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205-115
• 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. Q(, Q ~ - ~ ~ ~ Well History Fite Identifier Organizing (done) ^ Two-sided II I II ~I I I I~ I) I II ~~~ ^ Rescan Needed ~I I I) ~) I~ ~) I I II ~ II~ RESCAN DIGITAL DATA OVERSIZED (Scannable) ~j Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: b S /s/ Project Proofing I I I l l II ~) I I I ll I I Il l BY: Maria Date: ! / s d Scanning Preparation ~_ x 30 = Q + ~~ =TOTAL PAGES / (Count does not i ~S~ude cover sheet) /A ~ ~ BY: Maria ' Date: I ~ ~ (V l Production Scanning Stage 7 Page Count from Scanned File: ~ ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: f/ YES _ BY: Maria Date: ~/~/O Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. lsl ~/ V ~ r NO t ~IIIIIIIIIIIIYIII!I ReScanned BY: Maria Date: /s/ Comments about this file: a~a~,«~~ iuuiuuiiiuim 10/6/2005 Well History File Cover Page.doc 1 ~ Nam ~~~? DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051150 Well Name/No. KUPARUK RIV UNIT 1B-15AL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22465-51-00 MD 10992 TVD 6534 Completion Date 10/14/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional FrCt"rvey Yes DATA INFORMATION -~~~~ Types Electric or Other Logs Run: MWD GR (data t aken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Inte rval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED D Asc Directional Survey 9658 10992 Open 1 B-15A L1, 1 B-15A L2, 1 B- 15A L2 PB 1, & 1 B-15A L2 PB 2 on diskette Directional Survey 9658 10992 Open 16-15A L2 Directional Survey 8270 9056 Open 1 B-15A L2 PB 1 `fpt Directional Survey 8500 10033 Open 1B-15A L2 PB 2 ~ t 14292 LIS Verification 1 8296 10992 Open 12/15/2006 LIS Veri, GR ROP w/Graphics (NO LIS DIGITAL) ~ vF,O D 14292 Gamma Ray Blu 1 $290 10992 Open 12/15/2006 GR 13-Oct-2006 14292 h~ Gamma Ray iL ~.~~ S 25 Blu 1 8290 10992 Open 12/15/2006 MDlT'VD GR 13-Oct-2006 ~ vRpt 14293 LIS Verification 1 8296 9055 Open 12/15/2006 P61 LIS Veri GRAX, ROP ', w/Graphics (NO LIS DIGITAL) D 14293 Gamma Ray Blu 1 8290 9056 Open 12/15/2006 PB1 GR 1-Oct-2006 a ~~ ~ 0 14293 9 Gamma Ra Y ` ~ 25 Blu 1 8290 9056 O en p 12/15/2006 P61 MD/TVD R 1- G Oct- 2006 pt 14294 LIS Verification 1 8296 10033 Open 12/15/2006 P62 LIS Veri, GR ROP I w/Graphics (NO LIS DIGITAL) D 14294 Gamma Ray Blu 1 8290 10033 Open 12/15/2006 P62 GR 7-Oct-2005 g 14294 Gamma Ray ~ ~-e9 ~ 1 25 Blu 1 8290 10033 Open 12/15/2006 PB2 MD/TVD GR 7-Oct- 2005 Well Cores/Samples Information: S ample Interval Set Name Start Stop Sent Received N umber Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051150 Well Name/No. KUPARUK RIV UNIT 1B-15AL2 Operator CONOCOPHILLIPS ALASKA INC MD 10992 TVD 6534 Completion Date 10/14/2005 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-22465-61-00 UIC N ADDITIONAL INFORMI~jION Well Cored? _Y kfl~pU\f Daily History Received? ~~ N Chips Received? Y/ N Formation Tops ~ N /. Analysis Y-f~1V' Received? Comments: Compliance Reviewed By: Date: Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1B-15AL2 • '~~ BAKER NUG~IES Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log LAC Job#: 982397 Sent By: Deepa Joglekar Received By: ~, Date: ~~'tt(~,~ .~ -., Date: , ~~.,~ ~~ ~, ~ ~, ~, .~~~ a ~..,,_ r PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETT7Rl~TING OR FAXING YOUR COPY ~ FAX: (907) 267-6623 Faker IIughes INTEQ ~ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 ,., ~- ~~~ a FAX: (907) 267-6623 I:I mmvm-iro~vo mn~x.o i-~ ~__ ~ -- ';; `i ~,'. ~-- , ~. _ ~, ~~~. A~ ~~-- - -- ~. ~~ ... . ~~ ,~ . ~~ _ -._ -- .~J ---- - i ,,... ~®~~~ i5 ~ • r Transmittal Form ~~® B~-KER NUCNES ri ~~.~~.m~~mr<~ INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1 B-15AL2PB 1 Anchorage GEOScience Center ~...,:.... ~ w .,~ Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log I blueline - GR TVD Log E ;~ LAC Job#: 982397 ~~ .,~ Sent By: Deepa Jo ekar ;'~. =IP~c.~~, 2006 a ,~ ~ _ ~. Received By: Dati~ ' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY r.., • ,~,.~ FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska a?OS ~ ~ i ~ 99518 )~'6 ~J ~~ Direct: (907) 267-6612 i 6 FAX: (907) 267-6623 __ --_ L__ , _T- I, ~~~ ' c~~ _. ~~ -` , ~' .- ~~ I :__ ~' i= i I • • Transmittal Form ~~.® BAKER HUGNES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1 B-15ALZPB2 Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log ,LAC Job#: 982397 Sent By: Deepa Jo le ar D . ~ ~ ~ F ~.,. Received By: - Date = ;~ ~ - ~~,~;~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & ?` -~~22NING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska. _ 9918 ~~5 -~`~ ~ { ~~~ ~~ Direct: (907) 267-6612 FAX: (907) 267-6623 r . __- __ '~ ~ -- -____ -- ~~~ l -~ ~, ~ ~- ~` `~- i _ _ _= i ~' ~:: ', ~ - ~~, . _ _ , STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC2s.,os 2oAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Glass: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Ina 5. Date Comp., Susp., or Aband. 10/14/2005 ~ 12. Permit to Drill Number 205-115 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-661 6. Date Spudded jc,~ ~ ~=-~> 200 /r.~i~•z,:~~ 13. API Number j 50-029-22465-~-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/13/2005 ~ 14. Well Name and Number: KUP 1 B-15AL2 500 FNL, 484 FEL, SEC. 09, Ti t N, R10E, UM Top of Productive Horizon: 2950' FNL, 3343' FEL, SEC. 09, T11 N, R10E, UM g. KB Elevation (ft): 34' RKB 15. Field /Pool(s): Kuparuk River Unit Total Depth: 3986' FNL, 1161' FEL, SEC. 09, T11 N, R10E, UM 9. Plug Back Depth (MD+TVD) 10992 + 6534 Ft ~*. ,~* 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 549955 y- 5969647 Zone- ASP4 10. Total Depth (MD+TVD) ~ 10992 + 6534 ' Ft 16.eP ope ~ ~' ADL 8 TPI: x- 547118 y- 5967179 Zone- ASP4 Total Depth: x- 549310 ' Y- 5966156 'Zone- ASP4 11. Depth where S 833' MD ~ ~~'~-Gnd U e ~s ` 18. Directional Surrey ^ Yes ^ No 19. Water depth, if offshore N/A MSL rost 20. ~ss ~~1558' ( Q9x.) 2 ogsRun: ~~.,rna ,~~>~ ~~~,E,, ~ ~~7_~ ' 'i 1~3J 2. ASING, LINER AND EMENTING RECORD CASING ETTINCi EPTH MD ETTINO EPTH'TVO HOLE AMOUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 121' Surtace 121' 24" 00 sx Arcticset I 9-5/8" 40# L-80 Surface 4190' Surtace 4138' 12-1/4" 00 sx AS III, 400 sx Class 'G' 7" 26# L-80 Surtace 4405' Surface 4324' 8-1/2" 50 sx Class 'G' 5-1/2" 15.5# L-80 4234' 8289' 4176' 6309' 6-1/8" 83 sx Class 'G' 3-1/2" 9.2# L-80 8121' 8289' 6170' 6309' 6-118" 5 sx Class 'G' 2-3/8" 4.6# L-80 8259' 10896' 6283' 6537' 3" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. Tusln-G RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-1/2", 9.3#, L-80 8121' MD TVD MD TVD 8449' - 8957 6418' - 6438' 9368' - 9622' 6488' - 6526' 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9656' - 10862' 6525' - 6538' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 8289' et Flow-Thru Whipstock 2000' Freeze Protect w/ Diesel 26. PRODUCTION TEST Date First Production: October 23, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 10/29/2005 Hours Tested 18 PRODUCTION FOR TEST PERIOD OIL-BBL 698 GAS'MCF 1490 WATER-BBL 300 CHOKE SIZE 176 GAS-OIL RATIO 2136 Flow Tubing Press. 17 Casing Pressure 1224 CALCULATED 24-HOUR RATE OIL-BBL 930 GAS-MCF 1986 WATER-BBL 400 OIL GRAVITY-API (CORK) 24 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ,,.,~ None ~ , /Z' / .G.' S ~~~ NOV ~ ~ 2005 -/~''~_ _. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE G 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state °None". Kuparuk 62 8337' 6348' None Kuparuk 61 8374' 6375' Kuparuk A6 8415' 6401' Kuparuk A5 8428' 6408' Kuparuk A4 8463' 6425' Kuparuk B2 8988' 6438' Kuparuk B1 9198' 6450' Kuparuk A6 9331' 6477' Kuparuk A5 9353' 6483' Kuparuk A4 9408' 6500' 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. Si d I tP~ I ~ / b~ gne ! Title Technical Assistant Date Terrie Hubble KUP 1 B-15AL2 205-115 Prepared By Name/Number.• Terre Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Aras Worthington, 265-6802 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. h'EM 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). tTEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate °None°. ITEM 29: List all test information. If none, state °None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 18 Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To -Hours Task Code NPT Phase Description of Operations 9/22/2005 10:00 - 18:00 8.00 MOB P PRE Move rig off 1 D-34. Move down Spine Road to 1 B Pad. Move rig over well and set down 18:00 - 21:00 3.00 RIGU P PRE Accegt rig for operations at 1800 hrs 9/22/05 ND tree cap. NU BOPE. Install 10' lub 21:00 - 23:15 2.25 BOPSU P PRE Initial ROPE test 4000/250. Witness waived by AOGCC Load new 2" CT reel into reelhouse. Set TL shack and camp. Set other misc buildings and cuttings box 23:15 - 23:45 0.50 BOPSU P PRE Prespud mtg given by Aras Worthington 23:45 -00:00 0.25 BOPSU P PRE Resume BOPE test 9/23/2005 00:00 - 03:45 3.75 BOPSU P PRE Finish ROPE test. Prep reel. APC build berm and set tiger tank 03:45 - 05:15 1.50 RIGU P PRE PT grapple connector. Pull CT to floor and stab. Replace packoff. Stab onto Iub 05:15 - 06:30 1.25 RIGU P PRE Fill CT w/ FW 06:30 - 07:15 0.75 RIGU P PRE Hold pre spud meeting with.day crew and A. Worthington. Review well plan and general KRU CTD performance issues. Hold HSE discussion regarding brown bear do's and don'ts. Good group participation. 07:15 - 11:00 3.75 RIGU P PRE Install Kendall coil connector. Pressure and pull test same. MU a-coil head. Test same. 11:00 - 13:00 2.00 STWHIP P WEXIT Review SSSV panel with DSO. Open sssv and monitor whp. 22 psi. Bleed same. Slowly bled off to zero. Monitor well. Complete upright tank berm. 13:00 - 13:30 0.50 STWHIP P WEXIT MU clean out BHA (2.74" D331 mill on straight mtr). Stab coil. Get on well. Test mwd. 13:30 - 15:00 1.50 STWHIP P WEXIT Run in hole to 230'. Open EDC. Forward circulate to pump e-line slack forward. Continue to run in hole. Circ at min rate. IA/OAJPVT: 1/0/275 bbls. Open sssv. No increase in whp. Continue in hole displacing coil & well to 8.6 ppg used flo pro mud. 15:00 - 15:30 0.50 STWHIP P WEXIT Circulate btms up. Take rtns to tiger tank. 15:30 - 18:00 2.50 STWHIP P WEXIT Pull out of hole. Continue to circulate following whp schedule. Close TRSSSV 18:00 - 20:00 2.00 STWHIP P WEXIT LD cleanout assy. Test MWD tools and found short. MU MWD assy to WS PVT 321 20:00 - 22:00 2.00 STWHIP P WEXIT RIH w/ BHA #2 at 80'/min. Open EDC. Circ 0.35/1260 holding 400 psi bp. Open TRSSSV 22:00 - 23:15 1.25 STWHIP P WEXIT Log GR tie-in down from 8200' to 8360' CTD. PUH 19.5k to 8300' and park while compare logs, Corr -11' to PDC GR at 8192'. Close EDC 23:15 - 23:30 0.25 STWHIP P WEXIT RIH from 8289' to 8365'. PUH to set depth 22.2k and park at 40R. Start pump at 0.5 bpm and tool stroked before 2920 psi (losing str wt). Stack 3.5k. PUH pumping at 0.5 bpm 3300 psi 19.5k. Left WS at 40R w/ top at 8336', bottom at 8345' (for now). RA pip at 8341.7'. Open EDC 23:30 -00:00 0.50 STWHIP P WEXIT POOH following pressure schedule 9/24/2005 00:00 - 01:00 1.00 STWHIP P WEXIT Fin POOH w/ WS setting assy. Close TRSSSV PVT 307 01:00 - 02:20 1.33 STWHIP P WEXIT LD WS setting assy and load out. LD MWD tools and reconfigure. MU milling assy 02:20 -04:00 1.67 STWHIP P WEXIT RIH w/ BHA #3. Open EDC and circ 0.3/1300 following pressure schedule. Open TRSSSV. Close EDC at 8200'. PVT 323 RIH at 0.53/1700 and first MW at 8343.8' 04:00 - 05:10 1.17 STWHIP P WEXIT PUH 23.5k, start motor 1.64/1.41/3400 w/ 11.25 ECD. RIH to Printetl: 10117/2005 7:36:41 AM BP EXPLORATION Page 2 of 18 O erations Summa Re ort p rY p Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: bate From`- To Hotars Task Code ' NPT Phase Description of Operations 9/24/2005 04:00 - 05:10 1.17 STWHIP P WEXIT first MW at 8343.4' and flag. Corr to 8336'. Got 0.15' too quick and stalled. Start over and mill to 8337' 05:10 - 08:00 2.83 STWHIP P WEXIT Mill v~indow from 8337' 1.65/1.50/3400 w/ 11.21 ECD w/ 100 psi dill 2.5k wob 08:00 - 09:30 1.50 STWHIP N DFAL WEXIT Mill window from 8339'.. Taking a lot of DHWOB to mill: 4k-5k#. Not much motor work. 09:30 - 11:00 1.50 STWHIP N DFAL WEXIT Pull out of hale maintaining whp. Close sssv. Pull to surface. 11:00 - 11:45 0.75 STW HIP N DFAL WEXIT Flow check well. LD BHA #2 (window milling assy). Mill & reamer recovered, but something failed inside Weatherford motor. Mill indicates centerline of 3-1/2' crossed. Mill still in good condition. Unable to determine what failed in Weatherford motor. Discuss and decide to go with Baker mtr until Weatherford problem is addressed. 11:45 - 13:00 1.25 STWHIP N DFAL WEXIT Call for Baker 2-3/8" extreme motor. 13:00 - 13:45 0.75 STWHIP N DFAL WEXIT MU BHA #4 (Baker mtr w/ 2.74" DSM window mill). Stab coil. Test mwd. Get on well. 13:45 - 15:30 1.75 STWHIP N DFAL WEXIT RIH. Pressure well. Open sssv. Continue to run in hole. 15:30 - 18:45 3.25 STWHIP P WEXIT Mill ahead from 8340'. 3650 psi fs ~ 1.5 in. 50-100 dpsi. DHWOB: 1.5k# to 3.Ok#. WHP/BHP/ECD: 25/3650/11.29 ppg. Appear to break out into formation at 8342.6' with loss of string wt, dill and increase in return loss rate 18:45 - 20:10 1.42 STWHIP P WEXIT Drill rathole from 8342.6' 1.51/1.15/3600 w/ 200 psi dill 1.5-3.5k wob ECD 11.52 to 8352' 20:10 - 22:00 1.83 STWHIP P WEXIT Backream and ream window until clean 1.5/1.21/3400. Dry drift, clean PVT 318 22:00 - 23:30 1.50 STWHIP P WEXIT POOH for build assy circ 1.5/3200 thru mill. Close TRSSSV PVT 288 23:30 - 00:00 0.50 STWHIP P WEXIT LD and load out milling assy. WM was 2.73" no-go and had outside wear Fire drill 9/25/2005 00:00 - 01:00 1.00 DRILL P PROD1 MU build assy 01:00 - 02:40 1.67 DRILL P PROD1 RIH w/ BHA #5 (2.2 deg motor, bi bit). Circ thru open EDC 0.5/1320 w/ 200 psi bp. Open TRSSSV 02:40 - 03:15 0.58 DRILL P PRODi Log tie-in down from 8190', Corr -12'. Close EDC, RIH and tag at min rate at 8356'. PUH and start pump 1.6/1.313500, bleed off 200 psi whp PVT 306 Work with orientor stops 03:15 -04:05 0.83 DRILL N DFAL PROD1 Attempt to drill from 8356' 1.54/1.30/3350/408 w/ 100 psi dill, 0.5-1.5k wob at 11.5 ECD (3715 psi dhp). Work with orientor stops, then couldn't get orientor to move. PUH thru window, clean. Determine that when the orientor is in contact w/ the WS the internal magnetometers go hay-wire. This is a BHI 'lessons teamed' that catches all the new DD's since it is not documented, but only passed on verbally. It will be documented now .. . 04:05 - 05:20 1.25 DRILL P PROD1 Drill from 8356' 1.58/1.4013500/458 w/ 200-500 psi dill, 2.5-5k wob at 11.6 ECD 05:20 - 06:15 0.92 DRILL P PROD1 Drill from 8382' 1.58/1.40/3500/458 w/ 300-600 psi dill, 3-6k wob at 11.5 ECD 06:15 - 12:00 5.75 DRILL P PROD1 Drill ahead from 8400'. 3550 psi fs ®1.157 in/1.27 out. DPSI: 100-200. DHWOB: 3-6k#. WHP/BHP/EDC? 22/3730/11.48 ppg. IA/OA/PVT: 411/10/272 bbls. ROP varying from 10 to 30 fph. Printed: 10/77/2005 7:36:47 AM BP EXPLORATION Page 3 of 18 Operations Summary Report Legal Well Name: 16-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/1512005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: ' Date From;- To Hours Task Code NPT Phase Description of Operations 9/25/2005 12:00 - 13:45 1.75 DRILL P PROD1 Drill ahead from 8503'. INC/AZM/TF: 58.1/274.2/158. PVT: 229 bbls. Complete /land build section at 8560'. 13:45 - 15:30 1.75 DRILL P PRODi Pull out of hole following whp/bhp schedule to maintain a minimum of 11.2 ppg on 62 and 62 shales. Shut in sssv with 750 psi whp. Continue to surface. 15:30 - 16:30 1.00 DRILL P PROD1 At surface. Get off well. Unstab coil. LD BHA # 5. MU BHA # 6 (0.8 deg mtr w/ Hyc bicenter). Stab coil. Test mwd. Get on well. 16:30 - 18:15 1.75 DRILL P PRODi RIH w/ BHA #6 circ thru EDC 0.3/1200 following pressure schedule. Open SSSV 18:15 - 18:50 0.58 DRILL P PROD1 Log tie-in down from 8210', corr -9'. Close EDC. RIH 0.3/1900 w/ 400 psi whp thru window, clean. Log tie-in down from 8354' to tie-in RA tag to 'mother'. See RA pip at 8346'. Therefore TOWS/TOW is 8340', BOW is 8347'. Wiper to TD 1.5/3400 18:50 - 19:20 0.50 DRILL P PROD1 Set down at 8414' several times. Ream thru at 1.35/1.32/3250/DTF w/ 11.85 ECD and precautionary ream to TD w/ MW and wt loss at 8541'. Tag TD at 8560' 19:20 - 22:40 3.33 DRILL P PROD1 Drill from 8560' 1.5/1.3/3500/908 w/ 200-500 psi dill, 2-4k wob w/ 11.85 ECD at 93 deg 22:40 - 23:05 0.42 DRILL P PROD1 Wiper to window, clean both ways 23:05 -00:00 0.92 DRILL P PROD1 Drill from 8700' 1.55/1.47/3600/908 w/ 300-500 psi dill, 2-5k wob w/ 11.94 ECD at 93 deg 9/26/2005 00:00 - 02:25 2.42 DRILL P PROD1 Continue drilling from 8754' 1.55/1.49/3560/908 w/ 400-600 psi dill 2-5k wob at 12.0 ECD. Swap to left side at 8800' 02:25 - 03:00 0.58 DRILL P PROD1 Wiper to window, clean both ways PVT 442 03:00 - 05:45 2.75 DRILL P PROD1 Drill from 8850' 1.53/1.44/3580/90L w/ 200-500 psi, 2-4k wob w/ 12.0 ECD at 94 deg. Start getting into ankerite at 8890' and slower drilling 05:45 - 09:30 3.75 DRILL P PROD1 Drill ahead from 8920'. 3650 psi fs ~ 1.60 in/1.50 out. DPSI: 250-350 DHWOB:3.0-5.Ok# WHP/BHP/EDC: 44/3942/11.98 ppg IA/OA/PVT: 668/192/418 bbls INC/AZMlrF: 93.8/299.0/90L. Continued slow drilling in ankerite streak in A sand: 10-15 fph. Get out of ankerite at 8950'. ROP: 30-50 fph. 09:30 - 10:10 0.67 DRILL P PROD1 Wiper trip to window. Log gr across RA tag. Add 4' correction. Continue wiper trip in hole. Hole smooth. 10:10 - 13:45 3.58 DRILL P PROD1 Drill ahead from 9012'. 3600 psi fs ~ 1.61 in/1.54 out. PVT: 401 bbls. 13:45 - 14:30 0.75 DRILL P PROD1 Wiper trip to window. Hole smooth both in and out. 14:30 - 19:20 4.83 DRILL P PROD1 Drill ahead from 9162'. 3750 psi fs ~ 1.63 in/1.54 out. PVT: 368 bbls. ROP: 35-50 fph. DHWOB: 2.0 - 3.Ok#. WHP/BHP/ECD: 29/4010/12.23 ppg. Back in ankerite at 9270'. Drill to 9300' and swap to right side 19:20 - 20:20 1.00 DRILL P PROD1 Wiper to window, clean both ways PVT 362 20:20 -00:00 3.67 DRILL P PROD1 Drill from 9300' in and otrt of ankerite 1.56/1.5/370011058 w/ 200-600 psi dill, 2.5-4Ak wob w/ 11.93 ECD at 87 deg 6337 TVD 9/27/2005 00:00 - 01:30 1.50 DRILL P PROD1 Drill from 9410' 1.6/1.54/3780/1358 w/ 100-400 psi dill, 1-4k wob w/ 12.2 ECD at 89 deg at 6350' TVD 01:30 - 02:10 0.67 DRILL P PRODi Wiper to window, clean 02:10 -02:20 0.17 DRILL P PROD1 log tie-in down from 8360', corr +4' 02:20 - 03:00 0.67 DRILL P PROD1 Wiper back to TD, clean PVT 368 Printed: 10/17/2005 7:36:41 AM BP EXPLORATION Page 4 of 18': Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours `'Task Code NPT Phase Description of Operations 9!2712005 03:00 - 05:15 2.25 DRILL P PROD1 Drill from 9450' 1.6/1.55/3780/1058 w/ 100-300 psi dill, 1.5-3.5k wob w/ 12.25 ECD at 85 deg at 6351' TVD PVT 361 05:15 - 06:45 1.50 DRILL P PROD1 Wiperto window. Hole smooth in and out. 06:45 - 10:45 4.00 DRILL P PROD1 Drill ahead from 9600'. 3800 psi fs ~ 1.61 in/1.53 out. DPSI: 100-200 DHWOB:1.5.-2.5k# WHP/BHP/ECD: 4414060/12.30 ppg IA/OA/PVT: 258/212/354 bbls INC/AZMlfF: 88.68/291.3/55L. ROP: 35-55 fph. Drill into a high gr formation (160 api +) at 9698'. Call TD at 9725'. 10:45 - 11:45 1.00 DRILL P PROD1 Wiper trip to window. Log gr tie in across RA. Add 6' correction. TD corrected to 9731'. 