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208-034
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~g - D~ (~.. Well History File Identifier Or anizin (done) ^ Two-sided III II'III VIII VIII ^ Rescan Needed III II'lII II II III III 9 g RES AN DIGI AL DATA OVERSIZED (Scannable) Color Items: iskettes, No.' ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: © /s/ Project Proofing II I II II II II III I I III BY: Maria Date: ~, /s/ Scannin Pre aration _~ x 30 = ~_ + ~_ =TOTAL PAGES (Count does not include cover sheet) g ~r (nnI BY: Maria Date:. ~I ~ `7 I I D /s/ Y! L-~ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~I'~ ' ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 11 BY: Maria Date: /s/ VIII Scanning is complete at this point unless rescanning is required. III II'I II I II II ReScanned BY: Maria Comments about this file: Date: Quality Checked uiiiuiiuiui 10!6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2!17/2010 Permit to Drill 2080340 Well Name/No. KUPARUK RIV UNIT 1R-01BL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21404-60-00 MD 9730 TVD 6663 Completion Date 5/2/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~ ~,/~ Mud Log No Samples No Directional Survey Ye DATA INFORMATgN Types Electric or Other Logs Run: MWD DIR 1 GR / RES (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 D Asc -~` Directional Survey 8049 9730 Open 5/23/2008 Rpt Directional Survey 8049 9730 Open 5/23/2008 i/ D Asc Directional Survey 8078 8170 Open 5/23/2008 PB 1 ~Rpt Directional Survey 8078 8170 Open 5/23/2008 PB 1 I ~~'' ' " C Tap uction/Resistivity 18069 Ift d 7505 9730 Open 5/20/2009 GR, ROP, RAD< RAS, RPD, RPS tog Induction/Resistivity 5 Col 8055 9730 Open 5/20/2009 TVD MPR, GR og Induction/Resistivity 25 Col 8055 9730 Open 5/20!2009 MD MPR, GR C Lis 18278 Gamma Ray 7505 8170 Open 7/14/2009 PB 1 GR, ROP Plus PDF, Meta and CGM graphic logs -~! - - Gamma Ray _ 25 Col _- 8085 8170 Open 7/14/2009 PB 1 GR, ROP Nell Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • DATA SUBMITTAL COMPLIANCE REPORT 2/17/2010 Permit to Drill 2080340 Well Name/No. KUPARUK RIV UNIT 1 R-016L1 Operator CONOCOPHILLIPS ALASKA INC MD 9730 TVD 6663 Completion Date 5/2/2008 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y/ N Daily History Received? Y J N Chips Received? Y / N Formation Tops Y / N Analysis Y / N Received? Comments: API No. 50-029-21404-60-00 UIC N Compliance Reviewed By: __ ____ Date: CONOCOPHILLIPS ALASKA, INC. # PRINTS 1R-01BL1 P61 KUPARUK RIVER UNIT NORTH SLOPE BOROUGH, ALASKA ConocoPhillips Alaska, Inc. 1 NSK Wells Aide, NSK 69 700 G Street, Anchorage, AK 99501 ATTN: MAIL ROOM # LAS AOGCC 1 1 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Christine Mahnken BP 1 1 Petrotechnical Data Center, M633 P.O. Box 196612 Anchorage, Alaska 99519-6612 David Douglas CHEVRON/KRU REP 1 1 P.O.Box196247 Anchorage, Alaska 99519 Glenn Fredrick State of Alaska; DNR, Div. of Oil and Gas 1 550 W. 7th Ave, Suite 800 Anchorage, Alaska 99501-3510 Kristen Dirks, Geologist JUL ~ 4 20u9 ?,iaska Oil ~ Gas Cons. Commissia ~nchoragP ~3`f_ 1 ConocoPhillips Alaska Data Distribution RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wri ht, 907 263-4823 hardco prints ConocoPhillips Alaska, Inc. Sharon Allsup-Drake Drilling Tech, ATO-1530 ConocoPhillips Alaska, Inc. 1 NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 ConocoPhillips Alaska, Inc. Ricky Elgarico 1 1 Well Data Specialist, ATO 1802 700 G Street, Anchorage, AK 99501 ftp://b2bftp.conocophillips.com **** AOGCC 1 Christine Mahnken 1 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 BP 1 Petrotechnical Data Center, MB33 1 David Douglas P.O. Box 196612 Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Glenn Fredrick 1 P.O.Box196247 Anchorage, Alaska 99519 Kristen Dirks, Geologist State of Alaska; DNR, Div. of Oil and Gas 1 550 W. 7th Ave, Suite 800 Anchora e, Alaska 99501-3510 ~~-Ov~ l ~ ®C~~i ~,~ A® MAY ~ ~ Luu~ - 1 X11 t~k ~O43I3S, 1,~~'uf ~ ~i~SS(2i~i A~d~e Page 1 of 2 STATE OF ALASKA 6- 3~8 ALAS~OIL AND GAS CONSERVATION CO~ISSION J U N ~ 2 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOCH' : ' ~.~ =~. ~'~?ns. Commissian r ~ ., 1 a. Well Status: ®Oil ^ Gas ^ .Plugged ^ Abandoned ^ Suspended 2oAAC2s.~os 2oAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Abal]d/~ 5/2/2008 ,,~~~~ 12. Permit to Drill Number 208-034 ~ 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/9/2008 13. API Number 50-029-21404-60-00 ~ ~4a. Location of Well (Governmental Section): Surface: ' 7. Date T.D. Reached 4/15/2008 14. Well Name and Number:, Kuparuk 1 R-01 BL1 FNL, 5140; FEL, SEC. 20, T12N, R10E, UM 153 Top of Productive Horizon: 1728' FNL, 2232' FEL, SEC. 20, T12N, R10E, UM 8. KB (ft above MSL): 79.9' ~ Ground (ft MSL): 15. Field /Pool(s): ~ Kuparuk River Unit /Kuparuk Total Depth: 761' FNL, 1609' FEL, SEC. 20, T12N, R10E, UM 9. Plug Back Depth (MD+TVD) 9730' 6663' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 539830 y- 5991050 Zone- ASP4 10. Total Depth (MD+TVD) 9730' 6663' 16. Property Designation: ADL 025635 TPI: x- 542752 y- 5989493 Zone- ASP4 Total Depth: x- 543367 y- 5990463 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ~ Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic andprinted ' formation per 20 AAC 25.071): MWD DIR / GR / RES L~/il/Q04J ~ PJ1~ Si/I,p ~'j ~.,~ '7~YD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT.. GRADE -' TOP BOTTOM TOP - .BOTTOM SIZE CEMENTING RECORD PULLED 2- /8" 4.44# L-80 8723' 9400' 6657' 634' 2.69" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TualNC RECORD If Yes, list each i (MD+TVD of To & Bottom Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD p ; 2-3/8" Slotted Section Note: 3-1/2", 9.3#, L-80 6285' 6243' MD TVD MD TVD 8733' - 9019' 6656' - 6648' Well Branch Well Branch 9145' - 9240' 6647' - 6637' 1 R-01 BL1 1 R-01 BL1 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Departs From Is not Directly DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED Well Branch Accessible 01 BL1 01 1 R 8055' - 8057' (Squeeze Perfs), Pumped 10.5 Bbls Cement, , - - PTD # 208-035, Placing 3.6 Bbls behind pipe (for zonal isolation) at 8723' MD ' 8085' Set (1st) Whipstock (failed) (xxx TVD) 8055' Set {2nd) Whipstock, Top of Window 26. PRODUCTION TEST Date First Production: Reported on 1 R-01 BL1-01 Method of Operation (Flowing, Gas Lift, etc.): See 1 R-01 BL1-01 (Dated xxx, PTD #208-035) for Production & Test Data Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-aBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. I {rtluh iiC'.~I'i ~.~~ None ~ S-d~-~0~ 1 Form 10-407 Revised 0212007 ONTINUED ON REVERSE SIDE ~ ~., ,~tJ~ ,~ ~ 1D~E~ ~~ ~RIGINA~. 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS RKERS ENCOUNTERED): 29. FORMATION TESTS NAME D TVD Well Tes ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top Kuparuk A6 8185' 6635' None Top Kuparuk A5 8196' 6638' Top Kuparuk A4 8260' 6655' Top Kuparuk A3 8370' 6673' Invert Top A4 9230' 6638' Revert Top A6 9564' 6644' Revert Top A5 9605' 6648' Revert Top A4 9690' 6658' Formation at Total Depth (Name): Top A4 9690' 6658' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true d correct to the best of my knowledge. ~~~ ~ c ~ ~ Signed Terrie Hubble Title Drilling Technologist Date Kuparuk 1 R-01 BL1 208-034 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Mel Rixse, 564-5620 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only Well History for 1 R-01 BL1 & 1 R-01 BL1-01 DATE SUMMARY 8/7/07 PERFORMED 30 MINS SBHPS C~2 6221' RKB=2286 PSI, 131 DEG F. 10 MIN GRADIENT STOP MADE C~ 6100'. JOB COMPLETE. 8/24/07 GAUGE TBG W/ 2.77" GAUGE TO DS-NIP Q 6221' RKB, BRUSH & FLUSH TBG TO DS-NIP. DRIFT W/ 2.86" GAUGE RING, SD IN COLLARS, APPEARS TO BE SCALED UP, WORK DN TO 4971' SLM. JOB SUSPENDED 9/17/07 Perform Scale Millout, Ran 2.8 mill, Milled from surface to 6150 CTMD, Well turned over to DSO, Ready for S/L. 9/19/07 PULLED 2.81" CLOCK & FLOW THROUGH SUB C«~ 6221' RKB. TAGGED METAL OBSTRUCTION C~ 6283' WLM. IN PROGRESS. 9/20/07 WORKED 5' x 2.50" DRIVE DOWN BAILER FROM 6468' TO 8088' WLM TO CLEAN UP TBG. GAUGED TO 2.79". RAN 15' x 2.74" DUMMY WHIP STOCK DRIFT TO 6464' WLM, WORKED TO 6472' WLM. IN PROGRESS. 9/21/07 GAUGED TBG WITH 2.79" BROACH TO 8077' WLM. ATTEMPTED DRIFT TBG WITH 16' x 2.74" DUMMY, UNABLE TO PASS 6464' TO 6471'. ATTEMPTED DRIFT TBG WITH 5.5' x 2.74" DRIFT, UNABLE TO WORK PAST 6471'. JOB SUSPENDED. 9/29/07 RAN 2.75" MILL FROM SURFACE TO 8100' CTMD, WORKING AREA BETWEEN 6400' CTMD AND 8100' CTMD, MADE DUMMY WHIPSTOCK DRIFT (2.65" OD x 17') TO 8100' CTMD AND INCOUNTERED NO RESISTANCE. TURN WELL BACK OVER TO DSO, WELL ON PRODUCTION. JOB COMPLETE. 9/30/07 RAN 17' X 2.74" AND 17' X 2.72" DRIFTS, NEITHER COULD PASS 6472' SLM. RDMO. 1/21/08 (CTD PREP) T & IC POT/PPPOT -PASSED, MITOA -PASSED, TIFL -PASSED, PT/DD MV & WING VALVES -PASSED, DD SV PASSED, PT SV FAILED 3/8/08 TAGGED APPARENT FISH WITH 2.5" x 5' DRIVE DOWN BAILER C~ 8099' WL. SET 2.81 CA2 PLUG C~ 6221' RKB; SET CATCHER ON PLUG. TESTED PLUG TO 2500 PSI, GOOD. PULLED OV C~3 6174' RKB. IN PROGRESS. 3/9/08 PULLED GLVs C~? 2632', 5015' RKB; REPLACED WITH DVs. WELL READY TO LOAD WITH SW. 3/10/08 Loaded well with SW containing 1 % corrosion inhibitor, down the tubing and up the IA from 2500' to 6147'. Freeze protected the tubing and IA down to 2500'. 3/11/08 SET 1.5" DV @ 6174' RKB, MIT IA TO 3000# BAILED FILL (SCALE) PULLED CATCHER C~3 6182' WLM. IN PROGRESS 3/12/08 PULLED CA-2 BLANKING PLUG Q 6221' RKB, CALIPER TBG FROM 8095' WLM TO SURFICE 3/21/08 MADE DRIFT RUN WITH 2.74" X 11.5' DUMMY DRIFT TO 8140' MD ENCOUNTERED NO RESTRICTION THROUGH BUCKLED 3.5" LINER ~ 6470' MD. NOTIFIED DSO OF WELL STATUS. JOB IN PROGRESS. 3/22/08 PERFORMED SLB MEMORY LOGGING RUN WITH GAMMA RAY/CCL FROM 6100' - 8100' CTMD, POOH, JOB IN PROGRESS. NOTIFIED DSO OF WELL STATUS. 3/25/08 PERFORMED WEEKLY BOP TEST. RIH W/ BAKER J HYD. SETTING TOOV 2.74" KB PACKER ON I-COIL TO SETTING DEPTH OF 8,134'MB TEN FEET ABOVE FISH C«~ 8,144'MD. AFTER SETTING PACKER, UNABLE TO STACK WEIGHT ON PACKER. PUSHED AND LEFT PACKER ABOVE FISH C~3 8,144'MD. WILL ATTEMPT TO FISH PACKER IN AM. JOB IN PROGRESS. 3/26/08 PULLED 2.74" BAKER KB PACKER FROM ABOVE FISH C«3 8135' CTM. NOTIFIED DSO OF DEPARTURE. JOB IN PROGRESS. Page 1 of 2 ~ ~ Well History for 1 R-01 BL1 & 1 R-01 BL1-01 DATE SUMMARY 3/27/08 WASH TUBING TO 8,135' CTM, WASH ACROSS PACKER SET DEPTH C~ +/- 8,100' MD SEVERAL TIMES, MAINTAIN 1:1 RETURNS THROUGHOUT TUBING WASH, VERY LITTLE METAL IN RETURNS. SET BAKER KB PACKER C~ 8,114' MD, HOWEVER UNABLE TO GET PT ON PACKER, JOB IN PROGRESS. 3/28/08 PRESSURE TEST BAKER KB PACKER C«~ 8104'MD TO 2000 PSI. LEAK RATE THE SAME AS PREVIOUS DAY 80-90 PSI PER MINUTE. DECIDE TO PUMP SAND PLUG. PUMPED 220# OF 20/40 ABOVE KB PACKER. AFTER PUMPING SAND PLUG, TAG UP ON KB PACKER, NEVER SAW PLUG, POOH. JOB IN PROGRESS. 3/29/08 PUMPED TOTAL OF 500# 20/40 SAND ABOVE BAKER KB PACKER C~ 8104' MD IN TWO STAGES. FOUND SAND TOP ON FIRST STAGE C~3 8102' MD, WHILE ATTEMPTING SECOND TAG GOT HUNG UP C~3 8045' MD, ABLE TO PUMP FREE, JETTED TUBING TO 8065' MD, PT TUBING TO 1600 PSI, LEAK RATE IS 10-15 PSI PER MINUTE, RDFN, JOB IN PROGRESS. 3/30/08 SHOT 2' PERF INTERVAL WITH 2" HSD ~ 8055'-8057' MD. PERFORM INJECTIVITY TEST ON NEW SHOT PERF .5 BPM 920 PSI, TOTAL OF 20 BBLS PUMPED, TUBING LOADED WITH DIESEL. NOTIFIED DSO OF WELL STATUS. JOB COMPLETE. 3/31/08 BH LEAK DETECT/ MITOA -PASSED See Daily Drilling Report Summary, 03/31/08 - 05/02/08 5/10/08 THAW TREE OF ICE.PULL BPV. D&T "DS" NIPPLE C~ 6186' SLM W / 2.84" GAUGE RING. PERFORMED 30 MIN SBHPS C~3 6365' SLM=2536 PSI, 124 DEG F. 15 MIN GRADIENT STOP MADE C~ 6165' SLM=2471 PSI. JOB IN PROGRESS 5/11/08 SET 2.81" CA-2 PLUG C~3 6221' RKB.TESTED TBG=GOOD.SET CATCHER BAITSUB ASSY WITH PULLING TOOL ON PLUG.PULLED 1.5" DV FROM STA #5.`"`OPEN POCKET"*. IN PROGRESS 5/13/08 LOADED TBG X IA W/ 255 BBLS OF 9.6# Naar BRINE. PERFORMED DRAWDOWN TEST ON TBG/IA; BLED TO 0 PSI, MONITORED FOR 30 MINS, REMAINED C~ 0 PSI. 5/14/08 DRILL AND TAPPED TWO 1/2" HOLES,REMOVED FURMANITE CLAMP. 5/17/08 CMIT-T+IA COMBO,REMOVE OA VR PLUG INSTALL JEWELRY FOR NITROGEN PURGE. 5/18/08 REMOVE IA VR PLUG, INSTALL JEWELLY FOR NITROGEN PURGE. 5/20/08 1 R-01 B BRADEN HEAD WELD. 5/21/08 1 R-01 B INSTALL VR PLUGS AND NORMAL ANNULUS JEWELRY W/2000# GAUGE.MITOA PASSED. 5/22/08 CIRCULATED 250 BBL DSL DOWN IA, TAKING RETURNS TO TANK. SET 1/4" OV ~ 6174' RKB. PULLED DVs C~ 5718' & 5015' RKB. SET GLVs C~3 SAME. IN PROGRESS. 5/23/08 PULLED DV C~ 2632' RKB, REPLACED WITH GLV. ATTEMPTED PULL DV C«? 3998' RKB WITH OVERSHOT; EVENTUALLY SHUCKED GRAPPLE. DV MAY BE CONSIDERED TO BE PERMANENT. PULLED EMPTY CATCHER SUB & CA-2 PLUG C~3 6221' RKB. COMPLETE. Page 2 of 2 BP EXPLORATION Page 1 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task 'Code NPT Phase Description of Operations 4/1/2008 00:00 - 03:00 3.00 ~ P PRE 03:00 - 03:15 ~ 0.25 P PRE 03:15 - 04:00 0.75 P PRE 04:00 - 06:00 2.00 P PRE 06:00 - 07:30 1.50 P PRE 07:30 - 10:00 2.50 P PRE 10:00 - 11:00 1.00 P PRE 11:00 - 16:35 5.58 P PRE 17:00 - 18:00 1.00 P PRE 18:00 - 19:00 1.00 P PRE 19:00 - 20:00 1.00 P PRE 20:00 - 21:00 1.00 P PRE 21:00 - 21:15 0.25 P PRE 21:15 - 22:30 1.25 P PRE 22:30 - 23:00 0.50 P PRE 23:00 - 00:00 1.00 P PRE 4/2/2008 00:00 - 05:00 5.00 BOPSU P PRE 05:00 - 06:00 1.00 BOPSU P PRE 06:00 - 12:00 6.00 BOPSU P PRE 12:00 - 20:30 8.50 BOPSU N SFAL PRE 20:30 - 21:00 0.50 BOPSU P PRE 21:00 - 21:15 0.25 RIGU P 21:15 - 23:00 1.75 RIGU P 23:00 - 00:00 1.00 RIGU P 4/3/2008 00:00 - 00:30 0.50 BOPSU P 00:30 - 02:30 2.00 BOPSU P 02:30 - 02:45 0.25 P 02:45 - 03:55 1.17 P 03:55 - 04:30 I 0.58 I I C 04:30 - 05:30 1.00 C PRE PRE PRE PRE PRE PRE PRE PRE PRE Complete Stacking back equipment on rig. Changed Injector chains on Injector head. Completed a walk around with 30-02 Pad operator. Cleared to move the rig off 30-pad. Safety meeting prior to moving off well. Discuss loose objects, good communication, clear view of rig movement. Start moving rig off well. begin moving down the road to 40 man camp and wait for field shift change at 06:00 hrs. Stop and wait on crew change for STP. Recontinue drive to intersection at CPF 3. Stop and wait at CPF 3 for crew change out at CPF 3. Recontinue dive from CPF 3 to DS 1 R. Rig On 1 R -Pad, Continue with well site prep for rig to move into place. Crew change out and safety meeting. Continue with rig maintenance. Spot rig mats in front of Well. Call out Pad maintenace to help install WH working platform Install Wellhead working Platform. Pre-Spotting safety meeting Move rig over 1 R-01 well. Level rig over well. Accept Rig as of 23:00 hrs Begin setting equipment in place for NU/BOP's and hard line. NU Bop's, hard line & Well control valves. Function test BOP's & fill stack. Start pressure testing BOP's and control valves. Test BOPE 250/4000 against the tree SV. Test MPD loop 250/4000 against the tree MV. AOGCC waived witnessing Replace internal components of leaking kill HCR, but didn't have the right ones. Head to Price Pad to fetch a backup HCR PT hardline line to tiger tank to 2500 Pressure test HCR ensure no leaks on flange or body. Looked good, Test valve 250 & 4000psi. BOP test Complete. Pre-job safety meeting for stabbing CT into injector. Set up injector & Stab CT, change out stripper packing. Make up FMC lubricator and stabbing bar. Bring up to rig floor I rig upon well. Pull BPV, 500 psi on wellhead when BPV was pulled. Intall CT connector, stinger, nozzle. Stab injector on well, pressure test stripper rubber & inside reel valve (250/4000 psi). Safety meeting prio to RIH. Bleed IA down from 840 psi to 240psi fluid packed. WHP 500/ IA 200 / OA 160 Lined up to Tiger tank, open well begin to RIH displacing well with 9.01#KCL. WHP 560 psi while RIH, with gas/diesel to TT. IA slowly increasing up to 600psi looks like equalizing with WHP. Continue RIH with 560psi on choke gas/diesel returns less than 1 bpm. Currently pumping .6 bpm, 500psi. Tagged top of packer or Sand top ~ 8100'. P/U CT depth to 8060' increase pump rate to 2.0 bpm. WHP 540 psi / IA 700 / OA 600 Printed: 6/10/2008 4:15:59 PM 4 t a M BP EXPLORATION Page 2 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ~ NPT ~ Phase Description of Operations 4/3/2008 04:30 - 05:30 1.00 1 C PRE Getting around 1 bpm/gas cut diesel for returns to TT. 05:30 - 06:00 0.50 C PRE Getting good warm brine fluid back to surface. Pinch in choke 06:00 - 06:45 0.75 C PRE 06:45 - 06:55 0.17 C PRE 06:55 - 07:30 0.58 C PRE 07:30 - 07:45 0.25 C PRE 07:45 - 08:40 0.92 C PRE 08:40 - 09:00 0.33 C PRE 09:00 - 10:05 1.08 C PRE 10:05 - 11:00 0.92 C PRE 11:00 - 11:25 0.42 C PRE 11:25 - 11:50 0.42 C PRE 11:50 - 12:00 0.17 X PRE 12:00-12:20 ~ 0.33 ~X PRE 12:20-13:00 ~ 0.67 ~X ~ PRE 13:00-14:15 ~ 1.25 ~X ~ PRE 14:15 - 15:15 I 1.001 I X I I PRE 15:15-15:50 I 0.581 IX I IPRE to 620psi to ensure no infulx follows CT while POOH. MM not working on out rate, no gas just straight brine. POOH slowly.. total volume pumped 57 bbls. IA 940 psi, bleed it down to 200 psi. POOH, Increase WHP to 700psi, IA 255psi, OA 750psi. Red whp to 300 psi at 6000' 1.9/2930 w/ IA 320, OA 900 Park at 5000' 1.89/1.80/3080 w/ IA 350, OA 980 Circ at 5000' 1.89/1.85/2830 w/open choke IA 360, OA 1000 Continue to get frothy returns Bleed IA from 370 psi to 170 psi. Circ until wellbore returns were clear of gas SD pump and flow check for 15 min Begin circ 2.05/1.94/3320 w/ OA 1055. POOH for cement assy PVT 124 Flowcheck. Remove nozzle. Set injector to side IA 165, OA 1085 RU to run jointed pipe to cover a-line slack of 425' MU 15jts 1-1/4 CSH IA 145, OA 955 RIH w/ CT circ 0.7/450 Safety mtg re: cementing Park at 4900' while Nordic replaces a valve in reel house Resume RIH and circ 0.89/885 IA 145, OA 810 RIH to 8088' CTD at min rate and did not tag. Cementers had not mixed up cement due to miscommunication. Noticed OAP was at 640 psi and a check of cellar showed gas/diesel blowing 3' of spray from under the wellhead clamp area on the braidenhead toward the reserve pit side Make initial notifications to DSO and DSM while bleed OA from 640 psi to +/-50 psi to bleed trailer. The leak stopped. Bled the IA from 150 psi to 40 psi and the OAP increased to 85 psi and then started blowing gas/diesel again from prior spot DSO arrived and notified Security while shutting down all operations on the Pad. Start bleeding gas off of OA to bleed trailer again while leak on wellhead subsided to lite blow. Discuss w/CPAI Anchorage and decided to POH to minimize exposure and conduct diagnostics. RDMO cementers Report to Security <2 gal leak of diesel into secondary containment in the cellar. Send PIR to Well Ops Supv POOH circ 0.8/800 Leave OA open and bleed gas to bleed trailer and gas coming from the wellhead stopped Recover 210' of a-line slack. Set injector on legs. LD 15 jts CSH By 1445 hrs the OA and leak area were stable w/ no returns. Conference call w/ CPAI town, Well Ops Supv on plan forward. Will RIH to 4000', circ warm fluids, MIT IA Seal a-line. MU 2.65" nozzle asst' w/ stinger SI OA and monitor pressure. IA 20, OA 21 Printed: 6/10/2008 4:15:59 PM BP EXPLORATION Page 3 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ' Code NPT Phase Description of Operations 4/3/2008 15:50 - 16:30 0.67 X PRE 16:30 - 19:40 3.17 X PRE 19:40 - 20:00 0.33 X PRE 20:00 - 20:50 0.83 X PRE 20:50 - 21:30 0.67 X PRE 21:30 - 23:00 1.50 X PRE 23:00 - 00:00 1.00 X PRE 4/4/2008 00:00 - 01:00 1.00 X PRE 01:00 - 01:30 0.50 X PRE 01:30 - 07:00 5.50 X PRE 07:00 - 11:30 4.50 X PRE 11:30 - 14:00 2.50 X PRE RIH w/ nozzle assy and circ 0.55/320 to 4000' while warm up surface fluids to prior temperature of 98 deg in/out IA 24, OA 23 Park at 4000' and circ 1.3/1220 to pit 4 (36 bbls). Heat KCI from 83F to 98F in/out Fluid temp in/out of well 97/91. Hold pre-test safety meeting. Discuss gas senors in Cellar, double checked all grounding wires, possible gas release on wellhead, well control & muster station routes. IA test procedure reviewed and ready to move forward. Pressure test tri-plex lines to 3500psi. Stop pumping down CT and shut in Choke. IA = 36psi OA = 39 psi WHP = 6psi Pumped 2.5 bbl IA to 2540psi ~ 20:18 min. Dropped to 2430 psi ~ 20:30, 2367psi ~ 20:48. OA = 50 psi increased 10 psi held. IA leaked off as per test try bump up again for another 30 min. From 2350 psi additional 1/4 bbl to bump up IA 2550 ~ 20:56, 2500psi C~3 21:10, 2460 ~ 21:26. Going by Well Integrety guidelines test has failed at this point and time. Prior to more discussion. Bled pressure back down to 40psi on IA/OA. Circulate CT string and wait on phone conversations from town Engineers. Plan forward is to POOh with CT, prep well for possible SL run and further integrety tests. POOH with CT from 4000' IA - 120psi OA - 38psi WHP - 150 psi keeping positive pressure on well, pumping 1.5bpm. POOH with CT to surface. Stand back injector & continue to circ. CT while waiting on Slickline. Wait on Slick-line Unit. No 24 hour operations on short notice. Performed safety drills on rig /reviewed procedures. HES slickline arrives. PJSM. Bring tools to floor. PT lub at 3000 psi RIH w/ plug and set in D nipple at 6221'. PT to 1500 psi. POOH Set back lubricator and install nitecap Rig pressure up on tubing w/ 1.1 bbls of 9.1#KCI to 2700 psi Start 30 min MIT of tubing at 1140 hrs 1140 Tbg=2680, IA=20,OA=31 1155 Tbg=2667, IA=20, OA=31 1210 Tbg=2657, IA=20, OA=31 Left pressure on tubing while wo DHD crew. PJSM. RU DHD guys 1252 Tbg=2630, IA=20, OA=31 Initial CMIT 1301 Tbg=3032, IA=2499, OA=37 After IA pressured to 2500 psi w/ 2.0 bbls diesel 1316 Tbg=3029, IA=2417, OA=38 Printed: 6/10/2008 4:15:59 PM F ~ r BP EXPLORATION Page 4 of 35 ~ Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ', Hours Task Code NPT 4/4/2008 11:30 - 14:00 2.50 X Start: 3/24/2008 Rig Release: 5/2/2008 Rig Number: Spud Date: 4/1 /2008 End: 5/2/2008 14:00 - 17:30 ~ 3.50 ~ ~ X 17:30 - 19:30 I 2.00 I I X 19:30 - 20:00 0.50 C 20:00 - 21:25 1.42 C Phase Description of Operations PRE 1332 Tbg=3025, IA=2396, OA=40 1355 Tbg=2622, IA=12, OA=34 Bleed off pressures and discuss results. Both pass PRE Install slickline equalizing prong. RIH and unseat watermelon. POH. RIH w/ plug pulling tool. POOH w/ plug. Seals intact. RD lub and BOP's. RDMO slickline unit PRE PJSM. RU floor tools. MU nozzle on 10 jts CSH tubing w/ SD for crew change PRE Pre-mix/ Rlh meeting for cement job. PRE RIH with CT, Start mixing up cement while RIH. 20:55 -cement to weight 15.8# 20:55 -Begin shearing for 30min. 21:30 -start cement test. 21:25 - 21:45 0.33 C PRE tagged TD ~ 8106ft, P/U weight 23,000#, POOH 50 ft, RIH tag same spot. P/U to 8090' continue to circulate well while waiting on cement test. Set up to go through manual choke/ bypass MI choke. Establish 1:1 returns with 9.05# 80 degree fluid. Current WHP 30 psi, circ. 2110psi, pump rate 1.52 bpm /out 1.51 bpm. 21:45 - 22:00 0.25 C PRE Cement test complete. Switch from mud pump to Cement pump pumping 2 bbl fresh water spacer. P-test to 4000psi. 22:00 - 23:40 1.67 C PRE 22:00 -start pumping cement, total pumped 10.5 of 15.9#. 