WRP plug 16:30 - 17:30 1.00 PULL C DECOMP Jarred on plug from 6001b to 1900 Ib without any movement for 1 hr 17:30 - 18:00 0.50 PULL C DECOMP Sheared down to release GS from GD baited sub. POOH with wireline tools 18:00 - 18:30 0.50 PULL C DECOMP PJSM. Rig down Halliburton slickline. 18:30 - 19:30 1.00 PULL C DECOMP MU 4.5" overshot assembly. 19:30 -00:00 4.50 PULL C DECOMP Run in hole with 3.5" dp. Pick up 30 singles. 2/4/2006 00:00 - 02:00 2.00 PULL C DECOMP Continue to RIH with overshot on 3-1/2" dp. Pick up 30 singles. 02:00 - 02:15 0.25 FISH C DECOMP Jt #254. Up wt 122k#, do wt: 63k#. PU 6' pup. Engage fish 4' in on pup. Clear four and prep to RU SLB a-line. 02:15 - 03:00 0.75 EVAL C DECOMP Wait on SLB to repair broken cable spooler head. 03:00 -03:30 0.50 EVAL C DECOMP Hold PJSM with SLB and Nordic crews. Discuss job, well I control, assignments, communications, safe briefing area, hazards & mitigation of same. 03:30 -04:15 0.75 EVAL C DECOMP RU SLB a-line. 04:15 - 05:00 0.75 EVAL C DECOMP Run CCL tool to locate WRP and packer. Tag WRP. 05:00 - 05:30 0.50 EVAL C DECOMP Log CCL up above overshot assy. 05:30 - 06:30 1.00 EVAL C DECOMP SLB stopped CCL at 200 ft from surface. Held PJSM after crew change. POOH with CCL. There is 12 ft below the packer to top of the WRP 06:30 - 09:30 3.00 FISH C DECOMP RU to run tubing punch. Tie in and tagged WRP at 8260 ft. Perf 8255.5 ft to 8253.5 ft 10 (holes) Well went on vacuum. Fill hole, took 21 bbl to fill hole (797 ft) Circulated down annulus tossing 1.25 bpm and improved to 0.78 bpm in 30 minutes. loaded DP and cir well before RD SLB 09:30 - 11:45 2.25 FISH C DECOMP RIH with string shot. Fired across collar at 8221 ft POOH, SLB having trouble with their counter/encoder Losing 0.4 to 0.25 bpm following the tubing punch. 11:45 - 13:00 1.25 FISH C DECOMP SLB RU Chem cutter 13:00 - 17:00 4.00 FISH C DECOMP RIH and tied in . PU and set Chem cutter at 8,119 ft and shot. PUH cutter stuck in collar at 8,150 ft. Worked several times and pump down DP at various flowrates. After talking to SLB, decided to pull out of weak point. PU to 2100 Ib and toot pulled free. Pulled up to next collar and had to work through. PUH to below OS and took several attempts to work through. POOH smoothly through drill pipe. LD tool, 3 out of 6 anchors still eMended. LD Tool 17:00 - 18:30 1.50 FISH C DECOMP POOH with DP and fish. PUH at 118k to 123k somewhat ratty. Getting better after 5 stands. Hole not losing any fluid prior to POOH 18:30 - 19:45 1.25 RIGD C DECOMP Rig down pressure control equipment stood back on rig floor. (lubricator and slickline unit). Store in pipe shed. This frees up a lot of room in pipe rack area. 19:45 -00:00 4.25 FISH C DECOMP Continue to POH with tbg fish. 2/5/2006 00:00 - 01:00 1.00 FISH C DECOMP Continue to POH with cut tubing fish. 01:00 - 01:30 0.50 FISH C DECOMP Break out overshot from fish. LD BHA and single. 01:30 - 02:15 0.75 FISH C DECOMP POOH and LD: 4 full jts 3-1/2 tbg Printed: 2/13/2006 12:02:20 PM BP Page 9 of 11 Operations Summary Report Legal Well Name: 10-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date from - To Hours Task Code NPT Phase Description of Operations 2/5/2006 01:30 - 02:15 0.75 FISH C DECOMP GLM #12 with pups 1 cut jt 3-1/2" tbg Total length: 162.11 Top of fish estimated to be at 8219'. Chemical cut was fairly clean, with a smooth od. According to the tbg talley, the tbg stub above the collar looking up is 4.13'. Upper joint recovered was slighly corkscrewed. 02:15 - 03:00 0.75 FISH C DECOMP MU overshot assembly with bumper sub, jars, and drill collars. Add extra extension to overshot to cover cut stub length. 03:00 -09:50 6.83 FISH C DECOMP Run in hole with fishing BHA. Tagged top of fish at 8215 ft with 253jts+16.5ftinonjt#254 09:50 - 10:25 0.58 FISH C DECOMP RU Cir sub and Cir at 4 bpm and work over fish at 8215 ft. SD pumps and lached fish and set grapple. 10:25 - 10:50 0.42 FISH C DECOMP With up wt at 132k and down wt at 66k. Jarred down on fish ( from 140k to 45k 27 times and no movement seen at surface 10:50 - 11:10 0.33 FISH C DECOMP SD cool. brake and circulate well at 4 bpm 11:10 - 12:00 0.83 FISH C DECOMP Jarred on fish Total are 60 times down and 11 up. Maybe a foot of movement 12:00 - 18:00 6.00 FISH C DECOMP Cir and mix 1-1/2 ppb Bio pill. Op = 4.0 bpm at 2043 psi Jarred another 11 times down and the packer moved down the hole 18 ft. PU and unable to come up the distanced traveled down. PU singles starting at jt 254. RIH and tried to PU offen and was unable to PU Max PU at 240 k .Jarring from 140k to 240 k and jarring down from 140 k to 40k. Worked down to 8961 ft with 263 jts DP in the hole. BHA includes the top packer and tail pipe. BHA len = 686.39. Tagged someting hard at 8961 ft. 18:00 - 21:00 3.00 FISH C DECOMP RU to cir at 8961 ft. Circulate at 1.8 bpm at 1150 psi. Occaisional spikes in pump pressure. Not sure why. 1:1 rtns. CBU. No solids noted over shaker. Discuss plan with town. Decide to end fishing ops. Rig down circulating head. 21:00 -22:30 1.50 FISH C DECOMP Work pipe and rotate string to the right to release overshot. 22:30 - 23:00 0.50 FISH C DECOMP Remove extra pipe and kelly from pipe shed. 23:00 -00:00 1.00 FISH C DECOMP Pull out of laying down drill pipe in singles. 2/6/2006 00:00 - 10:45 10.75 FISH C DECOMP Continue to pull out of hole, laying down drill pipe. 10:45 - 12:00 1.25 FISH C DECOMP LD 6 DC and fishing tools. Inspected grapple and stop. The stop is 4" ID (confirmed) 3.37 ft from bottom. 2-5-3/4' extension above that at 6.65 ft 12:00 - 13:00 1.00 FISH C DECOMP Load out fishing tools and make ready to bring in tubulars. RU wireline for evaluation on tubing stub and drift tubing and parker for integrity to WRP 13:00 - 13:30 0.50 EVAL C DECOMP RU Hallibuton WL white loading tubulars 13:30 - 14:00 0.50 EVAL C DECOMP RIH with 5-1/2" UB and tagged at 8490 ft WLMD. POOH and had a picture of a 3-112' stub perfectly round 14:00 - 14:45 0.75 EVAL C DECOMP RIH with a 2.19" LIB and centralizers to check the drift RIH and set down at 8,494 ft, 4 ft inside of stub (collar). POOH to look at 2.19' LIB Starling to load row 2 in pipe shed of 3-1/2" tubing at 1600 hrs. Marks on the high side and small marks( frac sand) on bottom of 2.19" LIB 14:45 - 17:30 2.75 EVAL C DECOMP RU and RIH with 1-3/4' drive down bailer to get sample of fill. Printed: 2/13/2008 12:02:20 PM gp Page 10 of 13 Operations Summary Report Legal Well Name: 10-04 Common Well Name: iQ-04 Spud Date: 10!7!2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 2/6/2006 14:45 - 17:30 2.75 EVAL C DECOMP Tag at 8494' Still loading pipe shed (2 rows in) 17:30 - 18:30 1.00 EVAL C DECOMP No recovery in bailer. Locate additional slickline tools: a larger bailer with a mule shoe. 18:30 - 20:30 2.00 EVAL C DECOMP Run 2.25' pump bailer with 2.79 od centralizer. Work deeper than smaller bailer, at 8506'. This is 6' below top of PBR above FHL packer. POOH. Found several cups of scale and frac sand in bailer. Continue to load pipe shed with 3-1/2" tbg. 20:30 - 22:30 2.00 EVAL C DECOMP Run 6.0" od gauge ring and junk basket. Tag tbg stub at 8490'. Pull out of hole. Small amount of scale in junk basket. RD Halliburton. 22:30 -00:00 1.50 BUNCO RUNCMP Continue to load strap, and drift 3-1/2" tbg in pipe shed. 2/7/2006 00:00 - 03:00 3.00 BUNCO RUNCMP Continue to load pipe shed with 3-1/2' tubing. Drift, strap, and install seal rings in same. RU floor to run completion. 03:00 - 18:00 15.00 BUNCO I RUNCMP Run 3-1/2" EUE 8rd-m tubing completion w/ overshot, nipple, FHL pkr, pbr, sliding sleeve, 5 GLMs and nipple. 18:00 - 21:00 3.00 BUNCO RUNCMP Tag up on stub at 8490' w/ OS and see shear pins shear while fully swallow to wt loss. PU 2' off bottom at 62k. Drop ball-on-rod and wait to fall to RHC plug. Pressure up on tubing and see packer start to set at 1600 psi. Incr press to 3000 psi and hold for 20 min. Pull out of PBR at 66k and dump pressure. LD one jt, add 3 pups to allow slickline ops to work from floor level starting point and be stung into PBR up to 1' 21:00 -22:00 1.00 WHSUR P RUNCMP Safety mtg re: RU/WL ops Bring HES tools to floor. RU on top of tubing pup w/ XO, PIS and packoff 22:00 -00:00 2.00 WHSUR P RUNCMP RIH and recover ball-on-rod at 8937' WLM RIH to recover RHC plug 2/8/2006 00:00 - 03:15 3.25 WHSUR P RUNCMP Fin pull RHC plug from 8937' WLM RIH and set X plug at 8937' WLM. POOH. PT plug to 1000 psi 03:15 -03:45 0.50 WHSUR P RUNCMP RDMO HES WL 03:45 -06:00 2.25 WHSUR P RUNCMP PUH 62k and LD 2 ea 10' and 1 ea 4' pups, plus 2 jts tubing. MU RTTS w/ storm valve on one pup and one full jt 3-1/2 DP. RIH 39k and set RTTS at 35' RKB (7' below spool). PT above RTTS to 1000 psi against blind/shear rams 06:00 - 09:00 3.00 WHSUR P RUNCMP ND riser. ND BOPS. Lift using bridge crane in cellar. 09:00 - 13:30 4.50 WHSUR P RUNCMP Verity OA pressure is bled off. ND tubing spool. Back out LDS for OA packoff/slip assembly. One LDS sheared off. Prep casg spool for replacement plug in LDS port. Pull pack off assembly. 13:30 - 18:30 5.00 WHSUR P RUNCMP Install replacement OA packoff assembly. NU new tubing spool. Inject plastic sealant into packoff void and seals would not energize 18:30 - 20:40 2.17 WHSUR N RUNCMP ND tubing spool and remove packoff assy. Packoff was for larger diameter casing 20:40 - 21:30 0.83 WHSUR N RUNCMP Wait on CIW to get correct packoff from Kup whse 21:30 -00:00 2.50 W HSUR N RUNCMP Install OA packoff assy. NU new tubing spool Fin clean pits 2/9/2006 00:00 - 01:45 1.75 WHSUR N RUNCMP Fin NU new tubing spool. Inject sealant into void and test packoff at 3000 psi 01:45 -04:45 3.00 WHSUR P RUNCMP NU BOPE and riser. Fill stack and riser. Connection at top of Hydril leaked Printed: 2/13/2006 12:02:20 PM BP Page 11 of 11 Operations Summary Report Legal Well Name: 10-04 Common Well Name: 10-04 Spud Date: 10/7/2005 Event Name: WORKOVER Start: 1/22/2006 End: 2/10/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/9/2006 04:45 - 05:15 0.50 WHSUR N RUNCMP ND riser and fix leak. FiII riser 05:15 - 05:40 0.42 WHSUR P RUNCMP PU RTTS pulling tool and latch up to RTTS. Close annular PT above RTTS to 3000 psi for 10 min to check flange connection 05:40 -06:30 0.83 WHSUR P RUNCMP Release RTTS and check for pressure. POOH w/ RTTS, LD and load out 06:30 - 09:00 2.50 BUNCO RUNCMP PU singles and btm out in PBR assembly. Determine space out. LD 3 singles. PU space out pups and top full joint, with hanger & pup assembly. 09:00 - 10:00 10:00 - 11:00 1.00 1.00 BUNCO BUNCO RUNCMP RUNCMP Spot 20 bbls inhibitied brine above PBR and inside tubing. RIH wwhile circulating at 0.5 bpm. Note pressure increase as seal assembly entered PBR. SHut do pumps. Bleed off. Slack off and land tbg. 62k# up wt, 38k# do wt. RILDS. 11:00 - 13:30 2.50 BUNCO RUNCMP Pressure test tubing to 3000 psi for 30 minutes. Chart test. Bleed tbg to 2000 psi. Pressure IA to 3000 psi. Hold and chart I for 30 minutes. Bleed IA and tbg to zero. Pressure IA. RP valve sheared at 1800 psi. 13:30 - 20:00 6.50 WHSUR P RUNCMP Back out and LD landing joint. Set two way check in tbg hanger. ND riser and BOPE. Remove from cellar. Remove excess pipe and materials from pipe shed. 20:00 - 00:00 4.00 WHSUR P RUNCMP NU adaptor flange and tree and PT ~ 3000 psi. Bring HP lubricator to floor to pull TWC-has 7" Otis and needs 4" 2/10/2006 00:00 - 01:30 1.50 WHSUR N RUNCMP WO Kup valve shop to bring XO to HP lubricator Continue loading trailers and prep for move 01:30 - 03:15 1.75 WHSUR P RUNCMP RU XO to lubricator and pull TWC 03:15 - 06:00 2.75 WHSUR P RUNCMP Safety mtg w/ LRS. RU cellar manifold and LRS. LRS pump 71 bbls 80 deg diesel down the IA at avg 2.0/950 and take 9.6# brine returns to tiger tank. RDMO LRS. Let diesel U-tube to tubing to FP to 2000' 06:00 - 07:00 1.00 WHSUR P RUNCMP Set BPV. Secure tree in cellar. Remove circ lines. 07:00 - 08:30 1.50 RIGD P POST Finalize prep for move. Secure tubulars in pipe shed. Load out additonal equipment to BP Stores. Hold PJSM in pump room 1 to review move off well. Rig released at 0830 on 2/10-06. Printed: 2/13/2006 12:02:20 PM (~~~ ConocoPhillips Alaska, Inc. 1li~l.~ , KRU 1Q-04L1-01 1 f2-04L1-01 API: 500292125061 Well T : PROD An le TS: d SSSV T : NIPPLE Ori Com lotion: 11/5/2005 An le TD: 93 d 11270 Annular Fluid: Last W/O: 2/10/2006 Rev Reason: GLV C/O Reference L 33' RKB Ref Lo Date: Last U ate: 2/24/2006 - Las[ Ta TD: 11270 ftK8 Last Ta Date: Max Hole An le: 95 d 10977 _ ~ Casin Strin -COMMON ST RINGS Descri lion Size To Bottom TVD Wt Grade Thread SURFACE 9.625 0 4622 3571 36.00 PRODUCTION 7.000 0 9511 6710 26.00 CONDUCTOR 16.000 0 103 103 62.50 - L7-03 LINER TOP 2.650 9061 9167 6663 4.60 STL L1-03 SLOTTED LINER TOP 2.650 9167 10102 6716 4.60 STL ~_ Casin Strin - L1-01 SLOTTED LINER NOT ACCESSIBLE FOR WELLWOR Descri lion Size To Bottom TVD Wt Grade Thread L1-O7 SLOTTED LINER 2.375 10102 11270 11270 4.60 L-80 STL I 1 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 9085 6621 9.30 J-55 EUE 8rd Pertorations Su mma Interval TVD Zone Status Ft SPF Date T Comment 8709 - 8719 6347 - 6354 10 12 4/24/2005 IPERF 120d h~ 5" Scallo HDC 8722 - 8726 6357 - 6360 4 12 4!24!2005 IPERF 120d h• 5" Scallo HDC 8735 - 8740 6366 - 6370 5 12 4/24/2005 IPERF 120d h• 5" Scallo HDC 8742 - 8753 6372 - 6380 11 12 4/24/2005 IPERF 120d h' S" Scallo HDC 8756 - 8764 6382 - 6388 8 12 4/24/2005 IPERF 120d h' S" Scallo ed HDC 8771 - 8777 6393 - 6398 6 12 4/24/2005 IPERF 120d h' S" Scallo ed HDC 8834 - 8881 6440 -6475 47 12 4/24/2005 IPERF 120d h' S" Scallo ed HDC -- 8914 - 8928 6499 - 6509 14 12 4/24/2005 IPERF 120d h• 5" Scallo ed HDC 10116 - 11268 6717 - 6735 1152 99 11/1/2005 Slots Lt-01 SLOTTED LINER Gas Lift Ma ndr elsNalves _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VN Cmnt 1 3031 2524 CAMCO MMG GLV 1.5 RK 0.188 1314 2/15!2006 2 5402 ~ 4064 CAMCO MMG GLV 1.5 RK 0.188 1307 2/15/2006 3 6935 5050 CAMCO MMG OV 1.5 RK 0.188 0 2/15/2006 ___. ___ 4 7871 5724 CAMCO MMG DMY 1.5 RK 0.000 0 2/10/2006 5 8303 6042 CAMCO MMG DMY 1.5 RK 0.000 0 2/15/2006 Prod uction Mandr elsNalve s St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 6 8542 6221 CAMCO MMG-2 DMY 1.5 RKP 0.000 0 5/6!2005 7 8612 6274 CAMCO MMG-2 DMY 1.5 RKP 0.000 0 5/7/2005 8 8910 6496 CAMCO MMG-2 DMY 1.5 RKP 0.000 0 1!28/2003 Other lu s ul .etc. -POST 2/10/2006 WO RKOVER De th TVD Tee Descri lion ID 490 490 NIP CAMCO'DS' LANDING NIPPLE 2.875 8359 6084 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 8406 6119 PBR/SBR BAKER 80-40 PBR/SBR 2.970 8420 6130 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 8431 6138 NIP HES'X' NIPPLE 2.913 8454 6155 OVERSHOT UNIQUE POORBOY OVERSHOT 3.625 Other lu s ui .etc. - POST 11/6!2005 WORKOVER De th TVD T e Descri lion ID 8490 6182 PBR BAKER PBR 2.992 8504 6193 PACKER BAKER'FHL'PACKER 3.000 8746 6375 Blast Rin s 2.992 8777 6398 Blast Rin s 2.992 -- 8806 6419 Blast Rini 2.992 8950 6525 LOCATOR ___ _ _______ BAKER LOCATOR SUB w/5' SEALS 3.000 - 9013 6571 PACKER BAKER'FB-1'PACKER 4.000 9021 6577 CEMENT CEMENT PLUG FOR UPCOMING SIDETRACK set 10/7/2005 0.000 9051 6598 NIP CAMCO'D' NIPPLE w/NO GO PROFILE 2.750 9064 6608 L1-03 Deploy SLV BTT SEAL BORE DEPLOYMENT SLEEVE w/3" GS PROFILE, set 10/7/2005 1.920 9066 6609 Window L1-03 WINDOW TO L1-03, L1-02, L1-01, Lt 6.151 General Notes Date Note 11/6/2005 SIDETRACKED MULT-LATERAL WELL w/FOUR LATERAL LEGS; ONLY L1-03 ACCESSIBLE -SEE SCANNED DRAWING TUBING 2/10/2006 MULTIPLE TUBING LEAKS FOUND FOLLOWING CTD WORK - WORKOVER wlTUBING CUT 8 NEW TUBING, w/POORBOY OVERSHOT STABBED INTO REMAINING PORTION OF ORIGINAL COMPLETION OF 11/6/2005 (0-9085, OD:3.500, ID:2.992) I Perf = ~ ~ ~ ;10116.11268) - ~I. 1 - _ ~ = i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~SION RECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND LOG JAN 2 0 2006 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. I ®C~evelopmerl~ftmt@aQbratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 11/5/2005 ~ 12. Permit to Drill Number 205-140 ` 3. Address: do P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/27/2005 ' 13. API Number 50-029-21250-61-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11!1/2005 14. Well Name and Number: Kuparuk 1Q-04L1-01 1227 FNL, 1057 FEL, SEC. 26, T12N, R09E, UM Top of Productive Horizon: 1473' FSL, 4106' FWL, SEC. 24, T12N, R09E, UM g. KB Elevation (ft): 90' 15. Field /Pool(s): Kuparuk River Unit /Kuparuk River Pool Total Depth: 3302' FSL, 4759' FWL, SEC. 24, T12N, R09E, UM 9. Plug Back Depth (MD+TVD) 11270 + 6734 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528566 ~ y- 5984646 'Zone- ASP4 10. Total Depth (MD+TVD) 11270 + 6734 ~ Ft 16. Property Designation: ADL 025634 TPI: x-_ 533717 y- 5987368 Zone- ASP4 Total De the x- P 534362 - Y- 5989200 'Zone- ASP4 11 • Depth where SSSV set 1815` MD 17. Land Use Permit: -------^-- --------_----- -----~~---- -- f f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL rost 20. Thickness o Perma 1400' (Approx.) 