11:45 - 12:20 0.58 DRILL P PROD1 Run in hole. Start 80 bbl 8.9 ppg new flopro pill with max tubes and 3 ppb coarse Alpine beads down coil. 12:20 - 14:30 2.17 DRILL P PROD1 Wiper trip from 9700'. Pull out of hole laying in bead pill. 2600 psi ~ 1.06 in. Pull at 33 fpm. Slow rate to 0.3 bpm through window. Continue to POOH and lay in bead pill at 1.12 bpm and 35 fpm coil speed. Bead pill top at +/-6700'. Paint EOP flags at 8200' and 6700'. Continue circulating out of hole. Close sssv with 750 psi on well. Circulate to surface. 14:30 - 15:30 1.00 DRILL P PROD1 At surface. Monitor well during PJSM to review handling BHA. Get off well. Unstab coil. LD lateral drilling assy. 15:30 - 15:45 0.25 CASE P RUNPRD Safety mtg re: liner 15:45 - 19:00 3.25 CASE P RUNPRD MU 38 slotted and 5 solid jts 2-3/8" 4.6# L-80 STL R2 liner w/ Unique Indexing Guide Shoe and O-ring sub. MU BBT GS assy MU BHI MWD assy 19:00 - 20:50 1.83 CASE P RUNPRD Pressure well to 700 psi. Open SSSV bled down to 300psi. RIH with 2-3/8" finer. Weight check at window 19.5k up 9.2 dwn 20:50 - 21:10 0.33 CASE P RUNPRD Log GR tie in from 8173' -12' correction 21:10 - 2125 0.25 CASE P RUNPRD RIH to 9700'. Bring pump up to 1.2bpm. Pick-up and dropped off liner placing top at 8334'. Up wt 15.5k Open EDC 21:25 - 22:45 1.33 CASE P RUNPRD TOH to surface. Trap 300psi on well and shut SSSV. 22:45 - 23:00 0.25 CASE P RUNPRD PJSM reveiw BHA changes. 23:00 - 00:00 1.00 DRILL P PROD1 Bleed off WHP and insure SSSV is closed. Setback injector. LD BTT and BHI tools. PU BHI orienter and Weatherford LSX Whipstock and Fury setting tool. Align toolfaces. 3 PIP tags have been installed 5.69' from top of WS 9/28/2005 00:00 -00:20 0.33 STWHIP P WEXIT PU and stab injector. 00:20 - 02:15 1.92 STWHIP P WEXIT RIH to 8220' 02:15 - 02:35 0.33 STWHIP P WEXIT Log tie-in -13' correction. 02:35 - 02:55 0.33 STWHIP P WEXIT RIH to 8297' putting top of WS at 8288'. With EDC closed bring on pump build pressure to 3750psi shearing setting tool same time setdown 3-4k. PU clean to 8265' open EDC. 02:55 -04:25 1.50 STWHIP P WEXIT TOH stop at 200' close EDC close SSSV. Tag up. 04:25 -04:35 0.17 STWHIP P WEXIT PJSM. Review BHA changes. 04:35 - 06:00 1.42 STWHIP P WEXIT LD Weatherford tools and BHI orienter. PU BTT motor and 2.74" window and string mill assembly. 06:00 - 07:35 1.58 STWHIP P WEXIT RIH w/ BHA #9 0.3/1300 following pressure schedule after open TRSSV. Tag WS at 8299' at min rate PVT 391 07:35 - 11:00 3.42 STWHIP P WEXIT Start motor 1.5/1.5/3840 and RIH to first MW at 8299.7'. Corr to 8288' and flag. Mill window from 8288' 1.52/1.52/3750 w/ Printed: 1417/2005 7:36:47 AM ;BP EXPLORATION Page 5 of 18 Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hotars Task Code ' NPT Phase Description of Operations - 9/28/2005 07:35 - 11:00 3.42 STWHIP P WEXIT 100-200 psi dill 1-3k wob w/ 11.9 ECD PVT 390 11:00 - 14:30 3.50 STWHIP P WEXIT Mill from 8292' 1.52/1.52/3600 w! 100-200 psi dill, 1-3k wob w/ 11.9 ECD. Stall at 8295.6' and assume bottom of window 14:30 - 15:30 1.00 STWHIP P WEXIT Mill/dress BOW then drill OH from 8295.6' 1.5/1.5/3520 to 8303' 15:30 - 16:10 0.67 STWHIP P WEXIT Backream and ream window clean, dry tag PVT 390 16:10 - 17:30 1.33 STWHIP P WEXIT POH following pressure schedule. Close TRSSSV w/ 650 psi PVT 360 17:30 - 18:00 0.50 STWHIP P WEXIT LD and load out milling assy. Window mills gauged 2.74" go 2.73" no-go 18:00 - 22:30 4.50 DRILL P PROD2 Cut-off CTC. Perform slack management. Cut-off 90 coil. Rehead Kendal connector pull test to 38k. Rehead with BHI upper quick connect. PT to 4000psi. 22:30 - 23:20 0.83 DRILL P PROD2 PU BHA #10 23:20 -00:00 0.67 DRILL P PROD2 RIH following pressure schedule 9/29/2005 00:00 - 01:25 1.42 DRILL P PROD2 TIH w/ BHA #10 01:25 - 01:40 0.25 DRILL P PROD2 Log tie-in -13' correction. 01:40 - 01:50 0.17 DRILL P PROD2 RIH through window. No problems 01:50 - 06:00 4.17 DRILL P PROD2 Directionally drill ahead f/ 8303' with L2 build section. 1.54!1.54 FS= 3550psi Ann= 3836 ECD= 11.94 2-300psi motorwork 15-20'/hr PVT 391 06:00 - 11:00 5.00 DRILL P PROD2 Continue drilling with slow penetration in B Shales at 60-09L to 8430' 11:00 - 12:00 1.00 DRILL P PROD2 Increase in penetration rate from 8430', but also more stalls. Drill to 8453' 12:00 - 12:15 0.25 DRILL P PROD2 Wiper to window 12:15 - 16:15 4.00 DRILL P PROD2 Drill from 8453' 1.55/1.55/3600/ 75L w/ 200-400 psi dill, 2-5.5k wob w/ 11.95 ECD at 62 deg 16:15 - 17:00 0.75 DRILL P PROD2 Drill from 8500' 1.55/1.55/3640/158 w/ 200-400 psi dill, 1.5-4.Ok wob w/ 12.0 ECD at 66 deg and finally get in sand (and higher penetration race) at 8510' and land build at 8535' 17:00 - 17:15 0.25 DRILL P PROD2 Wiper to window, clean 17:15 - 18:30 1.25 DRILL P PROD2 POOH for lateral assy following pressure schedule 18:30 - 20:00 1.50 DRILL P PROD2 Check torque on BHI tools coming out. LD 2.6deg motor PU .Sdeg motor and new bicenter bit. Sevice lower quick connect. 20:00 -22:00 2.00 DRILL P PROD2 Pressure well to 700psi and open TRSSSV. RIH to 8192'. No problem seen at 8085'. 22:00 - 22:15 0.25 DRILL P PROD2 Log tie-in -13' continue logging past PIP tags installed in whipstock. Confirm window depths as follows: TOW 8289' (Pip tag 8295') BOW 8296' 22:15 - 22:30 0.25 DRILL P PROD2 RIH to bottom. 22:30 - 00:00 1.50 DRILL P PROD2 Directionally drill ahead f/ 8535' to 8625'. 1.52/1.52bpm freespin 3500psi 3-400psi motorvvork. On bottom annular pressure 3919psi ECD 11.9 2-3k wob 50-60'/hr 9/30/2005 00:00 -00:55 0.92 DRILL P PROD2 Directionally drill ahead fl 8625' to 8685'. 1.52 / 1.52 fs=3500 mw= 3-400 wob= 2k 50'/hr ann= 3900 00:55 - 01:20 0.42 DRILL P PROD2 Wiper trip to window. No problems. 01:20 - 02:00 0.67 DRILL P PROD2 Drilling ahead tJ 8685' to 8700' and hit Ankorite striver. 02:00 - 03:05 1.08 DRILL P PROD2 Drilling on Ankorite. 1.52 / 1.52 fs=3500 mw=80 wob= 4k 1 o'mr 03:05 -04:00 0.92 DRILL P PROD2 Drilling ahead f/ 8715' 1.52/1.52 fs=3500 mw=2-300 wob=1-2k 60'/hr ann=3923 ecd=11.93 04:00 - 06:00 2.00 DRILL P PROD2 Drilling on Ankorite 8775' ~ 0600hrs Printed: 10/17/2005 7:36:41 AM BP EXPLORATION Page 6 of t8 Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/30!2005 06:00 - 09:00 3.00 DRILL P PROD2 Drill from 8775' 1.5/1.5/3520/110L w/ 100-400 psi dill, 1.5-3.5k wob w/ 11.9 ECD at 80 deg in shale at 15'/hr 09:00 - 09:35 0.58 DRILL P PROD2 Start r)ew mud and drill from 8828' 1.5/1.5/3520/165L w/ 100-400 psi dill, 1.5-3.5k wob w/ 11.9 ECD at 76 deg 09:35 - 10:40 ~ 1.08 DRILL P PROD2 Wiper to window w/fresh mud at bit. Minor overpull and MW at 8440'. On RIH had set down and stall at 8415' w/ HS TF. Orient to DTF (80L) and set down at 8440'. Backream to 8390'. Ream w/ DTF to 8480' at 1.0 bpm. Continue wiper and had set down and MW at 8760', 8790', 8766' and 8815' 10:40 - 13:30 2.83 DRILL P PROD2 Drill from tag at 8839' 1.53/1.53/3800/110L w/ 100-300 psi diff, 2-4k wob at 11.80 ECD at 75 deg at 15'/hr and still in shale 13:30 - 15:50 I 2.33 DRILL P PROD2 Drill from 8900' 1.45/1.45/3740/50L w/ 100-350 psi diff, 2-4k wob at 11.84 ECD at 70 deg at 6390' TVD at 25'/hr 15:50 - 17:30 1.67 DRILL P PROD2 At 8945' perform a BHA length wiper due to slower penetration rate. GR showed Miluveach top later at 8926'. Continue drilling 1.43/1.43l3550/30L w/ 100-250 psi diff, 3-5k wob at 11.7 ECD at 70 deg at 6405' TVD at 15'/hr in the Miluveach 17:30 - 23:30 6.00 DRILL N DPRB PROD2 At 8970' perform a 100' wiper, but could not go back down past 8935'. Wiper to window. Problems washing down through build section. Maintaining constant BHP ECD 11.8ppg. RIH slow <20'/min following as drilled TF's okay to 8770 seeing MW to 8780' pick-up 22.7k work back okay RIH slow to 8880' stacking wt. work area back to 8730' RIH 1.50bpm 35'/min tag 8812' stalled motor. PU 6k over. RIH to 8814 stacking, PU 14k over. W/R slowly 12'/hr wo MW (alerted town group of problems and possible sidetrack considerations) Increase WHP from 0 to 300 psi. ECD 12.6ppg work down to 8850', increase WHP to 400psi. Work down to to 8880' and cleared up. W/R to 8935 (Miluveach Sh) and tagged. Work down maintaining 400psi WHP to 8967'. 3' difference from previous TD. 23:30 -00:00 0.50 DRILL P PROD2 Directionally drill ahead f/ 8967' 1.44 / 1.44 fs= 3900psi mw=50psi ann=4344 ecd=13.07ppg holding 400psi at surface. 2-3k wob <10'/hr 10/1/2005 00:00 -06:00 6.00 DRILL P PROD2 Directionally drilling ahead in Miluveach Sh f/ 8973' 1.45 / 1.45 fs=3925 mw=100psi ann=4367 ecd=12.93 {holding 400psi at surface) wob= 3-4k rop= 10-15'/hr 06:00 - 07:00 1.00 DRILL P PROD2 Drill from 9040' 1.45/1.45/3800/350/60L w/ 100-200 psi diff, 4k wob w/12.8 ECD at 15'Jhr in the Miluveach PVT 327 07:00 - 07:50 0.83 DRILL P PROD2 Perform 100' wiper w/ 400 psi bp. Choke and out MM started plugging off w/ shale. Choke cycling between 100 and 1400 psi. Overpulls to 5k and high MW to 8780'. Continue wiper to window while using manual choke and cleaning return lines. Shaker had a steady stream of shale peices as large as 3/8' 07:50 - 10:00 2.17 DRILL P PROD2 Pull thru window, clean at min rate. Continue to plug off choke. Bypass 'out' MM. POOH circ thru bit at 1.5 bpm wl 500 psi by ant! plug off occasionally while POOH (at reduced speed of 50'/min). Pull to surface, do in/out jog to 500' w/ no additional solids other than those from the possum belly, POOH, close TRSSSV 10:00 - f 1:15 1.25 DRILL P PROD2 LD drilling BHA. MU sidetrack BHA Function test BOP rams 11:15 - 13:30 2.25 STKOH P PROD2 RIH w/ BHA #12 (R60ST bit on 1.7 deg motor) circ thru EDC 0.3/1300 following pressure schedule. Open TRSSSV Printed: 10/17/205 7:36:41 AM 'BP EXPLORATION Page 7 of 18 Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/1/2005 13:30 - 13:45 0.25 STKOH P PROD2 Log tie-in down from 8310'/ corr -10' 13:45 - 14:00 0.25 STKOH P PROD2 Wiper to TD 1.0 bpm ~ 15'/min w/ 200 psi by with one setdown at 8410' and see brass cap get shucked PVT 313 14:00 - 15:45 1.75 STKOH P PROD2 Trough 8510-8525' 1.53/1.53l3540/140L w/ 11.78 ECD 15:45 - 16:15 0.50 STKOH P PROD2 Begin kickoff at 0.1'/min from 8525' at 135E 16:15 - 21:30 5.25 STKOH P PROD2 At 8533' see NB incl at 8517' show 2 deg loss so move TF to 90L and start drilling at 25'/hr while gradually bring TF to HS. Drilled to 8620'md 6365'tvd. (Projected dev at bit 96deg. Plan to level off to 90deg at 8800' ) 21:30 - 22:00 0.50 STKOH P PROD2 Backream sidetrack. 22:00 -00:00 2.00 STKOH P PROD2 TOH following pressure schedule. 10/2/2005 00:00 - 00:30 0.50 STKOH P PROD2 Cfose TRSSSV trapping 500psi on well. Pull to surface then RIH to 300' and circulate trapped cuttings around BHA. 00:30 - 01:00 0.50 STKOH P PROD2 L/D sidetrack BHA. 01:00 - 02:00 1.00 STKOH P PROD2 Flush all surface and BOP stack lines of trapped shale. 02:00 - 02:15 0.25 DRILL P PROD2 PJSM review procedures for cutting coil. 02:15 - 03:30 1.25 DRILL P PROD2 Cut off BHI UOC. Pump slack management. Cut 650' of coil due to fatigue. 03:30 - 06:00 2.50 DRILL P PROD2 Dress end of coil and install new Kendal CTC. Pull test to 35k and PT to 4000psi. Start reheading BHI UOC. 06:00 - 08:30 2.50 DRILL N SFAL PROD2 Test a-line continuity and found short somewhere. Track it to BHI Jupitor connector-solder had failed. Resolder and test 08:30 - 09:00 0.50 DRILL P PROD2 Pump slack forward 09:00 - 09:15 0.25 DRILL P PROD2 MU lateral assy 09:15 - 10:50 1.58 DRILL P PROD2 RIH w/ BHA #i3 (used Hyc bi bit, 0.8 deg motor) circ thru bit 0.3/1700 following pressure schedule. Open TRSSSV 10:50 - 11:05 0.25 DRILL P PROD2 Log tie-in down from 8310', corr -12' 11:05 - 11:20 0.25 DRILL P PROD2 RIH 15'/min 1.0/2300 w/ 200 psi by w/ one set down at 8410'. RIH thru sidetrack area at 135E clean to 8550'. PUH 11:20 - 12:00 0.67 DRILL P PROD2 Log tie-in down 0.6/1300 w/ 400 psi by from 8510' to 8590' and stacking wt 12:00 - 15:00 3.00 DRILL P PROD2 Ream/redrill tite hole from 8590'-TD 1.5/1.5/3520/DTF w/ 11.8 ECD. Get to sidetrack TD of 8620' and stacking wt. Attempt to PUH and were BHA stuck. Work pipe several times and came free at 51k (30k over). Wiper back up hole to 8550'. Ream/redrill from stall at 8560' 1'/min. Several stalls at 8578', then notice ECD is 14.0 ppg w/ open choke, but full returns and no loss. Ream in hole at 5'/min from 8560' to 8617' w/ no problem except stacking near the end. Wiper back up hole and 10k overpulls and MW to 8560'. Assume problem w/ BHA (motor) 15:00 - 15:15 0.25 DRILL P PROD2 Wiper thru sidetrack point and window was clean 15:15 - 16:50 1.58 DRILL P PROD2 Open EDC. POOH following pressure schedule 16:50 - 17:40 0.83 DRILL P PROD2 LD lateral assy. PT CTC, okay. FW PT MWD assy. Motor was tite and bit okay, but change both anyway 17:40 - 18:45 1.08 DRILL P PROD2 MU BHA #14 18:45 - 20:20 1.58 DRILL P PROD2 TIH open TRSSSV with SOOpsi assist TIH 8345' following pressure schedule. 20:20 - 20:30 0.17 DRILL P PROD2 Log tie-in -13' correction. 20:30 - 20:50 0.33 DRILL P PROD2 TIN past OHST wo problems at reduced pump rate. Inc rate 1.55/1.55 fs= 3320psi ecd= 11.8 ann= 3882. Stall at 8560'. 20:50 - 22:45 1.92 DRILL P PROD2 Backream to 8530' ream to 8569' stalled. Reduce pump rate to 1.Obpm RIH to 8580' backream to 8560'. Work this area. Printed: 10/17/2005 7:36:41 AM BP EXPLORATION Page 8 of 1:8 Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To -Hours Task Code NPT Phase Description ofi Operations 10/2/2005 20:50 - 22:45 1.92 DRILL P PROD2 Continue ream/backreaming .5'/min to 8620'. Backreamed to 8540 then reamed back to TD. 22:45 - 00:00 1.25 DRILL P PROD2 Direc)onally drill ahead. 1.50/1.50 fs= 3300 ann= 3880 ecd= 11.75 2-3k wob 10'/hr 10/3/2005 00:00 -04:25 4.42 DRILL P PROD2 Continue drilling ahead.f/ 8640'. 1.5 / 1.5 fs/3300 mw/2-300 ann/3910 ecd/11.87 wob/2-3k 20-30'/hr. Problem with communication to BHI tools. 04:25 - 05:00 0.58 DRILL P PROD2 Wiper trip. up wt 18.5k pulled tight at 8658'. Work down. Backream to OHST wo problem. Attempting to re-start BHi tools.Motorwork at 8450' in 'B' shale {8420'-8500') BHi problem appears to be downhole with Power/Comms sub. Wiper / backream to window. 05:00 - 06:30 1.50 DRILL N SFAL PROD2 TOH for dead BHi tools following pressure schedule. 06:30 - 10:00 3.50 DRILL N SFAL PROD2 LD lateral BHA and test tools. T~Is tested okay. Found short in same Jupitor connector (BHI end). Install new connector, test okay. Then, find fault in SWS end of connector 10:00 - 10:30 0.50 DRILL N SFAL PROD2 MU lateral assy PVT 271 10:30 - 12:00 1.50 DRILL N SFAL PROD2 RIH w/ BHA #15 (new bi bit, 0.8 deg motor) 12:00 - 12:20 0.33 DRILL N SFAL PROD2 Log tie-in down from 8320', corr 10' PVT 301 12:20 - 13:00 0.67 DRILL N SFAL PROD2 Precautionary ream from 8550' to TD 1.54/1.54/3400lDTF w/ 11.88 ECD w/ high MW and PU's at 8574', 8582', 8597', 8610', 8643'. Resi of hole was clean 13:00 - 14:00 1.00 DRILL P PROD2 Drill from tag at 8757' 1.54/1.54/3440/80-100L w/ 150-400 psi dill, 0.5-2.5k wob w/ 12.0 ECD at 25-45'/hr to 8800' PVT 302 14:00 - 14:30 0.50 DRILL P PROD2 Wiper to 8550' to check for solids in belly and ream belly some more. Wiper was clean of overpulls, but had MW from 8590-8610'. RBIH and had set downs and MW at 8560' and 8592', but much better than first time thru. Rest of hole was clean 14:30 - 15:25 0.92 DRILL P PROD2 Drill from 8800' 1.53/1.53!35001100-170L w/ 200-400 psi diff, 2-4k wob w/ 12.08 ECD at 50-70'fltr to 8850' 15:25 - 15:45 0.33 DRILL P PROD2 Wiper to 8550' to check for solids and ream fife hole again. Had MW at 8570-90' while PUH, was clean RIH! 15:45 - 16:25 0.67 DRILL P PROD'L Drill from 8850' 1.53/1.53/3520/100L w/ 200-400 psi, 2-3.5k wob w/ 12.14 ECD at 60-80'/hr to 8900' PVT 302 16:25 - 17:15 0.83 DRILL P PROD2 Wiper to window w/ MW at 8590'. RIH had set down at 8600', rest of hole was clean 17:15 - 19:00 1.75 DRILL P PROD2 Drill from 8900' 1.53/1.53/3520/801 w/ 200-400 psi, 2-3.5k wob w/ 12.12 ECD at 80-100'/hr. Drilled across fault at 8970-80 area. Drilled to 9014'. 19:00 - 19:45 0.75 DRILL P PROD2 Wiper trip. Overpulls at 8590-8570'. Pull into tbg. Called town to figure out plan forward. Intially wanted to drop 40'tvd within 100' md. Not possible. Recalled town. Waiting on call back 19:45 - 20:30 0.75 DRILL P PROD2 WOO. Plan is to drill ahead drop 5' tvd looking for sand and then leveling off. If no sand re-evaluate situation. 20:30 - 21:00 0.50 DRILL P PROD2 Wiper back in. Clean.. 21:00 -00:00 3.00 DRILL P PROD2 Directional! drill ahead f/ 9014' (6342'tvd) 1.52/1.53 fs= 3500 mw= 2-300 ann= 3985 ecd= 12.12 wob= 2-3k 50-70'/hr dropping angle .Drilled to 9105' (6345'tvd) 10/4/2005 00:00 - 02:00 2.00 DRILL P PROD2 Continue directionally drill f/ 9105' 1.5/1.5 fs=3450 mw= 2-300 ecd= 12.1 wob=2k 30'/hr Drill to 9165'. 02:00 - 02:30 0.50 DRILL P PROD2 Wiper trip back to 8310'. Clean pu of bottom. 5k overpulls 8620'-8570'. Printed: 10/17/2005 7:36:41 AM • BP EXPLORATION Page 9 of 18 Operations Summary .Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 10/4/2005 02:30 - 03:00 0.50 DRILL P PROD2 Log tie-in +11' (missed on 1st try) 03:00 - 03:45 0.75 DRILL P PROD2 Wiper in hole. Setdown at 8430', 9088' then good to bottom. 03:45 - 06:00 2.25 DRILL P PROD2 Directionally drill ahead 1.50 t 1.50 fs= 3520 mw= 2-300 ecd= 12.3 wob= 2-3k. (Town group agrees we've crossed the major fault at+/- 8970' and arg now in the 'B' shale. Plan forward is to drop angle to 75-78deg. Will revise as 'B' sh markers are seen.) 06:00 - 08:50 2.83 DRILL P PROD2 See a marker at 9195' and slow down drop rate and move TF to 908 at 9240'. Drill 1.54/1.54/3580/908 w/ 200-400 psi dill, 2-4k wob at 12.3 ECD 78 deg at 6360' TVD Drill to 9300' PVT 302 08:50 - 09:35 0.75 DRILL P PROD2 Wiper to window. Sk overpulls and MW thru B Shale area and at 8990' (fault). Pulled tite and packed off at 8590'. Couldn't go down. Backream at reduced rate and cleaned up. Fin wiper to window, clean 09:35 - 10:45 1.17 DRILL P PROD2 Wiper in hole was clean thru build and OH sidetrack point 1.2/2800 w/ 200 psi by to hold 12:0 ECD. Set down at 8665' w/ TF 90 deg out. Orient around to repostion stops and to get DTF. RIH, clean until set down at 8990' w/ TF 100 deg out. 8950' is where TF changed from 90L to 908. Work thru this spot at DTF, then get to 9074' set down. Get to 9100' setdown and PUH sticky. Wiper back to 8960', clean. Wiper in hole clean to 9074' set down. Red rate to 0.9 bpm w/ 200 psi by and make a high speed run to 9150' 10:45 - 11:05 0.33 DRILL P PROD2 Sticky back to 9100'. PUH to 9050'. Make a high speed run to 9210', then PUH sticky to 9160'. RIH to 9180' and can't get by and getting real sticky 11:05 - 11:50 0.75 DRILL P PROD2 Wiper 1.5/3580 w/ 12.1 ECD back to OH sidetrack point w/ MW and overpulls at 9100', 9088', 9050'. Packed off at 8580' again. Wipe clean then PUH to 8540'. Wiper back in hole at 0.95/2550/DTF w/ 200 psi by was clean to set down at 9060' w! TF 90 deg off 11:50 - 12:25 0.58 DRILL P PROD2 RIH thru 9060' clean, then get to 9198', then to 9280'. Wiper back to 9210' was clean. Wiper back to TD PVT 289 12:25 - 15:40 3.25 DRILL P PROD2 Resume drilling from 9300' 1.52/1.52/3590/1708-160L wf 100-400 psi dill, 2-5k wob w/ 12.3 ECD at 78 deg. Good A6 marker seen at 9358'. Plan to land in A4 pay at +1- 9600'md 6329'tvd. Drilled to 9400'. 