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Home My WebLink About203-084New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 /Image ~ _bject Well History File C\. )er 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. d. Q3 - ().B ~ Well History File Identifier Organizing (done) o Two-sided 111111111I111111111 D Rescan Needed I RESCAN DIGITAL DATA ~iskettes. No. ;)-. D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds: Scanning Preparation ~ x 30 = &(] D Other:: Date: '6' d3 0 S /s/ ty~ D Iru I .0 Date~ ~ð 05 151 ~VV\( , + 1 ~ = TOTAL PAGES I d- (Count does not ir elude cover st£et) "^ Af Date: 9' ~?t 05 151 V V ~ . I ul NOTES: BY: Helen ~ Project Proofing BY: Helen~ BY: Hele~ Maria ) Production Scanning Stage 1 Page Count from Scanned File: 7 ð (Count does include """ sheet) Page Count Matches Number in Scanning Preparation: V Y~S NO Hei~ Date:'ô J.Ò 0(:) /s/ m-.O If NO in stage 1 page(s) discrepancies were found: YES NO Bÿ: Stage 1 BY: Helen Maria Date: 151 II! 11111111111 11111 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned I BY: Helen Maria Date: 151 Comments about this file: Quality Checked 11I1111111111111111 • • --~._ ,~_ - l ~ ~ ~ 03/01/2008 DO NOT PLACE ,,:.. . "~ .. ,~, : - ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc K t:. \.."....1 V .... U . STATE OF ALASKA. U N 2006 ALASKA~IL AND GAS CONSERVATION COM~SION J 1 3 WELL COMPLETION OR RECOMPLETION REPORT AND LO~laska Oil & Gas Cons. Comnission Anchorage 1 a. Well Status: D Oil DGas D Plugged 181 Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/21/2006 203-084 306-124 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 05/30/2003 50- 029-20438-0 1-00 4a. Location of Well (Governmental Section): 7. Date TD. Reached 14. Well Name and Number: Surface: 06/03/2003 PBU C-16A 116' FNL, 1218' FEL, SEC. 19, T11 N, R14E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 758' FSL, 289' FEL, SEC. 18, T11N, R14E, UM 61.77' Prudhoe Bay Field 1 Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 288' FNL, 277' FEL, SEC. 19, T11N, R14E, UM 10266 + 8978 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 664130 y- 5961098 Zone- ASP4 10350 + 8973 Ft ADL 028305 TPI: x- 665037 y- 5961992 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 665075 y- 5960946 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes 181 No N/A MSL 1900' (Approx.) 21. Logs Run: MWD, DIR, GR, RES 22. (,;ASING, LINER AND (,;EMENTING KECORD //, !Š$¡~0 ,< " :«\ < /, GRÀDE( ··..SEB"INGDËP1'HMO .SETT1!\ißDEentT\(D I«;~?l~ ., .... 'c. . ..j/ '2/ !,/i/i 1(/:W~ë~6f, _. ", 101'< II:SOTTOM >IOPI:SOTTOM ., . ,,' 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 12.9 cu yds Concrete 13-3/8" 72# L-80 Surface 2691' Surface 2691' 17-1/2" 3720 cu ft Permafrost II 9-5/8" 47# L-80 Surface 8578' Surface 8278' 12-1/4" 1160 cu ft Class 'G', 130 cu ft AS 7" 26# L-80 2672' 8073' 2672' 7773' N/A Scab liner: 870 cu ft Class 'G' 7" 29# L-80 8073' 9040' 7773' 8740' 8-1/2" 401 cu ft Class 'G' 4-1/2" 12.6# L-80 8894' 10350' 8594' 8973' 6" 225 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and f24./,!·· /" _'i. '·fii/ifiiS/!