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Home My WebLink About205-139Image Project Well History Fite Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~`j - 1 ~Wefl History File Identifier Organizing (aone> RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria o,wo,~,a iuuiimiiiiiui DIGI AL DATA Diskettes, No. ^ Other, No/Type: Date: Re,~a.~recea iuumuiuiim OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ Project Proofing BY: ~~ Mari Date: ~'(~~ U~ /s/ V ~ I ~I Scanning Preparation _~ x 30 = + `~ =TOTAL PAGES (Count does not include cover sheet) I /1 /~,~ BY: Maria Date:g I/ j_ ~ ~ /s/ l/ r Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Dater ~.~- O~ /s/ . ~~ Stage 1 If NO in stage 1, page(s) dlscrepancles were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II ((I'I II I II II I I III ReScanned III II'III IIIII II III BY: Maria Date: /s! Comments about this file: ow„~,~~e«ea uummuiimu 10/6/2005 Well History File Cover Page.doc 1`) ~.. ~ DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051390 Well Name/No. KUPARUK RIV UNIT 1Q-04L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21250-60-00 MD 10895 TVD 6612 Completion Date 11/5/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes DATA INFORMATION Types Electric or Other Log s 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 / Type Med/Frmt Number _- _ _ _-_ _ ---- Name - ------ Scale -- Media No -- Start - ------ Stop _- CH Received Comments i D D Asc Directional Survey 9000 10895 Open ------- 1Q-04 L1, 1Q-04 L1-01, ', 1 Q-04 L 1-02, 1 Q-04 L 1-03 ~~ ~/ on diskette , I~Rpt Directional Survey 9000 10895 Case „Isbg 14332 Gamma Ray 25 Blu 1 9072 10895 Open 1/16/2007 MD GR 20-Oct-2005 ~0 14332 Gamma Ray 25 Blu 1 9072 10895 Open 1!16/2007 TVD GR 20-Oct-2005 C:Kpt 14332 LIS Verification 1 9072 10894 Open 1/16/2007 LIS Ver GR, ROP 20-Oct- 2005 Asc 14332 InductionlResistivity 1 9072 10894 Open 1/16/2007 LIS Veri in Ascii Format GR, ROP 20-Oct-2005 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM/~TION Well Cored? Y jl~V\) Daily History Received? Chips Received? ~1~TN - Formation Tops f~ N Analysis ~-/'I~ Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051390 Well Name/No. KUPARUK RIV UNIT 1Q-04L1 MD 10895 TVD 6612 mpietion Date 11/5/2005 Compliance Reviewed By: _ ________ Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21250-60-00 Completion Status 1-01L Current Status 1-OIL /__,,, U~ N Date: _~-_ 1_ ~_~_ • Transmittal Form INTEQ To AOGCC 333 West 7th Ave, Suite 100 ' ~ Anchorage, Alaska"~ ~-=, , ~ ~ ' ~ ,~ ~~~~ 99501 3 Attention: Helen Warman 1 LDWG Compact Disc (Includes Graphic Image files) I LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log • ~- ~-- -- l I YMiM ~Y.e:m n. ei. R .w BAKER ,~... ,~ ....., HUGHES '~-==-----,-= ... Anchorage GEOScience Center _ _ ', Reference: 1Q-04L1 II Contains the following: Sent By: Deepa Joglekar ~' ; ~ %' Received B / ` ~~ ~ y: l ~ _,i~~_~ Date: Jan.10, 2007 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska. ~~~ J~ 9918 ~J Direct: (907) 267-6612 _~ ;`.~~ FA_X: (907) 267-6623 - --- -~ "~ i ~ ~~~x: ~: 1~~ ,. - - i i ~. ~... ~- _ _: -- - -,. _ ,, _. I ;.~ ,~_ f ~`_ _ I, ; {~ _. ~~ ,,._ _ ~: - __ STATE OF ALASKA DECEIVED ALASK~L AND GAS CONSERVATION CC~9ISSION ~iN.~ 13 2006 REPORT OF SUNDRY WELL OPERATI~~Va`~f, it b'~ Gas Cons. Commission Anchorage 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. ermit To Drill Number: Conoco Phillips Alaska Inc. ®Development ^ Exploratory 205-139 "~ 3. Address: ^ Stratigraphic ^ Service 6. API Number: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21250-60-00 7. KB Elevation (ft): 90, 9. Well Name and Number: Kuparuk 1Q-04L1 8. Property Designation: `~ zia3~ 10. Field /Pool(s): ADL 025641 .4'p~ .„~,~ Kuparuk River Unit /Kuparuk River Pool 11. Present well condition summary Total depth: measured 10895 ~ feet true vertical 6612 ~ feet Plugs (measured) None Effective depth: measured 10895 feet Junk (measured) None true vertical 6612 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate Production Liner Liner 833' 2-3/8" 10062' - 10895' 6664' - 6612' 11200 11780 Perforation Depth MD (ft): sbned section: 10075' - 10894' Perforation Depth TVD (ft): 6663' - 6612' 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: ^ Exploratory ®Development ^ Service ® Dail Re ort of Well O erations y p p ® Well Schematic Diagram 16. Well Status after proposed work: ® Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I here y certi that t e oregomg is true an correct tote est o my knowle ge. Sundry Numbe or N/A if C.O. E~ a pt: Contact Steve Mukavitz, 263-4021 ~ ~ IiiA Printed Name Terrie Hubble Title Technical Assistant Phone J~ n Prepared ey NameMumber. O~ / Signature v Terrie Hubble, 564-4628 564-4628 Date "` Form 10-404 Revised 04/2004 ~ - tSf"~ ~~~ ~ 21~~~ ,~` ~~~~a~ Submit Original Only 1 ~ ' S `~,.i ,~lfL " 7"s. BP Page 1 of 11 Operations Suummary 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 1/22/2006 06:00 - 07:00 1.00 MOB P PRE Warm up moving system, prep to move off well-weather worsening 07:00 - 09:20 2.33 MOB P PRE 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) Use rig loader for crew changes 1/23/2006 00:00 - 10:30 10.50 MOB P PRE Continue WOW Phz 2 (-9F, 18-32 mph SW, -40CF Phz 2 ~ 0600 hrs) 10:30 -00:00 13.50 MOB P PRE Kuparuk CPF1, CPF2, GPB go to Phz 3. CPF3 and GPB in Phz 2 (-11 F, 32-46 mph WSW, -62CF w/ blowing snow, low visibility) 1/24/2006 00:00 - 06:00 6.00 MOB P 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 morning. 06:00 - 12:00 6.00 MOB P PRE Clearing snow from around rig and camps also clearing 1 O pad. Called AOGCC with 12-24hr BOP notice. 12:00 - 18:45 6.75 MOB P PRE Pull off 3H-146. 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 - Held PJSM on backing over well. 21:00 -22:00 1.00 MOB P PRE Move rig over welt. 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 bbl 9.6 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' SM 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 spoil and 7-1/16' BOP stack, choke/kitl lines, and riser. This could take awhile. Very cold temps inside cellar even with heaters going. AOGCC previously notified of test and wavied witnessing. 18:00 -18:30 0.50 BOPSU P PRE Pre Workover Meeting conducted by S. Mukavitz 18:30 -22:30 4.00 BOPSU P PRE Finished NU BOP's and riser. Having problems with adaptor belOW riS@f, (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 boots on riser while testing some of choke manifold 1/26/2006 00:00 -06:00 6.00 BOPSU P PRE BOP testing and repaired riser boots Printed: 2!13/2006 12:02:20 PM BP Operations Summary Report Legal Well Name: 10-04 Common Well Name: 1 Q-04 Event Name: WORKOVER Start: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 2/10/2006 Rig Name: NORDIC 2 Rig Number: Date I From - To ~ Hours Task` (Code I NP 1/26/2006 00:00 -06:00 6.00 BOPSU P 06:00 - 08:00 2.00 WHSUR P 08:00 - 08:30 0.50 WHSUR P 08:30 - 08:40 0.17 WHSUR P 08:40 - 09:20 0.67 PULL P 09:20 - 10:00 0.67 PULL P 10:00 - 10:30 0.50 PULL P 10:30 - 13:30 3.00 PULL P 13:30 - 20:30 ~ 7.00 ~ PULL ~ P 20:30 -00:00 3.50 PULL C 1/27/2006 00:00 - 10:45 10.75 PULL C 10:45 - 11:00 0.25 PULL C 11:00 - 13:00 2.00 PULL C 13:00 -19:15 6.25 PULL C 19:15 - 19:45 0.50 PULL C 19:45 - 21:30 i.75 PULL C Page 2 of 11 Spud Date: 10/7/2005 End: 2/10/2006 T Phase Description of Operations 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. DECOMP RU shooting nipple and SLB lubricator sections DECOMP Call town for dispensation for not pulling TWC with lubricator. Granted. All 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. DECOMP Pull TWC with dry rod. DECOMP Clear rig floor of tools. MU 75t DP elevators. PU 1 jt 3-1/2" DP and TIW XO to 3-1/2" 8rd tbg. DECOMP MU to tbg hanger. Clear floor and pull hanger to floor. Hanger unseated easily. After streach in tbg seen seal assembly pulling through PBR at max pulls of 114k-120k. (blocks weigh 7K included) Control line came 1:1 to this point. DECOMP LD hanger and pup jt. Change out elevators to 75t flat top tbg elevators. DECOMP Pull on next jt #2. Should have cleared PBR but 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 DECOMP RU air slips. Pull and LD 3-1/2" tbg. Arrange for fishing tools, DP, DC's LD 98 jts (3067 ft) 3-112" 9.3#/ft J-55 Tbg, 1 SSSV and DGLM # 1 All 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 i at approximately 3100 ft. Fill hole. Tubing displacement was correct on POOH. DECOMP Unload 3-1/2' tubing in pipe shed and clean and RU rig floor. DECOMP Loaded pipe shed with 3-1/2" 15.5#/ft X-95 DP and prep Steamed joints, drift and tally. RU floor tongs etc.. DECOMP PJSM review pipe handling hazarcJs and procedures. Assign job positons DECOMP PU fishing BHA #1 Finished working ~ change out of coil rest motor. DECOMP PU 85 jts 3-1/2' DP and BHA DECOMP Circulated wellbore volume to clean up DP of scale. DECOMP RIH and tagged the top of the fish at 3,124 ft. Seat 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: 2/13x2006 12:02:20 PM BP Page 3 of 11 Operations Summary Report Legal Well Name: 1 Q-04 Common Well Name: 1 Q-04 Spud Date: 10!712005 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 i jts 3-1/2" below GLM All 9 jts layed down were not torqued up. It 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 with 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 toot. 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 1/2hr and made k through. Clear floor 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: 35klup 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 additional 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 1/28/2006 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 OECOMP 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-i0 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 normal 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 m9. L/D 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 1200ftJlbs and took 5 rds. Rec make-up torque values are 1710 min 2280 optimum. Chemical cui looked normal. 15:00 - 16:00 1.00 PULL DECOMP Re-dress OS 16:00 - 21:15 5.25 PULL DECOMP RIH with BHA ff4 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 cir bottom ups at 6.0 bpm P =626 psi Small amount of scale coming across shaker 1/31/2006 00:00 - 00:40 0.67 PULL C DEGOMP Circulating and cleaning wellbore Printed: 2/13/2006 12:02:20 PM gp Page. 5 of 1 f 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 1/31/2006 00:40 - 01:00 0.33 PULL C DECOMP Red C:p 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 confine (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 eline 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-Tine/sheave off to A leg drillers side. 09:00 - 10:00 1.00 PULL C I 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 up on WRP. Results show we have the packer assembly and at least the 1 st jt below it that the WPR 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 SL8 Eline and change out 188' bails 15:00 - 15:30 0.50 PULL C DECOMP PU on string, 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 sticktine. Tag WRP at 8375'. Attempt to hokf 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: 2/13J2006 12:02:20 PM BP Page 6 of 11 Operations Summary Report Legal Well Name: 1 Q-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 2/1/2006 00:00 - 01:00 1.00 PULL C DECOMP 8379'. Recover another 1/2 gallon of sand and scale. No marks on bailer 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 tt. 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 2-1/4 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 I 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 slicktine. Discuss cold weather operations and concerns. 19:00 -19:45 0.75 PULL C DECOIu1P 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 Pull 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 fiH normal. Pipe pulling smoothly. Puff 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: 2/1312006 12:02:20 PM g,p Page. 7 of 11 Operations Summary .Report Legal Well Name: 1Q-04 Common Wefl 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 3-112" 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 I 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. W RP 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 with2" drive bailer assembly. Tag again at 8265'. PuA 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 8057'. Pull out of hole. " Clear evidence of 3-/1f2' 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 2-1l2' 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 W RP 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 RIH 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 ~e 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 gp Page 8 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 2/3/2006 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 wl: 63k#. PU 6' pup. Engage fish 4' in on pup. Clear foor 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 l 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 theircounter/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 21001b and tool 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 extended. LD Tool 17:00 - 18:30 1.50 FISH C DECOMP POOH with DP and fish. PUH at 118k to 123k somewhat ratty. Getfing 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 slicklir-e 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: 2/1312006 12:02:20 PM B P Page 9 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/i 0/2006 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 253 jts + 16.5 ft in on jt # 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 I 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. 