22:08 -water spacer - 3 bbl 22:11 - 40 bbl Bio pill 22:31- cement ~ nozzle, CT @ 8060 ft. Pump 1 bbl start to POOH ~ 50fpm ~ .5bpm, WHP - 50 psi with 1:l returns. WHP slowly dropped to zero after 5 bbl away, rate of returns slightly under 1:1. 22:50 - 10.5 bbls of cement away, CT depth ~ 7000', pump 3 bbl water spacer, POOH to 6800'. Squeeze cement away increments 200psi, 300, 500, 700, 900 - 950 psi. Total of 45 minutes of squeeze time. Pressure increased as more cement went behind pipe. total 3.6 bbls behind pipe before max. pressure reached. 23:30 - 00:00 0.50 C PRE Begin flushing Cement while RIH pumping Bio ~ 2bpm. Monitor choke, WHP 200 psi, 1;1 returns. Washed Packer top C«~ 8106' numerous times at a high rate. Flushed Bio/Cement to surface, POOH slowy & increase WHP once heavier fluids flushed from well - CT 7800' POOH speed 40 fpm, 1:1 returns. 4/5/2008 00:00 - 03:00 3.00 C PRE POOH slowly with CT washing GLM. CT Speed 50 - 70 fpm, pumping 1.5 bpm, increasing WHP in 100 psi increments every 800 - 1000 ft to surface. Kept 1:1 while POOH. Stopped CT ~ 450 ft, WHP 900psi, closed choke and shut down pumps. No leak off observed held solid ~ 910 psi for 15 min. POOH to surface. 03:00 - 08:30 5.50 C PRE Holding 900 psi on WH while circulating CT string ~ surface. Cannot remove BHA/injector due to holding constant pressure for cement compressive test time. Waiting on Lab to call back, SLB Sup. est. 15 hrs (1500 hrs) Bled OA from 30 psi to zero-gas/fluid Printed: 6/10/2008 4:15:59 PM BP EXPLORATION Page 5 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours ; Task Code NPT Phase Description of Operations 4/5/2008 08:30 - 08:40 0.17 C PRE Safety mtg re: resume operations 08:40 - 09:30 0.83 C PRE Fin POH. Bleed off whp, SD pump. Set injector on legs LD 10 jts CSH. Close top SV 09:30 - 12:30 3.00 C PRE Cut off -26' a-line and seal. Install swizzle stick. Function test rams. Jet stack of cement. Remove swizzle stick PJSM. Reverse slack back. RU cutter and cut off 330' of CT and find wire 12:30 - 15:00 2.50 C PRE Dress CT stub, meg a-line, install Kendall CTC. PT 35k. Head up BHI. PT 4500 Pump slack forward 1.68/1890 to bung hole 15:00 - 15:15 0.25 C PRE Safety mtg re: MU BHA 15:15 - 16:00 0.75 C PRE MU milling BHA Cement compressive strength at 1500 hrs=100 psi, 1600 hrs=500 psi 16:00 - 17:20 1.33 C PRE RIH w/ BHA #5 (2.80" D331) circ 0.48/326 17:20 - 18:00 0.67 C PRE Log GR tie-in down from 7525' 0.3/140 at 300'/hr. Corr -6' to GR at 7548' PDC 18:00 - 18:30 0.50 C PRE Precautionary ream in hole 5'/min from 7950' 1.55/2580 looking for cement 18:30 - 19:05 0.58 C PRE Easy going till hard tag at 8100' corected depth. Back ream to 7994' Ream down again to ~ 1.48 bbl/min and CP = 24020 psi ROP of 18.5 FPM Slow to 11 FPM at 8090' MD. Pumps Off, Tag again at 8100.35' MD Flag Pipe 8100' Pick up to 8080' ream back down to 8100' MD. ROP of .5 fpm till tag at 8100' 19:05 - 20:00 0.92 C PRE POH at 1.8 tills/min CP =initial 3340 psi/ 2500 psi 20:00 - 22:00 2.00 C PRE Lay down milling BHA. P/U clean out BHA with a 1.75" stinger & nozzle. Total lenght of BHA 44.73 ft. 22:00 - 00:00 2.00 C PRE RIH Stop at flag (8100') slightly increase pumps to 1.8 bpm, RIH, slight weight loss C~ 8102', continue to RIH to 8110 ft. Circ pressure increased 300psi, good indication we may be inside KB packer cleaning out the float sub. POOH and stab back in again. Switch to BIO at surface and clean out/spot BIO pill (15bb1). 4/6/2008 00:00 - 00:45 0.75 C PRE POOH 00:45 - 00:55 0.17 C PRE PJSM on LD of clean out stinger BHA 00:55 - 01:30 0.58 C PRE At surface, Unstab injector, and LD Clean out BHA. 01:30 - 02:45 1.25 STWHIP C WEXIT MU and handel Whip Stock setting BHA 02:45 - 02:55 0.17 STWHIP C WEXIT PJSM on PU of Whipstock BHA and Injector handling. Installed 2 PIP TAGS (37 kbq per pip). SO# 11974851. 02:55 - 03:15 0.33 STWHIP C WEXIT PU Whipstock BHA total lenght (72.94 ft). Test comms, P/U and stab on injector. 03:15 - 05:30 2.25 STWHIP C WEXIT Tagged tight spot in corkscrew tubing @ 6503'. P/U weight looked good. Orient tool from 45 right to 160 right. Start pumping 1 bpm through EDC, RIH no problems second time. Continue RIH slowly to 7555' for Tie-in depth. 05:30 - 06:00 0.50 STWHIP C WEXIT Tie in depth correction -6 ft. 06:00 - 06:30 0.50 STWHIP C WEXIT RIH to set depth of 8094' (TOWS at 8085') while orient to 20R 06:30 - 07:30 1.00 STWHIP C WEXIT Pressure up to 3640 psi where tool stroked. Stack 5k to Printed: 6/10/2008 4:15:59 PM a c ~ r BP EXPLORATION Page 6 of 35 Operations Summary Report Legal Well Name: 1 R-01 Date I~ From - To Hours Task ~I Code NPT Phase 4/6/2008 06:30 - 07:30 1.00 STWHIP C WEXIT Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: 07:30 - 09:00 1.501 STWHIP~X ~ ~ WEXIT 09:00 - 10:15 1.251 STWHIP~X ~ ~ WEXIT 10:15 - 10:45 0.501 STWHIP~ X ~ ~ WEXIT 10:45 - 12:30 1.75 STWHIP X WEXIT 12:30 - 13:20 0.83 FISH X WEXIT 13:20 - 14:45 1.42 FISH X WEXIT 14:45 - 15:55 1.17 FISH X WEXIT 15:55 - 17:25 1.50 FISH X WEXIT 17:25 - 18:10 0.75 FISH X WEXIT 18:10 - 20:15 2.08 FISH X WEXIT 20:15 - 22:00 ~ 1.75 ~ FISH ~ X ~ ~ W EXIT 22:00 - 23:20 1.33 FISH X WEXIT 23:20 - 00:00 0.67 FISH X WEXIT 4/7/2008 00:00 - 00:15 0.25 FISH X WEXIT 00:15 - 00:20 0.08 FISH X WEXIT 00:20 - 01:30 1.17 FISH X WEXIT 01:30 - 03:00 ~ 1.50 ~ FISH ~ X ~ ~ W EXIT 03:00 - 03:40 0.671 FISH ~ X ~ ~ W EXIT 03:40 - 03:50 ~ 0.17 ~ FISH ~ X ~ ~ WEXIT Description of Operations 8095.9' and looks good. PUH w/ 10k over and were still attached to WS. Confer w/ BTT. Cycle between 10k over and 5k down in attempt to fatigue w/o success. Work w/ orientor and pumps and had no success releasing. Max pull was 13k over Discuss and decide to go conservative and disconnect at the EDC rather than attempt a straight pull release SD pump, go to neutral wt w/ 11 k at 8093'. Send command to disconnect. PUH 23k, clean. Lower half of EDC is at 8039' POOH circ 1.38/1450 Bleed off OA from 30 psi-fluid LD BHI tools thru the top part of the EDC. Set injector over bung hole. SI SV Nordic 1 electrician replace brushes on SWS power pack traction motor while BTT hand gets rest PJSM. MU fishing BHA (Hipp-Tripper w/ GS) Test Hipp-Tripper, then RIH w/ BHA #8 w/o circ Wt chk 25.3k Tag at 8046'. PUH 31 k and were latched. Start Hipp-Tripper w/ 0.76/1620 and slack off slow while beating down until stalled three times. Not too effective. Pull 5k over and start Hipp-Tripper 0.86/1820. Slack off and repeat holding 5k at 1.25/2940. Straight pull to 40k before giving up. Release GS POOH filling from BS Change out the Hipp-Tripper tool for jars RIH w/ BHA #9 circ 0.4/220. P/U weight 22,000# break over 26,000# ~ 8000'. Tagged fish ~ 8047' latched, start jarring. Neutral weight 11,000# ~ 8047' Nuetral weight 11,000# C~ 8047' P/U weight 36,000# @ 8037.56ft X 6 times Down weight to "0" 8050' P/U weight 42,000# @ 8036.23 X 8 times P/U weight 45,000# ~ 8035.80ft X 11 Jars stopped firing, P/U to 50,000# no luck. Set down to release from fish. Release from fish POOH Unstab CT Injector, Pull testeed UOC and Coill connector to 40K#, LD fishing BHA #9 Continue to LD BHA PJSM for MU and PU of BHA # 10 MU and PU Fishing BHA # 10, with 7 JNTs 2 3/8" Drill Collars. Total BHA length 219.7' Stab in Injector. RIH Impact guidance tool will begin recording at 02:30 02:30 Depth is 5529' Stop above fish and circulate in Low torque. Obtain parameters: Up Wt = 24K Dwn WT = 11.5K Latch in to GS profile at 8047, Straight pull to 38K to verify Jar 5 times up and freed up with a 45 K pull at 8036.8' 27k UP WT. Printed: 6/10/2008 4:15:59 PM ~ '~ BP EXPLORATION Page 7 of 35 ~ Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Nours Task i Code NPT 4/7/2008 03:50 - 05:20 1.50 FISH X 05:20 - 05:35 0.251 FISH X 05:35 - 06:00 I 0.421 FISH X 06:00 - 07:00 I 1.001 FISH I X 07:00 - 07:50 I 0.831 FISH I X 07:50 - 08:30 I 0.671 STWHIPX 08:30 - 08:45 I 0.251 STWHIPIX 08:45 - 12:45 ~ 4.001 STWHIP~X 12:45 - 12:55 0.17 STWHIP X 12:55 - 13:35 0.67 STWHIP X 13:35 - 14:20 0.75 STWHIP X 14:20 - 15:40 1.33 STWHIP P 15:40 - 16:15 0.58 STWHIP P 16:15 - 17:30 I 1.251 STWHIPI P 17:30 - 18:00 I 0.501 STWHIPI P 18:00 - 00:00 I 6.001 STWHIPI P Spud Date: 4/1 /2008 Start: 3/24/2008 End: 5/2/2008 Rig Release: 5/2/2008 Rig Number: Phase Description of Operations WEXIT POOH While coming out getting ocasional weight spikes through tubing joints. WEXIT PJSM on unstabing injector and LD of BHA and Fish, while POOH. Checking plumbing/tanks for possible fluid loss. WEXIT Finish POOH, 60 bbls lost while POOH. Close choke at surface and check for feed rate. ~ 60 psi and .6 bbl min the well is taking fluid. Monitor for 15 min and check for suction on well. Strong Vac on well, suspecting damage to Tubing when whipstock set? Total bbls pumped down hole 110bb1s prior to shutting in. WEXIT Crew change out and discuss well situatuion prior to removing BHA. Continue circ over the top and losing 1.25 bpm w/ 50 psi charge pump pressure WEXIT Set injector on legs. LD 7 DC's, LD BHI MWD assy. LD WS setting tool w/ rod. The 'tang' had been bent back in the upward position and appears a -1"piece was torn off and left in the hole-see pics FIII hole, SI swab WEXIT Discuss. Will assume WS is still where it was set at 8085' ELMD and proceed with milling operations using 8.7# mud if injection test has no effect WEXIT Open swab and bullhead 30 bbls 9.1#KCI at up to 4.2 bpm/500 psi in an attempt to reseat the float in the KB packer in case that it is the fluid loss point-had no increase in returns WEXIT SI SV. Wait on more fluids. Will need to cut the used 9.4# FloPro mud back to 8.7# and add FloVis/KG. So, vac truck reloaded the reconditioned 9.4# mud from the uprights (that had just been filled) and dropped off 50 bbls at rig and went back to MI Deadhorse w/ the rest. Fill CT w/ 23 bbls KCI. Circ 150 bbls of 9.1 #KCI in pits while water back to <8.9# SWS 3rd party (Hayden Electric) did quarterly inspection of the power pack traction motor WEXIT Safety mtg re: MU milling BHA WEXIT MU milling BHA. Add 2' lub for pressure undeployment WEXIT BHt damaged pin on lower quick connect when stabbing tools. Change it out WEXIT RIH w/ BHA #11 circ 9.1#KCI thru mill 0.75/400 w/o returns WEXIT 8060' 26.5k, 13.6k 0.75/535 . Red rate to 0.35/100 and tag at 8095' which is 4' deeper than expected. Discuss Swap to 40 bbl biozan pill 1.5/1600 and and start getting minimal returns WEXIT Open EDC. Recip over 8050-8080' bit depth. Swap to <8.9# mud 1.81/2140 w/ 0.4 bpm returns w/ 9.4 ECD w/ biozan at mill. When mud exited the EDC the returns diminished to 0.1 bpm w/ ECD at 9.55 ppg. Returns increased back to 0.45 after 40 bbls mud had exited the mill, but were out of fluid by then. Circ at min rate w/ well SI while wo truck w/mud WEXIT Mud arrived. Close EDC and open choke. Start pump and ease down to WS to begin milling operations 1.52/0.35/2580 at 9.80 ECD See first MW at 8095.0' Park and flag coil at 8095' WEXIT Time Mill at 1/10' every 6 Sec. from 8095' 1.52/0.66/2800 w/ 50 Printed: 6/10/2008 4:15:59 PM z BP EXPLORATION Page 8 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To .Hours Task Code NPT Phase Description of Operations 4/7/2008 18:00 - 00:00 6.00 STWHIP P WEXIT psi MW, 0.1k wob w/ 10.2 ECD (still have 9.1# KCI returns) 4/8/2008 ~ 00:00 - 02:05 ~ 2.08 ~ STW H I P ~ P ~ ~ W EXIT 02:05 - 03:55 I 1.831 STWHIPI P I I WEXIT 03:55 - 04:45 I 0.831 STWHIPI P I I WEXIT 04:45 - 05:00 0.25 STWHIP P WEXIT 05:00 - 07:30 2.50 RIGD P PROD1 07:30 - 09:00 1.50 RIGD P PROD1 09:00 - 11:30 2.50 RIGD P PROD1 11:30 - 13:30 2.00 RIGD P PROD1 13:30 - 16:30 3.00 RIGU P PROD1 16:30 - 16:45 0.25 RIGU P PROD1 16:45 - 19:45 3.00 RIGU P PROD1 19:45 - 20:00 0.25 RIGU P PROD1 20:00 - 20:40 0.67 RIGU P PROD1 20:40 - 21:00 0.33 RIGU P PRODi 21:00 - 21:10 0.17 RIGU P PROD1 21:10 - 22:25 1.25 RIGU P PROD1 22:25 - 23:00 0.58 BOPSU P PROD1 23:00 - 23:20 0.33 RIGU P PROD1 23:20 - 00:00 0.67 RIGU P PRODi At 21:30 and 8098' 1.52/1.11 bbls/min CP = 3025 8.84/8.90 ppg At 22:41 through window at 8099' ~ at 00:00 at 8100'. 1.50/1.19 bbls/min CP = 2900 psi 8.81/8.91 PP9 Fluid loss since 18:00 is 120 bbls Pit Vol ~ 00:30 140 active / 352 on board at 00:00 at 8101.5' 1.51/1.21 bbls/min CP = 2875psi 8.81/8.89 PP9 IA= 100 psi OA=27 psi pv = 131 bbls losses of 17.6 bbls/hr After 8110.5' Slow up and down string reaming of window from ~ 8110.5 to 8080' five times. Dry run was clean. POOH with Geo's verification of formation cuttings.- POOH at 80 fpm 1.49/1.06 bbls/min CP= 2650 psi 8.82/8.89 PP9 At start of trip PV = 304 bbls (tanks 2,3,&5) Lost 16 bbls during trip out of hole. Unstab injector, Blow down BHA, and LD BHA. Fill hole accros top. Function test BOP's. WO N2 Safety mtg and MIRU SWS N2 Blow down CT w/ N2 and bleed off to tiger tank Safety mtg and install internal grapple and pull CT back to reel and secure Remove hardline Load out used E-CT w/ 712k RF and set on CHILL lowboy. Load in new reel of E-CT Welder cut out space in reel to fit valuing for hardline. RU inner hardline. MU drive retaining bolts. MU end plates. MU a-line J-box. Test wire. Good test. MU pressure bulkhead. Fill hole - 5bbls to fill the hole. Fill hole every hour. 2bbls to fill hole PJSM regarding pulling coil across & stabbing pipe. Pull test internal grapple. Pull coil across & stab into injector. Fill hole - 4bbls to fill hole. Test wire -good test. Terminate end of wire. Stab injector onto well. C/O packoffs. PJSM regarding filling coil & pumping slack. Begin reverse filling coil with 8.7ppg Flo-Pro ~ 0.75 bpm. Pressure test injector packoffs & inner reel valve per AOGCC regs -good test. Fill hole - 3bbls to fill hole. Pump slack into reel C~3 3.2bpm/4400psi. Can hear wire moving for - 2 min. PJSM regarding cutting coil. Bleed off coil. Pop off well. Cut coil to find wire. Cut 9ft of coil. Stab back onto well. Attempt to pump slack into coil. Slight movement. Printed: 6/10/2008 4:15:59 PM ~ ~ BP EXPLORATION Page 9 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date I From - To I Hours I Task I Code I NPT 1 Phase 4/9/2008 100:00 - 01:30 I 1.501 RIGU I P I I PROD1 01:30 - 01:50 0.33 RIGU P PROD1 01:50 - 02:00 0.17 RIGU P PROD1 02:00 - 03:00 1.00 RIGU P PROD1 03:00 - 03:20 0.33 RIGU P PROD1 03:20 - 03:30 0.17 DRILL P PROD1 03:30 - 04:25 0.92 DRILL P PROD1 04:25 - 06:00 1.58 DRILL P PROD1 06:00 - 06:20 0.33 DRILL P PRODi 06:20 - 08:25 2.08 DRILL N PROD1 08:25 - 09:40 1.25 DRILL N PROD1 09:40 - 09:55 0.25 DRILL N PROD1 09:55 - 10:15 0.33 DRILL P PROD1 10:15 - 12:10 1.92 DRILL P PROD1 12:10 - 14:10 2.00 DRILL P PROD1 14:10 - 16:25 2.251 DRILL P PROD1 16:25 - 16:50 ~ 0.42 ~ DRILL ~ P ~ ~ PROD1 16:50 - 17:00 ~ 0.17 ~ DRILL P ~ ~ PROD1 Description of Operations Pop off well & wire is still at end of coil. Fill coil with rig water. Same rate /pressures as before. Pump slack 3.3bpm/4500psi. No movement of wire. Pop off well, wire still at the end of the coil. SLB reel paperwork says 55ft of a-line slack in the reel = 0.3% slack. Unknown reel volume. Unknown % of slack. Test wire -good test. Install CTC. Pull test CTC to 35k -good. Head up BHI UOC. P.T. CTC & BHI's UOC to 4000psi -good. PJSM regarding MU build BHA PU 2.1deg AKO motor & MU to BHI coil track tools. PU injector & MU to BHA. Stab injector onto well. Power up & test tools. Set depths. Open EDC. RIH w/ build BHA. Circ through EDC at 1.22bpm/2290psi in, 1.29bpm out. 0.3bpm losses while RIH. Lost 24 bbls on trip in the hole. Log down for tie-in from 7550ft (-10.5ft). RIH, closed EDC and Tagged at 8,103 ft Working to get through WS area. Tried several things and still tagging hard at 8103 ft. Confirmed BHI offsets Tried different TF Unable to get through whipstock area Open EDC, Cir at 1.51 bpm and out rate is slow coming up. Op = 1.51 / 1.00 bpm RIH and corrected +7 ft at 7548 ft RIH Tagged bottom corrected to GR maker at 7548 ft at 9,101 ft. Drillling turn section with 2.1 AKO setting TF at 90 R of HS Op = 1.52 / 1.23 bpm at an off bottom CTP of 3000 psi Out micro motion is cycling betwen 1.25 bpm and 1.45 bpm Op = 1.44 psi WHP /BHP/ ECD = 40psi / 3737 psi / 11.05 ppg. Drilled to 8111 ft and stalled. PU and had some trouble getting back to bottom? Trying to get back to 8,111 ft, Pulling tight and able to get back to bottom without pumping. Shale unstable. Unable to RIH with Op at 1.5 bpm. RIH and tagged bottom at 8,109 ft. PU 3 ft and started pump. RIH Op = 1.4 / 1.35 bpm and tagged bottom at 8,111 ft Drilling turn section Op =1.41 / 1.14 bpm at 2900 psi. Out micro cycle around 1.2 bpm TF at 90deg RHS DHP/WHP = 3736 psi at 11.00 ppg ECD Drilling turn section in A3 Section Increased WHP to 55 psi and monitor the micro motion Op = 1.50 / 1.30bpm at 3,550 psi CTP on bottom Vp = 327 bbl BHP 3800 psi w/ EDC of 11.25ppg Increase WHP to 90 psi at 8152 ft MD Wiper trip at 8170 ft ,Some motor work at 8131 ft Pulled tight at 8105 ft, SD pump and pummed into tubing. Open EDC and cir and holding 200 psi on wellhead PUH to tie-in Tieing in at 7550 ft going down Op = 1..43 / 1..20 bpm at 2.00 Printed: 6/10/2008 4:15:59 PM e BP EXPLORATION Page 10 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase - - _ - 4/9/2008 16:50 - 17:00 0.17 DRILL P PROD1 17:00 - 18:04 ~ 1.07 ~ DRILL ~ N ~ DPRB ~ PROD1 18:04 - 18:50 0.77 DRILL N DPRB PROD1 18:50 - 18:55 0.08 DRILL N DPRB PROD1 18:55 - 19:20 0.42 DRILL N DPRB PROD1 19:20 - 19:35 0.25 DRILL N DPRB PROD1 19:35 - 20:00 ~ 0.42 ~ DRILL ~ N ~ DPRB ~ PRODi 20:00 - 21:00 I 1.001 DRILL I N I DPRB I PROD1 21:00 - 22:40 1.67 DRILL N DPRB PROD1 22:40 - 23:10 0.50 DRILL N DPRB PROD1 23:10 - 00:00 0.83 DRILL N DPRB PROD1 4/10/2008 100:00 - 01:50 1.83 ~ FISH N DPRB PROD1 01:50 - 02:00 0.17 FISH N DPRB PROD1 02:00 - 03:00 1.00 FISH N DPRB PROD1 03:00 - 05:25 2.421 FISH N DPRB PROD1 05:25 - 07:00 1.581 FISH N DPRB PROD1 Description of Operations fpm RIH. WHP = 200 psi and BHP = 3700 psi at 11.6 ppg ECD Tied in and corrected +5 ft. RIH and close EDC at 8050 ft Logged RA TOWS =TOW = 8086.65 ft RA Marker = 8092 ft BOW at 8091.95 ft Logged down without pump and located RA and while bringing the pump up became stuck at 8,120 ft. Tried several things and finally after putting 900 psi on annular, the BHA became free. Pulled up hole above the WS at 8,086 ft Cir, checked tool out (OK) open EDC and PUH to confirm tie-in. Tied in at 7548 ft Corrected +2.5 ft. RIH without pump and tagged at 8115 ft, PU and drag up to 35k. Attempt 3 more times. Keep tagging at 8115' & 8110'. Pull up to 7550' & tie-in (+2.5ft corr. RIH. With pumps off, RIH past window & tag at 8110'. Attempt 3 times. Start pumping ~ 0.25bpm, set down at 8114'- very sticky. PU & pump at 1.5bpm, set down ~ 8114' -lots of overpulls & had to dump coil pressure to help pull free. Pull into casing. Open EDC & jet max rate to clean up the tubing. PU to 7550ft. Log down for tie-in (+1 ft). RIH & log down CCL from 7800ft to 8105ft to capture collars for setting another whipstock. Open EDC & POH pumping 2 bpm to clean up the tubing. Wierd weight bobble at 6260ft (PBR area). Tag up & flow check well. PJSM regarding LD BHA. Pop off well. Blow down & purge BHA. Pull BHA out of hole. Double dart valve assembly + motor + bit backed off from the bottom of the HOT. No scarring on HOT 1-1/2 MT threads & no scarring on the shoulder of the 1-1/2 MT pin either. Assume fish is in tubing as no scarring occurred while attempting to RIH. Fish is 2-3/8" O.D. x 1" I.D. (internal bore on dart check valve) with 1-1 /2" box looking up, AOL = 10.79ft. C/O injector packoffs. Reconfigure coil track tools for fishing ops. Call BOT for fishing hand. Fill hole every hour. Wait for BOT fisherman. Continue to fill hole every hr, only taking 1/2 bbl per hr. PJSM regarding MU fishing BHA. MU fishing BHA. Stab coil onto BHA. Bad stab, unstab & change out o-rings on LOC. Stab coil. Power up & test tools. Set depths. RIH w/fishing BHA. RIH to 6000ft, break circulation. 