15:40 - 16:55 1.25 DRILL P PROD2 Wiper trip to window and tie-in point. PU off btm 18.2k 1.59 bpm 12.1ecd Overpulls and MW at 9300', 9253', 9126'-9110', 9044' 'mtr stall, then clean through A4 area pulling at 26'/min 1.6/3680 up to 8615 then slowed to 6'/min mw at 8600' pulling 22-26k 2-400psi mw 8600'-8570' pulling fairiy clean 2k over but high mw (belly of well) 1.55/0.80 12.Oecd full returns back at 8544' clean to 8440'. Pull through B sh again with 2-4k over and 300 mw. Clean to window. PVT 278 16:55 - 17:05 0.17 DRILL P PROD2 Log tie-in +10' 17:05 - 18:50 1.75 DRILL P PROD2 Wiper trip at reduced pump rate .9 holding 280psi on well. Had to ream back to bottom the last 100'. Pickups slightly heavy at full pump rate. Able to get back to bottom finally at 0.6 bpm and 300 psi WHP. 18:50 - 19:00 0.17 DRILL P PROD2 Tag bottom and resume drilling. 19:00 - 19:50 0.83 DRILL P PROD2 Took 2 bbl kick. Held back pressure at surface to circulate kick Printed: 10/17/2005 7:36:41 AM BF' `EXPLORATION Page 10 of 18 Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 16-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To 'Hours Task Code NPT Phase Description of Operations 10/4/2005 19:00 - 19:50 0.83 DRILL P PROD2 OOH. Had crude and gas cut mud. Picked up slowly. Density fell off to 6.6 ppg. Held 550 psi to keep returns 1 for 1. Circul8led until we got out denisty equal to in density. 19:50 - 20:40 0.83 DRILL P PROD2 Resume drilling. 1.44/1.45/4200 psi. PVT=275 bbls. Pickup weight is 17 klbs. Free spin is 4070 psi at 1.44 bpm. WHP=550 psi. BHP=4720 psi. ECD=14.5 ppg. IAP=390 psi, OAP=348 psi. 20:40 - 00:00 3.33 DRILL P PROD2 Continue drilling ahead with slow ROP. Begin swap to new mud. Pumping 8.9 ppg mud with 14 Ib Klagard. 10/5/2005 00:00 - 02:30 2.50 DRILL P PROD2 Continue drilling ahead with very slow ROP. Geo reports we are in Anchorite, and have another 2' TVD to nibble our way thru at 77 degs INC. Now holding 750 Ibs on the surface choke to keep 1 for 1 returns. Any less WHP than that and the well wants to flow. Drilling at 1.5/1.5/3940 psi, with new mud all the way around. WHP = 750 psi. BHP=4590 psi, ECD=13.82 ppg. A noticable decrease in BHP since we swapped to new mud. 02:30 - 03:30 1.00 DRILL P PROD2 Broke thru the Anchorite. ROP now 80 fph. 03:30 -04:20 0.83 DRILL P PROD2 Wiper trip to the window. Clean PU off bottom at 18 klbs. One overpull at 9180'. Ratty from 9090' to 9040' with motor work and heavy overpulls. Ratty from 8990'-8950. Overpulls 8580'-8530'. 04:20 - 05:15 0.92 DRILL P PROD2 Continue back in the hole on the wiper trip. Maintaining 4530 psi BHP. Pumping at a reduced pump rate of 0.9 bpm. No problems running back to bottom! 05:15 - 07:35 2.33 DRILL P PROD2 Resume drilling lateral section. 1.50 / 1.50 8.9/8.9 3765 2-300mw 765whp 4630ann 13.91 ecd 2-3kwob 40-60'/hr 07:35 - 09:35 2.00 DRILL P PROD2 Wiper trip. PU off btm 19k. Essentially seen the same areas of overpulls and mw as prior wiper trip coming out. RIH with reduced pump rates and higher choke pressures and also maintaining TF's as drilled. Lost 10bbls mud during wiper trip. PVT 370 09:35 - 11:45 2.17 DRILL P PROD2 Directionally drill ahead f/9690'. 1.50/1.65 8.89!8.73 3780fs(pressure balance shows 8.9) holding 824psi WHP " 4590ann 13.78ecd. These annular pressures are lower than before the wiper trip suggesting cuttings build-up in the belly area of well. Will limit future wiper trips intervals to 100'-130' range. 2-3k wob 50-60'lhr 2-300psi mw ROP slowed at 9725' coming up into predicted shale then into Ankorite. 11:45 - 17:15 5.50 DRILL P PROD2 Drilling Ankorite 1.5/1.6 3750fs 100mw 2-3kwob 4'/hr 4572ann 13.72ecd 820whp 17:15 - 18:00 0.75 DRILL P PROD2 Still drilling Ankorite at 9793' 18:00 - 21:00 3.00 DRILL P PROD2 Still drilling Anchorite with slow ROP of about 4 fph. 1.5/1.48!3950 psi. 800 psi WHP. PVT=340 bbls. IAP=498 psi, OAP=438 psi. Pumping 1, 10 bbl sweep of 100 klsrv high vis mud per hour to assist in hole cleaning. 21:00 -00:00 3.00 DRILL P PROD2 ROP now up to 14 fph. PVT=333 bbls. 10/6/2005 00:00 - 01:05 1.08 DRILL P PROD2 Continue drilling Anchorite with slow ROP. 01:05 - 02:05 1.00 DRILL P PROD2 Wiper trip to window. Clean PU off bottom. Pumped a high vis sweep to exit bit as we went thru belly of well. slight overpulls with motor work in the same places as previous runs, but much better than yesterday. No significant motor work or overpulls. 02:05 - 02:40 0.58 DRILL P PROD2 Log tie in pass over RA tag. Make +17' correction. Printed: 11N17/2005 7:36:41 AM BP EXPLORATION ' Page 11 of 1s Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date. From - To Hours Task Code NPT Phase Description of Operations 10/6/2005 02:40 - 03:25 0.75 DRILL P PROD2 Continue back in the hole on a wiper trip. Using reduced pump rate of 0.75 bpm while RIH. No problems with motor work or set downs while running back in hole. 03:25 - 06:00 2.58 DRILL P PROD2 Free spin 4130 psi at 1.5 bpm. Tag bottom. Resume drilling Anchorite at 10 fph. 06:00 - 08:30 2.50 DRILL P PROD2 Drilling ahead in Ankorite. 4'/hr 3-4k wob 1.5/1.5 8.9/8.9 3900fs 100mw 4664ann 14.Oecd 08:30 - 11:15 2.75 DRILL P PROD2 TOH for BOP test, BHA inspection, new bit and following revised pressure schedule. (Notified AOGCC of pending test. Rep John Spaulding questioned our not giving 24hr notice. Explained situation with drilling Ankorite and well plans beyond and, it was in our best interest to trip how rather than scheduled test tomorrow. John waived the wittnessing of test.)Trapped 1480psi on well prior to shut-in of TRSSSV. I (PJSM before reaching surface re: I/d of BHA and prep for BOP test) Checked torque on all BHi connections on catwalk. 11:15 - 16:30 5.25 I BOPSU P PROD2 Test BOP's 250psi low / 4000psi high (2500psi annular). Draw down test accumulator. 16:30 - 17:00 0.50 DRILL P PROD2 Service injector. 17:00 - 18:00 1.00 DRILL P PROD2 PU BHA #16 18:00 - 19:50 1.83 DRILL P PROD2 RIH with BHA #16. Using Hughes bicenter bit with "Z" cutters. Opened SSSV and found 1380psi beneath it. (SI w/1480psi) Followed revised pressure schedule. 19:50 - 20:10 0.33 DRILL P PROD2 Log tie in pass over RA tag. Make -14' correction. 20:10 - 20:45 0.58 DRILL P PROD2 RIH in open hole. Pumping at 0.9 bpm. 1100 Ibs on choke. BHP=4690 psi. ECd=14.26 ppg. PVT=256 bbls. Getting crude and gas back in returns. Run retums thru gas buster. Will need to do a mud swap once on bottom. Probably got crossflow from high pressure zone at toe of well to lower pressured zone near heel. 20:45 - 21:40 0.92 DRILL N DFAL PROD2 BHI equipment no longer working. They suspect an electrical short in the surface wiring. PUH to the window. Defer mud swap until we get this sorted out. 21:40 - 22:00 0.33 DRILL N DFAL PROD2 Stop above window. Lock reel brake. Set pins in drum. Energize warning lights. Hold pre task safety meeting. Enter reel and troubleshoot BHI wiring. 22:00 - 23:30 1.50 DRILL N DFAL PROD2 BHI determined that the problem is not on surface, it is downhole, possibly in the ecoil. POOH to trouble shoot downhole problem. 23:30 -00:00 0.50 DRILL N DFAL PROD2 Tag up at surface. Hold PJSM. Stand back injector, and troubleshoot BHA. 10/7/2005 00:00 -00:45 0.75 DRILL N DFAL PROD2 Lay down BHA #16. Trouble shoot MWD. Found bad upper quick connect. Change same. Pick up BHA #17. Same motor and bit. Using Hughes bit with "Z" cutters. 00:45 - 02:20 1.58 DRILL N DFAL PROD2 RIH with BHA #17, following pressure schedule. 02:20 - 02:40 0.33 DRILL N DFAL PROD2 Log a tie in pass over the RA tag in the WS. Make -13' correction. 02:40 -03:00 0.33 DRILL N DFAL PROD2 Continue RIH to resume drilling. Pumping 0.75 bpm while RIH and holding 1100 psi on WHP. No problems in open hole. 03:00 - 03:30 0.50 DRILL P PROD2 Continue RIH. 03:30 -04:00 0.50 DRILL P PROD2 Bring pumps up to full rate. Free spin is 4140 psi at 1.4 bpm. Printed: 10/17/2005 7:36:41 AM BP-EXPLORAT{ON Page 12 of 18 Operations Summary Report. Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15!2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/7/2005 03:30 -04:00 0.50 DRILL P PROD2 Holding 800 psi on WHP. Tag bottom at 9879'. Begin drilling at 1.44/1.46/4300 psi. ROP=20 fph. Getting crude and gas back p returns. Run returns thru gas buster. 04:00 - 05:30 1.50 DRILL P PROD2 Begin pumping new mud for mud swap. Continue drilling in Ankorite with slow ROP. Broke through Ankorite a t 9897'. 05:30 - 16:05 10.58 DRILL P PROD2 Drilling ahead f/ 9897'. Drilled +/- 20'md of sand then into shale. Turned down looking for sand again. Haven't seen it yet. 3-4k wob 10'lhr avg 1.46/1.46 4015fs 170mw 4635ann 13.9ecd. Pumped 10bb1 sweeps/2hrs. Lost +/-5 bbls/hr mud to formation. 16:05 - 18:05 2.00 DRILL P PROD2 Wiper trip clean p/u 17k. Overpulls 5-10k 9326, 9220, 9180, 9080-40,9004-8970, 18:05 - 18:50 0.75 DRILL P PROD2 Resume drilling. Having trouble getting weight to bit now. String wt = -8000 lbs. DHWOB = 2001bs. Ask mud man to add an additional 1.5% of EMI-776 to system. System currently has 4% of lubetex, no EMI-776. Free spin 4000 psi at 1.4 bpm. Drilling at 1.37/1.35/4200 psi. PVT=323 bbls. IAP=230 psi., OAP=212 psi. BHP=4933 psi. ECD=14.3 ppg. Pump high vis sweeps 1 per hour. 18:50 - 19:05 0.25 DRILL P PROD2 Not getting weight to bottom. Make a BHA wiper. Heavy pickup off bottom with motor work. PUH slow for 100'. 19:05 - 20:00 0.92 DRILL P PROD2 Back on bottom. W06=12001bs. String wt = -7000 lbs. WOB immediately drills off, then we can't make additional hole. Make multiple pickups, and we get the same situation. We pick up off bottom, tag bottom and get WOB and motor work, then it quickly drills off, and we cant make additional hole. Pickups are clean. Not differential sticking. 20:00 - 21:10 1.17 DRILL P PROD2 Call town, discuss situation. Also discuss with slope Geo. Able to get weight to bit finally. DHWOB=1500 lbs. String wt = -90001bs. Not making any ROP. Continue trying to drill while waiting on orders. 21:10 - 20:00 22.83 DRILL P PROD2 Discuss with town. POOH to pick up sidetrack bit. Clean PU off bottom. Slight motor work and overpulls at the usual places in open hole. 20:00 - 23:30 3.50 DRILL P PROD2 POH in cased hole with EDC open and pumping at 1.5 bpm. Following choke schedule while POH. 23:30 - 00:00 0.50 DRILL P PROD2 Tag up at surface. Stand back injector. Lay down BHA #17. Bit was packed off with clay. Problem downhole could have been swelling shale preventing us from getting good weight transfer. Bit recovered graded 1,1. 10/8/2005 00:00 - 00:30 0.50 STKOH P PROD2 Pick up R60 sidetrack bit with brass cap and 1.7 deg motor. 00:30 - 02:00 1.50 STKOH P PROD2 RIH with BHA #18 to sidetrack hole. 02:00 - 02:10 0.17 STKOH P PROD2 Log tie in pass over RA tag in whipstock. Make -14' correction. 02:10 -03:00 0.83 STKOH P PROD2 Shut EDC, RIH. Pumping 0.3 bpm ihru the motor. A few bounces while RIH, but no set downs or significant motor work. 03:00 - 05:00 2.00 STKOH P PROD2 RIH to 9750', Kick on pumps to full rate. Free spin = 1.38 bpm, 3900 psi. PUH to sidetrack depth. Trough 2 times from 9650'-9665'. WOB on first time down was 2001bs. Motor work was 100 lbs. WOB on 2nd time down was 0 lbs. Motor work was 200 lbs. 05:00 -06:00 1.00 STKOH P PROD2 Begin time milling from bottom of trough at 9665' to 9685'. Applied more WOB drill ahead to 9705'. Doesn't appear to be Printed: 10/17/2lK)5 7:36:41 AM $P EXPLORATION Page 13 of'ts Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From = To Hours Task Code NPT Phase Description of Operations 10/8/2005 05:00 -06:00 1.00 STKOH P PROD2 sidetracked. 06:00 - 07:00 1.00 STKOH P PROD2 Start time drilling again. No motor work. Thinking brass cap is I still in place. RIH to 10033' try drilling ahead. No progress. Could be too soft here. Pull back to 9900. 07:00 - 08:15 1.25 STKOH P PROD2 Backream Ankorite from 9890 to 9750 with opposite drilled TF's. If brass cap is still on this should wear it off. 08:15 - 12:00 3.75 STKOH P PROD2 From 9650' trough 3 times to 9665'. 12:00 - 18:00 6.00 STKOH P PROD2 Stay parked at 9665' for 30min then begin time drilling from bottom of trough. Initially doing good for first foot then start having weight transfer problems. (mud system is at max lubricants). Switch tatics and PU to get weight back after 6min 'i ~ and then RIH back to last depth plus 0.1' seeing slight motor ', ~ wrok. ', ~ 18:00 - 18:30 I 0.50 STKOH P PROD2 Continue drilling at 0.1'/6 minutes. Not seeing motor work. '~ ~ 18:30 - 18:50 ~ 0.33 STKOH P PROD2 9666.0'. Saw 300 Ibs wt on bit at this tenth that drilled off. I i j Good sign. Begin drilling at 0.1'/1 minute. Getting WOB with I ~ drill off on each tenth. Time drilling at 1.46/1.44/4170 psi. ~ j ~ Getting more WOB as we make hole. Starting to get motor ~ ~ i work. ~ 18:50 - 1.9:05 i 0.25 STKOH P ~ PROD2 Start drilling at a constant 6 fph. Seeing 550 Ibs WOB and 100 i ~ Ibs motor work. Consistent with good sidetrack. 19:05 - 20:30 1.42 STKOH P PROD2 Begin pushing on it a little. Drilling at 15 fph. WOB=650 Ibs. Motor work = 50-100 Ibs. 20:30 - 22:35 2.08 STKOH P PROD2 Confirmed sidetrack on INC. Good weight on bit and motor work to new TD of 9721'. Begin backreaming at 90 UR to open up sidetrack. Make a total of 2 passes on each side. 22:35 - 23:30 0.92 STKOH P PROD2 POH to pick up lateral assembly. Pump high vis sweep to exit the bit as we pull thru the heel of the well. Hole was ratty in the usual places with motor work and overpulls. '~ 23:30 -00:00 0.50 STKOH P PROD2 Stop below window, open EDC, POOH pumping at full rate thru an open EDC. 110/9/2005 00:00 - 01:00 1.00 STKOH P PROD2 Continue to POH with sidetrack BHA. 01:00 - 02:00 1.00 STKOH P PROD2 Tag up at surface. Hold PJSM to discuss BHA swap. Lay down BHA #18. Change bits and motor. Pick up same Hughes bicenter with 'Z" cutters as run on BHA #17. Adjust motor AKO to 1.1 deg. 02:00 - 03:25 1.42 DRILL P PROD2 RIH with BHA #19 to resume drilling L2 lateral section from 9721'. 1230 psi below SSSV when opened. 03:25 - 03:40 0.25 DRILL P PROD2 Log tie in pass over RA tag. Make -13' correction. 03:40 -04:35 0.92 DRILL P PROD2 Open EDC. Run to bottom to resume drilling. RIH at reduced pump rate of 0.75 bpm. RIH slick down to 8980', set down. PU, and made it to 9004', PU made it to bottom ok. 04:35 -04:50 0.25 DRILL P PROD2 Log MAD pass for missing data in sidetrack interval. 04:50 -06:00 1.1.7 DRILL P PROD2 Resume drilling L2 lateral section as per Geo plan. 1.38/1.30/4182 psi. PVT=394 bbls. IAP=190 psi, OAP=205 ', psi. BHP=4835 psi. ECD=14.51 ppg. WHP=800 psi. ROP = I 60-90 fph. ~i 06:00 - 12:00 6.00 DRILL P PROD2 Climbing back into shale section looking for thin sand below Ankorite. Slow drilling f/ 9754' to 9778'. Hit sand at 9778'md (92.7deg NBI) Drilling ahead 1-2k wob 60'-80'/hr. 1.4/1.4 4065fs 4800ann 780whp 14.4ecd 100-200psi mw coil wt 4k. Turning down to level-off. Drilled good sand to 9855'. Then Printed: 10/17!2005 7:36:41 AM '-$P EXPLORATION Page 14 of 18 Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From = To Hours. Task Code NPT Phase Description of Operations 10/9/2005 06:00 - 12:00 6.00 DRILL P PROD2 back into slow drilling Ankorite/Shale? Continue drilling ahead with low TF. Broke out into sand at 9864'. 12:00 - 14:10 2.17 DRILL P PROD2 Wiper,trip to window. Clean p/u 15.5k tight coming through 9040-80' minor overpulls as in prior wiper trips. 14:10 - 15:50 1.67 DRILL P PROD2 Continue drilling ahead f/ 9870' to 9908' 6427'tvd. Same parameters. In/out of shales/sand. 15:50 - 18:00 2.17 DRILL P PROD2 Contine drilling dive down to target TVD of 6433' in A4 sand 18:00 - 18:30 0.50 DRILL P PROD2 Now drilling back up again at Geo's direction with slow ROP. Drilling at 1.37/1.32/4120 psi. ROP=10 fph. IAP=480 psi, OAP=405 psi. BHP=4820 psi. ECD=14.46 ppg. Ask Geo to catch a sample to confirm we are not in Ankorite. He indicates we are drilling shale. 18:30 - 19:15 0.75 DRILL P PROD2 Now drilling back down as per Geo's direction. ROP 5-10 fph. Make pickup to check free spin. FS = 3990 psi at 1.35 bpm. Tag bottom, continue chewing away at it. 19:15 - 21:20 2.08 DRILL P PROD2 Geo needs time to sort out situation. Make wiper trip while he discusses with town. Clean PU off bottom. Had motor work and overpulls at a half dozen spots in the shales as we pulled up hole. No worse, but no better than we have seen so far on this lateral. Need to get this hole TD'd pretty quick and get liner run lest they get worse. Run back to bottom, Had to work it past 9050'. Got to TD finally. 21:20 - 00:00 2.67 DRILL P PROD2 Tag bottom and resume drilling. The current plan is to drill up to get into a better sand. Geo reports we are currently drilling shale. ROP is certainly very slow and more reminisant of the ROP we had in Ankorite. Ask Geo to catch another sample. He confirms it is shale and not Ankorite. Continue drilling with very slow ROP. Trying to build up out of it as per Geo's directions. 10/10/2005 00:00 - Oi:05 1.08 DRILL P PROD2 Continue drilling. 1.37/1.39/4300 psi. WOP=3200 lbs. BHP=4800 psi. ECD=14.4 ppg. IAP=500 psi, OAP=430 psi. PVT=340 bbls. ROP is very slow. About the same as the last time we drilled Ankorite. If it quacks like a duck... 01:05 - 02:05 1.00 DRILL P PROD2 Geo needs to sort out a plan forward. Make a wiper trip to the window to give him time to discuss with town. Clean PU off bottom. Ratty with motor work and overpulls in half a dozen places. Not getting any better. Probably generatiing some shale cuttings and washing out shales each time we make a wiper. 02:05 - 02:25 0.33 DRILL P PROD2 Log tie in pass over RA tag in whipstock. Make +19' correction. 02:25 - 03:30 1.08 DRILL P PROD2 Continue wiper trip back in the hole. Pumping at a reduced rate of 0.75 bpm. Discuss plan forward with Geo. Latest interpretation of data is that we are in the Ankorite, and need to drill down to get out of it. Yikes! 03:30 - 06:00 2.50 DRILL P PROD2 Tag TD. Resume drilling. Tool Face oriented lowside. Drilling down at Geo's instructions. Drilling at 1.39/1.39/4400 psi. PVT=326 bbls. IAP=342 psi, OAP=322 psi. BHP=4872 psi. ECD=14.6 ppg. WHP=800 psi. 06:00 - 17:00- 11.00 DRILL P PROD2 Continue drilling ahead f/ 10008' 1.33/1.33 4050fs 200mw 780whp 14.6ecd 3k wob 5-6'/hr with 2'-3' spurts of faster drilling. Drilling Ankorite .Maintaining 87-85 deg inc all day Making BHA wipers every 1/2hr. Thinning mud down with 10bb1 Printed: 10/17/2005 7:36:41 AM BP EXPLORATION - Page 15 of 1'8'' Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/10/2005 06:00 - 17:00 11.00 DRILL P PROD2 additons of 8.9 brine mixed throughly in system. Drilled to 10095' 17:00 - 18:00 1.00 DRILL P PROD2 Drill ahead f/ 10095' Geo's saying we hsould break into A4 soon. 1.44/1.44 4100fs 100-150mw 760whp 14.37ecd 3-3.5k wob 4-8'/hr 18:00 - 18:45 0.75 DRILL P PROD2 Continuing to drill ahead in Ankorite. Drilling at 1.42/1.47/4140 psi. ROP=10 tph. IAP=580 psi, OAP=490 psi. BHP=4800 psi, ECD=14.4 ppg. WHP=780 psi. 18:45 - 19:40 0.92 DRILL P PROD2 ROP is down to 3 fph. Probably due to the Ankorite, but we j ~ were able to drill at closer to 10 fph when we first entered this zone. We have 24 hours on this bit in Ankorite. POOH to ~ change bits. Currently in the hole with a Hughes bicenter with ~ I "Z" cutters. Clean PU off bottom. Pump sweep to exit bit as ~ we pull thru the heel of the well. Hole condition in good shape ~ j ~ ~ only a few overpulls in the usual areas. Had one spot of motor ~ work at 8530', which is new. ~ 19:40 - 20:55 1.25 DRILL P PROD2 Open the EDC. Pull thru the window. POH, pumping at full rate and following the pressure schedule. ~ 20:55 - 21:10 0.25 DRILL P PROD2 PJSM to discuss BHA swap while POH. 21:10 - 22:00 ~ 0.83 DRILL P I PROD2 Tag up at surface. Close SSSV. Flow check ok. Stand back injector. Break out bit. Graded 2,3 with 1 broken cutter on the center of the pilot and 1 additional broken cutter on the wing section. The overall sharpness of the remaining cutters was excellent. They were not dulled in any obvious way, and did ~ much better than expected from the hard Ankorite that we have drilled for the past 24 hours. The bit was very balled up with clay. 22:00 - 22:35 0.58 DRILL P PROD2 Pick up BHA #20. We are running a Hycalog DS100 with Trex cutters. The rest of the BHA is identical to the last run. 22:35 -00:00 1.42 DRILL P PROD2 RIH with BHA #20. 