21. Logs Run: f<~i'' ~,/ l~ ~ ~31~, ~,~~7~ ~~7ti'~ MWD, GR ' ,6~ /~ ~ 3 c~s~., 2. CASING, LINER AND EMENTING ECORD CASING INCi Er'TH MD ETTIN(i EPTH TVD .HOLE MOUNT`v -SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 2-3/8" 4.6# L-80 10102' 11270' 6716' 6734' 3" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TuBIN~ RECORD Bottom Interval, Slze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-318" Slotted Section Note: ~ 3-1/2", 9.3#, J-55 9085' 8566' & 9013' MD TVD MD TVD 10116' - 10269' 6717 - 6734' Well Branch Well Branch 1 Q-04L1-01 1 Q-04L1-01 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Departs From Is not Directly W B h ib DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED ell ranc Access le iQ-04L1-03, PTD # 205-167, at 10099' MD ~ (6716' TVD) 26• PRODUCTION TEST Date First Production: Reported on iQ-04L1-03 ` Method of Operation (Flowing, Gas Lift, etc.): See iQ-04L1-03 10-407 (Dated 01-19-06, PTD 205-167) for Production & Test Data Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". fit, , ~~, °~°~ None t ~ ~_ ,~' ;'Ltd Form 10-407 Revised 12/2003 ` ~ i ~ ~ i N DON REVERSE SIDE ;~t ~~ ~ ~, 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. list intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk A3 9200` 6679' None - 30. List of Attachments: Summary of Daily Dritiing Reports, W eil Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. //~~ l Signed ~ Title Technical Assistant Date V ~ t ~.r Terrie Hubble Kuparuk 1 Q-04L1-01 205-140 Prepared By Name/Number. Terre Hubble, 564-4628 Welt Number Permit No. / A rOVal NO. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeaa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITean 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. ITeaA 4b: TPI (Top of Producing Interval). bean 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. bean 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEan 20: True vertical thickness. bean 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool bean 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). Irene 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersib{e, Water Injection, Gas Injection, Shut-In, or Other (explain). ITenn 27: if no cores taken, indicate "None". ITean 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP Page 1 of 16 Operations Summary Report Lega{ We{I Name: 1Q-04 - Common Well Name: 1 Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours 'Task' Code NPT Phase Descrip#ion of Operations 10/14/2005 13:00 - 14:00 1.00 MOB P PRE Continue to prep rig to move off welt 1 B-15. 14:00 - 14:15 0.25 MOB P PRE PJSM prior to moving off well. 14:15 - 14:35 0.33 MOB P PRE Move rig off well, and down to the entrance of 1 B pad. 14:35 - 15:00 0.42 MOB P PRE Spot rig at entrance to pad. Repair pressure gauge that is not reading properly. 15:00 - 15:15 0.25 MOB P PRE Pre move safety meeting with rig crew, Toolpusher, SLB Team Leader, BP WSL, and a representative from the Kuparuk drilliing toolhouse. 15:15 - 20:15 5.00 MOB P PRE Move rig from 16 pad to 1Q pad in Kuparuk. Stop move near KRU warehouse to allow field crew change out. 20:15 - 23:00 2.75 MOB P PRE Rig on 10 Pad. Found subsidence around mouse hole. Filf in with extra gravel. 1 O Pad operator and Toolpusher performed pad inspection. Continue to spot rig mats and plywood as a precaution due to poor location conditions around well head. Hold PJSM with crew. Spot rig over well. Accept rig at 2300 hrs on 10-14-05 23:00 -00:00 1.00 RIGU P PRE Spot cuttings tank. NU BOPs. 10/i512005 00:00 - 03:15 3.25 RIGU P PRE Continue to rig up on location. Spot and berm flow back tank. Berm cellar area. Take on fresh water for BOP test. Load pits with 8.6 ppg flo pro for mill out. Rig up com and power lines to camps. Measure BOPs and tree. Pressure test BOP body. Check injector chains. Found many loose bolts on tree flanges. Checked entire tree and tightened as required. 03:15 - 05;15 2.00 BOPSU P PRE Pressure test BOPs. Witnessed by BP WSL Gary Goodrich. 05:15 -06:15 1.00 BOPSU N WAIT PRE Shut down BOP test for 1 hour to allow BP WSL's to change out and to conduct Technical Limits Pretour meeting with oncoming crew. 06:15 - 08:15 2.00 BOPSU P PRE Resume BOP test. Witnessed by BP WSL Greg Sarber. Pressure test 2-318" combi's, bag, and perform drawdown test. All passed ok. AES support crew hooked up control panel to SSSV. 08:15 - 08:40 0.42 STWHIP P WEXIT PU WF motors for milling window. Open MV and SV. Well is dead. 08:40 - 09:10 0.50 STWHIP P WEXIT Prespud meeting with all rig hands on location, TL, TP, WSL, 2 W F hands. 09:10 - 10:30 1.33 STWHIP P WEXIT NU hardline from rig choke line tq-tiger tank. PT to 3500 psi. 10:30 - 11:00 0.50 STWHIP P WEXIT Make up BHA #1. D331 DSM, WF 1.75 deg motor. BHI Coiltrack MWD BHA with orienter, GR and CCL. 11:00 - 13:20 2.33 STWHIP P WEXIT RIH with BHA #1. Pump SSSV open with panel. Continue RIH, displacing gas cut diesel and seawater OOH. 13:20 - 14:50 1.50 STWHIP P WEXIT RIH and tag top of cement at 9048', uncorrected. PUH laying in mud to start our tie in logging pass. Pumping 1.5 bpm thru an open EDC. Log tie in pass down over GR character from 8885'. Make -8.5' correction. Relog same interval to check our correction due to critical nature of the window. Log was right on depth. Make CCL pass accross mandrel at 8660', log down and dry tag at 9039'. Check CCL vs jewelry log from SWS Memory tee CCUGR of 10-6-2005. CCL log exactly on depth to ref log. 14:50 - 18:15 3.42 STWHIP P WEXIT SI pumps. Shut EDC. Kick on pumps to 1.5 bpm. Free spin is 3250 psi at 1.5 bpm. Tag top of cement at 9038.3'. Paint flag. Printed: 71!7/2005 9:58:20 AM BP Page 2 of 16 Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 10-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5!2005 Rig Name: NORDIC 2 Rig Number: Date "'From - To Hours Task .Code. NPT `Phase Description of-0perations 10/15!2005 14:50 - 18:15 3.42 STWHIP P WEXIT Begin milling cement. 1.55/1.55/3500 psi. Initial ROP=16 fph. String wt =4400 lbs. DHW06=20001bs. Mill ahead. Exit tbg tail at 9072' holding HS toolface. See increased mfr work and reactive torque at 9076.8. PU 10'. Mill back down to 9076.5'. See reactive and mfr work again. PU 10'. Mill down to 9077'. Mtr work and reactive. Appear to have contacted the wall of the 7" csg, but this is approximately 2' early. Will go with reactive and mfr work instead of calculated contact depth. Treating flo pro with small amounts of PH6 and sodium bicarb to neutralize effects of cement. Held pre spud mfg with night crew. 18:15 - 18:30 0.25 STWHIP P WEXIT Open EDC. Log CCL tie in from 8920'. No correction. 18:30 - 20:00 1.50 STWHIP P WEXIT Circulate out of hole. At surface. Monitor well for flow. Well stable. 20:00 - 21:30 1.50 STWHIP P WEXIT Get off well. Unstab coil. LD motor and pilot mill. MU Weatherford fixed 2.5 deg mfr w/ HCC one-step window mill w/ brass ring. Stab coil. Test mwd. Get on well. 21:30 - 00:00 2.50 STWHIP P WEXIT Run in hole. Hanging up on a tbg collar every so often. Work and or circulate past each and continue in hole. Slow going. 10/16/2005 00:00 - 00:30 0.50 STWHIP P WEXIT Continue to run in hole. 00:30 - 01:00 0.50 STWHIP P WEXIT Log CCL tie in from 8920'. Subtract 10' correction. 01:00 - 02:00 1.00 STWHIP P WEXIT Dry tag at 9077.1'. Close EDC and tag white circ at 1.6 bpm at 3500 psi fs ~ 9076.1' PU 1' from btm tag. Begin time milling sequence. Lock brake for 45 min. 02:00 - 06:00 4.00 STWHIP P WEXIT Begin a very slow time milling schedule. 3450 psi fs ~ 1.6 inlout. WHP/BHP/ECD: 18!3820/11.34 ppg. IA/OA/PVT: 660/422/389 bbls. Small amount on metal accumulating on ditch magnets. 06:00 - 12:00 6.00 STWHIP P WEXIT Continue with window milling operations. Now at 9076', back at flag. Following the David Heam Extended milling schedule. Currently at 25 mintues10.1'. Free spin is 3500 psi at 1.6 bpm. Milling at 1.61 /1.63/3660 psi. String wt = 7300 lbs. DHWOB=1500 lbs. ECD=11.42 lbs. BHP=3850 psi. WHP=O psi. All is going according to plan with reasonable motor work and WOB for this point in the time milling sequence. 12:00 - 12:30 0.50 STWHIP P WEXIT Continue to miff. AH indications are that milling is proceeding according to plan. 1.6/1.61/3750 psi. DHWOB=4000 lbs. String wt=4900 lbs. PYT=387 bbls. BHP=3920 psi. ECD=11.62 ppg. Caught a sample and examined in GEO shack. Cutting show 98% metal shavings, 2% formation with a few glass beads. We did not pumps glass beads on this well, they must be left in the mud system/possum belly from last well. Formation cuttings could also be left over from the last welt. Cutting sample is inconclusive. Park at this depth to see if we get drill off and WOB to come back down. 12:30 - 12:50 0.33 STWHIP P WEXIT PU off bottom. Sticky pickup at 23 klbs. Pulled 2 klbs over on pickup. Pull up to 9660'. Free spin 3650 psi at 1.61 bpm. WOB = 110 lbs. RIH slow. Tag up at 9078.4'. 12:50 - 13:05 0.25 STWHIP P WEXIT Stop coil at 9079.8'. DHWOB=4300 lbs. String wt=57001bs. Printed: 11!7/2005 9:5820 AM BP Page 3 of 1'6 Operations Summary Report Legal Well Name: 1 Q-04 - Common Well Name: 10-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10!14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: `Date From - To Hours Task Code. NPT Phase Description of,Operations 10/16/2005 12:50 - 13:05 0.25 STWHIP P WEXIT 1.6/1.6/3980 psi. Getting good drill off. Continue milling at 14 fph. We appear to be drilling open hole. Window depths = 9076.1'-9078.9'. Started stacking wt, and losing motor work. 13:05 - 14:10 1.08 STWHIP P WEXIT PU at 4 klbs over. RIH, Tag up at 9081.3'. DHWOB=4780 lbs. 1.6!1.63/3750 psi. Try drilling OH at 10 fph. Making hole. Catch a bottoms up sample. Sample contained 30% metal cuttings and 70% formation. Confirms we have a window. Continue drilling ahead to get 10' of rathole. 14:10 - 16:05 1.92 STWHIP P WEXIT PU clean at 22 klbs. RIH, tag at 9091'. POOH to pick up crayola mill BHA. Follow pressure schedule, pumping at full rate while POH thru an open EDC. 16:05 - 16:15 0.17 STWHIP P WEXIT Tag up at surface. Flow check well while holding PJSM Re: BHA swap. No flow observed. 16:15 - 17:15 1.00 STWHIP P WEXIT Lay down BHA #2. 1 Step window mill recovered and gauged at 2.74" Go, 2.73" No-Go. The mill had a good swirl! pattern on the face. All indications are we have a good window. Pick up BHA #3, a crayola mill and 1.75 deg motor. The crayola mill gauges 2.74" Go, 2.73" No-Go. 17:15 - 19:00 1.75 STWHIP P WEXIT RIH with BHA #3 to dress window. Open sssv. Follow WHP schedule to maintain pressure on open B shale. 19:00 - 19:15 0.25 STWHIP P WEXIT Log ccl tie in. -10' correction. 19:15 - 21:45 2.50 STWHIP P WEXIT Ream window down at HS tool face. Make several up passes at HS, 90L and 90R. 3470 psi fs C~ 1.57 in/out. Dry drift down at HS tt. Window smooth. IA/OA/PVT: 509!577!384 bbls. WHP/BHP/ECD: 22/3873111.45 pP9• 21:45 - 23:00 1.25 STWHIP P WEXIT Open EDC. Circulate out of hole. Maintain whp as per schedule. Close sssv with 850 psi trapped below. Continue to surface. 23:00 -00:00 1.00 STWHIP P WEXIT At surface. Check for flow. Get off welt. Unstab coif. LD tools. 10/17/2005 00:00 - 01:30 1.50 DRILL P PRODi Prep for slack management. Pump slack. Cut pipe. 01:30 - 03:30 2.00 DRILL P PROD1 Insatll coil connector. Pull and pressure test same. Install a-line head. Test same. 03:30 -04:15 0.75 DRILL P PRODS MU build assembly (2.6 deg mtr w/ Hyc bicent) Sab coil. Test mwd. Get on well. Pressure up well to 850 psi. Open sssv. Whp remained at 840 psi. 04:15 - 05:50 1.58 DRILL P PROD1 Run in hole. ~ 05:50 -06:30 0.67 DRILL P PROD1 Log tie in pass down over GR character at 5880'. Make -15' correction using the Geologist PDC tog. 06:30 - 09:20 2.83 DRILL P PRODi Tag bottom at 9087'. PU, bring pumps to full rate. Free spin 3250 psi at 1.5 bpm. PVT=380 bbls. IAP=380 psi, OAP=530 psi. BHP=3904 psi. ECD=11.57 ppg. Drilling at 1.49/1.50/3600. 30 fph. 09:20 - 13:45 4.42 DRILL P PROD1 9135. Lost partial returns momentarily. Drilling at 1.5!1.313670 psi. Returns slowly healed up. 13:45 - 14:45 1.00 DRILL P PROD1 9220', Found the Ankorita we were looking for. ROP=E tph. PVT=374 bbls. IAP=680 psi, OAP=823 psi. Need to bleed OA. Send hand to do so. Drilling at 1.51/1.52/3620 psi. BHP=3935 psi, ECD=11.54 ppg. 14:45 - 15:00 0.25 DRILL P PROD1 9228', Back out of the Ankorite. Continue drilling build and turn to landing point. 15:00 - 15:15 0.25 DRILL P PROD1 Wiper trip to the window. Clean PU off bottom at 23 klbs. Printed: 11!!/2005 9:58:20 AM BP Page 4 of 16 Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10!14!2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Gode NPT Phase Description of Qperations 10/17!2005 15:00 - 15:15 0.25 DRILL P PROD1 Clean thru the A6 interval. Clean back to bottom. 15:15 - 18:30 3.25 DRILL P PRODt Resume drilling. ROP=65 fph. In the sand looking for a landing point. Land buildlturn at 9334'. Add additional klagard to mud for A6: now up from 12 ppb to 14 ppb. 18:30 - 20:00 1.50 DRILL P PROD1 Circulate out of hole for BHA change. Close sssv with 850 psi on well. 20:00 - 21:30 1.50 DRILL P PROD1 At surface. Flow check well. Get off well. Unstab coil. Change motor angle to 1.1 deg. MU HCC bicenter. 21:30 - 23:00 1.50 DRILL P PROD1 Get on well. Run in hole. Open sssv with 850 psi on tbg. Continue in hole following whp/bhp schedule. 23:00 - 23:15 0.25 DRILL P PROD1 Log gr tie in. Subtract 15' correction. Continue in hole. Open hole smooth. 23:15 -00:00 0.75 DRILL P PROD1 Drill ahead from 9334'. 3470 psi fs at 1.56 inI1.56 out. DPSI: 100-150. DHWOB: i.0 - 2.Ok#. WHP/BHPlECD: 33/4006111.65 ppg. IA/OA/PVT: 570/3961367 bbls. INC/AZM/TF: 90.3/85.1/158. ROP: 50-75 fph. 10/18/2005 00:00 - 02:30 2.50 DRILL P PROD1 Drill ahead from 9355'. 3470 psi fs at 1.56 in/1.56 out. DPSI: 100-150. DHWOB: 1.0 - 2.Ok#. WHP/BHP/ECD: 3314006/11.65 ppg. IA/OA/PVT: 570/396!367 bbls. 1NC/AZMIfF: 90.3/85.1/158. ROP: 50-75 fph. 02:30 - 03:00 0.50 DRILL P PROD1 Wiper trip to window. Hole smooth in both directions. 03:00 - 06:00 3.00 DRILL P PROD1 Drill ahead from 9500'. 3530 psi fs at 1.54 in/out. PVT: 365 bbls. 06:00 - 06:55 0.92 DRILL P PROD1 Drilling ahead. 1.58/1.58/3630 psi. ROP=30 fph. PVT=362 bbls. IAP=723 psi, OAP=560 psi. ECD=11.8 ppg. BHP=4063 psi. 06:55 - 07:30 0.58 DRILL P PROD1 Wiper trip to window. Glean PU off bottom at 23 klbs. Clean in open hole up to and thru the A6 at 9150'. Clean up to the window. No problems with the hole at all. Clean back to bottom. 07:30 - 10:40 3.17 DRILL P PROD1 Resume drilling. 10:40 - 11:00 0.33 DRILL P PROD1 Wiper trip to the window. Clean PU off bottom and in open hots. Pumps down, tool face high side as we pull thru the window. No problems. Open EDC. 11:00 - 11:15 0.25 DRILL P PROD1 Log tie in pass down from 8890'. Make +3.5' correction. 11:15 - 11:45 0.50 DRILL P PROD1 RIH thru the window. Shut the EDC. Kick on the pumps and run to TD. 11:45 - 15:10 3.42 DRILL P PROD1 Tag bottom and resume drilling. Free spin is 3530 psi at 1.5 bpm. Drilling at 1.54/1.55/3600 psi. PVT=357 bbls. IAP=700 psi, OAP=598 psi. BHP=4080 psi. ECD=11.92 ppg. ROP=52 fph. 15:10 - 15:30 0.33 DRILL P PROD1 Slow drilling, continue to try to drill up structure. INC=96 deg. 1.54 BPM, 3754 psi 15:30 - 16:30 1.00 DRILL P PROD1 Conduct wiper trip to window. 16:30 - 17:30 1.00 DRILL N SFAL PROD1 Drill ahead. 1.5 bpm, 3512 psi. BHi Hardware/Software problems occurring- depth reading wrong. 17:30 - 19:00 1.50 DRILL N SFAL PROD1 Trouble shoot SHI tools. Repeated sit down/tag up's to check tools. Attempt to drill ahead and still have problem-a BHI software thing. SWS counter reading 9941' 19:00 - 19:30 0.50 DRILL N SFAL PRODi Wiper to window, clean 19:30 - 19:45 0.25 DRILL N SFAL PROD1 Pull thru window and work on software while parked in tubing. Got it working Printed: 11!7/2005 9:5820 AM B P Page 5 of '{ 6 Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1 Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date From - To ,Hours Task Code NPT- Phase Description of Operations 10/18/2005 19:45 - 20:15 0.50 DRILL N SFAL PROD1 Wiper back to TD, clean. Tagged at 9941' PVT 348 20:15 - 22:00 1.75 DRILL P PROD1 Drill from 9941' 1.54/3600/18 w/ 100-300 psi dill, 1-4k wob w/ 11.95 ECD at 96 deg at 6582' TVD w/ slow penetration in 65 api rock. Get into ratty drilling area at 9970' and assume probable mapped fault 22:00 -00:00 2.00 DRILL P PRODt Drill from 9976' with better penetration rate and tum TF over to maintain 94 deg i.54/3630/SOR w/ ECD 12.28 due to increased solids from faster penetration rate 10/19/2005 00:00 - 00:30 0.50 DRILL P PROD1 Drill from 10070-10100' and swap to left at 10085' PVT 346 00:30 - 01:40 1.17 DRILL P PROD1 Wiper to window, clean both directions PVT 344 01:40 - 02:40 1.00 DRILL P PROD1 Start new mud. Drill from 10100' 1.57/3650l85L w! 100-300 psi dill, 1.2-3.Ok wob w/ 12.3 ECD at 94 deg at 6573' TVD 02:40 -04:40 2.00 DRILL P PROD1 Hole completely displaced to new mud. Drill from 10145' 1.56/3320/SOL w/ 11.4 ECD at 97 deg (6562' TVD) 04:40 - 05:25 0.75 DRILL P PROD1 Wiper to window, clean 05:25 - 05:45 0.33 DRILL P PRODi Log tie-in down from 8890', Corr +8' 05:45 - 06:30 0.75 DRILL P PRODi Wiper back to TD tagged at 10244' 06:30 - 07:30 1.00 DRILL P PROD1 Drill ahead from 10244' to 10280'. 0=1.5211.52, 3500 press, 1850/2500 WOB, 11.57 ECD, 53-35'fir, 120L. C°30700 hrs, change TF to 80L X0730 hrs, ROP dropped due to 10% Ankerite. 