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208-043
• • 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. 020 8 - Q ~ 3 Well History File Identifier Organizing (done) ^ Two-sided III II'III II III II III ^ Rescan Needed III II'lII II II III III RE CAN Color Items: ^ Greyscale Items: DIG AL DATA Diskettes, No. a..., ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: Q /s/ I Pro -ect Proofin I g II I II II II I I III I I III BY: Maria Date: ~--. ~ ~ /s/ Scannin Pre aration 9 P x 30 = ~ 0 + ~ ~ =TOTAL PAGES ~ u (Count does not include cover sheet) BY: Maria Date:. ~ I q / ~ ~ /s/ Production Scanning Stage 7 BY: Stage 1 BY: Page Count from Scanned File: ~. (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO Maria Date: ~ ~ i `a /s/ ~I If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: /s/„ „_, .. ... ,. ,.., Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Comments about this file: Date: Quality Checked uiiiimuiui 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/2/2010 Permit to Drill 2080430 Well Name/No. KUPARUK RIV UNIT 3F-16AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 5 1502-60-00 MD 10626 TVD 5955 Completion Date 5/20/2008 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATAINFORMATgN Types Electric or Other Logs Run: MWD DIR, RES, GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc ~ Directional Survey 0 10626 Open 6/30/2008 ~//D D Asc r/ Directional Survey 0 10054 Open 11/3/2008 PB 1 Second Copy .~D D Asc ~ Directional Survey 0 10054 Open 6/30/2008 PB 1 pt Directional Survey 0 10054 Open 11/3/2008 PB 1 og Induction/Resistivity 25 Col 9775 10626 Open 11/16/2009 MD MPR, GR og Induction/Resistivity 25 Col 9775 10626 Open 11/16/2009 ND MPR, GR ~D C Lis 18953 eduction/Resistivity 7844 10626 Open 11/16/2009 MPR logs in CGM, EMF and PDF og Induction/Resistivity 25 Col 8220 10054 Open 11/16/2009 P61 MD MPR, GR og Indyrction/Resistivity 25 Col 8220 10054 Open 11/16/2009 P61 TVD MPR, GR C Lis 18954 Induction/Resistivity 7844 10054 Open 11/16/2009 PB1 MPR logs in CGM, EMF and PDF Well Cores/Samples Information: fi Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/2/2010 Permit to Drill 2080430 Well Name/No. KUPARUK RIV UNIT 3F-16AL1 Operator CONOCOPHILLIPS ALASKA INC MD 10626 TVD 5955 Completion Date 5/20/2008 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? (`~'-~~ ~N~ Chips Received? `?~~ Formation Tops may'" Analysis Y / N Received? API No. 50-029-21502-60-00 Comments: Compliance Reviewed By: -_ -~ - __ Date: oC ~Q~~~, d~.l~ L (i J • ConocoPhillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital. Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia*'` Electronic Anchorage, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia*"` Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia"* Electronic Anchorage, Alaska 99519 CGM /TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas `; Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS 1~`~ ~ 3 I• Company ConocoPhillips, Alaska, Inc. Well Name 3F-16AL1P61 ~~~ S Date 11/10/2009 ~~~ ~~~ - -..... _ . _ . _ ~yy .... ~ .., , Page 1 of 4 ®_ ,.- BAKER Hu~HEs Il'~TEC~ ~~~~ '' ~ ~: BAITER ENE Il"'~TEI 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: October 31, 2008 Please find enclosed directional survey data for wells: 3F-16AL1PB1 This survey is being redistributed because of a well name error on its survey report in the original distribution on June 26, 2008. Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahnken Page 1 of 1 AAaunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 29, 2008 9:45 AM To: 'Eller, J Gary' Cc: 'Hubble, T rrie L' Subject: 3F-16A (208-043) Gary, This note coni~irms our conversation regarding the PBTD for this penetration. Drilled TD was 10626' and and that depth is also reported as the PBTD. However, it was not possible to run the liner to TD. The liner stopped with the shoe at 10320' md. Since no cleanout occurred and you believe it is likely that the non-lined hole section below the shoe will collapse, PBTD should be 10320' md, 594T tvd. I will make this change to the PBTD on the 407. Call or message with any questions. Tom Maunder, PE AOGCC 7/29/2008 STATE OF ALASKA ~~ `- ALASKA OIL AND GAS CONSERVATION COMMISSION Y ~~~ ~ ~ 2008 WELL COMPLETION OR RECOMPLETION REPORT AND L1~~~~ ~i! ~ ~~~ ~~~~ COmr~E~S-On AP1>~hnrarra 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.,05 zoAac z5.,,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 Aband. 05/20/2008 ~ 12. Permit to Drill Number 208-043 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 5!6/2008 - 13. API Number 50-029-21502-60-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 5/11/2008 ~ 14. Well Name and Number: Kuparuk 3F-16AL1 82 FSL, 227 FEL, SEC. 19, T12N, R09E, UM Top of Productive Horizon: 4016' FSL, 3145' FEL, SEC. 19, T12N, R09E, UM 8. KB (ft above MSL): 88' Ground (ft MSL): 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 2776' FSL, 4085' FEL, SEC. 19, T12N, R09E, UM 9. Plug Back Depth (MD+ D) ~ -~ 6' S' ~~ .,~ River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 508273 y- 5985905 Zone- ASP4 10. Total Depth (MD+TVD) ~''`lri, 10626' 5955' 7-t 16. Property Designation: ADL 025632 TPI: x- 505337 y_ 5989836 Zone- ASP4 Total Depth: x- 504402 y- 5988596 Zone- ASP4 11. SSSV Depth (MD+TVD) None 7. 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): 1465' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed i ormation per 2 AAC 25.071): MWD DIR, RES, GR /it/,QOIJ ~~0?6 MQ SXdr~TYd 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING:DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP -'- :BOTTOM SIZE CEMENTING RECORD PULLED 2-7/8" 6.16# L-80 8712' 10320' 6064' 5947' 4-1/8" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-718" Slotted Section Note: 4-1/2", 12.75#, L-80 6838' 6814' MD TVD MD TVD 8723' - 10318' 6062' - 5947 Well Branch Well Branch 3F-16AL1 3F-16AL1 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. Departs From Is not Directly DEPTH INTERVAL MD AMOUNT Se KIND OF MATERIAL USED Well Branch Accessible 3F 16AL1 01 8226' Set Flow-Through Whipstock (Top of Window) - - , PTD # 208-044, at 8712' MD ' (6398 TVD) 26. PRODUCTION TEST Date First Production: Reported on 3F-16AL1-01 Method of Operation (Flowing, Gas Lift, etc.): See 3F-16AL1-01 10-407 (Dated 06/18/08, PTD # 208-044) Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: 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 GRAVITV-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^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. ~a,.,~,,~._....... None B' ,$~v~ 0 ~~~ Form 10-407 Revised 02/2007 ~~ ir~ ~R ~ ~ ` ~~ ~TINUED ON REVERSE SIDE ~ ~~U i~` ~ ~ ~ODO ~l~/~~ ~` 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND _RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ 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 A2 8268' 6065' None Top Kuparuk A2 (Inverted) / 9632' 6007' Base Kuparuk A3 Base Kuparuk A3 / 10458' 5946' Top Kuparuk A2 Formation at Total Depth (Name): Top Kuparuk A2 10458' 5946' 30. List of Attachments:. Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. r O l0 ~~ Si d gne Terrie Hubble Title Drilling Technologist Date Kuparuk 3F-16AL1 208-043 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Gary Eller, 263-4172 (Office) Permit No. / A royal No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IrEM 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). ITEM 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. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a 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 25.07E Form 10-407 Revised 02/2007 Submit Original Only c Well Events, Pre-CTD Rig DATE SUMMARY OPS 12/18/07 TAGGED BOTTOM C~ 8289' SLM. EST 3' OF RATHOLE. PERFORMED 30 MIN SBHPS AT 8230' RKB=4006 PSI, 119 DEG F. 15 MIN GRADIENT STOP MADE C~1 8099'. JOB COMPLETE. 1/19/08 (PRE-CTD PREP) T & IC POT/PPPOT -PASSED, MITIA & OA -PASSED, PT/DD MASTER, SWAB & WING -PASSED. 2/18/08 PERFORMED 30 MIN SBHPS C«~ 8265' COR RKB=3955 PSI, 112 DEG F. GRADIENT STOP MADE C 8134'. JOB COMPLETE. 4/3/08 DRIFTED TBG TO 3.70" C~3 8295' RKB. LOGGED CALIPER SURVEY FROM 8295' RKB TO SURFACE. WILL RETURN FOR SBHP. 4/6/08 PERFORMED SBHPS: AT 8214 FT, 3901-PSI AND 132-DEG F; AT 8100 FT, 3858-PSI AND 137-DEG F. NEXT, ORIENTED WHIPSTOCK: SET TOP OF TRAY AT 8227' ~^ nFrRF~c LEFT OF H~aH SIDE. DID NOT GO DOWN TO TD DUE TO PULLING WEIGHT AT 8235'. 4/12/08 MILLED DB NIPPLE TO 3.80 @ 7843 CTMD. WELL IS FREEZE PROTECTED. READY FOR BPV. BP AMERICA Page 1 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date' From - To Hours Task ~ Code ~ IUPT Phase Description of Operations 5/3/2008 00:00 - 00:30 0.50 MOB P PRE Finish clean up 1 R-01 location and perform Post Pad inspection w/ DSO Premove safety mtg 00:30 - 02:00 1.50 MOB P PRE Move rig off Pad and head to 1 G Pad. Using blade and blower services (GPB is in Level 2 conditions 20+ mph wind w/drifting snow) 02:00 - 03:15 1.25 MOB P PRE Move from 1 G to Spine Road 03:15 - 04:45 1.50 MOB P PRE Move down the Spine Road to the Drilling Toolhouse Pad and park 04:45 - 07:15 2.50 MOB N WAIT PRE Wait for Field crew change Kuparuk announce Phz 2 conditions Fieldwide 07:15 - 11:30 4.25 MOB P PRE Continue moving from Drilling Tool House to 3F. On location at 1130 hrs. 11:30 - 15:30 4.00 MOB P PRE Inspect pad with DSO. Place herculite and spot mats. Bleed gaslift line and shut in adjacent well. Remove hand rails from off driller side adjacent wellhouse. Spot rig over well and set down. Dial in comms on rig. Acce t ri at 1.530 hrs on.513/08.~„. 15:30 - 16:30 1.00 RIGU P PRE Continue to rig up. Spot tanks. Run hard line. MU handi berm around cellar. Work on ESD for adjacent producer. 16:30 - 23:30 7 00 BOPSU P PRE N 7-1/16" BOPs on 4-1/16" tree. E r ___ . safe win valve alread in _ -- - 23:30 - 00:00 0.50 BOPSU P PRE Te t AOGCC waived their right to witness the test 5/4/2008 00:00 - 02:00 2.00 BOPSU P PRE BOPE test Kuparuk still Phz 2 due to blowing/drifting snow 02:00 - 03:45 1.75 BOPSU N HMAN PRE 2-3/8" combis would not test 03:45 - 06:00 2.25 BOPSU P PRE Resume BOP test 06:00 - 08:00 2.00 BOPSU P PRE Crew change. Hold PJSM to discuss testing plan. Test MDP equipment . 08:00 - 10:15 2.25 RIGU P PRE Hold PJSM with crew to review stabbing coil and slack management. Test grapple and pull 2-3/8" coil from reel and through injector. 10:15 - 11:00 0.75 RIGU P PRE Check a-line properties. Line test ok. 11:00 - 12:30 1.50 RIGU P PRE Fill coil with seawater. Pressure test inner reel valve to 250 and 4000 psi. Held ok. 12:30 - 13:45 1.25 RIGU P PRE Reverse circ reel to move a-line. Cut 18' of coil to find a-line. 13:45 - 16:00 2.25 RIGU P PRE MU Kendal connector. Pull test to 35k#. MU a-line connections. Pressure test to 3500 psi. 16:00 - 17:30 1.50 BOPSU N WAIT PRE Wait on Kuparuk Wells Group BPV lubricator 17:30 - 22:15 4.75 BOPSU P PRE Hold PJSM to review using BPV lubricator. Bring tools up to rig floor Hold PJSM after crew change for fresh Nordic crew. Fin RU stem and pulling tool. Attempt to PT lub. Find frozen choke line-thaw (3/4 hr). PT lub at 2500 psi against MV. PuII BPS/ and find 1590 si on w I re. RD BPV pulling tools and load out 22:15 - 22:45 0.50 KILL P WEXIT PreSpud mtg TL meeting Safety mtg re: MU BHA 22:45 - 00:00 1.25 KILL P WEXIT MU 3" nozzle BHA w/ DPS (26.73' OAL). Add 3' and 4' lubs to cover. Equalize to whp 1590 psi BP AMERICA Page 2 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: i Date I From - To Hours Task ~ Code NPT Phase Description of Operations 5/5/2008 100:00 - 00:35 0.58 KILL P WEXIT RIH w/ BHA #1 circ 0.48/1720 w/ well SI w/ 1600 psi IA 23, OA 17 Phz 2 00:35 - 02:00 1.42 KILL P WEXIT Open up to take returns at 2700' 0.50/2010 w/ 1970 psi whp. Mostly gas. Red whp to 1650 psi by 5000' 02:00 - 02:35 0.58 KILL P WEXIT Park at 8200' after pumping 120 bbls SW at 1.53/2340 w/ 1640 psi whp w/ 13.6 ECD and still have gas w/ 40 psi downstream press Incr rate to 2.47/3600 w/ 1650 psi whp=13.76 ECD Bleed down IA from 660 psi to 100 psi 02:35 -.02:55 0.33 KILL P WEXIT Swap to pump #2 due to pod leaks. Swap to 10.0# used FloPro 2.0/3000 w/ 1650 psi whp and 14.17 ECD w/ 40 psi downstream gas. With 18 bbls before mud at nozzle, finally started getting fluid returns w/ 8.2 ppg density and ECD at 14.25 ppg. Assume wellbore is full of SW 02:55 - 03:40 0.75 KILL P WEXIT SD pump, SI at choke. Monitor DHP for 40 min and final DHP=3964 (12.88 ECD) psi and falling slowly 03:40 - 04:50 1.17 KILL P WEXIT Bullhead mud to nozzle 1.0/2110 and inject 10 bbls w/ max 1700 psi whp. Check out pump #1 and pod still leaks. Work on pumps. Circ 1.10/0.60/2380 w/ 1600 psi whp and return density at 8.35 ppg. Circ 1.10/0.93/2300 w/ 1500 psi whp w/ 8.58 ppg density (13.88 ECD). Circ 1.12/0.88/2290 w/ 1400 psi whp (13.86 ECD). Circ 1.12/0.88/2330 w/ 1300 psi whp (13.84 ECD). Pumps fixed 04:50 - 06:00 1.17 KILL P WEXIT POOH circ 2.0/3200 holding 1000 psi whp while fin displace wellbore to 10.0 ppg mud 06:00 - 08:00 2.00 KILL P WEXIT Tag up with nozzle. Shut in we11.1050 psi WHP. Crew change. Hold PJSM to discuss getting off the well. Get off well. Verify deployment space out while handling BHA. 08:00 - 08:45 0.75 STWHIP P WEXIT MU Inteq BHA. Check tools. Rig up floor for pressure deployment. 08:45 - 10:00 1.25 STWHIP P WEXIT Hold PJSM with crew to review entire 3" pressure deployment procedure. Discuss specific hazards, assignments, communications and more. Also discuss picking up BTT tools. 10:00 - 13:45 3.75 STWHIP P WEXIT Pressure de l0 3" Inte window millin BHA with 3.80" i mond s eed mill. 805 psi WHP 13:45 - 14:15 0.50 STWHIP P WEXIT Run in hole. Maintain 900 psi WHP while circ at min rate. 14:15 - 15:15 1.00 STWHIP P WEXIT Log gr tie in from 7900'. Subtracr 24' correction. 15:15 - 18:00 2.75 STWHIP P WEXIT Ta whi stock at 8226'. Begin time milling. 0.1' per 6 minutes. 