10/11/2005 00:00 -00:20 0.33 DRILL P PROD2 Log tie in pass over RA tag in whipstock. Make -14' correction. 00:20 - 01:25 1.08 DRILL P PROD2 RIH in open hole.. Pumping minimum rate while RIH. Set down at 9050', worked thru. Continue to bottom. 01:25 - 06:00 4.58 DRILL P PROD~2 Kick on pumps. Free spin is 4050 psi at 1.36 bpm. Tag bottom, and start drilling. 1.43/1.45/4250 psi. WHP=800 psi. IAP=236 psi, OAP=248 psi. PVT=392 bbls. ECD=14.51 ppg. BHP=4840 psi. ROP=5-10 fph. About the same as before. 06:00 - 08:45 2.75 DRILL P PROD2 Continue drilling Ankorite f/ 10103' to 10145' increased rete to 1.53 in this section. No help. Did have a drilling break at 10145'. 08:45 - 11:00 2.25 DRILL P PROD2 Drilling ahead f/ 10145'. Drlg small amount of shale then dropped into sand. 1.5211.52 4150fs 2-300 mw 750whp 4800ann 2-3k wob 40-50'/hr +1500-2000# coil wt. while drilling pit vol at 0845 401 bbls. Still drilling good at 10210' 11:00 - 13:30 2.50 DRILL P PROD2 Wiper trip to window. PU off btm 16.7k No problems on wiper trip in or out. 13:30 - 14:00 0.50 DRILL P PROD2 Contintue drilling ahead f/ 10260' 1.52/1.52 4100fs 2-300mw 765whp 4846ann 2-3k wob 40'/hr good wt transfer 2-3k coil wt. Pit vol after wiper trip 394bb1s 14:00 - 19:00 5.00 DRILL P PROD2 Continue drilling ahead. 1.5/1.52/4400 psi. PVT=386 bbls. IAP=540 psi, OAP=440 psi. WHP=765 psi. BHP=4870 psi. ECD=14.56 ppg. INC=88 deg. ROP=40 fph. 19:00 - 21:30 2.50 DRILL P PROD2 Wiper trip to window. Hole mostly smooth. PVT: 370 bbls. Printed: 10/17/2005 7:36:41 AM BP EXPLORATION Page 16 of 18 ..Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/11/2005 21:30 - 00:00 2.50 DRILL P PROD2 Drill ahead from 10,405'. 4000 psi fs ~ 1.32 iN1.36 out. 100-200 DSPI. DHWOB: 1.5 - 2.5k#. WHP/BHP/ECD: 820/490/14.65 ppg. IA/OA/PVT: 475/405/361 bbls. I NC/AZM/TF: 87.2/134.9/1108. 10/12/2005 00:00 - 01:30 1.50 DRILL P PROD2 Drill ahead from 10493'. Pump high vis sweeps every 100 bbls pumped to help hole cleaning. ROP: 20-40 fph. PVT: 355 bbls. 01:30 -04:15 2.75 DRILL P PROD2 Wiper trip to window. Hole mostly smooth. Motor work in a few spots. PVT: 340 bbls. 04:15 - 06:00 1.75 DRILL P PROD2 Drill ahead from 10553'. 4300 psi fs ~ 1.44 in/1.38 out. DHWOB: 1.5-2.4k#. PVT: 336 bbls ~ 06:00 - 09:20 I 3.33 DRILL P PROD2 Slow drilling. 1.3511.4/4200 psi. DHWOB=600 lbs. String wt = -80001bs. Having to snub to get any WOB. Need new mud. Call for mud swap. IAP=520 psi, OAP=430 psi. BHP=4920 psi. WHP=750 psi. PVT=330 bbls. Finally able to get it to ~ drill by making a BHA wiper, then picking up and ramming bottom with pumps down, then bringing up pumps. Definately need to do a mud swap. Continuing to pump 1 10 bbl sweep of high vis mud per hour, and on wiper trips. 09:20 - 10:15 0.92 DRILL P PROD2 Begin pumping new mud downhole. Note, that this mud has 4% lubetex, but no EMI-776. Once we get mud back to surface, we will add the EMI-776 to bring it up to 1.5%. 10:15 - 12:45 2.50 DRILL P PROD2 Wiper trip to the window. Clean PU off bottom. Free spin 500 psi lower with new mud. Wiper trip to window. A few hickups on the trip up, nothing significant. Better than it was a few days ago. 12:45 - 13:30 0.75 DRILL P PROD2 Resume drilling. Free spin 3860 psi at 1.4 bpm. Drilling at 46 fph. Drilling at 1.42/1.4813940 psi. PVT=415 bbls of new mud. IAP=270 psi, OAP=230 psi. BHP=4650 psi. WHP=750 psi. Much better ability to slide with new mud in the hole. String wt _ -800 Ibs, DHWOB=2000 lbs. 13:30 - 14:40 1.17 DRILL P PROD°2 BHI orienter getting a bit weak. Having to pick up off bottom to orient now. 14:40 - 17:30 2.83 DRILL C PROD2 We have achieved the program TD. The asset would like to extend the well and get additional footage. MOC for the additional footage has been completed. Continue drilling as per the Geo. 17:30 - 20:30 3.00 DRILL C PROD2 Wiper trip to the window. Clean PU off bottom. Smatl amount of motor work in a few areas. Overall hole condition is very good. 20:30 -00:00 3.50 DRILL C PROD2 Drill ahead from 10,860'. 3910 psi fs ~ 1.41 iN1.42 out. DPSI:100-200. DHW06:1.4-2.1k#. WHP/BHP/ECD: 78014710/14.25 ppg. IA/OA/PVT: 349/286/402 bbls. ROP: 40-60 fph. Weight transfer is good. 10/13/2005 00:00 - 02:15 2.25 DRILL C PROD2 Hit hard spot. Perform wiper trip to get a btms up sample and to discuss with twon. Appear to have crosed a small fault and entered a zone containing ankorite. Log gr tie in at window. Add 16' correction. Run in hole. Smooth. 02:15 - 06:00 3.75 DRILL C PROD2 Drill ahead from 10,957. 3950 psi fs ~ 1.45 iN1.44 out. DHWOB: 2.3k#. TF straight down to try and drill out of hard Printed: 10/17/2005 7:36:41 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 B-15A Common Well Name: 1 B-15A Event Name: DRILL+COMPLETE Start: 9/22/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT ~ Phase 10/13/2005 02:15 - 06:00 3.75 DRILL C 06:00 - 08:10 2.17 DRILL C 08:10 - 09:50 I 1.671 DRILL I C 09:50 - 10:05 0.251 DRILL ~ C 10:05 - 12:00 1.921 DRILL i C 12:00 - 15:00 I 3.001 DRILL I C 15:00 - 15:15 ~ 0.251 DRILL ~ C 15:15 - 15:50 I 0.581 DRILL I C 15:50- 16:45 0.92 BOPSUI~C 16:45 - 17:05 0.33 CASE I P 17:05 - 19:45 2.67 CASE P 19:45 - 21:45 2.00 CASE P 21:45 - 22:30 I 0.751 CASE I P 22:30 - 00:00 I 1.501 CASE I P ~ 10/14/2005 100:00 - 00:45 I 0.751 CASE I P 'Page 17 of 18 Spud Date: 9/5/2005 End: 10/15/2005 Description of Operations PROD2 streak. PVT: 388 bbls. PROD2 Continued slow drilling in Ankorite. 1.46/1.46/4100 psi. W08~2100 lbs. String wt = -5000 lbs. IAP=520 psi, OAP=430 psi. PVT=384 bbls. BHP=4730 psi. ECD=14.16 ppg. PROD2 Discuss with town slow drilliing in Ankorite. The decision has been made to call this TD. Make wiper trip for final tie in. Clean PU off bottom at 18500 lbs. Call for vac truck to shuttle 80 bbls of new mud from uprights to pits for liner running pill. The trip up was very smooth. Minor overpulls, but no motor work at 10553', 9350'.. Hole is in much better shape than a few days ago. PROD2 Log tie in pass down over RA tag. Make +6' correction. PROD2 RIH pumping at minimum rate to get final TD tag. Smooth back to bottom. Pump 80 bbls of new mud with 4% Lubetex, 1.5% EMI-776 and 3#/bbl of course Alpine glass beads. PROD2 Tag bottom at 10992'. Pull off bottom laying in liner pill. Clean PU off bottom at 19 klbs. Clean in open hole. Paint EOP flags at 9500', 7000'. POH in tubing with EDC open and pumping at 1.7 bpm. PROD2 PJSM Re: Flow check, Laying down drilling BHA, BOP function test, and BHI BHA for next run. PROD2 Flow check welt. No flow observed. Stand back injector. Lay down BHA #20, last drilling BHA. Bit recovered and graded 1,1. PROD2 Weekly function test of BOP rams. All passed ok. RUNPRD PJSM Re: Running Liner. Discuss overhead loads, pinch points, MU torque, hazards and mitigations to hazards. RUNPRD Liner will be run in 2 sections due to depth of SSSV. Make up section #1. BHA consists of; BTT Deployment Slv 38 Jts of 2-3/8", 4.6#, L-80, Slotted STL tubing BTT O-Ring Sub. 1 Jt of 2-3/8", 4.6#, L-80, Solid STL tubing Unique Bias Edge Guide Shoe. Overall liner length is 1240.56' Stab coil. Test mwd. Get on well. Pressure up WHP to 1450 psi. Open SSSV. RUNPRD Run in hole with liner assembly. Offset at 7000' EOP flag (-23'). Made no correction. 16.5k# up wt, 8.3k# do wt. Through window ok. Continue to RIH at 50 fpm. Bounced through a spot at 9330'. RUNPRD Log gr tie in from 9530'. Subtract 13' correction. Continue to RIH. Bounced through another spot at 9675'. Stop with liner shoe at 10895'. 6.2k# coil down wt at setting depth. 20.4k# pick up. Circ at 1.2 bpm ~ 4200 psi to release from GS. Coil up wt 17.5k#. Keep 1000 psi WHP. Bottom of liner section #1 =10895.56 Top of liner section #1 = 9655'. RUNPRD Pull out of hole with liner running BHA. Circulate out of hole with 1000 psi on well head. RUNPRD ~ Continue to pull out of hole with liner setting BHA. Close sssv Printed: 10/t 7/2005 7:36:47 AM BP EXPLORATION Operations Summary Report. Page 18 of 18 ~ Legal Welt Name: 1 B-15A Common Well Name: 1B-15A Spud Date: 9/5/2005 Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/14/2005 00:00 - 00:45 0.75 CASE P RUNPRD with 1600 psi tubing pressure. PuA to surface. Flow check well. 00:45 - 01:00 0.25 CASE P RUNPRD Hold FJSM to discuss getting off well. Continue to flow check. Well stable. 01:00 - 01:45 0.75 CASE P RUNPRD Get off well. Unstab coil. Blow down tools. Remove and inspect GS spear. Test mwd tools. 01:45 -04:00 2.25 CASE P RUNPRD -Make up section #2, 44 jts of 2-3/8", 4.6#, L80, STL total. Deployment sleeve, 6 solid, 16 slotted, 13 solid, 8 slotted, o-ring sub, 1 solid, indexing guide shoe. Total length: 1396.36'. ~ MU mwd BHA tools with Baker GS spear. Stab coil. Get on well. 04:00 - 04:15 0.25 CASE P RUNPRD Pressure test lubricator and well to 1500 psi. Open sssv. 1450 ~ psitbg pressure. ~ 04:15 - 06:00 ( 1.75 CASE P RUNPRD Run in hole with liner assy #2. Maintain whp as per schedule. Wt check at window = 17 klbs. RIH thru the window slick. No ~ ! problems in open hole. ' 06:00 - 06:10 0.17 CASE P RUNPRD Wt check at 9630 =22 klbs. RIH at 6 klbs. Tag up on top of j liner #1 at 9655', right on depth. Pick up, and retag to confirm. Tagged up at 9656' on second tag. Confirmed at top of Liner section #1. 06:10 - 06:20 0.17 CASE P RUNPRD Shut EDC. Line up to pump down coil. Bring on pumps to t.35 bpm at 4300 psi. PU off liner. PU wt = 17 klbs. Released from liner. PU to tie in depth above window. 1 06:20 - 06:40 0.33 CASE P RUNPRD Log tie in pass down. Make 0 correction. We are on depth. ~ Retag top of liner. found liner on depth. Liner Section #2 Bottom at 9655' Top at 8258' 06:40 - 09:00 2.33 CASE P RUNPRD Circulate 2% KCL to the end of coif. POH swapping well to water. FP top 2000' of well with diesel. 09:00 - 10:00 1.00 CASE P RUNPRD Tag up at surface. Close SSSV. Flow check. No flow observed. Stand back injector, rig down Baker tools and BHI " BHA. 10:00 - 13:00 3.00 DEMOB P POST ND stack, NU tree cap. PT with diesel to 500 and 3500 psi. Clean pits. Prepare to move to move rig. Rig released at 13:00 Telex entries carried on 10-04 morning report. Printed: 10/17/2005 736:41 AM .~ ~ ., ~onoc Phillips ~aker Hughes INTEQ ~ •~ ~ Baker Hughes INTEQ Survey Report ~~-~~, Company: ConocoPhillips Alaska, Inc Date: 10!25/2005 Time:.- 09:50:00 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 15, True North Site: Pad 16 Vertical (TVD) Reference: Wellhead(95'} 95.0 Wells 15 Section (VS) Reference: Well (O.OON,O.OOE,150.OOAzi} ' Wellpath: 1 B-15AL2 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 B Site Position: Northing: 5970149.71 ft Latitude: 70 19 45.173 N From: Map Easting: 550434.96 ft Longitude: 149 35 27.418 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.39 deg Well: 15 Slot Name: Well Position: +N/-S -502.71 ft Northing: 5969643.84 ft Latitude: 70 19 40.229 N +E/-W -479.82 ft Easting : 549958.57 ft Longitude: 149 35 41.425 W Position Uncertainty: 0.00 ft Wellpath: 1 B-15AL2 Drilled From: 1 B-15AL2PB2 Tie-on Depth: 9658.67 ft Current Datum: Wellhead(95') Height 95.00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/10/2005 Declination: 24.14 deg Field Strength: 57614 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 150.00 Survey Program for Definitive Wellpath Date: 10/10/2005 Validated: No Version: 2 AMual From To Survey Toolcode Tool Name ft ft 463.34 4405.00 MWD<0 - 7450'> (470.34-7450.00) (0) MWD MWD -Standard 4430.86 8270.12 MWD (4430.86-8621.00) (1) MWD+IFR+MS MWD +IFR + Multi Station 8289.00 8500.99 MWD (8289.00-9056.00) (3) MWD MWD -Standard 8510.00 9658.67 MWD (8510.00-10033.00) (4) MWD MWD -Standard 9665.00 10992.00 MWD (9665.00-10992.00) MWD MWD -Standard Annotation MD TVD ft ft 9658.67 6525.06 TIP 9665.00 6524.83 KOP 10992.00 6533.68 TD Survey: MWD Start Date: 10/10/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ~~~ `~l Si '` Conoc Phillips aker Hughes INTEQ Baker Hughes INTEQ Survey Report ttv~rEQ ,Company::: ConocoPhillips Alaska, Inc Date: 10!25!2005 Time: 09:50:00 Page: . 2 .Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: iS True North . Site; Pad _16 Vertical (TVD) Reference: Wellhead(95'} 95.0 Well: 15 Section (VS) Reference: Well (O.OON,O.OOE,150.OQAzi} Wellpath: 1 B-15AL2 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inci Azim TVD SS TVD N!S E/W MapN MapE VS DLS Tool ft deg... deg ft ft ft ft ft ft ft deg/100ft ' 9658.67 91.95 113.57 6525.06 6430 .06 -2964.29 -1778.87 5966668. 05 548199.65 1677.72 0.00 MWD 9665.00 92.19 113.02 6524. 83 6429 .83 -2966.79 -1773.06 5966665. 59 548205.47 1682.79 9.47 MWD 9672.65 88.42 112.32 6524. 79 6429 .79 -2969.74 -1766.01 5966662. 69 548212.55 1688.87 50.12 MWD 9692.24 88.08 108.42 6525. 39 6430 .39 -2976.56 -1747.65 5966656. 00 548230.94 1703.95 19.97 MWD 9721.48 93.43 104.68 6525. 00 6430 .00 -2984.88 -1719.64 5966647. 86 548259.01 1725.16 22.32 MWD 9772.47 92.96 97.36 6522. 16 6427 .16 -2994.61 -1669.70 5966638. 47 548309.00 1758.55 14.36 MWD 9801.77 92.78 93.13 6520. 69 6425 .69 -2997.28 -1640.57 5966635. 99 548338.15 1775.44 14.43 MWD 9831.15 90.93 89.43 6519. 74 6424 .74 -2997.94 -1611.22 5966635. 53 548367.50 1790.68 14.07 MWD 9878.06 87.75 84.40 6520. 28 6425 .28 -2995.41 -1564.40 5966636. 36 548414.30 1811.90 12.68 MWD 9915.03 84.82 80.45 6522. 67 6427 .67 -2990.55 -1527.84 5966643. 47 548450.82 1825.97 13.28 MWD 9946.17 84.63 75.78 6525. 54 6430 .54 -2984.17 -1497.51 5966650. 05 548461.11 1835.61 14.95 MWD 9983.61 87.37 78.13 6528. 15 6433 .15 -2975.74 -1461.13 5966658. 72 548517.43 1846.50 9.63 MWD 10013.50 89.71 80.92 6528. 91 6433 .91 -2970.31 -1431.75 5966664. 35 548546.77 1856.49 12.18 MWD 10044.88 85.78 84.42 6530. 15 6435 .15 -2966.31 -1400.66 5966668. 55 548577.82 1868.57 16.76 MWD 10076.06 85.38 87.58 6532. 55 6437 .55 -2964.14 -1369.66 5966670. 93 548608.81 1882.19 10.19 MWD 10108.10 87.04 91.65 6534. 67 6439 .67 -2963.93 -1337.69 5966671. 36 548640.77 1897.99 13.69 MWD 10137.39 85.53 96.08 6536. 57 6441 .57 -2965.90 -1308.54 5966669. 58 548669.93 1914.27 15.95 MWD 10177.66 84.92 101.60 6539. 92 6444 .92 -2972.06 -1268.90 5966663. 68 548709.61 1939.43 13.74 MWD 10206.07 88.48 106.91 6541. 56 6446 .56 -2979.04 -1241.43 5966656. 88 548737.13 1959.21 22.47 MWD 10237.14 91.21 111.22 6541. 64 6446 .64 -2989.19 -1212.07 5966646. 93 548766.55 1982.68 16.42 MWD 10270.22 90.11 114.63 6541. 26 6446 .26 -3002.07 -1181.61 5966634. 26 548797.09 2009.06 10.83 MWD 10301.01 88.14 119.70 6541. 73 6446 .73 -3016.12 -1154.23 5966620. 39 548824.56 2034.92 17.66 MWD 10339.61 87.47 124.91 6543. 21 6448 .21 -3036.73 -1121.64 5966600. 00 548857.28 2069.06 13.60 MWD 10374.33 88.64 129.40 6544. 39 6449 .39 -3057.68 -1093.99 5966579. 24 548885.07 2101.03 13.36 MWD 10408.01 87.16 134.92 6545. 63 6450 .63 -3080.26 -1069.05 5966556. 83 548910.15 2133.06 16.96 MWD 10440.25 89.22 139.32 6546. 65 6451 .65 -3103.67 -1047.13 5966533. 37 548932.23 2164.46 15.06 MWD 10471.15 90.17 145.11 6546. 81 6451 .81 -3128.28 -1028.21 5966509. 09 548951.31 2195.06 18.99 MWD 10501.31 90.11 149.13 6546. 74 6451 .74 -3153.60 -1011.84 5966483. 88 548967.85 2225.18 13.33 MWD 10530.08 89.37 151.34 6546. 87 6451 .87 -3178.57 -997.56 5966459. 00 548982.29 2253.95 8.10 MWD 10560.01 91.49 153.55 6546. 64 6451 .64 -3205.10 -983.71 5966432. 57 548996.31 2283.84 10.23 MWD 10606.78 92.87 149.17 6544. 86 6449 .86 -3246.11 -961.32 5966391. 71 549018.98 2330.55 9.81 MWD 10652.01 89.74 144.31 6543. 83 6448 .83 -3283.91 -936.53 5966354. 09 549044.02 2375.68 12.78 MWD 10691.70 90.17 138.20 6543. 86 6448 .86 -3314.85 -911.70 5966323. 32 549069.05 2414.89 15.43 MWD 10723.85 90.45 134.97 6543. 69 6448 .69 -3338.20 -889.61 5966300. 11 549091.29 2446.16 10.08 MWD 10757.09 92.56 132.00 6542. 82 6447 .82 -3361.06 -865.50 5966277. 41 549115.55 2478.01 10.96 MWD 10789.46 94.16 129.76 6540. 92 6445 .92 -3382.21 -841.07 5966256. 43 549140.12 2508.54 8.49 MWD 10844.76 91.74 124.51 6538. 07 6443 .07 -3415.53 -797.06 5966223. 41 549184.34 2559.40 10.44 MWD 10871.02 90.11 121.88 6537. 65 6442 .65 -3429.90 -775.09 5966209. 18 549206.40 2582.84 11.78 MWD 10906.94 92.35 119.21 6536. 88 6441 .88 -3448.15 -744.17 5966191. 14 549237.45 2614.10 9.70 MWD 10943.10 92.10 116.22 6535. 47 6440 .47 -3464.95 -712.19 5966174. 55 549269.54 2644.64 8.29 MWD 10992.00 92.10 116.22 6533. 68 6438 .68 -3486.55 -668.35 5966153. 26 549313.51 2685.26 0.00 MWD Conoc Phillips ~aker Hughes INTEQ Baker Hughes INTEQ Survey Report ENTrc~ :'Company: ConocoPhllipsAlaska, Inc Date: 90/25/2005 Time: 3A:02:19 Page: 1 Field: Kuparuk River Unif Co-ordinate(NE) Reference: We11t 15, True North Site: Pad 1 B Vertical (TVD) Reference: Wellhead(95') 95.0' Well: 15 Section (VS) Reference: Well. (O.OON,O.OOE,150.OOAzi) Wellpath: 1 B-15AL2P61 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska ~ USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004 Site: Pad 1 B Site Position: Northing: 5970149.71 ft Latitude: 70 19 45.173 N From: Map Easting: 550434.96 ft Longitude: 149 35 27.418 W Position Uncertainty: 0.00. ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.39 deg Well: 15 Slot Name: Well Position: +N/-S -502.71 ft Northing: 5969643.84 ft Latitude: 70 19 40.229 N +E/-W -479.82 ft Easting : 549958.57 ft Longitude: 149 35 41.425 W Position Uncertainty: 0.00 ft Wellpath: 18-15AL2PB 1 Drilled From: 1 B-15A Tie-on Depth: 8289.00 ft Current Datum: Wellhead(95') Height 95.