0.4bpm/1326psi, 0.31 bpm out. RIH while circulating at 0.4bpm to 6200ft. Reduce RIH speed at 6200ft to 15ft/min. Increase speed to 50Wmin below 6300ft (past jewelry). RIH to 7700ft (45 degrees). Acts like we are pushing something through the corkscrewed tubing area. Tag up at 8117ft (uncorrected). Stack weight & let circ pressure build. Pressure built to 2000 psi. PU to 40k, let jars go off. PU to 60k, no movement. Repeat. Pressure up backside to 1000psi. Popped free & pulling ratty, 40k-30k. Pump down coil @ min rate, 0.25bpm/1100psi. POH. Increase rate to 1 bpm/2000psi. OOH and recover all of Printed: 6/10/2008 4:15:59 PM Y BP EXPLORATION Page 11 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date I From - To Hours Task 'Code' NPT ', Phase 4/10/2008 05:25 - 07:00 1.58 FISH N DPRB PROD1 07:00 - 09:00 2.00 FISH N DPRB PROD1 09:00 - 11:30 2.50 C WEXIT 11:30 - 14:30 3.00 C WEXIT 14:30 - 16:50 I 2.331 I C I I W EXIT 16:50 - 17:45 0.92 C ~ W EXIT 17:45 - 17:50 0.08 C WEXIT 17:50 - 19:35 1.75 C WEXIT 19:35 - 20:35 1.00 C WEXIT 20:35 - 20:55 0.331 C W EXIT 20:55 - 22:20 I 1.42 I I C I I W EXIT 22:20 - 22:40 0.33 C WEXIT 22:40 - 23:15 0.58 C WEXIT 23:15 - 23:25 0.17 C WEXIT 23:25 - 00:00 0.58 C WEXIT 14/11/2008 ~ 00:00 - 00:15 ~ 0.25 ~ C ~ ~ WEXIT 00:15 - 00:35 0.33 C WEXIT 00:35 - 01:00 0.42 C WEXIT Description of Operations the fish. LD same. OOGH, recovered all of the fish, LD same Inspected the CTC and decided to install new CTC and UOC. Waiting on FVS subs from Tuboscope and calibrating Little Jerks. Called town and worked on a plan forward. Plan is to set WS at 140R at 8057 ft 9sgz perfs) installed night cap and filling hole periodically Installed CTC and BHI reheaded UOC. Pull tested to 40k, Load pipe shed with WS #1 and milling equipment from BOT Setup Coiltrak w/ DGS sub and BOT TTWS Scribed tray to HS Installed 3 Pip tags. Confirmed scribed MU tool, check tool (OK) Set counters and RIH. Re-booted BHI computer at 900 ft. RIH to 7,550 ft for tie-in No problem at 6,500 ft RIH with WS. Tie-in at 7548 ft and corrected (-13 ft) RIH to 7900 ft and logged CCL down to confirm 3-1/2" collars for WS setting Correct 2 ft to CCL. RIH to 8063.5 ft with EDC closed Pressured up on CT and set TOWS at 8,055 ft ELMD At 3,956 psi, set WS. PUH, released from whipstock POOH. PJSM while POH regarding handling BHA. Flow check well. Pop off & place injector over bung hole. Blow down & purge BHA w/ water & air. LD BHI tools on catwalk & reconfigure for milling ops. Whipstock is missing! LD BOT setting tool on catwalk. Fill hole - no losses. "'NOTE'*' small metal debris in LOC of coil track tools. PU 2.74" DSM, 2.74" string reamer, BOT straight motor & place in the hole. PU BHI coil track tools & MU to motor. PU injector & stab onto tools. Stab onto well. Power up & test tools. Set depths. RIH with mill BHA. Clean ditch magnets. Review whipstock milling procedure. Oh, there isn't a procedure for milling through perfs. Log down for tie-in from 7530ft (-10ft corr. RIH. Increase pump rate to 1.6bpm/3300psi. RIH to 8050ft & slow RIH speed to 0.3ft/min & look for a tag. Tag up & showing 0.5k WOB at 8055ft. Let mill off. Time Mill at 0.1 ft every 6 min from 8055ft Op = 1.61 bpm at CTP of 3,245 psi, 1.4bpm out Density = 8.80/ 8.85 ppg 0.6k WOB BHP /WHP 3725 psi / 40 psi ECD 11.05 ppg Vp = 386 bbls Getting lots of metal in the samples. Continue to Time Mill at 0.1ft every 6 min Op = 1.61 bpm at CTP of 3,245 psi, 1.4bpm out Density = 8.80/ 8.85 ppg 1.Ok - 1.4k WOB ,BHP /WHP 3725 psi / 40 psi ECD 11.05 ppg Vp = 380 bbls Mill to 8056ft Let mill off from 1.4k WOB to 0.5k WOB. Time Mill at 0.1ft every 6 min from 8056ft Nnntea: wtuizuuts a:t5:5arm ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 I Start: 3/24/2008 Rig Release: 5/2/2008 Rig Number: Date I From - To Hours I Task Code' NPT ' Phase 4/11/2008 00:35 - 01:00 0.42 C WEXIT 01:00 - 01:25 0.42 C WEXIT 01:25 - 02:45 1.33 C WEXIT 02:45 - 02:50 0.08 C ~ ~ W EXIT 02:50 - 03:35 ~ 0.75 ~ ~ C ~ ~ W EXIT 03:35 - 03:40 0.08 C WEXIT 03:40 - 06:00 2.33 C WEXIT 06:00 - 06:05 0.081 C W EXIT 06:05 - 08:40 I 2.581 I C I I W EXIT 08:40 - 11:00 I 2.331 I C I I W EXIT 11:00 - 11:20 0.33 C WEXIT 11:20 - 12:40 1.33 C WEXIT 12:40 - 14:30 1.83 ~ C ~ ~ W EXIT Page 12 of 35 ~ Spud Date: 4/1 /2008 End: 5/2/2008 Description of Operations Op = 1.61 bpm at CTP of 3,245 psi (300psi motor work), 1.48bpm out Density = 8.80/ 8.85 ppg 0.6k WOB BHP /WHP 3725 psi / 40 psi ECD 11.05 ppg Vp = 372 bbls Milled to 8056.6ft & starting to stack weight. Let mill off from 1.9k WOB very slowly to 1.2k. Time Mill at O.ift every 10 min from 8056.6ft Op = 1.61 bpm at CTP of 3,245 psi (300psi motor work), 1.50bpm out Density = 8.81/ 8.85 ppg 1.9k WOB BHP /WHP 3759 psi / 40 psi ECD 11.05 ppg Vp = 368 bbls At 8057.5ft the WOB dropped off while milling from 1.9k WOB to 1k WOB. Time Mill at 0.1ft every 10 min from 8057.5ft Op = 1.61 bpm at CTP of 3,245 psi (150psi-200psi motor work), 1.50bpm out Density = 8.81 / 8.85 ppg 0.7k-i.ik WOB BHP /WHP 3745 psi / 40 psi ECD 11.09 ppg Vp = 356 bbls WOB increased from 0.7k to 1.5k at 8058.2ft At 8058.2ft the WOB jumped from 0.7k to 1.5k Time Mill at 0.1ft every 10 min from 8058.2ft Op = 1.61 bpm at CTP of 3,245 psi (200psi motor work), 1.50bpm out Density = 8.81/ 8.85 ppg 0.8k-1.Ok WOB BHP /WHP 3745 psi / 40 psi ECD 11.09 ppg Vp = 350 bbls Starting to get cement in the samples. While milling at 8,059.5ft the WOB went from 1 k to 2k and then fell to 0. Started drilling rathole at 8,061.9 ft and drilled to 8,067 ft TOW S =TOW = 8,055 ft BOW ~ 8,059.6 ft Rathole TD f~ 8,067 ft Reaming window area Op = 1.5 / 1.40 bpm Formation at 60% silty shale to siltstone and 40% ss Dry tagged and seen stacking below the window. Washed / reamed back down and was clean to 8067 ft, clean pick up. Retag again (WHP 600 psi) Still at the same spot 8066 ft Bleed down OA from 33 psi PUH to 7,540 ft and relog tie-in to confirm No correction POOH following MPD schedule Held PJSM and discussed all of the HZARDS associated with Pressure Undeploy of BHA Tagged up, slacked off 1.2 ft Pressure undeployed BHA with 800 psi on WH being supplied by MPD loop. Changed slack off to 1.1 ft instead of 1.2 ft Printed: x/10/21708 4:15:55 F'M BP EXPLORATION Page 13 of 35 ~ Operations Summary Report Legal Well Name: 1 R-01 Common W Event Nam Contractor Rig Name: Date ell Name: 1 e: Name: N N Fram - To R-01 REENTE ORDIC ORDIC Hours R+COM CALIST 2 Task ~ PLET A Code I E NPT " Start Rig Rig N Phase Spud Dater 4/1/2008 : 3/24/2008 End: 5/2/2008 Release: 5/2/2008 umber: Description of Operations 4/11/2008 14:30 - 16:30 2.00 C WEXIT Break out motor and LD MDD RU MWD for build /turn section Mill at 2.72" No/Go and 2.73" Go Mill looked good 16:30 - 18:30 2.00 DRILL C PROD1 Pressure deploying 2.1 deg BHA BHA with 800 psi on well Op into the well 0.57 / 0.44 bpm and holding 800 psi Lost 33 bbl during BHA change Open EDC 18:30 - 19:50 1.33 DRILL C PROD1 RIH w/ build section BHA following pressure schedule. 19:50 - 20:05 0.25 DRILL C PROD1 Log down for tie-in from 7548ft (-11ft corr. 20:05 - 20:25 0.33 DRILL C PROD1 Continue to RIH following pressure schedule. RIH to 8025ft & trap 850 psi WHP & close EDC. RIH through the window. Tag up at 8066.5ft. PU to get coil WT back. Start pumping 1.6bpm & slowly reduce WHP to maintain 3900psi BHP. 20:25 - 00:00 3.58 DRILL C PROD1 Drill build section in 'B' shale Zone w/ 140-120 R HS from 8067ft. Maintain 30fUhr ROP for the first 10ft to establish a pattern. Op = 1.60 bpm at CTP of 3,450 psi (200psi motor work), 1.50bpm out Density = 8.80/ 8.86 ppg 1.1k-2.7k WOB BHP /WHP 3950 psi / 200 psi ECD 11.72 ppg Vp = 248 bbls Losses are 0.1 bpm Stalled at 8071ft, 26k PU wt. Pump sweep of new mud at 8100ft. 4/12/2008 00:00 - 01:25 1.42 DRILL P PROD1 Continue to drill build section in 'B' shale Zone w/ 110-80 R HS from 8155ft. Op = 1.60 bpm at CTP of 3,450 psi (200psi motor work), 1.50bpm out Density = 8.80/ 8.86 ppg 1.5k-2.9k WOB, ROP 30-70ft/hr BHP /WHP 3990 psi / 150 psi ECD 11.76 ppg Vp = 239 bbls Drill to 8200ft. 01:25 - 01:40 0.25 DRILL P PROD1 Wiper to window & to TD -clean both ways. 01:40 - 06:00 4.33 DRILL P PROD1 Drill build section in 'A' Zone? w/ 110-80 R HS from 8200ft. Op = 1.60 bpm at CTP of 3,450 psi (200psi motor work), 1.50bpm out Density = 8.80/ 8.86 ppg 2.5k-4.6k WOB, ROP slow 3-5Whr BHP /WHP 3990 psi / 150 psi ECD 11.76 ppg Vp = 235 bbls Pump 30bb1 new mud sweep. Finally drill past hard zone (base of 'B' ?) ~ 8210ft - 2 hrs to drill through 5ft. Samples contain pyrite. Slowed down to 3ft/hr at 8230ft (base of 'A6'?). Slowed down to 3ft/hr at 8240ft (base of 'A5'?). 06:00 - 08:50 2.83 DRILL P PROD1 Drilling turn section from 8280 ft to 8352 ft Op=1.61 /1.53 bpm String Wt PU at 25k Off bottom P = 3,620 psi at 1.60 pbm BHP = 4,024 psi at 11..8 ppg. WHP = 150 psi Bleed OA down from 33 psi to 0 psi Need to drop 9 ft TVD 93.5 deg ~ 6,598 ft TVDss 08:50 - 10:20 1.50 DRILL P PROD1 Wiper trip Printed: tinoizuuts a:u:ae Pnn BP EXPLORATION Page 14 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ', Hours Task Code NPT Phase i Description of Operations 4/12/2008 08:50 - 10:20 1.50 DRILL P PROD1 10:20 - 10:40 0.33 DRILL P PROD1 10:40 - 12:30 1.83 DRILL P PROD1 12:30 - 14:00 1.50 DRILL P PROD1 14:00 - 14:20 0.33 DRILL P PRODi 14:20 - 16:30 2.17 DRILL P PROD1 16:30 - 18:20 1.83 DRILL P PRODi 18:20 - 18:50 0.50 DRILL P PROD1 18:50 - 21:00 2.17 DRILL P PROD1 21:00 - 22:35 1.58 DRILL P PROD1 Pulled tight at 8,190 ft, reduced Op to 0.27bpm . Pulled above WS and open EDC and circulated at 2.00 bpm WHP = 100 psi BHP at 4,050 psi Tied in and corrected +2 ft Rebooted computers and RIH to 8025 ft Stopped at 8040 ft and closed EDC orient TF to 140 R and RIH to 8075 ft Logged RA marker TOWS =TOW = 8053 ft RA Marker at 8058.5 ft BOW at 8058.5 ft Increased Op to 1.60 bpm and RIH MPD schedule Little bobble at 8125 ft with correct TF Set downb at 8,165 ft reduced Op to 1.25 bpm and inc WHP to 250 psi Reduced Op to 0.25 bpm and holding 800 psi on wellhead Able to RIH through the shales with high WPH, Op <0.4 bpm and correct TF Drilling from 8352 ft Started Mud swap at 8,359 ft Op = 1.60 / 1.55 bpm Getting better ratio Off bottom Pp is 3800 psi off bottom at 1.62 ps WHP/BHP/ECD = 4044 psi / 1000 psi / 11.83 ppg Looks like a Fault at 8430 ft wit Stalls and some fluid Ioss.Drill lateral and determine the formation on the other side of the fault. Drilling turn section Op = 1.60 / 1.55 bpm Getting better ratio Off bottom Pp is 3800 psi off bottom at 1.62 ps WHP/BHP/ECD = 4044 psi / 1000 psi / 11.83 ppg Climb up to 93 deg (6495 ft TVDss) and get back into the sand following the fault at 8430 ft Wiper trip 8500 ft 8260 ft Good wiper Drilling turn. Estimated TD for turn section 8600 ft Op = 1.61 / 1.53 bpm Pp off bottom 3800 psi BHP/WHP = 3992psi / 100 psi /ECD 11.66 ppg Density = 8.87 / 8.90 ppg Vp = 339 bbl's ROP = 35-40 fph. GR API Units cycles between 85 to 100 API Units POOH after landing 6585 ft TVDss (8,600 ft MD) Reduced Op to 1.35 bpm and inc WHP to 125 psi Pulled a little ratty(some overpull and motor work) at 8,160 ft - 8,150 ft. Pulled above WS and open EDC and circulated at 1.7 bpm POOH Swaco choked plugged up while POOH, switch to hand choke. Cleared out choke and switched back while still maintaining WHP Tag up. C/O w/day crew. PJSM regarding pressure undeploying BHA. Begin pressure undeploying BHA. OOH w/ build BHA. LD coil track tools on catwalk, purge w/air & water. Reconfigure tools for resistivity & test same, C/O LOC o-rings. Dial down motor to 1.0 AKO. Remove HYC bit (1 rnntea: tNiuizuua n:~o:aarm ~ ~ BP EXPLORATION Page 15 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To !Hours Task Code NPT Phase Description of Operations 4/12/2008 21:00 - 22:35 1.58 DRILL P PROD1 chipped nose tooth, balled & had 5 large pieces of metal). Install Smith bit. C/O shaker screen. Inspect blocks per derrick inspection. C/O chicksan on MPD loop & pressure test same. PJSM regarding pressure deploying BHA. 22:35 - 00:00 1.42 DRILL P PROD1 Begin pressure deploying BHA. 4/13/2008 00:00 - 01:30 1.50 DRILL P PROD1 Continue to pressure deploy lateral BHA. Test tools. Set counters. 01:30 - 02:55 1.42 DRILL P PROD1 Open EDC &RIH w/ lateral BHA following pressure schedule. 02:55 - 03:10 0.25 DRILL P PROD1 Log down for tie-in at 7560ft (-12ft corr. 03:10 - 03:20 0.17 DRILL P PROD1 Continue to RIH following pressure schedule. Stop at 8000ft & close EDC. RIH past window -clean. Start pumping 0.5bpm/2160psi at 8060ft. 03:20 - 03:40 0.33 DRILL P PROD1 Wiper to TD. Weight bobble at 8225ft. Set down at 8384ft, PU & reduce rate to 1 bpm to get past. Weight booble at 8450ft. Very ratty all the way. 03:40 - 05:50 2.17 DRILL P PROD1 Drill lateral Zone in 'A4' w/ 110-80 R HS from 8600ft. Op = 1.50 bpm at CTP of 3,750 psi (200psi motor work), 1.50bpm out Density = 8.88/ 8.84 ppg 1.5k-2.6k WOB, ROP 60-90fUhr BHP /WHP 4400 psi / 100 psi ECD 11.80 ppg Vp = 277 bbls Drill to 8750ft. 05:50 - 05:55 0.08 DRILL P PROD1 Wiper to 8,645ft -clean. 05:55 - 07:35 1.67 DRILL P PROD1 Log Mad pass up ~ 5Wmin (2 samples per foot) from 8,645ft to 8,260ft. Pulled tight between 8150 ft and 8200 ft while logging up at reduced Op and 500 on WH. Logged up from 8112 ft too locate the RA Marker on the up past to confirm if there is a tie-in point below the nasty shales at 8,150 fto 8,200 ft Found RA at 8056.5 ft 07:35 - 08:00 0.42 DRILL P PROD1 RIH at corrected TF and low Op PUH to log RA Marker down after drilling Logging down to locate the RA Marker Found RA at 8,057.5 ft 08:00 - 08:30 0.50 DRILL P PROD1 RIH with at correct TF and low Op till 8260 ft and then inc the Op to 1.28 bpm an WHP at 150 psi. Clean trip Still seeing the shale at 08:30 - 09:54 1.40 DRILL P PROD1 Tagged bottom at 8750 ft Drilling with 145R TF to start Op = 1.50 / 1.44 bpm at 3525 psi off bottom Density = 8.90 / 8.98 ppg WHP = 150 psi BHP = 4,009 psi at an ECD of 11.75 ppg Vp = 249 bbls ROP = 60-90 fph Found the 2nd faults at 8,838 ft 09:54 - 10:00 0.10 DRILL P PROD1 BHA Wiper Op = 1.50 / 1.38 bpm BHP = 3938 psi 10:00 - 11:05 1.08 DRILL P PROD1 Tagged bottom at 8850 ft Drilling with 145R TF Op = 1.50 / 1.44 bpm at 3525 psi off bottom density = 8.90 / 8.98 ppg WHP = 150 psi BHP = 4,009 psi at an ECD of 11.75 ppg Vp = 247 bbls ROP = 60-90 fph 11:05 - 11:55 0.83 DRILL P PROD1 Wiper trip at 8,900 ft to 8,260 ft Printed: 6/10/2008 4:15:59 PM BP EXPLORATION Page 16 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours it Task Code I! NPT ', Phase Description of Operations 4/13/2008 11:05 - 11:55 0.83 DRILL P PROD1 Trip out clean. RIH at 1.24 bpm and WHP = 200 psi BHP = 3952 psi Geologist was no higher than 6567 ft need to drop 90 deg from 94 deg 11:55 - 14:43 2.80 DRILL P PROD1 Tagged bottom at 8900 ft Drilling in Lower A3 Reservoirs with 145R TF Op = 1.50 / 1.42 bpm at 3500 psi off bottom Density = 8.92 / 8.99 ppg WHP = 150 psi BHP = 3,996 psi at an ECD of 11.71 ppg Vp = 240 bbls ROP = 60-90 fph Need to drop TVDss to 6565 ft at 90 deg 14:43 - 16:10 1.45 DRILL P PROD1 Wiper trip to 8260 ft, Clean, RIH Geologist wants to climb out of A3 Reservoir to 94 deg once back on bottom. 16:10 - 18:40 2.50 DRILL P PROD1 Tagged bottom at 9,050 ft Drilling up and out of lower A3 Reservoirs with HS TF Turned TF down at 9093 ft projected 94 deg at bit Op = 1.49 / 1.41 bpm at 3425 psi off bottom Density = 8.97 / 9.01 ppg WHP = 150 psi BHP = 3,996 psi at an ECD of 11.71 ppg Vp = 222 bbls ROP = 30-50 fph 18:40 - 20:35 1.92 DRILL P PROD1 Wiper to window. Pulled tight at 8175ft-8145ft (TF related) Stop pumping & pull through the window. Open EDC& PU to 7500ft. 20:35 - 20:50 0.25 DRILL P PROD1 Log down for tie-in from 7570ft (+3.5ft corr. 20:50 - 21:40 0.83 DRILL P PROD1 RIH. Close EDC &RIH past window. RIH pumping min rate. Set down at 8200ft. Work past. 21:40 - 21:55 0.25 DRILL P PRODi Drill from 9200ft with 150 RHS TF Op = 1.49 / 1.41 bpm at 3650 psi off bottom Density = 8.97 / 9.01 ppg WHP = 150 psi BHP = 3,996 psi at an ECD of 11.71 ppg Vp = 222 bbls ROP = 30-50 fph PU & call town regarding going outside of polygon & get plan forward. 21:55 - 22:20 0.42 DRILL P PROD1 Slowly PU. 22:20 - 00:00 1.67 DRILL P PROD1 Drill from 9220ft with 150-135 RHS TF Op = 1.50 / 1.45 bpm at 3595 psi off bottom Density = 8.97 / 9.01 ppg WHP = 150 psi BHP = 3,996 psi at an ECD of 11.71 ppg Vp = 222 bbls ROP = 30-50 fph Conduct mud swap. 4/14/2008 00:00 - 00:05 0.08 DRILL P PROD1 Drill from 9274ft with 150-135 RHS TF Op = 1.50 / 1.45 bpm at 3595 psi off bottom Density = 8.97 / 9.01 ppg WHP = 150 psi BHP = 3,996 psi at an ECD of 11.71 ppg Vp = 222 bbls ROP = 30-50 fph Begin mixing 2ppb more KlaGuard 00:05 - 00:10 0.08 DRILL P PROD1 BHA wiper -clean. 00:10 - 01:30 1.33 DRILL P PROD1 Drill from 9274ft with 150-135 RHS TF Printed: 6/10/2008 4:15:59 PM BP EXPLORATION Page 17 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date I From - To Hours i, Task Code NPT Phase Description of Operations - _ _ _ _ ' 4/14/2008 00:10 - 01:30 1.33 - DRILL P PROD1 Qp = 1.50 / 1.45 bpm at 3455 psi off bottom Density = 8.83 / 8.89 ppg WHP = 150 psi BHP = 3,996 psi at an ECD of 11.71 ppg Vp = 326 bbls ROP = 30-50 fph 01:30 - 02:50 1.33 DRILL P PROD1 Wiper to 8300ft -clean. Wiper to TD 02:50 - 03:35 0.75 DRILL P PROD1 Drill from 9330ft with 150-135 RHS TF Op = 1.62 / 1.52 bpm at 3650 psi off bottom Density = 8.83 / 8.89 ppg WHP = 150 psi BHP = 3,996 psi at an ECD of 11.71 ppg Vp = 318 bbls ROP = 30-50 fph Drill to 9390ft 03:35 - 03:50 0.25 DRILL P PRODi 200ft wiper trip -clean both ways. 03:50 - 07:45 3.92 DRILL P PROD1 Drill from 9390ft with 150-135 RHS TF Op = 1.62 / 1.55 bpm at 3650 psi off bottom Density = 8.83 / 8.89 ppg WHP = 200 psi BHP = 3,950 psi at an ECD of 11.61 ppg Vp = 316 bbls ROP = 30-50 fph Drill to 9390ft 07:45 - 09:50 2.08 DRILL P PROD1 Wiper after drilling 150 ft 09:50 - 14:45 4.92 DRILL P PROD1 Drill from 9400 ft with 90-135 LHS TF Op = 1.50 / 1.45 bpm at 3650 psi off bottom Density = 8.83 / 8.89 ppg WHP = 200 psi BHP = 3,950 psi at an ECD of 11.61 ppg Vp = 331 bbls. ROP = 10-45 fph From Town. Drop hole angle to 85 deg and locate A4 sand. Try and drill 100 to 200 ft in the A4 and then drop down to the A3 and TD. At 9,485ft decided to drop to 83 deg and get there quicker. Having stacking problems in shale from 9,535 ft still in shale 14:45 - 15:00 0.25 DRILL P PROD1 Drill from 9581 ft with 90-135 LHS TF Op = 1.65 / 1.62 bpm at 3650 psi off bottom Density = 8.87 / 8.94 ppg WHP = 200 psi BHP = 4,045 psi at an ECD of 11.91 ppg Vp = 288 bbls. ROP = 10-40 fph CT WOB -645001b DHWOB = 1.50k Trouble with BHI's Computer Need to drop 14ft TVDss 15:00 - 17:40 2.67 DRILL N SFAL PROD1 PUH working to to reconfigure BHI's computer or change it out. Tried a couple of computers and there is still a config problem. Bled down OA from 32 psi. PUH and will pull above the WS and confirm that the computer is fail safe. Open EDC at 80400 ft and inc Op = 1.72 bpm and PUH 17:40 - 19:20 1.67 DRILL N PROD1 BHI rebooted computers and logged tie-in at 7,548 ft inside the tubing. Corrected + 7 ft. RIH. Minor weight bobble at 8260ft. 9410ft to 9460ft was ratty had to reduce pumping (0.7bpm) to get past -acts like we are hydraulicing our selves out. 19:20 - 22:40 3.33 DRILL P PROD1 Drill from 9588 ft with 90-135 LHS TF Op = 1.30 / 1.25 bpm at 3000 psi off bottom Density = 8.90 / 8.94 ppg WHP = 200 psi BHP = 4,050 psi at an ECD of 11.74 ppg Printetl: 6/10/2008 4:15:59 PM • BP EXPLORATION Page 18 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Wetl Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~ Code I NPT Phase Description of Operations . CT WOB -30001b DHWOB = 1.50k-2.5k Drill to 9655ft Perform Hazard Hunt - 27 items identified & 13 items fixed. 22:40 - 23:05 0.42 DRILL P PRODi 150ft wiper trip up was ratty pulling up hole. Cannot RIH pumping normal rate (hydraulicing out), have to reduce rate to O.6bpm to RIH. 23:05 - 23:55 0.83 DRILL P PROD1 Drill from 9655 ft with 90-135 LHS TF Op = 1.50 / 1.50 bpm at 3550 psi off bottom Density = 8.90 / 8.94 ppg WHP = 100 psi BHP = 4,050 psi at an ECD of 11.89 ppg Vp = 258 bbls. ROP = 10-40 fph CT WOB -45001b DHWOB = 1.50k-2.Ok 23:55 - 00:00 0.08 DRILL P PROD1 Wiper trip. Consult w/ town geologist. 4/15/2008 00:00 - 00:25 0.42 DRILL P PROD1 Wiper trip to 9500ft. 00:25 - 02:15 1.83 DRILL P PROD1 Trying to find sand.... Drill from 9677 ft with 90-135 LHS TF Op = 1.50 / 1.50 bpm at 3550 psi off bottom Density = 8.90 / 8.94 ppg WHP = 100 psi BHP = 4,050 psi at an ECD of 11.89 ppg Vp = 258 bbls. ROP = 10-40 fph CT WOB -45001b DHWOB = 1.50k-2.Ok Drill to 9730ft. 02:15 - 04:05 1.83 DRILL P PROD1 Wiper trip to 8300ft & to TD. Reduce rate to 0.8bpm while going through 9400ft to TD. 04:05 - 05:35 1.50 DRILL P PROD1 Drill in A4 from 9730ft with HS TF & trying to level out 6584ft TVD Op = 1.50 / 1.50 bpm at 3550 psi off bottom Density = 8.93 / 8.99 ppg WHP = 100 psi BHP = 4,030 psi at an ECD of 11.79 ppg Vp = 239 bbls. ROP = 10-20 fph CT WOB -70001b DHWOB = 1.Ok-1.5k Cannot get back to bottom. Cannot get motor work or WOB. Tried multiple times to get to bottom. 