3475 psi fs at 2.2 in/out. 100-200 psi mtr wrk. Increasing DHWOB. PVT: 160 active. Some weight stacking noted. Slow time drilling rate to control DHWOB. Mill to 8228'.3 PVT 78 18:00 - 22:00 4.00 STWHIP P WEXIT Mill from 8228.3' 2.19/2.18/3400 w/ 600 psi whp w/ 3995 psi dhp=12.98 ECD w/ 50-100 psi dill, 1.0-2.5k wob. Stall at 8231.2' PVT 77 Phz 2 Fieldwide except CPF2 is Phz 3 Bleed OA from 540 to 100 psi 22:00 - 00:00 2.00 STWHIP P WEXIT Mill from 8231.2' 2.21/2.19/3400 w/ 600 psi whp w/ 3994 psi rnrneu: wiwavo c.w.Y~ rm r ~ BP AMERICA Page 3 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 ,Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 !,Rig Name: NORDIC 2 Rig Number: Date i From - To ~ Hours Task Code NPT Phase Description of Operations 5/5/2008 22:00 - 00:00 2.00 STWHIP P ~ WEXIT dhp=12.97 ECD. Mill to 8233.2' PVT 75 5/6/2008 00:00 - 03:40 3.67 STWHIP P WEXIT Mill window from 8233.2' 2.20/2.18/3350 w/ 600 psi whp w/ 03:40 - 04:30 0.83 STWHIP P 04:30 - 05:20 0.83 STWHIP P 05:20 - 06:05 0.75 ~ STWHIPI P 06:05 - 07:45 1.671 STWHIP~ P 07:45 - 09:00 1.25 STWHIP P 09:00 - 10:30 1.50 DRILL P 10:30 - 11:45 1.251 DRILL I P 11:45 - 14:00 I 2.251 DRILL I P 14:00 - 14:20 0.33 DRILL P 14:20 - 16:10 1.83 DRILL P 16:10 - 18:00 I 1.831 DRILL I P 18:00 - 21:00 3.00 DRILL P 21:00 - 00:00 3.00 DRILL P 5/7/2008 ~ 00:00 - 02:00 I 2.001 DRILL I P 02:00 - 02:15 0.25 DRILL P 02:15 - 04:20 2.08 DRILL P 4019 psi dhp=13.04 ECD. Did not see BOW, but assume it was no deeper than 8235'. Drill open hole to 8245' PVT 71 WEXIT Backream and ream window area and was clean. Start 50 bbl i-vis pill of 10.0# Flo Pro WEXIT Ream window area while finish pumping pill 2.5/3860. Follow pill w/ 13.05# (MM density) K-Formate mud. Find out that vac truck had 50 bbls less than planned WEXIT K-Formate at mill 1.48/2000 w/ 500 psi whp 4010 psi dhp=13.07 ECD. Stay parked at 8220' while circ in rest of K-formate (will lose less that way) maintaining dhp at 4000-4020 psi (13.0-13.1 ECD) WEXIT POOH for build assy circ K-Formate 1.0/1300. 13.0 ppg formate to surface. Running short on KWF. Begin to displace coil to 10.0 ppg flopro. WEXIT At surface. Verify 13.0 KWF back to surface. Hold PJSM to discuss getting off well with milling BHA. Well is stable, no flow. LD Inteq tools. Mill is 3.80" go, 3.79" no go. PROD1 MU Inteq tools for drilling build assembly. 2.8" deg mtr with new HTC 4-1/8" bicenter bit. Displace coil to KWF. PROD1 Deploy BHA with lubricator and slickline. BHA bounced through the BOP stack and reached the proper deployment depth. Pulled BHA back out with no problem. Stab coil. Test MWD tools. Get on well. PROD1 Fill hole with 2 bbls KWF. Run in hole with EDC open. Mix hi vis 10.0 ppg flopro pill for displacement.' PROD1 Log tie-in at 7890', corr -26' KRU is Phz 2/3. Only CPF3 is Phz 2 PROD1 RIH to 8200' while begin displacement back to 10.0# Flo Pro mud. Start out at 1.24/1.14/1170 while maintain 4000 psi dhp to avoid excessive loss of Formate mud (displaced the 58 bbl CT volume at this rate). Increased rate to 2.3 bpm and apply whp to keep whp at 4000 psi. Swap to pits at close to planned displacement. Recovered -200 bbls. Close EDC PROD1 RIH thru window. clean. Taa at 8245'. Start pump and drill build from 8245' w/ 2.3/3400/10L w/ 600 psi whp and maintain 4000 psi dhp=13.0 ECD w/ 1/1 returns. Drill to 8265' at 10-15'/hr w/ a few stalls getting started PRODi Drill from 8265' 2.31/3450/10L w/ 100-250 psi dill, 1.0-2.Ok wob w/ 600 psi whp w/ 4050 psi dhp=13.14 ECD PROD1 Drill from 8300' 2.50/3600/15L w/ 100-250 psi dill, 0.5-1.8k wob w/ 520 psi whp w/ 4010 psi dhp=13.00 ECD Increase pump rate & stack more WOB. PROD1 Continue to drill build section from 8350' 2.50/3750/15L w/ 100-250 psi dill, 0.9-1.8k wob w/ 550 psi whp w/ 4050 psi dhp=13.00 ECD. ROP = 15-20ft/hr. Drill to 8400ft. Bleed off IA & OA from 500 psi to 100psi. PROD1 Wiper trip to window -clean. Wiper to TD -clean. PROD1 Drill build section from 8400' 2.50/3750/30L w/ 100-250 psi dill, rnniea: wiaa~a cvrvi rm r • BP AMERICA Page 4 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours j Task Code NPT Phase Description of Operations 15/7/2008 102:15 - 04:20 I 2.081 DRILL P 04:20 - 05:50 1.501 DRILL P 05:50 - 06:20 0.50 DRILL P 06:20 - 08:40 2.33 DRILL P 08:40 - 09:35 0.921 DRILL P 09:35 - 10:10 0.58 DRILL P 10:10 - 10:35 0.42 DRILL P 10:35 - 12:00 1.42 DRILL P 12:00 - 13:00 1.00 DRILL P 13:00 - 15:45 2.751 DRILL P 15:45 - 17:30 1.75 DRILL P 17:30 - 17:40 0.17 DRILL P 17:40 - 18:10 0.50 DRILL P 18:10 - 18:35 0.42 DRILL P 18:35 - 21:25 2.83 DRILL P 21:25 - 23:00 1.58 DRILL P 23:00 - 23:25 0.42 DRILL P 23:25 - 23:35 0.17 DRILL P 23:35 - 23:45 0.17 DRILL P 23:45 - 00:00 0.25 DRILL P 5/8/2008 100:00 - 04:00 I 4.00 DRILL ~ P PROD1 0.9-2.4k wob w/ 550 psi whp w/ 4050 psi dhp=13.00 ECD ROP = 20-30 fUhr. Slowly begin turning & building at 8400ft. Landed build section at 98 degrees - 8475ft. PROD1 Drill turn section from 8475' 2.50/3750/90L w/ 100-250 psi dill, 1.9-2.9k wob w/ 550 psi whp w/ 4075 psi dhp=13.00 ECD ROP = 30-50 Whr. PROD1 Wiper to window, CT WT = 23k & clean to window. Wiper to TD - PROD1 Drill from 8550' 2.5/3750/85L w/ 150-250 psi dill, 1.15-2.50k wob w/ 550 psi whp giving 4094 psi dhp=13.12 ECD. Drill to 8641' PROD1 Wiper while geo's determine where we are-appear to be structurally higher than planned, but may be in a new fault area. Have good control points further out so will stick to plan PROD1 Drill from 8641' to end of turn at 8665' PVT 214 PROD1 Wiper to window 23k 2.51/3700 w/ 550 psi whp/4040 psi dhp. Pull thru window, clean. Open EDC PVT 212 PROD1 POOH circ thru EDC 2.62/3460 following pressure schedule PVT 166 PROD1 Park at 200' to close EDC and Swaco choke was leaking by. Clear choke Close EDC, pull to surface. Maintain 900 psi whp pumping down CT Safety mtg re: pressure undeploy 2.8 deg motor assy. Review/revise procedure for MPD since this is first go round for undeploy big tools SWS crew change out PROD1 A tivate MPD circ loo s ~i who Pressure undeploy BHA PROD1 BHI reconfigure BHA for lateral section Replace broken spring on shaker and shaker screens PROD1 Safety mtg re: MU BHA PROD1 MU lateral drilling assy in two sections. Add additional lubricator to cover res tool. Double check measurements for PU tools inside lubricator. PROD1 C/O w/day crew. Perform walk around & spill champion. PJSM regarding pressure deploying BHA. PROD1 Pressure deploy lateral BHA. Use 36's to double check torque on HOT by motor connection -good. Inspect CTC -good. Set depths. PROD1 RIH following pressure schedule. PROD1 Log down for tie-in from 7900ft (-20ft corr. PROD1 Continue to RIH following pressure schedule. PROD1 Wiper to TD -Clean. PROD1 Drill invert from 8668'. 3980 psi fs at 2.51 in/out. 100-200 psi mtr wrk. 1.5-2.5k# DHWOB. WHP/BHP/ECD: 550/4090/13.14 ppg. INClrF: 99/80 LHS. ROP: 20-40 fph. Drill to 8673'. PROD1 Continue to drill invert from 8673ft. rnmea: aioizooa z:~rvi rm ~ ~ BP AMERICA Operations Summary Report Page5of17~ Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours I Task Code NPT ~ Phase j Description of Operations 5/8/2008 ~ 00:00 - 04:00 ~ 4.00 ~ DRILL ~ P ~ ~ PROD1 04:00 - 04:10 0.17 DRILL P PROD1 04:10 - 05:35 1.42 DRILL P PROD1 05:35 - 05:40 0.08 DRILL P PROD1 05:40 - 05:55 0.25 DRILL P PROD1 05:55 - 06:05 0.17 DRILL P PRODi 06:05 - 06:20 0.25 DRILL P PRODi 06:20 - 06:35 0.25 DRILL P PROD1 06:35 - 08:15 1.67 DRILL P PROD1 08:15 - 09:00 0.75 DRILL P PROD1 09:00 - 10:55 1.92 DRILL P PROD1 10:55 - 11:55 ~ 1.00 ~ DRILL ~ P ~ ~ PROD1 11:55 - 13:45 I 1.831 DRILL I P I PROD1 13:45 - 14:15 0.50 DRILL P PROD1 14:15 - 14:25 0.17 DRILL P PROD1 14:25 - 15:00 0.58 DRILL P PROD1 15:00 - 16:20 1.33 DRILL P PROD1 16:20 - 17:35 1.25 DRILL P PROD1 17:35 - 19:30 1.92 DRILL P PROD1 19:30 - 21:20 ~ 1.83 ~ DRILL ~ P ~ ~ PRODi 21:20 - 23:05 ~ 1.75 ~ DRILL ~ P ~ ~ PROD1 3980 psi fs at 2.51 in/out. 100-200 psi mtr wrk. 1.5-2.5k# DHWOB. WHP/BHP/ECD: 550-450/4090/13.14 ppg. INClfF: 99/80-90 LHS. ROP: 20-50 fph. Drill to 8825ft. Bring on 290bb1s of used mud & discard 100bb1s. Wiper upto 8680ft. MAD pass up from 8680ft to 8227ft ~ 300ft/hr, pumping 2.5bpm/3900psi. Turn on centrifuge 'A'. 3k overpull at 8500ft while MAD passing up. Stop logging at 8260ft. PUH to 7900ft. Log down for tie-in from 7915ft (+1 ft corr. RIH to 8260ft. Log down from 8260ft to capture RA tag in whipstock. Revised depths TOWS/TOW 8226' RA Marker 8234.6' BOWS 8235' Wiper to TD PVT 311 Drill from 8825' 2.49/3960/130L w/ 100-250 psi dill, 1.5-3.Ok wob w/ 475 psi whp to give 4049 psi dhp=13.06 ECD. Begin to level out in the A2 at 93 deg. Drill to 8950' PVT 313 W iper to window was clean both ways PVT 308 Drill from 8950' 2.41/3900/95L w/ 100-250 psi dill, 1.5-3.Ok wob w/ 500 psi whp to give 4088 psi dhp=13.20 ECD and level out at 90 deg in the A2 looking for a fault. ROP is 70-90'/hr. Drill to 9100' PVT 307 W iper to window was clean both directions Logged 15' of missing res data at 8950' PVT 303 Drill from .9100' 2.40/3840/95L w/ 100-250 psi dill, 1.5-3.Ok wob w/ 525 psi whp to give 4085 psi dhp=13.21 ECD at 88 deg w/ ROP 80-110'/hr Swap to right at 9155'. Drill to 9250' Wiper to window was clean Log tie-in to GR marker in WS at 8234.6'. Corr +2' W iper to TD was clean Drill from 9250' 2.38/3840/758 w/ 100-250 psi dill, 2.0-3.5k wob w/ 525 psi whp to give 4100 psi dhp=13.27 ECD at 91 deg at 80-120'/hr. Swap to left at 9340' and begin invert. Drill to 9400' W iper to window was clean both directions except for set down at TF change at 9280' Drill from 9400' 2.42/3840/85L w/ 100-250 psi dill, 1.6-3.Ok wob w/ 500 psi whp to give 4087 psi dhp=13.22 ECD at 94 deg at 100'/hr. Cross close approach to parent wellbore. Drill to 9550ft. Wiper to window. 3k overpull at 9520ft, otherwise clean. Wiper ,through build section with reduce rate & increased WHP. Increase rate past build section. Wt bobble at 9280ft, otherwise clean. Drill invert from 9549ft. 3980 psi fs at 2.41 in/out. 100-200 psi mtr wrk. 1.8-2.5k# DHWOB. ~ • BP AMERICA Page 6 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT Phase ~ Description of Operations 5/8/2008 21:20 - 23:05 1.75 DRILL P PROD1 WHP/BHP/ECD: 500/4080/13.24 ppg. INC/TF: 100/80-90 LHS. ROP: 60-110 fph. Drill to 9700ft. ***NOTE*** Flo-Pro has slowly changed color to a brown /light black color. 23:05 - 00:00 0.92 DRILL P PROD1 Wiper to window, clean so far. 5/9/2008 00:00 - 00:05 0.08 DRILL P PRODi Continue to wiper to window -clean. 00:05 - 00:10 0.08 DRILL P PROD1 Log down for-in from 8260ft (+3ft corr. 00:10 - 01:00 0.83 DRILL P PROD1 Wiper through build section with reduce rate & increased WHP. Increase rate past build section. Start pumping new Flo-Pro down hole. 01:00 - 02:45 1.75 DRILL P PROD1 Drill invert from 9700ft. 4000 psi fs at 2.41 in/out. 100-200 psi mtr wrk. 1.6-2.2k# DHWOB. WHP/BHP/ECD: 500/4095/13.32 ppg. INClTF: 100/90-100 LHS. ROP: 60-110 fph. Drill to 9850ft 02:45 - 03:50 1.08 DRILL P PROD1 Wiper to window -clean. 03:50 - 04:30 0.67 DRILL P PROD1 Wiper through build section with reduce rate & increased WHP. Increase rate past build section. 04:30 - 06:05 1.58 DRILL P PROD1 Drill invert from 9847ft. 4300 psi fs at 2.38 in/out. 200-400 psi mtr wrk. 1.9-2.4k# DHWOB. -3k to -8k SWOB WHP/BHP/ECD: 500/4140/13.53 ppg. INC/TF: 100/90-115 LHS. ROP: 80-110 fph. Drill to 9970' and stacking due to TF change in progress from L to R via HS 06:05 - 06:20 0.25 DRILL P PROD1 BHA wiper and have trouble getting back to bottom. Once on bottom had sticky pickups. PVT 270 06:20 - 07:25 1.08 DRILL P PROD1 Wiper to window was clean 07:25 - 07:35 0.17 DRILL P PRODi Log tie-in, corr +5' 07:35 - 08:45 1.17 DRILL P PROD1 Slow wiper to TD while work on pump #2 swabs was clean to 9920' 08:45 - 09:00 0.25 DRILL P PROD1 Set down at 9920' was TF related. Get back to TD at 9970' using DTF, but last 15' lost a lot of wt PVT 264 09:00 - 09:30 0.50 DRILL P PROD1 Need to swap to right side, but stops on orientor are in bad spot. Drill ahead slow while orient around to right stop using LS. Drill w/ -8 to -12k surface wt 9970-9978'. PU clean. Orient to right side via HS. Ream back to TD 2.30/4050 09:30 - 10:40 1.17 DRILL P PROD1 Drill from 9978' 2.32/4050/908 slowly while getting BHA to slide thru TF change area. Drill ahead to 9995' and spend some time doing slow back/ream to 9930' to straighten out the TF change before drilling ahead 10:40 - 12:30 1.83 DRILL P PROD1 Drill from 9995' 2.31/4000/708. Becoming increasingly sticky w/ OP's to 20k. Frequent BHA wipers to above 9940' which is the start of a shale. Geo's feel we may be in A5/A6 or B Shales. Turn TF down at 10020' and target 87 deg while drill to 10054' 5851' TV .Determine we are too high at this point and will have too much shale open if we continue back down, so decide that a sidetrack i n 12:30 - 13:40 1.17 DRILL P PROD1 Wiper to window was clean. Pull thru window, clean. Open EDC PVT 253 rnntea: onazuuu cunai rnn • r -BP AMERICA Page 7 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NI'T Phase_ Description of Operations 5/9/2008 13:40 - 15:10 1.50 DRILL P PROD1 POOH circ thru EDC 2.5/3800 following pressure schedule PVT 212 15:10 - 17:00 1.83 DRILL P PROD1 Pressure undeploy using 900 psi MPD loop 17:00 - 18:00 1.00 DRILL P PROD1 LD lateral assy. Remove resistivity & reconfigure tools string. Slip & cut slickline & rehead, pull test same. Little jerk supply hose failed due to probable age. 18:00 - 19:00 1.00 DRILL P PROD1 C/O with day crew. Perform walk around & fill out spill champion paperwork. PJSM regarding pressure deploying sidetrack BHA. 19:00 - 21:40 2.67 DRILL P PROD1 Pressure deploy sidetrack BHA. Power up & test tools. Set depths. Clean high pressure filter - 1/2 cup of debris however, the filter is not eroded. 21:40 - 23:15 1.58 STKOH P PRODi RIH following pressure schedule. 