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/22/2005 Declination: 24.24 deg Field Strength: 57606 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 150.00 Survey Program for Definitive Wellpath Date: 10!2/2005 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 463.34 4405.00 MWD<0 - 7450'> (470.34-7450.00) (0) MWD MWD -Standard 4430.86 8270.12 MWD (4430.86-8621.00) (1) MWD+IFR+MS MWD +IFR + Multi Station 8289.00 9056.00 MWD (8289.00-9056.00) MWD MWD -Standard Annotation MD TVD ft ft 8270.12 6293.06 TIP 8289.00 6309.14 KOP 9056.00 6529.34 TD Survey: MWD Start Date: 10/2/2005 Company: Baker Hughes INTEO Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ~~5 ~ ~-~J Conoc Phillips '' ~aker Hughes INTEQ Baker Hughes INTEQ Survey Report tNT~t~ ..Company: ConocOPhillips Alaska, lnc Date: 10/25{2005 Time: 10:02:19 ,Page;: 2 Field: Kuparuk River Unit Co-ordinate(NE) References We11: 15, True North Site: > Pad 1$ Vertical (TVD) Reference; Wellhead(95') 95.0 Well: 15 Section (VS) Reference: Well (O:OON,O.OOE,150.OOAzi) Wellpath: 16-15AL2PB1 Survey Calculation Method: Minimum Curvature I)b: < Oracle Survey MD Intl Azim TVD SS TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 8270.12 31.71 231.73 6293.06 6198.06 -2356.97 -2825.58 5967268.33 547149.02 628 .41 0.00 MWD 8289.00 31.51 231.81 6309.14 6214.14 -2363.10 -2833.35 5967262.16 547141.29 629 .83 1.08 MWD 8319.34 36.28 220.99 6334.34 6239.34 -2374.79 -2845.49 5967250.38 547129.23 633 .89 25.30 MWD 8350.07 43.45 200.50 6358.02 6263.02 -2391.65 -2855.21 5967233.46 547119.63 643 .62 48.44 MWD 8382.48 49.73 181.31 6380.39 6285.39 -2414.58 -2859.42 5967210.50 547115.57 661 .38 47.02 MWD 8410.30 52.80 167.18 6397.85 6302.85 -2436.07 -2857.19 5967189.04 547117.94 681 .10 41.08 MWD 8440.16 60.74 154.48 6414.24 6319.24 -2459.52 -2848.91 5967165.64 547126.38 705 .55 44.35 MWD 8471.19 64.85 137.90 6428.51 6333.51 -2482.29 -2833.57 5967142.97 547141.87 732 .94 49.28 MWD 8500.99 70.27 129.99 6439.89 6344.89 -2501.35 -2813.74 5967124.05 547161.82 759 .37 30.53 MWD 8530.81 81.76 131.17 6447.09 6352.09 -2520.15 -2791.80 5967105.40 547183.88 786 .61 38.72 MWD 8560.80 85.35 129.07 6450.45 6355.45 -2539.35 -2769.02 5967086.35 547206.79 814 .63 13.85 MWD 8591.11 90.29 127.69 6451.60 6356.60 -2558.15 -2745.28 5967067.72 547230.65 842 .78 16.92 MWD 8621.59 90.84 123.14 6451.30 6356.30 -2575.80 -2720.45 5967050.23 547255.59 870 .49 15.04 MWD 8653.73 89.03 120.10 6451.34 6356.34 -2592.65 -2693.09 5967033.56 547283.07 898 .76 11.01 MWD 8684.22 88.91 118.15 6451.89 6356.89 -2607.49 -2666.46 5967018.91 547309.79 924 .92 6.41 MWD 8716.65 84.39 118.29 6453.78 6358.78 -2622.79 -2637.94 5967003.79 547338.41 952 .44 13.94 MWD 8747.14 81.83 117.39 6457.44 6362.44 -2636.93 -2611.18 5966989.84 547365.26 978 .06 8.89 MWD 8784.92 78.58 114.21 6463.87 6368.87 -2653.13 -2577.67 5966973.86 547398.87 1008 .84 11.95 MWD 8814.39 76.61 111.16 6470.20 6375.20 -2664.23 -2551.12 5966962.94 547425.49 1031 .73 12.12 MWD 8846.47 74.24 109.83 6478.27 6383.27 -2675.10 -2522.04 5966952.26 547454.64 1055 .69 8.41 MWD 8875.94 71.48 109.47 6486.96 6391.96 -2684.57 -2495.52 5966942.97 547481.22 1077 .15 9.44 MWD 8900.04 69.43 109.07 6495.02 6400.02 -2692.07 -2474.08 5966935.62 547502.70 1094 .36 8.65 MWD 8925.58 71.64 106.29 6503.53 6408.53 -2699.38 -2451.14 5966928.46 547525.69 1112 .16 13.42 MWD 8955.23 76.52 102.50 6511.66 6416.66 -2706.45 -2423.54 5966921.57 547553.34 1132 .09 20.54 MWD 8985.52 77.46 98.01 6518.49 6423.49 -2711.70 -2394.51 5966916.52 547582.41 1151 .15 14.77 MWD 9015.65 82.14 95.64 6523.82 6428.82 -2715.22 -2365.07 5966913.19 547611.86 1168 .91 17.35 MWD 9056.00 82.14 95.64 6529.34 6434.34 -2719.15 -2325.29 5966909.53 547651.66 1192 .20 0.00 MWD t ' Conoc Phillips aker Hughes INTEQ ~ ~ ~'~ Baker Hughes INTEQ Survey Report I1~T>~~ Company: ' ConocoPhillips Alaska, Inc Date: 10/25/2005 Time: 10:04:27 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: `Welt: 15, True North Site:' Pad 4B Vertical (TVD) Reference:. Wellhead(95') 95:0 Well: 15 Sectiou (VS) Reference: Well (OOON,O.OOE,150.OOAzi) Wellpathc 1 B-15AL2P62 Survey Calculation Method: Minimum Curvature Db: -0raCle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004 Site: Pad 1 B Site Position: Northing: 5970149.71 ft Latitude: 70 19 45.173 N From: Map Easting: 550434.96 ft Longitude: 149 35 27.418 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.39 deg Well: 15 Slot Name: Well Position: +N/-S -502.71 ft Northing: 5969643.84 ft Latitude: 70 19 40.229 N +E/-W -479.82 ft Easting : 549958.57 ft Longitude: 149 35 41.425 W Position Uncertainty: 0.00 ft Wellpath: 1 B-15AL2PB2 Drilled From: 1 B-15AL2P61 Tie-on Depth: 8510.00 ft Current Datum: Wellhead(95') Height 95.00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/2(2005 Declination: 24.15 deg Field Strength: 57613 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 150.00 Survey Program for Definitive Wellpath Date: 10/2/2005 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 463.34 4405.00 MWD<0 - 7450'> (470.34-7450.00) (O) MWD MWD -Standard 4430.86 8270.12 MWD (4430.86-8621.00) (1) MWD+IFR+MS MWD +IFR + Multi Station 8289.00 8500.99 MWD (8289.00-9056.00) (3) MWD MWD -Standard 8510.00 10033.00 MWD (8510.00-10033.00) MWD MWD -Standard ,nnotation MD TVD ft ft 8500.99 6439.89 TIP 8510.00 6442.67 KOP 10033.00 6509.30 TD purvey: MWD Start Date: 10/2/2005 ;ompany: Baker Hughes INTEQ Engineer: 'ool: MWD;MWD -Standard Tied-to: From: Definitive Path ~pj --U 1' .~ Conoc Phillips aker Hughes INTEQ Baker Hughes INTEQ Survey Report ~~ It'VTE(l Company: ConoCAPhiIlips Alaska, InC Date: 10/25/2005 Time: 10:04:27 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: We11: 15, True North Site: Pad 1B Vertical (TVD) Reference: Weffhead(95') 95.6 Well: 15 Section(VSjReference: We1F(O.OON,O. OOE,150:OOAzi) Wellpat~: 16-15AL2P62 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inca Azim ' TVD SSTVD N/S E/W MapN MapE VS DLS Toot ft deg deg ft ft ft ft ft ft ft deg/100ft 8500.99 70.27 129.99 6439.89 6344.89 -2501. 35 -2813.74 5967124 .05 547161.82 759. 37 0.00 MWD 8510.00 73.74 130.36 6442.67 6347.67 -2506. 88 -2807.19 5967118 .56 547168.40 767. 43 38.71 MWD 8532.03 67.56 125.23 6449.97 6354.97 -2519. 62 -2790.79 5967105 .93 547184.89 786. 66 35.62 MWD 8563.76 77.55 123.43 6459.48 6364.48 -2536. 66 -2765.82 5967089 .06 547209.97 813. 90 31.94 MWD 8592.71 87.41 123.20 6463.26 6368.26 -2552. 40 -2741.87 5967073. 48 547234.02 839. 51 34.07 MWD 8622.00 94.75 121.59 6462.71 6367.71 -2568. 08 -2717.16 5967057 .97 547258.84 865. 45 25.65 MWD 8652.65 95.24 119.66 6460.04 6365.04 -2583. 64 -2690.88 5967042 .59 547285.21 892. 05 6.47 MWD 8682.38 97.21 117.45 6456.82 6361.82 -2597. 76 -2664.93 5967028. 64 547311.26 917. 26 9.93 MWD 8714.04 96.72 113.65 6452.97 6357.97 -2611. 31 -2636.58 5967015. 28 547339.69 943. 17 12.01 MWD 8742.72 97.27 112.61 6449.48 6354.48 -2622. 50 -2610.40 5967004. 27 547365.94 965. 95 4.08 MWD 8772.81 98.15 109.88 6445.44 6350.44 -2633. 30 -2582.61 5966993. 65 547393.80 989. 20 9.45 MWD 8801.64 96.56 109.13 6441.75 6346.75 -2642. 85 -2555.66 5966984. 29 547420.81 1010. 94 6.09 MWD 8833.67 92.56 108.57 6439.21 6344.21 -2653. 16 -2525.45 5966974. 18 547451.08 1034. 98 12.61 MWD 8861.22 88.85 106.29 6438.87 6343.87 -2661. 41 -2499.18 5966966. 10 547477.41 1055. 26 15.81 MWD 8892.93 90.84 102.34 6438.95 6343.95 -2669. 25 -2468.46 5966958. 47 547508.18 1077. 41 13.95 MWD 8928.02 90.57 98.81 6438.52 6343.52 -2675. 69 -2433.97 5966952. 26 547542.70 1100. 23 10.09 MWD 8964.45 91.05 97.34 6438.01 6343.01 -2680. 80 -2397.91 5966947. 39 547578.80 1122. 69 4.24 MWD 8993.76 90.54 101.05 6437.60 6342.60 -2685. 48 -2368.98 5966942. 90 547607.75 1141. 21 12.78 MWD 9026.35 89.98 104.79 6437.45 6342.45 -2692. 77 -2337.22 5966935. 83 547639.55 1163. 40 11.60 MWD 9055.51 87.56 106.39 6438.08 6343.08 -2700. 60 -2309.15 5966928. 18 547667.68 1184. 22 9.95 MWD 9094.34 87.03 109.18 6439.91 6344.91 -2712. 45 -2272.22 5966916. 58 547704.68 1212. 94 7.31 MWD 9124.62 85.99 111.65 6441.76 6346.76 -2722. 99 -2243.89 5966906. 23 547733.07 1236. 23 8.84 MWD 9152.39 85.03 113.56 6443.93 6348.93 -2733. 63 -2218.34 5966895. 76 547758.70 1258. 23 7.68 MWD 9184.22 81.97 114.81 6447.53 6352.53 -2746. 59 -2189.49 5966883. 00 547787.63 1283. 87 10.38 MWD 9229.09 77.88 115.28 6455.38 6360.38 -2765. 28 -2149.48 5966864. 57 547827.76 1320. 07 9.17 MWD 9257.13 78.20 118.15 6461.19 6366.19 -2777. 61 -2124.97 5966852. 41 547852.34 1343. 00 10.08 MWD 9288.22 78.77 122.48 6467.40 6372.40 -2792. 99 -2098.68 5966837. 21 547878.73 1369. 46 13.77 MWD 9321.85 75.58 123.97 6474.87 6379.87 -2810. 95 -2071.26 5966819. 43 547906.28 1398. 72 10.42 MWD 9354.42 72.20 122.23 6483.90 6388.90 -2828. 04 -2045.05 5966802. 52 547932.59 1426. 63 11.58 MWD 9381.22 71.46 120.23 6492.26 6397.26 -2841. 24 -2023.28 5966789 .46 547954.45 1448. 95 7.61 MWD 9412.33 74.16 118.10 6501.45 6406.45 -2855. 72 -1997.33 5966775. 16 547980.49 1474. 46 10.87 MWD 9443.08 76.69 117.41 6509.19 6414.19 -2869. 57 -1970.99 5966761. 48 548006.92 1499. 63 8.51 MWD 9470.91 78.67 117.88 6515.13 6420.13 -2882. 19 -1946.91 5966749. 03 548031.08 1522. 59 7.30 MWD 9502.57 82.29 117.07 6520.37 6425.37 -2896. 59 -1919.21 5966734. 81 548058.87 1548. 92 11.71 MWD 9530.56 84.76 116.51 6523.52 6428.52 -2909. 13 -1894.39 5966722 .45 548083.78 1572. 18 9.05 MWD 9559.77 87.71 115.60 6525.44 6430.44 -2921. 93 -1868.21 5966709. 82 548110.04 1596. 36 10.57 MWD 9593.41 90.05 116.43 6526.10 6431.10 -2936. 68 -1837.98 5966695. 27 548140.36 1624. 25 7.38 MWD 9626.62 90.84 115.06 6525.84 6430.84 -2951. 10 -1808.07 5966681. 05 548170.36 1651. 69 4.76 MWD 9658.67 91.95 113.57 6525.06 6430.06 -2964. 29 -1778.87 5966668. 05 548199.65 1677. 72 5.80 MWD 9690.71 93.18 110.80 6523.62 6428.62 -2976. 38 -1749.24 5966656 .17 548229.36 1703. 00 9.45 MWD 9722.11 94.87 109.19 6521.42 6426.42 -2987. 09 -1719.81 5966645 .65 548258.86 1726. 99 7.42 MWD 9749.86 94.87 107.67 6519.06 6424.06 -2995. 83 -1693.58 5966637. 09 548285.14 1747. 68 5.46 MWD 9770.00 90.00 107.00 6518.21 6423.21 -3001. 82 -1674.37 5966631. 22 548304.38 1762. 47 24.41 MWD 9810.36 94.95 101.96 6516.47 6421.47 -3011. 90 -1635.36 5966621 .41 548343.46 1790. 70 17.49 MWD 9840.62 95.34 100.17 6513.75 6418.75 -3017. 69 -1605.78 5966615 .82 548373.07 1810. 50 6.03 MWD 9873.61 91.95 98.33 6511.65 6416.65 -3022. 98 -1573.29 5966610 .75 548405.59 1831. 33 11.69 MWD 9903.63 93.82 95.41 6510.14 6415.14 -3026. 56 -1543.53 5966607 .36 548435.38 1849. 31 11.54 MWD 9935.21 90.38 92.79 6508.99 6413.99 -3028. 82 -1512.06 5966605 .31 548466.86 1867. 00 13.69 MWD 9964.97 91.49 89.51 6508.50 6413.50 -3029. 41 -1482.31 5966604 .91 548496.60 1882. 39 11.63 MWD 9995.50 88.70 88.75 6508.45 6413.45 ' -3028. 95 -1451.79 5966605 .58 548527.12 1897. 25 9.47 MWD 10033.00 88.70 88.75 .6509.30 6414.30 -3028. 13 . -1414.31 5966606 .65 .548564.59 1915. 29 0.00 M W D • ConocoPhillips Alaska, Inc. KRU 1 B-15AL2 • ConocoPhillips Alaska, Inc. • KRU 1 B-15AL1 ~~ 1 B-15AL1 API: SSSV T : Annular Fluid: 500292246560 TROP Well T : Ori Com lesion: Last W/O: PROD 9/2/2005 An le TS: An le TD: Rev Reason: d 89 d 973 NEW WELL 1 Reference L : 30.33' RKB Ref L Date: Last U ate: 1 1 /1 512 00 5 Last Ta TD: 9731 ftKB Lasi Ta Date: Max Hole An le: 96 d 8560 Casin Strin -ALL STR INGS Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 WELDED SURFACE 9.625 0 4190 4138 40.00 L-80 PRODUCTION 7.000 0 4405 4324 26.00 L-80 BTCM 5.5" PROD LINER TOP 5.500 4234 8400 6400 15.50 L-80 H drill 511 3.5' PROD LINER TOP 3.500 8121 8400 6400 9.20 L$0 H drill 511 L2 LINER TOP 2.375 8258 8300 6319 4.60 L-80 STL L1 LINER 2.375 8334 9700 6457 4.60 L-80 STL Tubin Strin -TUBING Size To Bottom ND Wt Grade Thread 3.500 0 3992 3963 9.30 L-80 EUEBrd 3.500 3922 7876 5977 9.30 L-80 IBT 3.500 7876 8077 6134 9.30 L-80 EUEBrd Perforations Summa Interval ND Zone Status Ft SPF Date T e Comment 8462 - 9667 6439 -6457 1205 99 10/14/2005 Slotted TBG SLOTTED TBG Gas Lift Mandrels/Valves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2631 2630 CAMCO KBUG-M GLV 1.0 BK 0.125 1225 10/1712005 - 2 3903 3881 CAMCO KBUG-M GLV 1.0 BK 0.156 1265 10/17/2005 3 5093 4791 CAMCO KBG-2-9 GLV 1.0 INT 0.188 1295 10/17!2005 4 6978 5494 CAMCO KBG-2-9 GLV 1.0 BTM 0.188 1290 10/16/2005 5 7822 5940 CAMCO KBG-2-9 OV 1.0 BTM 0.188 0 10/16/2005 Other lu s, a ui ., etc . - W/O & SIDETRACK COMPLET ION De th ND T e Descri lion ID TUBING 30 30 HANGER FMC GEN IV TBG HANGER 3.500 (7876-8077 1482 1481 _ _ _ SSSV CAMCO TRM-5E SSSV 2.920 , OD:3 500 7875 5977 PBR BAKER PBR 3.000 . , ID:2 992) 7889 5987 PACKER BAKER SABL3 PACKER 2.800 . 8032 6098 NIP HES 2.75'X'NIPPLE 2.750 8077 6134 OVERSHOT POOR BOY OVERSHOT SWALLOWED 5' OF TUBING STUB FROM ORIGINAL COMPLETION 3.870 OVERSHOT 8259 6284 De to SLV L2 DEPLOYMENT SLEEVE wl3" GS PROFILE 1.920 (8077-8085, 8288 6308 WINDOW L2 L2 OPEN HOLE 0.000 OD:4.500) 8292 6312 Whi stock L2 3.5' LSC FLOW-THRU WHIPSTOCK TO L2 1.992 TBG STUB 8334 6347 De to SLV L1 DEPLOYMENT SLEEVE w/3" GS PROFILE 1.920 (8081 X118, 8340 6353 WINDOW L7 L1 OPEN HOLE 0.000 OD:3.500) 8343 6355 Whi stock L1 3.5" LSC FLOW-THRU WHIPSTOCK TO L7 1.992 9666 6457 O-RING L1 LINER BTT O-RING SUB 1.000 Other lu s e ui .etc . -ORIGINAL COMPLETION De th ND T e Descri lion ID 8081 6137 TBG STUB TUBING STUB FROM ORIGINAL COMPLETION 2/13/2005 2.992 8118 6167 LOCATOR BAKER NO GO LOCATOR 2/13/2005 2.970 8119 6168 SEAL BAKER BULLET SEAL ASSEMBLY 2/13/2005 2.990 Other lu s e ui ., etc. - 3.5" LINER COMPLETION De th ND T e _ Descri lion ID 8121 6170 TIE BACK SLV BAKER LINER TIE BACK SLEEVE 4.130 8140 6185 PACKER BAKER ZXP LINER TOP PACKER 3.410 8148 6192 PBR BAKER POLISHED BORE NIPPLE SL-HT 3.230 8152 6195 HANGER 3.5" z 5.5" BAKER'HMC' LINER HANGER 2.920 8556 6461 COLLAR BAKER 3.5" LANDING COLLAR 2.993 Other lu s e ui .etc . - 5.5" LINER COMPLETION De th ND T e Descri lion ID I 4235 4177 TIE BACK SLV BAKER LINER TIE BACK SLEEVE 5.500 4241 4182 PACKER BAKER'CPH' LINER TOP PACKER 4.870 4245 4186 HANGER BAKER 'HMC' LINER HANGER 4.920 8177 6215 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850 8221 6252 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850 8224 6255 COLLAR 4.950 8264 6288 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850 ' t 8309 6326 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850 WINDOW L2 (BZes-szsz, General Notes oD:s.ooo) Date Note 10/14/2 005 MULTI-LATERAL WELL: 18-15A ASAND L1 A-SAND EAST L2 A-SAND WEST 10/14/2 005 TREE: FMC I GEN IV / 3-118"SM -Tree Ca Connection: 5.75" Otis Oulck Connect WINDOW L1 (8340343, OD:5.000) Perf (8462-9667) = _ 1 I I I I I - I 1 ~ I r I = =_ -- - • • TUBING (7876-8077, OD:3.500, ID:2.992) Pert (64oa-8417) FRAC (8432-8452) KRU 1 B-15A ConocoPhillips Alaska, Inc. t t 1 B-15A API: 500292246501 Well T :PROD An le TS: 34 d 8206 SSSV T e: TRDP Ori Com letion: 2/16!2005 An le TD: 24 d 8621 Annular Fluid: Last W/O: 9/2/2005 Rev Reason: Workover/ Sidetracks Reference L : 30.33' RKB Ref L Date: Last U ate: 11/14/2005 Las1Ta : 8341 TD: 8621ftKB Last Ta Date: 9/4/2005 Max Hole An le: 71 0 5294 Casin Strin -ALL STRI NGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H40 SURFACE 9.625 0 4190 4138 40.00 L-80 PRODUCTION 7 000 0 4405 4324 26.00 L-SO BTC-M Producttion Liner . 5.500 4234 8350 6361 15.50 L-80 drll 511 il 511 H d Production Liner L2 LINER TOP 3.500 2.375 8121 8258 8621 8300 8621 6319 9.20 4.60 L-80 L-80 r STL L1 LINER TOP 2.375 8334 8400 6405 4.60 L-80 STL Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 3922 3898 9.30 L-80 EUEBrd IBT 3.500 3922 7876 5977 9.30 L-BO 3.500 7876 8077 6134 9.30 L-80 EUE8rd Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 8208 - 8218 6241 - 6250 C~ 10 6 9/5/2005 SOZ 2.5" HMX PJ 2506 10.SG for cement PERF SOZ on back side 8291 - 8296 6311 - 6315 UNIT a 5 6 9/5/2005 SOZ 2.5" HMX PJ 2506 10.5G for cement PERF SOZ on back side 8305 - 8307 6323 - 6325 UNIT B 2 4 3/2/2005 SQZ 1 9/16" Gun, Small charges for PERF cements ueeze on back side 8408 -8417 6472 -6420 A-5 9 6 7/25/2005 IPERF 2.5" HMX PJ 60 d hase 8432 -8452 6434 -6452 A~ 20 4 6 6 3/28/2005 3/2/2005 PERF SOZ Alternatin PJ & PF char es 2.5" HSD Powerflow 60 deg phase 8506 - 8510 6501 - 6505 A•3 PERF for cements ueeze on back side Stimulations & Treatments Interval Date T e Comment 8432 -845 2 5/14/2005 FRAC FRAC w1180 OOOff 16!20 Gas Lift M andrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2631 2630 CAMCO KBUG-M GLV 1.0 BK 0.125 1225 10/17/2005 2 3903 3881 CAMCO KBUG-M GLV 1.0 BK 0.156 1265 10/17/2005 3 5093 4791 CAMCO KBG-2-9 GLV 1.0 INT 0.188 1295 10/17/2005 4 6978 5494 CAMCO KBG-2-9 GLV 1.0 BTM 0.188 1290 10/16/2005 5 7822 5940 CAMCO KBG-2-9 OV 1.0 BTM 0.188 0 10/16/2005 ETRACK CO MPLET ION Other lu s e ui .etc. - W/O & SID De th TVD T e Descri lion ID 30 30 HANGER FMC GEN IV TBG HANGER 3.500 1482 1481 SSSV CAMCO TRM-SE SSSV 2.920 000 3 7875 5977 PBR BAKER PBR . 800 2 7889 5987 PACKER BAKER SABL3 PACKER . 2 750 8032 8077 6098 6134 NIP Overshot HES 2.75'X' NIPPLE POOR BOY OVERSHOT SWALLOWED 5' OF TUBING STUB FROM ORIGINAL COMPLETION . 3.870 8259 6284 De to SLV L2 BTT SEAL BORE DEPLOYMENT SLEEVE w/3" GS PROFILE 1.920 8288 6308 WINDOW L2 OPEN HOLE 0.000 1 992 8292 6312 Whi stock L2 3.5" LSX FLOW-THRU WHIPSTOCKTO l2 " . 1 920 8334 6348 De to SLV GS PROFILE L1 BTT SEAL BORE DEPLOYMENT SLEEVE wl3 . 0.000 8340 6353 WINDOW Lt OPEN HOLE 1 992 8343 6355 Whi stock Lt 3.5" LXS FLOW-THRU WHIPSTOCK TO L1 . Other lu s e ui .etc. -ORIGINAL COMPLETION De th TVD T e Descri lion ID 8081 6137 TBG STUB TUBING STUB FROM ORIGINAL COMPLETION 2!13/2005 2.992 970 2 . 8118 6167 LOCATOR BAKER NO GO LOCATOR 2/13/2005 990 2 . 8119 6168 SEAL BAKER BULLET SEAL ASSEMBLY 2/13/2005 Other lu s e ui .etc . - 3.5" PRODUCTION LINER De th TVD T e Descri lion ID 8121 6170 TIE BACK SLV BAKER LINER TIE BACK SLEEVE 4.130 410 3 8140 6185 PACKER BAKER'ZXP' LINER TOP PACKER . 230 3 8148 6192 PBR POLISHED BORE NIPPLE SL-HT . 920 8152 6195 HANGER 3.5" x 5.5" BAKER'HMC' LINER HANGER 2. 000 0 8498 6494 RETAINER HES 3.5" EZ DRILL RETAINER . 8556 6547 COLLAR BAKER 3.5" LANDING COLLAR 2.993 Other lu s e ui .etc . - 5.5" PRODUCTION LINER De th TVD T e Descri lion ID 4235 4177 TIE BACK SLV BAKER LINER TIE BACK SLEEVE 5.500 870 4241 4182 PACKER BAKER'CPH' LINER TOP PACKER 4. 4 920 4245 4186 HANGER BAKER 'HMC' LINER HANGER . 4 850 8177 6215 Centralizer WEATHERFORD IN-LINE CENTRALIZER . 4 850 8221 6252 Centralizer WEATHERFORD IN-LINE CENTRALIZER . 4 950 8224 6255 COLLAR 5.5" JOINT w/INSERT LANDING COLLAR . 4 850 8264 6288 Centralizer WEATHERFORD IN-LINE CENTRALIZER . 4 850 8309 6326 Centralizer WEATHERFORD IN-LINE CENTRALIZER . General Notes Date Note 2/13/2005 TREE: GMC /GEN IVI 3-1/8' SM TREE CAP CONECTION: 5.75 OTIS OUICK CONNECT Perf (8506-8510) 11 /09/04 STATE O F ALASKA OIL AND GAS CONSERVATION COMMISSION RO PE Test Report Submit to: ~irf3...rE'-.r~ g •~ ~ur~€t3:s~~ f _~ >t:u~ ~ . a d f~ f ~ ce ~i~~~~~~...i _' ~.~ts:~~~~?..i3c:.T+O~U.yi~CS 7~~~~_.~'~r7: ~~_c~t~_Ee I'3~;1; E£?::IxE•`.-nSt£:iFl ~Il~tef~"ii~3 St~'t~;,~iC.tiZ Contractor: Nordic Rig No.: 2 QATE: 10/6/05 Rig Rep.: Holmes-Igtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Feketi-Sarber E-Mailst~.~c~~~~dr1~:rE~~:'+~lE:~~E?t~~~)t~S~3E}E_;~~7~):~_~_3 Well Name: 1 B-15AL2 PAD # 205-115 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 25C-C~;C -,,,~~:ular: " __50'; i~,fes `',.. '-0`?0 MISC. INSPECTIONS; TEST DATA FLOOR SnF'=i ~' ~JALVES; Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MU13 S ;°~~EI~: `u~isual Alars Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/15" P Pit Level Ir~~~ators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N!A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result CHOKE MANIFOLD: System ~ ss~,re xr;.,r, Pressure After Closure 2250 '~ Quantity Test Result 200 psi Attained 24 sec P No. Valves 14 P Full Pressure Attained 89 sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P _ Nitgn. Bottles (avg): 4~ 2150 Test Results Number of Failures: 0 Test Time: 5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Ins ector 659-3607, follow with written confirmation to Supervises at: ,f~E~t_._rEtc<:~ 7zrrYi~~_sf~_tr_~K_ Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES NO XXX c - Oper./Rig Waived By John Spaulding c -Database Date 10/6/05 Time 08:15 c -Trip Rpt File Witness Lancaster /Feketi c -Inspector Test start 12:00 Finish 17:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 10-6-05p.xls ~ i Aras Worthington CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk 1 B-15AL2 ConocoPhillips Alask Inc. Permit No: 205-115 Surface Location: 500' FNL, 484' FEL, SEC. 09, T 11 N, R 10E, UM Bottomhole Location: 3756' FNL, 1413' FEL, SEC. 09, T 11 N, R 10E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new wellbore segment of existing well KRU 1B-15A Permit No.204-256, API No. 50-029-22465-01. Production should continue to be reported as a function of the original API number stated above. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this~~day of July, 2005 cc: Department of Fish 8~ Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. RE: 1B-15A • _ • Subject: : B-1SA `„~~~ a ©~ - ~ ~' From: CUNOCO$ {,~, :^~, ~~` -^ ~ ~ ~a,'~ <IMCEAEX-_O=CONOCO_OU=NORTH+20AMERICA-SW_CN=RECIPIENTS_CN=AJW ORTH@conocophillips.com> Date: Fri, 29 Ju12005 13:21:41 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> No problem; here it is... Tom, Apologies for lack of detail; basically the 3 1/2" x 5 1/2" liner lap was remedially (and successfully) squeezed once before (post rotary rig sidetrack) but the squeeze didn't bring cement up above the point where we will set the upper A-sand whipstock. Since there is some concern about movement of the 3 1/2" liner inside the 5 1/2" (might cause mechanical problems with the window milling) as well as some isolation concerns for a possible C-sand CTD lateral that may be drilled at a future date, we have decided to do a second "remedial" job on the 3 1/2" x 5 1/2" liner lap to cover both issues. Steps are as follows: 1) Pump CaC03 pill over existing A-sand frac'ed perfs, covering them entirely 2) Tag top of CaC03 to confirm coverage 3) Dump-bail latex slurry sand cap on CaC03 to prevent cement filtration into CaC03 4) E-line perforate the 3 1/2" x 5 1/2" liner at both the planned uppper A-sand whipstock set depth and the assumed future C-sand whipstock depth 5) Lay in cement with Coiled Tubing and squeeze 2-3 barrels away 6) Mill out cement with CTU & Clean-out CaC03 plug 7) Run whipstock Dummy drift w/ Slickline 8) MIRU Nordic 2 (whipstock will be set on rig) Please let me know if you need further details. Aras Worthington CPAI CTD Engineer 265-6802 -----Original Message----- From: Thomas Maunder [maa.l.tG;tGm maunder:_adm.i.n,state.ak.us Sent: Friday, July 29, 2005 8:15 AM To: Worthington, Aras J Subject: 1B-15A Aras, I am looking at the proposed CT laterals from 1B-15A. I am curious regarding the operation for step 3 of your procedure where it says "Pre CTD CT cement squeeze of 3-1/2" x 5-1/2"." Could you please provide further information. Thanks in advance. Tom Maunder, PE AOGCC -----Original Message----- From: Thomas Maunder [mailtc:tcm maundera.admin.state.ak.us) Sent: Friday, July 29, 2005 11:32 AM To: Worthington, Aras J Subject: Re: 1B-15A Aras, Hate to bother you, but could you resend your original response to my question on the procedure for 1B-15AL1?? I did a print, trashed and deleted the emails and there was a sizing error on the printing. I would like to put a copy of the message in the well files. Thanks for the help. Tom Thomas Maunder wrote: ', Aras, 1 of 2 7/29/2005 1:29 PM RE: 1B-15A • • I am looking at the proposed CT laterals from 1B-15A. I am curious regarding the operation for step 3 of your procedure where it says "Pre CTD CT cement squeeze of 3-1/2" x 5-1/2"." Could you please provide further information. Thanks in advance. Tom Maunder, PE AOGCC 2 of 2 7/29/2005 1:29 PM i STATE OF ALASK~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2~ AAC 25_nO5 FZ~G~IV~~~` ~u~ „ 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Devel I ^ Stratigraphic Test ^ Service ^ Development Gas [~~i e 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ` 11. Well Name and Number: KUP 1 B-15AL2 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-661 6. Proposed Depth: MD 10750 'TVD 6476ss 12. Field /Pool(s): Kuparuk River Unit 4a. Location of Well (Governmental Section): Surface: 500' FNL 484' FEL SEC 09 T11 N R10E UM ' 7. Property Designation: ADL 025648 , , . , , , Top of Productive Horizon: 2905' FNL, 3376' FEL, SEC. 09, T11 N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 10, 2005 Total Depth: 3756' FNL, 1413' FEL, SEC. 09, T11 N, R10E, UM 9. Acres in Property: 2560 ~ 14. Distance to Nearest Property: 22,700' ' 4b. Location of Well (State Base Plane Coordinates): Surface: x-549955 ' y- 5969647 ' Zone- ASP4 10. KB Elevation (Height above GL): 34' RKB feet 15. Distance to Nearest Well Within Pool 1A-04 is offset by 660' 16. Deviated Wells: Kickoff Depth: 8286 -feet Maximum Hole Angle: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4370 Surface: 3740 ' 18. asng Program: Size Specifications Setting Depth To Bottom uantity of ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2474' 8276' 6203' 10750' 6476' Uncemented Slotted Liner 19. PRESENT WELL CONDITfON SUMMARY (To be completed forRedrill AND'Re-entry Operations) Total Depth MD (ft): 8621 Total Depth TVD (ft): 6607 Plugs (measured): None Effective Depth MD (ft): 8588 Effective Depth TVD (ft): 6576 Junk (measured}: None Casing Length Size Cement Volume MD TVD n t 121' 16" 200 sx Arcticset I 121' 121' 4190' 9-5/8" 900 sx AS III, 400 sx Class 'G' 4190' 4138' I t 4405' 7" 350 sx Class 'G' 4405' 4324' Pr ti n in 4116' 5-1/2" 383 sx Class 'G' 4234' - 8350' 4176' - 6361' Liner 500' 3-1/2" 55 sx Class 'G' 8121' - 8621' 6170' - 6607' Liner 1651' 2-3/8" Uncemented Slotted Liner 8324' - 6520' 9975' - 8368' Perforation Depth MD (ft): 8305' - 8510' i .~ -Q Perforation Depth TVD (ft): 6323' - 6505' 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. !hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 265-6802 Printed Name Aras Worthington Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 265-6802 Date Terrie Hubble, 564-4628 Commission Use Only Permit To Drill . Number: ~--~~~ ~~.~ API Number: ~,~ ~~ ~ 50- 029-22465- -00 ' 'Z" `~ Permit Approval Date: f" See cover letter for other requirements Conditions of Approval: Sampl uired ^ Yes ~, No Mud Log Required ^ Yes Q'No Hydr en ulfide Measures .'Yes ^ No Directional Survey Required f,~'~'es ^ No Other: ~© Q~" 5~ cas D~gt~t~~ r APPROVED BY A roved B _' `~ THE COMMISSION Date ~lt~t~ Form 10-401 Revised 06lZ~06r4 ~ ~~ "' ` ` ~ ~ ` t ~ / i l... S~Ibmit Ir~/Duplicate ~KRU 1 B-15AL1 and 1 B-15AL2 Sidetracks -Coiled Tubin Drillin 9 9 Summary of Operations: Coiled tubing drilling will dri1121aterals in producer KRU 1B-15A using Dynamically Overbalanced pressure drilling technique (DOBCTD, see description below). This horizontal laterals will target Kuparuk A sand ' reserves for production. The Frac'ed Kuparuk A Sand perforations in the existing well, 1B-15A, will be retained. CTD Drill and Complete 1B-15AL1 & 1B-15AL2 program: Planned for AuS 10, 2005 1. Pre CTD MIT-IA, MITT 2. Pre CTD test MV & SV 3. Pre CTD CT cement squeeze of 3 ''/2" X 5 %" 4. Pre CTD CT Mill out cement. 5. Pre CTD drift tubing/liner with dummy whipstock 6. MIRU Nordic 2. NU 7-1116" BOPE, test 7. Set 3 %2" whipstock at 8334' and 8. Mi112.74" window at 8334' and and 10' of openhole 9. Dril13" bicenter hole horizontal lateral from window to 9975' and targeting Kuparuk A sands 1Q; Complete with 2 3/8" slotted liner from TD 9975', up into the 3 1/2" liner to 8324' 11. e /2" whipstoc ~ 86' and ~ _ 12. Mi112.74" window at 8286' and and 10' of openhole. ' ~'C~, PF.x'~Z ~ _ 13. Dri113" bicenter hole horizontal lateral from window to 10750' and targeting Kuparuk A sands 14. Complete with 2 3/8" slotted liner from 10750', up into the 3 ''/z" liner to ~ 8276' 15. ND BOPE. RDMO Nordic 2. , ~,,,,~~ ~ ~ ~~_ ~ ~ ~" 16. Post CTD rig -Run GLVs. BOL. Mud Program: • Step 8: 8.9 ppg Chloride based biozan mud • Step 9-14: Chloride based Flo-Pro (8.9 - 10 ppg) Disposal: • No annular injection on this well • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drillsite 4 • Class I wastes will go to Pad 3 for disposal Casing Program: • 1B-15AL1: 2 3/8", 4.6#, L-80, STL slotted liner from 8324' and to 9975' and • 1B-15AL2: 2 3/8", 4.6#, L-80, STL slotted liner from 8276' and to 10750' and " Well Control: • Two wellbore volumes 0220 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plans for 1B-15AL1 & 1B-15AL2. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1B-15AL1 is 1B-20, which is offset by 430'. KRU boundary is 23,900' away. • The nearest well to 1B-15AL2 is 1A-04, which is offset by 660'. KRU boundary is 22,700' away. Logging • MWD Gamma Ray will be run. ' •KRU 1 B-15AL1 and 1 B-15AL2 Sidetr'~ks -Coiled Tubin Drillin 9 9 Hazards • High pressure (4370 psi) is expected after crossing a mapped fault in 1B-15AL2. • 1B is an H2S pad, the highest H2S measurement on the pad is 183 ppm. All H2S monitoring equipment will be operational. Reservoir Pressure • The drilling plan includes crossing a fault (1B-15AL2) where the expected pressure is 4370 psi at 6307' TVD, 13.3 ppg EMW. Max. surface pressure with gas (0.1 psilft) to surface is 3740 psi. - DOBCTD Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 8.9-10 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 stabili 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 wellbores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing either the TRSSSV or the BOP pipelslips (2-3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Estimated max reservoir pressure: 4370 psi at 6307' TVD, 13.3 ppg EMW. Expected annular friction losses while circulating: 750 psi. Planned mud density: 10 ppg equates to 3280 psi hydrostatic bottom hole pressure. While circulating 10 ppg fluid, plus 340 psi surface pressure applied via the choke, bottom hole circulating pressure is estimated to be 4370 psi or 13.3 ppg ECD. When circulation is stopped, a minimum of 1090 psi surface pressure will be applied to maintain constant BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The production liner will be deployed by closing the SSSV as a barrier. • • y.~;- ConocoPhillips Alaska, Inc. KRU 1 B-15A 1B-15A API: 500292246501 Well T : PROD An le TS: 34 de 8206 rueiNG (0-8121, 00:3.500 SSSV Type: TRDP Orig Com letion: 2/16/2005 Angle @ TD: 24 deg @ 8621 , io:z.ss2) Annular Fluid: Last W/O: Rev Reason: Post FCO Ta Reference Lo 34' RK8 Ref L Date: Last U ate: 7110/2005 Last Ta : 8488 TD: 8621 ftK8 Last Ta Date: 6/29/2005 Max Hole An le: 71 de 5294 Gam' Casin Strin -ALL STRINGS ' Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 '; ,~. SURFACE 9.625 0 4190 4138 40.00 L-80 ; PRODUCTION 7.000 0 4405 4324 26.00 L-80 BTC-M Protection Liner 5.500 4234 8350 6361 15.50 L-80 H dril 511 Production Liner 3.500 8121 8621 8621 9.20 L-80 H dril 511 Tubin Strin -TUBING w'ti~ Size To Bottom TVD Wt Grade Thread 3.500 0 8121 6170 9.30 L-80 EUE8rd Perforations Summar Interval TVD Zone Status Ft SPF Date T e Comment 8305 - 8307 6323 - 6325 UNIT B 2 4 3/2/2005 SOZ PERF 1 9/16" Gun, Small charges for cement squeeze on back side 8432 - 8452 6434 - 6452 A-4 20 6 3/28/2005 PERF Alternatin PJ & PF char es ±^c 8506 - 8510 6501 - 6505 A-3 4 6 3/2/2005 SOZ PERF 2.5" HSD Powerflow 60 deg phase for cement squeeze on back side Stimulations & Treatments Interval Date T e Comment { 8432 - 8452 5/14/2005 FRAC FRAC w/180,000# 16/20 I Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2573 2572 CAMCO KBUG-M GLV 1.0 BK 0.188 1300 5/17/2005 2 3939 3914 CAMCO KBUG-M GLV 1.0 BK 0.200 1270 5/17/2005 3 5364 4888 CAMCO KBG-2-9 GLV 1.0 BTM 0.188 1245 5/17/2005 4 7263 5615 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/23/2005 LOCATOR 5 8037 6102 CAMCO KBG-2-9 OV 1.0 INT 0.188 0 5/16/2005 (e11e-e11s, Other lu s, a ui ., etc. -JEWELRY oD:a.zso> De th TVD T e Descri lion ID 30 30 HANGER FMC GEN IV TBG HANGER 3.500 1833 1832 SSSV CAMCO TRM-4E SAFETY VALVE 2.812 8080 6136 NIP CAMCO'D' LANDING NIPPLE 2.750 8118 6167 LOCATOR BAKER NO GO LOCATOR 2.970 8119 6168 SEAL BAKER BULLET SEAL ASSEMBLY 2.990 PACKER Other lu s, a ui ., etc. -Protection Liner Jewelr (s1ao~1a1, De th TVD T e Descri lion ID oo:a.s~o) 4235 4177 TIE BACK SLV BAKER LINER TIE BACK SLEEVE 5.500 pgR 4241 4182 PACKER BAKER'CPH' LINER TOP PACKER 4.870 (e1aaBlas, 4245 4186 HANGER BAKER'HMC' LINER HANGER 4.920 OD:4.350) 8177 6215 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850 8221 6252 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850 it ~ ; / 8224 6255 COLLAR 5.5" JOINT w/INSERT LANDING COLLAR 4.950 ~ 8264 6288 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850 ~ 8309 6326 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850 ~ ~ ~ Other lu s, a ui ., etc. -Production Liner Jewler De th TVD T e Descri lion ID I ~ 8121 6170 TIE BACK SLV BAKER LINER TIE BACK SLEEVE 4.130 P rt' 8140 6185 PACKER BAKER 2XP' LINER TOP PACKER 3.410 e (e3os-s3o~) 8148 6192 PBR POLISHED BORE NIPPLE SL-HT 3.230 8152 6195 HANGER 3.5" x 5.5" BAKER 'HMC' LINER HANGER 2.920 8498 6494 RETAINER HES 3.5" EZ DRILL RETAINER 0.000 FRAC 8556 6547 COLLAR BAKER 3.5" LANDING COLLAR 2.993 (8432$452) ~. General Notes Perf (8432.8452) ~ ' Date Note ~ ~ 2/13/2005 TREE: GMC /GEN IV/ 3-1/8" 5M TREE CAP CONECTION: 5.75 OTIS QUICK CONNECT 2/13/2005 WELL SIDETRACKED Perf (8506510) KRU 1B-15A Dual A-sand Producer Proposed Completion 3-1/2" Camco TRM-4# SSSV, 2.875" min ID at 1833' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 3-'/2" Camco KBUG-M GLM @ 2573', 3939' MD ~onocoP'hillips Alaska, Inc. • 3-'/2' Camco KBG-2-9 GLM @ 5364', 7263', 8~ 8037' MD 9-5/8" 40# L-80 also' 3-%2' Camco DS nipple, 2.75" min ID @ 8080' MD Baker CPH Packer w/SBE @ 9927' MD r' 2s# L-so 4405' MD L2 KQ~ 8286' MD L1 KOP 8334' MD 3- 5 '/z ' 15.5# L80 @ I ~~ 8350' and J 3-'/z' LSX WS (flowthru) A sand perfs e 2-318" slotted liner 3" openhole 1 B-15A L2 Lateral (A-sand west), TD ~ 10750' and CfiTa~ral (A-sand east), TD @ 9975' and 7/18105 / • Ct~nvt~Phillips Baker Hughes INTEQ Planning Report Baker Hughes INTEQ ~~ I Company: ConocoPhillips Alaska, Inc Date: 7/26/2005 Timc 14:01:11 Page: 7 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 15, True North Site: Pad 1B Vertical (TVD) Reference: Wellhead(95') 95.0 Well: 15 section (VS) Reference. Well (O.OON,O.OOE,150 .ODAzi) Wcllpath: PIan3, 1B-15L2 SurveyCalculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 B Site Position: Northing: 5970149.71 ft Latitude: 70 19 45.173 N From: Map Fasting: 550434.96 ft Longitude: 149 35 27.418 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.39 deg Well: 15 Slot Name: Well Position: +N/-S -502.71 ft Northing: 5969643.84 ft Latitude: 70 19 40.229 N +E/-W -479.82 ft Fasting : 549958.57 ft Longitude: 149 35 41.425 W Position Uncertainty: 0.00 ft Wellpath: PIan3, 16-15L2 Drilled From: 1B-15A Tie-on Depth: 8175.52 ft Current Datum: Wellhead(95') Height 95.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/22/2005 Declination: 24.24 deg Field Strength: 57606 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVA) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 150. 00 Plan: Plan #3 Date Composed: 7/22/2005 Copy Lamar's Plan#3 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <<- Latih~de --> <--- Longitude -> Name Description TVD +N/-S +E/-W Northing Fasting Ucg Min Sec Deg Min Sec Uip. llir. ft ft ft ft ft 16-15L2 Polygon 95.00 -2383.08 -3009.80 5967241.00 546965.00 70 19 16.785 N 149 37 9.261 W -Polygon 1 95.00 -2383.08 -3009.80 5967241.00 546965.00 70 19 16.785 N 149 37 9.261 W -Polygon 2 95.00 -2352.29 -2827.57 5967273.00 547147.00 70 19 17.089 N 149 37 3.943 W -Polygon 3 95.00 -2528.68 -2621.72 5967098.00 547354.00 70 19 15.355 N 149 36 57.934 W -Polygon 4 95.00 -2587.28 -2233.06 5967042.00 547743.00 70 19 14.780 N 149 36 46.592 W -Polygon 5 95.00 -2741.15 -1805.04 5966891.00 548172.00 70 19 13.268 N 149 36 34.100 W -Polygon 6 95.00 -2711.73 -1415.79 5966923.00 548561.00 70 19 13.558 N 149 36 22.741 W -Polygon 7 95.00 -2832.86 -1098.56 5966804.00 548879.00 70 19 12.367 N 149 36 13.483 W -Polygon 8 95.00 -3521.47 -269.05 5966121.00 549713.00 70 19 5.595 N 149 35 49.276 W -Polygon 9 95.00 -3775.48 -270.74 5965867.00 549713.00 70 19 3.097 N 149 35 49.325 W -Polygon 10 95.00 -3476.86 -959.83 5966161.00 549022.00 70 19 6.033 N 149 36 9.432 W -Polygon 11 95.00 -3053.61 -1291.05 5966582.00 548688.00 70 19 10.196 N 149 36 19.099 W -Polygon 12 95.00 -3042.06 -1823.04 5966590.00 548156.00 70 19 10.308 N 149 36 34.623 W -Polygon 13 95.00 -2629.05 -3019.43 5966995.00 546957.00 70 19 14.366 N 149 37 9.540 W 16-15L2 Faultl 95.00 -1192.64 -4857.09 5968419.00 545110.00 70 19 28.484 N 149 38 3.194 W -Polygon 1 95.00 -1192.64 -4857.09 5968419.00 545110.00 70 19 28.484 N 149 38 3.194 W -Polygon 2 95.00 -1155.49 -4278.77 5968460.00 545688.00 70 19 28.853 N 149 37 46.315 W -Polygon 3 95.00 -1317.51 -3827.80 5968301.00 546140.00 70 19 27.262 N 149 37 33.149 W -Polygon 4 95.00 -1603.98 -3611.68 5968016.00 546358.00 70 19 24.445 N 149 37 26.837 W -Polygon 5 95.00 -1647.93 -3168.92 5967975.00 546801.00 70 19 24.015 N 149 37 13.914 W -Polygon 6 95.00 -1884.57 -2927.47 5967740.00 547044.00 70 19 21.689 N 149 37 6.864 W -Polygon 7 95.00 -1903.36 -2659.56 5967723.00 547312.00 70 19 21.505 N 149 36 59.045 W -Polygon 8 95.00 -2064.49 -2342.59 5967564.00 547630.00 70 19 19.921 N 149 36 49.793 W -Polygon 9 95.00 -2090.89 -2132.75 5967539.00 547840.00 70 19 19.662 N 149 36 43.668 W -Polygon 10 95.00 -2490.88 -1239.30 5967145.00 548736.00 70 19 15.730 N 149 36 17.592 W -Polygon 11 95.00 -2827.91 -940.51 5966810.00 549037.00 70 19 12.416 N 149 36 8.871 W -Polygon 12 95.00 -3402.58 -249.25 5966240.00 549732.00 70 19 6.765 N 149 35 48.698 W ,~,, . • • Con©coPh~lhps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report 6439.00 Company: ConocoPMillips Alaska, !nc Field: Kuparuk River Unit Site: Pad 16 Well: 1 S Wellpath: PIan3, 1B-15L2 Targets '.Name -Polygon 13 -Polygon 14 -Polygon 15 -Polygon 16 -Polygon 17 -Polygon 18 -Polygon 19 -Polygon 20 -Polygon 21 -Polygon 22 18-15L2 Fault 2 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 1 B-15L2 Fault 3 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 1 B-15L2 Fault 4 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 -Polygon 11 -Polygon 12 llescription 't'VD Dip. Dir. ft 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 16-15L2 Target 1 1 B-15L2 Target 3 1 B-15L2 Target 2 1 B-15L2 Target 4 1 B-15L2 Target 5 1 B-15L2 Target 6 Date: 7!26/2005 Timc: 14;01:11 Page: 2 Co-nrdinate(NE) Reference: Well: 15, True North Vertical ('PVD) Keference: Wellhead(95') 95.0 Section (VS) Reference: Well (O.OON,O.OOE,150.OOAzi) Surve}~ Calculation Method: Minimum Curvature Db: Oracle Map Map +;V/-S +E!