/./'! ,',i ,/,i..iii Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 8905' 8848' MD TVD MD TVD 25,." '" (11::i1::-';";~' (jjG/GG' ,', .·_,G'·',-.··- i.-"/"/(/-G i/' ,P~''''·t '... ,< èS{i'/i' ,.x /! l·~f ,'- ." t:.'" DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ":_:, ¡,. .J... ~J ,,,,,u .... "","' 9440' Set CIBP 9425' Set Whipstock 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. OIL-BBL GAs-McF W A TER-BBL OIL GRAVITy-API (CORR) Press. 24-HoUR RATE 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 RBDMS 8FL JUN 1 5 2006 Form 10-407 Revised 12/2003 0 R \ G \ MfX'L ON REVERSE SIDE G 28. GEOLOGIC MARKER 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 23SB I Zone 2 9067' 8767' None 22TS I Zone 2 9142' 8840' 21TS 122N 9234' 8916' 14N 9378' 8984' 30. list of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date O~(¡a/O(p PBU C-16A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Sean McLaughlin, 564-4387 203-084 306-124 Permit No.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e C-16B Prudhoe Bay Unit 50-029-20438-02-00 206-051 Accept: Spud: Release: Ri: PRE-RIG WORK 01/10/06 DRIFT WI 3.5" DUMMY GUN TO 9113' SLM, STOPPED DUE TO DEVIATION, NO SAMPLE. RAN CALIPER FROM 9120' SLM TO SURFACE, GOOD DATA. 04/21/06 RIH W. 3.68" DWSTK DRIFT TUBING TO 9500', POOH RIH WI PDS MEMORY LOGGING TOOLS TO 9500'. LOG UP AT 40 FPM STOP AND FLAG PIPE AT 9300', CONTINUE TIE IN LOG TO 9000'. POOH WI GOOD GAMA DATA -22' CORRECTION. RIH WI WF CIBP TO FLAG STOP AND CORRECT CT DEPTH TO TOP OF CIBP. CONTINUE IN HOLE AND RUN PAST SETTING DEPTH 10'. PUH TO SETTING DEPTH OF 9440' (TOP OF CIBP). SET CIBP SET DOWN 3K AFTER RELEASING THEN TEST TUBING TO 1000 PSI FOR 5MIN. POOH AND FREEZE PROTECT WELL RD. JOB COMPLETE. 04/23/06 T/I/O = 01010 TESTED CASING PACKOFF TO 3000 PSI. PRESSURE WAS 2950 PSI AT 15 MIN. AND 2950 PSI AT 30 MIN. TEST PASSED. ALL LOCKDOWN SCREWS WERE FUNCTIONED. TESTED TUBING HANGER TO 5000 PSI. PRESSURE WAS 4900 PSI AT 15 MIN. AND 4850 PSI AT 30 MIN. TEST PASSED. ONE LOCKSCREW IS BACKED OUT (FLAGGED). THE REST OF THE LOCKSCREWS WERE FUNCTIONED AND RETORQUED TO 450 FT LBS. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date . 5/12/2006 5/13/2006 BP EXPLORATION Operations Summary Report Page 1 _ C-16 C-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 5/1 0/2006 5/21/2006 Spud Date: 5/11/1980 End: 5/21/2006 From - To Hours Task Code NPT Phase 17:30 - 18:00 0.50 RIGD P PRE 18:00 - 19:00 1.00 MOB P PRE 19:00 - 21 :00 2.00 MOB N WAIT PRE 21 :00 - 22:00 1.00 MOB P PRE 22:00 - 00:00 2.00 BOPSUF P PRE 00:00 - 05:00 5.00 BOPSUF P PRE 05:00-05:151 0.25 WHIP P WEXIT I 05: 15 - 05:30 0.25 WHIP P I WEXIT 05:30 - 07:00 1.50 WHIP P WEXIT 07:00 - 07:30 0.50 WHIP P WEXIT 07:30 - 07:45 0.25 WHIP P WEXIT 07:45 - 10:40 2.92 WHIP P WEXIT Description of Operations 12:00 - 14:00 Rig released from C-34A @ 22:00Hrs on 5/12/2006. Prep rig for move to C-16B. Move rig off C-34A, spot on upper side of pad Wait on site prep MIRU over C-16B, Accept Rig at 22:00 hours on 05/12/06 NU BOP's Grease tree valves & perform initial BOPE pressure & function test, while filling rig pits with double