05:35 - 06:50 1.25 DRILL P PROD1 POH following pressure schedule. Pulled very heavy 20-25k over from 9640ft-9410ft. Turn pumps off & or vary rate to pull through this section & able to work free. Pulled normal weights above 9400ft. 06:50 - 08:35 1.75 DRILL P PROD1 Above WS, Open EDC and circulate at 1.8 bpm while POOH for BOP test Swaco choke plugged POOH at 1,700 ft, switch to hand choke and cleaned out Swaco choke 08:35 - 08:55 0.33 DRILL P PROD1 Tagged up and slacked off 1.1 ft. Held PJSM and discussed hazards 08:55 - 11:10 2.25 DRILL P PROD1 Pressure undeploying BHA as per procedure 11:10 - 13:00 1.83 DRILL P PROD1 Changed out CT upper brass in the injector stripping head 13:00 - 17:30 4.50 WHSUR P PROD1 BOP Test as per AOGCC MPD while BOP testing at 900 psi John Crisp wavered witnessing the BOP test Phase I and II in Kuparuk 17:30 - 19:30 2.00 DRILL P PROD1 PU injector and rehead BHI UOC 4/14/2008 19:20 - 22:40 3.33 DRILL P PROD1 Vp = 267 bbls. ROP = 10-40 fph MPD at 900 psi lost 35 bbl while maintaining WHP Nnntea: onuizuua aao:oy rnn • C~ BP EXPLORATION Page 19 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours , Task Code NPT Phase Description of Operations 4/15/2008 19:30 - 20:15 0.75 WHSUR P PROD1 P.T. inner reel valve & injector packoffs. 20:15 - 20:30 0.25 DRILL P PROD1 PJSM regarding pressure deploying BHA. 20:30 - 22:40 2.17 DRILL P PROD1 Pressure deploy BHA. Stab onto well. Set counters. Test agitator -good vibrations. 22:40 - 23:55 1.25 DRILL P PROD1 RIH following pressure schedule. 23:55 - 00:00 0.08 DRILL P PROD1 Log down for tie-in from 7560ft (-5ft corr. 4/16/2008 00:00 - 00:10 0.17 DRILL P PROD1 Continue to log down. 00:10 - 00:20 0.17 DRILL P PROD1 RIH to window. 00:20 - 01:10 0.83 DRILL P PROD1 Wiper to TD following pressure schedule. Pump 0.5bpm/2500psi from 8060ft to 8300ft - 'B' shale section. Set down at 8205ft & popped free. Increase rate to 1.25bpm/3900psi. Set down at 9400ft, turn pumps off & popped free (TF change related). Slight set down at 9500ft but popped free. Stop RIH at 9550ft. 01:10 - 01:30 0.33 DRILL P PROD1 Increase pump rate to 1.3bpm/4000psi. No better, no worse than last night. Still ratty coming up & can't backream to help open the hole. Clear after 9400ft. Pulled 20-25k over through the section & tuning the pumps on/off to help get free. 01:30 - 02:40 1.17 DRILL P PROD1 Wiper to 9450ft pumping 1.3bpm/4100psi. Back ream to 9400ft C~ 3ft/min 1.3bpm/4000psi. Reduce rate to 0.6bpm &RIH to 9500ft. Back ream to 9450ft ~ 3ft/min. RIH to 9550ft. Try to back ream, can't pump & back ream at the same time - to packed off. RIH to 9600ft & try from there. Shales are to packing off. Pulled 60k most of way up to 9500ft. From 9500ft to 9400ft have cleaned up & are able to back ream at 1.3bpm. 02:40 - 03:45 1.08 DRILL P PROD1 Slowly PUH & swap well over to 9.4ppg mud. Lay in new mud from 9465ft. 03:45 - 04:25 0.67 DRILL P PROD1 Wiper in hole at normal pump rate 1.45bpm/4100psi. Clean down to 9500ft. Work down to 9550ft & wiper up to 9500ft at 1 bpm. Work down to 9586ft & wiper up 9500ft. 04:25 - 05:30 1.08 DRILL P PROD1 Hole is clean from 9550ft & shallower & can pump normal rate while RIH &PUH to these depths, however we are still fighting the TF changes. RIH to 9608ft. We are fighting TF changes & shales. Wiper back to 9300ft to clear BHA of shale. 05:30 - 05:40 0.17 DRILL P PROD1 Wiper to 9450ft. Depths are inaccurate now due to pulling 60k for 50ft. 05:40 - 06:35 0.92 DRILL P PROD1 PUH to 8080ft Tie in to RA marker at 8058 ft. RIH at min rate to 8260 ft and then increased to 1.25 bpm and WHP = 100 psi DHBHP = 4,080 psi 11.98 ppg Lot of cutting on shaker. Decrease WHP to 50psi 06:35 - 10:50 4.25 DRILL P PROD1 W/R from 8,080 ft to 9,516 ft. ,OK to 9516 ft. Reduced WHP = 29 psi from 100 psi BHP at 4025 psi (11.7ppg ECD) Once tagged at 9, 516 ft backed reamed up to 9400 ft at Op = 1.22 bpm Work our way in to 9591 with low OP. Backed reamed 9591 ft up to 9400 ft BHP at 4050 ft / Op 1.29 bpm. At 9416 ft while RIH with correct everything, tagged, Took 60 k several times to get free PUH Ref to Comment Section of Dims. POOH hole clean above 9400 ft. Pulled above WS and open EDC and cir at 1.8 bpm and tied in at 7,548 ft Corrected +6 ft. RIH. Closed EDC and RIH past the WS area. 10:50 - 12:15 1.42 DRILL P PROD1 RIH bringing in tubulars and prep. Stopped at 9390 ft 12:15 - 14:40 2.42 DRILL P PROD1 Working CTwhile waiting on 200 bbl of 11.8ppg KWF from MI Deadhorse rnrnea: wiwmuo nna:oa rm • BP EXPLORATION Page 20 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: .NORDIC 2 Rig Number: Date From - To Hours Task Cade ~ NPT ' Phase 4/16/2008 ~ 12:15 - 14:40 2.42 ~ DRILL P PROD1 14:40 - 16:10 1.50 ~ DRILL ~ P 16:10 - 18:00 1.83 DRILL P 18:00 - 18:30 0.50 DRILL P 18:30 - 19:15 0.751 DRILL P 19:15 - 19:30 ~ 0.25 ~ DRILL ~ P 19:30 - 20:30 1.00 CASE P 20:30 - 22:10 1.67 CASE P 22:10 - 22:40 0.50 CASE P 22:40 - 00:00 1.33 CASE P 4/17/2008 00:00 - 00:40 0.67 CASE P 00:40 - 01:00 0.33 CASE P 01:00 - 01:30 0.50 CASE P 01:30 - 01:35 0.08 CASE P 01:35 - 03:35 2.00 CASE P 03:35 - 04:35 1.00 DRILL P 04:35 - 06:10 1.58 DRILL P 06:10 - 08:50 2.67 DRILL P 08:50 - 11:45 I 2.92 I STKOH I P PROD1 PRODi PRODi PROD1 PROD1 LNRi LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 WEXIT WEXIT WEXIT WEXIT Description of Operations RIH and mix up 2ppb Alpine beads in 37 bbl 9.4ppg flo-pro pill TVD at window at 6,502 ft TVD and 6,552 ft TVDss at 9,400 ft MD Pump 2ppb beads down CT at Op = 1.44 /1.44 bpm at 4095psi. POOH laying in beads at 1:1 from 9,390 ft to 8,060 ft Above WS pumping 11.8 ppg Naar brine. Displacing wellbore to11.8ppg Naar KWF POOH laying in 11.8 ppg KWF at 1:1 Monitor well on annular and CT sides. Fill hole - 4bbls to fill. Pump down coil to warm it up. PJSM regarding handing BHA. Flow check well - no flow. Discuss incident w/crew & get commitment to focus on the job at hand. Inspect handling equipment for running liner. Inspect liner & tallies -good to go. Pop off well. Blow down BHA, purge w/ air & water. LD BHA on catwalk. Orientor is bent - 2 degrees. It appears that the agitator is slightly bent, not as severe as the orientator. Remove HOT from coil track BHA & test tools -tested good. Visually inspect coil track tools & appear to be straight. Motor appears to be straight. Bit was 1-1 (still good for re-run). MU new HOT to coil track tools & test same -good test. Lay coil track BHA off to the side of the catwalk. MU safety joint & find x-overs. C/O elevators for running liner. Clean up slips & dog collar for running liner. MU liner per program. PU injector & install check valves in UOC. Inspect CTC -good. MU coil to BHA. Stab onto well. Power up & test tools. Set depths. RIH w/liner. Continue to RIH w/ liner. WT ck ~ 8000ft = 21.5k. Tag up at 8074ft uncorrected. PU & try to orientate past the set down. Set down a maximum of 6k each time. Got past by yo-yoing pipe. Log down for tie-in 7548ft GR depth. (-6.5ft corr. RIH w/liner. BHP = 4175psi w/ coil track tools f~ the window. Lost 12 bbls on the trip in the hole to 9400ft. WT ck ~ 9300ft = 23k, RIW =9.3k. Slight booble at 9390ft. Made it to 9427ft. PU to 9380ft &RIH to 9400ft. Start pumping & release from liner, went to 4010psi. Set 6k down, clean PU w/ 20k up WT. Top of whipstock is 8723ft & anchor is set up for low side exit. POH. PJSM while POH regarding handling BHA. Unstab injector. Break off liner J setting tool & LD on catwalk. MU 1.5 AKO motor+2.73" STR bit. Loctite all connections. Stab onto well. Power up & test tools. RIH w/ KO BHA. Tag up uncorrected at 6300ft (Baker OS). Pump min rate through bit & orientate at the same time to get past. Log down for tie-in ~ 7560ft (-1 ift corr. Open EDC and RIH to 8050 ft and turned hole over to 9.4ppg flo-pro and recovered the 11.7ppg KW F for frurther use. RIH and lightly tagged top of billet 8723 ft. PU 1 ft and started trouh up at 8723 ft Conducting OH sidetrack off al billet Set 1.5 deg AKO setting F'rlflt8tl: tb/lU/LUUtS 4:75:~}i F'M BP EXPLORATION Page 21 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date ,From - To Hours I~, Task Code NPT Phase Description of Operations 4/17/2008 08:50 - 11:45 2.92 STKOH P 11:45 - 12:45 1.00 STKOH P 12:45 - 13:25 I 0.671 STKOH I P 13:25 - 15:50 2.92 STKOH P 15:50 - 19:35 I 3.75 I STKOH I P 19:35 - 22:10 2.58 STKOH P 22:10 - 23:10 1.001 STKOH P 23:10 - 00:00 0.83 STKOH P .4/18/2008 00:00 - 01:10 1.171 STKOH P 01:10 - 02:40 I 1.501 STKOH I P 02:40 - 04:00 1.331 DRILL P 04:00 - 04:10 0.17 DRILL P 04:10 - 05:20 1.17 DRILL P 05:20 - 07:00 1.67 DRILL P 07:00 - 07:45 0.75 DRILL P WEXIT TF at 90R HS. Old hole was drilled using 150 TF with 1.0 deg AKO motor setting. Op = 1.60 / 1.60 bpm CTP = 3950 psi off bottom WHP/BHP/ ECD = 29 psi / 4278 psi / 12.53 ppg Vp = 310 bbl Backed reamed 8,720 ft to 8,690 ft. at 15fUhrs after setting at 8720 ft for 5 min WEXIT Backreamed 8,720 ft to 8,690 ft at 90R TF ~ 30 fph Op = 1.60 / 1.56 bpm CTP = 3950 psi off bottom WHP/BHP/ ECD = 33 psi / 4146 psi / 12.13 ppg Vp = 305 bbl WEXIT Backreamed 8,720 ft to 8,690 ft at 90R TF 60 fph Op = 1.61 / 1.56 bpm CTP = 3950 psi off bottom WHP/BHP/ ECD = 29 psi / 4156 psi / 12.17 ppg Vp = 303 bbl WEXIT Set at 8720 ft and time drill at O.ift / 5 minutes Op = 1.61 / 1.56 bpm CTP = 3950 psi off bottom WHP/BHP/ ECD = 29 psi / 4186 psi / 12.25 ppg Vp = 302 bbl Lowered Op to 1.40/1.39 bpm at 8,722.3 ft Work down to 8722.9ft & started showing WOB. WEXIT Begin time drilling at 8722.9ft ~ 0.1 W5min w/ 90R TF. Op = 1.41 / 1.37 bpm CTP = 3470 psi off bottom WHP/BHP/ ECD = 29 psi / 4186 psi / 12.25 ppg Vp = 289 bbl Time drill to 8724.1ft & stacked 2k. PU & start over at 8723ft. Started taking weight at 8723.5ft. Time drill at 0.1ft/10min. Pause drilling as required to keep less than 2k WOB. WEXIT Auto drill from 8724ft ~ 5fUhr w/ 100R TF. Op = 1.41 / 1.37 bpm CTP = 3470 psi off bottom WHP/BHP/ ECD = 29 psi / 4186 psi / 12.25 ppg Vp = 282 bbl Increase ROP to 14ft/hr from 8730ft. Drill to 8750ft. WEXIT Ream & backream drilled TF and 45 left & right of drilled TF to open sidetrack. WEXIT POH for lateral BHA following pressure schedule. Reduce min rate from 8260ft to 8060ft while POH & holding appropriate WHP. Open EDC at 8000ft. WEXIT Continue to POH following pressure schedule. PJSM while POH regarding pressure undeploying. WEXIT Pressure undeploy KO BHA. Bit was 2.73" 1-1 & had small bits of aluminum inside. PROD2 LD BHA on catwalk. Check LOC, remove debris & C/O o-rings. Add in USR. Test same. Dial down motor to 1.1 deg AKO & install Smith BC bit. C/O rock catcher...ah, I meant high pressure filter on reel manifold -plugged & eroded. PROD2 PJSM regarding pressure deploying lateral BHA. PROD2 Pressure deploy lateral BHA. Stab onto well. Power up & test tools. Set depths. PROD2 RIH following pressure schedule. Tie-in at 7,548 ft and corrected -9 ft PROD2 RIH, close EDC. orient TF to 140R RIH past WS to 8260 ft with Punted: s~toizoos a:is:ss run • • BP EXPLORATION Page 22 of 35 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ', Name: 1 ell Name: 1 e: Name: N N From - To R-01 R-01 REENTE ORDIC ORDIC Hours ', R+COM CALIST 2 Task PLET A Code - E NPT Start Rig R Rig N Phase _ Spud Date: 4/1/2008 : 3/24/2008 End: 5/2/2008 elease: 5/2/2008 umber: Description of Operations _ -_ - 4/18/2008 07:00 - 07:45 0.75 DRILL P PROD2 min flowrate Tagged bottom at 8,750 ft 07:45 - 11:25 3.67 DRILL P PROD2 Drilling later at 8,750 ft to 8900 ft TF at 90 to 65 R TS Op = 1.5 / 1.45 bpm CTP 3,730 psi WHP /BHP /ECD = 4,105 psi / 37 psi / 12.03 ppg ROP 40-50 fph using 1.5-0.5 WOB Vp = 248 bbls 11:25 - 11:55 0.50 DRILL P PROD2 Wiper trip and trying to get a survey before making wiper Magnetic interferences from the old wellbore Wipered from 8900 ft to 8750 ft 11:55 - 17:26 5.52 DRILL P PROD2 Drilling later at 8900 ft to 9050 ft TFat90to110RTS Op = 1.5 / 1.45 bpm CTP 3,930 psi WHP /BHP /ECD = 4,222 psi / 37 psi / 12.37 ppg ', ROP 40-50 fph using 1.5-0.5 WOB Vp = 240 bbls ~, Table top drills in the Dog House. Rig Fire Drill, Kick While Drill and Spill Drills) 17:26 - 17:45 0.32 DRILL P PROD2 Wiper trip to 8750 ft 17:45 - 22:50 5.08 DRILL P PROD2 Drilling lateral at 9050 ft TFat90to110RTS Op = 1.5 / 1.45 bpm CTP 3,930 psi WHP /BHP /ECD = 4,222 psi / 37 psi / 12.37 ppg ROP 40-50 fph using 1.5-0.5 WOB Vp = 209 bbls Drill to 9200ft 22:50 - 23:40 0.83 DRILL P PROD2 Wiper trip to 8070ft -slight overpull at whipstock ~ 8723ft. Reduce pump rate through sidetrack area & from 8260ft to 8060ft. 23:40 - 23:45 0.08 DRILL P PROD2 Log down for tie-in at 8080ft (+3ft corr. 23:45 - 00:00 0.25 DRILL P PROD2 Wiper to TD. 4/19/2008 00:00 - 00:35 0.58 DRILL P PROD2 Continue to wiper to TD -clean. 00:35 - 04:40 4.08 DRILL P PROD2 Drilling lateral from 9200ft TFat90to110LTS Op = 1.49 bpm / 1.45 bpm CTP 3,730 psi WHP/BHP/ECD=4,170 psi/26psi/12.22 ppg ROP 40-60 fph using 1.5-0.5 WOB Vp = 277 bbls Drilled to 9350ft Clean out high pressure filter -plugged. 04:40 - 05:30 0.83 DRILL P PROD2 Wiper trip to 8750ft -clean. Wiper trip to TD, slight booble at 9320ft, otherwise clean. 05:30 - 07:15 1.75 DRILL P PROD2 Drilling lateral from 9350ft TFat90to110RTS Op = 1.49 bpm / 1.45 bpm CTP 3,730 psi WHP/BHP/ECD=4,160 psi/18 psi/12.20 ppg ROP 40-60 fph using 1.5-0.75 WOB Vp = 258 bbls 07:15 - 07:45 0.50 DRILL P PROD2 Working BHA, unable to get survey due to the close proximity of the Li lateral 07:45 - 10:15 2.50 DRILL P PROD2 Drilling lateral from 9405ft Printed: 6/10/2008 4:15:59 PM BP EXPLORATION Page 23 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: NPT Phase Description of Operations Date From - To Hours Task Code 4/19/2008 ~ 07:45 - 10:15 ~ 2.50 ~ DRILL ~ P 10:15 - 10:33 0.301 DRILL ~ P 10:33 - 11:40 1.12 DRILL P 11:40 - 14:20 2.67 DRILL P 14:20 - 14:30 0.17 DRILL P 14:30 - 16:00 1.50 DRILL P 16:00 - 17:15 1.251 DRILL P 17:15 - 18:05 I 0.831 DRILL I P 18:05 - 23:25 ~ 5.33 ~ DRILL ~ P 23:25 - 00:00 0.58 DRILL P 4/20/2008 00:00 - 01:00 1.00 DRILL P 01:00 - 06:00 5.00 DRILL P PROD2 TF at 90 to 110 R TS Op = 1.51 bpm / 1.47 bpm CTP 3,730 psi Density 9.63 / 9.67 ppg WHP /BHP /ECD = 4,211 psi / 18 psi / 12.35 ppg ROP 10-50 fph using 1.5-0.75 WOB Vp = 208 bbls Started mud swap at 9444 ft at 08:44 hrs. Taking returns to Tiger tank PROD2 Drilling lateral from 9488ft TF at 60L TS Op = 1.50 bpm / 1.45 bpm CTP 3,400 psi Density 9.48 / 9.50 ppg WHP/BHP/ECD=4,061 psi/29psi/11.89 ppg ROP 10-50 fph using 1.5-0.75 WOB Vp = 192 bbls and building due to mud swap PROD2 Wiper trip to 8750 ft PROD2 Drilling lateral from 9500ft TF at 60L TS Op = 1.50 bpm / 1.45 bpm CTP 3,420 psi Density 9.41 / 9.50 ppg WHP /BHP /ECD = 4,054 psi / 29 psi / 11.85 ppg ROP 10-50 fph using 1.5-0.75 WOB Vp = 402 bbls Mud Swap done Have some difficulty getting survey probably due to proximity of the old wellbore PROD2 100 ft wiper trip PROD2 Drilling lateral from 9605ft TF at 150E TS Op = 1.50 bpm / 1.45 bpm CTP 3,420 psi Density 9.41 / 9.50 ppg WHP /BHP /ECD = 4,063 psi / 33 psi / 11.88 ppg ROP 10-60 fph using 1.5-0.75 WOB PROD2 Wiper trip to tie-in Pulled a little heavy at the OHST and 8,718 ft Increased Op to 1.54 bpm PUH to 8,260 ft Tied in at 8075 ft and corrected +4 ft PROD2 RIH at min flowrate to 8270 ft Increased Op to 1.5 bpm and RIH, slowed pump down to min running through the OHST at 8723 ft PROD2 Drilling lateral from 9650ft TF at 150E TS Op = 1.50 bpm / 1.45 bpm CTP 3,490 psi Density 9.41 / 9.50 ppg WHP /BHP /ECD = 4,087 psi / 22 psi / 11.95 ppg ROP 10-60 fph using 1.5-0.75 WOB Still having some problems getting survey's Drill to 9800ft. PROD2 Wiper trip to 8750ft. PROD2 Continue wiper trip -clean both ways. PROD2 Drilling lateral from 9800ft TF at 60L TS & building angle to find sand. Op = 1.48 bpm / 1.44 bpm CTP 3,530 psi Density 9.49 / 9.52 ppg WHP/BHP/ECD=4,122 psi/33 psi/12.02 ppg Nnntea: tinuieuut3 a:to:oa rnn BP EXPLORATION Page 24 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date. From - To ~I Hours ~~ Task Code NPT Phase ~',, Description of Operations 4/20/2008 01:00 - 06:00 5.00 DRILL P PROD2 ROP 10-40 fph using 1.5-0.75 WOB Drill to 9935ft. 06:00 - 07:45 1.75 DRILL P PROD2 Wiper trip to 8750ft. clean up RIH and had some problems getting 07:45 - 08:10 0.42 DRILL P PROD2 Drilling inverted w/ CTW at -6600 k and WOB = 1.43k Drilling with 45L TF and try build hole angle up to 98 deg and look for sand Op = 1.51 / 1.46 bpm at3700 psi Vp = 328 bbl Density 9.50 / 9.55 ppg BHP = 4128 psi at 12.11 ECD Looking for sand 08:10 - 11:21 3.18 DRILL P PROD2 POOH to change BHA Held PJSM on pressure undeploying BHA with 750 psi 11:21 - 12:19 0.97 DRILL P PROD2 Tagged up and zeroed counter. RIH 1.1 ft Pressure undeploying BHA as per procedure. Crew change at 12:00 hrs, held PJSM with new crew and discussed hazards 12:19 - 13:15 0.93 DRILL P PROD2 Undeploying BHA 13:15 - 14:30 1.25 DRILL P PROD2 Changed out BHA STC at 1-1-I Will PU a RB HTC RWD BC. Lost SLB Primary Computer. Called for one and its on the way. Chnanged out slings in the derrick holding the hose bundle to the injector. Re-headed wireline after 10 runs. 14:30 - 15:00 0.50 DRILL P PROD2 Circulation MPD loop while reheading wireline head Pull tested 3 times OK 15:00 - 15:15 0.25 DRILL P PROD2 PJSM on PU and pressure deploying BHA ', 15:15 - 17:20 2.08 DRILL P PROD2 Pressure deploy BHA in the well Stab on well 17:20 - 19:45 2.42 DRILL N SFAL PROD2 Re-booting the SLB Primary Computer Re-formatting the new hard drive 19:45 - 21:05 1.33 DRILL P PROD2 PJSM regarding non routine ops of RIH using mechanical gauges. RIH following pressure schedule. 21:05 - 22:00 0.92 DRILL P PROD2 Log down for tie-in from 7560ft (-5ft corr. Continue RIH. SLB computer is up & running. Close EDC. 22:00 - 23:40 1.67 DRILL P PROD2 Wiper to TD. Pump min rate through shales from 8060ft to 8260ft. Tag up three times on the OHST, got past with 105 R HS TF. Perform check shot survey's along the way -matching numbers. Stacking at 9794ft -work area. Stacking at 9820ft, reduce pump rate & increase WHP & got past. 23:40 - 23:50 0.17 DRILL P PROD2 Log from 9900ft to TD to compare GR & to prevent gap in GR log as we shortened the BHA length. 23:50 - 00:00 0.17 DRILL P PROD2 Drilling lateral from 9936ft TF at 20L TS & building angle to find sand. Op = 1.30 bpm / 1.30 bpm CTP 3,700 psi Density 9.52 / 9.55 ppg BHP/WHP/ECD=4,125 psi/48 psi/12.15 ppg ROP 10 fph using 1.5-0.75 WOB -7k surface wt 4/21/2008 00:00 - 05:15 5.25 DRILL P PROD2 Continue to drill lateral from 9940ft TF at 30L TS & building angle to find sand. Op = 1.30 bpm / 1.24 bpm CTP 3,700 psi Density 9.52 / 9.55 ppg BHP /WHP /ECD = 4,165 psi / 125 psi / 12.22 ppg Increase WHP to help drill. ROP 10 fph using 1.5-0.75 WOB -6.5k surface wt. Drill to 9968ft. 05:15 - 05:25 0.17 DRILL P PROD2 BHA wiper trip - a little sticky with 3k overpulls. Printetl: 6/10/2008 4:15:59 PM • BP EXPLORATION Page 25 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT` Phase Description of Operations 4/21/2008 05:25 - 06:30 1.08 DRILL P PROD2 Continue to drill lateral from 9968ft TF at 30L TS & building angle to find sand. Op = 1.28 bpm / 1.26 bpm CTP 3,700 psi Density 9.50 / 9.42 ppg BHP/WHP/ECD=4,165 psi/125psi/12.29 ppg ROP 4-8 fph using 2.5k WOB -6.5k surface wt. 06:30 - 09:50 3.33 DRILL P PROD2 POOH following MPD senario 09:50 - 14:00 4.17 DRILL P PROD2 Tagged up WHP = 800 psi. Held PJSM on pressure deploying BHA Bit at 0-0 ,agitator works fine and the motor turns and normal. Scribe Motor to1.75deg AKO and MU R-60 with a nose cone and deploying 1.75" AKO setting motor with R-60 ST Bit. 14:00 - 14:30 0.50 DRILL P PROD2 RIH and found the tool was shorted. Troubleshoot the electrical issue with the Tap waster The surface check out OK 14:30 - 14:45 0.25 DRILL N DFAL PROD2 POOH to check the electrical short 14:45 - 16:45 2.00 STKOH N DFAL PROD2 Pressure undeployed the injector off and trouble shoot the electrical problem Found the flow sub had a short, changed out and checked ok 16:45 - 17:30 0.75 STKOH N DFAL PROD2 Pressure undeploy BHA to locate the tool short 17:30 - 18:25 0.92 STKOH N DFAL PROD2 Trouble BHA shoot tool. Found the HOT was shorted. Changed out and tested the new one OK 18:25 - 18:40 0.25 STKOH N DFAL PROD2 PJSM regarding pressure deploying. 18:40 - 20:45 2.08 STKOH N DFAL PROD2 Pressure deploy BHA. Set counters.Open EDC. 20:45 - 22:20 1.58 STKOH N DFAL PROD2 RIH following pressure schedule. 