8HA includes the top packer and tail pipe. BHA ten =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 DECORIIP 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 while loading tubulars 13:30 - 14:00 0.50 EVAL C DECOMP RIH with 5-1/2" LIB and tagged at 8490 ft WLMD. POOH and had a picture of a 3-1/2" 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 Starting 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: 2/13/2006 12:02:20 PM BP Page 10 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 2/6/2006 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 893T 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 3-112 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 Verify 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 W HSUR 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 spoof 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: 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 'bescription of Operations 2/9/2006 04:45 - 05:15 0.50 WHSUR N RUNCMP ND riser and fix leak. Fill 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 1.00 BUNCO RUNCMP Spot 20 bbls inhibitied brine above PBR and inside tubing. 10:00 - 11:00 1.00 BUNCO RUNCMP 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. RILOS. 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 1A 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 ibg hanger. ND riser and ROPE. 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 mfg 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 R1GD 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. KRU 1Q-04L1 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: .€iE"3...rE'tt~~ ~~r~:i~t__s~~tc ~~c_ ~)~~~~, E~~?u~E`l1S~£?t~~~tef~"i153.,5~~'~f_%~?C_Li~i Contractor: Nordic Rig No.: 2 DATE: 2/2/06 Rig Rep.: Holmes-Igtanloc-Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Goodrich-Hildreth E-Mail ~tf ~c~y~c~rl~rt~.~3c ~'~c?~1~?u~~E~E ~~~?_c_~.3 Well Name: 1Q-04L1 PTD # 205-139 Operation: Drlg: Workover: XXX Explor.: Test: Initial: Weekly: XXX Bi-Weekly 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 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper . 1 2" NT_ Trip Tank P P Annular Preventer 1 7 1/1.6" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 3 112" P Meth Gas Detector P P #3 Rams 1 2 7/8"x3 1/2" P H2S Gas Detector P P' #4 Rams 1 3 1/2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 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 3050 P CHOKE MANIFOLD: Pressure After Closure 2300 P Quantity Test Result 200 psi Attained 20 sec P No. Valves 14 FP Full Pressure Attained 80 secs P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2100 Test Results Number of Failures: 0 Test Time: 6 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~ift3_..rEtg~~~t~rti_3_s~~tt__~K_u Remarks: Choke manifold valves needed to be greased before they would test. Test plug had to be changed out due to a damaged rubber seal. 2 extra valves on the stack were tested (used for pressure deplo ment issues during CTD work . Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES ??? NO c - Oper./Rig Waived By c -Database Date 2/1/06 Time ???? c -Trip Rpt File Witness Sloan /John Crisp c -Inspector Test start 16:00 Finish 20:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 2-2-06p.xls r 11/09/04 STATE OF ALASKA OlL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: ~ >t,u~ ~~r~i~3:s~~tf _~ .€iE"3.. Cf'g ~ d d f~ f ~ ceU~.~C'.".. i..' iEE1:1C?~?.-i3C~itAt`W~_iEEt'~2eF~..i~_:'7:~.':c~f~_EeS I'3ft~`......£?~.~£`t~S~£_£lr,U,~~tet~" ie3_S~c~![ ~?S,~'i Contractor: Nordic Rig No.: 2 DATE: 1/26/06 Rig Rep.: Holmes-Igtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Feketi-Hidreth E-Mail s~.f~c~~sc~r~cr_f~~~~;c"Yc?c~f?~~~E~~_~i~~7:~_~~3 Well Name: 1 Q-04L1 PTD # 306-014 -_. ~ ~~ y ~ 5 Operation: Drlg: Workover: XXX Explor.: Test: Initial: XXX Weekly: Bi-Weekly 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 1 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 3 1/2" P Meth Gas Detector P P #3 Rams 1 2 7/8"x3 1/2" P H2S Gas Detector P P #4 Rams 1 3 1/2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves HCR Valves 2 3 118" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3050 P CHOKE MANIFOLD: Pressure After Closure 2150 P Quantity Test Result 200 psi Attained 25 sec P No. Valves 14 P Full Pressure Attained 99 secs P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2150 Test Results Number of Failures: 0 Test Time: 7 Hours Components tested 27 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ~ir~3..C~'g~~~~r~itt,st~~tf__~x_ Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES ??? NO c - Oper./Rig Waived By Jeff Jones c -Database Date 1/24/06 Time ???? c -Trip Rpt File Witness Sloan / Hildreth c -Inspector Test start 23:00 Finish 06:00 Coil Tubing BFL 11/09!04 Nordic 2 SOP 1-26-06p-1.xls STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ia. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 2oAAC 2s.~os 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: A~Chotap@ ®Development ^ Exp oratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 11/5/2005 12. Permit to Drill Number 205-139 ' 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/17/2005 13. API Number 50-029-21250-60-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/20/2005 14. Well Name and Number: Kuparuk 1Q-04L1 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: 114' FNL, 4461' FWL, SEC. 25, T12N, R09E, UM 9. Plug Back Depth (MD+TVD) 10895 + 6612 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528566 ' y- 5984646 'Zone- ASP4 10. Total Depth (MD+TVD) ~ 110895 + 6612 Ft 16. Property Designation: ADL 025641 TPI: x- 533717 y- 5987368 Zone- ASP4 Total Depth: x- 534080 ' Y- 5985782 -Zone- ASP4 11 • Depth where SSSV set 1815' MD 17. Land Use Permit: ------------~--- --------- ---- -~ 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1400' (Approx.) 21. Logs Run: /CL)r~ %5 Y CGac~- °str'1~~ ,(, E;~•~ ' /~ :.~ MWD, GR ~ ~~~3•~t; 2. CASING, LINER AND EMENTING ECORD CASING ETTINCi EPTH MD ETTINQ EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE pp TTOM OP TTOM SIZE CEMENTING RECORD PULLED 2-3/8" 4.6# L-80 10062' 10895' 6664' 6612' 3" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section Note: '~ 3-1/2", 9.3#, J-55 9085' 8566' & 9013' MD TVD MD TVD 10075' - 10894' 6663' - 6612' Well Branch Well Branch 1 Q-04L1 1 Q-04L1 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Departs From IS nOt DlreCtly ll B h A W ibl DEPTH INTERVAL MD AMOUNT Si KIND OF MATERIAL USED e ranc ccess e 1Q-04L1-02, PTD # 205-155, at 10061' MD (6664' TVD) 26. PRODUCTION TEST Date First Production: Reported on 1 O-04L1-03 ~ Method of Operation (Flowing, Gas Lift, etc.): See 1 Q-04L1-03 10-407 (Dated 01-19-06, PTD 205-167) for Production & Test Data y 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". ,_._ _.w _ . None R~I~MS ~F~, ,IAN 2 3 20D6 "~ -~' ~; Form 10-407 Revised 12/2003 ~ ,.t INUED ON REVERSE SIDE +E ~_ RECEIVED' IQN 2 0 2006 Alaska Oil & Gas Cons. C 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 A6 9151.' 6655' None '' Kuparuk A5 9160' 6660' Kuparuk A4 9177 6668' Kuparuk A3 9200' 6679' Kuparuk A3 (Inverted) 10400' 6630' Kuparuk A3 (Reverted) 10715' 6611' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / ` a / 1 (f ~~ Signed Terrie Hubble Title Technical Assistant Date D Kuparuk 1 Q-04L1 205-139 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Dolling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: list all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1 Q-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALIS TA Rig Name: NORDIC 2 Date From - To ~ Hours Task i Code 10/14/2005 13:00 - 14:00 1.00 MOB P 14:00 - 14:15 0.25 MOB P 14:15 - 14:35 0.33 MOB P 14:35 - 15:00 0.42 MOB P Page 1 of 16 Spud Date: 10/7/2005 Start: 10/14/2005 End: Rig Release: 11/5/2005 Rig Number: NPT Phase Description of Operations Continue to prep rig to move off well 1 B-15. PJSM prior to moving off well. Move rig off well, and down to the entrance of 1 B pad. Spot rig at entrance to pad. Repair pressure gauge that is not reading properly. Pre move safety meeting with rig crew, Toolpusher, SLB Team Leader, BP WSL, and a representative from the Kuparuk drilliing toolhouse. Move rig from 1 B pad to 1 O pad in Kuparuk. Stop move near KRU warehouse to allow field crew change out. Rig on 10 Pad. Found subsidence around mouse hole. Fill 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 Spot cuttings tank. NU BOPS. 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. Pressure test BOPs. Witnessed by BP WSL Gary Goodrich. 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. Resume BOP test. Witnessed by BP WSL Greg Sarber. Pressure test 2-3/8" combi's, bag, and perform drawdown test. All passed ok. AES support crew hooked up control panel to SSSV. PU WF motors for milling window. Open MV and SV. Well is dead. Prespud meeting with all rig hands on location, TL, TP, WSL, 2 W F hands. NU hardline from rig choke line to tiger tank. PT to 3500 psi. Make up BHA #1. D331 DSM, WF 1.75 deg motor. BHI Coiltrack MWD BHA with orienter, GR and CCL. RIH with BHA #1. Pump SSSV open with panel. Continue RIH, displacing gas cut diesel and seawater OOH. 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 charecter 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 Lee CCL/GR of 10-6-2005. CCL log exactly on depth to ref log. 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. PRE PRE PRE PRE 15:00 - 15:15 I 0.251 MOB I P I I PRE 15:15 - 20:15 ~ 5.00 ~ MOB ~ P ~ PRE 20:15 - 23:00 I 2.751 MOB I P I I PRE 23:00 - 00:00 1.00 RIGU P PRE 10/15/2005 00:00 - 03:15 3.25 RIGU P PRE 03:15 - 05:15 2.00 BOPSUF~ P PRE 05:15 - 06:15 1.00 BOPSU N WAIT PRE 06:15 - 08:15 I 2.001 BOPSUFf P I I PRE 08:15-08:40 I 0.421STWHIPIP I IWEXIT 08:40-09:10 I 0.501STWHIPIP I IWEXIT 09:10 - 10:30 1.33 STWHIP P WEXIT 10:30 - 11:00 0.50 STWHIP P WEXIT 11:00-13:20 I 2.331STWHIPIP I IWEXIT 13:20 - 14:50 I 1.501 STWHIPI P I IWEXIT 14:50-18:15 ~ 3.42~STWHIP~P ~ IWEXIT Printed: 11/7/2005 9:58:20 AM gp Page 2 of 16 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 I, Task ~ Code li NPT ' Phase 10/15/2005 14:50 - 18:15 3.42 STWHIP P WEXIT 18:15 - 18:30 0.25 STWHIP P WEXIT 18:30 - 20:00 1.50 STWHIP P WEXIT Description of Operations Begin milling cement. 1.55/1.55/3500 psi. Initial ROP=16 fph. String wt = 4400 lbs. DHWOB=2000 lbs. Mill ahead. Exit tbg tail at 9072' holding HS toolface. See increased mtr work and reactive torque at 9076.8. PU 10'. Mill back down to 9076.5'. See reactive and mtr 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 mtr 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 mtg with night crew. Open EDC. Log CCL tie in from 8920'. No correction. 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 mtr 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 while 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 in/out. 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 Hearn Extended milling schedule. Currently at 25 mintues/0.1'. 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 mill. All indications are that milling is proceeding according to plan. 1.6/1.61/3750 psi. DHWOB=4000 lbs. String wt=4900 lbs. PVT=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 well. 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=5700 lbs. Printed: 11/7/2005 9:58:20 AM • BP Operations Summary Report Page 3 of 16 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 I NPT ' Phase !~~I 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 @ 1.57 in/out. Dry drift down at HS tt. Window smooth. IA/OA/PVT: 509/577/384 bbls. WHP/BHP/ECD: 22/3873/11:45 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 well. Unstab coil. LD tools. 10/17/2005 00:00 - 01:30 1.50 DRILL P PROD1 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 PROD1 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 charecter at 8880'. Make -15' correction using the Geologist PDC log. 06:30 - 09:20 2.83 DRILL P PROD1 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 1.5/1.3/3670 psi. Returns slowly healed up. 13:45 - 14:45 1.00 DRILL P PROD1 9220', Found the Ankorite we were looking for. ROP=6 fph. 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: 11/7/2005 9:58:20 AM • BP Operations Summary Report Page 4 of 16 Legal Well Name: 1 Q-04 Common Well Name: 1 Q-04 Spud Date: 10/7/2005 Event Name: REENTER+COMPLETE Start: 10/14/2005 End: Contractor Name: NORDIC CALIS TA Rig Release: 11/5/2005 Rig Name: NORDIC 2 Rig Number: Date From - To I Hours ' Task Code~ NPT ' Phase III Description of Operations 10/17/2005 15:00 - 15:15 0.25 DRILL P PRODi Clean thru the A6 interval. Clean back to bottom. 