slick 120 deg KCL fluid. Spot, R/U hardline to tiger tank & PT to 4000psi, AOGCC test witness waived by Chuck Schevie Offload WS tools and equipment. PU to rig floor. SLB insert 2 RA pip tags into WFD LSXN 4-1/2" monobore whipstock. RA PIP tag to TOWS == 8.9'. Held pre-operations safety meeting. Reviewed well plan, potential hazards & WS setting BHA M/U procedures. M/U WS setting BHA #1 with WFD LSX-N 4-1/2" monobore whipstock, setting adapter, hyd setting tool, BKR FAIV, Sperry MWD/GR, orienter & WFD MHA. Scribe WS tray to MWD. Circ out MeOH from CT. Cut 5' of CT. Install WFD CTC & Pull test to 35k - OK. Pressure test inner reel valve & CTC to 3500psi - OK. Open up well & observe Opsi WHP. lAP == 63psi. OAP == 39psi. M/U injector & stab onto well. RIH WS setting BHA #1 taking MeOH FP returns to the tiger tank. SHT MWD @ 1500' & orienter @ 3000' with 1.6bpm/1150psi - OK. Wt check @ 9400' - Up == 39k, Run-in == 20k. RIH & lightly tag CIBP @ 9463'. P/U to up wt & correct CTD to 9940' (CTMD). PUH to 9170' for MWD tie-in. Log down from 9170' to 9213' @ 1.6bpm/1150psi & tie-into 04-Jun-03 Sperry-Sun MWD Log (which is -4' off depth from Geology PDC log). Add 3.5' to CTD. RBIH & position BOWS @ 9433.15' with TOWS @ 9420' & 4-1/2" Lnrcollars @ 9411' & 9452' (from 21-Apr-06 PDS MGR/CCL). Check TF - @ 145R. Survey @ 9397.91' gives 81.74degs inclination. Orient TF 1 click to 156R. Orient TF 1 more click to 161 R. Orient TF 1 more click to 173R. Circ @ 3.05/3.05bpm & 4350psi for 5mins to arm the FAIV. Drop pump to Obpm. Wait 5mins. Bring on pump to 1.6bpm, pressure up & shear off WS @ 1600psi (- lower shear pressure is due to different WFD setting adapter). Continue pumping & observe TF of 178R. Set down 10k & WS held. WEXIT Paint EOP flag @ 9300'. POOH with WS setting BHA#1 circ @ 0.9bpm/2oopsi. Paint EOP flag @ 9300'. Meanwhile bleed down the lAP from 1200psi to SOOpsi & OAP from 760psi to 55psi. OOH. PJSM. SIB injector. UD WS setting BHA #1. M/U window milling BHA #2 with a 3.80" WFD DWM, 3.80" HC DSR, WFD PDM, MHA & 2 jts of PH6 tbg (OAL - 83.79'). M/U injector. RIH window milling BHA #2. Wt check @ 8800' == Up - 34k, Run-in - 19k. Tag XN @ 8911'. P/U to up wt & correct CTD (-19') to "Schematic" depth of 8892'. Establish freespin @ 10:40 - 11 :20 0.67 WHIP P WEXIT 11 :20 - 11 :30 0.17 WHIP P WEXIT 11 :30 - 11 :40 0.17 WHIP P WEXIT 11 :40 - 12:00 0.33 WHIP P WEXIT 2.00 WHIP P 14:00 - 14:15 0.25 WHIP P WEXIT 14:15 - 14:40 0.42 STWHIP P WEXIT 14:40 - 16:15 1.58 STWHIP P WEXIT Printed: 5/2212006 11 :58:05 AM e e BP .EXPLORATION Operations Summary. Report Page 2 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 5/1 0/2006 5/21/2006 Spud Date: 5/11/1980 End: 5/21/2006 Date From - To Hours Task Code NPT Phase Description of Operations 5/13/2006 14:40-16:15 1.58 STWHIP P WEXIT 2.65bpm & 1300psi. 16:15 - 17:40 1.42 STWHIP P WEXIT Ease into milling from 8890' & mill thru XN nipple with 2.65bpm & 1550psi. Make few passes with & without pumping to ensure there are no restrictions/overpulls. Got back some gas to surface (suspect from behind tail pipe). 