23:15 - 23:30 0.25 STKOH P PROD1 Log down for tie-in 8250ft (-22.5ft corr. 23:30 - 00:00 0.50 STKOH P PROD1 Continue to RIH following pressure schedule. Pump 0.4bpm while RIH. 5/10/2008 00:00 - 00:50 0.83 STKOH P PROD1 Continue RIH. Set down at 10,030ft. Start pumping, stall.. PU 10k overpull. PU to 9960ft. RIH, 300psi motor work -brass cap is off. 00:50 - 03:20 2.50 STKOH P PROD1 2.32bpm/4100psU13.29ECD/475W H P. 03:20 - 04:10 0.83 STKOH P PROD1 Time drill OHST from 9775ft, 0.1ft/6min for the first 1.5ft. 2.28bpm/3960psi/13.31 ECD/465WHP. Stacking out at surface & no WOB. 04:10 - 05:40 1.50 STKOH P PRODi PU 10ft. RIH to 9775ft & let drill off for 6 min. Repeat same j process but 0.1ft deeper each time. Drill to 9776ft using this process. 05:40 - 06:15 0.58 STKOH P PROD1 PU 10ft. RIH to 9776ft & drill as slow as possible - 0.2ft/min to prevent stacking at surface. Slowly increase ROP at 9782ft. Drill to 9800' 06:15 - 07:35 1.33 STKOH P PRODi Backream/ream 9750-9800' 45 deg both sides of DTF 07:35 - 08:30 0.92 STKOH P PROD1 Wiper to window was clean. Open EDC PVT 225 08:30 - 10:10 1.67 STKOH P PROD1 POOH circ thru EDC PVT 179 10:10 - 12:00 1.83 STKOH P PRODi Pressure undeploy using 900 psi on MPD loop 12:00 - 12:30 0.50 STKOH P PROD1 LD sidetrack BHA 12:30 - 14:00 1.50 DRILL P PRODi BHI reconfigure BHA to lateral assy SWS replace packoff and check injector chains Function test BOPE 14:00 - 14:15 0.25 DRILL P PROD1 Safety mtg re: pressure deploy 14:15 - 17:10 2.92 DRILL P PROD1 MU lateral BHA w/ 1.1 deg motor and agitator Pressure deploy using 900 psi on MPD loop 17:10 - 18:50 1.67 DRILL P PROD1 RIH w/ BHA #6 circ thru bit 0.30/940 while follow pressure schedule 18:50 - 19:20 0.50 DRILL P PROD1 Log down for tie-in (-22ft corr. Out MM is reading 9.75ppg. Mud scales read the same. Will check mud for less/extra salt content. 19:20 - 20:00 0.67 DRILL P PRODi Wiper to TD. 2bpm/4100psi. 20:00 - 20:35 0.58 DRILL P PROD1 Backream through OHST area. 2.OObpm/3950psi. Bottom's up revealed a slight gas bubble. 20:35 - 22:55 2.33 DRILL P PROD1 Drill invert from 9802ft. 4120 psi fs at 2.1 in/out. 200-400 psi mtr wrk. 1.2-1.9k# DHWOB. 1 k SWOB WHP/BHP/ECD: 500/4085/13.33 ppg. ~ ~ Operations Summary Report Page 8 of 17 ~ Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date I From - To Hours Task Code j NPT Phase Description of Operations 5/10/2008 20:35 - 22:55 2.33 DRILL P 22:55 - 00:00 1.08 DRILL P 5/11/2008 00:00 - 00:55 0.92 DRILL P 00:55 - 02:35 1.67 DRILL P 02:35 - 04:50 2.25 DRILL P 04:50 - 05:30 0.67 DRILL P 05:30 - 05:40 0.17 DRILL P 05:40 - 06:25 0.75 DRILL P 06:25 - 07:40 1.25 DRILL P 07:40 - 07:55 0.25 DRILL P 07:55 - 09:05 1.17 DRILL P 09:05 - 10:30 1.42 DRILL P 10:30 - 11:20 0.831 DRILL I P 11:20 - 13:45 2.42 DRILL P 13:45 - 15:40 1.92 DRILL P 15:40 - 17:00 I 1.331 DRILL I P 17:00 - 18:30 1.501 DRILL I P BP AMERICA PROD1 INClrF: 96/90-105 LHS. ROP: 60-110 fph. Turn on 'A' centrifuge. After 2 bottom's up, getting slight gas? Increase WHP to 600psU42006HP. Turn on gun lines. Pump 25bb1 new flo-pro pill out of pit #4. Drilling has slowed down & 10k overpulls, & hard to get to bottom. Big improvement in drilling w/ the pill. Drill to 9943ft. PROD1 Wiper to window, 3k overpull at 9812ft, otherwise clean. PROD1 Wiper to TD -clean. PROD1 Drill invert from 9939ft. 4200 psi fs at 2.1 in/out. 200-400 psi mtr wrk. 1.2-1.9k# DHWOB. -8k SWOB WHP/BHP/ECD: 500/4098/13.41 ppg. INC/TF: 92/60-90 LHS. ROP: 60-110 fph. Drill to 10100ft. PROD1 Wiper to window, overpull at 9812ft. Wiper to TD -clean. PROD1 Drill invert from 10101ft. 4130 psi fs at 2.1 in/out. 200-400 psi mtr wrk. 1.2-2.6k# DHWOB. -Sk SWOB WHP/BHP/ECD: 500/4100/13.43 ppg. INC/TF: 98/60-90 LHS. ROP: 25-100 fph. Drill to 10150ft. 35k overpull off bottom. PROD1 BHA wiper trip. PROD1 Drill invert from 10150ft. 4130 psi fs at 2.1 in/out. 200-400 psi mtr wrk. 1.8-2.4k# DHWOB. -9k SWOB WHP/BHP/ECD: 500/4100/13.43 ppg. INC/TF: 98/60-90 LHS. ROP: 25-100 fph. Drill to 10200' PVT 172 PROD1 Wiper to window 2.1/4000 w/ 5k OP ~ 9810' and 9260'. See 200 psi CTP loss at 8665' (end of bicenter run) PROD1 Log tie-in to RA marker at 8234.6', Corr +10' PVT 155 PROD1 Wiper back to TD w/ wt loss at 9810-30' and 9460' PROD1 Drill from tag at 10210' 2.1/4030/90L w/ 100-300 psi dill, 1.0-3.Ok wob w/ 475 psi whp to give 4100 psi dhp=13.45 ECD at 95 deg. Drilling w/ -6k to -9k surface wt 60-100'/hr. Drill to 10229' (5865' TVD) and have dill sticking. 60' wiper and needed -12k string wt to get back to TD. Begin swap to fresh mud PROD1 Drill from 10288' 2.0/4000/80L w/ 100-300 psi dirt, 1.3-2.5k wob w/ -8 to -10k surface wt w/ 475 psi whp to give 4064 psi dhp=13.35 ECD at 94 deg. Drill to 10350' and wellbore is swapped to fresh mud PROD1 Wiper to window was clean both directions PROD1 Drill from 10350' 2.03/3950/110L w/ 100-300 psi dill, 1.5-3.Ok wob w/ -6.5k to -10k surface wt w/ 475 psi whp to give 4070 psi dhp=13.36 ECD at 94 deg. Begin slow drop to cross-cut to TD at revised 10800' PVT 204 PRODi Drill from 10420' 2.11/4000/110L w/ 100-300 psi dill, w/ 0.5-2.5k wob w/ -8k to -13k surface wt w/ 450 psi whp to give 4030 psi dhp=13.25 ECD at 91 deg. Getting differentially sticky again w/ 25k OP's due to the 'hump'. Drill to 10475' and have 87 deg at bit PVT 204 PROD1 Wiper to window -clean. ~ ~ BP AMERICA Page 9 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: i Date i From - To Hours Task Code NPT Phase Description of Operations 5/11/2008 18:30 - 18:45 0.25 DRILL P PROD1 Log tie-in to RA marker at 8234.6', Corr +4.5ft 18:45 - 19:30 0.75 DRILL P PROD1 Wiper to TD, 3k wt bobble at 9827ft. PVT 201 at TD. 19:30 - 21:55 2.42 DRILL P PROD1 Drill invert from 10478ft. 4100 psi fs at 2.1 in/out. 200-400 psi mtr wrk. 1.8-2.2k# DHWOB. -6k SWOB WHP/BHP/ECD: 500/40800/13.41 ppg. INC/TF: 93/60-90 LHS. ROP: 50-125 fph. Drill to TD at 10625ft PVT 198 21:55 - 00:00 2.08 DRILL P PROD1 Wiper to window, overpull at 10480ft. 20k overpull at 9277ft. Pull up through window. BHP = 3966psi, WHP = 700psi, ECD = 12.94ppg. Open EDC & pump 2.75/3900psi while slowly PUH to jet 4-1/2" tubing. 5/12/2008 00:00 - 00:25 0.42 DRILL P PROD1 Continue to pump 2.75/3900psi while slowly PUH to jet 4-1/2" tubing. 00:25 - 00:45 0.33 DRILL P PROD1 Wiper to 7910ft. 00:45 - 00:55 0.17 DRILL P PROD1 Log down for tie-in (+3ft corr. 00:55 - 02:20 1.42 DRILL P PROD1 Wiper while pumping 2.75/3900psi while slowly RIH to jet 4-1 /2" tubing. Stop at 8200ft & close EDC. Continue to wiper to TD. Start pumping 100k LSRV liner pill w/ 2ppb Alpine beads while wipering in hole. Set down at 10500ft, work till clean & continue wiper trip. 02:20 - 03:35 1.25 DRILL P PROD1 Ta TD at 10626ft. La in liner ill from 10626ft to the window. PJSM regarding handling KWF. Stop pumping & pull through the window. 03:35 - 04:30 0.92 DRILL P PROD1 Slowly reciprocate coil & circulate 40bb1 hi-vis Flo-Pro pill followed by 13.09ppg (MM density) K-Formate KWF down coil. 04:30 - 05:10 0.67 DRILL P PRODi K-Formate at bit 2.04/3775 w/ 425 psi whp 4000 psi dhp=13.07 ECD. Let 2 bbls get above BHA & slowly PUH while circ in rest of K-formate maintaining dhp at 4000-4020 psi (13.0-13.1 ECD). 05:10 - 05:20 0.17 DRILL P PROD1 K-formate ~ surface. Shut down & flow check well. 05:20 - 07:00 1.67 DRILL P PROD1 POH filling across the top. 07:00 - 07:15 0.25 DRILL P PROD1 Flowcheck while have safety mtg on LD BHA 07:15 - 08:00 0.75 DRILL P PROD1 LD drilling BHA. Bit was 1-1-I 08:00 - 08:30 0.50 CASE P LNR1 RU to run liner 08:30 - 08:45 0.25 CASE P LNR1 Safety mtg re: run liner 08:45 - 12:30 3.75 CASE P LNR1 MU Unique Indexing Guide shoe +51 its 2-3/8" 6.16# L-80 R2 STL liner w/ Farr tongs. Chk MU/BO torque w/ rental Little Jerks. MU BTT aluminum billet assn w/ GS running tool., MU BHI MWD assy PVT 17 12:30 - 13:50 1.33 CASE P LNRi RIH w/ liner on CT w/o pump 13:50 - 16:05 2.25 CASE P LNR1 8200' 26.2k, 11.3k RIH in openhole 50'/min. Wt loss at 9850'. Set down at 9943' took 20min to pass, PU 32k. RIH at max speed at max down wt pushing something. Set down at 10343' CTD. PU 31 k, DN 4k at 100'/min. Work for 40 min w/ no progress-solid bottom and starting to get sticky on pickups. Apply 370 psi whp or 4300 psi dhp=14.0 ECD which is inj rate at 0.3 bpm. Cycle 4 times w/o progress 16:05 - 16:35 0.50 CASE P LNR1 Release from liner 2.3/4050. POOH thru openhole circ 0.52/340 16:35 - 17:05 0.50 CASE P LNR1 Log tie-in down to GR at 7980', corr -15'. This puts TOL at -8712' and BOL C>~ -10320'., 17:05 - 18:40. 1.58 CASE P LNR1 POOH filling from BS. PJSM regarding handling liner BHA. Panted: sns2oots z:orai rM ~ ~ BP AMERICA Page 10 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours i Task Code NPT ~ Phase Description of Operations i 5/12/2008 18:40 - 18:50 0.17 CASE P LNR1 Flow check well. 18:50 - 19:15 0.42 CASE P LNR1 Pop off well. PU on BHA to confirm liner is gone. Blow down BHA w/air. BHA is covered in heavy paraffin. Remove debris from inside agitator (2 large cement chunks) from last bit run, oil same. 19:15 - 21:45 2.50 STKOH P PROD2 LD BHI tools on catwalk. C/O o-rings on LOC. Reconfigure tool string for the addition of HOT, test same. MU 3.75" STR bit to motor & checks, scribe same. PJSM regarding MU BHA & swapping well over to flo-pro. MU BHI tools to motor. PU injector, check CTC & replace grub screws on CTC, pull test same to 35k. Stab coil onto tools. Power up & test tools. Set depths. 21:45 - 23:10 1.42 STKOH P PROD2 RIH. MU 40bb1 hi-vis flo-pro pill. 23:10 - 23:30 0.33 STKOH P PROD2 Open EDC, start pumping hi-vis flo-pro pill & log down for tie-in at 7900ft (-23ft corr. 23:30 - 23:40 0.17 STKOH P PROD2 RIH to 8200ft. 23:40 - 00:00 0.33 STKOH P PROD2 Swap well to 10ppg Flo-Pro & recover 13ppg K-Formate KW F. Start out at 1.Obpm/2060psi while maintain 4000 psi dhp to avoid excessive loss of Formate mud, displace CT volume at this rate. Increased rate and apply WHP to keep dhp at 4000 psi. 5/13/2008 00:00 - 00:35 0.58 STKOH P PROD2 Continue to swap well to 10ppg Flo-Pro holding 4000 dhp. Recovered 235bb1s. Close EDC. 00:35 - 01:00 0.42 STKOH P PROD2 Wi er to TD. Li htl d to TOL at 8713ft. 01:00 - 02:00 1.00 STKOH P PROD2 Time drill HS sidetrack off billet from 8712ft. 3790 psi fs at 2.34 in/out. 50-100 psi mtr wrk. 0.10k DHWOB. 7k SWOB i \~ ~ I ~ 1 ~J-~ ~~ NC/TFH99/5 HS 280/4035/12.98 PPg• Stalled at 8712.3ft Drill to 8712.6' PVT 141 Stacking out & no WOB. PU & start over. 02:00 - 04:40 2.67 STKOH P PROD2 Time drill HS sidetrack off billet from 8712.3ft. 3800 psi fs at 2.34 in/out. 50-100 psi mtr wrk. 0.8-1.5K DHWOB. 7k SWOB WHP/BHP/ECD: 370/4009/12.90 ppg. INClTF: 99.5/HS. PVT 116 Still stacking, yo-yo pumps to get WOB- worked. Time drill ahead keeping applied WOB. At 8714ft drill at constant O.ift/min. WOB dropped at 8716.4ft (off billet), increase ROP to 0.2ft/min to 8718ft. Increase ROP to 30ft/min from 8718ft to 8733ft. Drill to 8733ft. 04:40 - 05:50 1.17 STKOH P PROD2 Backream sidetrack area twice at 45 degrees L & R of drilled TF. Turn off pumps and RIH dry from 8700ft to 8732ft -clean. 05:50 - 06:20 0.50 STKOH P PROD2 W iper to window. Open EDC 06:20 - 07:45 1.42 STKOH P PROD2 POH circ thru EDC 2.43/3450 following pressure schedule 07:45 - 08:15 0.50 STKOH P PROD2 Work to clear Swaco choke of aluminum (won't close) 08:15 - 10:15 2.00 STKOH P PROD2 Pressure undeploy using MPD loop w/ 900 psi LD drilling BHA 10:15 - 13:00 2.75 DRILL P PROD2 Cut off CTC. Pump slack back w/ mud w/ pump #1. Pump #2 is on MPD loop. Cut CT back 90' and find wire. Cut off a total of 500' to move wear spot Install CTC. PT 43K 13:00 - 14:25 1.42 DRILL P PROD2 Head up BHI. PT 4000 s • BP AMERICA Page 11 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: i Date ~ From - To ~ Hours Task Code NPT Phase Description of Operations 5/13/2008 14:25 - 14:35 0.17 DRILL P PROD2 PJSM regarding pressure deployment. 14:35 - 17:50 3.25 DRILL P PROD2 Begin pressure deploying lateral BHA. C/O gripper blocks, replaced 1 bad gripper block. 17:50 - 19:25 1.58 DRILL P PROD2 Open EDC. RIH following pressure schedule. 19:25 - 20:30 1.08 DRILL P PROD2 Log down for tie-in from 7915ft (ft corr. Closed EDC and RIH to 8200 ft and found the HOT was not functiong coorrectly Amp'd out with very slow movement and low rpm's (10 deg/10 min). 20:30 - 22:00 1.50 DRILL N DFAL PROD2 POOH to change out HOT. Held PJSM on undeploying 3" tools and diwscussed all of the hazards associated with same 22:00 - 00:00 2.00 DRILL N DFAL PROD2 Pressure un-deployed BHA with 825 psi on wellhead PU BHA and confirmed AKO setting 5/14/2008 00:00 - 01:45 1.75 DRILL N DFAL PROD2 Pressure deploy BHA in the well at 825 psi WHP 01:45 - 03:10 1.42 DRILL N DFAL PROD2 RIH 03:10 - 03:30 0.33 DRILL N DFAL PROD2 Tied in at 7910 ft (Corrected -23 ft). Closed .EDC 03:30 - 04:10 0.67 DRILL P PROD2 RIH and tagged bottom at 8735 ft 04:10 - 07:00 2.83 DRILL P PROD2 Drilling lateral from 8735 ft TF at 10L HS to 90LHS O p 2.35/2.35 bpm at 3850 psi off bottom psi Density = 10.00 / 10.10ppg Vp = 260 bbl BHP/WHP = 4092 / 469psi Drilled to 8900ft. 07:00 - 07:50 0.83 DRILL P PROD2 Wiper to window -clean. Wiper to 8755ft -clean. 07:50 - 08:10 0.33 DRILL P PROD2 Reduce rate & log MAD pass down from 8790ft to 8820ft. 08:10 - 08:15 0.08 DRILL P PROD2 Wiper to TD -clean. 