07:30 - 17:40 10.17 DRILL P PROD1 Drill ahead from 10280' to. 0=1.5/1.5, 3400-3500 press, -5K to -6.4K CTW / 1500-3100 WOB, 11.55 ECD, 2-5'fir, 80L, 98 deg. Work pipe and varying WOB's to establish better ROP. -No apparent losses or sticking problems ~ 1500, TF set at 30L 17:40 - 18:25 0.75 DRILL P PROD1 Break out of ankerite at 10320', swap TF to left at 10385' and drill at 80'fir 1.51/3440!808 w/ 300-500 psi dill, 2-4k wob w/ 11.9 ECD at 96 deg from 6546' TVD PVT 394 18:25 - 19:55 1.50 DRILL P PROD1 Wiper to window, clean both directions 19:55 - 21:20 1.42 DRILL P PROD1 Drill from 10400' 1.52/3450!808 w/ 200-500 psi dill, 2-3k wob w/ 11.95 ECD at 97 deg to 10470' at 60'fir 21:20 - 23:10 1.83 DRILL P PROD1 Grind on a hard spot at 10470' for 30 min, then back to 60-80'fir. Drill to 10550' at 93 deg and start seeing signs of losing push PVT 389 23:10 - 00:00 0.83 DRILL P PROD1 Wiper to window was clean 10/20/2005 00:00 - 01:15 1.25 DRILL P PROD1 Wiper back in hole from window w/ set downs at 10387' twice in TF change area. Rest of hole yvas clean PVT 385 01:15 -04:10 2.92 DRILL P PROD1 Drill from 10550' 1.53/3600/100L w/100-300 psi dill, 1.5-2.5k wob w/ -2k surface wt w! 12.0 ECD at 93 deg. Add lubetex to bring concentration up to 4%. Enter 60 api sand in A4 at 10615' 04:10 - 05:10 1.00 DRILL P PROD1 Wiper to window, clean 05:10 - 05:30 0.33 DRILL P PROD1 Log tie-in down from 8880', Corr +10' 05:30 -06:45 1.25 DRILL P PROD1 Wiper back to TD tagged at 10710'. 06:45 -09:45 3.00 DRILL P PROD1 Drill ahead from 10710' to 10820'. Q=1.6/1.6, 4100 press, 0 CTW/ 2000-1600 WOB, 12.4 ECD, 26'fir. 09:45. 10:45 1.00 DRILL P PROD1 Drilling break- ROP increased to 60'fir. Drill ahead from 10820 to 10880'. Q=1.6!1.6, 4100-4300 press, -1400 CTWI 1800 WOB, 12.5 ECD, 45089 deg. 10:45 - 11:45 1.00 DRILL P PROD1 ROP reduction- 10-30'fir. 0=1.6211.62, 4100 - 4300 press, -3700 CTW/1800 WOB, 12.5 ECD, 120089 Deg. 11:45 - 13:45 2.00 DRILL P PROD1 Conduct wiper trip to window. Slight motor work at 9150'. Printed: 11/7!2005 9:58:20 AM BP Page 6 of 16 Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description' of Operations 10/20/2005 11:45 - 13:45 2.00 DRILL P PROD1 Tagged bottom at 10887'. 13:45 - 16:30 2.75 DRILL P PROD1 Drill ahead to TD at 10892'. 0=1.5711.57, 4000-4300 press, -9K to -4K CTW/ 2500 - 1500 WOB, 12.5 ECD, 0 HS/ 88 deg. 16:30 - 17:45 1.25 GRILL P PROD1 Conduct final wiper to window. 17:45 - 18:00 0.25 DRILL P PROD1 Log tie-in, corr +9' 18:00 - 19:00 1.00 DRILL P PROD1 Wiper back to TD w/ set downs at 10732' and 10750' w/ TF 140 deg off. Rest of hole was clean. Tag at 10895' which is official TD 19:00 - 19:45 0.75 DRILL P PROD1 Wiper thru OH leaving mud w/ 3 ppb coarse beads 1.0/3050 w/ 200 psi by at 45'/min was clean. Flag at 9000' EOP 19:45 - 21:20 1.58 DRILL P PROD1 POOH for liner following pressure schedule. Close TRSSSV w/ 850 psi 21:20 - 21:45 0.42 DRILL P PRODi LD drilling BHA 21:45 - 22:05 0.33 CASE P RUNPRD RU to run liner 22:05 - 22:20 0.25 CASE P RUNPRD Safety mtg re: run liner 22:20 - 23:45 1.42 CASE P RUNPRD MU 25 jts 2-3/8" 4.3# L-80 STL R2 slotted liner w/ Unique indexing guide shoe. MU WFT 2.50° OD aluminum liner top deployment sub w! GS profile. MU BHI MWD assy 23:45 - 00:00 0.25 CASE P RUNPRD RIH w/ liner assy on CT pumping thru EDC 0.3/1000 following pressure schedule. Open TRSSSV w/ 850 psi 10/21/2005 00:00 - 01:30 1.50 CASE P RUNPRD Continue RIH w! liner following pressure schedule 0.312000 thru EDC. RIH thru window, clean to 9800'. Close EDC. 18.2k, 8k See flag 22' deep, did not correct 01:30 - 01:50 0.33 CASE P RUNPRD RIH in OH w/o pump with a few wt loss spots at TF changes to solid TD at 10911' CTD. PUH 28.1 k. Set finer back at TD. Pump 1.26/4700 psi and released from liner at 18k Left top of aluminum billet at 10061' and shoe at TD of 10895' 01:50 - 02:15 0.42 CASE P RUNPRD POOH thru OH 0.5/3000 holding by 02:15 -04:00 1.75 CASE P RUNPRD Open EDC in tubing. POOH 1.4!3200 following pressure schedule. Close TRSSSV w/ 850 psi 04:00 - 05:00 1.00 CASE P RUNPRD LD WS setting assy. Reconfigure MWD 05:00 -05:20 0.33 DRILL C PROD1 MU sidetrack assy 05:20 - 07:45 2.42 STKOH C PROD1 RIH w/ BHA #7 (2.0 deg w/ used STR324 bit) pumping 0.55/2250 thru EDC following pressure schedule. Open TRSSSV w/ 900 psi. Adjust and orient TF, drop pumps while running through the window slowly. No problems. Tagged top of billet at 10058.5' 07:45 - 09:00 1.25 STKOH C PROD1 PU to 10030', orient TF to 150L, drill trough at 25'/hr. 0=1.55/1.55, 3800 psi, 5400 CTW/800 WOB, 12.3 ECD. 09:00 - 09:45 0.75 STKOH C PROD1 PU to 10030', orient TF to 150L, drill trough at 40'lhr. 0=1.5/1.5, 3700 psi, 5800 CTW/1000 WOB, 12.3 ECD. 09:45 - 11:00 i.25 STKOH C PROD1 PU to 10030', orient TF to 150L, drill trough at 50'/hr. Q=1.4/1.4, 3500 psi, 5900 CTW/0 WOB, 12.2 ECD. -Stacked out at 10058.8'. Stick/Slip problems above us, not at bit. Set brake and watch weight transfer. Work way down to 10059.3- stall. PU pipe and work back and forth to 10057.5'. Continuously drill down at .1'/min until a light stall at 10058.2'. PU and set back down at 10057' and work way down to tag depth at .1'/min intermittantly. 11:00 - 14:15 3.25 STKOH C PROD1 PU to 10020' and work back down to 10035'. Slowdown to 10'/hr and work trough to top of billet, 150E TF. Work from 10050 to 10057' several times- Work trough as slow as possible. Prm~ea: r tinr~oos s:sa:2o a~n BP Page'? of 16 Operations Summary Report Legal Well Name: 1Q-04 - Common Well Name: 10-04 Spud Date: 10!7!2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ' Description of Operations 10/21/2005 14:15 - 18:10 3.92 STKOH C PROD1 Sit on billet: Initially, 8100 CTW/ 150 WOB, 3700 press, 0=1.48/1.48, 12.22 ECD. -When BU, recieving aluminum returns at surface. Good weight transfer and pressures. Working pipe .1' at a time as weight I and pressures dictate. WOB slowly increasing, CTW ~ decreasing, little stick/slip. ~ -At 10060', 150 WOB, 6200 CTW, stable 3700 press, no stick/slip. -At 10064', have 1400 WOB, 3000 CTW, stable 3700 press, i 90L TF, no sticWslip. Drill to 10085' ~ 1.5/3700/90L w/ 100-150 psi dill 1-2k wob w/ NB inc at 10071' at 91 deg 18:10 - 19:20 1.17 STKOH C PROD1 Backream 20.8k, then ream 5.4k from 10' below to 10' above top of billet at DTF at 1.5113790 at 90'/hr, clean. Repeat at 110E at 150'fir and was clean. Repeat at 179E at 150'fir and was clean. Wiper at 15'/min to 10020' at DTF, then back to TD ' at DTF, clean 19:20 - 19:50 0.50 STKOH C i PROD1 Wiper to window, clean. 8k overpull thru window and first 20' j due to probable aluminum cuttings. Incr pump rate until clean i PUN. Open EDC 19:50 - 21:45 1.92 STKOH C ~ PROD1 POOH for lateral asst' following pressure schedule. Close TRSSSV w/ 850 psi 21:45 - 22:00 0.25 STKOH C ~ PROD1 LD sidetrack BHA 22:00 - 22:15 0.25 BOPSU P PROD1 Function test ROPE rams 22:15 - 23:00 0.75 DRILL C PROD1 MU lateral asst' 23:00 -00:00 1.00 DRILL C PROD1 RIH wl BHA #7 (1.1 deg motor w/ bi bit) following pressure schedule. Open TRSSSV w/ 900 psi 10122!2005 00:00 -00:30 0.50 DRILL C PROD1 Continue RIH w/ lateral asst' following pressure schedule 00:30 - 00:45 0.25 DRILL C PROD1 Log tie-in down from 8900', corr -16' 00:45 - 02:00 1.25 DRILL C PROD1 RIH thru window, clean. Wiper to TD w/ set down/8k overpull at 9150' w/ TF 90 deg out. Set down at 9410' twice. Ream at drilled TF w/ 300 psi MW from 9390-9415'. Set downs at w 9528', 9642', 9780'. Enter sidetrack area at 0.5 bpm w/ DTF and clean. Slow ream to TD tagged at 10085' 02:00 - 02:20 0.33 DRILL C PROD1 Drill from 10085' 1.51/3800l85L w/ 100-300 psi dill, 1-3k wob w/ 12.3 ECD to 10100' 02:20 - 02:30 0.17 DRILL C PROD1 Wiper at drilling rate back thru sidetrack at 15'/min, clean. RIH thru sidetrack at 1.0 bpm ai i 5'lrpin, clean. Finish wiper back to TD 02:30 -04:00 1.50 DRILL C PRODi Drill from 10100' 1.5/3700/70L w/ 100-300 psi dill, 1-3k wob w/ 12.3 ECD at 92 deg to 10200' (6570' TVD) at 50'-70/hr 04:00 - 05:15 1.25 DRILL C PRODi Wiper to window, clean thru sidetrack at normal rates and clean to window. Wiper back in hole was clean at normal rates too (slowed down to 15'/min thru OH sidetrack point-just for you, moj) 05:15 -06:30 1.25 DRILL C PROD1 Drill from 10200' 1.513700I70L w/ 100-300 psi dill, 1-3k wob w/ 12.4 ECD at 92 deg. ROP decreasing from 60'fir to 15'fir j -Drilled into ankerite streak 06:30 - 06:45 0.25 DRILL C PROD1 Conduct short wiper to 10220' to clean BHA and attempt to increase ROP 06:45 - 08:45 2.00 DRILL C PROD1 Drill ahead to 10310'. 0=1.5/1.5, 3700 press, 0 CTW/2500 WOB, 12.3 ECD, 70U92 deg. 2-15'fir. 08:45 -09:00 0.25 DRILL C PROD1 Conduct short wiper to 10220' to clean BHA/hole. Printed: 11/7/2005 9:5820 AM BP Page 8 of 16 Operations Summary Report Legal Welt Name: 1Q-04 Common Well Name: 10-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10!14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: :Date 'From - TO Hours Task Code NPT Phase - Description of Operations 10/22/2005 09:00 - 10:15 1.25 DRILL C PROD1 Drill ahead to 10355'. 0=1.5/1.5, 3850 press, -1100 CTW! 1800 WOB, 12.39 ECD, 1158/96 deg, 9-15'fir 10:15 - 11:30 1.25 DRILL C PROD1 Conduct wiper trip to window. Slight tag at 9135' on way out. No problems at window. No problems on way out. Orient at KO point, no problems. 11:30 - 17:00 5.50 DRILL C PROD1 Drill ahead to 10385'. 0=1.52/1.52, 3900 press, 0 CTW/2700 WOB, 12.38 ECD, 308/92.5 deg, 9-15'/hr 17:00 - 18:15 1.25 DRILL C PROD1 Out of ankerite. Drill ahead: 50-70'fir. 0=1.5/1.5, 3900 press, -2KGTW/2.3KW06, 12.45 ECD, 1058/95 deg. Drill to 10443' and stacking in a shale, need fresh mud too PVT 315 18:15 - 18:35 0.33 DRILL C PROD1 Wiper to 10290' 18:35 - 20:50 2.25 DRILL C PROD1 Drill from 10443' 1.5!3800/908 wJ 100-400 psi dill, 1-3k wob w/ 12.48 ECD at 92 deg. Drill to 10490' and can't get wt to bit PVT 311 20:50 - 21:45 0.92 DRILL C PROD1 Wiper to window while wo fresh mud, clean 21:45 - 22:00 0.25 DRILL C PROD1 Log tie-in down from 8880', corr+l2' 22:00 - 22:50 0.83 DRILL C PRODi Wiper back to TD tagged at 10498', clean 22:50 -00:00 1.17 DRILL C PRODi Drill from 10498' 1.51/3790/1108 at 94 deg w/ max neg wt. Swap to left ai 10525' Drill to 10542' Begin swap to fresh mud 10/23/2005 00:00 - 00:30 0.50 DRILL C PROD1 Ream TF change area from 10500-10542' while circ new mud to bit 00:30 - 02:05 1.58 DRILL C PROD1 Resume drilling from 10542' w/ fresh mud at bit 1.5/3450/90L w/ 12.25 ECD at 95 deg at 6550' TVD and now on a really hard spot. After fresh mud around 1.51/3160/80L w/ 11.5 ECD 02:05 - 03:00 0.92 DRILL X SFAL PROD1 PUH 50' and park 1.5/3160 while determine source of CTDS tubing speed/depth error. Disconnect encoder and still showing 90'/min when pipe is not moving ... Elect to RBIH and drill on the hard spot while wo SWS ET to arrive and fix problem 03:00 - 18:00 15.00 DRILL C PRODi Drill from 10546' in ankerite at 3-4'fir 1.5/3300/90L w/ 100 psi dill wl 3.6k wob w/ 11.5 ECD at 94 deg PVT 414 Work pipe on occasion to try to clear BHA -1130 hrs, changed TF to 60L (92 deg) -~ 1545 hrs, talked with town and changed TF to 160E (92 deg) to try to get out of ankerite. 18:00 - 20:45 2.75 DRILL C PROD1 Continue to drill in akerite at 3'fir 1.5/3600/170L w/ 100 psi dill, 3-4k wob w/ 11.85 ECD PVT 409. CTP and ECD higher due to flovis additions due to LT addtions due to expected penetration rate increase any day now .. . 20:45 - 22:45 2.00 DRILL C PROD1 Drilling break at 10610' for 7' of 60'fir gave hope, but then back to 3'fir. Now at 90L 22:45 - 00:00 1.25 DRILL C PROD1 Drill to 10626' at 3'fir w/ TF now at 135E PVT 409 10/24/2005 00:00 - 05:45 5.75 DRILL C PROD1 Continue slow progress in ankerite from 10626' 1.52/3630/120L w! 100 psi dill, 2-3k wob at 11.93 ECD at 91 deg at 6544' TVD 05:45 - 08:30 2.75 DRILL C PROD1 conduct wiper trip to window. Slight motor work at 10100', 9060' (near window). Log down from 8080' at 2.5 fpm. -1.5' correction. RBIH. Slight setdown at 10140, 10590'. Tagged bottom at 10638' (13' discrepancy) 08:30 - 12:00 3.50 DRILL C PROD1 Drilt ahead to 10649'. 0=1.5/1.5, 3600 press, -6K CTW/ 2.9 WOB, 210U 89 deg, 11.9 ECD. 12:00 - 14:30 2.50 DRILL C PROD1 Conduct wiper trip to window. +13.5' correction. 14:30 - 16:30 2.00 DRILL C PROD1 Drill ahead to 10668'. Q=1.5/1.5, 3700 press, -7.6K CTW/ 3.2K WOB, 180 U 89 deg, 12 ECD Printed: t 1!7/2005 9:58:20 AM $P Page 9 of 16- Operations Summary Report Legal Well Name: 1Q-04 - Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: 'Date From - To Nours Task .Code NPT Phase Description of Operations,- 10/24/2005 16:30 - 18:00 1.50 DRILL C PROD1 Drilling break out of ankerite- 55'/hr. 0=1.52/1.52, 3800 press, 0 CTW12300 WOB, 30U 89 deg, 12.1 ECD. -~ 1730 hrs, changed TF to 60L 18:00 - 20:30 2.50 DRILL C PRODi Drill from 10710' (6550' TVD) 1.5/3690/80L w/ 150-300 psi dill, 2-3.5k wob w/ 12.10 ECD at 86 deg at 20-40'/hr PVT 384 20:30 - 21:30 1.00 DRILL C PRODi Wiper to window, clean 21:30 - 21:50 0.33 DRILL X DFAL PROD1 Stop at 9223' when pinhole occurred coming thru injector. SI ~ Swaco choke, swap to pump #1 down kill line to maintain 800-1000 psi. Bleed off Baker choke and let CT drain on rig floor-checks holding. PJSM. Puil CT wlpinhole over pipeshed and onto reel and flag Pinhole occurred w/ 266k RF at a 25% wear spot 21:50 - 22:10 0.33 DRILL X ~ DFAL PROD1 Fin POOH thru OH and was clean, window was clean. PUH into tubing and park. Inspect pipeshed roof and no drips, reelhouse clean too 22:10 - 23:40 1.50 DRILL X DFAL PROD1 POOH holding 800-1100 psi against closed choke and noting proper hole fill. Close TRSSSV w/ 950 psi MIRU SWS N2 23:40 - 00:00 0.33 DRILL X i PROD1 LD drilling BHA 10/25/2005 00:00 - 00:55 0.92 DRILL X ~ DFAL PROD1 Fin LD drilling BHA. SI swab. Cut off Kendal CTC. Install SWS CTC. Stab back on 00:55 - 02:30 1.58 DRILL X PROD1 Flush CT w/ 40 bbls rig water while recover mud. Blow down CT w/ N2 and bleed off to tiger tank. RDMO SWS N2 02:30 - 03:30 1.00 DRILL X PROD1 Cut off CTC, install internal grapple and PT. Pull CT back to reel and secure. RD hardline 03:30 - 05:30 2.00 DRILL X PROD1 Load out pinholed reel. Load in new reel E-CT 05:30 - 10:00 4.50 DRILL X PROD1 Install internal grapple and PT. Pull CT to floor 10:00 - 10:45 0.75 DRILL X PROD1 Pump coil volume (40.6 bbls) plus 20 eMra. Cut 18 feet. 10:45 - 11:30 0.75 DRILL X PROD1 Re-head coil. 11:30 - 12:00 0.50 DRILL X PRODi Pull test to 40K. Held. PT to 4K. Held 12:00 - 13:30 1.50 DRILL X PROD1 PU new BHA 13:30 - 15:00 1.50 DRILL X PRODi RlH to 8880' at 100 fpm. 15:00 - 15:30 0.50 DRILL C PROD1 Log down at 2.5 fpm and tie in. -14.5' correction. 15:30 - 16:30 1.00 DRILL C PROD1 Continue RIH at 30 fpm. Orient through window and KOP. Slight motor work at 10092'. Drop pumps to .75 bpm. Work through spot several times with no further problems. 16:30 - 22:30 6.00 DRILL C PROD1 Drill ahead. 0=1.55/i.55, 3900 press (3800 FS), -3.5K CTW/ 1.5K WOB, 12.3 ECD, 15R/ 92 deg. 22:30 - 23:45 1.25 DRILL C PROD1 Wiper trip to 8880' Slight overpull,pt 10058'. 23:45 - 00:00 0.25 DRILL C PROD1 Log tie-in +2' correction. 10/26/2005 00:00 - 01:15 1.25 DRILL C PROD1 Finish wiper trip to bottom. Tagged bottom at 10934' TD. 01:15 - 03:50 2.58 DRILL C PROD1 TOH for liner following pressure schedule. Trap 950psi below SSSV and close. 03:50 -04:00 0.17 DRILL C PROD1 PJSM: review liner running procedures and hazards. Discuss shut-in procedures in case of How. 04:00 -04:45 0.75 DRILL C PROD1 UD BHA. RU floor to run liner. 04:45 -06:00 1.25 CASE C PROD1 MU Unique indexing Guide Shoe to 2-3/8" 4.43# L80 R2 STL slotted liner (mu torque 500-600ft/Ibs) 06:00 - 07:00 1.00 CASE C PROD1 RIH w/ 52 jts 2-3/8" liner. 07:00 - 07:15 0.25 CASE C PROD1 PU liner BHA, attempt to PU billet. 07:15 - 08:45 1.50 FISH X PROD1 While attempting to MU billet in mousehole, GS spear disengaged- dropping the billet. Billet was retrieved using state of the art fishing techniques involving rope and a used mop. However, the impact shattered the thread protector and flared Printed: t 1/7/2005 9:58:20 AM BP Page 10 of 16. Operations Summary Report Legal Welf Name: 1Q-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11!5/2005 Rig Name: NORDIC 2 Rig Number: Date From.- To Hours Task Code NPT Phase Description of Operations. 10/26/2005 07:15 - 08:45 1.50 FISH X PROD1 the pin connection on the billet sub. New one ordered out. 08:45 - 09:15 0.50 CASE C PROD1 PU new billet sub, reconnect to billet. PU liner BHA 09:15 - 10:00 0.75 CASE C PROD1 Test BHI liner BHA- no depth reading. Numerous attempts to rectify problem- will not work. Decision made to continue in hole as no tie in would be made anyways. 10:00 - 12:15 2.25 CASE C PROD1 RIH w/liner and liner BHA. Slight set down at 9180', 9330'-9388'. Tag bottom (10935'). PU wt- 29K. Set on bottom and bring pump rate to 1 bpm, Slowly PU again. Wt-20K. Liner disengaged. POOH. 12:15 - 14:30 2.25 CASE C PROD1 POOH w/ liner BHA 14:30 - 15:45 1.25 CASE P PROD2 LD liner BHA, PU and MU KO BHA. Test- good 15:45 - 18:00 2.25 STKOH P PROD2 RIH w/ KO BHA 18:00 - 18:20 0.33 STKOH P PROD2 Lot tie-in -16' correction 18:20 - 18:25 0.08 STKOH P PROD2 RIH tagged top of aluminum billet at 9198'. 1825 - 23:00 4.58 STKOH P PROD2 Starting at 9180' make 3 passes down to 9198' with 30L TF. Start time drilling off aluminum billet 0.1' every 2 min. I 1.47/1.47 fs= 3472 ecd=11.77 At 9201 increase rop to 6'/hr to 9211'. Grill ahead 30'!hr to 9220'. Pull back to 9180 with 90L TF Ream backream to 9220' with 90L. RIH wo to 9220 no problems. 23:00 - 00:00 1.00 STKOH P PROD2 TOH following pressure schedule. 