22:20 - 22:30 0.17 STKOH P PROD2 Log down for tie-in (-5ft Corr) from 9560ft. 22:30 - 00:00 1.50 STKOH P PROD2 Continue to RIH. Stop at SOOOft & close EDC. RIH pumping min rate past 8,260ft to bottom. Tag up ~ 9,945ft & remove brass cap. Very ratty, 15k overpulls through the section. Pull up to 9,432ft. 4/22/2008 00:00 - 00:25 0.42 STKOH P PROD2 POH to 9432ft. 00:25 - 00:55 0.50 STKOH P PROD2 Back ream from 9400ft to 9432ft. Attempt to repeat but hole is packing off. PUH, over pull 15k for 100ft. 00:55 - 01:25 0.50 STKOH P PROD2 Wiper up to 8800ft, cleaned up at 9000ft. 01:25 - 02:00 0.58 STKOH P PROD2 Hold WHP, reduce rate &RIH following drilled TF. 02:00 - 02:30 0.50 STKOH P PROD2 Back ream from 9432ft to 9400ft w/ LS TF Op = 1.3 bpm / 1.26 bpm CTP 3,550 psi Density 9.52 / 9.58 ppg BHP /WHP /ECD = 4,300 psi / 66 psi / 12.57 ppg 02:30 - 03:30 1.00 STKOH P PROD2 Back ream from 9432ft to 9400ft w/ LS TF Op = 1.4 bpm / 1.36 bpm CTP 3,710 psi Density 9.51 / 9.56 ppg BHP /WHP /ECD = 4,225 psi / 62 psi / 12.37 ppg 03:30 - 04:30 1.00 STKOH P PROD2 Time drill 1ft/hr w/ LS TF Op = 1.44 bpm / 1.36 bpm CTP 3,800 psi Density 9.50 / 9.50 ppg BHP /WHP /ECD = 4,200 psi / 60 psi / 12.29 ppg 04:30 - 05:15 0.75 STKOH P PROD2 Time drill 2ft/hr w/ LS TF Op = 1.44 bpm / 1.36 bpm CTP 3,800 psi Density 9.50 / 9.50 ppg BHP /WHP /ECD = 4,200 psi / 60 psi / 12.29 ppg Drill to 9434ft, stacking & no WOB. PUH to 9432ft & start over. 05:15 - 05:54 0.65 STKOH P PROD2 Time drill 1ft/hr w/ LS TF Op = 1.44 bpm / 1.31 bpm CTP 3,800 psi Density 9.50 / 9.50 ppg rnntea: tinuizuuts a:u:oa rnn • BP EXPLORATION Page 26 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ;, From - To Hours ~, Task Code NPT 4/22/2008 05:15 - 05:54 0.65 STKOH P 05:54 - 06:00 0.10 STKOH P 06:00 - 10:07 4.12 STKOH P 10:07 - 11:30 1.38 STKOH P 11:30 - 11:50 0.33 STKOH P 11:50 - 14:10 2.33 STKOH P 14:10 - 16:30 2.33 STKOH P 16:30 - 17:00 0.50 STKOH P 17:00 - 17:35 0.58 STKOH P 17:35 - 20:00 2.42 STKOH P 20:00 - 23:00 3.00 STKOH P Spud Date: 4/1 /2008 Start: 3/24/2008 End: 5/2/2008 Rig Release: 5/2/2008 Rig Number: Phase Description of Operations PROD2 BHP /WHP /ECD = 4,340 psi / 50 psi / 12.72 ppg PROD2 Drill 0.2ft every 10min, PU & repeat w/ LS TF Op = 1.44 bpm / 1.31 bpm CTP 3,800 psi Density 9.50 / 9.50 ppg BHP /WHP /ECD = 4,340 psi / 50 psi / 12.72 ppg PROD2 Time drilling OHST at 9,433 ft to 9436.4 ft at 6min / 0.1ft Op = 1.45 /1.40 bpm Density = 9.50 / 9.51 ppg Vp = 168 bbl BHP = 4233 psi at 12.37ppg ECD PROD2 PUH. and RIH to drill at a TF of 180 deg, Drill at 15 fph Op = 1.47 / 1.43 bpm 3,730 psi BHP = 4264 psi = 12.47 ppg ECD WOB at 0.3k Ib ROP at 15 fph Working to get it to drill stacking pulled up to 9,400 ft and seen CTP drop off and BH bore pressure drop off. RIH Started mud swap at 11:OOhrs 9440 ft Unable to ST in this area due faults and the unknown. Called town and changed KOP to 9335 ft Conducting equipment audit by Bill Hopkins and Paul Foreman BP PROD2 Conducting ST again at sand package at 9,335 ft TF at 180 deg Op 150 / 1.45 bpm at 3480 psi and dropping due to mud swap. Back reamed after 10 min PROD2 Backreaming at 13-15 fph from 9335 ft to 9300 ft at 170R TF Op = 1.50 / 1.48 bpm at 3,362 psi BHP = 4065 psi at 11.83ppg PROD2 RIH to 9,335 ft to 9300 ft Backed ream up 9335 ft to 9305 ft at 30 fph at 170 deg R HS Op = 1.50 / 1.40 bpm 3252 psi WHP /BHP = 4020 psi ECD = 11.76 ppg / 100 psi Lost SLB CTDS primary Computer for the 2nd time. Rebooted and called for help from the SLB computer people. Helene Harding and Mike Wheatall w/ CPAI visted the rig and was given the tour Backed reammed 9,335 ft to 9,300 ft at 60 fph. PROD2 RIH to 9,320 ft and reamed down from 9,300 ft 9,320 ft Drilling ST at 170R TS at 30 fph from 9,320 ft to 9,335 ft Op 1.51 / 1.48 bpm at 3303 psi BHP = 4,087 psi ECD = 11.79 ppg Timed milled at 9,335 ft for 10 min PROD2 Backed reamed 9,335 ft to 9,320 ft at 30 fph RIH at cycle speed and unable to see any delta P, WOB of any type. PROD2 POOH to PU AI billet and anchor POOH with EDC open at 1.85 bpm. Maintain BHP as per schedule. Hold PJSM to discuss undeployment. PROD2 At surface. Pressure undeploy BHA as per proceedure. See remarks for additional detail. Remove motor and bit. Brass cone gone. Bit in excellent condition. 1-1-I Printed: 6/10/2008 4:15:59 PM • BP EXPLORATION Page 27 of 35 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 4/22/2008 23:00 - 00:00 4/23/2008 00:00 - 03:00 4/24/2008 03:00 - 04:45 04:45 - 05:00 05:00 - 05:45 05:45 - 07:30 07:30 - 07:45 07:45 - 09:30 09:30 - 09:50 09:50 - 11:00 11:00 - 13:55 13:55 - 15:05 15:05 - 17:20 17:20 - 17:30 17:30 - 19:30 19:30 - 22:00 22:00 - 00:00 00:00 - 00:30 00:30 - 01:45 01:45 - 02:00 02:00 - 04:15 04:15 - 06:00 06:00 - 06:45 1 R-01 1 R-01 Spud Date: 4/1/2008 REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 NORDIC CALISTA Rig Release: 5/2/2008 NORDIC 2 Rig Number: Hours Task Code ~ NPT Phase Description of Operations 1.00 BOPSU P PROD2 Function test BOPS. Strip and cut slickline. Re-head. 3.00 STKOH P PROD2 Hold PJSM to discuss deployment. MU and deploy aluminum billet assembly on BHI tools. Scribe single slip to HS. 1.75 STKOH P PROD2 Run in hole. Maintain BHP schedule as per well plan. 0.25 STKOH P PROD2 Log GR tie in from 7565'. Subtract 5' correction. 0.75 STKOH P PROD2 Run in hole to 9335' setting depth. Set down and take 4k# weight at 7977'. Pick up and orient 180 deg. RIH. Set down again. Pick up and orient to 50-60L. RIH. Make 1' further down hole. Had 1 k# overpull when picking up. RIH again. Made an additional 4' of hole before stacking out. 1-2k# overpull. Appear to be pushing junk down hole. Discuss with town. 1.75 STKOH N PROD2 Pull out of hole to pick up clean out BHA. Maintain BHP as per schedule. 0.25 STKOH N PROD2 PJSM on pressure Undeployment of BHA 1.75 STKOH N PROD2 Undeploy and LD BHA. BHA had hard compacted shale still on the bottum anchors. 0.33 STKOH N PROD2 PJSM on PU and Pressure deployment of clean out BHA. 1.17 STKOH N PROD2 MU and Pressure Deploy clean out BHA with 1.1 AKO and HCC 2.7 X 3.0 bi center bit. 2.92 STKOH N PROD2 RIH following pressure schedule. Log GR from 7575' to 7577' -3' correction, continue RIH. open EDC at 7650 and circ at 1500 psi. Tag at 7995' 1.17 STKOH N PROD2 Cleaned out tubing with min. motor work. RIH to 8045' change to Window Tool Face 140 R. Continue to clean hole to 8260' at CP=2300 psi. IN/OUT .97/1.05 bbls/min. from 8260' to 9400' CP=3200 psi 1.42/1.55 bbls/min at tubing speed of 19 FPM. 2.25 STKOH N PROD2 POH following pressure schedule. Wiper with EDC closed from 9,400' to 7,500', RIH to 8,000' and opened EDC, continued POH. 0.17 STKOH N PROD2 PJSM Pressure Undeployment and LD of BHA, while POH 2.00 STKOH N PROD2 Pressure undeploy BHA. Maintain WHP as per program. 2.50 STKOH N PROD2 Hold PJSM with crew. Pressure deploy billet BHA. 2.00 STKOH N PROD2 Run in hole. Maintain BHP from surface. 0.50 STKOH N PROD2 Log GR tie in from 7765'. Subtract 13' correction. 1.25 STKOH P PROD2 Continue to run in hole. Took 3-4k# weight bobble passing through window. Set down at 8738'. (At OH billet). PU and work past to 8742'. PU again and RIH at 25 fpm. Past billet. Continue in hole. 0.25 STKOH P PROD2 Top of billet on depth at 9335'. Pressure coil to set. TF oriented with single slip at 160 LHS. Billet set at +/-4200 psi surface pressure. Set 2k# do wt on billet. Billet top at 9335'. 2.25 STKOH P PROD2 Pull out of hole. Maintain BHP as per schedule. 1.75 STKOH P PROD2 Hold PJSM with crew. Pressure undeploy billet setting BHA. 0.75 STKOH P PROD2 Crew change, Held PJSM on finishing pressure undeploying Printed: ti/lU/LUUtl 4:1 ~:5y YM BP EXPLORATION Page 28 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common W ell Name: 1 R-01 Spud Date: 4/1/2008 Event Nam e: REENTE R+COM PLET E Start : 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALIST A Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code; NPT '' Phase Description of Operations 4/24/2008 06:00 - 06:45 0.75 STKOH P PROD2 BHA. Discussed the procedure and note the possible hazards. 06:45 - 08:30 1.75 STKOH P PROD2 Removed BOT setting tools and loaded out. PU ST BHA with new motr and 1.75deg AKO setting Pressure deploying BHA as per SOP 08:30 - 09:45 1.25 STKOH P PROD2 RIH following pressure schedule. 09:45 - 10:00 0.25 STKOH P PROD2 Work to get past the tubing stub at 6313'. Unable to get past POOH 10:00 - 11:15 1.25 STKOH P PROD2 POOH following pressure schedule. 11:15 - 11:25 0.17 STKOH P PROD2 PJSM on pressure undeploying and LD of BHA. 11:25 - 12:15 0.83 STKOH P PROD2 Pressure undeploy and LD BHA. 12:15 - 12:45 0.50 STKOH P PROD2 reconfigure open hole sidetrack BHA from 1.75 AKO to 1.5 AKO 12:45 - 12:50 0.08 STKOH P PROD2 PJSM review Pressure deploy SOP 12:50 - 14:00 1.17 STKOH P PROD2 Pressure deploy new open hole sidetrack BHA with 1.5 AKO Abigail Warren directed the pressure deployment and did a fine job 14:00 - 16:55 2.92 STKOH P PROD2 RIH following MPD Schedule passed through 6,313' OK! Continue to RIH. GR tie in at 7,555' to 7,590' (-7') correction. Continue to RIH tag at 9,333' 16:55 - 17:15 0.33 STKOH P PROD2 PU to 9320 Free spin of CP=3140 psi. RIH to 9332.7 and hold position bulling trough with 170 R TF CP= 3250psi ~ 1.43/1.24 bbls/min. PV of 68 bbls in Pit 3. 17:15 - 21:30 4.25 STKOH P PROD2 Back ream at 15 Whr from 9332' to 9300 ft CP = 3270 psi ~ 1.43/1.37 bbls/min PV of Pit 3 is 91 bbls. ~ 18:05 C~ 9,319' still back reaming CP = 3250psi ~ 1.44/1.40 bbls/min ~ 10fpm Pit 3 volume = 87 bbls. Make two more backream passes. One at 30 fpm, then 45 fpm. 21:30 - 00:00 2.50 STKOH P PROD2 RIH. Time drill from 9332.0'. Begin time drilling at 1' per hour. TF: 165-170R. 3290 psi fs at 1.48 in/1.40 out. WHP/BHP/ECD: 18/4073/11.91 ppg. 4/25/2008 00:00 - 05:00 5.00 STKOH P PROD2 Continue to time mill. Weight transfer is poor. PU and restart several times. Eventually get DHWOB at 9336'. Continue to time drill. 75 to 150 dpsi. 1- 2k# DHWOB 3275 psi fs at 1.44 in/1.42 out. Noted aluminum on shakers. Mill to 9337.4'. Approximately 2' of billet milled. 05:00 - 06:30 1.50 STKOH P PROD2 PU to re-establish free spin. 3,475 psi at 1.51 in/out. Continue to time drill ahead by weight and motor work. 06:30 - 09:15 2.75 STKOH P PROD2 Took off break and drilled sidetrack at 170R HS Op = 1.40 / 1.35 bpm at 3,370 psi Stalled at 9,339 ft. TF at 170RHS PUH to clean the 30 ft trough and ST area Bleed OA down from 30 psi to zero Drillling ST and found the sand package at 9350 ft and drilled to 9357 ft Hauled in 290 bbl of 9.4 flo-pro and put in mud pits Printed: s~toizoots aas:5a rnn BP EXPLORATION Page 29 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 4/25/2008 ~ 09:15 - 09:50 ~ 0.58 ~ STKOH ~ P 09:50 - 12:10 2.33 STKOH P 12:10 - 13:30 1.33 STKOH P 13:30 - 14:20 ~ 0.83 ~ DRILL ~ P 14:20 - 14:35 I 0.251 DRILL I P 14:35 - 16:00 ~ 1.42 ~ DRILL ~ P 16:00 - 17:45 1.75 DRILL P 17:45 - 20:00 2.25 DRILL P 20:00 - 22:15 2.25 DRILL P 22:15 - 23:15 1.00 DRILL P 23:15 - 00:00 I 0.751 DRILL I P 4/26/2008 00:00 - 03:00 3.00 DRILL P 03:00 - 05:30 2.50 DRILL P 05:30 - 05:45 0.25 DRILL P 05:45 - 10:12 4.45 DRILL P 10:12 - 10:39 0.45 DRILL P 10:39 - 11:38 0.98 DRILL P PROD2 Reaming ST area at 170R and and 125R SD pump and trap 700 psi on wellhead, 4078 psi BHP. RIH and conduct dry tag Covered table top drills concerning Kicks while drilling. PJSM on Pressure Deplyment of BHA PROD2 POOH to PU sand seeker BC bit PROD2 Tagged up Undeploy BHA as per SOP Pw = 900 psi Vp = 343 bbl with all pits active PROD2 After 17 runs, conducted slack management Changed packoff and check accumulator pressure on the outside chain tension (100 psi) OK PROD2 Held PJSM on conducting Slack management on CT. Discussed trashing of the mud in the pits and coiled tubing. PROD2 Removed CTC and securec and protected wire. Reversed fluid at 2.5 bpm and hear the slack for while Cut CT to find wire. Cut off 130 ft and found wire. Tested wire Continunity = >2000 mega ohms 76 ohms PROD2 Rehead CTC and UOC Pull tested CTC to 35k Retested at continuity at 84 ohms and > 2000 megaohms PROD2 Set injector down and circulate.Hold PJSM after crew change. Pressure deploy BHA. PROD2 Run in hole. Maintain BHP as per pressure schedule. PROD2 Log gr tie in from 7548'. Missed marker. Re log gr tie in from 7535'. -35' correction. Tie in again at RA at 8058'. No correction. PROD2 Run in hole. Oreint TF 90RHS for billet at 8723. Pass second billet at 9332' at 170RHS. Hole smooth. PROD2 Drill lateral from 9354'. 3500 psi fs at 1.48 in/out. 100-200 psi mtr wrk. 0.5-1.5k# DHWOB. WHP/BHP/ECD: 26/4117/12.04 ppg. INC/AZM/TF: 84.0/54/120 RHS. ROP: 20-40 fph. Drill to 9455'. PROD2 Continue to drill ahead. TF: 90LHS. ROP: 25-40 fph. 3550 psi fs at 1.5 in/1.46 out. Drill to 9500'. PROD2 Make short wiper trip to 9350'. Swap to mud pump #2. PROD2 Drill ahead inverted in the A3 and faulted area. 3520 psi fs at 1.50 bpm in/out. Op = 1.50 / 1.46 bpm at 3630 psi off bottom BHP = 4015 psi at 11.98 ppg ECD Vp at 06:00 hrs = 342 bbls Having to PU perodically because of stacking. Cleans up at 9,560 ft to constant drillling ROP at 50 to 60 fph. .Drilled into a 45-50 API sand package at 9,555 ft. Best in the well so far. Restivity Tool is still reading backwards PROD2 Wiper trip to 9350 ft PROD2 Drill ahead inverted in the A3 9,650 ft. "SAND" TF at 80-90 LHS trying to stay in the sand 3,520 psi fs at 1.50 bpm in/out. Op = 1.42 / 1.38 bpm at 3,730 psi off bottom BHP = 4134 psi at 12.05 ppg ECD Printed: 6/10/2008 4:15:59 PM ~~ BP EXPLORATION Page 30 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT ', Phase Description of Operations 4/26/2008 10:39 - 11:38 0.98 DRILL P PROD2 ROP in the 50 API sand at 50-60fph 11:38 - 12:10 0.53 DRILL P PROD2 200 ft wiper trip due to stacking. PUH to 9,525 ft, clean trip up. 12:10 - 13:28 1.30 DRILL P PROD2 Drill ahead inverted in the A3 9,750 ft. TF at 80-90 LHS trying to stay in the sand 3,520 psi fs at 1.50 bpm in/out. Op = 1.53 / 1.50 bpm at 3,730 psi off bottom and 3900 psi on bottom BHP = 4211 psi at 12.27 ppg ECD Vp = 325 bbl's ROP in the 50 API sand at 50-60fph 13:28 - 16:10 2.70 DRILL P PROD2 Wiper trip to tie in at RA marker Corrected +2 ft RIH and started taking wt at 8500 and set down at 8508ft. PUH and pulled tight all of the way up to 8260 ft. Something was along side of us. RIH Must have had a hair ball around us. RIH and tagged bottom at 9,800 ft 16:10 - 16:27 0.28 DRILL P PROD2 Drill ahead 9,800 ft. Annulus pressure coming up TF at 80-90 LHS trying to stay in the sand 3,520 psi fs at 1.50 bpm in/out. Op = 1.50 / 1.46 bpm at 3,730 psi off bottom and 3900 psi on bottom Density = 9.46 / 9.53 ppg BHP = 4277 psi at 12.46 ppg ECD Vp = 307 bbl's Found the hose coming off the P-14 pump leaking 16:27 - 18:00 1.55 DRILL N SFAL PROD2 POOH to wiper the well bore, change out the hydraulic hose and tie-in at 7,548 ft. 18:00 - 18:45 0.75 DRILL N PROD2 Change out hydraulic hose on power pack 18:45 - 19:00 0.25 DRILL N PROD2 Log GR tie in from 7570'. Subtract 4' correction. 19:00 - 20:15 1.25 DRILL N PROD2 Run in hole. Orient at window and billets. Circulate to bottom. 20:15 - 00:00 3.75 DRILL P PROD2 Drill ahead from 9804' to 9926. 3725 psi fs at 1.48 in/1.44 out. 150-300 psi mtr wrk. 1 k#dhwob. IA/OA/PVT: 57/28/278 bbls WHP/BHP/ECD: 26/4258/12.45 ppg. I NC/AZMlf F: 99.8/14.5/758. ROP: 30-50 fph. Trouble sliding. 4/27/2008 00:00 - 02:30 2.50 DRILL P PROD2 Make wiper trip to 8300'. 3713 psi fs. PVT: 277 bbls Orient and stop pumps as needed across billets at 8723' and 9335'. Hole smooth. 02:30 - 06:00 3.50 DRILL P PROD2 Drill ahead from 9926' to 9980 ft 3700 psi fs at 1.51 in/out. 200-300 psi mtr wrk. 1-1.5k# dhwob I N C/TF/AZM: 100.3/18.5/1308 ROP: 30-50 fph. 06:00 - 08:00 2.00 DRILL P PROD2 Drill ahead from 9980 ft. Op = 1.49 / 1.48 bpm at 3828 psi off bottom Delta P 200-300 psi DHWOB = 1.0-1.5 klb I NClTF/AZM: 100.3/18.5/130 R Printed: 6/10/2008 4:15:59 PM ~ ~ BP EXPLORATION Page 31 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date I From - To Hours Task Code I' NPT Phase Description of Operations - - -- 4/27/2008 06:00 - 08:00 2.00 DRILL P PROD2 Built angle up to 10,000 ft and then oriented TF down to achieve 90 deg ROP: 10-30-50 fph. Started mud swap, pumped 50 bbls down CT 08:00 - 09:02 1.03 DRILL P PROD2 Wiper trip while conducting mud swap 09:02 - 11:35 2.55 DRILL P PROD2 Drill ahead from 10052 ft to . Op = 1.50 / 1.50 bpm at 3825 psi off bottom Delta P 200-300 psi DHWOB = 1.0-1.5 klb Built angle up to 10,000 ft and then oriented TF down to achieve 90 deg ROP: 10-30-50 fph. Started mud swap, pumped 50 bbls down CT. Back into sand at 10,055 ft API improved and good separation in resisitivity tool. Climb back up to level out in the sand. Filter in harline plugged, open bypass and cleaned out rock catcher. Back in the sand at 10,075 ft 11:35 - 12:45 1.17 DRILL P PROD2 Drill ahead from 10150 ft to 10,200 ft Op = 1.48 / 1.44 bpm at 3825 psi off bottom Delta P 200-300 psi DHWOB = 0.5 to1.0 klb TF at 90L HS Conducted 100 ft wiper trip due stacking. 12:45 - 14:12 1.45 DRILL P PROD2 Wiper trip up, clean RIH and set down at 9980 ft. Shale TF correct, RIH at reduced Op and RIH without much problem. 14:12 - 17:40 3.47 DRILL P PROD2 Drill ahead from 10,200 ft to 10,350 ft Drilling with -6,800 LB CTD wt Op = 1.50 / 1.46 bpm at 3944 psi off bottom Delta P 200-300 psi DHWOB = 0.5 to1.0 klb DHBHP = 4138 psi ECD 12.11 ppg TF at 90L HS Drilling in 50-70 API sand and good separation in Rest tool 17:40 - 19:00 1.33 DRILL P PROD2 Wiper trip to 9350 ft (Billet). Hole smooth. 19:00 - 20:45 1.75 DRILL P PROD2 Drill ahead. 3820 psi fs at 1.51 in/out. 150-250 dpsi TD well at 10,500'. 20:45 - 00:00 3.25 DRILL P PROD2 Make liner clean out trip to 7000', into liner. Ream hole at 9065'. Cleaned up. Shales at 8175 acting up. OK with pumps off. 4/28/2008 00:00 - 00:30 0.50 DRILL P PROD2 Log gr tie in from 7570'. Add 3' correction. 00:30 - 02:15 1.75 DRILL P PROD2 Make wiper trip back to bottom. Maintain TF and shut do pump as required at window & billets. Tag bottom at 10,402'. 02:15 - 04:30 2.25 DRILL P PROD2 Pump and spot 2 ppb new flo pro bead pill. Circulate at min rate out of hole. Lay in pill to 8000'. 04:30 - 05:45 1.25 DRILL P PROD2 Displace well to 11.8 KWF from 8050'. Monitor BHP during displacement. 05:45 - 07:20 1.58 DRILL P PROD2 Circulate out of hole. Flow check at 6600 ft with 11.8 ppg Naar around. No flow. POOH 07:20 - 07:30 0.17 DRILL P PROD2 Tagged up and monitor well 07:30 - 08:45 1.25 P LNR2 RU to run liner and PJSM 08:45 - 13:18 4.55 P LNR2 PU and RIH with liner as per Summary. PU Coiltrac with GS and knuckle joint. Pull tesed GS (OK) 13:18 - 15:00 1.70 P LNR2 RIH Wt check at 8,800 ft 23k up and 12 k down. RIH and set Printed: 6/10/2008 4:15:59 PM ~ ~ BP EXPLORATION Page 32 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code NPT Phase ', Description of Operations 4/28/2008 13:18 - 15:00 1.70 P LNR2 down at 8,080 ft and fell through. RIH and tagged hard at 9,090 ft. Tried several things to get past. Inc WHP to 500 psi and still trying to get past 9090 ft (hard) 15:00 - 16:00 1.00 N DPRB LNR2 Working to get past 9,090 ft. Hitting hard at 9090 ft, picks up clean. Tried several things to get past. Inc WHP to 500-700 psi and still trying to get past 9,090 ft (hard) PU 200 ft and tried to past. Tagging at the same place 9,090 ft TOL at 6,719 ft 16:00 - 17:30 1.50 N DPRB LNR2 POOH 17:30 - 18:30 1.00 N DPRB LNR2 Set injector back. PUH with BHA to look at Deployment sleeve and GS Deployment sleeve and GS. These have no marks from anything external. 18:30 - 22:30 4.00 N DPRB LNR2 Crew change. Hold PJSM. Pull and lay down liner in singles in pipe shed. The nose portion of the indexing shoe was hand tight. This should not have affected not getting the liner past 9090'. All liner joints and threads appear to be in good condition. 22:30 - 00:00 1.50 N DPRB LNR2 Hold PJSM. Open and check lower ram cavities for cuttings and/or shavings. 4/29/2008 00:00 - 02:00 2.00 N DPRB LNR2 Continue to inspect ram cavities and rams. Lower pipe ram cavities had a lot of cuttings. 2-3/8" combi ram seals were found damaged, and replaced. 02:00 - 08:30 6.50 N DPRB LNR2 Test all BOP equipment as per PTD and RPs. Annular failed the BOP test 08:30 - 12:00 3.50 N RREP LNR2 Replace the element that failed during BOP test Tested and OK 12:00 - 14:30 2.50 N LNR2 PJSM and PU Injector and stab on well. PT the stripper and inner reel valve as per AOGCC. 14:30 - 15:30 1.00 N LNR2 Mu clean out BHA assemby. 1.1 deg mtr with bi-center bit on Inteq tools. 15:30 - 18:15 2.75 N LNR2 Run in hole. Unable to maintain displacement rtns. BHP is following pressure schedule. 18:15 - 19:30 1.25 N LNR2 Displace KWF from well with 9.4 flo pro at 7500'. 