08:15 - 08:55 0.67 DRILL P PROD2 Drilling lateral from 8900 ft TF at 90-140L O p 2.3/2.3 bpm at 3640 psi off bottom psi Density = 10.22 / 10.29ppg DHWOB = 1 k to 2k. Surface wt = 5K Vp = 268 bbl BHP/WHP = 4023 / 400psi Drilled to 8961ft. 08:55 - 09:15 0.33 DRILL P PROD2 Slowly PUH & circulate sample out. 09:15 - 09:55 0.67 DRILL P PROD2 Drilling lateral from 8961 ft TF at 110-140L O p 2.3/2.3 bpm at 3700 psi off bottom psi Density = 10.22 / 10.29ppg DHWOB = 2k to 4k. Surface wt = OK Vp = 241 bbl (divert to C/O upper shaker screen) BHP/WHP = 4060 / 500psi Drill to 8980ft. 09:55 - 10:40 0.75 DRILL P PROD2 Slowly PUH & circulate sample out. 10:40 - 12:20 1.67 DRILL P PROD2 Drilling lateral from 8980 ft TF at 120-140L O p 2.3/2.3 bpm at 3700 psi off bottom psi Density = 10.22 / 10.29ppg DHWOB = 2k to 4k. Surface wt = OK Vp = 238 bbl BHP/WHP = 4075 / 500psi Conduct mud swap, new mud at the bit at 9000ft. • • BP AMERICA Page 12 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/14/2008 10:40 - 12:20 1.67 DRILL P 12:20 - 13:35 1.25 DRILL P 13:35 - 16:10 I 2.581 DRILL I P PROD2 PROD2 Drill to 9068ft. W iper to the window -clean. W iper to TD -clean, reduce rate through sidetrack area. Partial mud swap complete & the new Flo-pro is already achocolate/brown color. Drilling lateral from 9067 ft TF at 120-140L O p 2.3/2.3 bpm at 3760 psi off bottom psi Density = 10.06 / 10.06ppg DHWOB = 2k to 4k. Surface wt = 1.8k Vp = 137 bbl BHP/WHP = 4015 / 450psi Drill to 9200tt. Wiper to the window -clean. Log down for tie-in at RA marker (+2ff). Wiper to TD -clean. Drilling lateral from 9067 ft to 9302 tt TF at 120-140L O p 2.3/2.3 bpm at 3800 psi off bottom psi Density = 10.06 / 9.96ppg DHWOB = 2k to 4k. Surface wt = 1.8k Vp = 215 bbl BHP/WHP = 4025 / 450psi Mini wiper during SLB change out Drilling lateral from 9302 ft to 9350 tt TF at 90L O p 2.2/2.2 bpm at 3800 psi off bottom psi Density = 10.04 / 9.96ppg DHWOB = 2k to 4k. Surface wt = 1.8k Vp = 440 bbl BHP/WHP = 4107 / 520psi Wiper trip to base of billet ST at 8713 tt Clean Drilling lateral from 9350 ff to 9446 ft TF at 120E - 90 O p 2.2/2.2 bpm at 3800 psi off bottom psi Density = 10.05 / 9.97ppg DHWOB = 2k to 4k. Surface wt = 1.8k ' Vp = 441 bbl BHP/WHP = 4109 / 527psi Drilled to 9500 tt Wiper trip Drilling lateral from 9500 ft to 9569 ft TF at 90R O p 2.2/2.2 bpm at 3800 psi off bottom psi Density = 10.05 / 10.10 ppg DHWOB = 2k to 4k. Vp = 427 bbl BHP/WHP = 4105psi / 527psi Getting lots of negative CTW 200 ft mini wiper trip Drilling lateral from 9,569 tt to 9650ff. TF at 90R to 90L O p 2.2/2.2 bpm at 3800 psi off bottom psi Density = 10.05 / 10.10 ppg PROD2 16:10 - 17:00 0.83 DRILL P PROD2 17:00 - 17:15 0.25 DRILL P PROD2 17:15 - 17:50 0.58 DRILL P PROD2 17:50 - 20:00 2.17 DRILL P PROD2 20:00 - 20:20 0.33 DRILL P PROD2 20:20 - 21:11 0.85 DRILL P PROD2 21:11 - 22:05 I 0.901 DRILL I P I ~ PROD2 22:05 - 00:00 1.92 DRILL P PROD2 5/15/2008 00:00 - 00:50 0.83 DRILL P PROD2 00:50 - 01:55 1.08 DRILL P PROD2 01:55 - 03:30 1.58 DRILL P PROD2 03:30 - 03:40 0.17 DRILL P PROD2 03:40 - 08:15 4.58 DRILL P PROD2 BP AMERICA Page 13 of 17 .Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/15/2008 ~ 03:40 - 08:15 ~ 4.58 DRILL ~ P ~ ~ PROD2 08:15 - 09:25 1.17 DRILL P PROD2 09:25 - 09:40 0.25 DRILL P PROD2 09:40 - 10:25 0.75 DRILL P PROD2 10:25 - 13:45 3.33 DRILL P PROD2 13:45 - 15:50 2.08 DRILL P PROD2 15:50 - 17:10 1.33 DRILL P PROD2 17:10 - 18:10 1.00 DRILL N STUC PROD2 18:10 - 21:00 2.83 DRILL P PROD2 21:00 - 21:15 0.25 DRILL P PROD2 21:15 - 00:00 2.75 DRILL P PROD2 5/16/2008 00:00 - 00:15 0.25 DRILL P PROD2 00:15 - 02:00 1.75 DRILL P PROD2 02:00 - 03:30 1.50 DRILL P PROD2 03:30 - 03:50 0.33 DRILL P PROD2 03:50 - 05:10 1.33 DRILL P PROD2 05:10 - 08:25 ~ 3.25 ~ DRILL ~ P ~ ~ PROD2 08:25 - 08:50 ~ 0.42 ~ DRILL ~ P ~ ~ PROD2 08:50 - 10:30 ~ 1.67 ~ DRILL ~ P ~ ~ PROD2 10:30 - 10:45 0.25 DRILL P PROD2 10:45 - 12:20 1.58 DRILL P PROD2 DHWOB = 2k to 4k. Vp = 420 bbl BHP /ECD /WHP = 4,125psi / 13.48ppg / 527psi W iper to the window. Log down for tie-in from 8250ft (+2ft corr. W iper to TD -clean. Drilling lateral from 9,650 ft to 9800 TF at 90R to 90L O p 2.4/2.4 bpm at 3900 psi off bottom psi Density = 10.05 / 10.10 ppg DHWOB = 2k to 4k. Vp = 368 bbl BHP /ECD /WHP = 4,070psi / 13.22ppg / 480psi Wiper to the window, 3k overpull at 8490ft, otherwise clean. Drilling lateral from 9,800 ft to TF at 60L to 90L O p 2.4/2.4 bpm at 3870 psi off bottom psi Density = 10.14 / 10.19 ppg DHWOB = 2k to 4k. Vp = 364 bbl BHP /ECD /WHP = 4,077psi / 13.21 ppg / 470psi Lost motor work at 9839ft,;~ Attempt to PU. Tight hole at 9,839ft,. Pull to max of 43k on CTC, which is 70k. POOH to lay down URS and pick up agitator. OOH, PJSM on handling pressure undeploying BHA Pressure undeploy BHA with 900 psi on wellhead PU RB BC Bit, New motor with 1.1 AKO setting and agitator along with Coiltrac Held PJSM and discussed the Hazards associated with Pressure Deploying BHA in the well. Pressure deploying BHA in the well. Blanked off LOC check valves. PU injector and pull tested CTC to 40k Stabbed injector Open EDC Tagged up and set counters. RIH maintaining MPD Pressure schedule Tied in and corrected -21 ft, closed EDC and RIH RIH with drill TF. Op = 2.12 bpm CTP = 3,823 psi AV=186 fpm, WHP = 450 psi, BHP = 4076 psi Drilling Lateral from 9836 ft to 9,924 ft Op = 2.19 bpm at 3890 psi Density =.10.16 / 10.14 ppg. BHP = 4031 psi at 13ppg ECD Vp = 378 bbl Cleaning up this area up to 9,755 ft (TF change) Finish 50ft wiper trip. Tag bottom, lost motor work. PU & are stuck. Trap 825psi WHP & let coil relax. No change on WOB (stuck above DPS subZCrossed a fault - 9890ft., Call for new mud. Slowly wiper to the window to keep AV's above 150ft/min to rule out the possibility of hole cleaning issues & to help the formation relax. Log down for tie-in (+10ft corr. Wiper to TD -clean. Backream from TD to 9875ft. BP AMERICA Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code ~ NPT 5/16/2008 112:20 - 13:10 ~ 0.83 ~ DRILL ~ P 13:10 - 13:45 0.58 DRILL P 13:45 - 14:20 0.58 DRILL P Start: 4/28/2008 Rig Release: 5/20/2008 Rig Number: i Page 14 of 17 ~ Spud Date: 4/1/1988 End: 5/20/2008 Phase j Description of Operations PROD2 PROD2 PROD2 14:20 - 17:45 3.421 DRILL ~ N DFAL ~ PROD2 17:45 - 19:00 1.251 DRILL I N ~ DFAL ~ PROD2 19:00 - 20:30 1.50 DRILL N DFAL PROD2 20:30 - 22:20 1.83 DRILL N DFAL PROD2 22:20 - 23:45 1.42 DRILL N DFAL PROD2 23:45 - 23:55 0.17 DRILL N DFAL PROD2 23:55 - 00:00 0.08 DRILL N PROD2 5/17/2008 00:00 - 01:30 1.50 DRILL N DFAL PROD2 01:30 - 03:10 1.67 DRILL P PROD2 03:10 - 03:30 0.33 DRILL P PROD2 03:30 - 04:00 0.50 DRILL P PROD2 04:00 - 05:40 1.67 DRILL P PROD2 05:40 - 08:15 2.58 DRILL P PROD2 08:15 - 10:30 2.25 DRILL P PROD2 10:30 - 12:10 1.67 DRILL P PROD2 Drilling Lateral from 9,924 ft to 9,944 ft Op = 2.19 bpm at 4000 psi Density = 10.15 / 10.16 ppg. BHP = 4050 psi at 13.16ppg ECD Vp = 368 bbl Drill to 9,944ft. Sticky, 25k overpull off bottom. Wiper trip. Conduct mud swap. HOT is acting up intermittently. 10bbls of new mud out the bit. Drilling Lateral from 9944 ft to 9,977 ft Op = 2.2 bpm at 3800 psi Density = 10.04 / 10.20 ppg. BHP = 4030 psi at 13.09ppg ECD Vp = 216 bbl (conducting mud swap) HOT is unreliable. POH following pressure schedule. Open EDC in tubing, won't function & left it closed. Continue POH pumping through the bit. Crew change and held PJSM on Pressure undeploy of BHA Circulating through MPD loop Handle BHA using undeployment procedures Change out entire Coiltrac BHA and RR motor and PU STC BC Bit RIH Log Tie-in Corrected -24 ft Closed EDC and RIH RIH Drilling lateral from 9978 ft to 10070 ft Op = 2.20 / 2.23 bpm at 3,815 psi off bottom CTP = 4250 psi BHP /ECD /WHP = 4021 psi / 13.09 ppg / 450 psi Density = 10.06 / 10.05 ppg Vp =-379 bbls ROP started off at 90-100 fph with 2k DHWOB 200 ft wiper trip, getting a little stick, don't want to have to call town and see what I'm allow to pull if it get tight. Drilling lateral from 10,070 ft to 10,105 ft Op = 2.20 / 2.23 bpm at 3,815 psi off bottom CTP = 4250 psi BHP /ECD /WHP = 4000 psi / 13.05 ppg / 420 psi Density = 10.06 / 10.05 ppg Vp = 388 bbl.s Faulted at 10052 ft. aettina sticky Make wiper trip to avoid calling town Drilling lateral from 10,105 ft to 10,205 ft Op = 2.20 / 2.23 bpm at 3,815 psi off bottom CTP = 4,250 psi BHP /ECD /WHP = 4,000 psi / 13.05 ppg / 420 psi Density = 10.06 / 10.05 ppg Vp = 382 bbls Stacking & sticky while PU - 10k overpulls. Wiper trip -clean both ways. Drilling lateral from 10,205 ft to 10,260 ft Op = 2.20 / 2.23 bpm at 3,815 psi off bottom CTP = 4,250 psi BHP /ECD /WHP = 4,000 psi / 13.05 ppg / 420 psi • w BP AMERICA Page 15 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 5/17/2008 10:30 - 12:10 1.67 DRILL P PROD2 12:10 - 12:45 0.58 DRILL N DFAL PROD2 12:45 - 15:30 2.751 DRILL I N DFAL PROD2 15:30 - 19:45 4.251 DRILL I N I SFAL PROD2 19:45 - 20:00 I 0.251 DRILL I N I SFAL I PROD2 20:00 - 20:45 0.75 DRILL P PROD2 20:45 - 22:00 1.25 DRILL P PROD2 Density = 10.06 / 10.05 ppg Vp = 382 bbls HOT is not working. Slowly PUH. Appears to be a software problem. Only the DPS & EDC operate now & TF is stuck at 105R HS. POH following pressure schedule. 6k overpull at the OH billet & clean through the window. Pressure undeploy BHA. Slickline wire broke at the drum. Spool new wire onto drum & rehead. Held PJSM and discussed the hazard associated wit pressure deploying BHA. Pressure undeploy BHA after reheading wireline head Pressure undeploy BHA Clean floor and make ready to conduct BOP test Wavered witnessing by AOGCC Chuck Scheve BHI tested their BHA and found the HOT was non funtioning. Travel to Nordic 1 to get the back up HOT tool Open doors on VBR and inspect for debis. Re-building 2 accumulator bottles 22:00 - 00:00 I 2.00 I BOPSUFI P PROD2 5/18/2008 00:00 - 03:15 3.25 BOPSU~ P PROD2 03:15 - 04:15 1.00 BOPSU P PROD2 04:15 - 04:30 0.25 BOPSU P PROD2 04:30 - 06:15 1.75 BOPSU P PROD2 06:15 - 07:45 1.50 DRILL N DFAL PROD2 07:45 - 08:00 0.25 DRILL N DFAL PROD2 08:00 - 09:10 1.17 DRILL N DFAL PROD2 09:10 - 11:30 2.33 DRILL P PROD2 11:30 - 14:00 2.50 DRILL P PROD2 14:00 - 17:00 3.00 DRILL P PROD2 17:00 - 19:18 2.30 DRILL P PROD2 19:18 - 21:25 2.12 DRILL P PROD2 Chuck Scheve wavered witnessing BOP test BOP Test PT the injector stripper and inner reel valve to 250 / 4000 psi Test OKrelease P and set back injector. PJSM on PU BHA and pressure deployment Confirm valve aligment following BOP test PU BHA and pressure deploy as per SOP's RIH following pressure schedule. Log down for tie-in from 7890ft (-27ft corr. Wiper to TD -clean. HOT is acting up again Drilling lateral from 10,260 ft to 10,350 ft Op = 2.23 / 2.23 bpm at 3,815 psi off bottom CTP = 4,250 psi BHP /ECD /WHP = 4,000 psi / 13.08 ppg / 420 psi Density = 10.12 / 10.04 ppg Vp = 352 bbls Acting sticky again. Wiper to billet at 8713ft clean. Wiper to TD -clean. Drilling lateral from 10,350 ft to 10,500 ft Op = 2.23 / 2.23 bpm at 3,830 psi off bottom CTP = 4,400 psi BHP /ECD /WHP = 4,065 psi / 13.30 ppg / 475 psi Density = 10.11 / 10.09 ppg Vp = 360 bbls W iper to 8730 ft, Clean trip out Drilling lateral from 10,500 ft with HS TF. Need to build up quickly to compensate for the 4 dea dio Op = 2.23 / 2.23 bpm at 3,830 psi off bottom CTP = 4,400 psi BHP /ECD /WHP = 4,065 psi / 13.37 ppg / 475 psi Density = 10 / 10 ppg Vp = 310 bbls rnrneo: wrweuun cui:ai rnn BP AMERICA Page 16 of 17 Operations. Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: ' , Date j From - To Hours Task Code NPT Phase Description of Operations 5/18/2008 21:25 - 21:26 0.02 DRILL P PROD2 PU to conduct wiper trip and pulling tight off bottom Pulled to 50k max 6 times and tool still won't work String Wt at 24k, pulling 30k over. 21:26 - 21:55 0.48 DRILL N STUC PROD2 Waiting on SLB and BP approval for pulling on CT. Worked CT down to compare the string wt between the Martin decker and ~ SLB's computer and finally got free. PU hole ~ 21:55 - 00:00 2.08 DRILL P PROD2 Wiper trip to window and tie in Motor work at 8,430 ft Tied in and corrected +6 ft 5/19/2008 00:00 - 01:45 1.75 DRILL P PROD2 Wiper trip back in the hole 01:45 - 02:38 0.88 DRILL P PROD2 Drilling lateral from 10,578 ft to Op = 2.15 / 2.13 bpm at 3,830 psi off bottom CTP = 4000-4,400 psi BHP /ECD / WHP = 4,065 psi / 13.37 ppg / 475 psi Density = 10 / 10 ppg Vp = 286 bbls Having trouble getting to drill in the shale/silstone stacking and over pulls 02:38 - 05:30 2.87 DRILL P PROD2 Wiper trip to tie at 7,910 ft. Open EDC at 8,195 ft and inc Op to 2.75 bpm at 3,700 psi Tied in and corrected +1 ft. 05:30 - 07:15 1.75 DRILL P PROD2 RIH. Start pumping 100k LSRV liner pill w/ 2ppb Alpine beads 07:15 - 08:40 1.42 DRILL P PROD2 POH to the window laying in liner pill in the OH section. Pump 16bb1 hi-vis spacer pill while PUH to the the window. 08:40 - 09:15 0.58 DRILL P PROD2 Slowly reciprocate coil & circulate 12.99ppg (MM density) K-Formate KWF down coil. 09:15 - 10:00 0.75 DRILL P PROD2 K-Formate at bit 2.0/3600 w/ 400 psi whp 4000 psi dhp=13.07 ECD. Let 2 bbls get above BHA & slowly PUH while circ in rest of K-formate maintaining dhp at 4000-4020 psi (13.0-13.1 ECD). 10:00 - 10:15 0.25 DRILL P PROD2 KW F at surface. Flow check well. 10:15 - 11:40 1.42 DRILL P PROD2 POH filling across the top. PJSM regarding handling BHA. 11:40 - 12:15 0.58 DRILL P PROD2 Flow check well. 12:15 - 13:00 0.75 DRILL P PROD2 LD BHI tool string. Wear pads, CTC & LOC connection are covered in asphaltines?, recovered 1/4 cup for people to look at. 13:00 - 13:45 0.75 DRILL P PROD2 RU Farr tongs. MU 2-3/8" safety jt. PJSM regarding MU liner. 13:45 - 19:30 5.75 CASE P LNR2 MU 2-7/8" liner er ro ram. 19:30 - 22:05 2.58 CASE P LNR2 RIH with liner tagged bottom at 10608 ft, PU string wt at 30k RBIH and set down at 10,608 ft. Line up down the CT and Op = 1.62 bpm to release from the liner at 8,206 ft PU and lost 4k of ' 1 ppg mud liner wt in 13. 22:05 - 23:35 1.50 CASE P LNR2 POOH 23:35 - 0.00 CASE P LNR2 OOH, flow check 5/20/2008 00:00 - 00:22 0.37 CASE P LNR2 LD Liner running BHA and PU Nozzle BHA for displacing the KWF in the well 00:22 - 01:55 1.55 WHSUR P CLEAN RIH Pumped 15 bbl of 10ppg 100 k LSRV flowpro follow by 2% KCL 01:55 - 03:00 1.08 WHSUR P CLEAN Pumped 2% KCL around and back to surface while holding 1250 psi on well. 03:00 - 05:40 2.67 WHSUR P CLEAN POOH to 2500 to FB the top 2500 ft with diesel. Held PJSM and PT LRS to 3000 psi. Pump 50 bbl diesel down CT and rnntea: wi°/zv~° L:U/[41 nw BP AMERICA Page 17 of 17 Operations Summary Report Legal Well Name: 3F-16 Common Well Name: 3F-16 Spud Date: 4/1/1988 Event Name: DRILL+COMPLETE Start: 4/28/2008 End: 5/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/20/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/20/2008 03:00 - 05:40 2.67 WHSUR P CLEAN displaced with 2% KCL. RD LRS and POOH chasing diesel to surface. OOH, closed SV and MV with 1300 psi on well. 05:40 - 06:00 0.33 WHSUR P POST Pickle CT and make ready to blow down. 06:00 - 10:35 4.58 RIGD N WAIT POST Wait on nitrogen from GPB. 10:35 - 10:55 0.33 RIGD P POST Spot N2 unit. RU hardline to existing rig hardline. 