15:15 - 18:30 3.25 DRILL P PRODi Resume drilling. ROP=65 fph. In the sand looking for a 18:30 - 20:00 1.50 DRILL P 20:00 - 21:30 1.50 DRILL P 21:30 - 23:00 1.50 DRILL P 23:00 - 23:15 0.25 DRILL P 23:15 - 00:00 0.75 DRILL P 10/18/2005 100:00 - 02:30 I 2.501 DRILL I P 02:30 - 03:00 0.50 DRILL P 03:00 - 06:00 3.00 DRILL P 06:00 - 06:55 0.92 DRILL P 06:55 - 07:30 I 0.581 DRILL I P 07:30 - 10:40 3.17 DRILL P 10:40 - 11:00 0.33 DRILL P 11:00 - 11:15 11:15 - 11:45 11:45 - 15:10 0.25 DRILL P 0.50 DRILL P 3.42 DRILL P 15:10- 15:30 15:30 - 16:30 16:30 - 17:30 17:30 - 19:00 19:00 - 19:30 19:30 - 19:45 0.33 DRILL P 1.00 DRILL P 1.00 DRILL N 1.50 DRILL N PRODi PRODi PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 SFAL PROD1 SFAL PROD1 0.50 DRILL N SFAL PROD1 0.25 DRILL N SFAL PROD1 landing point. Land build/turn at 9334'. Add additional klagard to mud for A6: now up from 12 ppb to 14 ppb. Circulate out of hole for BHA change. Close sssv with 850 psi on well. At surface. Flow check well. Get off well. Unstab coil. Change motor angle to 1.1 deg. MU HCC bicenter. Get on well. Run in hole. Open sssv with 850 psi on tbg. Continue in hole following whp/bhp schedule. Log gr tie in. Subtract 15' correction: Continue in hole. Open hole smooth. Drill ahead from 9334'. 3470 psi fs at 1.56 in/1.56 out. DPSI: 100-150. DHWOB: 1.0 - 2.Ok#. WHP/BHP/ECD: 33/4006/11.65 ppg. IA/OA/PVT: 570/396/367 bbls. INC/AZM/TF: 90.3/85.1/158. ROP: 50-75 fph. 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: 33/4006/11.65 ppg. IA/OA/PVT: 570/396/367 bbls. INC/AZM/TF: 90.3/85.1/158. ROP: 50-75 fph. Wiper trip to window. Hole smooth in both directions. Drill ahead from 9500'. 3530 psi fs at 1.54 in/out. PVT: 365 bbls. 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. Wiper trip to window. Clean 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. Resume drilling. Wiper trip to the window. Clean PU off bottom and in open hole. Pumps down, tool face high side as we pull thru the window. No problems. Open EDC. Log tie in pass down from 8890'. Make +3.5' correction. RIH thru the window. Shut the EDC. Kick on the pumps and run to TD. 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. Slow drilling, continue to try to drill up structure. INC=96 deg. 1.54 BPM, 3754 psi Conduct wiper trip to window. Drill ahead. 1.5 bpm, 3512 psi. BHI Hardware/Software problems occurring- depth reading wrong. Trouble shoot BHI 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' Wiper to window, clean Pull thru window and work on software while parked in tubing. Got it working Printed: 11/7/2005 9:58:20 AM • BP Operations Summary Report Page 5 of 16 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 I' From - To Hours Task Code ''! NPT Phase Description of Operations 10/18/2005 19:45 - 20:15 0.50 DRILL N SFAL PRODi Wiper back to TD, clean. Tagged at 9941' PVT 348 20:15 - 22:00 1.75 DRILL P PROD1 Drill from 9941' 1.54/3600/1 R w/ 100-300 psi dill 1-4k wob w/ 22:00 - 00:00 2.00 DRILL P PRODi 10/19/2005 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01:40 1.17 DRILL P PROD1 01:40 - 02:40 1.00 DRILL P PROD1 02:40 - 04:40 I 2.001 DRILL I P I I PROD1 04;40 - 05:25 0.75 DRILL P PROD1 05:25 - 05:45 0.33 DRILL P PROD1 05:45 - 06:30 0.75 DRILL P PROD1 06:30 - 07:30 1.00 DRILL P PROD1 07:30 - 17:40 10.171 DRILL P PROD1 17:40 - 18:25 0.75 DRILL P PROD1 18:25 - 19:55 1.50 DRILL P PROD1 19:55 - 21:20 1.42 DRILL P PROD1 21:20 - 23:10 I 1.831 DRILL I P I I PROD1 23:10 - 00:00 0.83 DRILL P PROD1 10/20/2005 00:00 - 01:15 1.25 DRILL P PROD1 01:15 - 04:10 I 2.921 DRILL I P I I PROD1 04:10 - 05:10 1.00 DRILL P PROD1 05:10 - 05:30 0.33 DRILL P PROD1 05:30 - 06:45 1.25 DRILL P PROD1 06:45 - 09:45 3.00 DRILL P PROD1 09:45 - 10:45 I 1.001 DRILL I P I I PROD1 10:45 - 11:45 I 1.001 DRILL I P I I PROD1 11:45 - 13:45 i 2.00 ~ DRILL i P ~ i PROD1 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 Drill from 9976' with better penetration rate and turn TF over to maintain 94 deg 1.54/3630/808 w/ ECD 12.28 due to increased solids from faster penetration rate Drill from 1 0070-1 01 00' and swap to left at 10085' PVT 346 Wiper to window, clean both directions PVT 344 Start new mud. Drill from 10100' 1.57/3650/85L w/ 100-300 psi dill, 1.2-3.Ok wob w/ 12.3 ECD at 94 deg at 6573' TVD Hole completely displaced to new mud. Drill from 10145' 1.56/3320/80L w/ 11.4 ECD at 97 deg (6562' TVD) W iper to window, clean Log tie-in down from 8890', corr +8' Wiper back to TD tagged at 10244' Drill ahead from 10244' to 10280'. 0=1.52/1.52, 3500 press, 1850/2500 WOB, 11.57 ECD, 53-35'/hr, 120L. @ 0700 hrs, change TF to 80L @0730 hrs, ROP dropped due to 10% Ankerite. 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'/hr, 80L, 98 deg. Work pipe and varying WOB's to establish better ROP. -No apparent losses or sticking problems 031500, TF set at 30L Break out of ankerite at 10320', swap TF to left at 10385' and drill at 80'/hr 1.51/3440/808 w/ 300-500 psi diff, 2-4k wob w/ 11.9 ECD at 96 deg from 6546' TVD PVT 394 Wiper to window, clean both directions Drill from 10400' 1.52/3450/808 w/ 200-500 psi diff, 2-3k wob w/ 11.95 ECD at 97 deg to 10470' at 60'/hr Grind on a hard spot at 10470' for 30 min, then back to 60-80'/hr. Drill to 10550' at 93 deg and start seeing signs of losing push PVT 389 W iper to window was clean Wiper back in hole from window w/ set downs at 10387' twice in TF change area. Rest of hole was clean PVT 385 Drill from 10550' 1.53/3600/100L w/100-300 psi diff, 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' Wiper to window, clean Log tie-in down from 8880', corr +10' Wiper back to TD tagged at 10710'. Drill ahead from 10710' to 10820'. 0=1.6/1.6, 4100 press, 0 CTW/ 2000-1600 WOB, 12.4 ECD, 26'/hr. Drilling break- ROP increased to 60'/hr. Drill ahead from (0820 to 10880'. 0=1.6/1.6, 4100-4300 press, -1400 CTW/ 1800 WOB, 12.5 ECD, 45089 deg. ROP reduction- 10-30'/hr. 0=1.62/1.62, 4100 - 4300 press, -3700 CTW/1800 WOB, 12.5 ECD, 120089 Deg. Conduct wiper trip to window. Slight motor work at 9150'. Printed: 11/7/2005 9:5820 AM • gP Page 6 of 16 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To __ 0-04 0-04 REENTE NORDIC NORDIC Hours R+COM CALIS 2 Task PLET TA ' Code . E NPT Start Rig Rig Phase Spud Date: 10/7/2005 : 10/14/2005 End: Release: 11/5/2005 Number: ~ 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=1.57/1.57, 4000-4300 press, -9K to -4K CTW/ 2500 - 1500 WOB, 12.5 ECD, 0 HS/ 88 deg. 16:30 - 17:45 1.25 DRILL 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 PROD1 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 0.3/2000 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 liner 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'/hr. 0=1.5/1.5, 3700 psi, 5800 CTW/1000 WOB, 12.3 ECD. 09:45 - 11:00 1.25 STKOH C PROD1 PU to 10030', orient TF to 150L, drill trough at 50'/hr. 0=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. Printed: 11/7/2005 9:58:20 AM • gp Page 7 of 16 Operations Summary Report Legal Weli Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To Q-04 Q-04 REENTE NORDIC NORDIC Hours 'I R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig ' Phase Spud Date: 10/7/2005 : 10/14/2005 End: Release: 11/5/2005 Number: I 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 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, 90L TF, no stick/slip. 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 1.51/3790 at 90'/hr, clean. Repeat at 110E at 150'/hr and was clean. Repeat at 179E at 150'/hr 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 PROD1 Wiper to window, clean. 8k overpull thru window and first 20' due to probable aluminum cuttings. Incr pump rate until clean PUH. Open EDC 19:50 - 21:45 1.92 STKOH C PROD1 POOH for lateral assy 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 BOPE rams 22:15 - 23:00 0.75 DRILL C PROD1 MU lateral assy 23:00 - 00:00 1.00 DRILL C PROD1 RIH w/ BHA #7 (1.1 deg motor w/ bi bit) following pressure schedule. Open TRSSSV w/ 900 psi 10/22/2005 00:00 - 00:30 0.50 DRILL C PROD1 Continue RIH w/ lateral assy 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 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' 1.51/3800/85L w/ 100-300 psi diff, 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 at 15'/min, clean. Finish wiper back to TD 02:30 -04:00 1.50 DRILL C PROD1 Drill from 10100' 1.5/3700/70L w/ 100-300 psi diff, 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 PROD1 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' 1.5/3700/70L w/ 100-300 psi diff, 1-3k wob w/ 12.4 ECD at 92 deg. ROP decreasing from 60'/hr to 15'/hr -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'/hr. 08:45 - 09:00 0.25 DRILL C PROD1 Conduct short wiper to 10220' to clean BHA/hole. Printed: 11/7/2005 9:58:20 AM BP Operations Summary Report Legal Well Name: 1Q-04 Common Well Name: 1Q-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ;From - To Hours ~' Task !Code NPT I __ '_ 10!22/2005 109:00 - 10:15 1 1.25 ~ DRILL I C 10:15 - 11:30 I 1.251 DRILL I C 11:30 - 17:00 I 5.50) DRILL I C 17:00 - 18:15 I 1.251 DRILL I C 18:15 - 18:35 0.33 DRILL C 18:35 - 20:50 2.25 DRILL C Start: 10/14/2005 Rig Release: 11/5/2005 Rig Number: Page 8 of 16 Spud Date: 10/7/2005 End: Phase ~ Description of Operations PROD1 ~ Drill ahead to 10355'. 0=1.5/1.5, 3850 press, -1100 CTW/ 1800 PROD1 PROD1 PROD1 PROD1 PROD1 20:50 - 21:45 0.92 DRILL C PROD1 21:45 - 22:00 0.25 DRILL C PROD1 22:00 - 22:50 0.83 DRILL C PROD1 22:50 - 00:00 1.17 DRILL C PROD1 10/23/2005 100:00 - 00:30 I 0.501 DRILL I C I I PROD1 00:30 - 02:05 1.58 DRILL C PROD1 02:05 - 03:00 0.92 DRILL X SFAL PROD1 03:00 - 18:00 15.00 DRILL C PROD1 18:00 - 20:45 I 2.751 DRILL I C I I PROD1 20:45-22:45 2.OO~DRILL C ~PROD1 22:45 - 00:00 1.25 DRILL C PROD1 10/24/2005 00:00 - 05:45 5.75 DRILL C PROD1 05:45 - 08:30 I 2.751 DRILL I C I I PROD1 08:30 - 12:00 I 3.501 DRILL I C I I PROD1 12:00 - 14:30 2.50 DRILL C PROD1 14:30 - 16:30 2.00 DRILL C PROD1 WOB, 12.39 ECD, 1158/96 deg, 9-15'/hr 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. 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 Out of ankerite. Drill ahead: 50-70'/hr. 0=1.511.5, 3900 press, -2KCTW/2.3KW06, 12.45 ECD, 1058/95 deg. Drill to 10443' and stacking in a shale, need fresh mud too PVT 315 Wiper to 10290' Drill from 10443' 1.5/3800/908 w/ 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 Wiper to window while wo fresh mud, clean Log tie-in down from 8880', Corr +12' Wiper back to TD tagged at 10498', clean Drill from 10498' 1.51/3790/1108 at 94 deg w/ max neg wt. Swap to left at 10525' Drill to 10542' Begin swap to fresh mud Ream TF change area from 10500-10542' while circ new mud to bit 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/SOL w/ 11.5 ECD 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 Drill from 10546' in ankerite at 3-4'/hr 1.5/3300/90L w/ 100 psi diff w/ 3.6k wob w/ 11.5 ECD at 94 deg PVT 414 Work pipe on occasion to try to clear BHA -C 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. Continue to drill in akerite at 3'/hr 1.5/3600/170L w/ 100 psi diff, 3-4k wob wf 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 .. . Drilling break at 10610' for 7' of 60'/hr gave hope, but then back to 3'/hr. Now at 90L Drill to 10626' at 3'/hr w/ TF now at 135E PVT 409 Continue slow progress in ankerite from 10626' 1.52/3630/120L w/ 100 psi diff, 2-3k wob at 11.93 ECD at 91 deg at 6544' TVD 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) Drill ahead to 10649'. 0=1.5/1.5, 3600 press, -6K CTW/ 2.9 WOB, 210L/ 89 deg, 11.9 ECD. Conduct wiper trip to window. +13.5' correction. Drill ahead to 10668'. 0=1.5/1.5, 3700 press, -7.6K CTW/ 3.2K WOB, 180 L/ 89 deg, 12 ECD Printed: 11/7/2005 9:58:20 AM r~ u gP 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 Hours Task ~. Code NPT I Phase - - _ ~ _ - ~ 10/24/2005 ~ 16:30 - 18:00 ~ 1.50 ~ DRILL C ~ ~PROD1 18:00 - 20:30 I 2.501 DRILL I C I I PRODi 20:30 - 21:30 1.00 DRILL C PROD1 21:30 - 21:50 0.33 DRILL X DFAL PROD1 21:50 - 22:10 I 0.331 DRILL I X I DFAL I PROD1 22:10 - 23:40 I 1.501 DRILL I X I DFAL I PROD1 23:40 - 00:00 0.33 DRILL X PRODi 10/25/2005 00:00 - 00:55 0.92 DRILL X DFAL PROD1 00:55 - 02:30 I 1.581 DRILL I X I I PROD1 02:30 - 03:30 I 1.001 DRILL I X I I PROD1 03:30 - 05:30 2.00 DRILL X PROD1 05:30 - 10:00 4.50 DRILL X PROD1 10:00 - 10:45 0,75 DRILL X PROD1 10:45 - 11:30 0.75 DRILL X PROD1 11:30 - 12:00 0.50 DRILL X PROD1 12:00 - 13:30 1.50 DRILL X PROD1 13:30 - 15:00 1.50 DRILL X PROD1 15:00 - 15:30 0.50 DRILL C PROD1 15:30 - 16:30 1.00 DRILL C PROD1 16:30 - 22:30 I 6.001 DRILL I C I I PROD1 22:30 - 23:45 1.25 DRILL C PROD1 23:45 - 00:00 0.25 DRILL C PROD1 10/26/2005 00:00 - 01:15 1.25 DRILL C PROD1 01:15 - 03:50 2.58 DRILL C PROD1 03:50 - 04:00 I 0.171 DRILL I C I I PROD1 04:00 - 04:45 0.75 DRILL C PROD1 04:45 - 06:00 1.25 CASE C PROD1 06:00 - 07:00 1.00 CASE C PROD1 07:00 - 07:15 0.25 CASE C PROD1 07:15 - 08:45 1.50 FISH X PROD1 Description of Operations Drilling break out of ankerite- 55'/hr. 0=1.52/1.52, 3800 press, 0 CTW/ 2300 WOB, 30L/ 89 deg, 12.1 ECD. -@ 1730 hrs, changed TF to 60L Drill from 10710' (6550' TVD) 1.5/3690/80L w/ 150-300 psi diff, 2-3.5k wob w/ 12.10 ECD at 86 deg at 20-40'/hr PVT 384 Wiper to window, clean 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. Pull CT w/pinhole over pipeshed and onto reel and flag Pinhole occurred w/ 266k RF at a 25% wear spot Fin POOH thru OH and was clean, window was clean. PUH into tubing and park. Inspect pipeshed roof and no drips, reelhouse clean too POOH holding 800-1100 psi against closed choke and noting proper hole fill. Close TRSSSV w/ 950 psi MIRU SWS N2 LD drilling BHA Fin LD drilling BHA. SI swab. Cut off Kendal CTC. install SWS CTC. Stab back on Flush CT w/ 40 bbls rig water while recover mud. Blow down CT w/ N2 and bleed off to tiger tank. RDMO SWS N2 Cut off CTC, install internal grapple and PT. Pull CT back to reel and secure. RD hardline Load out pinholed reel. Load in new reel E-CT Install internal grapple and PT. Pull CT to floor Pump coil volume (40.6 bbls) plus 20 extra. Cut 18 feet. Re-head coil Pull test to 40K. Held. PT to 4K. Held PU new BHA RIH to 8880' at 100 fpm. Log down at 2.5 fpm and tie in. -14.5' correction. 