-W 1\orthing Fasting ft ft ft ft -2827.91 -940.51 5966810.00 549037.00 -2490.88 -1239.30 5967145.00 548736.00 -2090.89 -2132.75 5967539.00 547840.00 -2064.49 -2342.59 5967564.00 547630.00 -1903.36 -2659.56 5967723.00 547312.00 -1884.57 -2927.47 5967740.00 547044.00 -1647.93 -3168.92 5967975.00 546801.00 -1603.98 -3611.68 5968016.00 546358.00 -1317.51 -3827.80 5968301.00 546140.00 -1155.49 -4278.77 5968460.00 545688.00 -1465.40 -1893.55 -1465.40 -1893.55 -1856.49 -2037.17 -2197.25 -2230.47 -2668.62 -2333.62 -3131.59 -2346.70 -4064.85 -2473.93 -3131.59 -2346.70 -2668.62 -2333.62 -2197.25 -2230.47 -1856.49 -2037.17 -2491.71 -2616.47 -2491.71 -2616.47 -2641.66 -2627.47 -2791.64 -2633.47 -2641.66 -2627.47 -2560.99 -472.68 -2560.99 -472.68 -3003.30 -434.62 -3445.60 -397.56 -3606.65 -393.63 -3767.69 -389.70 -4235.59 -412.82 -4702.49 -436.93 -4235.59 -412.82 -3767.69 -389.70 -3606.65 -393.63 -3445.60 -397.56 -3003.30 -434.62 5968166.00 548075.00 5968166.00 548075.00 5967774.00 547934.00 5967432.00 547743.00 5966960.00 547643.00 5966497.00 547633.00 5965563.00 547512.00 5966497.00 547633.00 5966960.00 547643.00 5967432.00 547743.00 5967774.00 547934.00 5967135.00 547359.00 5967135.00 547359.00 5966985.00 547349.00 5966835.00 547344.00 5966985.00 547349.00 5967080.00 549503.00 5967080.00 549503.00 5966638.00 549544.00 5966196.00 549584.00 5966035.00 549589.00 5965874.00 549594.00 5965406.00 549574.00 5964939.00 549553.00 5965406.00 549574.00 5965874.00 549594.00 5966035.00 549589.00 5966196.00 549584.00 5966638.00 549544.00 -2525.52 -2795.72 5967100.00 547180.00 70 19 12.416 N 70 19 15.730 N 70 19 19.662 N 70 19 19.921 N 70 19 21.505 N 70 19 21.689 N 70 19 24.015 N 70 19 24.445 N 70 19 27.262 N 70 19 28.853 N 70 19 25.814 N 70 19 25.814 N 70 19 21.968 N 70 19 18.616 N 70 19 13.980 N 70 19 9.426 N 70 19 0.247 N 70 19 9.426 N 70 19 13.980 N 70 19 18.616 N 70 19 21.968 N 70 19 15.718 N 70 19 15.718 N 70 19 14.244 N 70 19 12.769 N 70 19 14.244 N 70 19 15.041 N 70 19 15.041 N 70 19 10.691 N 70 19 6.341 N 70 19 4.758 N 70 19 3.174 N 70 18 58.572 N 70 18 53.980 N 70 18 .58.572 N 70 19 3.174 N 70 19 4.758 N 70 19 6.341 N 70 19 10.691 N 149 36 8.871 W 149 36 17.592 W 149 36 43.668 W 149 36 49.793 W 149 36 59.045 W 149 37 6.864 W 149 37 13.914 W 149 37 26.837 W 149 37 33.149 W 149 37 46.315 W 149 36 36.692 W 149 36 36.692 W 149 36 40.881 W 149 36 46.519 W 149 36 49.525 W 149 36 49.903 W 149 36 53.607 W 149 36 49.903 W 149 36 49.525 W 149 36 46.519 W 149 36 40.881 W 149 36 57.782 W 149 36 57.782 W 149 36 58.101 W 149 36 58.275 W 149 36 58.101 W 149 35 55.219 W 149 35 55.219 W 149 35 54.108 W 149 35 53.026 W 149 35 52.911 W 149 35 52.796 W 149 35 53.470 W 149 35 54.172 W 149 35 53.470 W 149 35 52.796 W 149 35 52.911 W 149 35 53.026 W 149 35 54.108 W 70 19 15.385 N 6518.00 -2776.34 -2077.30 5966854.00 547900.00 70 19 12.921 N I~i"ii!~ 149 37 3.012 W 149 36 42.045 W 6524.00 -2692.95 -2283.77 5966936.00 547693.00 70 19 13.740 N 149 36 48.071 W 6524.00 -2875.79 -1710.92 5966757.00 548267.00 70 19 11.944 N 149 36 31.352 W 6542.00 -2833.92 -1239.59 5966802.00 548738.00 70 19 12.356 N 149 36 17.598 W 6564.00 -3250.04 -928.32 5966388.00 549052.00 70 19 8.264 N 149 36 8.514 W Annotation MD _ TVD _ _ _ _ __ _ _ ft ft ___ _-- 8175.52 6214.10..... TIP 8286.00 6306.58 KOP 8306.00 6323.48 End of 9°/100' DLS <_-- Latitude ----> <--- Longitude ---> Deg Min Sec Deg Min Sec ~'' ~ • ~ t Ctmncc~Phillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~1 E Company: GonoeoPhillips Alaska, Inc Date: 7/26/2005 Timr. 14:01:11 Pagc: 3 HSeld: Kuparuk Rive r Unit Co-or dinate(tiE) Reference: Well: 15, True North Site: Pad 1 B Verti cal (TVD) Reference: Wellhead(95' ) 95.0 Well: 1 5 Section (VS) Reference: Well (O.OON,0.00r=,150. 00Azi) ~~ ~Vcllpath: PIan3, 1B-15L2 Survey Calculation Method: Minimum Curvature Db: Oracle Annotation ~ID TVD -__ - -- _ -- _ _ - --- ft ~ ft - 8346.00 - -- 6354.74 - - 4 - - - - --- ---- - -- - - -- 8421.00 6402.76 5 8496.00 6437.18 6 8542.88 6445.72 End of 45°/100' DLS 8817.88 6472.06 8 8908.88 6497.40 9 9114.34 6530.45 10 9339.34 6524.54 11 9714.34 6531.38 12 9839.34 6535.56 13 10139.34 6546.33 14 10439.34 6558.22 15 10750.00 6571.47 TD Plan Section Information ~ Mll Incl Azim TVll +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/10 0ft deg 8175.52 35.11 233.59 6214.10 -2325.42 -2784.15 0.00 0.00 0.00 0.00 $270.12 31.71 231.73 6293.06 -2356.97 -2825.58 3.75 -3.59 -1.97 195.99 8286.00 31.54 231.80 6306.58 -2362.13 -2832.12 1.10 -1.07 0.44 167.85 8306.00 33.11 230.15 6323.48 -2368.86 -2840.42 9.00 7.85 -8.24 330.00 8346.00 44.58 207.74 6354.74 -2388.45 -2855.47 45.00 28.68 -56.03 300.00 8421.00 57.91 167.38 6402.76 -2444.38 -2860.94 45.00 17.77 -53.82 279.00 8496.00 68.90 131.47 6437.18 -2500.17 -2826.79 45.00 14.65 -47.87 280.00 8542.88 90.00 131.47 6445.72 -2530.52 -2792.45 45.00 45.00 0.00 0.00 8817.88 79.26 100.08 6472.06 -2648.50 -2549.66 12.00 -3.90 -11.42 250.00 8908.88 68.34 100.08 6497.40 -2663.77 -2463.75 12.00 -12.00 0.00 180.00 9114.34 93.00 100.08 6530.45 -2698.98 -2265.67 12.00 12.00 0.00 0.00 9339.34 89.96 126.92 6524.54 -2787.87 -2061.32 12.00 -1.35 11.93 96.00 9714.34 88.06 81.95 6531.38 -2878.98 -1707.49 12.00 -0.51 -11.99 267.30 9839.34 88.13 66.94 6535.56 -2845.58 -1587.48 12.00 0.05 -12.01 270.00 10139.34 87.90 102.96 6546.33 -2819.62 -1293.73 12.00 -0.08 12.01 91.00 10439.34 87.71 138.99 6558.22 -2971.37 -1040.93 12.00 -0.06 12.01 91.00 10750.00 87.57 176.30 6571.47 -3253.37 -924.96 12.00 -0.04 12.01 91.00 Survey MD lncl Azim SS T~'D 1\lS G/V1' MapN MapE llLS ~'S TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 8175.52 35.11 233.59 6119.10 -2325.42 -2784.15 5967300.16 547190.23 0.00 621.79 0.00 MWD 8200.00 34.23 233.14 6139.24 -2333.72 -2795.33 5967291.78 547179.12 3.75 623.40 195.99 MWD 8225.00 33.33 232.66 6160.02 -2342.11 -2806.41 5967283.32 547168.09 3.75 625.12 196.36 MWD 8250.00 32.43 232.15 6181.01 -2350.39 -2817.17 5967274.97 547157.39 3.75 626.91 196.76 MWD 8270.12 31.71 231.73 6198.06 -2356.97 -2825.58 5967268.33 547149.02 3.75 628.41 197.18 MWD 8275.00 31.66 231.75 6202.22 -2358.56 -2827.59 5967266.73 547147.02 1.10 628.78 167.85 MWD 8286.00 31.54 231.80 6211.58 -2362.13 -2832.12 5967263.14 547142.52 1.10 629.60 167.83 MWD 8300.00 32.64 230.63 6223.45 -2366.78 -2837.91 5967258.44 547136.75 9.00 630.74 330.00 MWD 8306.00 33.11 230.15 6228.48 -2368.86 -2840.42 5967256.35 547134.26 9.00 631.28 330.99 MWD 8325.00 38.03 218.09 6243.95 -2376.81 -2848.03 5967248.35 547126.70 45.00 634.36 300.00 MWD 8346.00 44.58 207.74 6259.74 -2388.45 -2855.47 5967236.66 547119.34 45.00 640.72 309.83 MWD 8350.00 44.89 205.22 6262.58 -2390.97 -2856.72 5967234.13 547118.11 45.00 642.28 279.00 MWD 8375.00 48.01 190.28 6279.85 -2408.15 -2862.16 5967216.92 547112.79 45.00 654.44 280.79 MWD 8400.00 52.85 177.08 6295.82 -2427.30 -2863.31 5967197.76 547111.76 45.00 670.44 291.12 MWD 8421.00 57.91 167.38 6307.76 -2444.38 -2860.94 5967180.70 547114.25 45.00 686.42 299.56 MWD 8425.00 58.24 165.29 6309.88 -2447.67 -2860.14 5967177.41 547115.07 45.00 689.fi8 280.00 MWD 8450.00 61.04 152.65 fi322.55 -2467.73 -2852.39 5967157.41 547122.95 45.00 710.93 281.10 MWD 8475.00 64.94 140.80 6333.94 -2486.28 -2840.17 5967138.94 547135.30 45.00 733.10 287.51 MWD 8496.00 68.90 131.47 6342.18 -2500.17 -2826.79 5967125.14 547148.77 45.00 751.82 292.91 MWD 8500.00 70.70 131.47 6343.56 -2502.66 -2823.97 5967122.67 547151.60 45.00 755.38 0.00 MWD Cc~nc~cxiPhilhps Baker Hughes INTEQ ~ '~"~ Baker Hughes INTEQ Planning Report ~. Compan}: ConocoPhiNips Alaska, Inc Date: 7/26/2005 Time: 14:01:11 Page: 4 Field: Kuparuk River Unit Cu-ordinate(VE) Re ference: Well: 15, Tr ue North Site: Pad 18 Ve rtical (TVll) Refe rence: We1{head(95') 95.0 Well: 15 Section (VS) Reference: Well (O.OON, 0.006,150 .OOAzi) Ncllpath: PIa n3, 1B-1 5L2 Su rvey Calculation Method: Minimum Curvature Db: Oracle Survey Kll Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 8525.00 81.95 131.47 6349.46 -2518.72 -2805.80 5967106.74 547169.87 45.00 778.37 360.00 MWD 8542.88 90.00 131.47 6350.72 -2530.52 -2792.45 5967095.02 547183.30 45.00 795.27 0.00 MWD 8550.00 89.71 130.67 6350.73 -2535.20 -2787.08 5967090.38 547188.70 12.00 802.01 250.00 MWD 8575.00 88.68 127.85 6351.09 -2551.02 -2767.73 5967074.70 547208.16 12.00 825.38 250.00 MWD 8600.00 87.66 125.03 6351.88 -2565.86 -2747.63 5967059.99 547228.35 12.00 848.28 250.04 MWD 8625.00 86.64 122.20 6353.13 -2579.68 -2726.84 5967046.31 547249.24 12.00 870.65 250.13 MWD 8650.00 85.64 119.37 6354.81 -2592.44 -2705.41 5967033.69 547270.74 12.00 892.42 250.27 MWD 8675.00 84.64 116.53 6356.93 -2604.12 -2683.41 5967022.16 547292.82 12.00 913.53 250.46 MWD 8700.00 83.65 113.68 6359.48 -2614.67 -2660.89 5967011.76 547315.41 12.00 933.92 250.70 MWD 8725.00 82.69 110.82 6362.45 -2624.07 -2637.92 5967002.52 547338.44 12.00 953.55 250.99 MWD 8750.00 81.73 107.95 6365.84 -2632.29 -2614.56 5966994.45 547361.85 12.00 972.35 251.33 MWD 8775.00 80.80 105.06 6369.64 -2639.31 -2590.87 5966987.59 547385.58 12.00 990.27 251.72 MWD 8800.00 79.90 102.16 6373.83 -2645.11 -2566.92 5966981.95 547409.57 12.00 1007.27 252.16 MWD 8817.88 79.26 100.08 6377.06 -2648.50 -2549.66 5966978.67 547426.84 12.00 1018.84 252.65 MWD 8825.00 78.41 100.08 6378.44 -2649.72 -2542.79 5966977.50 547433.73 12.00 1023.34 180.00 MWD 8850.00 75.41 100.08 6384.10 -2653.98 -2518.81 5966973.40 547457.73 12.00 1039.01 180.00 MWD 8875.00 72.41 100.08 6391.03 -2658.19 -2495.17 5966969.35 547481.40 12.00 1054.47 180.00 MWD 8900.00 69.41 100.08 6399.20 -2662.32 -2471.91 5966965.37 547504.68 12.00 1069.68 180.00 MWD 8908.88 68.34 100.08 6402.40 -2663.77 -2463.75 5966963.98 547512.85 12.00 1075.02 180.00 MWD 8925.00 70.28 100.08 6408.10 -2666.41 -2448.91 5966961.44 547527.71 12.00 1084.73 0.00 MWD 8950.00 73.28 100.08 6415.92 -2670.57 -2425.53 5966957.44 547551.11 12.00 1100.01 0.00 MWD 8975.00 76.28 100.08 6422.48 -2674.79 -2401.78 5966953.38 547574.88 12.00 1115.54 0.00 MWD 8977.22 y6.55 100.08 6423.00 -2675.16 -2399.66 5966953.01 547577.01 12.00 1116.93 360.00 1 B-15L2 9000.00 79.28 100.08 6427.77 -2679.06 -2377.73 5966949.26 547598.96 12.00 1131.27 0.00 MWD 9025.00 82.28 100.08 6431.78 -2683.38 -2353.43 5966945.11 547623.28 12.00 1147.16 0.00 MWD 9050.00 85.28 100.08 6434.48 -2687.73 -2328.97 5966940.92 547647.78 12.00 1163.16 0.00 MWD 9075.00 88.28 100.08 6435.89 -2692.10 -2304.39 5966936.72 547672.37 12.00 1179.23 0.00 MWD 9100.00 91.28 100.08 6435.99 -2696.47 -2279.78 5966932.51 547697.01 12.00 1195.32 0.00 MWD 9114.34 93.00 100.08 6435.45 -2698.98 -2265.67 5966930.10 547711.14 12.00 1204.55 0.00 MWD 9125.00 92.87 101.35 6434.91 -2700.96 -225522 5966928.19 547721.61 12.00 1211.49 96.00 MWD 9150.00 92.54 104.34 6433.72 -2706.51 -2230.87 5966922.80 547745.99 12.00 1228.47 96.07 MWD 9175.00 92.22 107.32 6432.69 -2713.32 -2206.84 5966916.15 547770.06 12.00 1246.38 96.21 MWD 9200.00 91.88 110.31 6431.79 -2721.38 -2183.20 5966908.25 547793.75 12.00 1265.18 96.33 MWD 9225.00 91.54 113.29 6431.04 -2730.65 -2160.00 5966899.13 547817.01 12.00 1284.82 96.44 MWD 9250.00 91.20 116.27 6430.44 -2741.13 -2137.31 5966888.80 547839.77 12.00 1305.23 96.53 MWD 9275.00 90.86 119.25 6429.99 -2752.77 -2115.19 5966877.31 547861.96 12.00 1326.37 96.60 MWD 9300.00 90.51 122.23 6429.70 -2765.55 -2093.71 5966864.68 547883.53 12.00 1348.18 96.65 MWD 9325.00 90.16 125.21 6429.55 -2779.42 -2072.92 5966850.94 547904.41 12.00 1370.59 96.69 MWD 9339.34 89.96 126.92 6429.54 -2787.87 -2061.32 5966842.58 547916.06 12.00 1383.70 96.70 MWD 9350.00 89.90 125.64 6429.55 -2794.17 -2052.73 5966836.33 547924.69 12.00 1393.46 267.30 MWD 9375.00 89.76 122.64 6429.63 -2808.20 -2032.04 5966822.44 547945.47 12.00 1415.95 267.30 MWD 9400.00 89.61 119.65 6429.77 -2821.13 -2010.65 5966809.66 547966.94 12.00 1437.85 267.31 MWD 9425.00 89.48 116.65 6429.96 -2832.92 -1988.61 5966798.01 547989.06 12.00 1459.08 267.33 MWD 9450.00 89.34 113.65 643022 -2843.55 -1965.98 5966787.54 548011.75 12.00 1479.59 267.35 MWD 9475.00 89.20 110.66 6430.54 -2852.97 -1942.83 5966778.27 548034.96 12.00 1499.33 267.38 MWD 9500.00 89.07 107.66 6430.92 -2861.17 -1919.22 5966770.22 548058.63 12.00 1518.24 267.42 MWD 9525.00 88.94 104.66 6431.35 -2868.13 -1895.22 5966763.43 548082.67 12.00 1536.27 267.47 MWD 9550.00 88.81 101.66 6431.85 -2873.82 -1870.88 5966757.90 548107.05 12.00 1553.36 267.52 MWD 9575.00 88.68 98.67 6432.39 -2878.23 -1846.28 5966753.65 548131.67 12.00 1569.48 267.58 MWD 9600.00 88.56 95.67 6433.00 -2881.35 -1821.49 5966750.70 548156.48 12.00 1584.58 267.64 MWD 9625.00 88.44 92.67 6433.65 -2883.17 -1796.57 5966749.05 548181.41 12.00 1598.61 267.71 MWD 9650.00 88.33 89.67 6434.35 -2883.68 -1771.58 5966748.71 548206.40 12.00 1611.55 267.79 MWD 9675.00 88.22 86.67 6435.10 -2882.88 -1746.61 5966749.67 548231.36 12.00 1623.34 267.88 MWD ~ ~ ~ ~s^ C~nocc~h;il;ps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report 1~T- ,- Company: ConocoPhillips Alaska, Inc Date: 7/26/2005 Time : 14:01.11 Page: 5 Field: Kuparuk River Unit Co-ordinate(VE) Reference Well: 15, Tr ue North Site: Pad 1B ~'erti cal(TVD)Refe rence: Wellhead(95')95.0 R'ell: 15 Scc4on (VS) Refere nce: Well (O.OON ,O.OOE,150 .OOAzi) Wellpath: PIa n3, 1B-15L2 Survey Calculation Method: Minimum Cu rvature Db: Orade Survev MD Incl Azim SS TVll h{S E/~V MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100fl ft deg 9700.00 88.12 83.67 6435.90 -2880.78 -1721.72 5966751.94 548256.24 12.00 1633.97 267.97 MWD 9714.34 88.06 81.95 6436.38 -2878.98 -1707.49 5966753.83 548270.45 12.00 1639.52 268.06 MWD 9725.00 88.06 80.67 6436.74 -2877.37 -1696.97 5966755.51 548280.96 12.00 1643.39 270.00 MWD 9750.00 88.07 77.67 6437.59 -2872.68 -1672.43 5966760.37 548305.47 12.00 1651.60 270.04 MWD 9775.00 88.0$ 74.67 6438.43 -2866.70 -1648.17 5966766.50 548329.68 12.00 1658.55 270.14 MWD 9800.00 88.09 71.66 6439.27 -2859.47 -1624.26 5966773.89 548353.55 12.00 1664.24 270.25 MWD 9825.00 88.11 68.66 6440.09 -2850.99 -1600.76 5966782.53 548376.99 12.00 1668.65 270.35 MWD 9839.34 88.13 66.94 6440.56 -2845.58 -1587.48 5966788.03 548390.22 12.00 1670.60 270.45 MWD 9850.00 88.10 68.22 6440.91 -2841.51 -1577.64 5966792.16 548400.04 12.00 1672.00 91.00 MWD 9875.00 88.06 71.22 6441.75 -2832.85 -1554.20 5966800.97 548423.41 12.00 1676.22 90.96 MWD 9900.00 88.01 74.22 6442.61 -2825.43 -1530.35 5966808.55 548447.22 12.00 1681.72 90.86 MWD 9925.00 87.98 77.22 6443.48 -2819.27 -1506.14 5966814.87 548471.38 12.00 1688.49 90.75 MWD 9950.00 87.95 80.23 6444.37 -2814.39 -1481.64 5966819.92 548495.85 12.00 1696.51 90.65 MWD 9975.00 87.92 83.23 6445.27 -2810.80 -1456.92 5966823.67 548520.54 12.00 1705.76 90.54 MWD 10000.00 87.90 86.23 6446.18 -2808.50 -1432.04 5966826.13 548545.40 12.00 1716.21 90.43 MWD 10025.00 87.89 89.23 6447.10 -2807.51 -1407.08 596682729 548570.35 12.00 1727.84 90.33 MWD 10050.00 87.88 92.23 6448.03 -2807.83 -1382.10 5966827.14 548595.33 12.00 1740.60 9021 MWD 10075.00 87.88 9524 6448.95 -2809.46 -1357.18 5966825.68 548620.26 12.00 1754.48 90.10 MWD 10100.00 87.88 98.24 6449.88 -2812.39 -1332.37 5966822.91 548645.09 12.00 1769.42 89.99 MWD 10125.00 87.89 101.24 6450.80 -2816.62 -1307.75 5966818.85 548669.73 12.00 1785.39 89.88 MWD 10139.34 87.90 102.96 6451.33 -2819.62 -1293.73 5966815.94 548683.76 12.00 1795.00 89.77 MWD 10150.00 87.87 104.24 6451.72 -2822.13 -1283.38 5966813.50 548694.13 12.00 1802.34 91.00 MWD 10175.00 87.83 107.24 6452.66 -2828.90 -1259.34 5966806.89 548718.21 12.00 1820.23 90.95 MWD 10200.00 87.79 110.25 6453.62 -2836.93 -1235.69 5966799.02 548741.92 12.00 1839.01 90.84 MWD 10225.00 87.75 113.25 6454.59 -2846.19 -1212.49 5966789.92 548765.18 12.00 1858.63 90.73 MWD 10250.00 87.72 116.25 6455.58 -2856.64 -1189.80 5966779.61 548787.93 12.00 1879.02 90.61 MWD 10275.00 87.70 119.25 6456.58 -2868.27 -1167.70 5966768.13 548810.11 12.00 1900.15 90.49 MWD 10300.00 87.68 122.25 6457.58 -2881.04 -1146.23 5966755.50 548831.65 12.00 1921.94 90.37 MWD 10325.00 87.67 125.26 6458.59 -2894.92 -1125.47 5966741.77 548852.51 12.00 1944.34 90.25 MWD 10350.00 87.67 128.26 6459.61 -2909.87 -1105.46 5966726.95 548872.62 12.00 1967.29 90.13 MWD 10375.00 87.67 131.26 6460.63 -2925.84 -1086.26 5966711.11 548891.92 12.00 1990.73 90.01 MWD 10400.00 87.68 134.26 6461.64 -2942.80 -1067.92 5966694.27 548910.37 12.00 2014.58 89.88 MWD 10425.00 87.70 137.27 6462.65 -2960.70 -1050.50 5966676.50 548927.91 12.00 2038.79 89.76 MWD 10439.34 87.71 138.99 6463.22 -2971.37 -1040.93 5966665.89 548937.55 12.00 2052.82 89.64 MWD 10450.00 87.69 140.27 6463.65 -2979.48 -1034.04 5966657.82 548944.50 12.00 2063.29 91.00 MWD 10475.00 87.64 143.27 6464.67 -2999.10 -1018.58 5966638.31 548960.08 12.00 2088.01 90.95 MWD 10500.00 87.60 146.27 6465.70 -3019.50 -1004.17 5966618.01 548974.62 12.D0 2112.88 90.83 MWD 10525.00 87.57 149.28 6466.76 -3040.63 -990.86 5966596.97 548988.08 12.00 2137.84 90.70 MWD 10550.00 87.54 152.28 fi467.82 -3062.43 -978.66 5966575.26 549000.41 12.00 2162.81 90.58 MWD 10575.00 87.52 155.28 6468.90 -3084.83 -967.63 5966552.93 549011.59 12.00 2187.73 90.45 MWD 10600.00 87.51 158.28 6469.98 -3107.78 -957.78 5966530.05 549021.59 12.00 2212.53 90.32 MWD 10625.00 87.50 161.29 6471.07 -3131.22 -949.16 5966506.67 549030.38 12.00 2237.14 90.19 MWD 10650.00 87.50 164.29 6472.16 -3155.07 -941.77 5966482.87 549037.92 12.00 2261.49 90.06 MWD 10675.00 87.51 167.29 6473.25 -3179.28 -935.64 5966458.70 54904421 12.00 2285.52 89.93 MWD 10700.00 87.52 170.30 6474.33 -3203.78 -930.78 5966434.24 549049.23 12.00 2309.16 89.80 MWD 10725.00 87.55 173.30 6475.41 -3228.50 -927.22 5966409.55 549052.96 12.00 2332.35 89.67 MWD j 10750.00 87.57 176.30 6476.47 -3253.37 -924.96 5966384.69 549055.39 12.00 2355.02 89.54 MWD BP Amoco weLLVwr« 0erwas T enssa p.», aer. 0peum. wennev0(vs~l 0s.0at 0.:e.° 0.:p.° •ngle ~IU~9 *EIW From TVO m0.oo o.o0 000 0.00 REFERENCE INFORMATION Ln-orAinute (N/E) RefOenre: Wall Centre: 15. Truo Nnrth vcrlical (TVD) Reference: System: Mean Sea Level Section I VS) Reference- Sfot - (O.nnN 0 (10E1 raeaswe0 Dentn Reverence- weuneanlu, r s6 00 GalCllla119n Metho[f-. M~nlmum C:urvaWre 5950--' 6000- 6050--' 6100 -_ T_P C 6150 ~ 6200- KOP - - ~ - -- t 6250 - ~ w ~ 6300- - -- d ~ 6350-_~- - - -- -_- - H ~ _., 6400 15 PIpn8. t8-1,511 W 3 L -~ V! _ 6450- -- __._ _. 3 6500- _- ___ _ L I- 15 (18-150.) 6550 - 6600 - 6650 °, 6700 - r 550 600 650 700 ~S"~t :4t~ ~° ~~+ _ #=, !+7,y ~ ~~~~~ ~~~'~~~ - ------ - -- ~'y1 +~~r ~ LEGEND ( - is (is-isn) 15 (P pn:1. 1B-15L1) - to fib-i6) - "11 B'0") - PIan3. 18-t SL2 - Pipn as T /~\ M I /,, 1/ I/ /d\ Plan-Plan L'i (157Pkni 1R-151 I1 F1ZIn1U[h8 tU Idle IVOfl11 Magne[i- worth: 2d [4` j craated oy Dnl M-.naals Date: 7 /2 612 0 0 5 I Magnetic Fleltl Strength: 57606nT -'- _- Din Angle 80.77` _ - _ .~ ~•~jA I t'H' `I/ Harp 7mnnnF , M~riP(_ hggm2nn4 r -1900 _- -_ ~"_-,~y. -2000- J -2100T -2200 = -nP ' _ :iBk:i _ - 15 (PIpn.1. 18-t;iL11 KClP Ir 555U -2300- -_ _ " ~ Bnnn - . - (Enn °r n-n not r+-2400- ~ - _ ~"' ra n~ .~ - ~ n"nn 2500- 1518.15a1 ~ 18. 2600-- - - ~ _ R;ftl. + -2700 ti _ 1g.15L2 Tor d 1 j. Enrl nr "5'/1nn'OLS i+ -2800 O _ Z -2900-- ---- - - ' .~. .C 3000 _ _ _ __: ~+ 3 O -3100- ~- --- , fA - -3200 ~_ _.. _._ -._ __ _.. ---' -3300-. __-. -_._ _. _- :. -3400- -3500--~ __ _. _: -3600--.. _-.-. -3200-3100-3000-2900-2800-2700-2600:500-2400-2300-2200- !0,-2000-t....~~-.,- ~...~ ~~~~-~..~~-14~..-~..~~-~~~~-~~~~-~~.... ~~~ -~..~ -~uu West( ~/East(+) [?OOf±!i.,] -----. _ _ 1 Tar 412 ~ 1B~15L2 T»r H3 i t8~15L2 Tar CI4 ~~~\ t"- ~~, 1 n ---- - - to-15L2 TnrGala ---.. 1t 12 1:1 -~--____ ~_~ ~~ ~ 1 -. _ I 1---- - 800 850 900 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 1450 15001'350 1600 1650 1700 1750 1800 1~ou X907 i95u 2000 2050 2ivu 2150 2200 <"250 2300 2350 2400 2450 Vertical Section ai 150.00° [50ft/in] 3 r ivi • i • Kuparuk DOBCTD BOP configuration 2" CT Well 1 B-15A Rig Floor 0 i TOT Tree Size Flow Tee J 7 1/16" 5000 psi (RX-46) or ~- 4 1116" 5000 psi (RX-39) Swab Valve SSV Master Valve Base Flan e Page 1 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# ~'/~`j CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS MULTI The permit is for a new wellbore segment of LATERAL existing well ~'/; /~ ` /S -- ~, ~`~ - Z ~ `/~, " f / , Permit No,~ y-z~~ API No. X' l~ (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (pig records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and togs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. =mar Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RV OIL • 490100 Well Name: KUPARUK RIV UNIT 1 B-15AL2 Program DEV Well bore seg ~ PTD#:2051150 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype DEV! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permitfee attached- _ _ _ _ _ _ _ - _ _ - - . _ - _ . _ _ NA_ _ _ - - _ - _ Multilateralwell bo[e; fee waived_pe[ 20 AAC 25.005(e) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . , _ _ 2 Lease number appropriate_________________________ ______ _________Yes_ _________---_-_- - - - 3 Uniquewell.nameandnumber_____________________________ _________Yes_ _______-_.______-_______.. ------------------------------------------------ 4 Welllocat_edina_definedpool__________________________--_ -..______Yes- -_-__-Kup_arukRive[OilPool,gov_ernedbyConseryationOrderNo.4320.____-__-.--._______--.___. 5 Well located proper distance from drilling unit_boundary_ - - - ... - Yes - - _ , - Conservation Order No. 4320 contains n9 spacing restrictions with r_espect_t4 drilling unit boundaries. _ _ - 6 Well located proper distance from other wells- _ - - - - - , - _ _ -Yes Conservation Order No. 4320 has no intenveli_spacing-restrictions, --------------- 7 Sufficient acreage availaable in_drilling unit- - _ _ - - _ - - . - Yes - Conservation Order No. 4320 has no in_terwelLspaeing-restrictions, Wellbore will be_more than 500' from _ - . . 8 If deviated, is_wellbore plat_included _ - - - _ - _ _ .. _ _ ,Yes an external property line where ownership or_landownership changes. _ - - - - - - _ - - - - - - . - . 9 Operator only affected early-------------------_----- --Yes- ------------__-.-- 10 Operakorhas-appropriate-bond in force---------- --- -------- -- - --Yes- ---- --~ -- ------ --- --- ------...- -- ---------- -- --------- -- -- 11 Permit can be issuedw~houtconseruationorder___________________ _________Yes_ -_________--__________--_-__--________-_______---_______-__--_____,- Appr Date 12 Permit_canbeissuedwithoutadministrative_appr-oval________________ _________Yes_ ________.---_-__-_______-.____-_____-__--_______----,-_____------. SFD 7!28!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within areaand_strataauthprizedby_Injection0[der#(putl9#in_comments)_(For_ NA_ _______________________ ______--,________-__--_-_______-.________-.-__ _ 15 All wells-within 114_mile area_of review identified (For senriee well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ . _ _ _ . - _ _ _ _ _ _ - - _ ----------------------------------------------------------- 16 Pre-produced injector; duration of pre production less than 3 months- (For_service well only) NA_ - - 17 ACMP-Finding of Consistency_hasbeenissued_fQr_thisproject----------- --------- NA-- _---_________--_-._,.___ __.-,--,_______----_-_,______---_________--.____- Engineering 18 Conductorstring_provided___________________________--_ -__---_,_ NA_- _-_--Conductorset_inoriginal-well, 1_B-15_(194_-051)._-__________-__.___._---______-_.-.___ 19 Surface casing_proteetsall_knownUSDWs_---_-.____.___-___ .----__ _ NA__ _--__-All aquifers exempted, 40CFR_147.102(b)~3).___ ______-___________-_._____-_-_.__ 20 CMT_vol_adequate-to circul_ate_on conductor& surf_csg . _ _ - - NA_ _ _ - - . _ -Surface casin set in 1B-15. g - - 21 CMT.v_ol_ adequate_to tie-in long string to_sun` csg_ - _ - - _ - - , _ - - - .. NA_ 7" csg not cemented into 9-518" csg, 5-1/2"liner fully cemented i_n 1 B-15A (204-256). - - _ 22 _C_MT_will coyer all known-productive horizons- _ - _ - - . _ - - . _ - - No_ . _ - - - Slotted liner completion planned, - - - 23 Casing designs adequate f_or C, T, B &_pe[mafrost - - - - - . - - - - - - - - - NA_ _ - _ - . Only slotted liner will be run_inchis-lateral, True casingstrings comply_with regulatiQns._ - - - - - 24 Adequate tan_kage_or reserve pit _ - , _ _ - - - - _ - .Yes Rig is-equipped with steel-pits.-No reserue_pitplanned, All waste to approved disposal wells.~ 25 If_a_re-drill, has-a-10-403 for abandonment been approved _ _ - - . NA_ - - _ 26 Adequate wellbore separationproposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes . _ _ _ _ - _ Proximity analysis performed. Close approaches identified.- All segments in reservoir. No collision issues.- - . - - 27 Ifdiverterrequired,doesitmeetregulations___________ __________ _________ NA__ ______BOf?stack_willalready_be.inplace,___-_---_.-_________-_______ -- Appr Date 28 Drilling fluid_prQgram schematic & equip list adequate- - - - - .. Yes Maximum expected formatipn pressure 13.3 EMW._ Plan to use dynamic overbalance and.10,0-peg mud.- - . TEM 7!29/2005 29 BOPEs,_do they meet regulation _ Yes . - - - - - - 2 hole u_olumes of kill_weight fluid-will be available on location for contin encles. - 9 t! ~ ~ (~ X ' , 30 _B_OPE,press rating appropriate; test to-(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ MASP caleulate_d up to 3740 psi.. 4000psi BOP_test planned, _ _ _ _ _ _ _ _ _ _ _ _ _ - 'r'~r' / u ( 31 Choke_manifoldcomp_liesw/API_RP-53(May84)____________________ ______.Yes__ ____,-.---,______ 32 Work willoccurwithoutoperationshutdown---.__________________ ________Yes__ ______,-____ 33 Is presence-of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - _ _ _ _ _ H2$ is repp[ted_at 1 B pad. Mud should preclude H2S on rig. _ Rig has_sensor& and -alarms.. _ _ - _ _ _ 34 Mechanical condition of wellswithiOAORverifed(Forse(vicewellonly)______ ________ NA___ __--_________-___-_--_____--_--__________----_--__-.---,___-_-,----_,_-_ Geology 35 Permit_ean be issued wlo hydrogen-sulfide measures _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ , - - - KRU 1B-15 mesuled_120 m H2S on 813012005_ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ Pp- - 36 Data_presented on_potential oyerpressur_e zones- _ _ - - _ _ - - - _ - . Yes - - - - - - Expected r_eservoirpressure is 13.3ppg EMW; will be drilled with-eoiled_tubing_and 10 ppgmud. - _ _ - - Appr Date 37 Seismic analysis-of shallpw gaszones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - _ _ _ _ _ using overbalanced pressure,drillingtechniques, SFl) - _ , _ _ _ _ _ _ _ _ _ _ - --------------------- SFD 7!28!2005 38 Seabed condition surYey-(if off-shore) . _ _ 39 Contact namelphone_for weekly progress-reports (exploratory only]- , - - _ - NA_ , Geologic Engineering P Co mmissioner: Da te: Commissioner: Date Com sio r Date RR g ~P~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History fife and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~J **** REEL HEADER **** MWD 06/12/02 BHI 01 LIS Customer Format Tape RECEIVED **** TAPE HEADER **** MWD 05/10/07 982397 01 2.375" CTK *** LIS COMMENT RECORD *** DEC 1 ~ 2006 AI~SkB ~ & V23 COti.4• CWgtIifSSIOfl !!!!!!!!!! !!!!!!!!! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8296.0000: Starting Depth STOP.FT 10033.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1B-15AL2PB2 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 19' 40.229" N 149 deg 35' 41.425"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 07-Oct-05 API API NYUMBER: 500292246571 Parameter Information Block #MNEM.UNIT Value Description --- - ----------------- SECT. ------- --- 09 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 95 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 95 Elevation of Kelly Bushinq EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~a~ =~c~' ~ ~~129~1 • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1B-15A through a milled window in 3 1/2" liner. Top of Window 8289 ft.MD (6214.1 ft.SSTVD) Bottom of Window 8296 ft.MD (6220.1 ft.SSTVD) (8) The interval from 10009 ft.to 10033 ft.MD (6412.6 ft. to 6413.1 ft.SSTVD) was not logged due to sensor bit offset at TD. (9) Tied to 1B-15A at 8208 ft.MD (6145.9 ft.SSTVD) (10) This wellbore 1B-15AL2PB2 was kicked off the wellbore 1B-15AL2PB1 at 8515 ft.MD (6349.13 ft. SSTVD) (11) The wellbore 1B-15AL2 was kicked off this wellbore 1B-15AL2PB2 at 9660 ft.MD (6430 ft.SSTVD) (12) The interval from 8510 ft. to 8593 ft.MD (6347.6 ft. to 6368.3 ft.SSTVD) was recorded in a mad pass. (13) The interval from 8510 ft. to 8618 ft.MD (6347.6 ft. to 6367.9 ft.SSTVD) ROP is not presented as ROP was not recorded when the Open Hole Sidetrack was Kicked off from the Plug Back. MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 72 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1B-15AL2PB2 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. • • WN 1B-15AL2PB2 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 42 Tape File Start Depth = 8296.000000 Tape File End Depth = 10033.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 51 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 • 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1B-15AL2PB2.xtf LCC 150 CN ConocoPhillips Alaska In WN 1B-15AL2PB2 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total Data Records: 84 1 Size Length 4 4 4 4 8 Tape File Start Depth = 8280.000000 Tape File End Depth = 10035.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** • Tape Subfile: 3 93 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/10/07 9$2397 O1 **** REEL TRAILER **** MWD 06/12/02 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LI5 • • Tape Subfile 2 is type: LIS DEPTH GR ROP 8296.0000 74.5900 -999.2500 8296.5000 81.8900 -999.2500 8300.0000 76.1200 -999.2500 8400.0000 114.5600 11.7200 8500.0000 49.2200 25.1300 8600.0000 134.8100 -999.2500 8700.0000 133.0100 31.2800 8800.0000 125.5800 48.2500 8900.0000 73.3100 76.9700 9000.0000 132.7600 59.2300 9100.0000 134.2900 40.6500 9200.0000 133.7800 30.3600 9300.0000 134.2900 13.4700 9400.0000 142.4900 22.6900 9500.0000 97.1400 97.4600 9600.0000 72.2800 54.2000 9700.0000 124.0400 53.3100 9800.0000 39.7400 3.8200 9900.0000 49.2200 63.1600 10000.0000 146.8500 17.2000 10033.0000 -999.2500 26.8000 Tape File Start Depth = 8296.000000 Tape File End Depth = 10033.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 8280.0000 54.6000 -999.2500 8280.2500 57.0350 -999.2500 8300.0000 76.1200 -999.2500 8400.0000 114.5600 11.7200 8500.0000 49.2200 25.1300 8600.0000 134.8100 -999.2500 8700.0000 133.0100 31.2800 8800.0000 125.5800 48.2500 8900.0000 73.3100 76.9700 9000.0000 132.7600 59.2300 9100.0000 134.2900 40.6500 9200.0000 133.7800 30.3600 9300.0000 134.2900 13.4700 9400.0000 142.4900 22.6900 9500.0000 97.1400 97.4600 9600.0000 72.2800 54.2000 9700.0000 124.0400 53.3100 9800.0000 39.7400 3.8200 9900.0000 49.2200 63.1600 10000.0000 146.8500 17.2000 10035.0000 -999.2500 -999.2500 Tape File Start Depth = 8280.000000 Tape File End Depth = 10035.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • ~ • Tape Subfile 4 is type: LIS L_J **** REEL HEADER **** MWD 06/12/02 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD OS/10/O1 982397 01 2.375" CTK *** LIS COMMENT RECORD *** • DECEIVED DEC ~ 5 2006 ~& ~ ~pR1t'AiSSK~ !!!!!!!!!! !!!!!!!!! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information 5TRT.FT 8296.0000: Starting Depth STOP.FT 9056.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1B-15AL2PB1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 19' 40.229" N 149 deg 35' 41.425"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: O1-Oct-05 API API NYUMBER: 500292246570 Parameter Information Block #MNEM.UNIT Value Description ----------------- -------------- SECT. 09 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 95 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 95 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks dos -rl5 ~ 11293 • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1B-15A through a milled window in 3 1/2" liner. Top of Window 8289 ft.MD (6214.1 ft.SSTVD) Bottom of Window 8296 ft.MD (6220.1 ft.SSTVD) (8) The interval from 9032 ft to 9056 ft.MD (6428 ft to 6434 ft.SSTVD) was not logged due to sensor bit offset at TD. (9) Tied to 1B-15A at 8208 ft.MD (6145.9 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MVJD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 63 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1B-15AL2PB1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1B-15AL2PB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP • ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 19 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 28 Minimum record length: 54 Maximum record length: 4124 **** FILE HEADER **** MWD .002 1024 8296.000000 9055.000000 0.500000 feet records... bytes bytes *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1B-15AL2PBl.xtf LCC 150 CN ConocoPhillips Alaska In WN 1B-15AL2PB1 FN Kuparuk River Unit • ~ • COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 37 Tape File Start Depth = 8280.000000 Tape File End Depth = 9055.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 46 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/10/01 982397 01 • • **** REEL TRAILER **** MWD 06/12102 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS ~ • Tape Subfile 2 is type: LIS DEPTH GR ROP 8296.0000 74.5900 -999.2500 8296.5000 81.8900 -999.2500 8300.0000 76.1200 -999.2500 8400.0000 114.5600 11.7200 8500.0000 49.2200 25.1300 8600.0000 96.3700 75.2200 8700.0000 128.4000 47.7900 8800.0000 125.8400 21.5300 8900.0000 148.1300 26.0000 9000.0000 146.5900 13.4100 9055.0000 -999.2500 13.4500 Tape File Start Depth = 8296.000000 Tape File End Depth = 9055.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 8280.0000 8280.2500 8300.0000 8400.0000 8500:0000 8600.0000 8700.0000 8800.0000 8900.0000 9000.0000 9055.0000 GRAX 54.6000 57.4175 76.1200 114.5600 49.2200 96.3700 128.4000 125.8400 148.1300 146.5900 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units ROP -999.2500 -999.2500 -999.2500 11.7200 25.1300 75.2200 47.7900 21.5300 26.0000 13.4100 13.4500 = 8280.000000 = 9055.000000 = 0.250000 = feet • • Tape Subfile 4 is type: LIS • • **** REEL HEADER **** MWD 06/12/01 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/10/13 RECENED DEC 1 5 2006 a Oil & Gas Goes • Commission Anchorage 982397 O1 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8296.0000: Starting Depth STOP.FT 10992.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1B-15AL2 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 19' 40.229" N 149 deg 35' 41.425"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 13-Oct-05 API API NYUMBER: 500292246561 ~ParamE>.ter Information Block #MNEM.LJNIT Value Description SECT. 09 Section TOWN.Af 11N Township RANG. l0E Range PDAT. MSL Permanent Datum EPD .F' 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 95 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 95 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~_~ is ~lY~~a • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1B-15A through a milled window in 3 1/2" liner. Top of Window 8289 ft.MD (6214.1 ft.SSTVD) Bottom of Window 8296 ft.MD (6220.1 ft.SSTVD) (8) The interval from 10968 ft.to 10992 ft.MD (6439.6 ft. to 6438.7 ft.SSTVD) was not logged due to sensor bit offset at TD. (9) Tied to 1B-15A at 8208 ft.MD (6145.9 ft.SSTVD) (10) This wellbore 1B-15AL2 was kicked off the wellbore 1B-15AL2PB2 at 9660 ft.MD (6430.0 ft.5STVD) (11) The wellbore 1B-15AL2PB2 was kicked off the wellbore 1B-15AL2PB1 at 8515 ft.MD (6349.13 ft.SSTVD) (12) The interval from 8510 ft. to 8593 ft.MD (6347.6 ft. to 6368.3 ft.SSTVD) was recorded in a mad pass. (13) The interval from 8510 ft. to 8618 ft.MD {6347.6 ft. to 6367.9 ft.SSTVD) ROP is not presented as ROP was not recorded when the Open Hole Sidetrack was Kicked off from the Plug Back. (14) The ROP data interval from 9166 ft. to 9174 ft.MD (6350.3 ft. to 6351.2 ft.SSTVD) was omitted due to the coil tubing elongation after the wiper trip. (15) The ROP data interval from 9401 ft. to 9405 ft.MD (6403.2 ft to 6404.4 ft.SSTVD) was omitted due to the coil tubing elongation after the wiper trip. (16) The interval from 9665 ft. to 9726 ft.MD (6429.7 ft. to 6427.6 ft.SSTVD} was recorded in a mad pass. (17) The interval from 9665 ft. to 9726 ft.MD (6429.7 ft. to 6427.6 ft.S5TVD} ROP is not presented due to ROP was not recorded when the Open Hole Sidetrack was kicked off from the Plug Back. (18) The ROP data interval from 9998 ft.to 10011 ft.MD (6433.7 ft.to 6433.9 ft.SSTVD) was omitted due to the coil tubing elongation after the wiper trip. (19) The ROP data interval from 10538 ft.to 10552 ft.MD (6451.9 ft.to 6451.8 ft.SSTVD) was omitted due to the coil tubing elongation after the wiper trip. (20) The ROP data interval from 10959 ft.to 10969 ft.MD (6439.9 ft.to 6439.5 ft.SSTVD) was omitted due to the coil tubing elongation after the wiper trip. MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 Minimum record length Maximum record length **** FILE HEADER **** MWD .001 1024 87 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1B-15AL2 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. wN 1B-15AL2 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** ?!!!!?!?!!!!!!????! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 • • 8 Total Data Records: 65 Tape File Start Depth = 8296.000000 Tape File End Depth = 10992.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 74 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1B-15AL2.xtf LCC 150 CN ConocoPhillips Alaska In WN 1B-15AL2 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 89 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 • • FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curv es: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 FjHR 4 4 8 Total Data Records: 130 Tape File Start Depth = 8280.000000 Tape File End Depth = 10992.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 139 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05110/13 982397 O1 **** REEL TRAILER **** MWD 06/12/01 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • • Tape Subfile 2 is type: LIS DEPTH GR ROP 8296.0000 74.5900 -999.2500 8296.5000 81.8900 -999.2500 8300.0000 76.1200 -999.2500 8400.0000 114.5600 11.7200 8500.0000 49.2200 25.1300 8600.0000 134.8100 -999.2500 8700.0000 133.0100 31.2800 8800.0000 125.5800 48.2500 8900.0000 73.3100 76.9700 9000.0000 132.7600 59.2300 9100.0000 134.2900 40.6500 9200.0000 133.7800 30.3600 9300.0000 134.2900 13.4700 9400.0000 142.4900 22.6900 9500.0000 97.1400 97.4600 9600.0000 72.2800 54.2000 9700.0000 86.3700 0.0000 9800.0000 45.8900 77.8500 9900.0000 67.4100 56.2700 10000.0000 41.0200 400.0000 10100.0000 37.4300 6.9600 10200.0000 66.1300 41.5500 10300.0000 116.8700 18.2800 10400.0000 50.7600 36.1000 10500.0000 105.0800 30.1400 10600.0000 55.6200 26.3400 10700.0000 123.7900 45.0600 10800.0000 68.4400 62.7200 10900.0000 57.1600 27.3800 10992.0000 -999.2500 -999.2500 Tape File Start Depth = 8296.000000 Tape File End Depth = 10992.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 8280.0000 54.6000 -999.2500 8280.2500 57.4175 -999.2500 8300.0000 76.1200 -999.2500 8400.0000 114.5600 11.7200 8500.0000 49.2200 25.1300 8600.0000 134.8100 0.0000 8700.0000 133.0100 31.2800 8800.0000 125.5800 48.2500 8900.0000 73.3100 76.9700 9000.0000 132.7600 59.2300 9100.0000 134.2900 40.6500 9200.0000 133.7800 30.3600 9300.0000 134.2900 13.4700 9400.0000 142.4900 22.6900 9500.0000 97.1400 97.4600 9600.0000 72.2800 54.2000 9700.0000 86.3700 0.0000 9800.0000 45.8900 77.8500 9900.0000 67.4100 56.2700 10000.0000 41.0200 400.0000 10100.0000 37.4300 6.9600 10200.0000 66.1300 41.5500 10300.0000 116.8700 18.2800 10400.0000 50.7600 36.1000 10500.0000 105.0800 30.1400 10600.0000 55.6200 26.3400 10700.0000 123.7900 45.0600 10800.0000 68.4400 62.7200 10900.0000 57.1600 27.3800 10992.0000 -999.2500 -999.2500 Tape File Start Depth = 8280.000000 Tape File End Depth = 10992.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • Tape Subfile 4 is type: LIS