10:55 - 11:05 0.17 RIGD P POST PJSM regarding pumping nitrogen. 11:05 - 12:45 1.67 RIGD P POST P.T. N2 lines to 4000psi. Pump 10bbls of methanol & 2 bbls from pits to clean rig pump lines. 12:45 - 15:00 2.25 RIGD P POST RD nozzle BHA. Install pull back grapple & cable inside coil. Tail coil to reel and secure. Lower reel to trailer. 15:00 - 00:00 9.00 RIGD P POST Install BPV, Clean pits. ND BOP stack. Install tree cap and PT to 4000 psi. RDMO. Rig released at midnight ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. ~ Kuparuk River Unit Kuparuk 3F Pad 3F-16 3F-AL1 PB1 TD Design: 3F-AL1 P61 Baker Hughes INTEQ Survey Report • 17 June, 2008 ~~.~r BAKER NU~I~IE~S INTEL ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Un8 Site: Kuparuk 3F Pad Weil: 3F-1ti Wellbore: 3F-AL1PB1 TD Design: 3F-AL1PB1 ConocoPhillips BAR r Baker Hughes INTEQ Survey Report ~~~$ INTEQ Local Coordinate Reference: Well 3F-16 TVD Reference: Mean Sea Level MD Reference: 3F-18A @ 88.OOft (3F-16A) North Reference: True Survey Calculatbn Method: Minimum Curvature. Database: EDMv16 Prod Project Kuparuk River Unit, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site .Kuparuk 3F Pad Site Poskion: Northing: 5,985,734.46 ft Latitude; 70° 22' 20.081 N From: Map Easting: 508,662.33 ft Longitude: 149° 55' 46.550 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.07 ° s WaN 3F-18 Well Position +WS 0.00 ft Northing: 5,985,904.95 ft Latitude: 70° 22' 21.762 N +E/-W 0.00 ft EasUng: 508,272.74 ft Longitude: 149° 55' 57.943 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft I Wetibore 3F-AL1PB1 TD Magnetlcs Modet Name Sample Date DecOnatlon Dip Angle Field Strength 1°) (°) InT1 BGGM2007 5/15!2008 17.62 79.75 57,275 Design 3F-AL1 P 61 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,147.53 VarUcal Section: Depth From (TUD) +NI-S +E!-W Direction (fU Ift) Iftl 1°) 0.00 0.00 0.00 311.07 • 6/17/2008 3:29:24PM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 3F Pad Weil: 3F-16 Weltbore: 3F-AL1PB1 TD Design: 3F-AL1PB1 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-oMinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Welt 3F-18 Mean Sea Level 3F-16A ~ 88.OOft (3F-16A) True Minimum Curvature EDMv16 Prod A.~~ s ~~~ Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description 95.00 7,000.00 3F-16 (3F-16) GCT-MS Schlumberger GCT multishot 7,020.00 8,147.53 3F-16A (3F-16A) MWD MVVD -Standard 8,226.00 10,054.00 3F-16AL1P61 (3F-AL1P81 TD) MWD MWD-Standard Survey ~ MD inc Azi TVDSS N/S FJW Northing Fasting DLS vertical Sectlon TFO 1~- t°! 1°) Ifs) Ift) (ffl Iff) Iff) 1°HOOft) 1~ !°I 8,147.53 39.80 9.00 5,887.53 3,855.22 -2,944.90 5,989,756.53 505,323.88 0.75 4,753.03 115.42 8,226.00 40.45 8.35 5,947.53 3,905.21 -2,937.27 5,989,806.52 505,331.45 0.99 4,780.13 -33.05 8,245.75 43.61 7.12 5,962.20 3,918.31 -2,935.50 5,989,819.62 505,333.21 16.53 4,767.40 -15.07 8,260.17 47.89 5.00 5,972.26 3,928.58 -2,934.41 5,989,829.89 505,334.28 31.49 4,793.33 -20.28 8,275.47 52.28 2.00 5,982.07 3,940.29 -2,933.71 5,989,841.60 505,334.97 32.39 4,800.49 -28.64 8,290.61 56.31 359.00 5,990.91 3,952.58 -2,933.61 5,989,853.89 505,335.06 31.10 4,808.49 -32.04 8,305.94 60.53 356.71 5,998.94 3,965.62 -2,934.10 5,989,866.93 505,334.55 30.32 4,817.43 -25.42 8,335.38 69.24 1.43 6,011.42 3,992.24 -2,934.50 5,989,893.55 505,334.13 32.94 4,835.21 27.18 8,365.38 78.34 359.80 6,019.79 4,021.01 -2,934.20 5,989,922.32 505,334.40 30.78 4,853.89 -10.00 8,395.39 87.64 356.94 6,023.45 4,050.75 -2,935.05 5,989,952.05 505,333.51 32.40 4,874.08 -17.17 8,425.64 94.27 349.61 6,022.95 4,080.75 -2,938.59 5,989,982.04 505,329.94 32.66 4,896.45 -47.86 8,455.53 98.79 341.21 6,019.54 4,109.46 -2,946.05 5,990,010.74 505,322.45 31.75 4,920.94 -61.13 8,485.92 100.51 331.59 6,014.44 4,136.88 -2,958.02 5,990,038.15 505,310.45 31.71 4,947.98 -78.94 8,515.86 100.24 322.27 6,009.03 4,161.53 -2,974.07 5,990,062.78 505,294.37 30.63 4,976.28 -90.84 8,544.80 99.72 310.77 6,004.00 4,182.17 -2,993.65 5,990,083.40 505,274.77 39.18 5,004.60 -91.62 8,576.67 100.10 301.59 5,998.50 4,200.69 -3,018.96 5,990,101.88 505,249.44 28.40 5,035.85 -86.81 8,607.13 98.88 291.27 5,993.47 4,214.04 -3,045.83 5,990,115.20 505,222.56 33.65 5,064.87 -95.96 8,632.41 99.88 282.71 5,989.34 4,221.32 -3,069.66 5,990,122.45 505,198.73 33.64 5,087.62 -82.56 8,660.30 99.34 275.61 5,984.68 4,225.69 -3,096.79 5,990,126.80 505,171.59 25.17 5,110.95 -93.81 8,690.13 99.94 270.55 5,979.68 4,227.27 -3,126.14 5,990,128.34 505,142.24 16.84 5,134.11 -82.72 6/17/2008 3:29:24PM Page 3 COMPASS 2003.16 Build 42F '~-' ConocoPhillips //.ir ConocoPhilli s B~$ p Baker Hughes INTEQ Survey Report Alaska INTEQ Company: ConocoPhdiips(Alaska)Jnc. Local Co-ordinate Reference: Well 3F-16 Project: Kupaak River Unit TVD Reference: Mean Sea Level Slte: Kuparuk 3F Pad MD Reference: 3F-16A ~ 88.OOft (3F-16A) Well: 3F-16 North Reference: True Welibore: 3F-AL1PB1 TD Survey Calculation Method: Minimum Curvature. Design: 3F-AL1PB1 Database: EDMv16 Prod Survey MD Inc Azf TVDSS PUS EIW Northing Easting DlS Vertical Section TFO (tt- 1°I 1°1 Ift! Ittl Iffl lfU Iff) 1°1looftl Iff! l°I 8,720.07 99.59 266.81 5,974.60 4,226.59 -3,155.64 5,990,127.63 505,112.75 12.37 5,155.90 -95.11 8,750.24 98.38 262.57 5,969.89 4,223.84 -3,185.30 5,990,124.84 505,083.09 14.45 5,176.45 -105.78 8,779.39 96.80 258.98 5,966.04 4,219.20 -3,213.82 5,990,120.18 505,054.58 13.36 5,194.90 -113.70 8,810.65 95.66 254.83 5,962.64 4,212.16 -3,244.07 5,990,113.10 505,024.34 13.69 5,213.09 -105.22 8,840.41 94.15 250.60 5,960.10 4,203.35 -3,272.38 5,990,104.26 504,996.04 15.04 5,228.64 -109.52 8,883.20 91.94 244.63 5,957.82 4,187.09 -3,311.87 5,990,087.96 504,956.58 14.86 5,247.72 -110.16 8,911.77 90.61 241.90 5,957.19 4,174.24 -3,337.37 5,990,075.08 504,931.09 10.63 5,258.51 -115.94 8,945.24 89.63 236.48 5,957.12 4,157.10 -3,366.11 5,990,057.91 504,902.37 16.46 5,268.91 -100.24 8,996.89 90.34 229.27 5,957.13 4,125.95 -3,407.26 5,990,026.72 504,861.26 14.03 5,279.47 -84.38 9,028.37 90.40 225.65 5,956.93 4,104.67 -3,430.45 5,990,005.42 504,838.09 11.50 5,282.97 -89.04 9,053.10 90.12 223.62 5,956.81 4,087.07 -3,447.83 5,989,987.80 504,820.74 8.29 5,284.51 -97.85 9,083.40 88.62 219.50 5,957.15 4,064.41 -3,467.92 5,989,965.12 504,800.67 14.47 5,284.77 -110.02 9,114.33 88.43 214.47 5,957.94 4,039.72 -3,486.52 5,989,940.41 504,782.11 16.27 5,282.56 -92.23 9,145.13 88.25 209.38 5,958.84 4,013.60 -3,502.79 5,989,914.27 504,765.86 16.53 5,277.67 -92.10 9,182.34 88.56 212.93 5,959.87 3,981.77 -3,522.03 5,989,882.43 504,746.66 9.57 5,271.27 85.06 9,217.00 89.39 217.69 5,960.49 3,953.50 -3,542.06 5,989,854.14 504,726.67 13.94 5,267.79 80.16 9,247.81 91.57 221.02 5,960.24 3,929.68 -3,561,59 5,989,830.30 504,707.16 12.92 5,266.86 56.78 9,280.91 91.07 227.63 5,959.47 3,906.02 -3,584.70 5,989,806.62 504,684.08 20.02 5,268.74 94.25 9,311.51 91.17 232.53 5,958.87 3,886.39 -3,608.16 5,989,786.97 504,660.65 16.01 5,273.53 88.78 9,340.98 91.81 237.06 5,958.11 3,869.42 -3,632.22 5,989,769.96 504,636.61 15.52 5,280.52 81.90 9,372.19 94.64 234.48 5,956.35 3,851.89 -3,657.98 5,989,752.41 504,610.87 12.26 5,288.42 -42.24 9,405.58 95.56 229.98 5,953.38 3,831.53 -3,684.26 5,989,732.02 504,584.61 13.70 5,294.86 -78,21 9,431.68 96.34 226.28 5,950.67 3,814.20 -3,703.59 5,989,714.68 504,565.31 14.41 5,298.04 -77.85 9,461.73 96.77 221.84 5,947.24 3,792.76 -3,724.35 5,989,693.21 504,544.58 14.75 5,299.60 -84.18 9,491.96 97.20 217.59 5,943.56 3,769.68 -3,743.52 5,989,670.12 504,525.43 14.03 5,298.89 -83.92 9,521.55 99.53 212.84 5,939.26 3,745.77 -3,760.39 5,989,646.19 504,508.58 17.73 5,295.91 -63.30 9,550.36 100.53 208.53 5,934.24 3,721.38 -3,774.87 5,989,621.79 504,494.14 15.13 5,290.79 -76.37 w 6/17/2008 3:29:24PM Page 4 COMPASS 2003.16 Build 42F / ConocoPhillips N.tr s ~;`~ ConocoPhilli s p Baker Hughes INTEQ Survey Report $ Alaska INTEQ Comparryr: ConocoPhillips(Alaska) Inc. Local Coordinate Reference: Well 3F-16 Protect Kuparuk River UnfY TVD Reference: Mean Sea Level Site: Kuparuk 3F Pad MD Reference: 3F-16A ~ 88,OOft (3F-16A) Wall: 3F-16 North Reference: True Watlbore: 3F-AL1PB1 TD Survey Calculation Method: Minimum Curvature Design: 3F-AL1P81 Database: EDMv16 Prod Survey MD Inc Azl TVDSS WS E/W Northing Easting DLS Vertical Section TFO IfU 1°- 1°! 1~ 1~1 Iftl Ift1 (ft) (°no0it- (e) (°) 9,580.66 101.15 203.71 5,928.54 3,694.67 -3,787.97 5,989,595.07 504,481.07 15.76 5,283.12 -82.09 9,610.60 100.65 200.10 5,922.87 3,667.40 -3,798.93 5,989,567.78 504,470.14 11.96 5,273.47 -97.68 9,640.48 99.99 195.41 5,917.52 3,639.41 -3,807.89 5,989,539.79 504,461.21 15.60 5,261.83 -97.72 9,670.06 100.68 191.63 5,912.21 3,611.12 -3,814.70 5,989,511.50 504,454.44 12.79 5,248.38 -79.15 9,700.24 100.40 187.57 5,906.69 3,581.88 -3,819.64 5,989,482.24 504,449.52 13.26 5,232.89 -93.64 9,730.23 100.18 183.78 5,901.33 3,552.52 -3,822.56 5,989,452.89 504,446.64 12.46 5,215.80 -93.04 9,760.16 99.25 178.81 5,896.27 3,523.04 -3,823.22 5,989,423.41 504,446.01 16.66 5,196.93 -100.32 9,790.90 99.78 174.25 5,891.19 3,492.78 -3,821.39 5,989,393.16 504,447.87 14.73 5,175.67 -82.91 9,820.25 100.43 169.49 5,886.04 3,464.19 -3,817.31 5,989,364.57 504,451.99 16.12 5,153.80 -81.69 9,849.99 100.84 165.63 5,880.55 3,435.65 -3,811.01 5,989,336.04 504,458.31 12.83 5,130.31 -83.48 9,880.27 99.19 161.90 5,875.28 3,407.03 -3,802.68 5,989,307.43 504,466.68 13.30 5,105.22 -113.86 9,910.41 96.59 158.89 5,871.14 3,378.91 -3,792.66 5,989,279.33 504,476.73 13.12 5,079.19 -130.87 9,942.85 95.10 155.38 5,867.84 3,349.18 -3,780.12 5,989,249.62 504,489.30 11.70 5,050.21 -112.92 9,975.46 93.32 152.49 5,865.44 3,319.97 -3,765.83 5,989,220.42 504,503.62 10.39 5,020.25 -121.59 10,054.00 93.32 152.49 5,860.89 3,250.43 -3,729.61 5,989,150.93 504,539.91 0.00 4,947.25 0.00 Checked By: Approved By: Date: • 6/17/2008 3:29:24PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. ~ Kuparuk River Unit Kuparuk 3F Pad 3F-16 3F-16AL1 TD Design: 3F-16AL1 Baker Hughes INTEQ Survey Report s 17 June, 2008 r~~r BAKER HU~NES INTEQ / ConocoPhillips ~/.tr BA ~ ConocoPhilli s p Baker Hughes INTEQ Survey Report ~ $ Alaska INTEQ Company: ConocoPh~lips(Alaska) Inc. Local Co-ordinate Reference: Weil 3F-16 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 3F Pad MD Reference: 3F-16A ~ SS.OOft (3F-16A) Weg: 3F-18 North Reference: True Wellbore: 3F-16AL1 TD Survey Calculation Method: Minimum Curvature Design: 3F-18AL1 Database: EDMv16 Prod project Kuparuk River Unit, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo DaWm: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetlc scale factor Site Kuparuk 3F Pad ,. _ Site Position: Northing: 5,985,734.46 ft Latitude: 70° 22' 20.081 N From: Map Easting: 508,662.33 ft Longitude: 149° 55' 46.550 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.07 ° Well 3F-16 Well Position +W-S 0.00 ft Northing: 5,985,904.95 ft Latitude: 70° 22' 21.762 N +EI-W 0.00 ft Easting: 508,272.74 ft Longitude: 149° 55' 57.943 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft WeHbore 3F-16AL1 TD Magnetics Model Name Sample Date Declinatlon Dip Angle Field Strength (°I 1°I (nTl BGGM2007 3!12/2008 17.70 79.75 57,268 Design 3F-16AL1_ Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,760.16 Vertical Section: Depth From (TVDj +N!-S +E/-W Direction (ft) (f4 (ft1 (°) 0.00 0.00 0.00 225.00 s 6/17/2008 3:31:35PM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhiliips(Alaska) Inc. Project: Kuparuk River Unit S1te: Kuparuk 3F Pad Well: 3F-16 Welibore: 3F-16AL1 TD Design: 3F-16AL1 ConocoPhillips Baker Hughes INTEQ Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation McUwd: Database: N.t>r s.:~~.