0.45 in/0.41 out at 2000 psi. 19:30 - 20:00 0.50 N LNR2 Log tie-in to GR at 7548', corr -13.4'. RIH thru window, clean 20:00 - 20:50 0.83 N LNR2 Wiper in hole using choke and adjusting TF as necessary. Wlper from 8800' 1.51/3640 w/ 100 psi whp w/ 4270 psi dhp=12.51 ECD at 24'/min. Had no weight loss at 9090'. Noted excessive fine shale at shaker and verified by a 0.4-0.5 ppg difference between the in and out MM's 20:50 - 22:05 1.25 N LNR2 Continue wiper to TD at 1.51/3650 at 25'/min. Set downs w/ corresponding 20 min each cleanouts at 9500' and 10000'. Rest of hole was clean to tag at 10400' 22:05 - 23:00 0.92 N LNR2 Wiper to window was clean to 9062' and then got hung up. Get free w/min rate and whp. 23:00 - 23:45 0.75 N LNR2 Ream and backream 9062' and were only able to clean out to 9077'. PU's were fairly clean, but unable to drill or spud ahead due to stalling and minor packing off 23:45 - 00:00 0.25 N LNR2 Resume wiper to window 4/30/2008 00:00 - 00:30 0.50 DRILL N LNR2 Wiper back in hole from window wo/ pump to 8325'. Start pump and unable to get deeper. Hole is sticky and having 15k OP's. Packing off when pumping. No MW, can't make hole, acts like gumbo above BHA 00:30 - 01:00 0.50 DRILL N LNR2 POH thru window. Circ thru bit 1.5/3600 to clean off BHA while Printed: snoizooe arias NM • BP EXPLORATION Operations Summary Report Legal Well Name: 1 R-01 Page 33 of 35 ~ Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To !Hours Task Code NPT Phase Description of Operations 4/30/2008 00:30 - 01:00 0.50 DRILL N 01:00 - 01:25 0.42 DRILL N 01:25 - 01:50 0.42 DRILL N 01:50 - 02:50 I 1.001 DRILL I N 02:50 - 04:00 I 1.171 DRILL I N 04:00 - 05:00 I 1.001 DRILL I N 05:00 - 06:30 I 1.501 DRILL I N 06:30 - 07:00 0.50 DRILL N 07:00 - 08:00 1.00 DRILL N 08:00 - 12:00 4.00 CASE N 12:00 - 14:00 2.00 CASE N 14:00 - 19:30 5.50 CASE N 19:30 - 21:30 2.00 CASE N 21:30 - 22:00 I 0.501 CASE I N 22:00 - 22:15 0.25 CASE N LNR2 22:15 - 22:40 0.42 CASE N LNR2 22:40 - 00:00 1.33 CASE N LNR2 5/1/2008 00:00 - 01:30 1.50 CASE N LNR2 01:30 - 01:40 0.17 CASE N LNR2 01:40 - 04:20 2.67 CASE N LNR2 PUH to log Log tie-in down from 7548', corr +4' RIH thru window w/o pump to set down at 8210' w/ 800 psi whp and can't get by. Have to RIH w/o pump at 60'/min to get past 8210'. Had setdowns from 8350'. Attempt to ream in hole and just stack out each time. Resume RIH at high speed w/o pump and go to 8500' setdown. Start pump and cannot wash in hole due to stacking out. Attempt to backream and are packed off POH slow w/ 5-20k overpulls. Very sticky. Holding 300 psi whp while pump 0.5 bpm and dhp is 4600 psi due to packing off. Gradually get all returns back and dhp returned to normal 4100 psi=12.6 ECD while pull slow thru B Shale. Pull thru window Begin circ 1.65/4010 thru bit while discuss. Need to run liner soon, wellbore is stressed out Open EDC. Recip and circ 2.0/4400 while reposition vac trucks Swap to 11.7 ppg Naar KW F down the CT 1.83/4000 POOH for liner while fin swapping wellbore above 8030' to 11.7# Naar. Overpull at 6720' and stop. RBIH, okay At surface. Check well for flow. Hold PJSM to discuss handling BHA and running liner. LD clean out BHA. MU 70 jts 2-3/8" STL liner (5 solid on top, 64 slotted, 1 solid jt on btm) Unlaod CSH from lowboy (had to rent pipe from Baker as Nordic 1 has Nordic 2's 1"CSH stood back in their derrick). Load 1"CSH pipe into pipeshed. Strap pipe. Hold PJSM to review running CSH. Rig up floor. MU and run 1"CSH with stinger. PJSM/crew change. Fin run 3 jts CSH. Space out. Pull a full joint and lay it down and note that the connection was hand tite. POOH LDDP. All connections can be broken using a 24" wrench with minimal effort Find that the Little Jerks calibration had been recently checked (DIMS 4/10/08) and were within spec. Determine that the connection from the manifold that supplies hyd pressure to the LJ's was not giving the correct pressure/rate since the valve to the injector pull-back winch was also open (the third hyd loop in the system that goes to the deployment winch was closed) Remove false table, change elevators. Pull one joint of 2-3/8" STL liner. Check MU and was easily broken w/ two 36" pipe wrenches Safety mtg re : LD liner LD 2-3/8" STL liner Replace blown hyd hose to W's Finish TOH w/ 2-3/8" STL liner Safety mtg re: MU liner MU 2-3/8" Unique Indexing Guide Shoe, one solid jt, O-ring sub, 64 jts 2-3/8" 4.6# L-80 STL R2 slotted liner and 5 jt 2-3/8" LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 Printed: 6/10/2008 4:15:59 PM • BP EXPLORATION Page 34 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: I Gode NPT Phase Description of Operations Date From - To Hours Task 5/1/2008 01:40 - 04:20 2.67 CASE N LNR2 STL solid liner to 1250#. Check MU w/ pipe wrenches occasionally 04:20 - 04:35 0.25 CASE N LNR2 PJSM. RU to run inner string. RU false table. Change elevators. Fill hole w/ 4 bbls 04:35 - 08:00 3.42 CASE N LNR2 MU 1"CSH on BTT stinger. Space out CSH with pups. MU deployment sleeve. 08:00 - 09:30 1.50 CASE N LNR2 Hold PJSM to review MU of Inteq tools. PU tool string and MU to liner assembly. Stab coil. Get on well. 09:30 - 11:30 2.00 CASE N LNR2 Run in hole. Maintain 12.0-12.7 ECD. 26k# up wt, 12k# do at 8000'. 11:30 - 14:15 2.75 CASE N LNR2 Run in open hole. Smooth to 9090'. Set do hard. Work pipe. Vary running speed. Hard btm with no additional ffg gained. Increase WHP to 500 psi or btm hole ECD: 12.5 ppg. Increase WHP to 1000, then 1300 psi: 14.5 ppg. Formation taking fluid at this pressure. RIH at each of these WHP's. Keep running at it hard. Popped through at 110 FPM. Continue to RIH to 10,250'. 36k# up wt. Bleed well head pressure to zero. Line up to circ down coil. 4100 psi at 1.05 bpm. PU and release from liner (21 k# up). 14:15 - 15:00 0.75 CASE P LNR2 Pull up hole to log GR tie in. Log do from 7500'. Subtract 14' correction. Top of liner is at 8022'. Liner btm is at 10,236'. 15:00 - 16:30 1.50 CASE P LNR2 Pull out of hole to place CSH btm at 8000'. Displace coil to 11.8 KWF. 16:30 - 18:00 1.50 CASE P LNR2 Pull out of hole. Replace voidage with KWF. 18:00 - 18:30 0.50 CASE P LNR2 At surface. Flow check well. Crew change/PJSM 18:30 - 19:45 1.25 CASE P LNR2 Set injector on legs. LD BTT CTLRT. LD BHI MWD tools 19:45 - 22:15 2.50 CASE P LNR2 PJSM. RU floor tools. POOH LD 1" CS Hydril workstring. LD stinger. Load out BTT tools. Clean floor of Naar 22:15 - 22:40 0.42 CASE P LNR2 PJSM. MU 2.25" nozzle assy 22:40 - 00:00 1.33 CASE P LNR2 RIH w/ nozzle assy circ 0.4/1300 w/ SW 5/2/2008 00:00 - 00:20 0.33 CASE P LNR2 Fin RIH to 8000' 16.5k while displ CT to SW and take 11.8# returns to vac truck 00:20 - 02:00 1.67 CASE P LNR2 POOH from 8000' while displacing wellbore to SW 1.35/2350 following pressure schedule. Fin POOH while displace top 2000' of wellbore to diesel. SIP=1335 psi. SI SV's MIRU SWS N2 02:00 - 02:30 0.50 RIGD P POST Prep to corrosion inhibit the CT while conduct safety mtg. Begin 50 bbls FW down CT while displ SW to tiger tank 0.38/100 02:30 - 05:00 2.50 RIGD P POST N2 crew fix problem w/ gauge on truck (1/2 hr) and then cool down. Finish CT corrosion inhibition. PT N2 ~ 4000 psi. Blow down CT w/ N2 and take returns to tiger tank. RDMO SWS N2 05:00 - 05:15 0.25 RIGD P POST Load out BHI MWD 2" BHA and load in 2-3/8" tools 05:15 - 05:25 0.17 RIGD P POST Safety mtg re: pull CT back to reel 05:25 - 06:00 0.58 RIGD P POST Remove injector from well. LD stinger BHA. Cut off CTC and install internal grapple and PT 06:00 - 06:30 0.50 RIGD P POST Crew change/PJSM to discuss unstabing coil. Make rounds on rig. 06:30 - 11:00 4.50 RIGD P POST Spool coil back through injector and on to reel. Secure coil on Printed: 6/10/2008 4:15:5y F'M BP EXPLORATION Page 35 of 35 Operations Summary Report Legal Well Name: 1 R-01 Common Well Name: 1 R-01 Spud Date: 4/1/2008 Event Name: REENTER+COMPLETE Start: 3/24/2008 End: 5/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/2/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 5/2/2008 06:30 - 11:00 4.50 RIGD P POST reel. Change out BOP rams from 2" to 2-3/8" for pipe size change. 11:00 - 14:00 3.00 RIGD P POST Hold PJSM with CHILL to review removing 2" reel. Reel removed and transported to 2D pad. Continue to work on BOPS. Pressure test body to 4500 psi. Continue to haul off equipment. Clean cuttings box with super sucker. 14:00 - 16:15 2.25 BOPSU P POST Hold PJSM with crew and FMC. PU and MU lubricator. Re-measure to tbg spool lock downs. Test lubricator to 1500 psi. Open well. Found 400 psi WHP. Set BPV. Bleed stack to verify holding. Good. RD and LD lubricator. 16:15 - 22:00 5.75 RIGD P POST Hold PJSM with crew. Review ND procedure. ND BOPs. NU tree cap and PT ~ 4000 Rig Released at 2200 hrs 5/2/200 22:00 - 00:00 2.00 DEMOB P POST Move rig off well and down the Pad. PU rig mats, Handy-Berm, general cleanup Perform location inspection w/ DSO Future entries will be found under 3F-16 rnn~eo: on wzuuu a: i oaa rm ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 R Pad 1 R-01 1 R-01 BL1 PB1 TD Design: 1 R-01 BL1 PB1 TD Baker Hughes INTEQ Survey Report 08 Nlay, 2008 r~~r BAKER N~1~NES INTEQ f ConocoPhillips Alaska Cpmp~srgr: ConocoPhillips(Alaska) inc. Projeck Kuparuk River Unit Sits; Kuparuk 1R Pad WeN: 1 R-01 WsNbore: 1 R-01 BL1PB1 TD ' Design: 1 R-01 BL1 P61 TD ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-0rdinate Reference: Well 1R-01 NORe~erence: 1R-O1(~82.OOft (1R-01) , MD Reference: 1R-U1 ~82.O~t(1R-01) North Reference: True Survey Calculation Method: Minanum Curvature Database: EDMv16 Prod INTEQ Project Kuparuk River Unit, North Slope Alaska Map $ysbm: US State Plane t927 (Exact solution) System Datum: Mean Sea Level G~ pagyn; NAD 1927 (NADCON CONUS) Using WeN Reference Point Map Zone; Alaska Zone 04 Using geodetic scale factor :Sits Kuparuk 1 R Pad gib Position: Northing: 5,991,050.01 ft Latitude: 70° 23' 11.370 N From: Map Fasting: 539,829.93 ft Longitude: 149° 40' 33.803 W Positbn Uncertainty: 0.00 ft Slot Radius: o " Grid Convergence: 0.31 ° yleS i R-01 Weg p~lpn +W-S 0.00 ft Northing: 5,991,050.09 ft LatlGute: 70° 23' 11.371 N +EIdAI 0.00 ft Fasting: 539,829.76 ft Longtude: 149° 40' 33.808 W Positlon tHwertadnty 0.00 ft WelUread Elevation: ft Ground Level: 0.00 ft y 1R-OtBL1PB1 TD ilagtugics Model Marne Sample Dete Daclfnatlon Dlp Angle Fiekf Strength t°! 1°I toil BGGM2007 4/10/2008 17.81 79.79 57,282 Design 1R-01BL1P61 TD Audit Nobs: Yersbn: 1.0 Phase: ACTUAL Tie On Depth: 8,078.56 Yertlcal 8ectloa: Depth From (ND) +NI-S +EI-W Direction (~! (~! lft! t°! 82.00 0.00 0.00 116.21 5/8/2008 4:45:30PM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Compar-y: ConocoPhiNips(Alaska) Ina proJact Kuparuk River Unit Sloe: Kuparuk 1R Pad iWeit: 1 R-01 WeHbora: 1R-0tBL1P61 TD Desiga: 1R-0tBL1PBt TD ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: r Survey Calculatbn AAethod: Database: Well 1 R-01 1R-O1 @ 82.OOft(1R-01) 1 R-01 @ 82.OOft (1 R-0 t ) True Minimum Curvature EDMv16 Prod ~c.r B'~u~s INTEQ Survey t'rogrxn Date Fran To (fq (1t) Survey (VUellbore) Tool Name Description 100.00 8,300.00 1 R-01 (1 R-01) GCT-MS Schlumberger GCT multishot 6,397.80 8,078.56 1R-01A (1R-01A) MWD MWD -Standard 8,085.00 8,116.24 1R-018L1PB1 MWDTD(1R-01BL1P61 T MWD MWD-Standard Survey MD tnc AZl TYDSS NJS t1W Northing Fasting DLS VeNcal Sectiop TFO 8,078.56 74.05 179.16 6,510.98 -1,453.36 3,131.06 5,989,613.57 542,988.20 12.15 3,451.01 32.58 8,085.00 74.75 179.03 6,512.69 -1,459.56 3,131.15 5,989,607.37 542,968.33 11.04 3,453.84 -10.18 8,116.24 77.22 179.03 6,520.26 -7,489.86 3,131.67 5,989,577.07 542,969.01 7.91 3,467.69 0.00 8,170.00 77.22 179.03 6,532.15 -1,542.28 3,132.55 5,989,524.66 542,970.17 0.00 3,491.64 0.00 ~ Checked By: Approved By: Date: ~ 5/8/2008 4:45:30PM Page 3 COMPASS 2003.188ui1d 42F ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 R Pad 1 R-01 1 R-01 BL1 TD Design: 1 R-01 BL1 TD Baker Hughes INTEQ Survey Report Os May, 2008 ~~.,~r BAKER Nu+~NE~ INTE(~ n ConocoPhillips Alaska Cgnpsrry; ConocoPhdtips(Alaska) Ina Proj~ Kuparuk River Unit $ite: Kuparuk 1 R Pad WeN: 1 R-01 Wetlbore: 1R-01BL1 TD Design: 1R-01BL1 TD ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: Well 1 R-01 ND Reference: 1 R-01 (~ 82.OOft (1 R-0t ) MD Reference: 1 R-01 @ 82.OOft (1 R-01) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod J ~.r s ~eiiles INTEQ Project Kuparuk River Unit, North Slope Alaska Map system: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level (gyp p~nr; NAD 1827 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Ske Kuparuk 1 R Pad g~ pear; Nortlring: 5,991,050.01 ft Latitude: 70° 23' 11.370 N From: Map Easting: 539,829.93 ft Longitude: 149° 40' 33.803 W Posfhon Uncertainty: 0.00 ft Slot Radius: 0 " Grid Convergence: 0.31 ° WsY 1R-01 WeN Posklon +W-S 0.00 ft NoAtdng: 5,991,050.09 ft Latfttrde: 70° 23' 11.371 N +EI-W 0.00 ft Easting: 539,829.76 ft Longkude: 149° 40' 33.808 W Positlar lNrcertainty 0.00 ft Wellhead Elevatbn: ft Ground LevN: 0.00 ft Wait 1R-01BL1 TD ModN Name Sample Data DecUnation Dip Angle Field Strength BGGM2007 4/612008 17.82 79.79 57,282 1R-0t8L1 TD Audk Notes: Version: 1.0 Phase: ACTUAL Tle On Depth: 8,049.74 1lertical Sectlgrt: Depth Fran {ND) +N/-S +E/-W Direction ffH l~) (ftl CI s2.oo o.oo o.o0 10.00 58/2008 4:52:57PM Paga 2 COMPASS 2003.16 Build 42F ConocoPhillips Alaska ConocoPhillips Baker Hughes INTEQ Survey Report Company: ConocoPhillips(Alaska) Ina Local Co-ordinato Retsrance: Well 1 R-Ot Kuparuk River Unit TVD Reference: 1R-O1 ~ 82.OOft (1R-Ot) Site: Kuparuk tR Pad AAD Reference: 1R-01 ~ 82.OOk(1R-Ot) Weu: t R-01 North Reference: True iNNlbort: 1R-OtBL1 TD Survey Calculation Method: Minimum Curvature Desiam 1R-01BL1 TD Database: EDMv16 Prod ~.r B W ~R 8uroyr Program Date Ftprp To 1~ lri) Survey (WleNbore) Tool Name Descriptloa 100.00 6,300.00 1R-01 (1R-01) GCT-MS SchlumbergerGCTmultishot 6,397.90 8,049.74 1R-OtA(1R-OtA) MWD MWD-Standard 8,055.00 9,665.06 1R-016L1 TD (1R-O1BL1 TD) MWD MWD-Standard Survey tied Inc Asl TVDSS WS EIW Northing Easdng DLS Verltcai Section TFO 8,048.74 71.09 177.20 6,502.33 -1,425.88 3,130.19 5,989,641.04 542,967.19 21.52 -860.67 -41.69 8,055.00 71.63 177.56 6,504.01 -1,430.86 3,130.41 5,989,636.06 542,967.44 12.14 -865.53 32.34 8,085.42 66.07 191.01 6,515.02 -1,459.06 3,128.36 5,989,607.85 542,965.54 45.07 -893.66 116.24 8,115.49 66.22 204.22 6,527.23 -1,485.20 3,120.06 5,989,581.68 542,957.38 40.17 -920.84 91.97 8,146.09 68.10 216.91 6,539.15 -1,509.40 3,105.74 5,989,557.40 542,943.19 38.70 -947.16 83.38 8,175.11 70.03 225.84 6,549.54 -1,529.70 3,087.84 5,989,537.00 542,925.40 29.49 -970.27 78.60 8,206.43 73.51 233.01 6,559.34 -1,549.02 3,065.26 5,989,517.57 542,902.92 24.41 -993.21 64.09 8,246.41 76.56 244.30 6,569.70 -1,569.05 3,032.32 5,989,497.36 542,870.09 28.32 -1,018.66 75.88 8,277.90 77.51 254.73 6,576.78 -1,579.77 3,003.61 5,989,486.49 542,841.45 32.42 -1,034.20 85.85 8,309.42 81.04 267.57 6,582.67 -1,584.50 2,973.08 5,989,481.60 542,810.95 41.55 -1,044.16 75.63 8,340.60 82.10 281.07 6,587.26 -1,582.18 2,942.40 5,989,483.76 542,780.26 42.96 -1,047.20 86.48 8,371.57 83.02 293.47 6,591.29 -1,573.08 2,913.14 5,989,492.70 542,750.95 39.81 -1,043.32 86.54 8,402.31 86.35 303.22 6,594.14 -1,558.56 2,886.24 5,989,507.08 542,723.98 33.38 -1,033.69 71.57 8,432.66 88.83 312.71 6,595.42 -1,539.93 2,862.37 5,989,525.58 542,700.00 32.29 -1,019.49 75.58 8,463.22 91.72 320.80 6,595.27 -1,517.69 2,841.45 5,989,547.71 542,678.97 28.11 -1,001.22 70.35 6,493.42 93.87 328.12 6,593.80 -1,493.16 2,823.93 5,989,572.14 542,661.32 25.23 -980.11 73.46 8,522.93 95.65 339.63 6,581.34 -1,466.80 2,811.00 5,989,598.42 542,648.25 39.33 -956.40 80.73 8,554.48 95.29 351.38 6,588.32 -1,436.45 2,803.15 5,989,628.73 542,640.24 37.09 -927.87 91.18 8,604.28 94.27 5.63 6,584.15 -1,386.97 2,801.86 5,989,678.19 542,638.69 28.59 -879.36 93.49 8,638.87 95.47 9.04 6,581.21 -1,352.80 2,806.26 5,989,712.39 542,642.91 10.42 -844.94 70.41 u 58/2008 4:52:57PM Page 3 COMPASS 2003.16 Build 42F '/ ConocoPhillips ConocoPhiliips Baker Hughes INTEQ Survey Report Cerny: ConocoPhtllips(Alaska) InG. Local Co-ordieate ReferencB: Well 1 R-Ot Prpjapr Kuparuk River Unit ND Reference: 1R-01 ~ 82.90ft (1R-Ot) obi: Kuparuk 1 R Pad MD Reference: 1 R-01 ~ 82:OOft (1 R-01) ilY~: 1R-01 Nortlr Reference: True yYYUbfuq: 1R-01BL1 TD Survey Calculation Method: Minimum Curvature Deslgr-: 1R-01BL1 TD Database: EDMv16 Prod ~.r INTEQ 511fVey.. 11D Inc Azi TVOSS N!S FJW Northing Fasting DLS Yerdcel Seetbn TFD t~) 1°! ~') (+~) (ft) (ff) !R) fft) t°It®Oft) (tq {`) 8,670.69 94.39 11.66 6,578.48 -1,321.61 2,811.96 5,989,743.60 542,648.44 8.88 -813.24 112.36 8,688.47 84.12 14.83 6,576.34 -1,283.68 2,818.53 5,989,771.57 542,654.86 11.02 -784.59 94.76 8,734.10 92.61 17.15 6,574.31 -1,260.45 2,828.05 5,989,804.84 542,664.21 7.98 -750.21 123.03 8,773.54 92.37 21.23 6,572.60 -1,223.24 2,841.00 5,989,842.11 542,676.96 10.35 -711.32 93.28 8,805.36 92.89 24.47 6,571.14 -1,193.96 2,853.35 5,889,871.46 542,689.14 10.30 -680.34 80.80 8,841.48 92.61 28.52 6,569.40 -1,161.66 2,869.44 5,989,903.64 542,705.07 11.22 -645.74 93.86 8,873.34 92.08 30.46 6,568.10 -1,133.97 2,885.11 5,989,931.62 542,720.58 6.30 -615.74 104.98 8,904.44 94.45 32.92 6,566.32 -1,107.55 2,901.41 5,989,958.12 542,736.75 10.95 -586.90 46.08 8,943.30 89.69 32.05 6,564.92 -1,074.80 2,922.27 5,989,990.97 542,757.42 12.45 -551.03 -169.63 8,973.23 88.83 34.73 6,565.31 -1,049.81 2,938.73 5,990,016.04 542,773.75 9.40 -523.56 107.81 9,004.37 88.56 37.66 6,566.01 -1,024.69 2,957.12 5,990,041.26 542,792.00 9.45 -495.63 95.30 9,036.55 87.60 40.60 6,567.09 -999.75 2,977.41 5,990,066.31 542,812.16 9.61 -467.54 108.14 9,069.57 89.54 43.02 6,567.92 -975.15 2,999.41 5,990,091.03 542,834.03 9.39 -439.49 51.31 8,100.43 82.09 43.62 6,567.48 -952.70 3,020.58 5,990,113.58 542,855.08 8.49 -413.71 13.24 8,134.71 93.75 44.94 6,565.73 -928.19 3,044.48 5,990,138.22 542,878.84 6.18 -385.42 38.42 9,168.53 95.23 47.25 6,563.08 -904.81 3,068.77 5,990,161.72 542,903.01 8.09 -358.18 57.19 9,201.31 97.26 50.26 6,559.52 -883.33 3,093.27 5,990,183.33 542,927.38 11.03 -332.77 55.69 9,229.73 95.90 52.75 6,556.26 -865.76 3,115.36 5,990,201.02 542,949.38 9.93 -311.63 118.66 9,261.31 92.67 55.74 6,553.90 -847.36 3,140.91 5,990,219.55 542,974.83 13.92 -289.08 137.17 9,290.70 90.71 58.12 6,553.03 -831.34 3,165.53 5,990,235.70 542,999.36 10.49 -269.02 129.44 9,320.61 90.77 62.41 6,552.65 -816.51 3,191.49 5,990,250.67 543,025.24 14.34 -249.90 89.17 9,351.74 90.52 65.23 6,552.30 -802.77 3,219.42 5,990,264.55 543,053.10 9.09 -231.53 95.05 9,380.18 90.09 68.91 6,552.15 -791.70 3,245.61 5,990,275.77 543,079.22 13.03 -216.07 96.65 9,415.27 89.60 72.01 6,552.24 -779.96 3,278.68 5,990,287.88 543,112.22 8.94 -198.78 98.98 9,452.52 88.83 67.64 6,552.75 -767.12 3,313.63 5,990,300.70 543,147.10 17.81 -180.06 -100.02 9,482.91 86.65 64.99 6,553.95 -754.82 3,341.43 5,990,313.05 543,174.84 11.29 -163.22 -128.51 9,511.73 84.56 62.14 6,556.16 -742.13 3,367.16 5,990,325.97 543,200.49 12.24 -146.16 -126.44 C~ 5/8/2008 4:52:57PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc Project.' Kuparuk River Unk Site: Kuparuk 1R Pad iNed: 1 R-01 Wai~ore: 1R-018L1 TD pesign: 1R-01BL1 TD ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: Well 1 R-Ot iVD Reference: 1 R-01 ti8 82.00ft (1 R-O t ) MD Reference: 1 R-01 ~ 82.OOft (1 R-01) North Reference: True Survey Calculatlon Method: Minimum Curvature Database: EDMv16 Prod .- ~.r INTEQ SYtMay AID hx Azi NDSS N/S E/W Northing EastMg DLS Vertkat Section 7FO tit} 1°! 1°! IW Iit- Iff- (~! Iftl !°N~! !~ {'} 8,544.56 83.38 58.63 6,559.61 -726.00 3,395.54 5,990,342.25 543,228.78 11.22 -125.34 -108.86 9,575.85 83.51 55.36 6,563.18 -709.07 3,421.61 5,990,359.32 543,254.76 10.39 -104.14 -87.90 9,605.84 84.00 52.08 6,566.44 -691.43 3,445.63 5,990,377.08 543,278.69 10.99 -82.60 -81.63 9,635.29 83.17 48.53 6,569.74 -672.75 3,468.15 5,990,395.89 543,301.10 12.31 -60.29 -103.43 9,665.06 83.14 .44.82 6,573.29 -652.47 3,489.65 5,990,416.28 543,322.49 12.37 -36.59 -90.69 9,730.00 83.14 44.82 6,581.04 -606.74 3,535.10 5,990,462.25 543,367.69 0.00 16.35 0.00 i •I 5/8/2008 4:52:57PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Iqc. project Kuparuk River Unit Site: ' Kuparuk 1 R Pad WeB: 1R-01 WelMore: 1R-01BL1 TD D~siga: 1R-018L1 TD ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordirwte Reference: 7VD Reference: MD Reference: North Reference: Survey CaicutaUon Meltwd: Datatxse: Well 1 R-O t 1 R-01 @ 82.OOft (1 R-01) 1R-01 «~ 82.OOft (1R-Ot) True Minimum Curvature EDMv16 Prod ~.r sw~ Taogals Target Name - hifltniss forgot .Dip Angle Dip Dk. ND +N/S AEI-W Nortlthtg Fasting - ~'~ t°I ('- (fU (8) Iftl ItU (~) l.agwde Longitude 1R-01BL1 Fault 4a 0.00 0.00 82.00 -067.95 3,339.06 5,990,400.00 543,172.00 70° 23' 4.794 N 149° 38' 56.062 W - actual welipath misses by 6549.68ft at 8049.74ft MD (6584.33 ND, -1425.88 N, 3130.19 E) - polygon Point 1 82.00 -667.95 3,339.06 5,990,400.00 543,172.00 Point 2 82.00 -729.60 3,460.75 5,990,339.00 543,294.01 Point3 82.00 -894.20 3,571.89 5,990,175.01 543,406.01 Point 4 82.00 -729.60 3,460.75 5,990,338.00 543,294.01 1R-018L1 Fauk 1a 0.00 0.00 82.00 -1,398.80 2,732.10 5,989,666.00 542,569.00 70° 22' 57.609 N 149° 39' 13.837 W - acWal we8path misses by 6514.568 at 8049.748 MD (6584.33 ND, -1425.88 N, 3130.19 E) - Paypat Point 1 82.00 -1,398.80 2,732.10 5,989,666.00 542,569.00 Point 2 82.00 -1,410.19 2,805.05 5,989,655.00 542,642.00 Point 3 82.00 -1,434.90 2,939.93 5,989,631.01 542,777.00 Point4 82.00 -1,410.19 2,805.05 5,989,655.00 542,642.00 1R-018L1 Target 6 0.00 0.00 6,639.00 -739.70 3,499.18 5,990,329.10 543,332.49 70° 23' 4.088 N 149° 38' 51.375 W - actual weUpath misses by 71.928 at 9615.108 MD (6649.43 ND, -685.71 N, 3452.84 E) - Point 1R-016L1 Fault 5 0.00 0.00 82.00 -396.75 3,496.52 5,990,672.00 543,328.00 70° 23' 7.460 N 148° 38' 51.448 W - actual wellpath misses by 6565.568 at 9482.91ft MD (6635.95 ND, -754.92 N, 3341.43 E) - Paygon Point 1 82.00 -396.75 3,496.52 5,990,672.00 543,328.00 Point 2 82.00 -397.37 3,613.53 5,990,672.00 543,445.00 Point 3 82.00 -397.98 3,730.54 5,990,672.02 543,562.00 Point 4 82.00 -397.37 3,613.53 5,990,672.00 543,445.00 1R-01BL1 Target 7 0.00 0.00 6,631.00 -460.19 3,594.68 5,990,609.10 543,426.49 70° 23' 6.836 N 149° 38' 48.576 W - actual weNpath misses by 161.41ft at 9730.OOft MD (6663.04 ND, -006.74 N, 3535.10 E) -Pant 1R-016L1 Fauk 4 0.00 0.00 82.00 -774.92 3,144.47 5,990,292.00 542,978.00 70° 23' 3.743 N 149° 39' 1.759 W - actual weUpath misses by 8534.858 at 8049.74ft MO (6584.33 ND, -1425.88 N, 3130.19 E) - PplY9pn Pant 1 82.00 -774.92 3,144.47 5,990,292.00 542,978.00 Point2 82.00 -857.72 3,295.05 5,990,210.01 543,129.00 Point3 82.00 -1,010.99 3,532.27 5,990,058.02 543,367.01 5/82008 4:52:57PM Page 6 COMPASS 2003.16 Build 42F Conoco hillips Alaska Campaoy: ConocoPh~lips(Alaska) Inc. pttiyJaC1~ Kuparuk River Unit Ske: , Kuparuk 1R Pad 1AIeN: 1 R-01 WeUbore: 1R-016L1 TD Deslgn: 1R-01BL1 TD ConocoPhillips Baker Hughes INTEQ Survey Report Local Co~orrNnete Reference: ND Reference: MD Refererue: North Reference: Survey Calculation Method: Database: Well 1 R-01 1 R-01 ~ 82.OOft (1 R-01) 1 R-01 ~ 82.OOft (1 R-01) True Minimum Curvature EDMv16 Prod ".