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. Drill ahead. 0=1.55/1.55, 3900 press (3800 FS), -3.5K CTW/ 1.5K WOB, 12.3 ECD, 15R/ 92 deg. Wiper trip to 8880' Slight overpull at 10058'. Log tie-in +2' correction. Finish wiper trip to bottom. Tagged bottom at 10934' TD. TOH for liner following pressure schedule. Trap 950psi below SSSV and close. PJSM: review liner running procedures and hazards. Discuss shut-in procedures in case of flow: L/D BHA. RU floor to run liner. MU Unique Indexing Guide Shoe to 2-3/8" 4.43# L80 R2 STL slotted liner (mu torque 500-600fUlbs) RIH w/ 52 jts 2-3/8" liner. PU liner BHA, attempt to PU billet. 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: 11/7/2005 9:58:20 AM • gp Page 10 of 16 Operations Summary Report Legal Well Name: 1 Q-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 10/26/2005 07:15 - 08:45 1.50 FISH X PROD1 08:45 - 09:15 0.50 CASE C PROD1 09:15 - 10:00 0.75 CASE C PROD1 10:00 - 12:15 I 2.251 CASE I C I (PROD1 12:15 - 14:30 2.25 CASE C PROD1 14:30 - 15:45 1.25 CASE P PROD2 15:45 - 18:00 2.25 STKOH P PROD2 18:00 - 18:20 0.33 STKOH P PROD2 18:20 - 18:25 0.08 STKOH P PROD2 18:25 - 23:00 4.58 STKOH P PROD2 23:00 - 00:00 1.00 STKOH P PROD2 10/27/2005 00:00 - 00:45 0.75 STKOH P PROD2 00:45 - 00:55 0.17 DRILL P PROD2 00:55 - 01:45 0.83 DRILL P PROD2 01:45 - 03:45 2.00 DRILL P PROD2 03:45 - 04:00 0.25 DRILL P PROD2 04:00 - 04:15 0.25 DRILL P PROD2 04:15 - 07:15 3.00 DRILL P PROD2 07:15 - 07:45 0.50 DRILL P PROD2 07:45 - 09:45 2.00 DRILL P PROD2 09:45 - 11:30 1.75 DRILL P PROD2 11:30 - 12:00 0.50 DRILL P PROD2 12:00 - 16:00 4.00 BOPSU P PROD2 16:00 - 16:45 0.75 DRILL P PROD2 16:45 - 18:00 1.25 DRILL P PROD2 18:00 - 18:20 0.33 DRILL P PROD2 18:20 - 19:25 1.08 DRILL P PROD2 19:25 - 19:35 0.17 DRILL P PROD2 19:35 - 22:15 2.67 DRILL P PROD2 22:15 - 23:15 1.00 DRILL P PROD2 23:15 - 00:00 0.75 DRILL P PROD2 the pin connection on the billet sub. New one ordered out. PU new billet sub, reconnect to billet. PU liner BHA 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. 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. POOH w/ liner BHA LD liner BHA, PU and MU KO BHA. Test- good RIH w/ KO BHA Lot tie-in -16' correction RIH tagged top of aluminum biilet at 9198'. Starting at 9180' make 3 passes down to 9198' with 30L TF. Start time drilling off aluminum billet 0.1' every 2 min. 1.47/1.47 fs= 3472 ecd=11.77 At 9201 increase rop to 6'/hr to 9211'. Drill ahead 30'/hr to 9220'. Pull back to 9180 with 90L TF Ream backream to 9220' with 90L. RIH wo to 9220 no problems. TOH following pressure schedule. Finished TOH. Trapped 975psi on well prior to shut-in of SSSV. PJSM review BHA changes. Change out bits. PU 3" bi-center. No changes to motor bend. Surface test tools TIH to 8880' Log tie-in -16' correction RIH to 9220' No problems at OHST. Directionally drill ahead with build section 1.52 / 1.52 fs= 3500psi mw= 3-400psi ecd= 11.78ppg 3-4k wob 15-20'/hr 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 turn. Conduct wiper trip to window. Slight motor work at 9175. Drill ahead. 0=1.55/1.55, 3800 press, 3.8K CTW/ 1.5K WOB, 11.9 ECD, 60U 81 deg, 55 ROP. POOH w/ build assy Stand back injector. LD build BHA. Clear floor for BOP tests. BOP testing- all pass Witnessed for BP by Tug Eiden- Drilling Rep Witnessed for AOGCC by Jeff Jones PU lateral BHA RIH w/ lateral BHA Log tie-in -16' correction 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. Holding 100R TF ream from 9162'. 1.52 / 1.52 fs= 3540 60'/hr Directionally drill ahead f/ 9410' to 9560'. 1.54/1.54 3-400psi mw 2k wob 60-70'/hr (pit vol 352) Wiper trip. tagged at 9163' worked through wo problems. Directionally drill 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: 11/7/2005 9:58:20 AM • gp Page 11 of 16 Operations Summary Report Legal Well Name: 10-04 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 ~I 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 DRILL P PROD2 Drill ahead. 0=1.5/1.5, 3600 press, 4.2K CTW/ 1.6K WOB, 11.9 ECD, 75R/ 88.5 deg, 65'/hr -Q 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, 75 R/ 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'/hr 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, 11.4 ECD, 90L/ 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. 10/29/2005 00:00 - 01:30 1.50 DRILL P PROD2 Directionally drill f/ 10150' to 10271' 1.54/1.54 fs= 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. RBIH. 07:30 - 10:15 2.75 DRILL P PROD2 Drill ahead. 0=1.6/1.6, 3600 press (3300 FS), -.5K CTW/ 2.9K WOB, 11.7 ECD, 45R/ 90 deg, 60-70'/hr. 10:15 - 12:30 2.25 DRILL P i 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. -C~ 1715 hrs, changed TF to 120E Hit Ankorite at 10810' diving down NB inc 85-86deg 2-3k wob +ik 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. 1.58/1.58 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 n~ u gp Page 12 of 16 Operations Summary Report Legal Well Name: 10-04 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 i Code NPT ', Phase ', Description of Operations 10/30/2005 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/ 2.1 K 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. -Q 1230 hrs, changed TF to 0 HS 13:45 - 14:45 1.00 DRILL P PROD2 Drilling break- 60-70'/hr. 0=1.5811.58, 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 RIH 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 @ 1.62/1.62 ECD 12.21 ppg 10/31/2005 00:00 - 02:00 2.00 DRILL PROD2 Directionally drill f/ 10968'. 1.57/1.57 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. 0=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. 0=1.55/1.55, 3800 press, -2.9K CTW/ 1.5K WOB, 12.0 ECD, 90L/ 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, -5.OK CTW/ 2.2K WOB, 12.0 ECD, 30U 84.6 deg. -@ 1515 hrs, changed TF to 75L. -C~ 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: 11/7/2005 9:58:20 AM ~, t~ J BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-04 1 Q-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/14/2005 Rig Release: 11 /5/2005 Rig Number: Date '' From - To Hours Task ' Code NPT I Phase 11/1/2005 03:40 - 05:00 1.33 DRILL P PROD2 05:00 - 07:30 2.50 DRILL P PROD2 07:30 - 08:15 0.75 DRILL P PROD2 08:15 - 08:30 0.25 CASE P PROD2 08:30 - 10:15 1.75 CASE P PROD2 10:15 - 11:00 0.75 CASE P PROD2 11:00 - 13:30 2.50 CASE P PROD2 13:30 - 15:30 2.00 CASE P PROD2 15:30 - 16:00 0.50 CASE P PROD2 16:00 - 17:00 1.00 CASE C PROD2 17:00 - 17:30 0.50 DRILL C PROD2 17:30 - 19:15 1.75 DRILL C PROD2 19:15 - 19:30 0.25 DRILL C PROD2 19:30 - 20:20 0.83 DRILL C PROD2 20:20 - 20:45 0.42 DRILL C PROD2 20:45 - 22:40 I 1.921 DRILL I C I I PROD2 22:40 - 23:10 I 0.501 DRILL I C I I PROD2 23:10 - 00:00 0.83 DRILL C PROD2 11/2/2005 00:00 - 01:15 1.25 DRILL C PROD2 01:15 - 02:30 I 1.251 DRILL I C I I PROD2 02:30 - 04:00 1.50 DRILL C PROD2 04:00 - 04:20 0.33 DRILL C PROD2 04:20 - 05:00 0.67 DRILL C PROD2 05:00 - 07:30 I 2.501 DRILL i C I I PROD2 07:30 - 10:15 ~ 2.75 ~ DRILL ~ C ~ ~ PROD2 10:15 - 10:30 ~ 0.25 J DRILL ~ C ~ ~ PROD2 10:30 - 13:30 3.00 DRILL X PROD2 13:30 - 14:00 0.50 DRILL X PROD2 14:00 - 14:15 0.25 BOPSU P PROD2 14:15 - 15:30 1.25 DRILL X PROD2 15:30 - 18:10 2.67 DRILL X PROD2 Page 13 of 16 Spud Date: 10/7/2005 End: Description of Operations RIH to bottom. Tagged at 11270'. TOH. Lay-in 15bb1 hi-vis pill w/ 2#/bbl Alpine Beads LD Drilling BHA, prep for running liner Conduct safety meeting for PU liner and running liner RIH w/ index shoe, 36 jts liner, billet PU liner running BHA, injector head. RIH w/ liner and liner BHA. Weight check on bottom, 29 klbs. Bring on pump. PU weight 18 klbs. Confirmed release from liner. POH with liner running BHA. Lay down liner running BHA. Work on Swaco Choke, coil. Make up BHA for sidetracking off of aluminum billett. RIH with kickoff assembly. BHA #17, Log tie in pass above window. Make -14' correction. RIH. Smooth thru window. Smooth in open hole. 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. 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. 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. Sidetrack is clean. POOH to pick up build section BHA. Continue top POH. Held PJSM while POH to discuss BHA Swap. Lay down BHA #17 with STR-324 bit. Readjust motor bend to 1.0 deg. Pick up Hughes bicenter bit. RIH with BHA #18 to begin drilling the lateral section of Li-03. Log tie in pass down over 8900'. Make -15' correction Run to bottom in open hole. No problems at window, or in open hole. Begin drilling 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. Drilling ahead f/ 10246' 1.55/1.55 freespin 3750psi 1-200psi mw ecd= 11.85ppg 2k wob <10'/hr 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. POOH LD drilling BHA, C/O motor, bit fine- will be re-run. Perform weekly BOP function test while out of hole PU BHA with new motor, test BHA and CTC. 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: 11/7/2005 9:58:20 AM gp Page 14 of 16 Operations Summary Report Legal Well Name: 1 Q-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 _~_ 11/2/2005 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. 22:30 - 23:00 0.50 DRILL C PROD2 23:00 - 00:00 1.00 DRILL C PROD2 11/3/2005 00:00 - 06:45 6.75 DRILL C PROD2 06:45 - 08:00 1.25 DRILL C PROD2 08:00 - 08:10 0.17 DRILL C PROD2 08:10 - 08:25 0.25 DRILL C PROD2 08:25 - 10:30 2.08 DRILL C PROD2 10:30 - 12:00 1.50 DRILL C PROD2 12:00 - 12:30 0.50 DRILL C PROD2 12:30 - 12:45 0.25 DRILL C PROD2 12:45 - 15:45 3.00 DRILL C PROD2 15:45 - 16:45 1.00 DRILL C PROD2 16:45 - 18:40 1.92 DRILL C PROD2 18:40 - 20:00 1.33 DRILL C PROD2 20:00 - 22:30 2.50 DRILL C i PROD2 22:30 - 22:45 0.25 DRILL C PROD2 22:45 - 23:10 0.42 DRILL C PROD2 23:10 - 00:00 0.83 DRILL C PROD2 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. 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. It was fun while it lasted. Back in the Ankorite. Drilling down as per the Geo at 3 fph. 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. Drilling break- 60-70'/hr. 0=1.5/1.5, 4200 press (and slowly inc w/ a 4100 FS), 1.8K CTW/ 1.7K WOB, 11.85 ECD, 75L/ 86.5 deg. Stuck. 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. SD pumps, hold 900 on choke. Hold pipe static for 15 minutes and see if we can free pipe. Pipe is on bottom, so PU to 46K, came free. PU to window and clean hole, check pressures. Still high- 4100-4200 psi. Drill ahead. 0=1.48/1.48, 4300 press (4000 FS), -2.1 K CTW/ 2.4K WOB, 11.8 ECD, 45L/ 83.8 deg, 60-70'/hr. Get stuck again. 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. Work pipe to clear BHA. PU to 10380', RBIH to bot. Drill ahead. 0=1.44/1.44, 4000 press, 0 CTW/ 1.6K WOB, 11.85 ECD, 135R/ 89.8 deg, 50-60'/hr -031345, changed TF to 90R Drill ahead- 5-10'/hr. 0= 1.4/1.4, 3600 press, -4.1 K CTW/ 1.OK WOB, 11.7 ECD, 60R/92.8 deg. Conduct a wiper to window. Tag bottom, and resume drilling Ankorite. PVT=388 bbls. IAP=640 psi, OAP=690 psi. WOB=1800 Ibs. String wt = -8000 lbs. ROP= 2 fph. ANN press = 4080 psi, Bore pressure = 4500 psi. ECD=11.88 ppg. Drilling break. ROP=70 fph. Lets hope it lasts to TD. Back in the Ankorite. INC=85 deg. Plan to keep INC the same, and try to get back down thru it ASAP. 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%. Call for 100 bbls of new mud to see if that helps. Resume drilling Ankorite. Not able to get any WOB. PU, and slam bottom at 80 fpm. Get a momentary blip of motor work and WOB. Keep repeating it. Printed: t 1/7/2005 9:58:20 AM L~ gp Page 15 of 16 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ;From - To 11 /4/2005 ~ 00:00 - 03:45 03:45 - 11:00 11:00 - 13:20 1 Q-04 1 Q-04 Spud Date: 10/7/2005 REENTER+COMPLETE Start: 10/14/2005 End: NORDIC CALISTA Rig Release: 11/5/2005 NORDIC 2 Rig Number: Hours Task Code NPT I, Phase Description of Operations 3.75 DRILL C 7.25 DRILL C 2.33 DRILL C 13:20 - 14:20 1.00 DRILL C 14:20 - 15:50 1.50 DRILL C 15:50 - 16:10 0.33 DRILL C 16:10 - 17:15 1.08 DRILL C 17:15 - 18:00 0.75 DRILL C 18:00 - 22:00 I 4.001 DRILL I C 22:00 - 22:55 I 0.921 DRILL I C 22:55 - 23:10 0.25 DRILL C 23:10 - 23:25 0.25 DRILL C 23:25 - 23:50 I 0.421 DRILL I C 23:50 - 00:00 0.17 DRILL C 11/5/2005 00:00 - 00:45 0.75 DRILL C 00:45 - 02:45 2.00 DRILL C 02:45 - 03:05 0.33 DRILL C 03:05 - 04:00 0.92 DRILL C 04:00 - 04:20 I 0.33 I CASE I C 04:20 - 07:15 I 2.92 I CASE I 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. 