~ VVe11 3F-18 Mean Sea Level 3F-16A ~ 88.OOft (3F-16A) True Minimum Curvature EDMv16 Prod Survey Program Date From To (ft) (ft) Survey (Wellborej Tool Name Description 95.00 7,000.00 3F-16 (3F-16) GCT-MS Schlumberger GCT multishot 7,020.00 8,147.53 3F-16A (3F-16A) MVVD MWD -Standard 8,226.00 9,760.16 3F-16AL1PB1 (3F-AL1PB1 TD) MVVD MWD-Standard 9,775.00 10,626.00 3F-16AL1 (3F-16AL1 TD) MWD MWD -Standard Survey AAD Inc Azl TVDSS NIS EIW Northing Easting DLS Vertical Section TFO (ft) l°I (°! lft) Ift1 Ift) (ft) (ft) (°/10oft- Ift1 l°- 9,760.16 99.25 178.81 5,896.27 3,523.04 -3,823.22 5,989,423.41 504,446.01 16.66 212.27 -100.32 9,775.00 99.51 176.61 5,893.85 3,508.41 -3,822.64 5,989,408.78 504,446.61 14.73 222.20 -82.99 9,803.75 95.53 181.95 5,890.09 3,479.92 -3,822.29 5,989,380.30 504,446.99 23.03 242.09 126.56 9,830.68 94.12 185.20 5,887.82 3,453.14 -3,823.96 5,989,353.52 504,445.35 13.12 262.21 t 13.38 9,860.41 93.26 187.92 5,885.91 3,423.67 -3,827.35 5,989,324.05 504,441.99 9.58 285.44 107.49 9,890.49 92.30 192.26 5,884.45 3,394.10 -3,832.61 5,989,294.47 504,436.76 14.76 310.08 102.38 9,930.30 90.46 194.72 5,883.49 3,355.41 -3,841.90 5,989,255.77 504,427.52 7.72 344.00 126.77 9,956.47 92.25 197.98 5,882.87 3,330.30 -3,849.26 5,989,230.67 504,420.19 14.21 366.96 61.19 9,978.59 92.89 200.90 5,881.88 3,309.47 -3,856.61 5,989,209.82 504,412.86 13.50 386.89 77.56 10,008.71 92.83 204.81 5,880.38 3,281.75 -3,868.30 5,989,182.10 504,401.21 12.97 414.75 90.78 10,028.85 92.40 208.06 5,879.46 3,263.74 -3,877.25 5,989,164.08 504,392.27 16.26 433.82 97.47 10,048.51 92.58 208.46 5,878.60 3,246.44 -3,886.55 5,989,146.77 504,382.99 2.23 452.63 65.74 10,076.32 92.83 205.11 5,877.29 3,221.65 -3,899.07 5,989,121.96 504,370.50 12.07 479.01 -85.65 10,105.55 93.70 201.85 5,875.63 3,194.88 -3,910.69 5,989,095.19 504,358.91 11.53 506.15 -74.95 10,136.29 85.38 198.21 5,873.19 3,166.10 -3,921.19 5,989,066.40 504,348.45 13.01 533.93 -65.02 10,162.51 95.38 195.41 5,870.73 3,141.11 -3,928.74 5,989,041.41 504,340.93 10.63 556.93 -89.87 10,192.46 95.20 193.71 5,867.97 3,112.25 -3,936.23 5,988,012.54 504,333.46 5.68 582.64 -95.99 10,226.39 94.77 190.46 5,865.02 3,079.20 -3,943.31 5,988,979.48 504,326.42 9.63 611.02 -97.42 10,265.06 92.83 186.46 5,862.46 3,041.05 -3,948.98 5,988,941.33 504,320.79 11.48 642.01 -115.78 10,296.26 93.69 179.77 5,860.68 3,009.96 -3,950.67 5,988,910.24 504,319.14 21.58 665.19 -82.48 6/17/2008 3:31:35PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska)lnc. Project: Kuparuk RiverUnit Site: Kuparuk 3F Pad Weli: 3F-16 Welibore: 3F-16AL1 TD Design: 3F-18AL1 ConocoPhillips Baker Hughes INTEQ Survey Report Local Coordinate Reference: Well 3F-18 TVD Reference: Mean Sea Level MD Reference: 3F-16A ~ 88.OOft (3F-16A) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMvt6 Prod ~.r Survey MD Inc Azi TYDSS N/S E/W Northing Fasting DLS Vertical Section TFO Ift1 1°1 1°? Ift1 Iff1 Ift) (ft) (ft) (°I1o0Rj IfU l°1 10,326.10 94.18 179.88 5,858.63 2,980.19 -3,950.58 5,988,880.48 504,319.26 1.68 686.17 12.62 10,361.56 92.67 176.39 5,856.52 2,944.82 -3,949.43 5,988,845.11 504,320.45 10.71 710.37 -113.32 10,391.65 90.43 173.30 5,855.70 2,914.87 -3,946.73 5,988,815.16 504,323.19 12.68 729.64 -125.90 10,427.66 87.08 165.69 5,856.49 2,879.50 -3,940.17 5,988,779.81 504,329.78 23.08 750.01 -113.81 10,457.06 85.61 165.71 5,858.36 2,851.07 -3,932.93 5,988,751.39 504,337.06 5.00 764.99 179.22 10,482.21 85.88 162.42 5,860.23 2,826.96 -3,926.04 5,988,727.28 504,343.97 13.09 777.17 -85.42 10,521.95 86.37 157.99 5,862.91 2,789.66 -3,912.62 5,988,690.01 504,357.43 11.19 794.05 -83.83 10,547.76 87.64 155.39 5,864.26 2,765.99 -3,902.42 5,988,666.35 504,367.66 11.20 803.57 -64.01 10,585.98 87.73 155.74 5,865.81 2,731.22 -3,886.62 5,988,631.60 504,383.49 0.94 816.99 75.58 10,626.00 87.73 155.74 5,867.39 2,694.77 -3,870.19 5,988,595.17 504,399.96 0.00 831.15 0.00 • • 6/17/2008 3:31:35PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Alaska ConocoPhillips Baker Hughes INTEQ Survey Report Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Reference: Well 3F-16 Project: Kuparuk River Unit ND Reference: Mean Sea Level Site: Kuparuk 3F Pad MD Reference: 3F-16A ~ 88.OOft (3F-16A) Weil: 3F-16 North Reference: True- Wellbore: 3F-16AL1 TD Survey Calculation Method: Minimum Curvature Design: 3F-16AL1 Database: EDMv16 Prod r~.r - Is ~ u~~s INTEQ Targets Target Name - hiUmiss target Dip Angle Dip Dir. ND +WS +EI•W Northing Fasting - Shape (°) 1°- (ft) Iftl Iftl Ift1 Iftl Latitude Longitude 3F-16AL1 Target 4 0.00 0.00 5,902.00 3,449.33 -3,743.42 5,989,349.80 504,525.88 70° 22' 55.676 N 149° 57' 47.514 W - actual wellpath misses by 81.77ft at 9828.27ft MD (5888.00 ND, 3455.54 N, -3823.75 E) -Point 3F-16AL1 Fault 2 0.00 0.00 0.00 3,474.57 -3,952.42 5,989,374.80 504,316.88 70° 22' 55.924 N 149° 57' 53.631 W - actual wellpath misses by 5878.34ft at 10226.46ft MD (5865.02 ND, 3079.14 N, -3943.32 E) - Polygon Point 1 0.00 3,474.57 -3,952.42 5,989,374.80 504,316.88 Point2 0.00 3,292.37 -3,783.60 5,989,192.80 504,485.89 Point3 0.00 3,110.18 -3,614.77 5,989,010.82 504,654.90 Point4 0.00 3,292.37 -3,783.60 5,989,192.80 504,485.89 3F-16AL1 Polygon 0.00 0.00 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 70° 23' 3.867 N 149° 57' 36.578 W - actual wellpath misses by 5961.39ft at 9785.87ft MD (5892.20 ND, 3497.67 N, -3822.19 E) - Polygon Point 1 0.00 4,281.99 -3,369.44 5,990,182.78 504,898.90 Point2 0.00 4,260.69 -3,089.43 5,990,161.79 505,178.91 Point3 0.00 4,192.54 -2,951.49 5,990,093.80 505,316.91 Point 4 0.00 4,044.61 -3,029.66 5,989,945.80 505,238.91 Point 5 0.00 4,071.80 -3,210.65 5,989,972.79 505,057.91 Point 6 0.00 3,934.05 -3,456.82 5,989,834.78 504,811.91 Point 7 0.00 3,767.16 -3,578.00 5,989,667.77 504,690.93 Point 8 0.00 3,556.13 -3,567.22 5,989,456.78 504,701.94 Point 9 0.00 3,246.15 -3,616.56 5,989,146.77 504,652.95 Point 10 0.00 2,252.19 -3,748.62 5,988,152.77 504,522.00 Point 11 0.00 2,323.61 -4,142.58 5,988,223.74 504,128.00 Point 12 0.00 3,705.47 -3,878.10 5,989,605.76 504,390.93 Point 13 0.00 4,134.32 -3,693.63 5,990,034.77 504,574.91 3F-16AL1 Target 5 0.00 0.00 5,882.00 3,048.35 -3,794.88 5,988,948.80 504,474.87 70° 22' 51.733 N 149° 57' 49.014 W - actual wellpath misses by 152.58ft at 10233.93ft MD (5864.42 ND, 3071.80 N, -3944.62 E) - Point 3F-16AL1 Fault 3 0.00 0.00 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 70° 22' 50.416 N 149° 57' 57.446 W - actual wellpath misses by 5857.29ft at 10391.65ft MD (5855.70 ND, 2914.87 N, -3946.73 E) - Polygon Point 1 0.00 2,914.66 -4,083.06 5,988,814.81 504,186.87 L 6/17/2008 3:31:35PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPh~lips(Alaska) Inc. Project: Kuparuk River Unit Slte: Kuparuk 3F Pad Well: 3F-16 Wellbore: 3F-16AL1 TD Design: 3F-16AL1 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: r~.r is iY6i1~8 INTEQ We11 3F-16 Mean. Sea Level 3F-16A (c~ 88.OOft (3F-16A) True. Minimum Curvature EDMv16 Prod Point 2 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 Point 3 0.00 2,914.13 -3,583.01 5,988,814.83 504,686.87 Point4 0.00 2,914.40 -3,833.04 5,988,814.82 504,436.86 3F-16AL1 Target 2 0.00 0.00 5,958.00 4,118.99 -3,382.63 5,990,019.78 504,885.90 70° 23' 2.264 N 149° 57' 36.962 W - actual wellpath misses by 743.70ft at 9760.16ft MD (5896.27 ND, 3523.04 N, -3823.22 E) - Point 3F-16AL1 Target 1 0.00 0.00 6,004.00 4,114.54 -2,981.59 5,990,015.78 505,286.90 70° 23' 2.222 N 149° 57' 25.223 W - actual wellpath misses by 1034.32ft at 9760.16ft MD (5896.27 ND, 3523.04 N, -3823.22 E) - Point 3F-16AL1 Fault 1 0.00 0.00 0.00 3,658.52 -3,896.20 5,989,558.80 504,372.89 70° 22' 57.733 N 149° 57' 51.989 W - actual wellpath misses by 5890.73ft at 9890.48ft MD (5884.45 ND, 3394.10 N, -3832.61 E) - Polygon Point 1 0.00 3,658.52 -3,896.20 5,989,558.80 504,372.89 Point 2 0.00 3,504.29 -3,696.34 5,989,404.80 504,572.90 Point 3 0.00 3,350.07 -3,496.48 5,989,250.82 504,772.91 Point4 0.00 3,504.29 -3,696.34 5,989,404.60 504,572.90 3F-16AL1 Target 3 0.00 0.00 5,962.00 3,931.19 -3,579.66 5,989,831.79 504,688.89 70° 23' 0.416 N 149° 57' 42.733 W - actual wellpath misses by 479.72ft at 9760.16ft MD (5896.27 ND, 3523.04 N, -3823.22 E) - Point 3F-16AL7 Target 6 0.00 0.00 5,834.00 2,623.41 -3,877.37 5,988,523.81 504,392.86 70° 22' 47.553 N 149° 57' 51.422 W - actual wellpath misses by 79.11ft at 10626.OOft MD (5867.39 ND, 2694.77 N, -3870.19 E) - Point Checked By: Approved By: Date: I • • 6/17/2008 3:31:35PM Page 6 COMPASS 2003.16 Build 42F KRU 3F-16A Injector with L1, L1-01 Laterals H. 4'/z" Camco DB nipple, 3.875" min ID at 510' MD 9-5/8" 36~ J55 ~ 3884' G. 4'/" Baker CMU sliding sleeve @ 6767' MD w/ 3.812" min ID 7" 26N J-55 Q 7015' AAD 2-7/8" liner top 8206' MD Window in 4-1/2" KOP at 8226' MD via flow-thru whipstock A3/A2 sand pert 8230' - 8246' MD 8662' - 8808' MD 4-1/2" 12.6'1« L-80 ~ 8580 MD' F. Baker `BABE-3' packer at 6814' MD E. 4'/" Otis "X" nipple, 3.812" min ID at 6828' MD D. Baker seal assembly at 6829' MD C. 4'/z" muleshoe at 6831' MD B. Baker CMC liner hanger at 6841' MD A. 4'/" Camco DB nipple at 7846' MD (Note: Milled out to 3.80" ID on 4/12/08.) 2-7/8" slotted liner, all laterals 3F-16AL1-01 TD @ 10,608' MD 41 /8" hole All laterals ~ 3F-16AL1-P61 ~ ~ 9775' -10,054' MD ~- ~ = ~~ -_ _.._ ..~ -- ~ - .~ 3F-16AL1 TD @ 10,626' MD Fill Aluminum billet KOP @ 8712' MD June 4, 2008 Conoco hilli s p Alaska, Inc. ~~~~ BAKER N~l~HE INTEL 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: June 26, 2008 Please find enclosed directional survey data for wells: 3F-16AL1PB1 ~ 3F-16AL1-~ 3F-16AL1-O1 2D-06BL1 Enclosed is: lea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahnken ~ °g-©~c ~ • ~ Maunder, Thomas E (DOA) Page 1 of 1 From: Regg, James B (DOA) Sent: Wednesday, April 30, 2008 4:39 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: KRU 3F-16A Redrills ~~~"~ ~~~ Martin -Regarding your question about flowing back wells to clean up prior to commencing injection... I confirmed our phone conversation with Tom Maunder since he handles the well permitting. He indicated that it is usual for wells to flow back for a short period of time for clean-up prior to initiating injection. In the past we have used up to 30 days of flaw back as a general guide before classifying the well as a producer, although we really do not have a specific time frame that we use. Really gets to intent -are you cleaning up to improve infectivity or are you producing the well. If the flow back resulted in classifying the well as a producer, CPAI would be required to submit paperwork to change the well to an injector before commencing injection. Based on what you explained for 3F-16A redrills, i.e., flow back was included in work procedure attached to the PTD application, and duration is estimated to be about 1 week, I don't forsee anything additional that we would need. Jim Regg AOGCC 333 W,7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 7/29/2008 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Eller CT Drilling Engineer ConocoPhillips Alaska Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk River Field, Kuparuk River Pool, KRU 3F-16AL1 ConocoPhillips Alaska Inc. Permit No: 208-043 (Corrected) Surface Location: 82' FSL, 227' FEL, SEC. 19, T12N, R09E, UM Bottomhole Location: 2759' FSL, 4113' FEL, SEC. 19, T12N, R09E, UM Dear Mr. Eller: This letter replaces our previous letter dated April 2, 2008 which omitted the condition of the multi-lateral clause. Please see below. The permit is for a-new wellbore segment of existing well KRU 3F-16A, Permit No 196-151, API 50- 029-21502-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair ~~ DATED this ? day of April, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~ COI~SERQA ATIO C M1~IIDSS O1S~T Gary Eller CT Drilling Engineer ConocoPhillips Alaska Inc. PO Box 196612 Anchorage, Alaska 99519-6612 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Pool, KRU 3F-16AL1 ConocoPhillips Alaska Inc. Permit No: 208-043 Surface Location: 82' FSL, 227' FEL, SEC. 19, T12N, R09E, UM Bottomhole Location: 2759' FSL, 4113' FEL, SEC. 19, T12N, R09E, UM Dear Mr. Eller: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). incerely, aniel - . Seamount, Jr. Chair n DATED this 2 day of April, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL ~~~ ~,~~~~ MAR 2 5 2008 20 AAC 25.005 t,^,png, Comrni~sinf~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well i fir: [~ Coalbed Methane G s 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 3F-16AL1 ° 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10500 ND 5835ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 82' FS 22T FEL SEC 9 T1 R0 E UM 7. Property Designation: ADL 025632 =River Pool L, , . 1 , 2N, 9 , Top of Productive Horizon: 3971' FSL, 3150' FEL, SEC. 19, T12N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 15, 2008 Total Depth: 2759' FSL, 4133' FEL, SEC. 19, T12N, R09E, UM 9. Acres in Property: 2569" Zc~~$ 14. Distance to Nearest Property: 11,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-508273 • y-5985905 ' Zone-ASP4 10. KB Elevation ;,L7.O~ (Height above GL): 88 feet 15. Distance to Nearest Well Within Pool: 1,470' ` 16. Deviated Wells: Kickoff Depth: •8230 ~ feet Maximum Hole An le: 101 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: ~ 3955 Surface: - 3349 t8. Casin Pr ram: S ecificatio ns To - Settin th -Bo ttom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" 2-7/8" 6.4# L-80 STL 475' 10025' 5884'ss 10500' 5835'ss Uncemented Slotted Liner 19. PRESE NT WELL-CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 8580 Total Depth TVD (ft): 6301 Plugs (measured): None Effective Depth MD (ft): 8484 Effective Depth TVD (ft): 6230 Junk (measured): None asing Length Size Cement Volume MD TVD Conductor /Structural 115' 16" 328 sx Arcticset I I 115' 115' Surface 3884' 9-5/8" 1125 sx Permafrost'E' 425 sx Class 'G' 3884' 3047' Intermediate 7015' 7" 250 sx Class 'G' 180 sx Permafrost'C' 7015' 5132' Producti n Liner 1748' 4-1/2" 250 sx Class'G' 6832' - 8580' 5002' - 6301' Perforation Depth MD (ft): 8230' - 8300' Perforation Depth TVD (ft): 6040' - 6093' 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 c that the for oing is true and correct. Contact Gary Eller, 529-1979 (Cell) Printed Na Gary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 263-4172 Date ~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: Z~.-L' ~3 API Number: 50-029-21502-60-00 Permit Approval See cover letter for Date: ' ~~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me~th~ane, gas hydrates, or gas contained shales: ~ ~ ~\W~ ~~, `J~~ ~~ ` Samples Req'd: ^ xes CldNo Mud Log Req'd: ^,Yes Q'No C T H S Measures: Q~Yes ^ No Directional Survey Req'd: ©'Yes ^ No other: ~i1 M l~ \ ~ 5~~~~ ~ Cdh~C~E~ ~-.l~~V.~<<`~S C~c~Jc~*~~ ~b E3~`~y;~-~~~. _/~ APPROVED BY THE COMMISSION lj ~ Date C/ ei ,COMMISSIONER Forrn 10-461 Rev~ed 12/2005 + l (..) ~ ~ ~ n' ~ ~v ~ ~ Submit In3D ZT Qtea KRU 3F-16A Triple Laterals -Coiled Tubing Drilling Summary of Operations: A coiled tubing drilling rig will drill three laterals in well KRU 3F-16A using the managed pressure drilling technique. These horizontal laterals will target Kuparuk A2/3 sands to increase injection support in an under- performing fault block to the south. The perforations in the motherbore will remain open to injection. 1. The ALl lateral will kick off from the motherbore the top of the existing A sand perfs at 8230' MD -~ targeting the A2 Sand to the south. The lateral will be 2270' in length and will be completed with 2'/e" slotted liner to a TD of 10,500' MD. ' 2. The AL1-O1 lateral will kick off from the AL1 lateral at 10,025' MD and will target the A3 Sand. The AL1-O1 lateral will be 675' in length and will be completed with 2'/8" slotted liner to a TD of 10,700' MD. 3. The final lateral, AL1-02, will kick off from the AL1 lateral at 9600' MD and will also target the A3 Sands. The AL1-021ateral will be 700' in length and will be completed with 2'/8" and 3-3/16" slotted liner to a TD of 10,300' MD. Only this final drilled lateral will remain accessible through-tubing. CTD Drill and Complete 3F-16A program: Apri12008 Pre-Rig Work I . Obtain updated static BHP on A sand. 2. Test Packoffs - T & IC. 3. Positive pressure and drawdown tests on MV and SV. 4. MIT-IA, MIT-OA. 5. Slickline tag fill and drift 4%i" tubing. 