10127!2005 00:00 -00:45 0.75 STKOH P PROD2 Finished TOH. Trapped 975psi on well prior to shut-in of SSSV. 00:45 - 00:55 0.17 DRILL P PROD2 PJSM review BHA changes. 00:55 - 01:45 0.83 DRILL P PROD2 Change out bits. PU 3" bi-center. No changes to motor bend. Surface test tools 01:45 - 03:45 2.00 DRILL P PROD2 TIH to 8880' 03:45 -04:00 0.25 DRILL P PROD2 Log tie-in -16' correction 04:00 -04:15 0.25 DRILL P PROD2 RIH to 9220' No problems at OHST. 04:15 - 07:15 3.00 DRILL P PROD2 Directionally drill ahead with build section 1.52 / 1.52 fs= 3500psi mw= 3-400psi ecd= 11.78ppg 3-4k wob 15-20'Ihr make a BHa wiper trip at 9226' started drilling better 70/80'/hr w/ 2k wob. Build landed at 9366', 20' higher than expected. Drill ahead to build tum. 07:15 - 07:45 0.50 DRILL P PROD2 Conduct wiper trip to window. Slight motor work at 9175. 07:45 - 09:45 2.00 DRILL P PROD2 Drill ahead. 0=1.55!1.55, 3800 press, 3.SK CTW/ 1.SK WOB, 11.9 ECD, 60U 81 deg, 55 ROP. 09:45 - 11:30 1.75 DRILt P PROD2 POOH w/ build assy 11:30 - 12:00 0.50 DRILL P PROD2 Stand back injector. LD build BHA. Clear floor for BOP tests. 12:00 - 16:00 4.00 BOPSU P PROD2 BOP testing- all pass Witnessed for BP by Tug Eiden- Drilling Rep Witnessed for AOGCC by Jeff Jones 16:00 - 16:45 0.75 DRILL P PROD2 PU lateral BHA 16:45 - 18:00 1.25 DRILL P PROD2 RIH w/ lateral BHA 18:00 -18:20 0.33 DRILL P PROD2 Log tie-in -16' correction 18:20 - 19:25 1.08 DRILL P PROD2 RIH tagged 9163. try different TF's to work through. This has been a problem area in the past. Able to pass through with 100R TF's. 19:25 - 19:35 0.17 DRILL P PROD2 Holding 100R TF ream from 9162'. 1.521 1.52 fs= 3540 60'/hr 19:35 - 22:15 2.67 DRILL P PROD2 Directionally drill ahead f/ 9410' to 9560'. 1.54/1.54 3-400psi mw 2k wob 60-70'/hr (pit vol 352) 22:15 - 23:15 1.00 DRILL P PROD2 Wiper trip. tagged at 9163' worked through wo problems. 23:15 - 00:00 0.75 DRILL P PROD2 Directionally drift ahead f/ 9560' to 9600' 1.54 / 1.54 8.7 in/out fs= 2500 mw= 3-400 ecd 11.89 wob=2k 50-60'/hr Printed: 17!7/2005 9:58:20 AM BP Page 11 of 16 Operations Summary Report Legal Well Name: 10-04 - Common Well Name: 1Q-04 Spud Date: 10!7!2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date From- To -Hours Task Code NPT Phase Description of Operations 10!28!2005 00:00 - 02:00 2.00 DRILL P PROD2 Continue drilling ahead f/ 9600' to 9710'. 60-70'/hr w/ 2k wob 400-500psi motorwork ECD 12.Oppg 02:00 - 02:55 0.92 DRILL P PROD2 Wiper trip. Seeing bits and pieces of motor stator across shaker. Tagged at 9163'. reamed through with 120R TF. Clean to TD. 02:55 - 03:05 0.17 DRILL P PROD2 Directionally drill ahead f/ 9710' to 9712'. Seeing way to many chunks of stator rubber and partial bit plugging. Need to TOH for motor. 03:05 - 05:15 2.17 DRILL N PROD2 TOH following pressure schedule. Close SSSV trapping 950psi on well. 05:15 - 05:45 0.50 DRILL N PROD2 LD BHA- motor is bowed in power section- probable cause of failure. Bit plugged. Unplug bit and change out motor 05:45 - 06:15 0.50 DRILL N PROD2 PU new motor, run same bit, PU rest of BHA 06:15 - 09:00 2.75 DRILL N PROD2 RIH w/ BHA. Log down and tie in. -15.5' correction. Continue RIH. 09:00 - 11:00 2.00 DRILI P PROD2 Drill ahead. 0=1.5/i.5, 3600 press, 4.2K CTW/ 1.6K WOB, 11.9 ECD, 75R/ 88.5 deg, 65'/hr -~ 1000 hrs, well completely swapped to new mud 11:00 - 12:00 1.00 DRILL P PROD2 Conduct wiper to window. 12:00 - 14:00 2.00 DRILL P PROD2 Drill ahead. 0=1.6!1.6, 3500 press, 4.8K CTW/ 2.OK WOB, 11.4 ECD, 75R/ 87.75 eg, 8-12'/hr 14:00 - 16:00 2.00 DRILL P PROD2 Drilling break. 0=1.6/1.6, 3600 press, 2.2K CTW/ 4.1 WOB, 11.3 ECD, 30R/89.4 deg, 60-75'fhr 16:00 - 17:00 1.00 DRILL P PROD2 Conduct wiper trip to window. No problems. 17:00 - 22:00 5.00 DRILL P PROD2 Drill ahead. 0=1.6/1.6, 3400 press, 3.7K CTW/ 2.5K WOB, i 1.4 ECD, 90U 88.5 Deg, 50-60'/hr Hit Ankorite stringer at 10128' to 10135'. Drilled to 10150' 22:00 - 22:50 0.83 DRILL P PROD2 Wiper trip to 8880' No problems 22:50 - 23:05 0.25 DRILL P PROD2 Log tie-in +6' correction 23:05 - 00:00 0.92 DRILL P PROD2 Wiper trip to bottom. OHST area at 9200' no problem. Good to bottom. i0l29/2005 00:00 - 01:30 1.50 DRILL P PROD2 Directionally drill f/ 10150' to 10271' 1.54/1.54 #s= 3330 mw= 3-400 ecd= 11.5 wob 2-3k 70-80'/hr 01:30 - 02:55 1.42 DRILL P PROD2 Wiper trip to 9000'. Hole good. 02:55 - 05:50 2.92 DRILL P PROD2 Directionally drill ahead f/ 10271' to 10420' 1.6/1.6 fs= 3350 mw=300 wob= 2k 40-50'/hr 05:50 - 07:30 1.67 DRILL P PROD2 Conduct wiper to window. No hole probs. R81H. 07:30 - 10:15 2.75 DRILL P PROD2 Drill ahead. 0=1.6/1.6, 3600 preps (3300 FS), -.5K CTW(2.9K WOB, 11.7 ECD, 45R/90 deg, 60-70'/hr. 10:15 - 12:30 2.25 DRILL P PROD2 Conduct wiper to window. No hole problems. PU to 8880' and log down at 2 fpm. +10.5' correction. RBIH. 12:30 - 14:15 1.75 DRILL P PROD2 Drill ahead. 0=1.55/1.55, 3600 press (3350 FS), -1.1 K CTW/ 2.2K WOB, 11.7 ECD, 60R/ 92.6 deg, 50-60'/hr. 14:15 - 16:30 2.25 DRILL P PROD2 Conduct wiper trip to window. No problems. 16:30 -00:00 7.50 DRILL P PROD2 Drill ahead. 0=1.55/1.55, 3800 press (3400 FS), -3.55K CTW! 2.5 WOB, 11.9 ECD, 135R/ 92 deg, 60-70'/hr. -~ 1715 hrs, changed TF to 120E Hit Ankorite at 10810' diving down NB inc 85-86deg 2-3k wob +1 k CTW also swapping out mud system for new Flo-Pro. 10/30/2005 00:00 - 07:30 7.50 DRILL P PROD2 Continue drilling ahead f! 10840' in Ankorite. 1.5811.58 freespin 3475psi motorwork 300psi ecd= 11.8 TF 120E NBI 83-82deg 3-4k wob w/-1.5k CTW Printed: 11!7/2005 9:58:20 AM gp Page 12 of 16 Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date .From -'To .Hours Task Code. NPT Phase °Description of Operations 10130!2005 07:30 - 08:15 0.75 DRILL P PROD2 Drilling break- 50-60'/hr. 0=1.58/1.58, 3800 press (3600 FS), -2.4K CTW/ 2.1K WOB, 15U 83.5 deg, 11.9 ECD. 08:15 - 10:30 2.25 DRILL P PROD2 Conduct wiper trip to window. 10:30 - 11:00 0.50 DRILL P PROD2 Drill ahead. 0=1.58/1.58, 3800 (3600 FS), -2.4K CTW/ 1.8K WOB, 60U 83.5 deg, 11.85 ECD. 11:00 - 13:45 2.75 DRILL P PROD2 Re-entered ankerite- 5-15'/hr. 0=1.6(1.6, 3800 press, -4.5K CTW/ 2.3K WOB, 75U 85 deg, 11.8 ECD. -~ 1230 hrs, changed TF to 0 HS 13:45 - 14:45 1.00 DRILL P PROD2 Drilling break- 60-70'/hr. 0=1.58/1.58, 3800 press, -3.7K CTW! 2.5K WOB, 75U 85 deg, 11.8 ECD. 14:45 - 16:00 1.25 DRILL P PROD2 Press climbed to 4100, PU and clear pipe and attempt to clear bottomhole. Work up and down several times, RBIH to bottom. Tag bottom several times, no go. POOH. 16:00 - 19:00 3.00 DRILL N PROD2 POOH. Close SSSV w/ 975psi. Hold PJSM while well bleeds down. 19:00 - 20:00 1.00 DRILL N PROD2 UD motor/bit PU new motor and new HCC bicenter 20:00 - 21:15 1.25 DRILL N PROD2 RIH open SSSV R1H to 8880'. 21:15 - 23:00 1.75 DRILL N PROD2 Log tie-in -14' 23:00 - 00:00 1.00 DRILL N PROD2 Directionally drill ahead f/ 10958. Freespin 3650psi C~3 1.62/1.62 ECD 12.21 ppg 10/31/2005 00:00 - 02:00 2.00 DRILL PROD2 Directionally drill f/ 10968'. 1.5711.57 Freespin 3625psi w/200-300psi mw 12.OOppg EDC Adding Lube 776 to mud system for better weight transfer. 2-3k wob 40-50'/hr 1 k CTW 02:00 -04:00 2.00 DRILL PROD2 Having problems with weight transfer just off bottom. Could be entering a fault. backeam 100' at opposite TF's. Slowly reaming back to bottom. Finally drilled through it. 04:00 - 06:45 2.75 DRILL PROD2 Directionally drill ahead f/ 11043' to 11065' 40'/hr then hit another wall. Ankorite 06:45 - 09:15 2.50 DRILL PROD2 Conduct wiper trip to window. Slight motor work at 9170'. 09:15 - 13:15 4.00 DRILL PROD2 Drill ahead. Q=1.55/1.55, 3700 press (3500 FS), -5.7K CTW/ 2.4K WOB, 11.9 ECD, 165U 90.3 deg, 5-10'/hr. 13:15 - 14:30 1.25 DRILL PROD2 Drilling break- 60-70'/hr. Q=1.5511.55, 3800 press, -2.9K CTW/ 1.5K WOB, 12.0 ECD, 90U 88.1 deg. 14:30 - 17:00 2.50 DRILL PROD2 Drill ahead through ankerite- 5-10'/hr with short bursts of 60-70'/hr. 0=1.55/1.55, 3600 press, -S.OK CTW/ 2.2K WOB, 12.0 ECD, 30U 84.6 deg. -~ 1515 hrs, changed TF to 75L. -1545 hrs, changed TF to 60R. 17:00 - 18:30 1.50 DRILL PROD2 Conduct wiper trip to window. Hole good. 18:30 - 18:45 0.25 DRILL PROD2 Log tie-in +16' 18:45 - 20:00 1.25 DRILL PROD2 RIH, no problem at OHST area, 20:00 - 22:00 2.00 DRILL PROD2 Directionally drilling ahead f/ 11227' (corrected depth) 1.6/1.6 freespin 3740psi drilling on hard spot as prior to wiper trip. TF 180deg dropping to 90deg incl from current nbi of 93.88deg, Broke through hard spot at 2050hrs 50'/hr 1-2k wob 400-500psi mw -1.5kCTW drilled to 11236' then hit another wall. 22:00 - 23:15 1.25 DRILL PROD2 Drill on Ankorite. 2-300psi mw -1 k wob 23:15 - 00:00 0.75 DRILL PROD2 Drilled through Ankorite. ROP 30'/hr 1-2k wob -4kCTW leveling off. Drilled to 11270' then hit Ankorite. NBI 90deg. 11/1/2005 00:00 - 02:10 2.17 DRILL P PROD2 Drilling on Ankorite at 11270'. No progress. Running out of weight transfer when hitting hard spot. Calling this TD. 02:10 - 03:15 1.08 DRILL P PROD2 Wiper trip to 8880'. 03:15 - 03:40 0.42 DRILL P PROD2 Log tie-in +11' Printed: 11!712005 9:58:20 AM Bp` Page 13 of 16 Operations Summary Report Legal Well Name: 10-04 - Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date Frorn -' To Hours Task Code NPT Phase - Description of Operations - 11/1/2005 03:40 - 05:00 1.33 DRILL P PROD2 RIH to bottom. Tagged at 11270'. 05:00 - 07:30 2.50 DRILL P PROD2 TOH. Lay-in 15bb1 hi-vis pill w/ 2#/bbl Alpine Beads 07:30 - 08:15 0.75 DRILL P PROD2 LD Drilling BHA, prep for running liner 08:15 - 08:30 0.25 CASE P PROD2 Conduct safety meeting for PU liner and running liner 08:30 - 10:15 1.75 CASE P PROD2 RIH w/ index shoe, 36 jts liner, billet 10:15 - 11:00 0.75 CASE P PROD2 PU {finer running BHA, injector head. 11:00 - 13:30 2.50 CASE P PROD2 RIH w/liner and liner BHA. Weight check on bottom, 29 klbs. Bring on pump. PU weight 18 klbs. Confirmed release from liner. 13:30 - 15:30 , 2.00 CASE ~ P PROD2 POH with liner running BHA. 15:30 - 16:00 I 0.50 CASE P PROD2 Lay down liner running BHA. 16:00 - 17;00 1.00 CASE C PROD2 Work on Swaco Choke, coil. 17:00 - 17:30 0.50 DRILL C PROD2 Make up BHA for sidetracking off of aluminum billett. 17:30 - 19:15 1.75 DRILL C PROD2 RIH with kickoff assembly. BHA #17, 19:15 - 19:30 0.25 DRILL C PROD2 Log tie in pass above window. Make -i4' correction. 19:30 - 20:20 0.83 DRILL C PROD2 RIH. Smooth thru window. Smooth in open hole. 20:20 - 20:45 ; 0.42 DRILL C PROD2 Kick pumps on to full rate. Free spin 3760 psi at 1.54 bpm. Tag up at 11057', 50' above whipstock. PU and orient to as '~ drilled toolface. RIH. Tagged up at 11055'. PU, shut-in pumps. RIH dry, and made it past the bad spot. RIH, dry and tag top of deployment sleeve/AI whipstock at 10099'. PU and ream up 30' with toolface at highside. 20:45 - 22:40 1.92 DRILL C ~ PROD2 Tag top of deployment sleeve with pumps at full rate, and TF at 30R. Time drill for 1 hour at 3 fph. Time drill at 6 fph for 30 min. Start pushing on it. Drilling at 20 fph. 22:40 - 23:10 0.50 DRILL C PROD2 Finish 20' of sidetrack. Pickup and run back down thru sidetrack clean. Ream back at 90L and 90R. Run up and down thru interval with TF=30 deg. No problems. Dry drift sidetrack with TF at 30R. 23:10 - 00:00 0.83 DRILL C PROD2 Sidetrack is clean. POOH to pick up build section BHA. 11/2/2005 00:00 - 01:15 1.25 DRILL C PROD2 Continue top POH. Held PJSM while POH to discuss BHA Swap. 01:15 - 02:30 1.25 DRILL C PROD2 Lay down BHA #17 with STR-324 bit. Readjust motor bend to " 1.0 deg. Pick up Hugfies bicenter bit. 02:30 -04:00 1.50 DRILL C PROD2 RIH with BHA #18 to begin drilling the lateral section of L1-03. 04:00 -04:20 0.33 DRILL C PROD2 Log tie in pass down over 8900'. Make -15' correction 04:20 - 05:00 0.67 DRILL C PROD2 Run to bottom in open hole. No problems at window, or in open hole. ,.- 05:00 - 07:30 2.50 DRILL C PROD2 Begin driNing lateral section from 10118'. 0=1.5!1.5, 3700 press, 2.3K CTW/ 1.3K WOB, 11.9 ECD, 90R/ 93.4 deg, 40-50'/hr. Drilled good to 10246' then rop slowed to 9'/hr. 07:30 - 10:15 2.75 DRILL C PROD2 Drilling ahead f! 10246' 1.55/1.55 freespin 3750psi 1-200psi mw ecd= 11.85ppg 2k wob <10'/hr 10:15 - 10:30 0.25 DRILL C PROD2 Conduct wiper trip to window. On way back down, tagging up in hole. Ream several times. Getting pressure spikes at surface and rubber coming over shakers. lost motor. POOH. 10:30 - 13:30 3.00 DRILL X PROD2 POOH 13:30 - 14:00 0.50 DRILL X PROD2 LD drilling BHA, C/O motor, bit fine- will be re-run. 14:00 - 14:15 0.25 BOPSU P PROD2 Perform weekly BOP function test while out of hole 14:15 - 15:30 1.25 GRILL X PROD2 PU BHA with new motor, test BHA and CTC. 15:30 - 18:10 2.67 DRILL X PROD2 RIH w/ drilling BHA to 8850. Log down at 2.5 fpm. -14.5' correction. Continue RIH. Slight set down at 9570' (shale). PU and work through it. Set down at top of L1-01 deployment Printed: 17!7/2005 9:58:20 AM gP Page 14 of 16 Operations Summary Report Legal Well Name: iQ-04 Common We11 Name: 1Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11!5/2005 Rig Name: NORDIC 2 Rig Number: Date Ftom - To ~ Hours Task Code NPT Phase Description of Operations 11/2/2005 15:30 - 18:10 2.67 DRILL X PROD2 sleeve at 10098'. Picked up and went thru it with pumps off ok. RIH to 10260'. 18:10 - 22:30 4.33 DRILL C PROD2 Tag bottom and resume drilling in Ankorite. Tool face 180 deg. ! Holding low side tool face to try to drill down out of Ankorite. PVT=383 bbls. IAP=300 psi, OAP=482 psi. Drilling at 1.56/1.57/3655 psi. 22:30 - 23:00 0.50 DRILL C PROD2 Broke out of the Ankorite. Drilling down at 85 deg as per Geo. Drillinga t 1.52/1.56/3700 psi. 1750 Ibs WOB. -1000 Ibs string wt. IAP=552 psi, OAP=625 psi. Free spin 3600 psi at 1.55 bpm. ECD=11.92 ppg. BHP=4085 psi. 23:00 -00:00 1.00 DRILL C PROD2 It was fun while it lasted. Back in the Ankorite. Drilling down j as per the Geo at 3 fph. 11/3/2005 00:00 - 06:45 6.75 DRILL C PROD2 ' Continue slow drilling in Ankorite. ROP=2 fph. TF=180 deg. NB Inc=85 deg. 1.58/1.6/3800 psi. WOB=2900 Ibs. String wt _ -2500 Ibs. ECD=11.99 ppg. BHP=4100 psi. Holding low side tool face trying to drill out of it. 06:45 - 08:00 1.25 DRILL C PROD2 Drilling break- 60-70'/hr. 0=1.5/1.5, 4200 press (and slowly inc i w/ a 4100 FS), 1.8K CTW/ 1.7K WOB, 11.85 ECD, 75U 86.5 ~ deg. Stuck. 08:00 - 08:10 0.17 DRILL C PROD2 Work pipe up and down several times. PU to 35K. Set back down. Can rotate orienter. Best estimate is differentially stuck between WOB sensor and motor. 08:10 - 08:25 0.25 DRILL C PROD2 SD pumps, hold 900 on choke. Hold pipe static for 15 minutes and see if we can free pipe. 08:25 - 10:30 2.08 DRILL C PROD2 ~ Pipe is on bottom, so PU to 46K, came free. PU to window and ~ clean hole, check pressures. Stiff high- 4100-4200 psi. 10:30 - 12:00 1.50 DRILL C PROD2 I Drill ahead. 0=1.48/1.48, 4300 press (4000 FS), -2.1 K CTW/ 2.4K WOB, 11.8 ECD, 45U 83.8 deg, 60-70'/hr. Get stuck again. 12:00 - 12:30 0.50 DRILL C PROD2 Work pipe several times. Differentially stuck again. Follow same procedure as this morning- SD pumps for 15 minutes. PU pipe to 29K, comes free and engage pumps. 12:30 - 12:45 0.25 DRILL C PROD2 Work pipe to clear BHA. PU to 10380', RBIH to bot. 12:45 - 15:45 3.00 DRILL C PROD2 Drill ahead. 0=1.44/1.44, 4000 press, 0 CTW7 1.6K WOB, 11.85 ECD, 135R/ 89.8 deg, 50-60'/hr -~ 1345, changed TF to 90R 15:45 - 16:45 1.00 DRILL C PROD2 Drill ahead- 5-10'/hr. Q= 1.4/1.4, 3600 press, -4.1 K CTW/ 1.OK WOB, 11.7 ECD, 60R/92.8 deg. 16:45 - 18:40 1.92 DRILL C PROD2 Conduct a wiper to window. 18:40 - 20:00 1.33 DRILL C PROD2 Tag bottom, and resume drilling Ankorite. PVT=388 bbls. IAP=640 psi, OAP=690 psi. WOB=1800 lbs. String wt = -8000 Ibs. ROP= 2 tph. ANN press = 4080 psi, Bore pressure = 4500 psi. ECD=11.88 ppg. 20:00 - 22:30 2.50 DRILL C PROD2 Drilling break. ROP=70 fph. Lets hope it lasts to TD. 22:30 - 22:45 0.25 DRILL C PROD2 Back in the Ankorite. INC=85 deg. Pfan to keep INC the same, and try to get back down thru ii ASAP. 22:45 - 23:10 0.42 DRILL C PROD2 Having trouble getting good weight to bit. There were a couple of directional changes in the last 100'. Make a backreaming pass up 100'. Mud drill solids currently at 0.8%. Cali for 100 bbls of new mud to see if that helps. 23:10 -00:00 0.83 DRILL C PROD2 Resume drilling Ankorite. Not able to get any WOB. PU, and scam bottom at 80 fpm. Get a momentary blip of motor work and WOB. Keep repeating it. Printed: 11!7/2005 9:58:20 AM BP Page 15 of 16 Operatiolns Summary Report Legal Well Name: 10-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14!2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5!2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/4/2005 00:00 - 03:45 3.75 DRILL C PROD2 Continue trying to nibble our way thru the Ankorite. Pump 100 bbls of new mud to see if it improves our ability to drill. Able to get good weight to bit. Able to drill now at slow ROP. 03:45 - 11:00 7.25 DRILL C PROD2 Continue slow ROP drilling in Ankorite. Adding an additional 100 bbls of new mud to pits to assist drilling. Total of 200 bbls of new mud added to the system. ROP is slow enough to suspect wom bit. Still able to see motor conducent with drilling other Ankorite sections 100-150psi. 11:00 - 13:20 2.33 DRILL C PROD2 TOH (opened ECD at 8900') following pressure schedule, closed SSSV trapping 950psi. PJSM while TOH. 13:20 - 14:20 1.00 DRILL C PROD2 L!D motor. P/U new motor and bit. Service UOC/LOC 14:20 - 15:50 1.50 DRILL C PROD2 TIH w/ BHA #20 15:50 - 16:10 0.33 DRILL C PROD2 Log tie-in -15' 16:10 - 17:15 1.08 DRILL C PROD2 TIH. Hole good shape. 