~ , J ~.r s ~tsNes INTEQ Point4 82.00 -857.72 - 3,295.05 - - 5,990,210.01 543,129.00 1R-01BL1 Target 3 0.00 0.00 6,662.00 -1,466.08 2,808.22 5,989,599.13 542,645.48 70° 22' 56.947 N 149° 39' 11.610 W - actual we8path misses by 11.38ft at 8525.41ft MD (6673.10 TVD, -1464.49 N, 2810.16 E) - Point 1R-01BL1 Target4 0.00 0.00 6,649.00 -1,193.15 3,012.71 5,989,873.12 542,848.48 70° 22' 59.630 N 149° 39' 5.621 W - actual wellpath misses by 139.83ft at 8890.OSft MD (6649.30 TVD, -1119.68 N, 2893.73 E) -Point 1R-01BL1 Target 5 0.00 0.00 6,637.00 -1,022.64 3,295.65 5,990,045.11 543,130.48 70° 23' 1.306 N 149° 38' 57.337 W - actual welipath misses by 230.93ft at 9308.78ft MD (6634.80 TVD, -822.14 N, 3181.09 E) -Point 1R-01BL1 Fault 2 0.00 0.00 82.00 -1,230.69 2,714.99 5,989,834.00 542,551.00 70° 22' 59.262 N 149° 39' 14.336 W - actual weNpath misses by 6518.49ft at 8048.74ft MD (6584.33 7VD, -1425.88 N, 3130.19 E) -Polygon Point 1 82.00 -1,230.69 2,714.99 5,989,834.00 542,551.00 Point 2 82.00 -1,253.33 2,836.88 5,989,812.01 542,673.00 Point3 82.00 -1,358.74 3,102.36 5,989,708.03 542,939.01 Point4 82.00 -1,253.34 2,836.88 5,989,812.00 542,673.00 1R-018L1 Target 8 0.00 0.00 6,622.00 -41.20 3,603.92 5,991,028.09 543,433.50 70° 23' 10.957 N 149° 38' 48.299 W - actual we8patii misses by 571.19ft at 9730.OOft MD (6663.04 TVO, -606.74 N, 3535.10 E) - Post 1R-01BL1 Target 1 0.00 0.00 6,595.00 -1,459.81 3,131.30 5,989,607.12 542,968.48 70° 22' 57.007 N 149° 39' 2.153 W - actual we8path misses by 3.60ft at 8085.18ft MD (6596.93 TVD, -1458.85 N, 3128.41 E) - Poa~t 1R-018L1 Polygon 0.00 0.00 82.00 -1,488.74 3,118.14 5,989,578.12 542,955.48 70° 22' 56.723 N 149° 39' 2.539 W -actual weNpath misses by 6502.64ft at 8049.74ft MD (6584.33 TVD, -1425.88 N, 3130.19 E) -Polygon Point 1 82.00 -1,488.74 3,118.14 5,989,578.12 542,955.48 Point 2 82.00 -1,565.15 3,004.72 5,989,501.12 542,842.48 Point 3 82.00 -1,552.74 2,927.78 5,989,513.12 542,765.48 Point4 82.00 -1,463.63 2,908.25 5,989,602.11 542,745.48 Point 5 82.00 -1,331.68 2,920.95 5,989,734.12 542,757.47 Point 6 82.00 -1,214.93 2,970.57 5,989,851.12 542,806.47 Poa~t7 82.00 -1,078.49 3,079.30 5,989,988.12 542,914.46 Poe1t 8 82.00 -978.38 3,249.85 5,990,089.13 543,084.45 PO~t 9 82.00 -882.17 3,402.37 5,990,186.14 543,236.45 Point 10 82.00 -786.59 3,483.88 5,990,282.14 543,317.44 Point 11 82.00 -638.22 3,605.68 5,990,431.14 543,438.43 Point 12 82.00 -473.69 3,698.56 5,990,596.15 543,530.43 5/8/2008 4:52:57PM Page 7 COMPASS 2003.16 Build 42F ConocoPhillips Alaska ConocoPhillips Baker Hughes INTEQ Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1R-Ot Pra~sct; Kuparuk River Unit TYD Reference: 1R-01 ~ 82.OOft (1R-01) Ske; Kuparuk 1R Pad MD Reference: 1R-01 ~ 82.OOft (1R-01) WeN: tR-Ot t+brthRe#erence: True Wetlbore: 1 R-01 BL1 TD Survey Cakulatbn Mettwd: Minimum Curvature Destga: 1R-01BL1 TD Database: EDMv16 Prod .- r~.r ~aNes INTEQ Point 13 82.00 -291.87 3,736.52 5,990,778.15 543,567.41 Point 14 82.00 -62.95 3,757.73 5,991,007.16 543,587.40 Point 15 82.00 130.04 3,762.75 5,991,200.15 543,591.39 Point 16 82.00 364.10 3,755.98 5,991,434.15 543,583.38 Point 17 82.00 529.44 3,695.85 5,991,599.15 543,522.38 Point 18 82.00 525.99 3,591.82 5,991,595.15 543,418.38 Point 19 82.00 517.41 3,510.76 5,991,586.14 543,337.37 Point 20 82.00 296.23 3,541.60 5,991,365.15 543,369.38 Point 2l 82.00 139.02 3,577.78 5,991,208.15 543,406.40 Point 22 82.00 22.92 3,593.17 5,991,092.14 543,422.40 Point 23 82.00 -111.02 3,580.46 5,990,958.15 543,410.41 Point 24 82.00 -303.00 3,571.44 5,990,766.14 543,402.41 Point 25 82.00 -414.89 3,548.85 5,990,654.15 543,380.42 Point 26 82.00 -584.70 3,508.95 5,990,484.14 543,341.43 Point 27 82.00 -726.03 3,379.19 5,990,342.14 543,212.44 Point 28 82.00 -864.73 3,129.43 5,990,202.12 542,963.44 Po~t29 82.00 -944.87 2,963.99 5,990,121.11 542,798.45 Post 30 82.00 -1,085.18 2,830.24 5,989,980.11 542,665.46 PaM31 82.00 -1,298.70 2,736.10 5,989,766.11 542,572.47 Point 32 82.00 -1,519.79 2,746.93 5,989,545.10 542,584.47 Point 33 82.00 -1,665.37 2,855.18 5,989,400.11 542,693.49 Poart 34 82.00 -1,694.50 3,068.05 5,989,372.12 542,906.49 Point 35 82.00 -1,574.08 3,181.70 5,989,493.13 543,019.48 Pant 36 82.00 -1,510.73 3,116.02 5,989,556.12 542,953.47 1R-01BL1 Fault6 0.00 0.00 82.00 311.51 3,461.29 5,991,380.00 543,289.00 70° 23' 14.426 N 149° 38' 52.470 W -actual we8path misses by 6640.95ft at 9511.73ft MD (6638.16 ND, -742.13 N, 3367.16 E) -P~9~ Post 1 82.00 311.51 3,461.29 5,991,380.00 543,289.00 Pant2 82.00 293.48 3,657.22 5,991,363.02 543,485.00 Point 3 82.00 293.28 3,694.22 5,891,363.01 543,522.00 Point4 82.00 293.48 3,657.22 5,981,363.02 543,485.00 1R-01BL1 Target 9 0.00 0.00 6,602.00 551.23 3,534.07 5,991,620.08 543,360.50 70° 23' 16.784 N 149° 38' 50.336 W - adua wegpath mosses by 1159.58ft at 9730.OOft MD (6663.04 ND, -606.74 N, 3535.10 E) -Point 1R-01BLt Fauk 3 0.00 0.00 82.00 -970.99 2,965.40 5,990,095.00 542,800.00 70° 23' 1.815 N 148° 39' 7.003 W - actual we8path misses by 6520.30ft at 8049.74ft MD (6584.33 ND, -1425.88 N, 31 30.19 E) -Pa ~ i • 5/H/2008 4:52:57PM Page 8 COMPASS 2003.16 Build 42F i; S ConocoPhillips Alaska ConocoPhillips Baker Hughes INTEQ Survey Report Company: ConowPh~lips(Alaska) Inc. Locat Co-ordinate Reference: Well 1R-Ot project: Kuparuk River Unit TYD Rstsrence: 1 R-01 (Q 82.OOft (1 R-01) Sites Kuparuk 1 R Pad MD Reference: 1 R-01 ~ 82.OOft (1 R-01) lAtsN: 1 R-01 North Reference: True lN~nbRre: 1R-01BL1 TD Survey Cakulatlon fiAethod: Minimum Curvature Desi~s: 1R-01BL1 TD Database: EDMv16 Prod ~c.r s$ INTEQ Point 1 82.00 -970.99 2,965.40 5,990,095.00 542,800.00 Point2 82.00 -1,022.12 2,989.13 5,990,044.00 542,824.00 Point3 82.00 -1,318.84 3,309.61 5,989,749.02 543,146.02 Point4 82.00 -1,022.12 2,989.13 5,990,044.00 542,824.00 1R-018L1 Target 2 0.00 0.00 6,672.00 -1,643.90 2,959.29 5,989,422.13 542,797.48 70° 22' 55.197 N 149° 39' 7.190 W -actual wellpath misses by 59.76ft at 8319.6911 MD (6666.24 TVD, -1584.54 N, 2962 .94 E) - Point 1R-01BL1 Fauk 1 0.00 0.00 82.00 -1,371.83 2,949.74 5,989,694.12 542,786.48 70° 22' 57.873 N 149° 39' 7.466 W - actual weNpath misses by 6505.OSft at 8049.74ft MD (6584.33 TVD, -1425.88 N, 31 30.19 E) - polygon Point 1 82.00 -1,371.83 2,949.74 5,989,694.12 542,786.48 Point2 82.00 -1,565.10 2,831.71 5,989,500.25 542,669.49 Point 3 82.00 -1,615.62 2,738.43 5,989,448.24 542,576.49 Point4 82.00 -1,565.10 2,831.71 5,888,500.25 542,888.48 Checked By: Approved By: Date: 5/8/2008 4:52:57PM Page 9 COMPASS 2003.16 Build 42F t'~` Well Name: 1R-01BL1 API # 50-029-21404-61-00 PTD: 208-035 Wellbore Diagram (5/02/08) ConocoPh i I I i ps Alaska 9-5/8" 36#/fl J-55 BTC -- by ~c 'a °_ 493 ft Camco DS Nipple 2.875" I.D. Schlumberger 7" 26#/ft J-55 BTC ID=6.26" ®o a -Calista ~~~,, ~• ~ DRIIUNG ~'_ ~, ', FUJIOS 6479.0 ft 7"Window 6515.0 ft 7" Bridge Plug 7" 26#Ift J-55 Casing -~ Abandoned C-Sand Abandoned ASand 8535.0 ft } 2,632 ft I DGLM # 1 3 998 ft DGLM # 2 5,015 ft DGLM # 3 5718ft DGLM#4 6,174 ft DGLM # 5 6221 ft Camco DS Nipple 2.812" I.D. 6243 ft BOT ZXP LT Packer 4.375" I.D. 6257 ft Baker HMC Tie-Back Hanger 6259 ft Baker Seal Assy 6264 ft PBR 6303.0 ft Baker OS 3-1/2" 9.3#/.ft L-80 EUE 8rd Solid Tubing I Liner _1-01 TOL Q 8022' TOWS ~ 8053' i~n~\d\o\w 8~055-8057' 1` 1~`~'~WS ~ 8085' Window 8085-8089' TD 1R-01BL1PB no Valve ST at 8,723k @90 degR Prepared by the Canuck and CTD Members 6/10!2008 - ST et 9,335k AI Billet @ 170R Page 1 ~~ BAKER H~I~HE~ II'~iTE~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: May 23, 2008 Please find enclosed directional survey data for wells: 30-02A 3 0-02AL 1 PB 1 30-02AL1 30-02AL2 30-02AL2-O1 1R-O1BL1PB1 1R-O1BL1 - .7U~-~~ `~ 1R-O1BL1-O1PB1 1R-O1BL1-O1 Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey .file Cc: State of Alaska, AOGCC Christine Mahnken a~~-~3y 1 R-O l BL 1 PB 1 • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 11, 2008 12:48 PM ~~~'~~ 1_` To: 'Rixse, Mel G' p~ Cc: McMullen, John C; Venhaus, Dan E; NSU, ADW Drlg Nordic 2 Supervisor Subject: RE: 1 R-01 BL1 PB1 Mel, Thanks for the information. You have correctly named the aborted penetration. Good luck with the new segment. Tom Maunder, PE AOGCC From: Rixse, Mel G [mailto:Mel.Rixse@bp.com] Sent: Friday, April 11, 200$ 12:38 PM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; Venhaus, Dan E; NSU, ADW Drlg Nordic 2 Supervisor Subject: iR-01BLiPB1 Tom, Nordic 2 attempted to sidetrack 1 R-01 B on 9-April-2008 from a whipstock set at 8085' ELMD, After drilling 85' from the tap o€ the whipstock to 8170' MD, the hole conditions deteriorated to the point where we could not get back in the well bore. The decision was made to set another whipstock at 8055' and attempt to drill 1 R-01 BL1 again. We have no good surveys from the P61 attempt, because we tracked along the high side of the casing. The whipstock was set at 20° right of highside. Please let me know if you need additional information. Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 -Office (907)223-3605 -Cell Cc. John McMullen, Dan Venhaus, N2 WSL 4/11J2008 ~~ j ~ ~ SARAH PALIN, GOVERNOR 4iI,C1•-7~A OI~ ~ liL~-7 333 W. 7th AVENUE, SUITE 100 CO1~SIiRQA'I'IOI1T COAII~TISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mel Rixse CT Drilling Engineer ConocoPhillips Alaska, Inc. c/o PO Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk River Field, Kuparuk River Oil Pool, Kuparuk 1 R-O1 BL1 ConocoPhillips Alaska, Inc. Permit No: 208-034 Surface Location: 153' FNL, 5140' FEL, SEC. 20, T12N, R1 OE, UM Bottomhole Location: 179' FNL, 1492' FEL, SEC. 20 T12N, R10E, UM Dear Mr. Rixse: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1R-O1BLA1, Permit No 200- 156, API 50-029-21404-02. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, aniel T. Seamount, Jr. ~~ii ~ ~ Chair DATED this ~ 7-day of March, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASi~LO41~D~~ CONSERVATION COMMIS~N ~~~ ~ ~ Gas PEE. DRILL ~i,3 1 a. Type of work ^ Drill ®Redrill - ^ Re-Entry 1 b. Current Well CI story ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test . ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 • 11. Well Name and Number: Kuparuk 1 R-01 BL1 • 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~ MD • 10450 TVQ 6539ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: ' 7. Property Designation: _ ADL 025635 ' River Pool FNL, 5140; FEL, SEC. 20, T12N, R10E, UM 153 Top of Productive Horizon: 1104' FNL, 2277' FEL, SEC. 20, T12N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 1, 2008 Total Depth: 179' FNL, 1492' FEL, SEC. 20, T12N, R10E, UM 9. Acres in Property: ~ 2560 14. Distance to Nearest Property: 12,250' 4b. Location of Well (State Base Plane Coordinates): Surface: x-539830. y-5991050 < Zone-ASP4 10. KB Elevation (Height above GL): 79.9 feet 15. Distance to Nearest Well Within Pool: 650' 16. Deviated Wells: Kickoff Depth: ~ gpg5 feet Maximum Hole An le: 94' de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole~ 2930 Surface: 2279 ' 18. Casin Pr' am: S ' c lio n To -'Settin De th - Bo m uantit of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 1150' 9300' 6556'ss 10450' 6539'ss Uncemented Slotted Liner 19. PRESE NT WELL CONDITION SUMMARY (l`obe completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12611 Total Depth TVD (ft): 6683 Plugs (measured): None Effective Depth MD (ft): 12611 Effective Depth TVD (ft): 6683 Junk (measured): 8114 asing Length Size: Cement Vohame MD TVD Conductor! Structural 115' 16" 260 sx Coldset II 115' 115' Surface 4380' 9-5/8" 1250 sx Permafrost III 420 sx PF 'C' 4380' 3867' Intermediate 6479' 7" 65 sx Class'G' 6479' 5315' Pro i n Liner 4672' 3-1 /2" 475 sx Class 'G' 6243' - 10915' 5115' - 6698' Liner 1814' 2-3/8" Uncemented Slotted Liner 10036' - 11850' 6703' - 6670' Perforation Depth MD (ft): 8588' - 10350' /Slotted: 10036' - 11850'; Open Hole: 11850' - 12611' Perforation Depth TVD (ft): 6685' - 6699' /Slotted: 6703' - 6670 ; Open Hole: 6670' - 6683' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mel Rixse, 564-5620 Printed Name Mel Ri a Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 564-5620 DateQ Y /~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill `~ Number: '~.3T API Number: 50-029-21404-60-00 Per o a/1 ~ See cover letter for Dat U other re uirements Conditions of Approval: ~~/ If box is checked, well may not be used to explore for, test, or produce coalbed me_t,,h/ane, gas hydrates, or gas contained shales: L~ Samples Req'd: ^ xes I!7 No Mud Log Req'd: ^~les [s~~No ~ "~ H2S Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: ~~~ ~S ~ ~`~~ ~5~ 3 ~ ~ APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12!2005 Submit In Duplicate ORIGINAL ,~~~° KRU 1 RS B L1 & L1-01 Dual Laterals - Cc~d Tubing Drilling To: Tom Maunder Petroleum Engineer ~~ Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer Date: March 4, 2008 Re: 1 R-01 BL1 & BL1-01 Application for Permit to Drill Request A coiled tubing drilling rig will drill two laterals in well KRU 1 R-01 B using the managed pressure drilling technique. These horizontal laterals will target Kuparuk A3/A4 sand reserves to capture and protect currently nonrecoverable resources. The perforations in the motherbore will remain open to production. The L1 lateral will exit the motherbore at 8,085' MD, and drill a 2365' horizontal lateral which will target the A3 sands to the north, and be completed with 23/8" slotted liner from 9,300' MD to a TD of 10,450' MD. The L1-01 lateral will exit the L1 lateral off a flow through liner top sidetrack billet and drill a 850' horizontal targeting the A4 sands above the lateral just drilled. It will be completed with 23/8" slotted liner from TD at 10,150 MD to the 1 R-01 B parent window at 8075'MD. CTD Drill and Complete 1 R-01 B program: Spud in April 1, 2008 Pre-Rig Work 1. O MIT-OA 2. O PPPOT-T, IC, PT Master & Swab valve to 4500 psi. Drawdown test MV, SV, & SSSV to 0 psi (SV failed 1/21/08, MV passed) 3. O MIT-IA (TIFL passed 1/21/08) 4. S Obtain SBHP after 3-5 day shut-in. (Done 8/7/07) 5. C Fill Clean Out & attempt to mill out restriction at 6470' (Done 9/29/07) 6. C Run memory correlation GR/CCVcaliper log up to 6100' MD to determine top offish in relation to KOP 7. C Freeze protect 8. S Dummy GLVs 9. O MIT-IA 10. C Run 2.78" KB packer with reverse float assembly (~5' long). Set as deep as possible. Pressure test packer. 11. C Lay in sand plug on top of KB packer. Wash out sand to 8085' GR 12. C RIH with 2' of 2" HSD guns (5' gun carrier), 6 spf, 60° phase. Tie in with GR, perf 8076' - 8080' MD. (Note: If unable to reach perf depth with a-line, convey guns on coil.) 13. C Pressure test squeeze perfs to 1250 psi (i.e. 12.2 ppg EMW with 8.5 ppg fluid). If pressure test fails proceed with cement squeeze. If pressure test passes, skip to step #'15 a. Run water-flow log to confirm whether cement channel is connected to the C-sand. If the channel only exists to the A-sand, there is no need to squeeze. b. RIH with 2' of same 2" HSD guns. Shoot another set of squeeze perf;s at 7985' MD. c. Establish injection rate/pressure. Lay in cement plug. Squeeze all pe~rfs. Clean out excess, WOC. d. Drill out cement, test squeeze perfs. If squeeze perfs test, continue drilling out to top of KB packer. 14. O Set BPV. Torque wellhead bolts to spec (FMC hand: 907-563-3990, ask for Kevin Hite). Install & test additional swab valve and hydraulic SSV on manual wing valve. 15. O Bleed production flow lines, IA, OA and GL lines down to zero and blind flange 16. O Remove wellhouse, level pad, drill mouse hole Page 1 of 4 March 4, 2008 KRU 1 RSB L1 & L1-01 Dual Laterals - Cc>~d Tubing Drilling Rip Work 1. MIRU Nordic 2. NU 7-1/16" BOPE, test 2. Pull BPV 3. Set 3-1/2" CT Flow-thru Monobore Whipstock _ ~~,~~ ~ 4. Displace the well to 2 ppb Biozan (or used Flo-Pro) / 9.4 #/gal ~~ S ~~ 5. Mill window/displace to 9.4#/gal Flo-Pro. ~~~ 6. Drill build/turn section with 3" bicenter bit and land well. 7. Drill lateral to 10,450'MD. 8. Flow check well and lay in KWF in needed. 9. Run approximately 1150' - 2-3/8" slotted liner with ported aluminum sidetrack billet on top. Place TOL at 9300' MD 10. Sidetrack 1 R-01 B L1/L1-01 lateral off TOL at 9300'MD. 11. Drill lateral to 10,150 MD. 12. Flow check well and lay in KWF in needed. 13. Run 2-3/8" slotted liner to TD placing liner top in open hole at B shale/A sand interface. 14. Run 2-3/8" solid liner with aluminum guide shoe (1" hole) with 2.7" swell packer placed 10-15' outside window. Space out so TOL is 10 above Top of whipstock. 15. ND BOPE. RDMO Nordic. Post-Rig Work 1. Obtain static BHP 2. Produce well to sales. Mud Program: . • Will use chloride-based Biozan brine (9.4 ppg) for milling operations, and chloride-based Flo- Pro mud (9.4 ppg) for drilling operations. Since there is no SCSSV installed in 1 R-01 B, the well will have to be killed prior to running 2-3/8" slotted liner. Disposal: • No annular injection on this well. • Class I I liquids to KRU 1 R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1 R-01 BL1 : 2-3/8", 4.6#, L-80, STL from TD(10,450'MD) to9300' MD 0 2-3/8"slotted (2" slots, 0.1875" slot width, 8 slots per ft, 2 slot per row, 90 deg phasing). Flow through aluminum billet at TOL. • 1 R-01 BL1-01:2-3/8", 4.6#, L-80, STL from TD(~10,150'MD) to just above the window 8075' MD 0 2-3/8"slotted (2" slots, 0.1875" slot width, 8 slots per ft, 2 slot per row, 90 deg phasing) with blanks across B-shale and across faults in L3. Top of liner placed 5'- 10' above window. Casing/Liner Information 9 5/8", J-55, 36#, Burst 3520; collapse 2020 psi. 7", J-55, 26#, Burst 4980, collapse 4320 3-1/2", L-80, 9.3#, Burst 10,160; collapse 10,530 psi Page 2 of 4 March 4, 2008 KRU 1R~6 L1 & L1-01 Dual Laterals - Cod Tubing Drilling Well Control: • Two well bore volumes (200 bbls) of KWF will be on 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 4000 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 1 R-01 BL1 & 1 R-01 BL1-01 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run, • The nearest well to 1 R-01 B is 1 R-16 which is 650 ft. away. • Distance to the nearest property line is 12,250 ft. (measured at closest point). Logging • MWD directional and Gamma Ray and Resistivity will be run over all of the open hole section. - Hazards • 1 R-01 B L1 lateral will cross 6 mapped faults. Plugbacks because of uncertain throw is a possibility. 1 R-01 B L1-01 should gain understanding of structure faulting from the 1 R-01 BL1 lateral. KRU 1 B pad is considered an H2S pad. The closest SHL to 1 R-01 B is 1 R-02 and has an H2S level of 100 ppm H2S. 1 R-14 has an H2S level of 150 ppm. All H2S monitoring equipment will be operational. Reservoir Pressure , • The most recent SBHP survey (08-07-07) was gauged at 2291 psi C~ 5047' SSTVD exposure through perforations in the A sand. The EMW is 8.7 ppg at 6114' TVD, or estimated BHP from the SBHP measure above is 2930 psi. Max. surface pressure with gas (0.1 psi/ft) to surface is 2279 psi. ' Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 9.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. This well does not have a functioning tubing sub-surface safety valve that will be utilized to facilitate BHA deployments and liner running. It is possible that deployment of the BHA under trapped wellhead pressure may 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 the 1 R-01 BL1 & L1-01 TD: Estimated reservoir pressure: 2930 psi at 6513' TVD, 8.7 ppg EMW. • Expected annular friction losses while circulating: 720 psi at KOP and 980 psi at TD (assuming 90 psi/ft, fora 2915' lateral). Page 3 of 4 March 4, 2008 KRU 1 R~B L1 & L1-01 Dual Laterals - C~d Tubing Drilling • While circulating 9.4 ppg fluid, bottom hole circulating pressure is estimated to be 3905 psi or 11.5 ppg ECD • When circulation is stopped, a minimum of 720 psi surface pressure will be applied to maintain constant BHP. Mel Rixse CTD Engineer 564-5620 CC: Well File Sondra StewmanlTerrie Hubble Page 4 of 4 March 4, 2008 ~ BP Alaska by Baker Hughes INTEQ Planning Report 1NTEQ Company: ConocoPhillips Afaska Inc. Date: 2!2212008 Time: 14:21:24 Page: 1 Field: Kuparuk River Unit Co-ardinate(NE) Reference: Well: 1 R-01, True North Site: Kuparuk 1 R Pad Vertical (TVD) Reference: 1 R-01 82.0 We1L• 1 R-01 Sectiop'(VS) Reference: Well (O.OON,O.OOE,90.38Azi) Wellpath: Plan 5, 1 R-0#BLi Survey Calculation Method: Minimum Curvature. Db: Sybase Targets - - - _ __-_ Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing ; 'Easting Deg Min Sec Deg ,Min Sec Dip.... Dir. __ Annotation MD TVD _ - Plan Section Information _____ - - MD Intl: Azim TVD +N/-S +FJ-W DLS Buitd Turn TFn Target ft deg,. deg ft ft ft deg/100ft deg/1OOft deg/100ft deg I, 8078.56 74.05 179.16 6592.96 -1453.36 3131.06 0.00 0.00 0.00 0.00 8085.00 74.75 179.03 6594.69 -1459.56 3131.15 11.04 10.87 -2.02 349.84 8105.00 76.44 179.66 6599.67 -1478.93 3131.37 8.98 8.45 3.15 19.93 8130.00 82.15 186.42 6604.31 -1503.43 3130.06 35.03 22.84 27.04 49.99 8230.00 74.99 221.42 6624.73 -1591.63 3091.36 35.00 -7.16 35.00 105.01 8274.00 71.57 237.11 6637.46 -1619.06 3059.58 35.01 -7.77 35.66 105.01 8491.47 93.00 311.40 6671.27 -1600.45 2861.48 35.00 9.85 34.16 82.00 8616.47 93.55 355.22 6663.76 -1491.67 2806.78 35.00 0.44 35.06 88.00 8666.47 93.54 0.23 6660.67 -1441.82 2804.80 10.00 -0.02 10.02 89.96 8866.47 91.28 20.12 6652.17 -1246.15 2839.95 10.00 -1.13 9.94 96.00 9066.47 91.20 40.13 6647.80 -1074.08 2939.79 10.00 -0.04 10.00 90.01 9241.47 93.24 57.52 6640.97 -959.39 3070.89 10.00 1.17 9.94 83.02 9291.47 92.19 62.41 6638.60 -934.40 3114.12 9.99 -2.10 9.78 102.01 9391.47 89.92 72.16 6636.75 -895.85 3206.23 10.01 -2.27 9.75 102.99 9541.47 89.15 57.17 6637.98 -831.85 3341.41 10.01 -0.51 -9.99 267.01 9691.47 89.96 42.20 6639.15 -735.08 3455.46 9.99 0.54 -9.98 273.02 Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: Kuparuk 1 R Pad Site Position: Northing: 5991050.01 ft Latitude: 70 23 11.370 N From: Map Easting: 539829.93 ft Longitude: 149 40 33.803 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.31 deg Well: 1 R-01 Slot Name: Well Position: +N/-S 0.08 ft Northing: 5991050.09 ft - Latitude: 70 23 11.370 N +E/-W -0.17 ft Easting : 539829.76 ft Longitude: 149 40 33.808 W Position Uncertainty: 0.00 ft Wellpath: Plan 5, 1 R-01 BLi Drilled From: i R-01 B Tie-on Depth: 8078.56 ft Current Datum: 1 R-01 Height 82.