6. Run caliper log from 8300' to surface 7. Drill out the 3.75" DB nipple at 7846' MD to 3.80" 8. Set aflow-through monobore whipstock for 4%2" liner whipstock at 8230' MD with high-side orientation. Rig Work 1. MIRU Nordic Rig #2 using 2'/g" coil tubing. NU 7-1/16" BOPE, test. 2. 3F-16AL1 Lateral a. Mi113.80" window with high-side orientation. The planned KOP is at 8230' MD at the top of the A sand perfs. `T''~ ~ ~ `-~' b. Drill 3.75" x 4'/e" bi-center lateral turning south to 8650' MD. c. Continue drilling the horizontal lateral south in the A2 sand with a 3.70" conventional bit to ~~~-t.-`~ TD of 10,500' MD. d. Kill well. Run 2%s" slotted liner with aluminum billet from TD up to f 10,025' MD. 3. 3F-16AL1-O1 Lateral a. Dri113.75" x 4'/s" bi-center horizontal AL1-O1 lateral in the A3 sand from 10,025' to TD at 10,700' MD. b. Kill well. Run 2'/s" slotted liner with aluminum billet from TD up to (9600' MD. 4. 3F-16AL1-02 Lateral a. Drill 3.75" x 4'/s" bi-center horizontal AL 1-021ateral in the A3 sand from 9600' to TD at 10,300' MD. b. Kill well. Run 2'/s" and 3-3/16" slotted liner from TD up inside the motherbore at 8200' MD. 5. Freeze protect. ND BOPE. RDMO Nordic 2. Post-Rig Work 1. Obtain static BHP 2. Produce well to flowback tanks to clean up. 3. Return well to injection. Page 1 of 3 March 24, 2008, FINAL u KRU 3F-16A Triple Laterals -Coiled Tubing Drilling Mud Program: , • Will use chloride-based Biozan brine (8.6 ppg) for milling operations, and chloride-based Flo-Pro mud 010.0 ppg) for drilling operations. Since there is no SCSSV installed in 3F-16A, we will have to kill the well to deploy slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 3F-16AL1: 2'/a', 6.4#, L-80, STL slotted liner from 10,025' MD to 10,500' MD • 3F-16AL1-O1: 2'/8", 6.4#, L-80, STL slotted liner from 9600' MD to 10,700' MD • 3F-16AL1-02: 2'/8", 6.4#, L-80, STL slotted liner from 8650' MD to 10,300' MD, and 3-3/16", 6.2#, L-80, TC-II pre-drilled liner from 8200' to 8650' MD. Existing Casing/Liner Information Surface: 95/8", J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi. Production: 7", J-55, 26 ppf Burst 4980 psi; Collapse 4320 psi Liner: 4'/z", L-80, 12.6 ppf Burst 8430 psi; Collapse 7500 psi Well Control: • Two well bore volumes 0250 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 23/8" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Maximum potential surface pressure is 3349 psi assuming a gas gradient to surface and the most recent measured pressure in 3F-16A (i.e. 3955 psi at 6065' TVD in Feb-08). • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 3F-16AL1: 11,500' to property line, 1470' to we113F-15 • 3F-16AL1-O1: 11,500' to property line, 1470' to we113F-15 • 3F-16AL1-02: 11,500' to property line, 1900' to well 3G-03 Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static pressure measured in 3F-16A is 3955 psi on 2/18/08 (i.e. 12.5 ppg EMW at 6065' TVD). Prior to that, the survey taken in December 2007 showed that reservoir pressure was 4006 psi (i.e. 12.8 ppg EMW). Page 2 of 3 March 24, 2008, FINAL • KRU 3F-16A Triple Laterals -Coiled Tubing Drilling Hazards • The static formation pressure in 3F-16 is elevated. Expect to encounter decreasing pressure as the laterals are drilled away from the 3F-16A motherbore. 3F-16, 3F-15, and 3A-02 injectors have been shut in to de-pressure the area prior to drilling these laterals. Formate-base completion brine (13.1 ppg maximum) will likely be required to kill the well to run slotted liners. Some applied backpressure will be ~ needed to balance formation pressure during drilling if 10.0 ppg solids-free mud is used. • There is some risk of collision with the original, abandoned 3F-16 wellbore. Plan #4 for the L1 lateral passes within 73' of 3F-16 at 9325' MD. A `Tolerable Collision Risk' worksheet has been completed. The only risk associated with colliding with this wellbore will be in lost time for sidetracking; there is no additional HSE risk associated with a collision of this abandoned well. • Well 3F-16A has been a miscible gas injector as recently as September 2007. Any kicks would be expected to contain a significant fraction of gas. • We113F-16A is an injection well so it has no HZS present. Wells 3F-17 and 3F-15 are adjacent to 3F-16A. 3F-17 has 115 ppm HZS as measured on 1/7/08, and 3F-15 another injection well with no HZS ~ present. The maximum HZS level on the 3F pad is 280 ppm from we113F-10. All HZS monitoring equipment will be operational. / Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by .% using 10.0 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 less expensive 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 manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 3" BHA will be accomplished utilizing the variable pipe rams and 3" slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. There is no SCSSV in we113F-16A, so the well will have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 3955 psi at 8265' MD (6065' TVD), or 12.5 ppg EMW. ~ • Expected annular friction losses while circulating: 537 psi (assuming friction of 65 psi/1000 ft). • Planned mud density: 10.0 ppg equates to 3154 psi hydrostatic bottom hole pressure at 6065' TVD • While circulating 10.0 ppg fluid, bottom hole circulating pressure is estimated to be 3691 psi or 11.7 ppg EMW without holding any additional surface pressure. Applied back-pressure of 300 psi will be required to overbalance formation pressure while circulating. • When circulation is stopped, it is anticipated that 800 psi of surface pressure shall have to be applied to balance reservoir pressure and maintain the same borehole pressure as during drilling operations. Page 3 of 3 March 24, 2008, FINAL • ConocoPhillips Alaska, Inc. KRU 3F-16A 3F-16A API: 500292150201 Well T e: INJ An le TS: 40 d 7990 SSSV Type: NIPPLE Orig Com letion: 9/23/1996 Angle @ TD: 42 deg @ 8580 Annular Fluid: Last W/O: Rev Reason: TAG FILL NIP(51o-511, Reference Lo : Ref Lo Date: Last U date: 8/7/2006 oD:a.SOO> Last Ta : 8299 TD: 8580 ftK6 TUBING - Last Ta Date: 7/28/2006 Max Hole An le: 54 d 3495 (0-6838, oo:a.5oo Casin Strin -CONDUCTOR , 10:3.b33) Descri (ion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 Casin Strin -SURFACE Descri lion Size To Bottom TVD Wt Grade Thread SUR. CASING 9.625 0 3884 3045 36.00 J-55 Casin Strin -PRODUCTION Nordic SIDETRACK 7015' Descri lion Size To Bottom TVD Wt Grade Thread SLEEVE PROD. CASING 7.000 0 7015 5130 26.00 J-55 (6767-6768, OD:4.500) Casin Strin -LINER PROD. I Descri lion Size To Bottom TVD Wt Grade Thread CASING LINER 4.500 6831 8580 8580 12.60 L-80 (oao15• OD:7 000 I Tubin Strin -TUBING . , wc:2s.oo) Size To Bottom TVD Wt Grade Thread 4.500 0 6838 5005 12.75 L-80 ABM-EUE Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 8230 - 8246 6039 - 6051 A-3 16 4 11/12/199 6 IPERF HSD Perf Gun, 180 deg. phasing; Oriented (+/-) 90 PKR (sala-sa15, de . F/ lowsid OD:6.151) 8266 - 8300 6066 - 6092 A-2 34 4 11/12/199 6 IPERF HSD Perf Gun, 180 deg. deasFgi Osednted (+/-) 90 Other lu s e ui .etc. -JEWELRY De th TVD T e Descri lion ID 510 510 NIP Camco'DB' Ni le 3.875 6767 4955 SLEEVE Baker CMU Slidin Sleeve; CLOSED 9/23/96 3.812 6814 4988 PKR Baker'SABL-3' 3.875 NIP (saza-sszs 6828 4998 NIP Otis 'X' Ni le 3.813 , oD:a.SOO) 6829 4999 SEAL Baker Locator SEAL ASSEMBLY 3.937 SEAL 6841 5007 HANGER BKER CMC MECHANICAL LINER HANGER 4.313 (saes-sa3o, OD 4 500 7846 5745 NIP Camco'DB' 3.750 : . ) HANGER (6841-6842, OD:5.000) LINER (6831-8580, OD:4.500, W (:12.60) NIP (7846-7847, OD:3.833) Perf (8230-8246) Perf (8266-8300) - KRU 3F-16AL1 /L1-01 /L1-02 Injector Proposed CTD Completion 9-518" 36M J55 ~ 3884' 7" 26# J-55 ~ 7015' MD G. 4-1 /2" Camco DB nipple, 3.875" min ID at 510' MD F. 4-1/2" Baker CMU sliding sleeve @ 6767' MD w/ 3.812" min ID Conoco hilli s p Alaska, Inc. E. Baker `BABE-3' packer at 6814' MD D. 4 YZ" Otis "X" nipple, 3.812" min ID at 6828' MD C. Baker seal assembly at 6829' MD 2-7/8" slotted liner, 12 slots/ft, 1/8" slot width B. Baker CMC liner hanger at 6841' MD A. 4-'/i" Camco DB nipple, 3.75" min ID at 7846' MD ~~~/~/~\ (milled out to 3.80" ID) /~ - - - 3-3/16" liner top @ / ~ 3F-16AL1-02 A3 Lateral, / +/-8200' MD 4-1 /8" hole / ~ TD @ 10,300' MD ~ ~ / ° All laterals / /L Window in 4-1/2" / / / ° _ _ _ _ _ i _ KOP at 8230' MD ° ° ° °R , - ~~~ - - - - -~ ~ /~ A3/A2 sand perfs - Q_ 8230' - 8246' MD ~ it 3-3/16" pre-drilled 8662' - 8808' MD ~!b ~~~ liner to - 8650' and s~o~, ~~r 4-t/2" 12 61k ~-so Fill 'F ~' Aluminum billet KOP @ ($ 8580 MD' 9600' MD 3F-16AL1-01 A3 Lateral, TD @ 10,700' MD = - - 3F-16AL1 A2 Lateral, TD @ 10,500' MD Aluminum billet KOP @ 10025' MD March 20, 2008 ConocoPhillips(Alaska) Inc. ~ Kuparuk River Unit Kuparuk 3F Pad 3F-16 Plan 4, 3F-16AL1 Plan: Plan #4 Baker Hughes INTEQ Planning Report • 20 March, 2008 r~.,~r BAKER NIJ~HE~ INTE(~ Company: CortocoPhiliips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 3F Pad WaN: 3F-16 WeNbore: PIan4,3F-16AL1 Design: Plan #4 ConocoPhillips Baker Hughes INTEQ Planning Report Is ~ tr ~u~s (INTEQ Local Co-ordinate Reference: Well 3F-16 ND Reference: Mean Sea Level MD Ref®rence: 3F-18A ~ 88.OOft (3F-16A) North Reference: True Survey Ca~ulatlon Method: Minimum Curvature Database: EDMv16 Prod project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum• NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3F Pad Site Position: From: Map Position Uncertainty: 0.00 ft WeN 3F-16 WeN Position +NI-S 0.00 ft +E/ W 0.00 ft Position Uncertainty 0.00 ft WeNhore Plan 4, 3F-16AL1 Magnetics Model Name Sample Date BGGM2007 3/12/2008 Design Plan #4 Audit Notes: Northing: 5,985,734.46 ft Latitude: Fasting: 508,662.33 ft Longitude: Slot Radius: Grid Convergence: Northing: 5,985,904.95 ft Latitude: Fasting: 508,272.74 ft Longitude: Wellhead Elevation: ft Ground Level: Declination (°) 17.70 Version: Phase: PLAN Vertical Section: Depth From (ND) +N/-S (ft) (ft) 0.00 0.00 Dip Angle Field Strength (°) (n~ 79.75 57,268 Tie On Depth: 8,147.53 +E/-W Direction (ft) (°) 0.00 225.00 70° 22' 20.081 N 149° 55' 46.550 W 0.07 ° 70° 22' 21.762 N 149° 55' 57.943 W 0.00 ft •I 3/20/2008 10:45:37AM Page 2 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 3F Pad WeM: 3F-16 Wellbore: Plan 4, 3F-16AL1 Design: Plan #4 Survey Tool Program Date From To (ft) (ft) Survey (Welibore) 95.00 7,000.00 3F-16 (3F-16) 7,020.00 8,147.53 3F-16A (3F-16A) 8,147.53 10,500.00 Plan #4(PIan4,3F-16AL1) Planned Survey MD Inc Azi 7VDSS (ft! t°) l°) (ft) 8,147.53 39.80 9.00 5,887.53 TIP 8,200.00 40.23 8.57 5,927.71 8,230.00 40.48 8.32 5,950.57 KOP 8,250.00 42.18 7.40 5,965.59 ConocoPhillips Baker Hughes INTEQ Planning Report s~R r II~+~s >.N•rEQ Local Co-ordinate Reference: Well 3F-16 TVD Reference: Mean Sea Level MD Reference: 3F-16A Q 88.OOft (3F-16A) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod Tool Name GCT-MS MWD MWD N1S (ft) 3,855.22 3,888.56 3,907.78 3,920.86 Description Schlumberger GCT multishot MWD -Standard MWD -Standard E/W (ft) -2,944.90 Northing (ft) 5,989,756.53 -2,939.75 -2,936.89 -2,935.09 5,989,789.87 5,989,809.09 5,989,822.17 Fasting DLS Vertical Section TFO (ft) (°rlooftl (ft) (°) 505,323.88 0.75 X43.69 115.05 505,328.99 0.98 -670.91 -33.07 505,331.82 0.98 -686.52 -32.74 505,333.61 9.00 -697.04 -20.00 • Start DLS 40. TFO 335. 8,300.00 60.77 357.87 5,996.64 3,959.70 -2,933.72 5,989,861.01 505,334.93 40.00 -725.48 -25.00 !, 8,396.09 97.50 346.11 6,014.50 4,051.30 -2,947.23 5,989,952.58 505,321.33 40.00 -780.69 -18.97 Start DLS 40. TFO 2T4. 8,400.00 97.62 344.53 6,013.99 4,055.05 -2,948.21 5,989,956.33 505,320.34 40.00 -782.65 -85.40 8,500.00 98.65 304.12 5,999.23 4,133.77 -3,004.66 5,990,034.98 505,263.81 40.00 -798.40 -85.61 8,546.09 97.71 285.52 5,992.62 4,152.82 -3,045.88 5,990,053.98 505,222.57 40.00 -782.72 -91.57 Start DLS 12. TFO 269. $600.00 97.55 278.99 5,985.46 4,164.16 -3,098.07 5,990,065.26 505,170.38 12.00 -753.84 -91.00 ', 8,650.00 97.31 272.95 5,978.99 4,169.31 -3,147.36 5,990,070.36 505,121.09 12.00 -722.63 -91.87 33/16" 8,700.00 96.99 266.91 5,972.76 4,169.25 -3,196.95 5,990,070.24 505,071.51 12.00 -687.52 -92.65 II 8,746.09 96.63 261.35 5,967.29 4,164.57 -3,242.45 5,990,065.52 505,026.01 12.00 -652.04 -93.40 I Start DL312. TFO 249. 8,800.00 94.28 255.30 5,962.15 4,153.71 -3,294.98 5,990,054.60 504,973.50 12.00 -607.21 -111.00 3/20/2008 10:45:37AM Page 3 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Ino. Project: Kuparuk River Unit. Sits: Kuparuk 3F Pad WeN: 3F-16 Wsilbore: Plan 4, 3F-16AL1 Design: Plan #4 Planned Survey ConocoPhillips Baker Hughes INTEQ Planning Report Lacal Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey CatculaUon Method: Database: N.ilr ~iiua~es INTEQ We113F-16 Mean Sea Level 3F-16A Q 88.OOft (3F-1BA) True Minimum Curvature EDMv16 Prod NDSS N/S E/W Northing Easting DLS ln) (~) (fti (n) Ift) (°nooft) 5,958.56 4,120.81 -3,385.02 5,990,021.61 504,883.51 12.00 AAD Inc Azi ', 8,896.09 89.99 244.58 Start DLS 12. TFO 266. 8,900.00 89.96 9,000.00 89.13 9,046.09 88.76 ', Start DLS 12. TFO 274. 9,100.00 89.21 ', 9,196.09 90.05 ', Start DLS 12 TFO 290. 9,200.00 90.21 9,300.00 94.29 9,400.00 98.19 ', 9,446.09 99.89 Start DLS 12. TFO 93. 9,500.00 99.49 ', 9,600.00 98.43 9,696.09 97.07 Start DLS 12. TFO 254 9,700.00 96.94 ', 9,800.00 93.50 ', 9,846.09 91.86 Start DLS 12. TFO 270. 9,900.00 91.85 9,996.09 91.77 Start OLS 1Y. TF0 ~. 10,000.00 91.77 10,096.09 91.73 ', Start DLS 12. TFO 66. 