17:15 - 18:00 0.75 DRILL C PROD2 Directionally drill ahead f/ 10585' 1.50/1.50bpm off-bottom 3680psi 100+ motonvork 3k wob 10'/tt 18:00 - 22:00 4.00 DRILL C PROD2 Drill ahead from 10588.2'. ROP slow in Ankorite. Drilling about 2 fph. PVT=414 bbls. IAP=428 psi, OAP=665 psi. Drilling at 1.5/1.51/3710 psi. Free spin is 3690 psi at 1.5 bpm. WOB=3400 lbs. String wt = -5300 lbs. BHP=4016 psi. ECD=11.69 ppg. 22:00 - 22:55 0.92 DRILL C PROD2 Discuss with town slow ROP in Ankorite, and that planned TD is only 100' away. Town decided to call this TD. Make wiper trip to window. Clean PU off bottom at 21500 lbs. Pulled heavy before popping free at 10094', top of aluminum billett deployment sleeve for L1-01 lateral finer. Ran back down thru it and back up slick. 22:55 - 23:10 0.25 DRILL C PROD2 Log tie in pass above window. Make +4.5` correction. 23:10 - 23:25 0.25 DRILL C PROD2 Run back in hole on wiper. Set down at 9150' with as drilled tool face of 120R. Orient to high side, and set down again. Try it with pumps off and still set down. 23:25 - 23:50 0.42 DRILL C PROD2 Orient to 100 R, as drilled tool face, and ream back down thru it at 2 fpm. Got thru it ok, and reamed up. No motor work ' observed on up pass. Run back down thru it again. 23:50 -00:00 0.17 DRILL C PROD2 Continue in hole on wiper trip. 11/5/2005 00:00 - 00:45 0.75 DRILL C PROD2 Continue back in hole with wiper trip. No problems to bottom. 00:45 - 02:45 2.00 DRILL C PROD2 POH with lateral section BHA, laying in liner pill. New flowpro mud with 4% lubetex, 1.5% EMI-~96, and 3#/bbl of Alpine course glass beads. Pill was pumped thru the motor with a closed EDC. 02:45 - 03:05 0.33 DRILL C PROD2 PJSM prior to laying down BHA #20. 03:05 -04:00 0.92 DRILL C PROD2 Stand back injector. Lay down BHA #20. Bit recovered with no obvious wear, graded 1,1. Reconfigure BHA for running liner. 04:00 -04:20 0.33 CASE C RUNPRp Hold PJSM prior to running liner. All rig hands, SWS hands, MWD and DD in attendence. Also 2 visiting BP engineers. Discuss job proceedure, hazards, and mitigations to hazards. 04:20 - 07:15 2.92 CASE C RUNPRD Make up 2-3/8" liner BHA. BHA consists of; BHI tools BTT Deployment Sleeve 1 - 10' Solid pup jt. 3 -Full solid joints 42 -Slotted jts BTr O-Ring Sub Printed: i inizoos ssazo ann gp' Page 16 of 16 Operations Summary Report - Legal Well Name: 1Q-04 Common Well Name: 1Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date From -'To 'Hours Task Code NPT Phase Description of Operations 11/5!2005 04:20 - 07:15 2.92 CASE C RUNPRD 1 -Full solid jt. BTT biased edge guide shoe Total BHA length = 1545.67'. Held kick drill when on first joint of slotted liner. Good responce from all hands. 07:15 - 09:50 2.58 CASE C RUNPRD RIH slow and open SSSV continue RIH. Weight check at window 23.4k. RIH bump at 9160-70' tagged bottom at 10611'. PU 45' (29.4k} then R4H to 10581'. (depths uncorrected) Closed EDC. Bring on pump. Dropped liner pu wt 19.8k. 09:50 - 10:15 0.42 CASE C RUNPRD PU to logging depth. Log tie-in corrected -14' 10:15 - 10:25 0.17 CASE C RUNPRD RIH tag TOL ai 9061' 10:25 - 12:25 2.00 CASE C RUNPRD TOH. Displace wellbore with seawater to 2500' then FP with diesel to surface. Close SSSV trapping 850psi beneath it. 12:25 - 13:20 0.92 CASE C RUNPRD UD liner running tools. 13:20 - 17:00 3.67 RIGD C POST Load coil with 15 bbls diesel and blowdown to Tiger Tank with N2. Froze a line and spent some time unthawing it. RD N2 equipment and bleed down coil. 17:00 - 18:00 1.00 RIGD C POST Setback injector and prep to drop reel from reel house. 18:00 - 18:30 0.50 RIGD C POST Shutdown operations for crew change. Hoid PJSM for spooling coil out of injector and back on reel. We will also be conducting a SIMOP's with Nordic hands working on replacing a leaking suction valve in the pits. No conflict between the 2 operations is expected. 18:30 - 20:00 1.50 RIGD C POST Unstab pipe from injector. Spool pipe back onto injector. Work on replacing leaking suction valve in pits. 20:00 - 20:45 0.75 RIGD C POST Break down hardline to reel. Take injector gooseneck off to change rollers. Rig down packoff and set injector on the deck to facilitate changing gripper blocks. 20:45 - 21:00 0.25 RIGD C POST PJSM prior to lowering reel onfo flatbed. Held in Ops cabin with SWS and Veco truck drivers. 21:00 - 22:45 1.75 RIGD C POST Lower reel out of reel house. Con#inue to work on Injector. 22:45 -00:00 1.25 RIGD C POST Change out rams in BOP stack for 2-318° coil. Change out horses head for 2-3/S" coil. Nipple down tree and secure in cellar for move. Rig released at midnight. Further telex entries carried on 10-02 DIMS reports. Printed: 11J7/2005 9:58:20 AM • Well: 10-04 / L1 / L1-02 / L1-01 / L1-03 Accept: 10/14/05 {in Order Drilled) Spud: 10/17/05 Field: Kuparuk River Field Release: 11/05/05 POST RIG WORK 11/07/05 DRIFT W/2.8 SWAGE TO XN AT 9051' RKB. SBHPS STOPS AT 9050' RKB AND 8913' RKB. 11/11!05 RAN LDL USING TECWELL NOISE TOOL: PUMPED DIESEL DOWN IA MAINTAINING IS PRESS AT 2200-2500 PSI WHILE LOGGING, WELL SHUT 1N. 11/14/05 TESTED IA 2500 PSI, LOST 200 PSI IN 10 MIN. SET 3-1/2" AVA CATCHER AT 9051' RKB. 11/15/05 CHANGE OUT DV AT 7588' RKB, FIRST WITH EXT. PKG, THEN TO WTR INJ PKG. MIT IA FAILED. ATTEMPTED TO IDENTIFY LEAK LOCATION WITH TEST TOOL, TOOL FAILED. 11/16/05 PULLED DV AT 7588' WLM. REPLACED USING WTR INJ PKG ON DV. RAN TEST TOOL, SET BELOW GLM. TESTED TBG, IA COMMUNICATING. GOOD COMBO MIT. SET TOOL ABOVE GLM, COMBO MIT FAILED. DV APPARENTLY LEAKING. PULL TEST TOOL. 11/17/05 PULLED CATCHER SUB AT 9051' RKB. DRIFTED TBG WITH 21' X 2.74" DUMMY PATCH TO 8245' WLM. 11/29/05 SET 3.5" WEATHERFORD DUAL ECLIPSE TUBING PATCH {2 RUNS} FROM 7580' - 7602'. 12/01/05 SET 2.75" GATHER SUB ON TOP OF PATCH AT 7580' RKB. RAN DANDD HOLE FINDER TO 7580' RKB, TBG TEST FAILED, SLOW LEAK TBG TO IA. PULLED 1" DV AT 7113' RKB. ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Survey Report 13AKEdd HUGHES 1'~ 11~.~ ~ - - Company: ConocoPhiliips Alaska, Inc. llate: 11!15/2005 Time: 11:34:10 Page: I ~~ Field: Kuparuk River Unit Co-ordinnte(NE) Reference. Well. 4, True North Site: KRU 10 Pad Vcrfical (TVD) Reference: SITE 90.0 Well: 4 Section (VS) Reference: Well (O.OON,O.OOE,12.OOAzi) Wellpath: 10-04L1-01 Survey Calculation Method: Minimum Curvature ~ Db: .Oracle Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 i Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004 j Site: KRU 1Q Pad UNITED STATES: North Slope Site Position: Northing: 5985877.04 ft Latitude: 70 22 20.956 N From: Map Easting: 529617.73 ft Longitude: 149 45 33.406 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 4 Slot Name: Well Position: +N/-S -1227.00 ft Northing: 5984645.99 ft ~ Latitude: 70 22 8.888 N +E/-W -1057.00 ft Easting : 528565.70 ft ' Longitude: 149 46 4.325 W Position Uncertainty: 0.00 ft Wellpath: 1 Q-04L1-01 Drilled From: 1 O-04L1 Tie-on Depth: 9185.72 ft Current Datum: SITE Height 90.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/14/2005 Declination: 24.10 deg Field Strength: 57607 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 90.00 0.00 0.00 12.00 Survey Program for Definitive Wellpath Date: 9/14/2005 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 9000.00 GMS (100.00-9535.00) (0) Good gyro Good Gyro 9066.00 9185.72 MWD (9066.00-10895.00) (1) MWD MWD -Standard 9198.00 11270.00 MWD (9198.00-11270.00) MWD MWD -Standard Annotation ft ft 9185.72 6672.09 TIP 9198.00 6677.91 KOP from L1 10270.00 6724.32 TD Survey: MWD Start Date: 11/1/2005 Company: Baker Hughes INTEO Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Baker Hu hes INTE Conoc©Phillfps g Q ~A~~~ ~~~~~~ Baker Hughes INTEQ Survey Report r'!~t ~:, -- - -- _ _- _ _ - - - - - _-- _ ___ _ _l Company: ConocoPhillips Alaska, Inc. Date: 11/15/2005 Time: 11:34:10 Page: 2 Field: Kuparuk River Unit Co-ordinate(1\F.) Reference: Well: 4, True North i Site: KRU 1Q Pad ~'crtiad (TVD) Reference: SITE 9D.0 Well: 4 Section (VS) Reference: Well (O.OON,O.OOE,I2.OOAzi) LWcllpath_iQ-04L1-01 Snrvcy Calculation Nicthod: Minimum Curvature Dh: Oracle Survey 'VID Inel Azim TVD SSTVll \{S FM' iVlapN DtapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 9185.72 61.19 96.04 6672.09 6582.09 2702.87 5151.44 5987368.22 533706.27 3714.85 0.00 MWD 9198.00 62.23 102.23 6677.91 6587.91 2701.15 5162.10 5987366.54 533716.95 3715.38 45.18 MWD 9230.10 72.72 $9.94 6690.23 6600.23 2698.14 5191.49 5987363.65 533746.34 3718.55 48.09 MWD 9261.30 75.24 79.03 6698.87 6608.87 2701.03 5221.28 5987366.65 533776.12 3727.57 34.56 MWD 9290.09 76.98 67.00 6705.80 6615.80 2709.19 5247.95 5987374.91 533802.75 3741.10 41.01 MWD 9321.73 81.30 59.82 6711.77 6621.77 2723.10 5275.70 5987388.93 533830.45 3760.47 26.13 MWD 9352.93 88.94 52.57 6714.42 6624.42 2740.38 5301.49 5987406.30 533856.17 3782.74 33.69 MWD 9380.29 92.23 41.58 6714.14 6624.14 2758.98 5321.49 5987424.98 533876.10 3805.09 41.92 MWD 9410.92 92.20 29.69 6712.96 6622.96 2783.81 5339.29 5987449.87 533893.80 3833.08 38.79 MWD 9440.62 91.92 25.43 6711.89 6621.89 2810.12 5353.02 5987476.23 533907.43 3861.66 14.37 MWD 9473.70 91.89 20.38 6710.79 6620.79 2840.56 5365.89 5987506.72 533920.18 3894.12 15.26 MWD 9501.47 91.73 15.88 6709.91 6619.91 2866.93 5374.52 5987533.12 533928.71 3921.71 16.21 MWD 9531.99 91.03 8.66 6709.17 6619.17 2896.73 5381.00 5987562.94 533935.07 3952.20 23.76 M W D 9560.86 92.56 5.67 6708.27 6618.27 2925.35 5384.60 5987591.58 533938.56 3980.95 11.63 MWD 9591.22 93.03 2.51 6706.79 6616.79 2955.60 5386.76 5987621.82 533940.61 4010.98 10.51 MWD 9621.44 91.21 357.41 6705.67 6615.67 2985.78 5386.74 5987652.01 533940.47 4040.50 17.91 MWD 9655.36 92.59 354.80 6704.54 6614.54 3019.60 5384.44 5987685.81 533938.04 4073.11 8.70 MWD 9700.23 88.57 358.13 6704.09 6614.09 3064.37 5381.67 5987730.57 533935.11 4116.32 11.63 MWD 9730.95 86.36 1.99 6705.45 6615.45 3095.05 5381.70 5987761.25 533935.02 4146.34 14.47 MWD 9762.03 87.89 6.90 6707.01 6617.01 3125.99 5384.11 5987792.19 533937.31 4177.10 16.53 M W D 9792.03 87.77 11.36 6708.15 6618.15 3155.58 5388.87 59$7821.79 533941.95 4207.03 14.86 MWD 9821.98 88.79 15.43 6709.05 6619.05 3184.70 5395.80 5987850.93 533948.77 4236.95 14.00 MWD 9853.44 89.43 20.13 6709.53 6619.53 3214.64 5405.40 5987880.91 533958.26 4268.24 15.08 MWD 9881.75 84.12 22.05 6711.13 6621.13 3241.00 5415.57 5987907.31 533968.32 4296.14 19.94 MWD 9910.66 88.51 24.85 6712.98 6622.98 3267.46 5427.05 5987933.81 533979.70 4324.41 18.00 MWD 9941.85 89.62 29.34 6713.49 6623.49 3295.22 5441.25 5987961.62 533993.79 4354.51 14.83 MWD 9971.70 89.28 33.05 6713.78 6623.78 3320.74 5456.70 5987987.20 534009.15 4382.69 12.48 MWD 10001.83 87.13 36.94 6714.72 6624.72 3345.41 5473.97 5988011.93 534026.32 4410.41 14.75 MWD 10035.12 91.46 33.39 6715.13 6625.13 3372.61 5493.13 5988039.20 534045.38 4441.00 16.82 MWD 10066.97 87.83 29.93 6715.33 6625.33 3399.71 5509.85 5988066.36 534061.99 4470.98 15.74 MWD 10096.45 88.94 24.76 6716.16 6626.16 3425.88 5523.38 5988092.58 534075.42 4499.39 17.93 MWD 10127.50 86.82 23.72 6717.31 6627.31 3454.17 5536.12 5988120.91 534088.05 4529.71 7.60 MWD 10158.71 83.34 19.30 6719.99 6629.99 3483.09 5547.51 5988149.87 534099.33 4560.37 17.98 M W D 10189.59 89.12 16.09 6722.02 6632.02 3512.43 5556.87 5988179.24 534108.58 4591.01 21.40 MWD 10226.37 88.88 11.89 6722.66 6632.66 3548.10 5565.76 5988214.95 534117.33 4627.75 11.44 MWD 10260.26 87.06 6.17 6723.86 6633.86 3581.53 5571.08 5988248.40 534122.52 4661.56 17.70 MWD 10290.83 88.63 1.95 6725.01 6635.01 3612.00 5573.24 5988278.87 534124.56 4691.81 14.72 MWD 10320.57 88.26 357.74 6725.82 6635.82 3641.72 5573.16 5988308.59 534124.37 4720.86 14.21 MWD 10350.89 88.20 354.23 6726.76 6636.76 3671.95 5571.04 5988338.80 534122.13 4749.99 11.57 MWD 10381.42 89.77 357.65 6727.30 6637.30 3702.39 5568.87 5988369.23 534119.85 4779.32 12.32 MWD 10412.64 90.17 0.74 6727.31 6637.31 3733.60 5568.44 5988400.44 534119.30 4809.76 9.98 MWD 10442.78 89.31 5.38 6727,45 6637.45 3763.69 5570.04 5988430.53 534120.79 4839.52 15.66 MWD 10475.14 91.49 7.84 6727.23 6637.23 3795.83 5573.77 5988462.68 534124.39 4871.74 10.16 MWD 10506.58 92.69 10.26 6726.08 6636.08 3826.86 5578.71 5988493.72 534129.21 4903.11 8.59 MWD 10539.02 89.09 13.38 6725.57 6635.57 3858.60 5585.35 5988525.48 534135.73 4935.54 14.68 MWD 10570.14 89.40 17.04 6725.98 6635.98 3888.62 5593.52 5988555.53 534143.78 4966.60 11.80 M W D 10603.34 92.96 19.50 6725.30 6635.30 3920.13 5603.92 5988587.08 534154.06 4999.59 13.03 MWD 10634.07 90.91 22.24 6724.26 6634.26 3948.82 5614.86 5988615.81 534164.89 5029:93 11.13 MWD 10665.00 91.21 26.94 6723.69 6633.69 3976.94 5627.72 5988643.97 534177.65 5060.10 15.22 MWD 10695.86 91.98 30.80 6722.83 6632.83 4003.94 5642.61 5988671.04 534192.44 5089.61 12.75 MWD 10725.71 90.69 33.92 6722.14 6632.14 4029.15 5658.58 5988696.30 534208.31 5117.59 11.31 MWD 10754.04 88.33 37.97 6722.38 6632.38 4052.08 5675.21 5988719.29 534224.84 5143.47 16.54 MWD 10784.27 84.40 37.01 6724.29 6634.29 4076.01 5693.57 5988743.29 534243.11 5170.70 13.38 M W D r ~~~ER ConocoPhillips .Baker Hughes INTEQ ~~~~~, Baker Hughes INTEQ Survey Report ~~ i ~, ~~ - Companp: ConocoPhiliips Alaska, Inc. Date: 11/15/2005 Timc: 11:34: 10 Page: 3 Nield: Ku paruk Rive r Unit Co-ordinate(NE) Reference: Well: 4, T rue North Site: KRU 1Q Pad t'crtic al (TVD) Reference: SITE 90.0 Well: 4 Sectio n (VS ) Reference: Well (O.OON,O .OOE,12.OOAzi) ~, Welipath: 10-041-01 Sur~~cy Calculation Method : Minimum Curvature Ub: Oracle Curvev MD Incl Azim TAD SS TVD - N/S F/W iMapN MapE ~'S -- DLS 'Cool ~ ft deg deg ft ft ft ft ft ft ft deg/100ft 10818.88 83.57 36.72 6727. 92 6637. 92 4103. 55 5714 .22 5988770 .90 534263. 65 5201 .93 2.54 MWD 10856.22 81.88 31.26 6732. 65 6642. 65 4134. 24 5734 .92 5988801 .67 534284. 23 5236 .25 15.19 MWD 10885.30 84.97 29.51 6735. 98 6645. 98 4159. 16 5749 .53 5988826 .64 534298. 74 5263 .67 12.19 MWD 10915.04 88.51 26.53 6737. 67 6647. 67 4185. 36 5763 .47 5988852 .90 534312. 59 5292 .20 15.55 MWD 10946.04 92.14 25.03 6737. 50 6647. 50 4213. 27 5776 .95 5988880 .85 534325. 96 5322 .30 12.67 MWD 10976.82 94.76 21.98 6735. 65 6645. 65 4241. 44 5789 .20 5988909 .07 534338. 10 5352 .40 13.05 MWD 11007.78 91.12 20.08 6734. 06 6644. 06 4270. 30 5800 .29 5988937 .96 534349. 08 5382 .93 13.26 MWD 11037.66 90.38 13.49 6733. 67 6643. 67 4298. 88 5808 .92 5988966 .58 534357. 59 5412 .68 22.19 MWD 11067.66 90.08 9.02 6733. 55 6643. 55 4328. 30 5814 .77 5988996 .01 534363. 34 5442 .67 14.93 MWD 11100.76 88.02 5.26 6734. 09 6644. 09 4361. 13 5818 .88 5989028 .86 534367. 32 5475 .64 12.95 MWD 11129.38 84.57 2.77 6735. 94 6645. 94 4389. 61 5820 .88 5989057 .34 534369. 21 5503 .92 14.85 MWD 11158.14 86.73 357.63 6738. 13 6648. 13 4418. 28 5820 .98 5989086 .01 534369. 20 5531 .98 19.34 MWD 11187.28 91.06 355.05 6738. 69 6648. 69 4447. 35 5819 .12 5989115 .06 534367. 23 5560 .02 17.30 MWD 11219.79 93.43 359.55 6737. 41 6647. 41 4479. 78 5817 .59 5989147 .49 534365. 58 5591 .43 15.63 MWD 11270.00 93.43 359.55 6734. 41 - 6644. 41 4529. 90 5817 .20 5989197 .60 " 534364. 99 5640 .38 0.00 MWD ~- KRU 1Q-04 L1/L~1/L1-02/L1-03 Produe~ CTD Completion rev.2 ConocoPhillips A{aska, Inc. H 3-'.&" Baker 'FVL SSSV set at 1815' RKB, 2.912" 10 9-SIB" 36# J-55 casing ~ 4622' G. 3-112" 9.3rd J-55 EUE &d Mod tubing wl 3.112" x 1" Camco 'KBtJG' mandr~als F. 3-'h' x 1-'h" Camco MMG mandrel E. Baker 3-112" FHL packer at 8586' RKB wNh PBRlseal assembly D. Camco &112' MMG prod mandrels at 8604', 8674', and 8972' RKB C-sand perfs 2-3r8' liner tap ~4 9061' hID Top of Cement KOP at 9076' MD (6616 TVD) Window in 7" C. Baker 3-112' FB-1 packer a19013' RKB wrfh PBRlseal a9semt,)Fy B 3-'~~" Camco D nipple with 2.75' ID at 9051' RKB A. 3-1r'2" tubing fait at 9085' RKB (9W5' ELM) 3" openhole L1-01, TD ~ 11270' and (6734' tvd ) permit 205-140 KOP Q 9198' and (6678' tvd} \ L 1-{:3, TD ®1059T and \ (6716' tvd) 0 0 4 4 P ~ , oas9' Q d (6716' tvd) L1-02, TD {a7 10934' and (6626' tvd }permit 205-155 ~ T 26# J 55 rs~ 9511' MO 2-3f8" slotted liner KOP @ 10061' and (6664' tvd) L 1, TD rz 10895' md, (6612' tvd) perrTVt 205-139 DEV 4~7r05 • • KRU 1 Q-04L1-01 ConocoPhillips Alaska, Inc. • -~. ~~~ °~ `- a Eye 5 0yi s t - -~ ^~ ~ , ~ ••~ a 1C4I~T~l~l[I~~l7CIO1~T C41-~5'-~I~i~T Steve Mukavitz Kuparuk Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK Re: Kuparuk River, 1 Q-04L 1-01 Sundry Number: 306-015 Dear Mr. Mukavitz: • FRANK H. MURKOWSK/, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907)279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice fora ,r~pre~entative of the Commission to witness any required test. Contact :the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehe~~ring is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~~day of January, 2006 Encl. ~~--- ~- t ConocoPhillips January 10, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Steve Mukavitz Drilling Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4021 Subject: Application for Sundry Approval for 1Q-04L1, 1Q-04L1-01, 1Q-04L1-02 and 1 Q-04L1-03 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Applications for Sundry Approval for the Kuparuk multilateral well 1Q-04L1, 1Q-04L1-01, 1Q-04L1-02-and 1Q-04L1- 03. We are planning to workover this well to pull and replace the tubing. The Nordic 2 rig will be used for this work. If you have any questions regarding this matter, please contact me at 263-4021. Sincerely, (~ , Steve ukavitz Drilling Engineer CPAI Drilling and Wells SM/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,. RECE~l~." JAN 1 ~ rli+h APPLICATION FOR SUNDRY APPROVAL `" 20 AAC 25.2so Alaska Oii & bas ~`~;-.