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/22/2008 Declination: 22.91 deg Field Strength: 57633 nT Mag Dip Angle: 80.87 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 82.00 0.00 0.00 90.38 Plan: Plan #5 Date Composed: 2/22/2008 Version: 1 Principal: Yes Tied-to: From: Definitive Path by ~ BP Alaska Baker Hughes INTEQ Planning Report ATE Q Company: ConocoPhillips Alaska inc: Date: 2/22/2008. Time: 14:21:24 Page: 2~ Field: Site: K K uparuk Riv uparuk 1 R er Unit Pad Co-ordinate(NE) Referertee: Well: 1 R-01, True Vertical (TVD) Reference: 1 R-01 82.0 North Well: 1 R-01 Section (VS) Reference: Well (O .OON,O.OOE,90.38Azi) Wellpat6: P lan 5, 1 R-01 BLi Survey Calculation Method: Minimu m Curvature D b: Syba se 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/1'OOft degl100ft deg 9991.47 92.96 12.33 6631.33 -471.56 3591.32 10.00 1.00 -9.96 2 76.00 10091.47 91.08 22.16 6627.80 -376.24 3620.92 10.00 -1.88 9.83 1 00.63 10416.47 90.91 349.66 6622.00 -57.33 3653.93 10.00 -0.05 -10.00 2 70.00 10450.00 90.91 353.01 6621.46 -24.20 3648.88 9.99 0.00 9.99 89.97 Survey MD Inct" Azim SS TVD 1V/S FJW MapN MapE ` DLS VS TFO Too ft deg deg ft ft ft ft ,ft deg/100ft ft deg 8078. 56 74.05 179.16 6510.96 -1453.36 3131.06 5989613.57 542968.20 0.00 3140.62 0.00 MWD 8085. 00 74.75 179.03 6512.69 -1459.56 3131.15 5989607.37 542968.33 11.04 3140.76 349.84 MWD 8100. 00 76.02 179.50 6516.48 -1474.07 3131.34 5989592.86 542968.60 8.98 3141.04 19.93 MWD 8105. 00 76.44 179.66 6517.67 -1478.93 3131.37 5989588.00 542968.66 8.98 3141.11 19.81 MWD 8125. 00 81.00 185.09 6521.58 -1498.51 3130.56 5989568.42 542967.94 35.03 3140.42 49.99 MWD 8130. 00 82.15 186.42 6522.31 -1503.43 3130.06 5989563.49 542967.47 35.03 3139.96 48.93 MWD 8150. 00 80.40 193.28 6525.35 -1522.90 3126.68 5989544.01 542964.20 35.00 3136.71 105.01 MWD 8175. 00 78.40 201.94 6529.96 -1546.30 3119.26 5989520.58 542956.91 35.00 3129.45 103.96 MWD 8200. 00 76.67 210.73 6535.37 -1568.15 3108.45 5989498.67 542946.21 35.00 3118.78 102.37 MWD 8225. 00 75.24 219.63 6541.45 -1587.96 3094.50 5989478.79 542932.37 35.00 3104.96 100,47 MWD 8230. 00 74.99 221.42 6542.73 -1591.63 3091.36 5989475.10 542929.25 35.00 3101.85 98.30 MWD 8250. 00 73.29 228.48 6548.20 -1605.24 3077.78 5989461.42 542915.74 35.01 3088.36 105.01 MWD 8274. 00 71.57 237.11 6555.46 -1619.06 3059.58 5989447.50 542897.62 35.01 3070.25 103.08 MWD 8275. 00 71.62 237.48 6555.78 -1619.57 3058.79 5989446.99 542896.83 35.00 3069.46 82.00 MWD 8300. 00 73.07 246.53 6563.37 -1630.74 3037.77 5989435.71 542875.88 35.00 3048.52 81.88 MWD 8325. 00 74.90 255.43 6570.28 -1638.55 3015.08 5989427.78 542853.23 35.00 3025.88 79.13 MWD 8350. 00 77.08 264.17 6576.35 -1642.83 2991.23 5989423.37 542829.41 35.00 3002.06 76.67 MWD 8375. 00 79.55 272.74 6581.42 -1643.48 2966.79 5989422.59 542804.97 35.00 2977.62 74.55 MWD 8400. 00 82.23 281.18 6585.38 -1640.48 2942.31 5989425.46 542780.48 35.00 2953.12 72.81 MWD 8425. 00 85.09 289.50 6588.15 -1633.91 2918.37 5989431.90 542756.51 35.00 2929.14 71.47 MWD 8450. 00 88.04 297.75 6589.65 -1623.92 2895.53 5989441.77 542733.62 35.00 2906.24 70.55 MWD 8475. 00 91.03 305.98 6589.85 -1610.73 2874.32 5989454.84 542712.34 35.00 2884.94 70.06 MWD 8491. 47 93.00 311.40 6589.27 -1600.45 2861.48 5989465.06 542699.44 35.00 2872.03 69.99 MWD 8500. 00 93.10 314.39 6588.82 -1594.65 2855.24 5989470.82 542693.17 35.00 2865.75 88.00 MWD 8525. 00 93.34 323.15 6587.41 -1575.90 2838.81 5989489.49 542676.64 35.00 2849.19 88.16 MWD 8550. 00 93.51 331.91 6585.91 -1554.87 2825.42 5989510.45 542663.14 35.00 2835.67 88.65 MWD 8575. 00 93.59 340.68 6584.36 -1532.04 2815.40 5989533.21 542653.00 35.00 2825.50 89.18 MWD 8600. 00 93.60 349.44 6582.79 -1507.96 2808.97 5989557.26 542646.45 35.00 2818.91 89.72 MWD 8616. 47 93.55 355.22 6581.76 -1491.67 2806.78 5989573.53 542644.17 35.00 2816.61 90.27 MWD 8625. 00 93.55 356.07 6581.23 -1483.18 2806.14 5989582.02 542643.48 10.00 2815.91 89.96 MWD 8650. 00 93.55 358.58 6579.69 -1458.26 2804.97 5989606.93 542642.18 10.00 2814.58 90.01 MWD 8666. 47 93.54 0.23 6578.67 -1441.82 2804.80 5989623.36 542641.92 10.00 2814.30 90.17 MWD 8675. 00 93.45 1.08 6578.15 -1433.31 2804.90 5989631.88 542641.98 10.00 2814.34 96.00 MWD 8700. 00 93.18 3.57 6576.70 -1408.38 2805.91 5989656.81 542642.86 10.00 2815.19 96.05 MWD 8725. 00 92.91 6.06 6575.37 -1383.50 2808.01 5989681.70 542644.82 10.00 2817.12 96.20 MWD 8750. 00 92.63 8.55 6574.16 -1358.73 2811.18 5989706.48 542647.86 10.00 2820.13 96.33 MWD 8775. 00 92.35 11.03 6573.08 -1334.12 2815.42 5989731.11 542651.97 10.00 2824.21 96.45 MWD 8800 .00 92.06 13.52 6572.11 -1309.72 2820.74 5989755.54 542657.15 10.00 2829.36 96.56 MWD 8825 .00 91.77 16.00 6571.28 -1285.56 2827.10 5989779.73 542663.39 10.00 2835.56 96.65 MWD 8850 .00 91.48 18.48 6570.57 -1261.69 2834.51 5989803.64 542670.67 10.00 2842.81 96.74 MWD 8866 .47 91.28 20.12 6570.17 -1246.15 2839.95 5989819.20 542676.03 10.00 2848.15 96.81 MWD 8875 .00 91.28 20.97 6569.98 -1238.17 2842.94 5989827.20 542678.98 10.00 2851.09 90.01 MWD 8900 .00 91.28 23.47 6569.42 -1215.03 2852.39 5989850.39 542688.30 10.00 2860.39 90.03 MWD 8925 .00 91.27 25.98 6568.87 -1192.33 2862.85 5989873.14 542698.64 10.00 2870.69 90.08 MWD 8950 .00 91.27 28.48 6568.31 -1170.11 2874.28 5989895.42 542709.95 10.00 2881.98 90.14 MWD BP Alaska ~ ~ by Baker Hughes INTEQ Planning Report 1NTEQ Company: Field: Site: Well: Wellpath: Survey MD ft ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1 R Pad 1 R-01 Plan 5, 1 R-01 BL1 Incl Azim SS TVD " deg deg ft S ft Dater .2122/2008 Time: 14:21:24 Page: 3 Co-ordinate(NE) Reference: Well: 1 R-01, True North Vertical (TVp) Reference: 1 R-01 82.0 Section,(VS)Reference: Well (O.OON,O.OOE,90.38Azi) Survey Calculation Method: Minimum Curvature Db: Sybase --- E/W MapN MapE DLS VS TFO Too ft ft ft deg/100ft ft deg 8975. 00 91.26 30. 98 6567.76 -1148.40 2886.68 5989917.19 542722.23 10.00 2894. 23 90.19 MWD 9000. 00 91.24 33. 48 6567.22 -1127.26 2900.00 5989938.40 542735.44 10.00 2907. 41 90.25 MWD 9025. 00 91.23 35. 98 6566.68 -1106.72 2914.24 5989959.01 542749.57 10.00 2921. 52 90.30 MWD 9050. 00 91.21 38. 48 6566.15 -1086.83 2929.36 5989978.99 542764.58 10.00 2936. 51 90.36 MWD 9066. 47 91.20 40. 13 6565.80 -1074.08 2939.79 5989991.78 542774.94 10.00 2946. 85 90.41 MWD 9075. 00 91.30 40. 98 6565.61 -1067.60 2945.34 5989998.29 542780.45 10.00 2952. 35 83.02 MWD 9100. 00 91.61 43. 46 6564.98 -1049.10 2962.13 5990016.88 542797.14 10.00 2969. 02 83.03 MWD 9125. 00 91.90 45. 94 6564.21 -1031.34 2979.71 5990034.74 542814.62 10.00 2986. 48 83.10 MWD 9150. 00 92.20 48. 42 6563.32 -1014.36 2998.03 5990051.81 542832.86 10.00 3004. 69 83.17 MWD 9175. 00 92.49 50. 91 6562.30 -998.19 3017.07 5990068.08 542851.81 10.00 3023. 62 83.26 MWD 9200. 00 92.78 53. 39 6561.15 -982.87 3036.79 5990083.50 542871.44 10.00 3043. 24 83.36 MWD 9225. 00 93.06 55. 88 6559.87 -968.42 3057.15 5990098.06 542891.72 10.00 3063. 50 83.48 MWD 9241. 47 93.24 57. 52 6558.97 -959.39 3070.89 5990107.16 542905.42 10.00 3077. 19 83.61 MWD 9250. 00 93.06 58. 35 6558.50 -954.87 3078.11 5990111.72 542912.61 9.99 3084. 37 102.01 MWD 9275. 00 92.54 60. 80 6557.28 -942.23 3099.64 5990124.47 542934.07 9.99 3105. 82 102.05 MWD 9291. 47 92.19 62. 41 6556.60 -934.40 3114.12 5990132.38 542948.50 9.99 3120. 24 102.17 MWD 9300. 00 92.00 63. 24 6556.29 -930.51 3121.70 5990136.31 542956.07 10.01 3127. 80 102.99 MWD 9325. 00 91.43 65. 68 6555.54 -919.74 3144.25 5990147.20 542978.55 10.01 3150. 28 103.02 MWD 9350. 00 90.86 68. 12 6555.04 -909.93 3167.24 5990157.13 543001.48 10.01 3173. 20 103.09 MWD 9375. 00 90.30 70. 55 6554.79 -901.11 3190.62 5990166.07 543024.82 10.01 3196. 53 103.14 MWD 9391. 47 89.92 72. 16 6554.75 -895.85 3206.23 5990171.42 543040.40 10.01 3212. 10 103.16 MWD 9400. 00 89.88 71. 31 6554.77 -893.17 3214.33 5990174.13 543048.48 10.01 3220. 18 267.01 MWD 9425. 00 89.75 68. 81 6554.85 -884.65 3237.83 5990182.78 543071.94 10.01 3243. 62 267.02 MWD 9450. 00 89.62 66. 31 6554.99 -875.11 3260.93 5990192.45 543094.99 10.01 3266. 66 267.02 MWD 9475. 00 89.49 63. 81 6555.19 -864.57 3283.60 5990203.11 543117.59 10.01 3289. 26 267.04 MWD 9500. 00 89.36 61. 31 6555.44 -853.05 3305.78 5990214.74 543139.72 10.01 3311. 37 267.06 MWD 9525. 00 89.23 58. 82 6555.75 -840.58 3327.45 5990227.33 543161.31 10.01 3332. 95 267.08 MWD 9541. 47 89.15 57. 17 6555.98 -831.85 3341.41 5990236.13 543175.23 10.01 3346. 85 267.11 MWD 9550. 00 89.20 56. 32 6556.10 -827.17 3348.54 5990240.85 543182.33 9.99 3353. 95 273.02 MWD 9575. 00 89.33 53. 82 6556.42 -812.86 3369.04 5990255.26 543202.75 9.99 3374. 35 273.03 MWD 9600. 00 89.46 51. 33 6556.69 -797.67 3388.89 5990270.56 543222.51 9.99 3394. 10 273.07 MWD 9625. 00 89.60 48. 83 6556.89 -781.63 3408.06 5990286.70 543241.60 9.99 3413. 17 273.09 MWD 9650. 00 89.73 46. 34 6557.04 -764.77 3426.51 5990303.66 543259.96 9.99 3431. 51 273.11 MWD 9675. 00 89.87 43. 84 6557.13 -747.12 3444.22 5990321.40 543277.57 9.99 3449. 10 273.13 MWD 9691. 47 89.96 42. 20 6557.15 -735.08 3455.46 5990333.50 543288.74 9.99 3460. 25 273.14 MWD 9700. 00 90.05 41 .35 6557.15 -728.72 3461.14 5990339.89 543294.39 10.00 3465. 89 276.00 MWD 9725. 00 90.31 38 .86 6557.07 -709.60 3477.24 5990359.09 543310.39 10.00 3481. 87 276.00 MWD 9750. 00 90.57 36 .38 6556.88 -689.80 3492.50 5990378.97 543325.54 10.00 3497. 00 275.99 MWD 9775. 00 90.83 33 .89 6556.57 -669.36 3506.89 5990399.49 543339.82 10.00 3511. 25 275.97 MWD 9800. 00 91.09 31 .40 6556.15 -648.31 3520.37 5990420.60 543353.19 10.00 3524. 59 275.94 MWD 9825. 00 91.34 28 .91 6555.62 -626.70 3532.93 5990442.27 543365.63 10.00 3537. 00 275.90 MWD 9850. 00 91.60 26 .43 6554.98 -604.57 3544.53 5990464.47 543377.11 10.00 3548. 46 275.84 MWD 9875. 00 91.85 23 .94 6554.23 -581.96 3555.16 5990487.13 543387.62 10.00 3558. 94 275.78 MWD 9900. 00 92.09 21 .45 6553.37 -558.91 3564.80 5990510.23 543397.14 10.00 3568. 43 275.71 MWD 9925. 00 92.34 18 .96 6552.40 -535.46 3573.43 5990533.72 543405.64 10.00 3576. 90 275.62 MWD 9950. 00 92.58 16 .46 6551.33 -511.67 3581.02 5990557.54 543413.11 10.00 3584. 34 275.52 MWD 9975. 00 92.81 13 .97 6550.16 -487.58 3587.58 5990581.67 543419.53 10.00 3590. 73 275.42 MWD 9991. 47 92.96 12 .33 6549.33 -471.56 3591.32 5990597.71 543423.19 10.00 3594 .37 275.30 MWD 10000. 00 92.80 13 .17 6548.90 -463.25 3593.20 5990606.03 543425.03 10.00 3596 .19 100.63 MWD 10025. 00 92.34 15 .63. 6547.78 -439.06 3599.41 5990630.24 543431.11 10.00 3602 .24 100.68 MWD 10050. 00 91.87 18 .09 6546.86 -415.16 3606.66 5990654.19 543438.22 10.00 3609 .33 100.79 MWD 10075 .00 91.39 20 .54 6546.15 -391.57 3614.92 5990677.81 543446.36 10.00 3617 .44 100.88 MWD 10091 .47 91.08 22 .16 6545.80 -376.24 3620.92 5990693.18 543452.27 10.00 3623 .33 100.95 MWD BP Alaska ~ ~$ by Baker Hughes INTEQ Planning Report INTEQ Company: ConocoPhillips Alaskatne. Date: 2/22/2008 Time: 14:21:24 Page: 4 Field: Ku paruk River Unit Co-ordinate(NE)Reference: Well: 1 R-01, True North ~ Site: Ku paruk YR Pad Vertical (TVD) Re[erence: 1 R-01 82.0 Well: 1 R-01 Section (VS)'Reference: Well (O .OON,O.OOE,90.38Az i) ~ Wellpath: Plan 5, 1 R-01 BL1 Survey Calculation Method: Minimu m Curvatu re Db: Sybase Survey MD Incl - Azim S S TVD N/S E/W - MapN MapE DLS VS 'fF0 Too ft deg deg ft ft ft' ft ft deg/100ft ft deg 10100.00 91..08 21.31 6545.64 -368.32 3624.07 5990701.11 543455.39 10.00 3626.44 270.00 MWD 10125.00 91.08 18.81 6545.16 -344.84 3632.65 5990724.64 543463.83 10.00 3634.85 269.98 MWD 10150.00 91.07 16.31 6544.69 -321.01 3640.19 5990748.50 543471.25 10.00 3642.23 269.94 MWD 10175.00 91.07 13.81 6544.23 -296.87 3646.68 5990772.67 543477.61 10.00 3648.57 269.89 MWD 10200.00 91.06 11.31 6543.76 -272.48 3652.11 5990797.09 543482.91 10.00 3653.84 269.84 MWD 10225.00 91.05 8.81 6543.30 -247.87 3656.48 5990821.72 543487.15 10.00 3658.04 269.80 MWD 10250.00 91.04 6.31 6542.85 -223.09 3659.76 5990846.51 543490.30 10.00 3661.16 269.75 MWD 10275.00 91.02 3.81 6542.40 -198.19 3661.97 5990871.42 543492.37 10.00 3663.20 269.70 MWD 10300.00 91.01 1.31 6541.95 -173.23 3663.08 5990896.39 543493.35 10.00 3664.15 269.66 MWD 10325.00 90.99 358.81 6541.52 -148.23 3663.11 5990921.38 543493.24 10.00 3664.01 269.61 MWD 10350.00 90.97 356.31 6541.09 -123.26 3662.04 5990946.35 543492.04 10.00 3662.78 269.57 MWD 10375.00 90.95 353.81 6540.67 -98.36 3659.89 5990971.23 543489.76 10.00 3660.46 269.53 MWD 10400.00 90.93 351.31 6540.26 -73.57 3656.65 5990996.00 543486.39 10.00 3657.06 269.49 MWD 10416.47 90.91 349.66 6540.00 -57.33 3653.93 5991012.22 543483.58 10.00 3654.23 269.44 MWD 10425.00 90.91 350.51 6539.86 -48.93 3652.46 5991020.61 543482.07 9.99 3652.70 89.97 MWD • 10450.00 90.91 353.01 6539.46. -24.20 3648.88 5991045.33 543478.35 9.99 3648.96 89.99 MWD ~paruk Managed Pressure Drillin~ BOP Configuration for 2" Coil Tubing Well 1 R-01 B L1 & L1-01 Floor ril 7 1/16" 5000 psi BOP's. ID = 7.06" 7 1/16" 5000 psi, RX-46 7 1/16" 5000 psi RX-46 Choke Line C C Tree Size 3-1/8", 5M ~ I4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee SSV Master Valve Base Flan e o~ Page 1 • TRANSMITTAL LETTER CHECKLIST WELL NAME ___ I<.J~.. (/L ~/`~ ~( Development Service Exploratory Stratigraphic Test Non-Conventional Well ) FIELD: ~'~~~~1-C~JEt~ POOL: ~~? ~~R~,(--~~y£T- Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well ""` l , (If last two digits in permit No. ZL'Y~-l AP[No. 50-~' - ~ -OZ! API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water ~vel! ±es±irg ro ram. Rev: 1/1(/2008 WELL PERINIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNiT 1R-01 BL1 Program DEV Weil bore see (~ PTD#:2060340 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV 1 PEND GeoArea 890 Unit 11160 On10ff Shore On Annular Disposal ^ Administration 1 Permit fee atfaghe~- - - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - 2 1.easenumberapprgpriate-__________---------------- --- - ---Yes-_____ _Egtirewell inADL25635--____________________-___--_____--_--__--__--__-- 3 Unique welt name and number______________-__--____ ____---_-Yes-____ ___-__-_--__--- 4 Well Igcated in a_defnedpogl_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - - _ Yes _ _ _ _ _ _ _KUPARUK RIVER,-KUPARUK RVOIL - 490100, ggverned by Conservation Order Ng. 4320.- - - - - - _ - - - - - - 5 Well located proper distance from drilling unit-boundary- - - _ _ . _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Conservation Older Ng. 4320 contains rig spacing testric6ons with respect-tg drilling unit boundaries. - _ - - - - - - 6 Well Igcated proper distance from ether wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ . _ _ _ _ Yes Cgnservatton Older Ng.-4320 has rig intennrell_spacing restrictigns, - _ _ _ 7 Sufficieniacreage availebie in-drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - - _ _ Conservation Order Ng. 4320 has no interwell-spaeing_restnctigns, We11bo[e wll be-mgrs than 5Q0' frgm _ 8 if deviated, is_weilbore plat_included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ - - - _ an external property line where:ownership griandownershpchanges. - _ _ _ _ _ _ - - _ _ - _ _ - - _ _ _ _ _ _ _ _ _ - - 9 Opsratotgnlyaffectedparty--- ------- -- - -- - ---- - Yes - ----- ----- -- -- ---------------- - - -- 10 Operatotbas_approprialebondinf4rge --- - - --- -- - Yes------ --- --- - --- ------ -- ----- -- -- -- --- 11 Permit can be issuedwlthgutccnseNatigngrder------------------- ---------Yes----- ----------------------------------------------------.--------_-__-- Appr Date 12 Permit_canbeissuedwithoutadministrativ_e_approval--------------- ------ --Yes_----- -------------------------------------.-.----------------------_--_-- SFD 3/6/2008 13 Can permit be eRRroved befgre 15-day well- - - - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 14 Welllgcatedwiihinaree>~ndstraiaauthgrizedbylnjectionOrder#(put-IQ#in-commenis)-(Fgr_ NA------- --------------------------------------------------------------------- 15 Allwelis-withtn114-mile_area_of[eyiewidentified(FOrservicewellonly)-__-_ -________ NA------- ------__-_____---____--_.-______________-__--__-__--_____-________ 16 Pre-produced injector;duratignofpreproducti9nlessthan3months-(Forssrvicewellon~r)_--NA______ ______________________-______.-______________-._--_--__-__-____._ 17 Nonconven, gas-cgnfgrmstgA$31,05.03QQ•LA),Q.2.A-D) - - - - - - - - - - -~A - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductorsiring-prgvided_____________________________- ----___-- NA-----__ Cgnductgrset_in1R-01(185-175).-----------------------------------------_----- 19 Surfaceeasingprgtectseil_knownUSDWS______________________ _________ NA______ Aliaqutfersexempted,40CFR-147.1Q2-(b1(3).____--______-________-_____-_--______ 20 CMT-valadequa#e-tgeirculate-onconductgr&surf_csg_______________ ____-_-_ NA-----__ _$urf_acecasingsetirtlR•Q1._____--_______-___-__--__--__-__-___-__--__--__--__ 21 CMT_v_oladequate-to tie-inlQngsiringtosurfcsg------___-________ __________NA_____ -ProductiQn_casingsetin-1R-01,------_--__------__-____--__-_______---_----_- 22 CMT_willcoverailknown_ptoductivehgrizgrts_--______-________ ________No--____ _Slottedliner-completion plenned,___________-__--____----__-_____--_______-___ 23 Casing desgnsadequate for C, T B-&permafrost- - - - - _ - _ _ - - _ _ - _ _ _ _ _ - - _ _ _ NA_ _ - - - _ - Q[iginal well-met design specifications, _ NA for slgtted liner-- - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ 24 Adequateaankage-orrsserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - - - _ _ _ _ .Yes _ _ _ _ _ _ _ Rig equipped with steel pits, No reserve pit planned•_ All waste-tg approved disRosal wells - - - - - - - - - - - _ _ - 25 Ifa-re~J[ill, has-a 10.403 fgrabandgnmentbeen apptgved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- - _ _ _ _ _ _ Lateralplanned, 1R-01B oQmpietedintrrvalwill_be-retained. _ - - - - - - - - - - - _ _ _ - _ - - - - - - - - - - - - - _ - 26 Adequate wellbore separation-praposed_ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - Yes _ _ - - _ _ _ Proximity analysis performed, tJearestsegment is 1R-018 and-paths diverge.- _ _ - - _ _ . _ _ - _ _ _ - _ - - _ - 27 Ifdiverter-required,deesitmeetregulations_-_----_--___-__--- -- -__--NA-----__ BQPStackwillalceadY-be in place,---------------------------------------------- Appr Date 28 Dulling fluid prggram schematic & equip listadequake_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - Maximum expected fo[matign pressure 8,7_EMW._ Well to-be_dril_led with 9.4-ppg and_managed-pressure iechniqu- TEM 311312008 29 BOPEs,_do theymeet regulaiign _ _ - _ _ _ _ _ _ _ _ _ _ - - _ _ - - _ _ _ Yes _ - _ _ _ _ _ _ _ to enhance hgle.stability. 2 well vglumes_of KW fluid will_be on Iecailon as cgntingency-__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 BOPS-press rating appropriate; test to-(pui prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - MASP calculated at 2279 psi, 4Q00-psi_BOP testplanned. _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 Chgke-manifoldcgmplieswlAPl_RP-53tMay84)----_____________ _________Yes______ _ _ _ _ _ _ _ _ ___--__ 32 VyQrkwilloccu[withouioperationshutdown--_---_---__-------- ______Yes------ ------------------------------------------------------------- 33 Is presence of H2S gasprgbable_ - - - _ - - - _ - - - - - - _ _ - - _ _ _ _ _ Yes - - - _ - - - H2S is reported-at 1R pad. Mud shguid preclude H2S an rig.-Rig hassensors and ala[ms- - - - - - - - - - - - - - - 34 MechanicalcondflionofwellswithinAQRyerified(FOrservicewelf gnly)----- --------- NA_-.____ ______--__-__--__--___-___-______-__-_---_______--______-________ Geology 35 Permitcanbeissuedwlohydrogen-sulfidemeasu[es________________ _________ No_-____ _KRl11R-01Qmeasured125ppmti2$gnfi11812006.___________-_________________-____ 36 Data-presented on potential pverpressurezones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - - _ _ Expected reservoirpressure is 8,6-ppg; will be_drilled with 9,4-ppg mud._ _ _ _ _ _ - - _ _ _ _ - - - Appr Date 37 Seismic analysisQfskrallgwgas_zones________________________ ___.____ NA------- _-_ ------------------------------------------------------------------ SFD 3/612008 38 Seabed conditionsurvey_(ifgff_-shore)--__-__________________ _________ NA-.____ _____- 39 Coniactnamelphgneforweekly_progress[eports_[exploratoryonlyj------- -------- NA------ ---------------------------------------------------.--------------- Geologic Date: Engineering Date P Date Lai eral from KRU 1R-01B that will access undeveloped reserves. Commissionee Co fission Co issio er C~~ 3~~~ ~~~ Q~ •