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 worn bit. Still able to see motor conducent with drilling other Ankorite sections 100-150psi. PROD2 TOH (opened ECD at 8900'] following pressure schedule, closed SSSV trapping 950psi. PJSM while TOH. PROD2 L/D motor. P/U new motor and bit. Service UOC/LOC PROD2 TIH w/ BHA #20 PROD2 Log tie-in -15' PROD2 TIH. Hole good shape. PROD2 Directionally drill ahead f/ 10585' 1.50/1.50bpm off-bottom 3680psi 100+ motorwork 3k wob 10'/ft 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. PROD2 Discuss with town slow ROP in Ankorite, and that planned TD is only 100' away. Towrr 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 Li-01 lateral liner. Ran back down thru it and back up slick. PROD2 Log tie in pass above window. Make +4.5' correction. 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. 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. PROD2 Continue in hole on wiper trip. PROD2 Continue back in hole with wiper trip. No problems to bottom. PROD2 POH with lateral section BHA, laying in liner pill. New flowpro mud with 4% lubetex, 1.5% EMI-776, and 3#/bbl of Alpine course glass beads. Pill was pumped thru the motor with a closed EDC. PROD2 PJSM prior to laying down BHA #20. PROD2 Stand back injector. Lay down BHA #20. Bit recovered with no obvious wear, graded 1,1. Reconfigure BHA for running liner. RUNPRD 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. 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 BTT O-Ring Sub Printed: 11/7/2005 9:58:20 AM • 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 RIH 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 at 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 L/D 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. Hold 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 onto 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. Continue to work on Injector. 22:45 - 00:00 1.25 RIGD C POST Change out rams in BOP stack for 2-3/8" coil. Change out horses head for 2-3/8" coil. Nipple down tree and secure in cellar for move. Rig released at midnight. Further telex entries carried on 1Q-02 DIMS reports. Printed: 11!7/2005 9:58:20 AM • • KRU 1 Q-04 L 1 /L 1-01 /L 1-02/L 1-03 Producer CTD Completion rev.2 H. 3-'/z" Baker 'FVL' SSSV set at 1815 RKB, 2.812" ID 9-5/8" 36# J-55 casing @ 4622' G. 3-1/2" 9.3# J-55 EUE 8rd Mod tubing w/ 3-1/2" x 1"Camco 'KBUG' mandrels _:~,~~ ConocoPh i I I i ps Alaska, Inc. F. 3-'h" 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', and 8972 RKB C-sand perfs C. Baker 3-1/2" FB-1 packer at 9013 RKB with PBR/seal assembly B. 3-'h" Camco D nipple with 2.75" ID at 9051 RKB 2-3/8" liner top ~ 9061' MD Top of Cement KOP at 9076' MD (6616 TVD) Window in 7" A. 3-1/2" tubing tail at 9085 RKB (9075 ELM) 3" openhole L1-01, TD @ 11270' and (6734' tvd ) permit 205-140 D KOP @ 9198' and (6678' tvd) D L1-03, TD @ 10597' and Q (6716' tvd) permit 205-167 ~ P @ 10099' Q ~ (6716' tvd) 7" 26~ J 55 9511' MD :~:~>:~::~:~:~::::~:~::::::: \ ~ L1-02, TD @ 10934' and ~`~`~~~~~:~.~."+~~. ~~:~:~:~:~:~: - 6626' tvd permit 205-155 \ ~ _ ~ - - -_ 2-3/8" slotted liner \ \ ~ , \ KOP @ 10061 and (6664' tvd) `~ L1, TD @ 10895' md, DEV 9/7/05 (6612' tvd) permit 205-139 ~ • • ~~~ ConocoPhillips Alaska, Inc. KRU 1Q-04L1 • • Well: 10-04 / L1 / L1-02 / Li -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 IN. 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. ConocaPhilli s ~ Baker Hu hes INTE p g Q Baker Hughes INTEQ Survey Report 133~FCFiR' s FtUGiF~E~ I~1 ht,3 °_._._ Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit ~ Sire: KRU 1Q Pad ~' Well: 4 ~, Wellpath: 10-04L1 Date: 11/15/2005 Time: 11:29:10 Page: 1 Co-ordinate(NE) Reference: Well: 4, True North Vertical (TVD) Refereuce: SITE 90.0 Section (VS) Reference: Well (O.OON,O.OOE,160.OOAzi) 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 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004 Site: KRU 1C2 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 Drilled From: 10-04 Tie-on Depth: 9000.00 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 0.00 160.00 Survey Program for Deffnitive Wellpath Date: 9/14/2005 Validated: No Version: 1 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 10895.00 MWD (9066.00-10895.00) MWD MWD -Standard Annotation 1~l ll 1' V D I ft ft _ - __ __ 9000.00 6561.68 TIP 9066.00 6609.26 KOP ' 10895.00 6612.47 TD Survey: MWD Start Date: 10/18/2005 Company: Baker Hughes INTEO Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey J1D lncl Azim 1'VD SSTVll N/S E/W ~iapN ~7apE VS DLS 'fool ft deg deg ft ft ft ft ft ft ft deg/100ft 9000. 00 43. 58 54.97 6561. 68 6471.68 2653 .69 5017 .03 5987318 .54 533572 .07 -777 .73 0.00 M W D 9066. 00 44. 15 55.29 6609. 26 6519.26 2679 .84 5054 .56 5987344 .83 533609 .49 -789 .46 0.93 M W D 9096. 40 57. 95 66.94 6628. 37 6538.37 2690 .99 5075. 26 5987356 .06 533630 .15 -792 .86 54.18 M W D 9125. 23 61. 70 76.41 6642. 88 6552.88 2698 .77 5098. 88 5987363. 93 533653 .74 -792 .10 31.22 MWD 9156. 87 60. 92 85.35 6658. 09 6568.09 2703 .17 5126. 25 5987368. 43 533681 .08 -786 .87 24.90 MWD 9185. 72 61. 19 96.04 6672. 09 6582.09 2702 .87 5151. 44 5987368. 22 533706 .27 -777 .97 32.43 MWD 9214. 04 64. 00 110.11 6685. 17 6595.17 2697 .16 5175. 83 5987362. 61 533730 .68 -764 .27 45.18 MWD 9243. 81 76. 07 115.30 6695. 33 6605.33 2686 .34 5201. 56 5987351. 89 533756 .46 -745 .30 43.71 MWD 9277. 21 80. 30 133.19 6702. 22 6612.22 2668 .00 5228. 44 5987333. 65 533783 .40 -718 .86 53.91 MWD 9319. 86 82. 78 152.89 6708. 55 6618.55 2634 .45 5253. 65 5987300. 20 533808 .74 -678. 72 46.05 M W D 9353. 78 85. 10 159.61 6712. 14 6622.14 2603 .59 5267. 22 5987269. 40 533822 .43 -645. 08 20.85 M W D ConocoPhilfips Baker Hughes INTEQ Baker Hughes INTEQ Survey Report >~A~1&1~ ~~~~~$ Ganpan~: ConocoPthillips Alaska, Inc. Field: Kuparuk River Unit Site: KRU 1Q Pad "vVell: 4 W'ellpath: 1 Q-04L1 .SUI'~'ey Date: 11/15/2005 Time: 11:29:10 Page: 2 Co-oi•dinateQVE) Reference: Well: 4, True North Vertical ("1'VD) Reference: SITE 90.0 Section (VS) Reference: Well (O.OON,O.OOE,160.OOAzi) Sunny Calculation Method: Minimum Curvature Db: Oracle J1U Intl Azim 1'~'ll SS"1'b'D ft deg deg ft ft - ---- -- - 9385.50 90.11 161.40 6713.46 6623.46 9416.38 95.02 162.28 6712.08 6622.08 9446.17 94.68 166.19 6709.56 6619.56 9481.27 93.33 170.18 6707.11 6617.11 9511.89 91.09 174.51 6705.93 6615.93 9552.10 94.84 178.21 6703.85 6613.85 9583.51 93.64 182.44 6701.52 6611.52 9616.17 94.31 185.80 6699.26 6609.26 9649.11 91.95 183.13 6697.46 6607.46 9691.31 95.33 180.56 6694.78 6604.78 9715.50 97.65 178.61 6692.05 6602.05 9749.89 94.07 173.13 6688.53 6598.53 9781.26 95.24 167.84 6685.98 6595.98 9816.23 96.08 168.41 6682.54 6592.54 9852.45 95.30 173.22 6678.94 6588.94 9894.52 95.21 174.39 6675.09 6585.09 9924.43 90.45 174.62 6673.61 6583.61 9959.03 95.34 175.06 6671.87 6581.87 10004.06 96.16 180.33 6667.35 6577.35 10038.45 92.66 183.91 6664.71 6574.71 10069.85 92.41 188.44 6663.32 6573.32 10102.69 93.98 187.07 6661.49 6571.49 10131.40 95.27 182.37 6659.17 6569.17 10163.47 95.20 177.99 6656.24 6566.24 10199.24 98.83 172.58 6651.87 6561.87 10230.85 97.32 168.98 6647.43 6557.43 10273.68 94.42 163.16 6643.05 6553.05 10301.78 95.65 159.36 6640.58 6550.58 10335.26 98.62 156.05 6636.42 6546.42 10369.50 94.75 156.31 6632.44 6542.44 10401.25 95.71 160.28 6629.54 6539.54 10436.18 97.17 164.10 6625.62 6535.62 10466.31 93.27 168.06 6622.88 6532.88 10496.93 92.53 172.85 6621.33 6531.33 10531.19 95.52 179.21 6618.92 6528.92 10564.26 94.55 179.97 6616.02 6526.02 10597.47 94.50 176.31 6613.40 6523.40 10641.36 91.58 172.60 6611.07 6521.07 10672.70 89.37 167.29 6610.81 6520.81 10709.20 89.37 162.80 6611.21 6521.21 10739.48 90.75 159.97 6611.18 6521.18 10777.87 88.33 156.07 6611.49 6521.49 10813.05 88.33 150.79 6612.52 6522.52 10854.14 90.60 146.09 6612.90 6522.90 r 10895.00 90.60 146.09 6612.47 - 6522.47 N/S _. ft 2573.73 2544.42 2515.86 2481.60 2451.28 2411.22 2379.91 2347.41 2314.63 2272.55 2248.51 2214.41 2183.59 2149.53 2113.96 2072.32 2042.59 2008.18 1963.43 1929.18 1898.00 1865.51 1837.00 1805.07 1769.71 1738.82 1697.50 1670.99 1640.26 1609.16 1579.79 1546.75 1517.64 1487.49 1453.42 1420.48 1387.39 1343.78 1312.94 1277.69 1248.99 1213.40 1181.96 1146.96 1113.06 N;/~~ ft 5277.80 5287.41 5295.47 5302.64 5306.71 5309.26 5309.08 5306.74 5304.18 5302.83 5303.00 5305.47 5310.63 5317.79 5323.54 5328.07 5330.93 5334.03 5335.84 5334.56 5331.19 5326.77 5324.41 5324.31 5327.22 5332.24 5342.49 5351.48 5364.08 5377.81 5389.50 5400.12 5407.33 5412.40 5414.77 5415.00 5416.08 5420.31 5425.78 5435.20 5444.86 5459.23 5474.95 5496.45 5519.24 J1apV ~7apN: ft ft 5987239.58 533833.11 5987210.32 533842.84 5987181.79 533851.01 5987147.56 533858.30 5987117.26 533862.49 5987077.21 533865.20 5987045.90 533865.14 5987013.40 533862.92 5986980.61 533860.49 5986938.52 533859.29 5986914.50 533859.56 5986880.41 533862.15 5986849.60 533867.44 5986815.58 533874.73 5986780.04 533880.61 5986738.41 533885.29 5986708.70 533888.26 5986674.31 533891.50 5986629.57 533893.47 5986595.32 533892.34 5986564.13 533889.08 5986531.63 533884.78 5986503.11 533882.54 5986471.18 533882.56 5986435.84 533885.60 5986404.97 533890.73 5986363.69 533901.15 5986337.22 533910.24 5986306.54 533922.95 5986275.49 533936.80 5986246.17 533948.60 5986213.18 533959.34 5986184.10 533966.66 5986153.97 533971.85 5986119.91 533974.35 5986086.97 533974.71 5986053.90 533975.91 5986010.31 533980.31 5985979.49 533985.90 5985944.28 533995.45 5985915.62 534005.22 5985880.09 534019.72 5985848.72 534035.56 5985813.80 534057.19 ~ J 5985779.98 534080.11 -- __ VS DLS '1'001 ~~ ft deg/100ft -613.40 16.77 MWD -582.58 16.15 M W D -552.98 13.13 M W D -518.33 11.97 M W D -488.45 15.91 MWD -449.93 13.09 MWD -420.57 13.96 MWD -390.83 10.47 MWD -360.90 10.81 MWD -321.82 10.05 M W D -299.18 12.50 MWD -266.29 18.96 MWD -235.56 17.22 MWD -201.11 2.90 MWD -165.72 13.39 MWD -125.03 2.78 MWD -96.12 15.93 M W D -62.73 14.19 M W D -20.06 11.79 MWD 11-.69 14.54 MWD 39.84 14.43 MWD 68.85 6.34 MWD 94.84 16.92 M W D 124.81 13.60 MWD 159.03 18.12 MWD 189.77 12.25 MWD 232.12 15.12 MWD 260.10 14.16 MWD 293.28 13.23 MWD 327.21 11.33 MWD 358.80 12.81 MWD 393.48 11.64 MWD 423.30 18.41 MWD 453.37 15.81 MWD 486.19 20.47 MWD 517.23 3.72 MWD 548.69 10.99 MWD 591.11 10.75 MWD 621.97 18.35 MWD 658.32 12.30 M W D 688.58 10.40 M W D 726.94 11.95 M W D 761.86 15.00 M W D 802.10 12.70 M W D 841.76 0.00 MWD I • -- a ~ a~ <^ ~~ ~ '~ ~ a-~--1 ~~`~ ~ i ~o.~ 5 5 r~ ~µ ~ FRANK H. MURKOWSKI, GOVERNOR ~- 7~T ~1 ~a--s~tt~~~ ®A~ ~ 333 W. 7T" AVENUE, SUITE 100 ~~~~~~t7aAi®e®a ~q~r~~iSI ~` ANCHORAGE, ALASKA 99501-3539 / PHONE (907) 279-1433 Steve MukaVltZ FAx (907) 27s-7642 Kuparuk Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK Re: Kuparuk River, 1Q-04L1 Sundry Number: 306-014 Dear Mr. Mukavitz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of January, 2006 Encl. Cr;.....,...,-.1~. LJ ConocoPhillips January 10, 2006 • Steve Mukavitz Drilling Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4021 Commissioner state of Alaska (RECEIVED Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 .IAN 1 2 2006 Anchorage, Alaska 99501 Alaska Oif ~ Gas Cons. ComrrMSaion Anchorage 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 1~1`ukavitz Drilling Engineer CPA( Drilling and Wells SM/skad ~ ~~~~~~ ~ ~,n. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION tfi~ JAN ~ 2 2006 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Waiver nC Ofa ther ^ Alter casing ^ Repair well ^~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^/ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill N~nber: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 205-139 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21250-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 33' 1 O-04L1 8. Property Designation: 10. Field/Pool(s): ADL 025641, 025634 Kuparuk River Field /Kuparuk Oil Pool 11. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10895' 6612' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80~ 16" 103' 103' SURFACE 4589' 9-518" 4622' 3571' PRODUCTION 9478' 7" 9511' 6706' L1 Liner 834' 2-3/8" 10895' 6612' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft}: 8709'-10895' x347'-ss12' 3-1/2" J-55 9085' Packers and SSSV Type: Packers and SSSV MD (ft) Baker'FHL' pkr, Baker'FB-1' pkr @ 8566', 9013' Baker'FLV' SSSV @ 1815' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 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 Engine r Signature ~~ Phone e Date ~ ~1 ~ b Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~Sr ~~ ~ OLS P~C9~~~`LCl r Subsequent F eq ' d 1 *~ ~~ ~~~ ~ ~ ~~~~ APPROVED BY ~ Approve COMMISSIONER THE COMMISSION ~~/ ~~ Date: p "~ o Form 10-403 Revis 7/2005 ~ ~ 1 ~ g ~ ~ ~ Submit in Duplicate ~` • ~QnocsaPhillps Alaska, Inc. 1 Q-04L1 APi: SSSV T e: ' Annular Fluid: TUBING (0-9085, OD:3.500, ID:2.992) Perf (8709$719) Perf (8722$726) Perf (8735$740) Perf (8742$753) Perf (8756$764) Perf (8771$777) Perf (8834$881) Perf (8914$928) CEMENT (9021-9511, OD:7.000) Perf ;10075-10696) ~'. - 1 _~ ~;; e 1 ~,' -_~ _J `'' ~ _z ~` ~ I ~`, I ~~ I I / _ II I' I' - ~~ ~~ Last Tag Date: _ __ __~Max Hole Angle: ~ 99 deg @ 10199 ~ ___ _ ! _ _ --- Casing String -.COMMON STRING Casing String - L1 SLOTTED LINER THIS LATERAL LEG IS NOT ACCESSIBLE~_ _ - - _ --- -- Description Size Top Bottom ~ TVD ~ Wt Grade Thread L1 LINER _ 2.375 10061_ _ 10895 10895 4.60_____... L-80 STL Tubing Strin TUBING Size ~ To i B9t~tsom ~, TVD ' W~rade ~ Thread - - ~ __' 3.500 0 _ I 6621 ___ _ 9.30 J-55 i _ EUE 8rd Perforations Summary T__ _ ___ ___ Interval TVD T Zone I StatUS I Ft SPF Date I Tvpe~- Comment O /'1G - O/JJ pJ/G - VJOV I I IL Y/LY/ 1.70J IrCRr ILVUC II,J J1:411V CU fIUV 8756 - 8764 6382 - 6388 8 12 4/24/1985 IPERF 120d h;5"Scallo ed HDC 8771 - 8777 6393 - 6398 6 12 4/24/1985 IPERF 120de h;5"Scallo ed HDC 8834 - 8881 6440 -6475 47 12 4/24/1985 IPERF 120de h;5"Scallo ed HDC 8914 - 8928 6499 - 6509 14 12 4/24/1985 IPERF 120de h;5"Scallo ed HDC 10075 - 10896 6663 - 10896 821 99 _ 10/20/2005 Slotted Li_ SLOTTED LINER gas Lift Mandr els/Valves St MD TVD - Man Mfr - Man Type - V Mfr V Type - _ _ - V OD Latch Port TRO ~ Date -- Vlv RUn Cmnt 1. BK2 latch @ 6698' RKB bent slight ty up of of pocket Ref.' WSRs 1219-117/1999 2. WATER INJECTION PKG production Mandrels/Valves - St MD TVD Man Mfr Man Type V Mtr V Type - V OD Latch Port - TRO Date Run - Vlv Cmnt 13 8604 6268 CAMCO MMG-2 DMY 1.5 RKP 0.000 0 5/6/2005 14 8674 6321 CAMCO MMG-2 DMY 1.5 RKP 0.000 0 5/7/2005 15 8972 6541 CAMCO MMG-2 DMY 1.5 RKP 0.000 0_ , 1/28/2003 ether lugs equip., etc.) -COMMON JEWELRY __ Depth I TVD i Tvpe i Description ID 9021 6577 CEMENT CEMENT PLUG set 10/7/2005 FOR UPCOMING SIDETRACK 9051 6598 NIP CAMCO'D' NIPPLE NO GO PROFILE 9064 6608 L1-03 Deploy BTT SEAL BORE DEPLOYMENT SLEEVE w/3" GS PROFILE set 10/7/2005 SLV 9066 6609 Window WINDOW TO L1-03, L1-02, L1-01, L1 L1-03 -__ General Notes I Date Note 6.151 E SCANNEI • KRU 1Q-04L1 • . 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 3-1/2" 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 - 1 Q-04-(1 ~4-234) .~, ~~~ _ ~~ From: Thomas Maunder <tom maunder@adminatate.ak.us> Date: Thu, ~I l D~,c 200 07:0:1 ~ -0~~O0 To: NSK Problem Vdcll Supv ~n1617(a.conocophiliihs.conl% Y ~5~ CC:.lim Re~`i : jim_i~;g$(tvadmin.stat~.ak.tls> - t to 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 j 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 ~-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 • 11 /09/04 STATE O F ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: ~ir~3...rE'r~~~~~r~i~3_s~~~t__~K, ietC~~.::~...~' EEi~iIC?£?.. i3r~tt`µ~,~i~~~:~13f1_~~_t7E~'_c~~,Ei~i I.3fbl'~ ~E£'.::}~E`-Y1S~£??El ,~?.:+~~fT9i~3_S~c~:l:_t. ~?C,U~4 Contractor: Nordic Rig No.: 2 DATE: 10/15/05 Rig Rep.: Holmes-Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sarber-Goodrich E-Mail s~~~c~~A,s~rl~rE.~.:~ic~~~c?~~~?us(?E~~~,~z~'~.~~?:~_~?I Well Name: 1Q-04L1 PTD # 205-139 Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-3500 Annular: 250-2500 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 3050 P CHOKE MANIFOLD: Pressure After Closure 2100 P Quantity Test Result 200 psi Attained 22 sec P No. Valves 14 P Full Pressure Attained 91 sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2050 Test Results Number of Failures: 0 Test Time: 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: ,E~E~3...f~'g~ ~~~r~'i~3._s~~t~_ ~>t:u Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By Chuck Scheve c -Database Date 10/13/05 Time 17:15 c -Trip Rpt File Witness Sarber-Goodrich c -Inspector Test start 03:00 Finish 08:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 10-15-05p.xls Re: 1 Q CTD sidetracks -naming convention ~ ~ Subject: Re: 1Q CTD sicletra~ks - namin~~ convention From: Thomas tilaunder °'ton~ rrlaunder~cz?admin.state.ak.us= Date: Fri, 09 Sep ?OOj 10:~~:?7 -OS00 'I'o: "Venhaus, Dan E" ~~Dan.E.Ven}latis(~i>conocophillips.com=' C'C: GanttLL ~i;:I3Y.con~, Scan.McLaughlin(~i;BP.c~ou1, Steve. Davies =stove davics«i!adinin.s~ate.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 1 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. 1Q-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 1 Q-04L1 and 1 Q-04L1-01. And I assume we will need to file a sundry for the A-sand pert abandonment. «1 Q-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 1 Q-02AL1. 1 of 2 9/23/2005 10:41 AM Re: 1 Q 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 • 1 d 1 a 7 9 ',~) ~ ~ ~ ~ ; ~~ ~ ~ ~'°"~ ~ ~ ; Via . ~~ ~ d~~ ~'~ FRANK H. MURKOWSKI, GOVERNOR , ~9 ~~~~ ~~~~++ ~1~ ~t~~~+ ~7~ OlT/ ~ ~ 1 f~° 333 W. T" AVENUE, SUITE 100 CO1~T3ERQATI011T CODII~IISSIOI~T j ANCHORAGE, ALASKA 99501-3539 , PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer Conoco Phillips Alaska Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: KRU 1 Q-04L 1 Conoco Phillips Alaska Inc. Permit No: 205-139 Surface Location: 1227' FNL, 1057' FEL, SEC. 26, T12N, R09E, UM Bottomhole Location: 428' FNL, 4604' FWL, SEC. 25, T12N, R09E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of September, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ` . , STATE OF ALASKA ALASKA ~'fL AND GAS CONSERVATION CO~ISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. 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 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 11300 ~ TVD 6533ss 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: /jai, ADL 0256411 ~~~~~ River Pool ~ , , . , , , Top of Productive Horizon: 1313' FSL, 3800' FWL, SEC. 24, T12N, R09E, UM 8. Land Use Permit: ~ ~Z,~s 13. Approximate Spud Date: October 20, 2005 Total Depth: 428' FNL, 4604' FWL, SEC. 25, T12N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 21,900' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528566 ~ y- 5984646 ~ Zone- ASP4 10. KB Elevation (Height above GL): gp feet 15. Distance to Nearest Well Within Pool 1 Q-23 is offset by 415' 16. Deviated Wells: Kickoff Depth: 9080 ~ feet Maximum Hole Angle: 99 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3100 ' Surface: 2449 ' 18. Casing rogram: Size $peC'rfications Setting Depth To Bottom uantity o merit C.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2090' 9210'- 6620' 11300'. 6533' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY{To be completed for Redrill AND Re-entry Operations) 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 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' t Pr ion 9511' 7" 80 sx Class 'G' 9511' 6918' Perforation Depth MD (ft): 8709' - 930 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 /~ A Prepared By Name/Number: Si nature ~ ~ IvU t ,~~- Phone 564-4387 Date Z b $ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: '/ API Number: 50- 029-21250-60-00 Permit prQv~J .D~ Date: ~ See cover letter for other requirements Conditions of Approval: Samples q 'red ^ Yes o Mud Log Required [] Yes ~'No Hydro n Sul de Measures es ^ No Directional Survey Required ~'rYes ^ No Other: '~,`i0 C~ " ~ c~~ Qlc9,a~ `~ ~ ~c~~c~.o~~ ~ 3~~.~-IC~S~ ~~~~c~~~`l~ Cxtxc~~.~i~~ r ~0 1~4C. ~~:03C~ <-~~ , APPROVED BY fib e~ A roved B THE COMMISSION Date Form 10-401 Rwf~ed 0671984 ~°~._tJ 1 ~ ' v ' ' "- ~5ubmit'In Duplicate KRU~04L1 & 1Q-04L1-01 Sidetracks - ~ed Tubing Drilling Summary of Operations: , A coiled tubing drilling unit will drill 2 laterals in producer KRU l 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 10-04L1 & 1Q-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-]l2" liner, memory GR/CCL log 6. Cement 7" casing in preparation for a cement ramp exit Rig Work z_MIRU Nordic 2. NU 7-1/16" BOPE, test. ________...._.~.___ _ ~ _ 10 Cy4L1 `.-.---f...e._._. __.~ - -'~"~`t`~ Q~~'`r.^" 3c--~ - 8. Mi112.74" window off a cement ramp. Plan the top of ramp to start at 9080' .' 9. Dri113" bicenter hole horizontal lateral from window to l 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 of the second liner to use as a KOP for L1-O1. Use SSSV for liner run. 11. Mi112.74" window off the aluminum billet at 9210'. 12, Dril13" 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. 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: • 1Q-04L1: 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. KRU~04L1 & 1Q-04L1-01 Sidetracks - d Tubing Drilling Directional • See attached directional plans for 1Q-04L1 & 1Q-04L1-O1 ,, • 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 1Q-04L1-O1 is 1Q-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 se ~ tion. ' Hazards • Each lateral will cross two mapped faults. Lost circulation risk is moderat . • Expect to encounter increasing pressure as lateral is drilled away from the other well. • Well 1Q-04 has a H2S reading of 1 l0 ppm. Well 1Q-21 has recorded 220 ppm H2S. All H2S monitoring ~ equipment will be operational. Reservoir Pressure ~ • The most recent SBHP survey (7105) was gauged at 2,200 psi after having een SI for just 3S 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 - 6511' TVD (L1 invert point). Max. surface pressure with gas (0.1 psi/ft) to surface is 2449 psi. - Variance request QCr~~j~u~~C ~~~ ~t (~'~ • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 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 hel~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. KRU 1 Q-04 L 1 /L'f-01 Producer Proposed CTD Completion ~~~~~~~~~~~~' ~~ ~ Rlaska, Inc. 9-5/8" 36# J-55 casing @ 4622' 2-3/8" liner top @ +/-9065' MD Top of Cement KOP at ~ +/-9080' M D Window in 7" H. 3-Ys" Baker 'FVL' SSSV set at 1815 RKB, 2.812" IC G. 3-1 /2" 9.3# J-55 EUE 8rd Mod tubing w/ 3-1 /2" x 1"Camco 'KBUG' mandrels F. 3-'/z" x 1-Yz" 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 RKB 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 RK8 A. 3-1/2" tubing tail at 9085 RKB (9075 ELM) 3" openhole Openhole KOP @ 9210' and (using inum billet) I North lateral (L1-01) , TD @ 11350' and ~a~°! 2-3/8" slotted liner ~~- _ _ e - A-sand South Lateral (L1), TD @ 11300' and 9511' MC ~ DEV i • KRU 1 Q-04 ConocoPhillips Alaska, Inc. 1 Q-04 API: 500292125000 Well T : PROD An le TS: 41 d 8708 SSSV T TRDP Ori Com letion: 3/19/1985 An le TD: 46 d 9535 Annular Fluid: Last W/O: Rev Reason: GLV desi n Reference Lo Ref L Date: Last U date: 7/10/2005 Last Ta : 9365 TD: 9535 ftK6 , - - Last Ta Date: 4/6/2005 Max Hole An le: 53 d 5400 ~ Casin Strin -ALL STRINGS Descri lion Size To Bottom TVO Wt Grade Thread CONDUCTOR 16.000 0 103 103 62.50 H-40 SUR. CASING 9.625 0 4622 3571 36.00 J-55 PROD. CASING 7.000 0 9511 6920 26.00 J-55 Tubin Strin -TUBING ' Size To Bottom TVD Wt Grade Thread 3.500 0 9085 6623 9.30 J-55 EUE SRD r Pertorations Summa l Interval ND Zone Status Ft SPF Date T e Comment 8709 - 8719 6347 - 6354 C-4 10 12 4/24/1985 IPERF 120de h'S"Scallo ed HDC e, 8722 - 8726 6357 - 6360 C-4 4 12 4/24/1985 IPERF 120de h'S"Scallo ed HDC 8735 - 8740 6366 - 6370 C-4 5 12 4/24/1985 IPERF 120de h~5"Scallo ed HDC ' 1 8742 - 8753 6372 - 6380 C-4 11 12 4/24/1985 IPERF 120de h~5"Scallo ed HDC 8756 - 8764 6382 - 6388 C-4 8 12 4/24/1985 IPERF 120de h 5"Scallo ed HDC ~ • 8771 - 8777 6393 - 6398 C-3 6 12 4/24/1985 IPERF 120de h•5"Scallo ed HDC - - 8834 - 8881 6440 - 6475 C-1 UNIT B 47 12 4/24/1985 IPERF 120de h•5"Scallo ed HDC 8914 - 8928 6499 - 6509 UNIT B 14 12 4124!1985 IPERF 120de h•5"Scallo ed HDC 9157 - 9164 6674 - 6679 A-4 7 4 10/4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 de .CCW F/ 9164 - 9224 6679 - 6721 A-0,A-3 60 8 10!4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 de .CCW F/ 9285 - 9303 6764 - 6776 A-2 18 8 10/4/1993 RPERF 2.5" Titan Hollow 180 deg. ph; Orient 27 d .CCW F/ Gas Lift Mandrels/Valves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv 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 4/25/1985 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 4/25/1985 ~,, 6 5751 4280 Camco KBUG GLV 1.0 BK2 0.156 1352 5/25/2002 _ 7 6224 4579 Camco KBUG DMY 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 ocket; Ref.' WSRs 12/19-20/99 Production Mandrels/Valves • St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv 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 Closed Other lu s e ui .etc . -JEWELRY - De th TVD T e Descri lion ID 181 5 SSSV 1714 ~ 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 De th Descri lion Comment - 9051 Ke s & Plu from CR Plan to Push down to Tubin Tail. 9119 27' of 1 7/8" Tool Strin Tool Strin lost in rathole 5l8/94~ wire recovered 5/10/94• Fish histo in WSR. 9530 DMY VALVE 1.5" DMY valve set 9/15102, but during check for DMY on 1/27/03, impression of em socket 9/15/02 DMY dro ed~ de th not known. BP Amoco w.v, ~oau~ +oa. ~••ati.~o) sooa.oo q: ww+ka ^w.wm.: ame ao.oon v.a.eae^ o.Mt~ o.pa aani!