<. ~.ctfnmssion 1. Type of Request: Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Waiver A~t 8~$ Other ^ Alter casing ^ Repair well Q Plug Pertorations ^ Stimulate ^ Time F~ctension ^ Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 205-140 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21250-61 7a KB Elevation (ft): 9. Well Name and Number: RKB 33' 1Q-04L1-01 8. Property Designation: 10. Field/Pool(s): ADL 025634 Kuparuk River Field /Kuparuk Oil Pool 11. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth M~ (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11270' 6734' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 103' 103' SURFACE 4589' 9-5/8" 4622' 3571' PRODUCTION 9478' 7" 9511' 6706' L1-01 slotted liner 1168' 2-3/8" 11270' 6734' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): s7os'-11268' 6347'-6735' 3-1/2" J-55 9085' Packers and SSSV Type: Packers and SSSV MD (ft) Baker'FHL' pkr, Baker'FB-1' pkr @ 8566', 9013' Camco'FLV' SSSV @ 1815'.. 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 20, 2006 Oil ~ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Mukavitz @ 263-4021 Printed Name Stet/ MUkaVItZ Title: Kuparuk Drilling En ineer Signature ~/ Phone Date. ~ t 1 ~~ Commission Use Only Conditions of a roval: Notif Commission so that a re resentative ma witness Sundry Number. `~ y p y pp Plug Integrity ^ BOP Test ,. ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~J~p~i ~JL/~~~-C9`> ~GC\'~C~ ~) II((yy1//1~r~r /„„/~~ 6 ~~ ~ ! 6UaL Subsequent Fo q 're . APPROVED BY /~ /~ ~~~ ` J Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 7!2005 ~ ~ ~~ Submit in Duplicate ~ ~~ w • ~RU 1Q-04L1-01 ,~ ~gnacaPh~lfii~s ~~aska, Enc. TUBING (o-sobs, OD:3.500, ID2.992) Perf (8709-8719) Perf (8722=8726) Perf (8735-8740) Perf (8742-8753) Perf (8756-8764) Pert (8771-8777) Perf (8834-8881) Perf (8914-8928) CEMENT (9021-9511, OD:7.000) Perf :10116-11268) ~: ~` • ~_ I r" I'~-~= 1 ~~ ~ i - I, - ~I• _, I I -- Casing String - L1-01 SLOTTED L{NER (LATERAL LEG L1-01 NOT ACCESSIBLE) Descri tion T Size To Bottom TVDj Wt Grade Thread L 01 SLOTTED LINER .375 ~ 10102 ~ 11270 ~ 11270 4.60 L-80 STL ~Casinn Strinn<-"RnMMC}N STRINGS Descri tion Size To Bottom TVD Wt Grade Thread PRODUCTION 7.000 0 9511 6710 26.00 CONDUCTOR 16.000 0 103 103 62.50 SURFACE 9.625 0 4622 3571 36.00 L1-03 LINER TOP 2.650 9061 9167 6663 4.60 STL L1-03 SLOTTED LINER _TOP _ _ 2.650. 9167 10102 6716 4.60 STL _ Tubin~Strin -TUBING _ ___ _ _Size ~_Top Bottom TVD ~ Wt Grade= Thread 3.500 111~~~ 0 ~ 9085 ', 6621 _ ',_ 9.30 J-55 _~_ EJE 8rd _ _ Parfnratinnc .Summary Interval TVD Zone Status Ft SPF Date T e Comment 8709 - 8719 6347 - 6354 10 12 4/24/2005 (PERF 120de h; 5" Scallo ed HDC 8722 - 8726 6357 - 6360 4 12 4/24/2005 IPERF 120de h; 5" Scallo ed HDC 8735 - 8740 6366 - 6370 5 12 4/24/2005 {PERF 120de h; 5" Scallo ed HDC 8742 - 8753 6372 - 6380 11 12 4/24/2005 IPERF 120de h; 5" Scallo ed HDC 8756 - 8764 6382 - 6388 8 12 4/24/2005 (PERF 120d h' S" Scallo ed HDC 8771 - 8777 6393 - 6398 6 12 4/24/2005 (PERF 120de h; 5" Scallo ed HDC 8834 - 8881 6440 - 6475 47 12 4/24/2005 IPERF 120de h' S" Scallo ed HDC 8914 - 8928 6499 - 6509 14 12 4/24/2005 (PERF 120de h' S" Scallo ed HDC 10116 - 11268 6717 - 6735 1152 99 11/1/2005 Slots Li-01 SLOTTED LINER .r • • Rig Workover -Description Summary of Proposal Well 1Q-04 Kuparuk Producer Replace Tubing and Repair 7" Wellhead Packing ^ Verify well. is dead. A retrievable bridge plug will have been set in the 3-1/2" tubing below the upper packer and tested from above. The well will be loaded with kill weight fluid and a BPV set. .Nipple down tree. and nipple up and test BOP (pressure test BOP to 3500 psi, based on maximum anticipated. surface pressure of 2700 psi). ^ Pull seals from PBR. If the seal assembly will not release from the PBR, chemical cut tubing in first full joint above the seals. ^ POOH with tubing to SSSV. Seta 7" storm packer and change out the tubing spool and packing to repair the chronic-7" x 9-5/8" packing leak. Nipple'up and function test the BOP. Close blind rams and pressure test tubing-spool and packing. POOH with storm packer and remaining 3-1l2" .tubing and gas lift completion. ^ Run a new string of 3-1/2" 9.3# L-80 tubing and a new gas lift completion (will not re-run SSSV). If the tubing was chemical cut, run a "poorboy" overshot and new FHL packer above the 3-1/2" tubing stub. ^ Space out and test. Nipple up-the tree and test.- SJM/ 1-11-06 • Subject: Re: Kuparuk temporary flow approval - 1Q-04-(184-234) °~ t-~ L.,s~- \~ From: Thomas Maunder <tom_maunder@admin.state:ak.us> r Date:Thu. (11 T)ec. ?~)0~ 07:~O:13 -U~100 - ~~ To: NSK Prohler~~ V4~ell Supv <n1Ci17(u conocophillips.com> -- (~ ~ CC: ,lim Re~~`< <jimre~~~r~ ad~~~irl.state.ak.us== ~~1 Jerry, The original was a gas lifted producer and that is what the plan is for the well "complex". The gas lift pressure is much lower than the 2500 psi test pressure applied in the unsuccessful MIT. Bringing the well on for cleanup is acceptable. If the rig is delayed into the the new year, it would be appropriate to consider where the well falls in the SCP rules and apply the approval/waiver process. Keep us informed regarding the wells performance (pressure behavior) and the anticipated arrival of N3S. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 11/30/2005 5:36 PM: Tom: Kuparuk producing well 1 Q-04 (PTD 1842340) was recently sidetracked by the Coiled Tubing Drilling unit (Nordic 2). During the safeout for drilling T x IA communication was discovered, the repair of which was delayed until CTD was finished with the well. Subsequent to CTD a Leak Detect Log was ran which found a leak in the tubing. There were also indications two possible additional small leaks. Yesterday (11/29) a patch was set across the primary leak and today the MIT failed. We suspect the additional leaks are present and repairing these is not the preferred option. The well is now being considered for a tubing swap to replace the old with new (Nabors 3S). The T x IA communication is not severe; the 2500 psi MITIA equalized with the tubing pressure in 25 minutes. The well will require gaslift to produce and the communication is expected to have minimal impact on the lift performance. Of immediate concern is that CTD left the multi-laterals full of FloPro drilling mud. To prevent formation damage we would like approval to flow the well for a period not to exceed 14 days in order to fully clean up the perforations/laterals. The well will be shut-in and secured at that point until the workover can be performed. The ETA for the rig is expected to be near the end of December. Please let me know if we have approval to flow 1 Q-04 for a period not to exceed 14 days. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 1 of 1 12!1/2005 7:56 AM r~ 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: ,€3f~3,. rE'g ~ ~! ~~t~i~3_s~~t_f,~ ~c.us JJ lf ~~ ,,St a f~ c~e;i~R~":...1 :l.~~A ~~~~~?., i3c':.'v` ~c.~C3:~~i~~ .`f,r~.F~:s"~t\.~.e ~.a .., : , C_.___9..??~'.::._E'-F1S~£3E~;tU ~L~ t~"_ t _ 3,S~c~'~f,~?C _~i ~4 Contractor: Nordic Rig No.: 2 DATE: 10/27/05 Rig Rep.: Mckeirnan / Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Eiden / Sevcik/Feketi E-Mail~~~ac~~~~~~icrE.~~ic~~c?~1~~us~E~E~~~~?:~_~r3 Well Name: 1Q-04L1-01 PTD# ~t-~ Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 250-3500 Annular: 250-3500 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3100 P CHOKE MANIFOLD: Pressure After Closure 2200 P Quantity Test Result 200 psi Attained 0:22 P No. Valves 14 P Full Pressure Attained 1:33 P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 21500 Test Results Number of Failures: 0 Test Time: 4.5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the N orth Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~3r:~3__,rE~g~ ~~~rti~3_.~~~~f__~X_u Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES NO X c - Oper./Rig Waived By c -Database Date 10/27/05 Time 0800 c -Trip Rpt File Witness Jeff Jones AOGCC c -Inspector Test start 1130 Finish 1600 Coil Tubing BFL 11/09/04 Nordic 2 BOP 10-27-05p.xls Re: 1 Q CTD sidetracks -naming convention • i Subject: Rc: lQ CTD sidetracks - t1a~~~in« convention >Frort~: Thomas Maunder atom maunder~cz admin.state.ak.us> Date: Fri, 09 Sep ?U0~ 10:>5:?7 -0500 To: "Ve.~~t~aus, llan ~" <=Dan.E.Venhat~s('~L`conocophillips.com,=> CC: GanttLL cr,~~BP.con1, Sean.IvleLau~hlin'uI3P.con~; Steve Davies ===stove davies<<i?admin.slate.ak.us= Dan, Naming is fun. Based on the drawings and your discussion, I would agree with your plan on 1 Q-04 to name the new penetrations -04L I and -04L 1-01. On 1 Q-02, I believe the new penetration name should be 1 Q-02B. There are 2 issues here.. In 1 Q-04, you are keeping the original C sand perfs at that BHL and establishing new A sand BHLs. After the work, production will be "coming" from 3 distinct BHLs. The new penetrations are properly called laterals. On 1 Q-02A, the entire present completed interval will be plugged and a new take point established. Since (at this time), none of the old interval will be retained the new penetration is properly given the "B" designation. Adding C sand perfs later will not change the BHL. I hope this helps. Thanks for checking. Tom Maunder, PE AOGCC Venhaus, Dan E wrote, On 9/9/2005 10:38 AM: Tom, We are preparing to drill two CTD sidetracks on wells 1 Q-02A and 1 Q-04 sometime in October. I want to run the proposal by you to make sure our naming convention is consistent. I have enclosed proposed completion schematics for more detail. 1 Q-04 producer Completion is currently a 3-1/2" selective single with C-sand perfs behind the straddle. We plan to cement off the A-sand perfs only and will sidetrack from the motherbore below the bottom packer just above the A-sand. We will drill an A-sand lateral south and complete with a liner with aluminum KO billet. We will then sidetrack off the billet from the first lateral and drill another A-sand lateral north. Since we are technically not abandoning the entire wellbore (C-sand is currently isolated via dummy valves in the production mandrels), I would name these 2 laterals as 1Q-04L1 and 1Q-04L1-01. And I assume we will need to file a sundry for the A-sand pert abandonment. «1Q-04 CTD proposed completion.word.doc» 1 Q-02A infector Current completion is a 4-1/2" monobore injector with perfs in the C and A sands. The well has a suspected channel between the A & C. We plan to cement squeeze both the A & C and exit the casing via whipstock just above the A-sand. The existing A-sand perfs will remain covered/squeezed with cement. We will drill just one lateral and complete with slotted liner. The liner top will terminate inside the motherbore casing but will be below the C-sand for future access to perforate. Note that since this is a monobore we are not mechanically required to use cement to exit the casing. The squeeze is for isolation purposes for injection control after the sidetrack. Therefore, I would assume we would file a sundry for the squeeze and the drilling permit would label the sidetrack 1Q-02AL1. 1 of 2 9/23/2005 10:41 AM Re: 1Q CTD sidetracks -naming convention «1 Q-02A CTD proposed completion.word.doc» The real question? Does partial abandonment of the production zone constitute these as laterals or sidetracks? If sidetracks then the naming convention would become 1 Q-04A & 1 Q-04AL1 and 1 Q-02B? Please give me a call if you need more clarification. Thanks, Dan Venhaus Wells/CTD Engineer ConocoPhillips AK, Inc. 907-263-4372 office 907-230-0188 cell 2 of 2 9/23/2005 10:41 AM ~~' ar~s ~' ~ '~ 11;~ a ~ dt ~ ~ 1 ~~~ ~ f { ~ ~ _~ 1~ ~. r~ ~' ~;'~ jam' ~~~ ~~~~ ~ ~a t~ I j i {~ t ~ a{ AI.ASSA OII, A1~TD GA5 COI~TSER~ATIOIK COl-iMI55I0I~T Sean McLaughlin CT Drilling Engineer Conoco Phillips Alaska Inc. P.O. Box 196612 Anchorage, AK 99519-6612 P R~ FRANK H. MURKOWSKI, GOVERNOR ~f 7 7 333 W. T" AVENUE, SUITE 100 ~'' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: KRU IQ-04L-Ol Conoco Phillips Alaska Inc. Permit No: 205-140 Surface Location: 1227' FNL, 1057' FEL, SEC. 26, T12N, R09E, UM Bottomhole Location: 3364' FSL, 4791' FWL, SEC. 24, T12N, R09E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleu~r-~ield inspector at (907) 659- 3607 (pager). Chairman DATED this day of month, 2005 cc: Department of Fish 8~ Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA IL AND GAS CONSERVATION CO~ISSI©N PERMIT TO DRILL - 2o aac 25 ons ~~~~ 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ° 11. Well Name and Number: Kuparuk 1Q-04L1-01 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~ MD 11350' TVD 6703ss 12. Field /Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): Surface: ~ 1227' FNL 1057' FEL SEC 26 T12N R09E UM 7. Property Designation: ADL 025634 River Pool , , . , , , Top of Productive Horizon: 1313' FSL, 3800' FWL, SEC. 24, T12N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 20, 2005 Total Depth: 3364' FSL, 4791' FWL, SEC. 24, T12N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 21,300' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528566 r y- 5984646 ' Zone- ASP4 10. KB Elevation (Height above GL): gp feet 15. Distance to Nearest well Within Pool 1 Q-03 is offset by 1100' 16. Deviated Wells: Kickoff Depth: 9210 -feet Maximum Hole Angle: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3100 Surface: 2449 ' 1 Casing Program: Size. Specfications Setting. Depth To Bcsttom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2285' 9065' 6594' 11350' 6703' Uncemented Slotted Liner 19. PRESENT WELL CONDIT ION SUMMARY (To be completed for RedriA AND Re-entry Opera#ions) Total Depth MD (ft): 9535 Total Depth TVD (ft): 6935 Plugs (measured): None Effective Depth MD (ft): 9365 Effective Depth TVD (ft): 6818 Junk (measured): 9051 Casing Length Size Cement Volume MD TVD t n t r 103' 16" 240 sx Coldset II 103' 103' 4622' 9-5/8" 1100 sx CS III, 500 sx CS I, TJ: 60 sx CSI 4622' 3570' r 6918 Pr tion 9511' 7" 80 sx Class 'G' 9511' 'n r Liner, L1 2090' 2-3/8" Uncemented Slotted Liner 9210' - 11300' 6620' - 6533' Perforation Depth MD (ft): 8709' - 9303' Perforation Depth TVD (ft): 6345' - 6775' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer (~ Prepared By Name/Number: Si nature tom- .mod Phone 564-4387 Date l ZZ o Terrie Hubble, 564-4628 Commi Sion Use Only Permit To Drill Number: 1 Q j / API Number: (~ ~~' 50- 029-21250- r `3 ~~ ~ ~ Permit A proval Date: • (~~ See cover letter for other requirements Conditions of Approval: Samples uired ^ Yes No Mud Log Required [] Yes ~No Hydro n S Ifide Measures Yes ^ No Directional Survey R"e~quired (Yes ^ No Other: 3.~ l~ "` O~ ~ s~~c,,~~rw`. ~ C,~c"t cy,.+~C~~ ~®~ ~So~~~ ~c~ .)C~-!!~ c~LC~~~~c ~-~ Y ~ ~C ~S,e~~C~ APPROVED BY A A roved B THE COMMISSION Date ~/ Form 10-401 RevisedTfi1~P964 ~ O R I G I [~ A ~ JSubmit Yh Duplicate KRI~-04L1 & 1 Q-04L1-01 Sidetracks - ~ed Tubing Drilling Summary of Operations: A coiled tubing drilling unit will drill 2 laterals in producer KRU 1 Q-04 using the managed pressure drilling ~ technique (MPD, see description below). These horizontal laterals will target Kuparuk A sand reserves for production. CTD Drill and Complete 1Q-04L1 & 10-04L1-Ol program: Planned for October 20, 2005 Pre-Rig Work 1. Positive pressure and drawdown tests on MV and SV 2. Test Packoffs - T&IC 3. Dummy GLV's 4. MIT-IA, MIT-OA 5. Caliper 3-1/2" liner, memory GR/CCL log 6. Cement 7" casing in preparation for a cement ramp exit Rig Work 7. MIRU Nordic 2. NU 7-1/16" BOPE, test. 1 -04L 1 8. Mi112.74" window off a cement ramp. Plan the top of ramp to start at 9080'. 9. Drill 3" bicenter hole horizontal lateral from window to 1 1300' TD targeting Kuparuk A sands. 10. Complete with a 2 segmented 2 3/8" slotted liner from TD to 9210' md. An aluminum billet will be on top o e second liner to use as a KOP for L1-O1. Use SS or liner run. 1 O-04L 1- 1 ]. Mill 2.74" window off the aluminum billet at 9210'.' ~ ~ ~`~ ~~~"~ 12. Drill 3" bicenter hole horizontal lateral from window to 11350' TD targeting Kuparuk A sands. ° 13. Complete with a 2 segmented 2 3/8" slotted liner from TD, to 9065'. Use SSSV for liner run. 14. ND BOPE. RDMO Nordic 2. ,,/ Post Rig work 15. Post CTD rig -Run GLVs. Mud Program: • Step 8: chloride-based biozan brine (8.6 ppg) • Steps 9-14: chloride-based Flo-Pro (8.6 ppg) Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: , • 1 Q-04L 1: 2 3/8", 4.6#, L-80, STL slotted liner from 9210' and to 11300' and • 1 Q-04L 1-01: 2 3/8", 4.6#, L-80, STL slotted liner from 9065' and to 11350' and Casing/Liner Information 9 5/8", J-55, 36#, Burst 3520; collapse 2020 psi. 7", J-55, 26#, Burst 4140; collapse 2900 psi 3'/z", J-55, 9.3#, Burst 6990; collapse 7400 psi Well Control: • Two well bore volumes 0160 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. KR~-04L1 & 1 Q-04L1-01 Sidetracks - ~ed Tubing Drilling Directional • See attached directional plans for 1Q-04L1 & iQ-04L1-Ol • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1Q-04L1 is 1Q-23 which is offset by 415'. KPA boundary is 21900' away. • The nearest well to 1 Q-04L 1-01 is 1 Q-03 which is offset by 1100'. KPA boundary is 21300' away. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. Hazards Each lateral will cross two mapped faults. Lost circulation risk is moderate. ' Expect to encounter increasing pressure as lateral is drilled away from the mother well. Well 1Q-04 has a H2S reading of 110 ppm: Well 1Q-21 has recorded 220 ppm H2S. All H2S monitoring equipment will be operational. Reservoir Pressure • The most recent SBHP survey (7/05) was gauged at 2,200 psi after having been SI for just 3.5 days. After pressure stabilization expect a SBHP of 2400psi to 2500psi.`Expect to encounter increasing pressure as lateral is drilled away from mother well. Max. expected pressure of 3100 psi.`The EMW is 9.2 ppg at 651 1' TVD (L1 invert point). Max. surface pressure with gas (0.1 psi/ft) to surface is 2449 psi. _ Variance request QCC~~Q~~~ ~ ~/~~ • BPXA requests a variance to the provisions of 20 A C 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 1Q-04 it will be routine to close the 2-3/8" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability- Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be .installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. This well has a tubing retrievable sub-surface safety valve that will be utilized to facilitate BHA deployments and liner running. However, it is still possible that deployment of the BHA under trapped wellhead pressure would be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2- 3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 3100 psi at 6511' TVD, 9.2 ppg EMW. ~ • Expected annular friction losses while circulating: 1017 psi (based on 90 psi/1000 ft) • Planned mud density: 8.6 ppg equates to 2912 psi hydrostatic bottom hole pressure. • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3929psi or 11.6 ppg ° ECD • When circulation is stopped, a minimum of 1017 psi surface pressure will be applied to ~ maintain constant BHP. ~ i ' KRU 1 Q-04 ConocoPhiliips Alaska, Inc. ~~ ~o-oa API: 500292125000 Weli T : PROD le TS: 41 d 8708 SSSV T : TRDP Ori Com etion: 3/19/1985 An le TD: 46 9535 Annular Fluid: Last W/O: Rev Reason: GLV des' n Reference Ref L Date: Last U te: 7/10/2005 Last Ta : 9365 TD: 9535 ftKB Last Ta Date: 4/6/2005 Max Hole le: 53 5400 - Casin Strin -ALL STRINGS Descri tlon Size T Bottom TVD V1It Grade Thread CONDUCTOR 16.000 0 103 103 62.50 FI-40 SUR. CASING 9.625 0 4622 3571 36.00 J-55 PROD. CASING 7.000 0 9511 6920 26.00 J-55 Tubin Strip -TUBING ' Size To Bottom TVD Wt Grade Thread _ 3.500 0 9085 6623 9.30 J-55 EUE 8RD Pertorations Summa ~_ Interval TVO Zone Status Ft SPF Date T Comment 8709 - 8719 6347 - 6354 C-4 10 12 4/24/1985 IPERF 120d h•5"Scalb HDC 8722 - 8726 6357 - 6360 C-4 4 12 4/24/1985 IPERF 120de 'S"Scallo HDC 8735 - 8740 6366 - 6370 C-4 5 12 4/24/1985 IPERF 120d h•5"Scallo HDC 8742 - 8753 6372 -6380 C-4 11 12 4/24/1985 IPERF 12 h•5"Scallo d HDC 8756 - 8764 6382 - 6388 C-4 8 12 4/24/1985 IPERF 12 h•5"Stall HDC 8771 - 8777 6393 - 6398 C-3 6 12 4!24/1985 IPERF 120d h•5"Scallo HDC 8834 -8881 6440 -6475 C-1 UNIT B 47 12 4/24/1985 IPERF 12 h•5"Stall HDC 8914 -8928 6499 - 6509 UNIT B 14 12 4/24/1985 IPERF 12 h•5"Scall HDC 9157 - 9164 6674 - 6679 A-4 7 4 10/4/1993 RPERF 2.5" Titan Follow 180 deg. ph; Orient 27 . CCW F/ 9164 - 9224 6679 - 6721 A-4,A-3 60 8 10/4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 . CCW F/ __ 9285 - 9303 6764 - 6776 A-2 18 8 10/4/1993 RPERF 2.5"Titan Follow 180 deg. ph; Orient 27 . CCW F/ Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD latch Port TRO Dste Run Vtv Cmnt 1 1957 1819 Camco KBUG DMY 1.0 BK2 0.000 0 3/13/1994 - 2 3383 2760 Camco KBUG GLV 1.0 BK2 0.125 1320 5/25/2002 3 4099 3234 Camco KBUG DMY 1.0 BK2 0.000 0 4f25l1985 4 4637 3580 Camco KBUG DMY 1.0 BK2 0.000 0 3/13/1994 5 5177 3923 Camco KBUG DMY 1.0 BK2 0.000 0 4125/1985 6 5751 4280 Camco KBUG GLV 1.0 BK2 0.156 1352 5/25/2002 7 6224 4579 Camco KBUG OMY 1.0 BK2 0.000 0 5!12!1994 8 6698 4887 Camco KBUG DMY 1.0 BK2 0.000 0 9/26/1993 1 9 7113 5177 Camco KBUG DMY 1.0 BK2 0.000 0 5/25/2002 10 7588 5519 Camco KBUG GLV 1.0 BK2 0.188 1382 5/25/2002 11 8095 5887 Camco KBUG DMY 1.0 BK 0.000 0 5/25/2002 12 8506 6194 Camco MMG-2 OV 1.5 RK 0.188 0 9/2/2004 1. BK latch 6698' RKB bent sl' ht u out of cket; Ref.' WSRs 12/19-201'99 Production Mandrels/Valves St MO ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vhr Cmnt 13 8604 6268 Camco MMG-2 DMY 1.5 RKP 0.000 0 5!6/2005 Closed 14 8674 6321 Camco MMG-2 DMY 1.5 RKP 0.000 0 5/7/2005 Closed 15 8972 6541 Camco MMG-2 DMY 1.5 RKP 0.000 0 1/28/2003 Ckued Other I s ui ,etc . -JEWELRY th TVD T Desrxt 'on ID 1815 1714 SSSV Baker'FVL' 2.812 8552 6229 SBR Baker PBR 2.992 8566 6239 PKR Baker'FHL' 3.000 9013 6571 PKR Baker'FB-1' 4.000 9051 6598 NIP Camco'D' Ni le NO GO 2.750 9084 6622 SOS Camco 2.992 9085 6623 TTL 2.992 Fish - Histo of FISH Oe Destxi on Comment 9051 & PI from CR Plan to Push down to Tubin Tail. 9119 27' of 1 7/8" Tool Stri Tod Strip bst in rathole 5/8/94• wire recovered 5110/94• Fish hist in WSR. 9530 DMY VALVE 1.5" DMY valve set 9/15/02, but during check for DMY on 1/27/03, impression of em socket• 9!15/02 DMY dro • de rat krawn. KRU 1 Q-04 L 1 ~ -01 Producer Proposed CTD Completion 9-5/8" 36# J-55 casing @ 4622' 2-3/8" liner top @ +/-9065' MD Top of Cement KOP at +/-9080' MD Window in 7" • ~.% . . ConocoPh~llips Alaska, Inc. H. 3-'h" Baker 'FVL' SSSV set at 1815 RKB, ^e.812" IC G. 3-1 /2" 9.3# J-55 EUE Srd Mod tubing w/ 3-1 /2" x 1"Camco 'KBUG' mandrels F. 3-'/z" x 1?/z" Camco MMG mandrel E. Baker 3-1/2" FHL packer at 8566 RKB with PBR/seal assembly D. Camco 3-1 /2" MMG prod mandrels at 8604', 8674', anc 8972 RK8 ~._ C-sand perfs C. Baker 3-1/2" FB-1 packer at 9013 RKB with PBR/seal assembly B. 3-'/z" Camco D nipple with 2.75" ID at 9051 RKB A. 3.112" tubing tail at 9085 RKB (9075 ELM) 3" openhole Openhole KOP @ 9210' and (using aluminum billet) ' / A-sand North t~teral (t_1-01) , TO --''' @ 11350' and ~ ` ` ` 2-3/8" slotted liner A-sand South Lateral (L1), TD @ 11300' and ~. 7" 26#J55 Cal _~~:~:~~i:~i~i;i~:~i~i~i~i~i~a~ 9511' MD DEV sn/o5 • BP Amoco weuraTM oeruu rr. a +cu~+m r.r.x wxrr.ar rra v +o-wu rr.. ra n+odo Rx. DrWe~ Ory /ITaprr W.0a11 Y ~Mr .Wi °FHY i TW IL00' O.eO OLe M.00 REFERENCE INFORMATION Co-ordinate N/E Reference: WeA Centre: 4, True NorN Vertlcal D Reference: System: Mean Sea level Section (VS Reference: Slot- (O OON,O.OOE) Measured Depth Reference: SITE 90.00 Calwlauon Method: Minimum Curvature k ar o a nw n.°. n,we W+oaq MN »a. a+N.ta t tllam 1]!0 i1+f.Y a1M.H _ TII.1 ~ .]T.A ~ M ]!C.]. N~+.At ~ou N29.a S~ .~~W a]flta .OJi i r°o'ni's °n:ee aa+ °wwn uw.ia m m.a .nas. iim an ro~ f I~rpm aT~i a~; iwa aIN.~ nal,{i MNAp {np.N r al~om ii~.~u aSA% MYI ) al~il.~ arxHBi ll~M~ji a. ar .+oa.M +a.M ties iw .v ti°r rv~m° ifrYt' ~ .v..x ~ p°a~M~ liry.~ ~~~M~- - redL~aiiry~ili b~ioam ml1 SpD.s~ Mr LEGEND T Plan: Plan p6 (4/Plan 6, tO-O4L1-01) ~~~ _ a taoa) Azimuths to True North gai~ii< 4 (was T.10-0au) M Magnetic North: 24.10° creates 13y sa Michaelson oats: 9no2oos 6~1D-04L1-ot IILi~il1E3 by Magnetic Field Comas mfu~maron Strength: 57607nT s~!~ Mmhae!son Dip Angle: 80.78° Direct. (907) 267-6624 ~~ Date: 9/14/2005 CciP. (907) 301-73570 Modal: bggm2004 E-mad: biu.michaelsonQinteq.com West(-)/East(+) [200ft/in] Vertical Section at 12.00° (50ft/in] 8400 6600 5400 5450 5500 5550 PM ConocoPhillips • • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~ Company: ConocoPhillips Alaska, Inc. Date: 9/20/2005 T Time: 14:22:56 Page: 1 Field: Kuparuk River Unit Co-or~inate(NE) Reference: Well: 4, True North Site: KRU 1Q Pad Vertical (TVD) Reference: SITE 90.0 Well: 4 Section {v5) Reference: Well (O.OON,O.OOE,I2.OOAzi) Wellpath: Plan 6. 1Q-04L1-01 Rurvev Cale~datinn Methods Minimum Curvature r nh~ (~rarla Field: Kuparuk River Unit North Slope 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: bggm2004 Site: KRU 1 Q Pad UNITED STATES: North Slope Site Position: Northing: 5985877.04 ft Latitude: 70 22 20.956 N From: Map Easting: 529617.73 ft Longitude: 149 45 33.406 W Position Uncertainty: 0.00 ft North Referenee: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 4 Slot Name: Well Position: +N/-S -1227.00 ft Northing: 5984645.99 ft ` Latitude: 70 22 8.888 N +E/-W _1057.00 ft Easting : 52$565.70 ft - Longitude: 149 46 4.325 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, 1Q-04L1-01 Drilled From: Plan 7, 1Q-04L1 Tie-on Depth: 9210.00 ft Current Datum: SITE Height 90.00 ft Alwve System Datum: Mean Sea Level Magnetic Data: 9/14/2005 Declination: 24.10 deg Field Strength: 57607 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (1'VD) +N/-S +E/-W Direction ft ft ft deg 90.00 0.00 0.00 12.00 Plan: Plan #6 Date Composed: 9/14/2005 Copy Lamar's Plan 6 Version: 5 Principal: Yes Tied-to: From: Definitive Path Targets Name Description Dip. Dir 1Q-04L1-01 Polygon -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 1Q-04L1-01 Fault 1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 1Q-04L1-01 Fault2 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 1Q-04L1-01 Target2 1Q-04L1-01 Target 1 TVD ft +N!-S ft +E!-W ft Map Map Northing Fasting ft ft <- Latitude -> Deg Min Sec <--- Longitude -> Deg Min Sec 90.00 2630.71 5132.88 5987296.00 533688.00 70 22 34.743 N 149 43 34.128 W 90.00 2630.71 5132.88 5987296.0 533688.00 70 22 34.743 N 149 43 34.128 W 90.00 2764.14 5549.44 5987431.00 534104.00 70 22 36.053 N 149 43 21.936 W 90.00 3341.03 5593.64 5988008.00 534146.00 70 22 41.726 N 149 43 20.629 W 90.00 4585.42 6048.44 5989254.00 534596.00 70 22 53.961 N 149 43 7.290 W 90.00 4738.44 6049.02 5989407.00 534596.00 70 22 55.466 N 149 43 7.270 W 90.00 4714.83 5683.89 5989382.00 534231.00 70 22 55.236 N 149 43 17.958 W 90.00 4382.83 5673.63 5989050.00 534222.00 70 22 51.971 N 149 43 18.266 W 90.00 3434.68 5373.98 5988101.00 533926.00 70 22 42.650 N 149 43 27,056 W 90.00 2842.21 5269.70 5987508.00 533824.00 70 22 36.822 N 149 43 30.120 W 90.00 2765.69 5142.40 5987431.00 533697.Ofl 70 22 36.071 N 149 43 33.846 W 90.00 40$3.85 5398.45 5988750.00 533948.00 70 22 49.033 N 149 43 26.326 W 90.00 4083.85 5398.45 5988750.00 533948.00 70 22 49.033 N 149 43 26.326 W 90.00 3882.88 5647.71 5988550.00 534198.00 70 22 47.054 N 149 43 19.035 W 90.00 3681.91 5896.97 5988350.00 534448.00 70 22 45.076 N 149 43 11.745 W 90.00 3882.88 5647.71 5988550.00 534198.00 70 22 47.054 N 149 43 19.035 W 90.00 4207.81 5412.93 5988874.00 533962.00 70 22 50.252 N 149 43 25.899 W 90.00 4207.81 5412.93 5988874.00 533962.00 70 22 50.252 N 149 43 25.899 W 90.00 4006.84 5662.19 5988674.00 534212.00 70 22 48.273 N 149 43 18.609 W 90.00 3805.86 5911.45 5988474.00 534462.00 70 22 46.295 N 149 43 11.318 W 90.00 4006.84 5662.19 5988674.00 534212.00 70 22 48.273 N 149 43 18.609 W 6725.00 3326.64 5433.57 5987993.00 533986.00 70 22 41.585 N 149 43 25.314 W 6732.00 2917.66 5416.01 5987584.00 533970.00 70 22 37.563 N 149 43 25.837 W ~/ Co~nocaPhdl~ps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report tcv~rEQ ' Company: ConocoPhillips Alaska, inc. Date: 9/2012045 Time: 14:22:56 Page 2 ~ Field: Kuparuk R iver Unit Co-ordinate(NE) &eference: WeN: 4, True North Site: KRU 1 Q Pad Vertical (TYD} Reference: SITE 90.0 Wetl: 4 Section NS) Referene: Weil (O.OON,D.OOE,I2.OOAzi) Wellpath_Plan 6, 1Q -- -04L1-01 ~_ __ ~ Survey Cal~vlation Method: Minimum Curvature Db: Qracte Targets Map Map <_. Latftude --~ <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Fasting Deg .Mtn Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1Q-04L1-01 Target 3 6770.00 3982.85 5657.10 5988650.00 534207.00 70 22 46.038 N 149 43 18.758 W 1Q-04L1-01 Target4 6793.00 4609.27 5828.51 5989277.00 534376.00 70 22 54.197 N 149 43 13.727 W Annotation MD TVD I ft l- ft -- 9210.00 6683.91 KOP from L1 9230.00 6690.32 2 9270.00 6699.33 3 9468.09 6727.51 End 30°1100' DLS 9599.39 6732.11 5 9774.39 6728.02 6 9974.39 6724.94 7 10199.39 6737.21 8 10399.39 6759.72 9 10574.39 6769.88 10 10600.00 6769.92 Fault 1 10700.00 6770.08 11 10725.00 6770.19 Fault 2 10900.00 6774.70 12 11200.00 6787.03 13 11350.00 6793.09 TD Plan Section -- Information ( MD Incl Azim TVD +N1-S -AEI-W DLS Bui3d Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg ;, 9210.00 68.68 99.39 6683.91 2715.11 5166.97 0.00 0.00 0.00 0.00 9230.00 73.90 96.27 6690.32 2712.54 5185.73 30.00 26.12 -15.59 330.00 9270.00 80.13 85.74 6699.33 2711.90 5224.63 30.00 15.58 -26.33 300.00 9468.09 $5.00 25.94 6727.51 2817.52 5379.21 30.00 2.46 -30.19 270.00 9599.39 91.00 11.36 6732.11 2941.47 5421.01 12.00 4.57 -11.11 292.00 9774.39 91.65 350.36 6728.02 3115.42 5423.62 12.00 0.37 -12.00 272.00 9974.39 90.09 14.31 6724.94 3313.78 5431.73 12.00 -0.78 11.98 93.50 10199.39 83.77 40.62 6737.21 3511.35 5534.25 12.00 -2.81 11.69 104.00 10399.39 83.50 16.47 6759.72 3684.63 5628.51 12.00 -0.14 -12.07 268.00 10574.39 89.91 356.42 6769.88 3857.27 5647.91 12.00 3.66 -11.45 287.00 10700.00 89.91 11.50 6770.08 3982.22 5656.57 12.00 0.00 12.00 90.00 10900.00 87.48 35.38 6774.70 4164.33 5735.51 12.00 -1.21 11.94 96.00 11200.00 87.96 359.36 6787.03 4445.72 5823.51 12.00 0.16 -12.01 270.00 11350.00 87.44 17.36 6793.09 4593.40 5845.21 12.00 -0.35 12.00 92.00 Survey MD Incl Azim SS TVD N1S E!W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg1100ft ft deg 9210.00 68.68 99.39 6593.91 2715.11 5166.97 5987380.53 533721.76 0.00 3730.06 0.00 MWD 9225.00 72.59 97.03 6598.88 2713.10 5180.98 5987378.56 533735.77 30.00 3730.99 330.00 MWD 9230.00 73.90 96.27 6600.32 2712.54 5185.73 5987378.03 533740.53 30.00 3731.44 330.78 MWD 9250.00 76.96 90.94 6605.36 2711.33 5205.04 5987376.89 533759.84 30.00 3734.27 300.00 MWD 9270.00 80.13 85.74 6609.33 2711.90 5224.63 5987377.54 533779.42 30.00 3738.90 301.34 MWD 9275.00 80.14 84.22 6610.18 2712.33 5229.53 5987377.99 533784.33 30.00 3740.34 270.00 M W D 9300.00 80.26 76.61 6614.45 2716.43 5253.80 5987382.18 533808.58 30.00 3749.40 270.26 MWD 9325.00 80.54 69.01 6618.62 2723.72 5277.33 5987389.55 533832.08 30.00 3761.41 271.56 MWD 9350.00 80.99 61.42 6622.64 2734.05 5299.72 5987399.97 533854.42 30.00 3776.18 272.83 MWD 9375.00 81.60 53.86 6626.43 2747.27 5320.58 5987413.27 533875.23 30.00 3793.45 274.05 MWD 9400.00 82.35 46.32 6629.92 2763.14 5339.55 5987429.21 533894.14 30.00 3812.92 275.19 MWD 9425.00 83.23 38.82 6633.07 2781.39 5356.32 5987447.52 533910.83 30.00 3834.26 276.25 MWD / ~ • fillips Baker Hughes INTEQ Baker Hughes INTEQ Flanning Report iii/ :` INTE(~ ~ Company: ConocoPhillips Alaska, Inc. Date: 9/2012005 Time: 14:22:56 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Re ference: Well: 4, True North Site: KRU 1 Q Pad Vertical(TVA) Reference: $iTE 90.0 Well: 4 Section (VS) Reference: Well (O.OON ,O.OOE,I2.OOAzi) Wellpath: Plan 6, 1Q-04L1-01 ~_ Survey Calculation Method: Minimum Curvature Db: CYacle J Survey MD Inel Azim SS TVD N/S E/W MapN Map>: DLS VS ~ TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9450.00 84.22 31.34 6635.80 2801.72 5370.58 5987467.90 533925.02 30.00 3857.10 277.19 MWD 9468.09 85.00 25.94 6637.51 2817.52 5379.21 5987483.73 533933.59 30.00 3874.35 278.01 MWD 9475.00 85.31 25.17 6638.09 2823.73 5382.18 5987489.95 533936.53 12.00 3881.04 292.00 MWD 9500.00 86.44 22.38 6639.89 2846.55 5392.23 5987512.81 533946.50 12.00 3905.45 292.07 MWD 9525.00 87.58 19.61 6641.19 2869.85 5401.18 5987536.14 533955.35 12.00 3930.11 292.27 M W D 9550.00 88.73 16.83 6641.99 2893.58 5408.99 5987559.90 533963.07 12.00 3954.94 292.41 MWD 9575.00 89.88 14.06 6642.30 2917.68 5415.65 5987584.02 533969.64 12.00 3979.89 292.50 MWD 9600.00 91.00 11.28 6642.10 2942.06 5421.13 5987608.42 533975.03 11.98 4004.89 292.04 MWD 9625.00 91.11 8.29 6641.64 2966.69 5425.38 5987633.07 533979.18 12.00 4029.86 272.00 MWD 9650.00 91.21 5.29 6641.14 2991.51 5428.33 5987657.89 533982.04 12.00 4054.75 271.94 MWD 9675.00 91.30 2.29 6640.59 3016.45 5429.98 5987682.83 533983.59 12.00 4079.49 271.88 MWD 9700.00 91.40 359.29 6640.00 3041.43 5430.32 5987707.82 533983.84 12.00 4104.00 271.82 MWD 9725.00 91.49 356.29 6639.37 3066.41 5429.36 5987732.78 533982.78 12.00 4128.22 271.75 M W D 9750.00 91.57 353.29 6638.70 3091.29 5427.09 5987757.66 533980.42 12.00 4152.09 271.67 MWD 9775.00 91.65 350.43 6638.00 3116.02 5423.52 5987782.37 533976.75 11.42 4175.54 271.54 MWD 9800.00 91.46 353.43 6637.32 3140.76 5420.01 5987807.10 533973.15 12.00 4199.01 93.50 MWD 9825.00 91.27 356.42 6636.73 3165.fi5 5417.80 5987831.98 533970.85 12.00 4222.90 93.58 MWD 9850.00 91.08 359.42 6636.21 3190.63 5416.90 5987856.95 533969.85 12.00 4247.14 93.65 MWD 9875.00 90.88 2.41 6635.79 3215.62 5417.30 5987881.94 533970.15 12.00 4271.67 93.72 MWD 9900.00 90.68 5.41 6635.44 3240.56 5419.00 5987906.88 533971.76 12.00 4296.42 93.77 MWD 9925.00 90.48 8.40 6635.19 3265.37 5422.01 5987931.70 533974.67 12.00 4321.31 93.81 MWD 9950.00 90.28 11.39 6635.02 3290.00 5426.30 5987956.34 533978.87 12.00 4346.29 93.84 MWD 9975.00 90.07 14.38 6634.94 3314.36 5431.88 5987980.72 533984.35 12.00 4371.29 94.10 MWD 10000.00 89.34 17.29 6635.07 3338.41 