244.11 5,958.57 4,119.12 -3,388.54 5,990,019.91 504,879.99 12.00 232.14 5,959.37 4,066.42 -3,473.31 5,989,967.12 504,795.29 12.00 226.62 5,960.22 4,036.43 -3,508.27 5,989,937.10 504,760.36 12.00 220.17 5,961.17 3,997.29 -3,545.29 5,989,897.92 504,723.39 12.00 208.67 5,961.79 3,918.16 -3,599.51 5,989,818.73 504,669.26 12.00 Vertical Section TFO (h) (°) -520.29 -111.58 -516.60 -94.00 -419.39 -94.00 -373.46 -93.90 -319.61 -86.00 -225.32 -85.89 208.23 5,961.78 3,914.72 -3,601.37 5,989,815.29 504,667.40 12.00 -221.57 -70.00 196.93 5,957.84 3,822.63 -3,639.68 5,989,723.17 504,629.20 12.00 -129.36 -70.00 185.51 5,946.94 3,725.31 -3,659.03 5,989,625.84 504,609.96 12.00 -46.87 •70.45 180.18 5,939.70 3,679.87 -3,661.29 5,989,580.40 504,607.75 .12.00 -13.14 -71.69 186.73 5,930.61 3,626.86 -3,664.50 5,989,527.39 504,604.60 12.00 26.62 93.00 198.84 5,914.98 3,530.72 -3,686.33 5,989,431.24 504,582.88 12.00 110.04 94.10 210.39 5,901.98 3,444.32 -3,725.93 5,989,344.81 504,543.38 12.00 199.13 96.00 209.94 5,901.50 3,440.96 -3,727.88 5,989,341.45 504,541.43 12.00 202.88 -106.00 198.39 5,892.38 3,350.26 -3,768.54 5,989,250.71 504,500.87 12.00 295.77 -106.06 193.10 5,890.23 3,305.97 -3,781.03 5,989,206.41 504,488.44 12.00 335.92 -107.11 186.63 5,888.48 3,252.91 -3,790.26 5,989,153.34 504,479.27 12.00 379.96 -90.00 175.09 5,885.44 3,157.04 -3,791.70 5,989,057.48 504,477.93 12.00 448.77 -90.21 175.56 5,885.32 3,153.14 -3,791.38 5,989,053.59 504,478.26 12.00 451.30 90.00 187.10 5,882.37 3,057.29 -3,793.61 5,988,957.74 504,476.14 12.00 520.66 90.01 3/20/2008 10:45:37AM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips ~~.r B Baker Hughes INTEQ Planning Report ~t~s INTEQ Company: ConocoPhillips(Alaska) .Inc. Local Co-ordinate Reference: We113F-16 Project: Kuparuk River Unit TVD Reference: Mean Sea Levei Site: Kuparuk 3F Pad MD Reference: 3F-16A ~ 88.OOft (3F-16A) Weli: 3F-16 North Reference: True Wellbore: PIan4, 3F-16AL1 Survey Caiculatlon Method: Minimum Curvature` Destgn: Plan 1W Database: EDMv16 Prod Planned Survey MD Inc Azi TVDSS N/S E/W Northing Easting DLS Vertical Section TFO 10,100.00 91.92 187.53 5,882.25 3,053.41 -3,794.11 5,988,953.86 504,475.64 12.00 523.75 66.00 10,200.00 96.73 198.56 5,874.68 2,956.44 -3,816.54 5,988,856.88 504,453.32 12.00 608.18 66.01 10,296.09 101.12 209.35 5,859.73 2,869.83 -3,854.95 5,988,770.23 504,415.00 12.00 696.59 66.85 '~ Start DLS 12. TFO 251. ~, 10,300.00 100.97 208.90 5,858.98 2,866.47 -3,856.82 5,988,766.87 504,413.14 12.00 700.28 -108.00 10,400.00 96.86 197.48 5,843.44 2,775.82 -3,895.60 5,988,676.18 504,374.46 12.00 791.81 -109.09 ', - 10,500.00 92.48 186.27 5,835.27 2,678.46 -3,916.05 5,988,578.81 504,354.13 12.00 875.11 -110.86 3/20/2008 10:45:37AM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips Type TarpM ALnattl Oln Type WS EM' Fmm ND User 018 Target (FreeNN) 22500 SMM 0.00 D00 0.00 ~(y~~ prylyyya 3F-16A ®00.001113F-16AI Mg061. I(u~ ]i M SNe: NIYl6ora: Pan 4. 3enslul .,,n . ,r la. P16n: Pion HIJF.1vPlan d, >F-i8AL1) nmMO. xu~sa WELL DET/~L3: SAS Gaewrtl LaeM5.5B NYS IEIiY NorNlnS Eaatlrtp latllprW LmplWtls Bbl 5.55 0.0985636.15 18NOS/.1N10' II' 25.N1 M49' 559.15! W SECTION DETAILS Sac MD Aa "TVD ~W-S ~EI~W DLag TFace VSec Taget NO MD AmdeUOn 56 1 810]53 39'60 9.00 566].53 3855.22 -290490 000 0.00 L43.69 ~53 810]53 TIC 5 ~ ~ 8230 00 2 8230.00 40.48 8.32 5930.5] 39D].]e -293G.B9 0.98 "33.0) .686.52 9 5 . + 98558 e25000 91w1 DLS 00 TFO 33 3 825000 42.18 ).40 5965.59 3920.86 -293509 900 390.0069].04 ] nOLS 40. TFO 21 id 50 396 6 839608 5 854608 9).50 9).]t 346.11 285.52 6014.50 5992.62 0051.30 9152 B2 "290).23 d0.00 335.00 - 80.69 -3005.88 00.00 2)d.fi0 ")82)2 ~ 599282 esle nOLS 12 iFO 26 14008 9 6 B]dfi.09 96.6J 261.35 59fiT29 0161.5) -32d245 12.00 26900 -fi5200 585856 8 2 TF026 w ~ ~ ) 888609 8 9066.08 9 8196.09 89.98 Be.l6 90.05 204.58 22662 208.6] 5958.% 5960.12 586119 J12D81 d036A3 3918.16 -338502 12.00 249.OD -SN29 -35082] 1200 26600 -3]306 3593.51 12.00 11d 00 -225.32 g 5~ 22 Da Sari DLS t2 TFO 2) ]e 8~98.o S~n oLS t2 TFO 281 0 O6S 12. TFD 83 10 9006.09 11 9696.09 99 88 97'.0] 180.18 210.39 SB39.]0 580199 36)9.8] 3410.32 -3661.29 12.00 290.00 -13.10 -3]T593 1200 8100 199.13 8 8888.09 SIen DLS t2 TF02 se0y e 8816.08 San DLS t2 TFD 2) 12 9846.09 13 9896.09 91.86 91.]1 193.10 115.09 589013 5885 JI ]305.9] 315]00 -3)81.03 1200 254.00 3J5.92 -3]91]0 1200 21D.00 448.n i4 9898.09 Sian DLS 12 iF090 56823) 1pW6.OB San D6912 TFO S6 14 10096.09 15 10288.09 9113 10112 18].10 20935 5882.3) 5B59.IJ 305).29 286083 3]83.61 1]00 90.W 520.fifi "385495 1200 66.00 096.59 5658)3 10288.09 San ohs 121F0251 50352) 1650000 TD e110500 18 1050000 92.08 18fi1] 5835.2] 2618.46 ~391fi O6 1200 251.00 8]5.11 ~~~~~OL~ 3F"tfi. 3F-16. 3F-16 V0 ~ ~ - Conlacl Information: l.VF1VtKrw~~IPS 3F-16. 3F-1fiA. 3F-16A V0 ~y.n ~- _ ~-__ BIII MIDhaelson: CBI: ~~-9t)f-3570 3F-16, Plan 4, 3F-16K1-01, Plan -- - "- 3F"tfi. Plan 4, 3F-16AL1-02. Plan v Ertl3il: bill.michafil3Dn~inle ~ ~ ~EaEen ~~ yrs,r~ _ ConocoPhillips ~a~ ~~~~,~ " ~.~m~ ~ p I~'I'CQ Type Target MnaN Oran TVPa N5 EIW Fnan TVD t User No Target lFraanaral 3]500 SM 0.00 0.00 0.00 Y r en V ' Y-18A~eeooa l3F-1aA1 ra. wn relxa0" Rgae: KuPerWr RlwTleYl ~ aae: ^wrrw aF v.a wr , . o w.g: Y-fe w.xeor.: tea, aFneru+ v.o, .. ,,. .r ~.. RYI: P1anYlY-18IRan ~. gF-1ML1) ~""r'~ `~' •, re. wn REFERENCE INFORMATION av M+a a Co-ordinate (N/E)Refare We113F-1fi, True NOrth g mFOF-m vo e: Mean Sea Level Vero I (ND) Re/er c 'n l~ r vp 5b1-(O.OON, O.OOE) Section (VS)Refere ~ T ~~ ~ ~~ ~ ~ Measured Oepih Referen ~ 3F-16A Q SS.OOR (3F-16A) " ' ' va~ Calculation McMOd: htiNmum Curvawre .e rnsmm ceu rMn uxn xaew "a,ca ram xrm Harr Bill Mlrrwelson. UII. 90T301~3'+TO Erred oIII.MClraekon®i/Yeq.can i - -- -sm -s_so -srao mo -rxoo -ww awo .eew -rzro -w.g -anon -nw -wro -uso -aim - rr o -lWrg W'. Ira» IlrmaTm -zsso awg -zw -+_rm -rgw -rrra -raw 37~ a' aa6~ Kuparuk~D BOP Configuration for Managed Pressu~rilling 2'/s" CT Well I 3F-16A Floor I Lubricator ID = 6.375" with 6" Otis Unions 1 >: RX-46 -~ 7 1/16" 5000 psi RX-46 Kill Line I L 2 1/16" 5000 psi , RX-24 Tree Size 4-1/16", 5M J 7 1/16" 5000 psi (RX-46) or •- 4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee I I~ ~ I I( G~.. b I -~ SSV Master Valve Base Flan e Page 1 n TRANSMITTAL LETTER CHECKLIST WELL NAME ~j /~G~. .31~-- l~o ~ L, PTD# ~Z~~ - ~ ~~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: S~, c~®e•-r-~C, ~z~., ~1~• POOL: Gt u, ~ E,~ 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 se ent of existing F K ~ ~ well ~ /~, i G .3 (If last two digits in permit No. //~p r /S/, API No. 50- CS API number are ~- ~-~ Z- ~• - between 6 on should continue to be reported as a function of the 9) ~, ' ~ ~~ ~, on final API number stated above. g 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 Well Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for name of well) until after (Company Namel has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Comoanv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: I/11/2008 WELL PERMIT CF~ECKl1$T Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 3F-16AL1 Program SER Well. bore seg ^ PTD#~ 2080430 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SERI 1-01L GeoArea 890 Unit 11160 On10ff Shore On Annular Disposal ^ Administration 1 PermitfeeatCached-------------- --- -- -__ NA-_ __ _-_-------------_-------- 2 _Leasenamker-appropriate------------------------------- ---------Yes-- --- -- -------------------------------- ---,Entire well wilt lie in ADL025635•--------------------- ---- 3 Uniquewell_n_ameandnumke[ -- -- -- - --- Yes-- ----------------------- -- -- -- -- - ------ 4 Wetl located in_a_defined-pool _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - --- - ---------------------- - _ _ _ KUPARUK RIVER,_KUPARUK RV OIL - 4901p0, gcvern_ed ky Conservatiop Order No. 432G._ _ . - - 5 Well located proper distance from drilling unit.koundary_ - _ _ _ _ - - - - - - _ - - _ _ - -Yes _ _ _ - _ _ Conservation Orde[ No. 4320 contains no spacing restrictions With respect-to drilling unit koundaries. _ _ _ - _ 6 Wetl located proper distance f[om other wells_ _ - - - - - - - - - - - - _ _ - _ _ _ -Yes _ _ _ _ Conservation Order No. 4320 has-no intenvell_spaFing_restrictions, _ _ - - - - ------ 7 Sufficient acreage ayail_akle in-drilling unit- - - - - - - - - - - - - - - - - - - - - - - - -Yes - - -------- - - _ _ -Conservation Order No. 4320 has no interweli_spaeing_restr_ictions, Welibore-wilt ke-mare than 500' from _ _ 8 !f deviated, is wellkore plat_included - - - - - - - - - - - - - - - - - _ - , _ - Yes - - _ _ _ - - - an external property line-when-e ownership er lan_downershpchanges, - - _ _ ---- 9 Operator only affected party---------------------------- --_ - __ Yes-- ------- _.__--____-__ ------------------ ~ 10 Operator has_appropriatekondfnforce_______--____-__.---- _--_----Yes-- ----------------------------------- ---------------------_---- 11 Pe[mitcanbeissuedwithoufconservati4norder------------------- --------Yes-- -------------------.------------ Appr Date 12 Permiteanbeissuedwithoutadminist[ative_approval-___-__-_------- --------Yes__- - _____------__----__-- _ _ _ SFD 3127/2008 13 Can permit beapprov_edbefore15-daywait____________________-- _-_____Yes_-- ---------------------------- ____--__-,__--_ 14 Well located within area and strata authorized ky Injection 0[der # (put_10# in_commenis)_(For_ Yes - - - Area Injection Order No._ 2B _ _ - _ - - _ ----------------- 15 All welts-within 114_mile_area of review ident~ed (For service well only)- - - - - - - - - - - - - Yes - - ------------------------ - _ - 3F-16, which has been p&A'd• _ - - _ - ------------------------ 16 Pre-produced injector, duration-of pre p[oduction less than 3 months_ (For-service Well only) . - -No- - - ------------------- - - - - - - - - - - - - - - - - - - _ _ 17 Nonconven, gas conforms to AS31,05.030(j.1.A),Q2.A-D} - - - - - - - - - - - - - - - - - - - - - - -Kq _ ---------------------------- _ _ - _ - - - - - - - - Engineering 18 Conductorstringprovided__--_--______________________ ________ NA__- _-__Conductorsetin3F-1ti(185-294)•_______------__--__ -- 19 Surface cagingprotects all known_ U$DWS _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ - - - _ _ NA_ _ _ _ --------------------------- _ - - - All aquifers exempted, 40CFR_147.1p2-(k}(3)._ _ _ _ _ _ - _ - - - - - . 20 CMT vol adequate to circulate on cgnduotor_ $ surf csg - - - - - - - - - _ _ - _ _ _ _ NA_ - - - - _ - - - - _ _ Surface casing set in 3F-16, _ - - _ - --------------------- 21 CMTvoladequatetotie-fn long stringtosurfcsg_-___-_____----____ _-__-__ No___ ---------------------- _______--_----_---_ _ --------- 22 CMTwillcover-aliknownproductivehorizons______________________ ________Yss___ --------------------------------------- _-_______----__--.---_-_-_ 23 Casing designs adequate fa[ C, T B &_ permafrost_ - - - - _ _ _ - - - - - - _ - - - NA_ - - - ------------------- _ Original well and redrill met design-specifcations._ NA for slotted_liner- - - - - - - - - - - - 24 Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ - _ - - - - - - - _ - yeS - - - _ - Rig equipped with steel pits, No reserve pit plann_ed._ All waste-to approved disposalwel_I(s), _ - , - _ - _ _ - - - 25 If-a-re~drill, has_a 10.403 forakandonment been approved - _ _ - - _ - _ _ _ - _ _ _ _ _ _ _ NA_ _ _ - - - - - - - - - - - - - - - - - - - ---- 26 Adequate wellkore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - ----------------------------------------- - _ - - Proximky analysis performed. Nearest segment is 4-1l2" liner sectiQn of 3F-15A and paths diverge ( 27 If-divetter required, does it meet regulations_ _ _ - _ _ - , _ _ - - - - - - _ - - - - - _ _ NA_ _ _ _ _ . - _ - _ _ _ _ _ _ _ - BOP stackwill already-ke in place, - . Appr Date X 28 Drilling fluid program schematic & equip list adequate- _ _ _ . _ - - _ _ - - Yes _ - _ _ _ - _ -- ---- ----- ------ ----- _ -Maximum expected formation pressure 12.6 EMW. Welt will ke drilled with managed_pressure and 10.0 ppg fluid. TEM 312812008 29 BOPts, dathey meetregulation - - _ - - _ - - - - - - _ - - _ - - - _ - _ _ _ _ -Yes - - _ - _ - - _2 Wellkores volumes of KW fluid will be availakle In_Kuparuk Field during drilling operations. ~~~ /r 30 BOPE press rating appropriate; test to_(pui prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ - - - _ - _ _ _ _ MASP calculated at 3349 psi, 4p00_psiBOP testperformed• _ _ _ _ _ _ - _ _ - - _ , 31 Choke-manifold complies wlAPl_RP-53 (May 84) - - - - - - - - Yes - - - - - - - - - - - - - - - - - 32 Work Willoccu[withoutoperationshuidown---------------------- ----~---Yes--- - - - - - - - - - - - --------------------- -- -- - 33 Is presence of H2S gas prokakle- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes -- -- -- - -- - ---------------- - - H2S is reported_on 3Fpad.-Mud-should preclude H2S on rig.-Rig has sensors and.alarms•- - - - - - - 34 Mechanical condition of wells within AOR verified (Forservice well only] . _ - - - - _ Yes _ _ _ _ _ _ _ _ _ No known integrity issue wl 3F,16A._ This segment departs in-Kuparuk reservoir. Noissues-identified, _ _ _ - Geology I 35 Permit can ke issued w1o hydrogen_sulfidemxcsures . - - - - - _ - - - - - - _ - - _ _ _ _ No- _ _ - - _ _ Wells_on 3F-Pad produce between 50and 275 ppm_ H2S. _H2S_monitors win be used- - - - - - - - - - - - - ~, 36 Data-presented 4n potential overpressure zones- _ - - - - - - _ - _ _ - - _ _ - _ _ - _ Yes _ _ - Expected reservoirpressure is 12.5ppg EMW. -Will ke drflledwith_10,0 ppg using managed pressure Appr Date 37 Seismic analysis of shallow gas.zones_ _ _ .. _ _ _ - _ - _ - --------- -------- NA_-_ _ _ _ - - _ _ _ _ ____drillingtechniques. 7 38 Seabed condition survey_(ifoff-shore} - - - - - - - - - - - - - - - - - - - -- NA--- ____--__- -------------------------------------- --- -- - --- -- -~ - -- - -- - 39 Contact namelphonefor weekly_progress reports_[exploratory onhc] - - - - - - - - - - - - - - NA_ _ - Geologic Commissioner. Engineering P ~ Date: ommissioner. Date C ner Daie lateral in ector wellbore. 1 C C~' ,~~~ ~ ~ ~ (~ /~ ! ~~ fJ