_ LEGEND T Plan: Plan k7 (4/PWn 7, 1D-04L1) b.. _ 4 (1a-o4l Azimuths to True North ~~y~jE'~'R~,l~ {-~ 4 Plan 6, 7G-04Li-0tl M Magnetic North: 24.10° Created By Bill Michaelson Date: en020o5 B nYGMES b Plan 7, 1G-04L1 - Plan p7 Magnetic Fleld Contact Intormatio~ Strength: 57607nT Bm Michaalson /~ Dip Angle: 80.78° Dlrech (907) 267-6624 ,~+~.1 Date: 9/14/2005 CeIC (907) 301-73570 Model: bggm2004 E-mall. bilLmichaelsonQmtegmm 1: ~ ~ • iliips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ><vr>E(,t Company: ConocoPhitlips Alaska, Inc. Date: 9/20/2005 Ttme: 14:15:14 Page: t ~ Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 4, True North ~' i Site: KRU 1 Q Pad Vertical (TVD) Reference: SITE 90.0 Wetl: 4 5ertia-(VS)Refereace: Well (O.OON,O.OQE,160.QOAzi) i Welipath: Plan 7, 1Q-041_1 SurveyCakuiation 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 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Weil Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 1Q Pad UNITED STATES: North Slope Site Position: Northing: 5985$77.04 ft Latitude: 70 22 20.956 N From: Map Fasting: 529617.73 ft Longitude: 149 45 33.406 W Position Uncertainty: 0.00 ft North Reference: True Grouud Level: 0.00 ft Grid Convergence: 0.23 deg WeIL• 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 Eastiog : 528565.70 ft ~ Longitude: 149 46 4.325 W Position Uncertainty: 0.00 ft Welipath: Plan 7, 1Q-04L1 Dril{ed From: 1Q-04 Tie-oo Depth: 9000.00 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 0.00 160.00 Plan: Plan #7 Date Composed: 9!14/2005 Copy Lamar's Plan 7 Version: 7 Principal: Yes Tied-to: From: Definitive Patfi Targets Name Description Dip. Dir 1Q-04L1 Polygon -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 -Polygon 11 1Q-04L1 Fault 1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 1Q-04L1 Fault2 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 1Q-04L1 Target4 1Q-04L1 Target 5 TVD ft 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 6600.00 6623.00 812.42 5682.00 5985480.00 534244.00 70 22 16.857 N +N!-S ft 2680.75 2680.75 2485.40 1976.49 1433.98 779.92 499.44 549.57 889.15 1763.27 2671.61 2765.69 2602.84 2602.84 2351.86 2100.88 2351.86 2363.06 2363.06 2112.08 1861.11 2112.08 1339.49 Map Map +E/-W Northing Fasting ft ft ft 5125.07 5987346.00 533680.00 5125.07 5987346.00 533680.00 5209.34 5987151.00 533765.00 5173.39 5986642.00 533731.00 5290.33 5986100.00 533850.00 5549.87 5985447.00 534112.00 5667.81 5985167.00 534231.00 5897.02 5985218.00 534460.00 5754.30 5985557.00 534316.00 5485.61 5986430.00 534044.00 5422.07 5987338.00 533977.00 5142.40 5987431.00 533697.00 5098.77 5987268.00 533654.00 5098.77 5987268.00 533654.00 5347.84 5987018.00 533904.00 5596.91 5986768.00 534154.00 5347.84 5987018.00 533904.00 5033.85 5987028.00 533590.00 5033.85 5987028.00 533590.00 5282.92 5986778.00 533840.00 5531.99 5986528.00 534090.00 5282.92 5986778.00 533840.00 5415.99 5986006.00 533976.00 --- <-- Latitude ---> G- Longitude -> Deg Min. Sec Deg Min Sec 70 22 35.235 N 70 22 35.235 N 70 22 33.314 N 70 22 28.309 N 70 22 22.973 N 70 22 16.538 N 70 22 13.779 N 70 22 14.270 N 70 22 17.611 N 70 22 26.210 N 70 22 35.143 N 70 22 36.071 N 70 22 34.469 N 70 22 34.469 N 70 22 31.999 N 70 22 29.529 N 70 22 31.999 N 70 22 32.112 N 70 22 32.112 N 70 22 29.642 N 70 22 27.171 N 70 22 29.642 N 70 22 22.042 N 149 43 34.355 W 149 43 34.355 W 149 43 31.893 W 149 43 32.955 W 149 43 29.545 W 149 43 21.966 W 149 43 18.522 W 149 43 11.815 W 149 43 15.983 W 149 43 23.825 W 149 43 25.665 W 149 43 33.846 W 149 43 35.126 W 149 43 35.126 W 149 43 27.843 W 149 43 20.561 W 149 43 27.843 W 149 43 37.031 W 149 43 37.031 W 149 43 29.748 W 149 43 22.466 W 149 43 29.748 W 149 43 25.871 W 149 43 18.100 W ConocoP'h~llips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report `+ L'VTE+[2 Company: ConocoPhiflips Alaska, Inc. Date: 9/20/2005 Time: 14:15:14 Page: 2 ~ Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 4, Tnte North Site: KRU 1 O Pad Vertical(TVD) Reference: SI TE 90.0 1 Well: 4 SeMio n (VS) Reference: Well (O.OON,OAOE,160. OOAzi) ~ Wellpath: Plan 7, 1Q-04L1 Survey Calculation Method: M inimum Curvature Db: Orade Targets ~ Map Map << Latitude -> <- Longitude -> 1 Name Description TW +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec 1 Dip. Dir. ft ft ft ft ft ~ 1Q-04 L1 Target3 6633.00 1631.69 5373.10 5986298.00 533932.00 70 22 24.916 N 149 43 27.119 W 1Q-04 L1 Target2 6664.00 1755.12 5262.56 5986421.00 533821.00 70 22 26.131 N 149 43 30.351 W 1Q-04 L1 Target 1 6706.00 2654.21 5264.99 5987320.00 533820.00 70 22 34.973 N 149 43 30.261 W Annotation MD TVD I ft ft ~ 9000.00 6561.68 TIP 9080.00 6619.29 KOP 9094.00 6628.82 3 9124.00 6645.94 4 9339.67 6706.20 End 40°/100' DLS 9589.67 6695.78 6 9650.00 6693.38 Fault 1 9814.67 6685.78 7 9900.00 6681.45 Fault 2 10100.00 6671.04 8 10250.00 6655.58 9 10400.00 6632.89 10 10500.00 6618.37 11 10600.00 6605.42 12 10700.00 6599.66 13 10850.00 6603.34 14 11075.00 6613.84 15 11300.00 0.00 TD Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target -~ ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9000.00 43.58 54.97 6561.68 2653.69 5017.03 0.00 0.00 0.00 0.00 9080.00 44.28 55.36 6619.29 2685.39 5062.59 0.94 0.87 0.49 21.27 9094.00 49.88 55.36 6628.82 2691.22 5071.02 40.00 40.00 0.00 0.00 9124,00 60.49 62.22 6645.94 2703.87 5092.08 40.00 35.36 22.87 30.00 9339.67 92.50 146.51 6706.20 2646.49 5269.40 40.00 14.84 39.08 85.00 9589.67 92.16 176.53 6695.78 2412.29 5347.68 12.00 -0.13 12.01 90.00 9814.67 92.84 203.55 6685.78 2193.00 5308.87 12.00 0.30 12.01 88.00 10100,00 92.91 169.26 6671.04 1914.03 5277.55 12.00 0.02 -12.02 271.00 10250.00 98.85 152.17 6655.58 1773.75 5326.51 12.00 3.96 -11.39 290.00 10400.00 98.41 170.38 6632.89 1633.91 5373.89 12.00 -0.29 12.14 90.00 10500.00 98.23 182.50 6618.37 1535.34 5380.03 12.00 -0.19 12.13 90.00 10600.00 96.60 170.51 6605.42 1436.56 5386.08 12.00 -1.63 -11.99 263.00 10700.00 89.99 160.47 6599.66 1340.09 5411.07 12.00 -6.60 -10.04 237.00 10850.00 87.22 142.68 6603.34 1208.75 5482.15 12.00 -1.85 -11.86 261.00 11075.00 87.52 169.70 6613.84 1005.02 5572.03 12.00 0.13 12.01 90.00 11300.00 87.79 142.68 6623.21 801.25 5661.94 12.00 0.12 -12.01 270.00 y.. CanocoPh~llips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report 11VTE(? Company: ConocoPhillips Alaska, Inc. Date: 9720!2005 Time: 14:15:14 Page: 3 Field: Ku paruk River Unit Caordiuate(NE) Reference: Wetl: 4, True North Site: KRU 1 Q Pad Vertical (TVD} Refe renee: SITE 90.0 Well: 4 Section (VS) Reference: Weli (O.OON, O.OOE,160. OOAzi) Wellpath: Plan 7, 1Q-04L1 Survey Calculation Metbod: Minimum Curvature Db: Oracle Survev MD Inc! Azim SS TVA N/S E!W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg ~ 9000.00 43.58 54.97 6471.68 2653.69 5017.03 5987318.54 533572.07 0.00 -777.73 0.00 MWD 9025.00 43.80 55.09 6489.76 2663.59 5031.18 5987328.49 533586.18 0.94 -782.19 21.27 MWD 9050.00 44.02 55.21 6507.77 2673.49 5045.41 5987338.45 533600.37 0.94 -786.63 21.18 M W D 9053.10 44.04 55.23 6510.00 2674.73 5047.18 5987339.69 533602.14 0.94 -787.18 21.10 1Q-04L1 9075.00 44.24 55.34 6525.71 2683.41 5059.72 5987348.42 533614.64 0.94 -791.05 21.09 M W D 9080.00 44.28 55.36 6529.29 2685.39 5062.59 5987350.41 533617.50 0.94 -791.94 21.01 MWD 9085.27 46.39 55.36 6533.00 2687.52 5065.67 5987352.55 533620.58 40.00 -792.88 360.00 1Q-04L1 9094.00 49.88 55.36 6538.82 2691.22 5071.02 5987356.27 533625.91 40.00 -794.53 0.00 MWD 9100.00 51.97 56.88 6542.61 2693.81 5074.89 5987358.88 533629.77 40.00 -795.64 30.00 MWD 9100.64 52.19 57.04 6543.00 2694.09 5075.31 5987359.16 533630.19 40.00 -795.76 29.04 1Q-04L1 9125.00 60.52 62.68 6556.43 2704.27 5092.86 5987369.40 533647.69 39.23 -799.32 31.01 M W D 9150.00 61.91 73.98 6568.50 2712.33 5113.17 5987377.54 533667.98 40.00 -799.95 84.77 MWD 9161.86 62.89 79.22 6574.00 2714.76 5123.40 5987380.01 533678.19 40.00 -798.74 79.32 1Q-04L1 9175.00 64.20 84.91 6579.86 2716.38 5135.04 5987381.67 533689.83 40.00 -796.28 76.89 MWD 9200.00 67.26 95.35 6590.15 2716.30 5157.78 5987381.68 533712,57 40.00 -788.42 74.35 MWD 9225.00 70.97 105.30 6599.08 2712.10 5180.72 5987377.57 533735.52 40.00 -776.63 70.05 MWD 9250.00 75.19 114.78 6606.37 2703.90 5203.15 5987369.45 533757.98 40.00 -761.25 66.50 MWD 9275.00 79.78 123.88 6611.80 2691.94 5224.39 5987357.58 533779.26 40.00 -742.76 63.73 MWD 9300.00 84.62 132.72 6615.20 2676.61 5243.79 5987342.32 533798.72 40.00 -721.70 61.75 MWD 9325.00 89.58 141.42 6616.46 2658.35 5260.77 5987324.12 533815.77 40.00 -698.74 60.55 MWD 9339.67 92.50 146.51 6616.20 2646.49 5269.40 5987312.30 533824.44 40.00 -684.65 60.11 MWD 9350.00 92.50 147.75 6615.75 2637.82 5275.00 5987303.66 533830.07 12.00 -674.59 90.00 M W D 9375.00 92.49 150.75 6614.66 2616.36 5287.77 5987282.25 533842.92 12.00 -650.05 90.05 MWD 9400.00 92.48 153.75 6613.57 2594.26 5299.40 5987260.19 533854.64 12.00 -625.31 90.18 MWD 9425.00 92.46 156.75 6612.50 2571.58 5309.85 5987237.55 533865.18 12.00 -600.42 90.32 MWD 9450.00 92.43 159.76 6611.43 2548.38 5319.11 5987214.39 533874.51 12.00 -575.45 90.44 MWD 9475.00 92.40 162.76 6610.37 2524.73 5327.13 5987190.78 533882.63 12.00 -550.49 90.57 MWD 9500.00 92.36 165.76 6609.33 2500.69 5333.90 5987166.77 533889.49 12.00 -525.58 90.70 MWD 9525.00 92.31 168.76 6608.31 2476.33 5339.41 5987142.43 533895.09 12.00 -500.80 90.82 MWD 9550.00 92.26 171.77 6607.32 2451.71 5343.63 5987117.83 533899.41 12.00 -476.23 90.95 MWD 9575.00 92.20 174.77 6606.34 2426.91 5346.56 5987093.04 533902.43 12.00 -451.91 91.07 MWD 9589.67 92.16 176.53 6605.78 2412.29 5347.68 5987078.43 533903.60 12.00 -437.80 91.18 M W D 9600.00 92.21 177.77 6605.39 2401.98 5348.19 5987068.12 533904.15 12.00 -427.94 88.00 MWD 9625.00 92.31 180.77 6604.41 2377.01 5348.51 5987043.15 533904.57 12.00 -404.36 88.05 MWD 9650.00 92.40 183.77 6603.38 2352.05 5347.52 5987018.19 533903.67 12.00 -381.24 88.17 MWD 9675.00 92.49 186.77 6602.31 2327.18 5345.22 5986993.32 533901.47 12.00 -358.66 88.29 MWD 9700.00 92.57 189.77 6601.21 2302.47 5341.63 5986968.59 533897.98 12.00 -336.67 88.42 MWD 9725.00 92.64 192.78 6600.08 2277.98 5336.75 5986944.09 533893.19 12.00 -315.32 88.55 MWD 9750.00 92.70 195.78 6598.91 2253.78 5330.59 5986919.87 533887.12 12.00 -294.69 88.69 MWD 9775.00 92.76 198.78 6597.72 2229.94 5323.17 5986896.00 533879.80 12.00 -274.82 88.83 MWD 9800.00 92.81 201.78 6596.50 2206.52 5314.52 5986872.55 533871.23 12.00 -255.78 88.97 MWD 9814.67 92.84 203.55 6595.78 2193.00 5308.87 5986859.01 533865.64 12.00 -245.00 89.11 MWD 9825.00 92.86 202.31 6595.27 2183.50 5304.85 5986849.49 533861.66 12.00 -237.45 271.00 MWD 9850.00 92.90 199.30 6594.01 2160.16 5295.99 5986826.12 533852.88 12.00 -218.55 270.94 M W D 9875.00 92.94 196.30 6592.74 2136.39 5288.35 5986802.33 533845.34 12.00 -198.83 270.79 MWD 9900.00 92.97 193.30 6591.45 2112.25 5281.98 5986778.17 533839.06 12.00 -178.33 270.63 MWD 9925.00 92.99 190.29 6590.15 2087.82 5276.88 5966753.72 533834.05 12.00 -157.11 270.48 MWD 9950.00 93.00 187.29 6588.84 2063.15 5273.06 5986729.03 533830.33 12.00 -135.23 270.32 MWD 9975.00 93.01 184.28 6587.53 2038.31 5270.55 5986704.19 533827.91 12.00 -112.75 270.17 MWD 10000.00 93.00 181.28 6586.22 2013.38 5269.33 5986679.26 533826.79 12.00 -89.74 270.01 MWD 10025.00 92.99 178.27 6584.91 1988.42 5269.43 5986654.30 533826.98 12.00 -66.25 269.85 MWD 10050.00 92.97 175.27 6583.61 1963.49 5270.84 5986629.38 533828.48 12.00 -42.35 269.69 MWD 10075.00 92.94 172.27 6582.32 1938.68 5273.55 5986604.58 533831.29 12.00 -18.10 269.54 MWD ` ~-' ~ • Conoc~hill~ps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ivr~c~ Company: ConocoPhillips Alaska, Inc. Date: 9!20!2005 Time: 14:15:14 ~ Page: d ii Field: Ku paruk River Unit Co-ordinate(NE) Reference: WetF 4, True NOrth Site: KRU 1Q Pad Vertical (TVA) Reference; SITE 90.0 Well: 4 Sectioa (VS) Reference: Well (O.OON, O.OOE,160 .OOAzi) ~Wellpath:-Plan 7, iQ-04L1 Survey Cak~utation Meshed: Minimum Curvature Db: Qracle Survev ~~ MD Inc! Azim SS TVD N/S E/W MapN MapF. DLS VS TFO Tool i ft .deg deg ft ft ft ft ft degt100ft ft deg 10100.00 92.91 169.26 6581.04 1914.03 5277.55 5986579.96 533835.39 12.00 6.43 269.38 MWD 10125.00 93.93 166.44 6579.55 1889.64 5282.81 5986555.58 533840.73 12.00 31.14 290.00 MWD 10150.00 94.94 163.60 6577.62 1865.56 5289.25 5986531.54 533847.26 12.00 55.97 289.83 MWD 10175.00 95.94 160.76 6575.25 1841.87 5296.86 5986507.88 533854.97 12.00 80.84 289.61 MWD 10200.00 96.93 157.91 6572.44 1818.63 5305.62 5986484.67 533863.82 12.00 105.68 289.34 MWD 10225.00 97.90 155.05 6569.22 1795.90 5315.51 5986461.98 533873.80 12.00 130.42 289.02 MWD 10250.00 98.85 152.17 6565.58 1773.75 5326.51 5886439.87 533884.87 12.00 154.99 288.65 M W D 10275.00 98.83 155.21 6561.73 1751.61 5337.45 5986417.77 533895.90 12.00 179.54 90.00 MWD 10300.00 98.80 158.24 6557.90 1728.92 5347.21 5986395.12 533905.75 12.00 204.21 90.47 MWD 10325.00 98.74 161.28 6554.09 1705.74 5355.76 5986371.98 533914.38 12.00 228.91 90.93 MWD 10350.00 98.65 164.31 6550.31 1682.13 5363.07 5986348.40 533921.78 12.00 253.59 91.39 MWD 10375.00 98.54 167.35 6546.57 1658.17 5369.12 5986324.46 533927.92 12.00 278.18 91.85 MWD 10400.00 98.41 170.38 6542.89 1633.91 5373.89 5986300.23 533932.79 12.00 302.61 92.31 MWD 10425.00 98.40 173.41 6539.23 1609.43 5377.38 5986275.76 533936.37 12.00 326.81 90.00 MWD 10450.Ofl 98.36 176.44 6535.59 1584.80 5379.57 5986251.74 533938.65 12.00 350.70 90.44 MWD 10475.00 98.31 179.47 6531.96 1560.08 5380.45 5986226.43 533939.63 12.00 374.23 90.89 MWD 10500.00 98.23 182.50 6528.37 1535.34 5380.03 5986201.70 533939.29 12.00 397.33 91.33 MWD 10525.00 97.85 179.50 6524.87 1510.60 5379.59 5986176.95 533938.96 12.00 420.43 263.00 MWD 10550.00 97.45 176.50 6521.54 1485.84 5380.46 5986152.20 533939.92 12.00 444.00 262.58 MWD 10575.00 97.03 173.50 6518.39 1461.13 5382.62 5986127.50 533942.17 12.00 467.95 262.18 MWD 10600.00 96.60 170.51 6515.42 1436.56 5386.08 5986102.94 533945.72 12.00 492.23 261.80 MWD 10625.00 94.96 167.99 6512.91 1412.12 5390.72 5986078.53 533950.45 12.00 516.77 237.00 MWD 10650.00 93.31 165.47 6511.10 1387.85 5396.44 5986054.29 533956.27 12.00 541.53 236.75 MWD 10675.00 91.65 162.97 6510.02 1363.82 5403.23 5966030.28 533963.15 12.00 566.44 236.56 MWD 10700.00 89.99 160.47 6509.66 1340.09 5411.07 5986006.58 533971.08 12.00 591.42 236.46 M W D 10725.00 89.52 157.51 6509.77 1316.75 5420.03 5985983.28 533980.13 12.00 616.42 261.00 MWD 10750.00 89.06 154.54 6510.08 1293.92 5430.19 5985960.48 533990.37 12.00 641.35 261.01 MWD 10775.00 88.59 151.58 6510.59 1271.64 5441.51 5985938.25 534001.78 12.00 666.16 261.05 MWD 10800.00 88.13 148.61 6511.31 1249.97 5453.97 5985916.64 534014.32 12.00 690.77 261.11 M W D 10825.00 87.67 145.65 6512.23 1228.99 5467.52 5985895.71 534027.95 12.00 715.13 261.20 MWD 10850.00 87.22 142.68 6513.34 1208.75 5482.15 5985875.53 534042.65 12.00 739.15 261.30 MWD 10875.00 87.23 145.68 6514.55 11$8.50 5496.76 5985855.34 534057.34 12.00 763.17 90.00 M W D 10900.00 87.24 148.68 6515.76 1167.52 5510.29 5985834.41 534070.95 12.00 787.52 89.85 MWD 10925.00 87.26 151.69 6516.96 1145.86 5522.70 5985812.79 534083.44 12.00 812.12 89.71 M W D 10950.00 87.28 154.69 6518.15 1123.57 5533.97 5985790.56 534094.79 12.00 836.92 89.57 MWD 10975.00 87.32 157.69 6519.33 1100.73 5544.04 5985767.75 534104.95 12.00 861.83 89.42 MWD 11000.00 87.36 160.70 6520.49 1077.39 5552.91 5985744.45 534113.91 12.00 886.80 89.28 MWD 11025.00 87.41 163.70 6521.63 1053.61 5560.55 5985720.70 534121.63 12.00 911.75 89.14 MWD 11050.00 87.46 166.70 6522.75 1029.47 5566.92 5985696.59 534128.10 12.00 936.62 89.00 MWD 11075.00 87.52 169.70 6523.84 1005.02 5572.03 5985672.16 534133.30 12.00 961.34 88.87 MWD 11100.00 87.53 166.70 6524.92 980.57 5577.14 5985647.74 534138.50 12.00 986.05 270.00 MWD 11125.00 87.54 163.70 6526.00 956.43 5583.51 5985623.62 534144.97 12.00 1010.93 270.13 MWD 11150.00 87.56 160.70 6527.07 932.65 5591.15 5985599.