5438.70 5988004.79 533991.08 12.00 4396.23 104.00 MWD 10025.00 88.62 20.21 6635.52 3362.08 5446.73 5988028.49 533999.03 12.00 4421.05 103.99 MWD 10050.00 87.90 23.12 6636.28 3385.30 5455.96 5988051.74 534008.16 12.00 4445.68 103.93 MWD 10075.00 87.18 26.04 6637.35 3408.01 5466.35 5988074.49 534018.46 12.00 4470.05 103.84 MWD 10100.00 86.48 28.96 6638.73 3430.15 5477.87 5988096.67 534029.90 12.00 4494.11 103.72 MWD 10125.00 85.78 31.88 6640.42 3451.66 5490.50 598811823 534042.44 12.00 4517.77 103.56 MWD 10150.00 85.09 34.81 6642.41 3472.47 5504.19 5988139.09 534056.06 12.00 4540.98 103.36 MWD 10175.00 84.42 37.75 6644.70 3492.54 5518.92 5988159.21 534070.71 12.Ofl 4563.67 103.13 MWD 10200.00 83.77 40.54 6647.28 3511.80 5534.64 5988178.54 534086.35 11.43 4585.78 103.23 MWD 10225.00 83.67 37.53 6650.01 3531.10 5550.29 5988197.89 534101.92 12.00 4607.91 268.01 MWD 10250.00 83.59 34.51 6652.79 3551.20 5564.90 5988218.04 534116.45 12.00 4630.60 268.34 MWD 10275.00 83.53 31.49 6655.59 3572.03 5578.43 5988238.92 534129.90 12.00 4653.79 268.67 MWD 10300.00 83.49 28.47 6658.41 3593.54 5590.84 5988260.48 534142.23 12.00 4677.42 269.01 MWD 10325.00 83.47 25.45 6661.25 3615.68 5602.10 5988282.66 534153.40 12.00 4701.41 269.35 MWD 10350.00 83.46 22.43 6664.10 3638.38 5612.18 5988305.39 534163.40 12.00 4725.71 269.70 MWD 10375.00 83.47 19.41 6666.95 3661.57 5621.04 5988328.62 534172.17 12.00 4750.24 270.04 MWD 10400.00 83.52 16.40 6669.78 3685.21 5628.68 5988352.28 534179.72 11.99 4774.94 270.77 MWD 10425.00 84.40 13.51 6672.41 3709.22 5635.09 5988376.32 534186.04 12.00 4799.77 287.01 MWD 10450.00 85.30 10.64 6674.66 3733.57 5640.30 5988400.68 534191.16 12.00 4824.67 287.31 MWD 10475.00 86.22 7.77 6676.51 3758.18 5644.29 5988425.30 534195.05 12.00 4849.57 287.57 M W D 10500.00 87.14 4,91 6677.96 3782.98 5647.05 5988450.11 534197.71 12.00 4874.40 287.78 M W D 10525.00 88.06 2.06 6679.00 3807.91 5648.57 5988475.04 534199.14 12.00 4699.10 287.95 MWD 10550.00 89.00 359.21 6679.65 3832.89 5648.84 5988500.03 534199.32 12.00 4923.60 288.07 MWD 10575.00 89.91 356.50 6679.88 3857.87 5647.88 5988525.E 534198.25 11.43 4947.83 288.59 MWD 10600.00 89.91 359.50 6679.92 3882.85 5647.00 5988549.98 534197.29 12.00 4972.08 90.00 MWD 10625.00 89.91 2.50 6679.96 3907.85 5647.44 5988574.97 534197.63 12.00 4996.62 90.00 MWD 10650.00 89.91 5.50 6680.00 3932.78 5649.18 5988599.91 534199.27 12.00 5021.37 89.99 MWD 10675.00 89.91 8.50 6680.04 3957.59 5652.23 5988624.73 534202.22 12.00 5046.28 89.99 MWD 10700.00 89.91 11.50 6680.08 3982.21 5656.57 59$8649.36 534206.47 12.00 5071.26 89.98 MWD 10725.00 89.60 14.48 6680.19 4006.57 5662.18 5988673.74 534211.99 12.00 5096.25 96.00 M W D '~ fillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report >li~rr~c~ Company: ConocoPhillips Alaska, Inc. Date: 9/20!2005 Tome: 14;22:56 Pagc: 4 ~ Field: Ku paruk Rive r Unit Co-ordinate(1~iE) Reference: Well: 4, Tru e North Site: KRU 1Q Pad Vertleai (TVD) Reference: S{TE 90.0 ~ Well: 4 Sectiea (VS) Reference: Weft (O.OON ,O.OOE,I2.ODAzi) Wetlpath: Ptan 6, 1Q-04L1-01 Survey Calculation Metbod: Minimum Curvature Db: Qracle Survey ~ MD incl Azlm SS TVD N1S E!W MapN MapE DLS VS TFO Tool i ~ ft deg deg ft ft ft ft ft deg/100ft ft deg 10750.00 89.29 17.47 6680.43 4030.60 5669.06 5988697.79 534218.78 12.00 5121.19 95.99 MWD 10775.00 88.98 20.45 6680.81 4054.24 5677.18 5988721.46 534226.81 12.00 5146.00 95.96 MWD 10800.00 88.67 23.43 6681.32 4077.42 5686.52 5988744.67 534236.06 12,00 5170.61 95.91 MWD 10825.00 88.36 26.42 6681.97 4100.08 5697.05 5988767.37 534246.50 12.00 5194.97 95.85 MWD 10850.00 88.06 29.41 6682.75 4122.16 5708.75 5988789.49 534258.11 12.00 5219.00 95.77 MWD 10875.00 87.77 32.39 6683.66 4143.59 5721.58 5988810.97 534270.86 12.00 5242.63 95.68 MWD 10900.00 87.46 35.38 6684.70 4164.33 5735.50 5988831.76 534284.70 12.00 5265.81 95.57 MWD 10925.00 87.49 32.38 6685.79 4185.06 5749.43 5988852.54 534298.54 12.00 5288.98 270.00 MWD 10950.00 87.50 29.38 6686.89 4206.49 5762.24 5988874.02 534311.28 12.00 5312.61 270.13 MWD 10975.00 87.51 26.37 6687.98 4228.57 5773.92 5988896.14 534322.87 12.00 5336.63 270.26 MWD 11000.00 87.54 23.37 6689.06 4251.23 5784.42 5988918.83 534333.29 12.00 5360,98 270.39 MWD 11025.00 87.57 20.37 6690.12 4274.40 5793.73 5988942.04 534342.50 12.00 5385.58 270.52 MWD 11050.00 87.61 17.37 6691.18 4298.04 5801.80 5988965.70 534350.49 12.00 5410.38 270.65 MWD 11075.00 87.65 14.36 6692.21 4322.06 5808.63 5988989.75 534357.22 12.00 5435.29 270.76 MWD 11100.00 87.70 11.36 6693.23 4346.41 5814.19 5989014.12 534362.69 12.00 5460.27 270.90 M W D 11125.00 87.76 8.36 6694.22 4371.02 5818.47 5989038.74 534366.87 12.00 5485.23 271.02 MWD 11150.00 87.82 5.36 6695.18 4395.82 5821.45 5989063.55 534369.76 12.00 5510.11 271.14 MWD 11175.00 87.89 2.36 6696.12 4420.74 5823.13 5989088.48 534371.35 12.00 5534.83 271.26 MWD 11200.00 87.96 359.36 6697.03 4445.72 5823.51 5989113.45 534371.62 12.00 5559.34 271.37 MWD 11225.00 87.86 2.36 6697.94 4470.70 5823.88 5989138.43 534371.90 12.00 5583.85 92.00 MWD 11250.00 87.77 5.36 6698.89 4495.62 5825.56 5989163.36 534373.49 12.00 5608.58 91.89 MWD 11275.00 87.68 8.36 6699.89 4520.42 5828.54 5989188.16 534376.37 12.00 5633.46 91.78 MWD 11300.00 87.59 11.36 6700.92 4545.02 5832.82 59$9212.78 534380.56 92.00 5658.42 91.66 MWD 11325.00 87.51 14.36 6701.99 4569.37 5838.38 5989237.15 534386.02 12.00 5683.39 91.53 MWD i 11350.00 87.44 17.36 6703.09 , 4593.39 5845.20 5989261.20 534392.76 12.00 5708.30 91.40 MWD Kuparuk DOBCTD BOP configuration 2" CT Well ~ 1Q-04L1,L1-01 Rig Floor 3" 5000 psi 1 HCR Choke Line ^~ Tree Size I Lubricator ID = 6.375" with 6" OG; P~ t 71/16" 5000 psi BOP's. ID = 7.06" ~~ `c • ~; ,, , :~~;.,..u, 7 1/16" 5000 psi. RX-46 114 Tum LT Valve 7 1/16" 5000 psi RX-46 ~ HCR Kill Line . 21/16" 5000 psi , RX 24 7 1/16" 5000 psi (RX-46) or f--- 4 1116" 5000 psi (12X 39) Swab Valve ssv Master Valve Base Flange Page 1 PERMtT TO QRILL 20 AAC 25.005 • (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~/~~ `~ ~-~'7~ ~ ~'~ PTD# ~ ~ /~~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore ~cegment of ' LATERAL ~~ existing well _~I~L~ ~~ ~ S-U ~d~~' Z~ `~'23~API N ~ umber If API o. i Permit No, ( Production should continue to be reported as n ( last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (per records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Comaany Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. °' Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CH E KLIST Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1Q-04L1-01 Program DEV Well bore seg ^~ PTD#:2051400 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permitfee attached_ _ . _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ - . -Multilateral-well bore, fee waived per 20_AAC 25.005(e) _ - _ _ - --------------------------- 2 Lease number appropriate - - - Yes - - - - - - - - - ------------------------------------- 3 Unique well-name and number -- ------------- ------- ------ -- -Yes ------ -- -- ------------- ---------- -- -- ------- -- - -------------- 4 Well located in a_defined_pool _ - . _ _ _ . - Yes - - - - - - KUPARUK RIVER,_KUPARUK RV OIL r 490100, governed by Conservation Order No.432E - - - - 5 Well located proper distance from drilling unit_bou~dary- _ - _ - - _ _ _ - - - Yes - - - - Conservation Order No. 4320 contains n4 spacing restrictions with respect t4 drilling unit boundaries. - _ 6 Well located proper distance_from other wells_ _ - - - _ _ _ - - _ - - _ Yes - _ - -Conservation Order No. 4320 has no in_terwell_spacing_restrictions_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 Sufficient acreage available in_drilling unit_ - - _ _ - _ _ - - _ Yes _ - _ _ _ -Conservation Order No. 4320 has_no interwell_spacing_restriclions, Wellbore will be_more than 500' from _ - . _ 8 If_deviated, is_wellbore plat-included _ - _ - - _ - _ _ _ - - _ Yes _ _ - an external property line whe[e ownership or_landownership_changes. _ - _ _ 9 Operator only affected party - - - Yes - - - - - - - - - - - - - 10 Ope[atorhas.appropriate-bond infonre---------- ---------- ------ -- Yes ------- -- ------------ -- ----------- ------------- --------------- -- 11 Permit_canbeissuedwithoutconsenrationorder__-_______--__ ___-__-.---Yes ______________ ------------------------------------------------------------- Appr Date 12 Permit_canbeissuedwithoutadministrative_approval_____________ ____________Yes __-_-_--________-____.--_________________-__-_ --------------------------- SFD 9!22/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized bylnjeotionOrder#(putl9#in-comments)_(For-NA_ ______________________.___--______-----________________-.-_________--_ 15 All wells within 114_mile area of review jdentified (For service well only)_ _ _ _ ___ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ - , - _ _ _ _ _ - - _ - ----------------------------------------------------- 16 Pre-produced injector duration of pre production Less than-3 months_(For_ service well only) _ _ NA_ - _ _ - _ _ _ -------------------------------------------------------------------- 17 ACMP-Finding of Consistency-has been issued_forthiS p[oject- - - - - - - - - - - - - - - - - NA_ 'Spoke" drilled from a _m_ultilateral wellbore_ _ _ _ _ - - - - -- -- Engineering 18 Conducto[st[ing_p_rovided----------------------------- ------------ NA_ _______Gonduetorset_inmotherbore1Q,04_(184-124),_-___.__________--___ ------------------- 19 Su_rfacecasingprotectsallknown-USDWs__-._-_______ ____________NA_ _____-_Allaquifers exempted, 40CFR_147.1Q2_(b~(3).__,.__._____-------___---_____---__-.- 20 CMT_vol adequate_to circulate on conductor & surf_csg _ _ - - _ _ . _ _ - NA_ Surface casing set in- motherbore.- - - - --- - - -- 21 CMT_vol_adequate_totie-in long string tosurfcsg______________ __________-NA_ _______Production_casingsetinmotherbore._--____-_________--_______-----____ 22 CMT-willcoverallknown-productiyehorizon_s_-_______________ ____________No_ ___--Slottedlinercompletionpl_anned,-________________--_______-__--____ 23 Casing designs adequate for- G, T l3 &_permaf[ost_ _ - _ - - - - . - - - - Yes _ _ _ _ _ - - Original design met requirements.- NA for slotted liners- - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage_or reserve pit - . - - - - - - . - - . - - - - - - - _ -Yes - - - - - Rig is-equipped with steel_pits. No resen!e_pitplanned, All waste to approved disposal wells._ _ - - 25 Ifa_re-dcill,has_a1.0-403forabandonmentbeen approved__________ ____________ NA_ ___--______--_______--_______-----_____-----__-.__--__ ------------------ 26 Adequate wellbore separationproposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - - _ - - - Proxim(ty. analysis performed, Well trajectgry diverges $om.motherbore.nnd Lt._ _ _ _ _ - - - - _ _ _ _ _ - - - - - - - 27 If_diverterrequired,doesitmeetr?gulations___________________ ____________ NA_ _____--BOPStack_willalready_beinplaee,__________._ ----------------------------------- Appr Date 28 Drilling Fluid-program schematic & equip listadequate_ _ _ - - - . - - - - - - -Yes Maximum expected formation pressure 9.2_EMW._ Managed pressure_driUingwill be used.- _ - - - - TEM 9123 2005 29 BOPEs, do they meet regulation _ - - _ _ _ - _ _ - - _ _ _ - Yes - - - - - - - 2 wellbore volumes-of kill weight fluid will be on location for contingency, _ - - _ _ - _ _ ;~ ! 30 BOPE_press rating appropriate; test to_(put prig in comments)_ - - - _ - - - - - Yes - - MASP calculated at 2449 psi. 3500_psi_BOP testplanned, _ 6 31 Choke manifold complieswlAPl_Rf?-53 (May 84) _ _ _ _ - - _ _ Yes _ _ 32 Work willoccu[withoutoperationshutdown__________________ ____________Yes ______-__--_____-__-______--______ - -- - - -- - 33 Is presence of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes t00-ppm H2S has been reported_in 1Q-04._ Mud should preclude-H2S_on-rig, Rig_has sensors and alarms._ . - - - 34 Mechanical condition of wells within AOR verified (Far service well only) - - _ _ - NA_ _ - - _ _ - - _ _ -------------------------------------------------------- Geology 35 Permitean be issued w!o hyd[ogen_ sulfide measures - - - - _ . - - _ - - - - No_ _ - - _ _ - 11.0_ppm H2S measured in parent vrel_Ibo[e, H2$ measures required. _ _ - - _ - - 36 Data_presented on potential overpressure zones _ _ - _ _ - - _ _ _ - - _ Yes - - - - - Maximum expected reservoirpressure is 9,2_ppg EMW; will be drilled with a coiled tubing rig, 8.6_ppg mud, and _ - Appr Date 37 Seismic analy&is-of shallow gas_2ones_ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - NA_ _ _ _ _ - . -managed pressure drillingtechnique. _ _ _ _ _ _ - - - - _ - _ - - - - --- -- SFD 9122!2005 38 Seabed condition survey-(ifoff-shore)______________________ __________NA- --_--_--.- 39 Contact namelphone_for_weekly progress_reports [exploratory only)_ _ _ - - - _ NA_ - _ _ _ - - _ Geologic Engineering Ru ~ Date: Date Date This wellbore will be a "s oke"drilled from the KRU 1Q-04L1 multilateral wellbore. p Commissioner: Commissioner: Co er -o~ 9~ ~'- • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information- of this nature is accumulated ai the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 4 • • **** REEL HEADER **** MWD 06/12/22 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/11/01 _® G~` ,/ 6 '1~~~ LPN '~ ors ~~1~1gg\On G ~1as~~®\1~ ~ ~~ 997967 01 2.375" CTK *** LIS COMMENT RECORD *** Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 9072.0000: Starting Depth STOP.FT 11270.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1Q-04L1-01 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 22' 8.888" N 149 deg 45' 4.325"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 01-Nov-05 API API NYUMBER: 500292125061 Parameter Information Block #MNEM.UNIT Value Description -- ----- ----------------- SECT. ---- --- 26 Section TOWN.N 12N Township RANG. 09E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 90 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 90 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes .INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1Q-04 through a milled window in 3 1/2" liner. Top of Window 9070.1 ft.MD (6522.16 ft.SSTVD) Bottom of Window 9072.9 ft.MD (6524.09 ft.55TVD) (8) The interval from 11246 ft.to 11270 ft.MD (6645.7 ft.to 6644.3 ft.SSTVD) was not logged due to sensor bit offset at TD. (9) Tied to 1Q-04 at 8884 ft.MD (6382.69 ft.SSTVD) (10) This wellbore 1Q-04L1-01 was kicked off the wellbore 1Q-04L1 at 9198 ft.MD (6587.91 ft.SSTVD) (11) The wellbore 1Q-04L1-03 was kicked off this wellbore 1Q-04L1-01 at 10098 ft.MD (6626.19 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CON5 MNEM VALU WDFN 1Q-04L1-01 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1Q-04L1-01, FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MrnTD 6 8 1 AAP I 9 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 53 Tape File Start Depth = 9072.000000 Tape File End Depth = 11269.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 62 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 • *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-04L1-01.xtf • • LCC 150 CN ConocoPhillips Alaska In WN 1Q-04L1-01, FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROP MwD 68 1 F/HR 4 4 8 Total Data Records: 106 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 115 Minimum record length: 54 Maximum record length: 4124 9062.000000 11269.000000 0.250000 feet records... bytes bytes **** TAPE TRAILER **** MWD 05/11/01 997967 01 **** REEL TRAILER **** MWD 06/12/22 BHI Ol Tape 5ubfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • i Tape Subfile 1 is type: LI5 • Tape Subfile 2 is type: LIS DEPTH GR ROP 9072.0000 73.2700 -999.2500 9072.5000 71.2100 -999.2500 9100.0000 139.5600 20.6600 9200.0000 128.4700 66.5056 9300.0000 114.5450 62.6500 9400.0000 118.9300 18.6300 9500.0000 95.7100 71.7400 9600.0000 82.0400 48.3700 .9700.0000 55.4700 76.40.00 9800.0000 70.9500 60.4600 9900.0000 88.7500 70.1700 10000.0000 112.4800 49.8800 10100.0000 84.8800 35.2200 10200.0000 97.5200 80.8600 10300.0000 115.3100 58.5400 10400.0000 106.5500 49.7200 10500.0000 104.4800 63.2000 10600.0000 100.6100 55.5900 10700.0000 105.7700 94.8700 10800.0000 99.2333 50.1000 10900.0000 89.0100 47.2200 11000.0000 111.9600 81.2800 11100.0000 66.5700 46.2200 11200.0000 50.5700 39.4500 11269.0000 -999.2500 -999.2500 Tape File Start Depth = 9072.000000 Tape File End Depth = 11269.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 9062.0000 54.9400 -999.2500 9062.2500 58.0500 -999.2500 9100.0000 139.5600 20.6600 9200.0000 128.4700 66.5056 9300.0000 114.5450 62.6500 9400.0000 118.9300 18.6300 9500.0000 95.7100 71.7400 9600.0000 82.0400 48.3700 9700.0000 55.4700 76.4000 9800.0000 70.9500 60.4600 9900.0000 88.7500 70.1700 10000.0000 112.4800 49.8800 10100.0000 84.8800 35.2200 10200.0000 97.5200 .80.8600 10300.0000 115.3100 58.5400 10400.0000 106.5500 49.7200 10500.0000 104.4800 63.2000 10600.0000 100.6100 55.5900 10700.0000 105.7700 94.8700 10800.0000 99.2333 50.1000 10900.0000 89.0100 47.2200 11000.0000 111.9600 81.2800 11100.0000 66.5700 46.2200 11200.0000 50.5700 39.4500 11269.0000 -999.2500 -999.2500 Tape File Start Depth = 9062.000000 Tape File End Depth = 11269.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet r~ L_.1 Tape Subfile 4 is type: LIS