$7 534152.70 12.00 1035.88 270.26 MWD 11175.00 87.58 157.69 6528.13 909.30 5600.02 5985576.56 534161.65 12.00 1060.85 270.39 M W D 11200.00 87.61 154.69 6529.18 886.45 5610.10 5985553.75 534171.82 12.00 1085.77 270.51 MWD 11225.00 87.65 151.69 6530.22 864.16 5621.37 5985531.51 534183.17 12.00 1110.57 270.64 MWD 11250.00 87.69 148.69 6531.23 842.49 5633.78 5985509.89 534195.67 12.00 1135.18 270.77 MWD 11275.00 87.74 145.69 6532.23 821.50 5647.32 5985488.95 534209.28 12.00 1159.54 270.89 MWD 11300.00 87.79 142.68 6533.21 801.25 5661.94 5985468.75 534223.98 12.00 1183.57 271.01 MWD .` .~ ~ • Kuparuk DOBCTD BOP configuration 2" CT Well 1Q-04L1,L1-01 Rig Floor . I 7 1/16" 5000 psi BOP's. ID = 7.06" -~-JI 7 1/16" 5000 psi, RX-46 1/4 Tum LT Valve Tree Size 7 1/16" 5000 psi (RX-46) or ~- 4 1/16" 5000 psi (RX-39) Swab Valve Tee I I ~ ~ I _~ SSV Master Valve Base Flan e Page 1 • PERMIT TO DRILL 20 AAC 25.005 • (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include alt infomnation 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 ~~~ ~~~` D yam/ PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellb re segment of LATERAL existing well /~'~~~,,,,,C/1Q ~"Gy d~ ,~ ZI Z Permit No,~~?~1PI No. -~~.~ (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (pI~ records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes _ the liability of any protest to the spacing exception that may occur. , DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RV OIL- 490100 Well Name: KUPARUK RIV UNIT 1Q-04L1 Program DEV Well bore seg^ PTD#:2051390 Company CONOCOPHILLIPS ALASKA INC Initial Classfrype DEV I PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mit.feeattached____________________________________ ________NA._ ..____Multilateral_wellbore;feewaiYed-pe[20_AAC25.004(e)___-___-__-_______--_--__-______. 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - --- - --- - - - - - - - - - -- - - Yes Omission corrected on. 1.0-401:_ top of productive interval in ADL 025634, TD_ in ADL 025641. 3 Unique well-name and number- ------------ ------ ------- ---------Yes- ----.....--- --------- ----------- --- -- -- ------ ----- -------------- 4 Well located in a_defined pool_ _ Yes _ KUPARUK RIVER,_KUPARUK RVOIL - 490100, ,governed by Conservation Order No. 4320. _ _ 5 Well Irzcated proper distance from drilling unit_boundary_ - Yes - Conservation Order No. 432C contains no spacing restrictions with respectto drilling unit boundaries. _ _ 6 Well located proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ Yes _ _ _ _ - -Conservation Oder No. 4320 has-no inter!~II_spaeing.restr_ictions, _ _ _ _ _ - - .... _ _ _ _ _ _ - _ _ .. - - . _ _ . 7 Sufficient acreage available in_drilling unit_ - - Yes _ _ _ - _ _ -Conservation Order No. 4320 has no in_tenvell_spacin9_restrictions, Wellbore_will be_more than 500' from _ _ _ - - _ 8 If deviated, is-wellbore plat-included - - - - - - - - - - - - ----- - - ----- - - - - Yes - _ - - _ _ - an external property line where.ownership or-lan_downersh~ changes. _ _ _ _ _ _ _ _ _ . _ 9 Operator only affected party- - - - - - - - - - - - Yes - - - - - - - - - - - 10 Operatorhas.appropriate-bond in force---------------- ------ - -- ----Yes- ------------ ------------ ------------------------ -------------------- 11 Permit_canbeissuedwithoutconservatignorder________________-_ ---_--__-Yes_ _-___----.-_--_________-____---_-_.___________ -------------------------- Appr Date 12 Permitcanbeissuedwithoutadminist[ative_approval_--__-_________ ________Yes- _--__--__-__________--_--__.____________-______--____--_-__..--.-_-_- SFD 9/2212005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection 0[der # (putl9# in_eomments). (FQr_ NA_ _ _ - - _ . - - . - . . .. . . .. . . .. . . . - ... _ - 15 All wells within 114_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ . _ _ _ _ _ _ .. _ , . _ - _ _ _ _ - ----------------------------------------------------- 16 Pre-produced injector duration of pre production Less than_ 3 months_ (For service well only) _ - NA_ _ -------------------------------------------------------------------------- 17 AC_M_P_FindingofConsistency_hasbeenissued-fo[thisp[oject--__--__--_ __-_.-_-NA__ __-___Multilateralwellbore____________________________-.-...__.-______.--..__-- Engineering 18 Conductorstring_provided________________________________ ________ NA__ ______Conductorset_inmotherbore1Q-04-(184,234),_----.._.-_._____--.-..__--____.--._ 19 Su_rfacecasingprotectsallkncwnUSDWs_______.___ .......... ......... NA__ ___Allaquifersexempted,40CFR_147.102_(b).(3).__-._,___________--__-__________.__,__ 20 CMT_v_ol_adequate_tocircul_ate_onconducior&surf-csg--------------- ----___- NA__ __-__-$rarfacecasing set in_motherbore._-___---__--__-_____-__..--..-_.______--_-:._-_ 21 CMTvol_adequate-to tie-in longstringtosurfcsg________-_____-._ _..__-._-NA__ ______Pr_oduction_easingset in_motherbore.._------------------------------------------- 22 CMT_willcoverallknow_n_productivehorizons____________________ ____--_-No__ __-___Slottedliner completion pl_anned.-_--__________________-__-__--____________-____- 23 Casing designs adequate for C, T, B &-permafrost_ - _ - ..... _ _ _ - _ - _ Yes - - - - - - - O[iginal design mek requirements._ NA for slotted liners- - - - - - - - - - - - - - - - _ - . - - . - . - _ - - - 24 Adequate tankage-or reserve pit - _ .. - - .. - -Yes Rig is_equipped with st_eel_pits. -No reserue_pitplanned, All waste to_approved disposalwells.. 25 If_a_re~lrill,has_a10-403 forabandoRmentbeenapproved_____________ _________ NA_- __--__-______._____--_________________-_-________________-___--_____-. 26 Adequate wellbore separationproposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _Yes _ _ _ _ - _ _ Proximity analysis performed, Nearest wellbore_is motherbgre and trajectories diverge, _ . - .. _ _ _ _ _ _ _ _ , _ _ 27 Ifdiverterrequired,doesitmeetregulations______________________ _______ NA__ _.___-BOPstack_willalready_beinplaee,-___---__--__-__-__-_-._-..-_.-______-_-..___. Appr Date 28 Dtiiling fluid.prggram schematic & equip listadequate_ _ . . .. . . . . . . . . .. Yes - Maximum expected formation pressure 9.2_ EMW._ Managed pressure drilling will be used._ - - . - TEM 912312005 29 BOPES, do they rneet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ Yes - _ .. - - - _ 2 wellbore volumes_of kilt weight fluid will be on location for contingency. _ - - - _ .. - - - - ~~~ " 30 BOPE_press rating appropriate; test to-(pu_t psig in comments) _ _ _ , _ _ _ _ _ Yes MASP calculated at 2449 psi 350Qpsi BOP testplanned, , _ _ _ _ _ , _ _ _ _ _ Y ~ 31 Choke_manif4ld complies w/APf RP-53 (M_ay 84) Yes _ _ _ _ 32 Work will occur without operation shutdown_____________________ _________Yes_ ______-__-.-____________-_---___.--.__._--_ -- -- - - 33 I& presence-of H2S gas_probable- _ . - . _ - _ - - - - - -- - - -- - -Yes 1Q0_ppm H2$ has been repo[ted-in 1Q-04._ Mud should preclude, H2S_on_rig, R~-has sensprs and alarms... _ _ 34 Mechanical condition of wells within AOR verified (Forservice well only) _ NA_ _ _ _ _ _ _ _ _ _ _ Geology 35 Permit_can be issued wlo hydrogen_sulfide measures .. - - ..... No_ _ _ _ _ _ _ - H2S exceeding 1l)D ppm. has been measured in the parent wellbore._ H2S measures required, - _ - - _ _ 36 Data_presented on_ potential ove_rAressure zones _ _ _ , _ _ - -Yes _ . _ Estimated reservoir pressure is 9.2 ppg_EMW~will be drilled_withcoiled tubing and 8.6 ppg mud using_ Appr Date 37 Seismic-analysis of shallow gas zones_ . - - - - - - - - - - - - -- - - NA_ _ _ _ - .managed pressure drillingtechnique. - _ _ .. - - .. - . - -------------------------------- SFD 9122/2005 38 Seabedcpnditionsuryey_(ifgff-share)------------------------- ---------NA.- ____-___--_- 39 _COntactna_melphonefor_weeklyprogressrepo[ts[expl4ratoryonly]--_--__ --__--__-NA__ ____________________________________________-_--_---____________--,__-- Geologic i i Engineering P ' Date C Date: C i i i Date Comm oner: ss omm ss oner: o ~z3-~ 9 Z~/~.S°r~ • f • 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 sirnpiify Tending intom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • • **** REEL HEADER **** MWD 06/12/21 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05110/20 SEC ~a ~~ JAN ~ ~~~~t Andes 997967 01 2.375" CTK *** LI5 COMMENT RECORD *** Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 9072.0000: Starting Depth STOP.FT 10895.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1Q-04L1 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: 20-Oct-05 API API NYUMBER: 500292125060 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 ;~~~> °~~~ ~ lY ~~~ • (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.SSTVD) (8) The interval from 10871 ft.to 10895 ft.MD (6522.72 ft.to 6522.46 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) The well 1Q-04L1-01 was kicked off this wellbore 1Q-04L1 at 9198 ft.MD (6587.91 ft.SSTVD) (11) The well 1Q-04L1-02 was kicked off this wellbore 1Q-04L1 at 10058 ft.MD (6573.81 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: l 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN 1Q-04L1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1Q-04L1, 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 MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 44 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 53 Minimum record length: 54 Maximum record length: 4124 **** FILE HEADER **** MWD .002 1024 9072.000000 10894.500000 0.500000 feet records... bytes bytes r~ L *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-04L1.xtf C7 LCC 150 CN ConocoPhillips Alaska In wN 1Q-04L1, 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: 88 Tape File Start Depth = 9062.000000 Tape File End Depth = 10894.250000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 97 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes • **** TAPE TRAILER **** MWD 05/10/20 • 997967 01 **** REEL TRAILER **** MWD 06/12/21 BHI O1 Tape Subfile: 4 2 records... • Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS Tape 5ubfile 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 128.9900 70.9900 9300.0000 83.0700 63.2900 9400.0000 125.6300 69.9400 9500.0000 106.8000 42.4300 9600.0000 114.8000 47.8800 9700.0000 118.9300 66.1000 9800.0000 105.0000 46.0500 9900.0000 104.4800 80.7500 10000.0000 90.3000 40.7100 10100.0000 95.7100 55.9300 10200.0000 79.5600 62.0100 10300.0000 38.7100 49.2900 10400.0000 123.8300 83.9000 10500.0000 89.0050 70.1300 10600.0000 102.6800 64.9400 10700.0000 101.6400 65.1100 10800.0000 116.3500 33.8500 10894.5000 -999.2500 -999.2500 Tape File Start Depth = 9072.000000 Tape File End Depth = 10899.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 9062.0000 54.4400 -999.2500 9062.2500 58.0500 -999.2500 9100.0000 139.5600 20.6600 9200.0000 128.9900 70.9900 9300.0000 83.0700 63.2900 9400.0000 125.6300 69.9400 9500.0000 106.8000 42.4300 9600.0000 114.8000 47.8800 9700.0000 118.9300 66.1000 9800.0000 105.0000 46.0500 9900.0000 104.4800 80.7500 10000.0000 90.3000 40.7100 10100.0000 95.7100 55.9300 10200.0000 74.5600 62.0100 10300.0000 38.7100 49.2900 10400.0000 123.8300 83.9000 10500.0000 89.0050 70.1300 10600.0000 102.6800 64.9400 10700.0000 101.6400 65.1100 10800.0000 116.3500 33.8500 10894.2500 -999.2500 10.6300 Tape File Start Depth = 9062.000000 Tape File End Depth = 10894.250000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • • Tape Subfile 4 is type: LIS