17:40 - 18:00 0.33 STWHIP P WEXIT Continue RIH BHA #2. Wt check @ 9350' - Up wt = 34k & Run-in wt = 19k. See EOP flag right on depth. Lightly tag WS/lnr pinch pt @ 9420.4'. PUH 15' & establish free spin @ 2.7bpm/1300psi. RBIH & ease in till motor work @ 9419.5. Flag pipe & start milling window with 1.5ppb bio-KCL fluid. 18:00 - 00:00 6.00 STWHIP P WEXIT Mill window fl 9420' - 9425' with 2.6/2.6bpm, 1490/1860psi, <1 k I WOB & 1fph ave ROP, Drill formation fl 9425' to 9430' with !2.62/2.62bPm, 1350/1769psi, <1k WOB & 9fph ave ROP 5/14/2006 00:00 - 00:30 0.50 STWHIP P WEXIT Drill formation fl 9425' to 9435' with 2.62/2.62bpm, ,1350/1769psi, <1k WOB & 9fph ave ROP 00:30 - 03:00 2.50 STWHIP P WEXIT I Dress off Window, Work thru window several times with . pumps, seeing mtr work of 40 psi at top of window 9421', I setting down with pumps off at 9421' 03:00 - 04:00 1.00 STWHIP P WEXIT Attempted to slide thru window w/o pumps, setting down at 19421', unable to pass thru window with pumps, mtr work I increased to 100 - 150psi, stalled once, worked thru window _ with pumps, mtr work of 150 psi fl 9421' to 9423', washed to 19435', no problems, still seeing 40 psi mtr work ream and I backreaming thru window at 9421' 04:00 - 06:00 2.00 STWHIP P WEXIT I Work thru window several times with pumps, seeing mtr work of 30-40 psi at top of window 9421', setting down with pumps off at 9421', roll pumps mill fall off, no problems RIH to btm once pasted trouble spot, consult with town engineer and wfd representative, displacing well to Flo-Pro Mud 06:00 - 06:30 0.50 STWHIP P WEXIT Passing thru window without the pumps sporadically continue to dress off window, displacing well to Flo-Pro Mud 06:30 - 07:20 0.83 STWHIP P WEXIT Backream/dress window/rat hole 3x & drift 2x. Window is clean on backreaming. On 1st down-drift, stacked wt @ +1-9423', roll pumps & pop into OH. On 2nd down-drift, RIH a bit faster @ 15fpm & run thru clean into OH. Suspect W/S is stacking the mill because it was set in a build curve and/or because it has some grind-off area on the ramp. Decide to POOH to P/U drilling BHA. Tentative window depths are: TOWSfTOW = 9420', BOW = 9425', RA PIP Tag = 9428.9'. 07:20 - 08:45 1.42 STWHIP P WEXIT Paint EOP flag @ 9300' & POOH window milling BHA #2, while displacing well to mud. 08:45 - 09:15 0.50 STWHIP P WEXIT OOH. PJSM. SIB injector. UD BHA #2 & inspect mills. Window mill & string mill gauge 3.79" go I 3.78" no-go. Wear on window mill face indicate mill center crossed the liner wall. 09: 15 - 09:30 0.25 DRILL P PROD1 Held pre-spud safety meeting. Reviewed well plan, potential hazards, drilling BHA M/U procedures & HNHM for cutting 150' of CT. 09:30 - 10:15 0.75 DRILL P PROD1 M/U drilling BHA #3 with 1.2deg X-treme motor, MWD/GR, orienter & used Hycalog 3-3/4" x 4-1/4" DS3611 M bicenter bit #2. Scribe tools & suspend in slips. 10:15 - 10:30 0.25 DRILL P PROD1 R/U hydraulic cutter & cut 150' of CT for fatigue management. Have 16350' of CT left on reel. 10:30 - 11 :00 0.50 DRILL P PROD1 Rehead & M/U SLB CTC. Pull test to 35k & pressure test to Printed: 5/2212006 11 :58:05 AM · , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date e e Page 3 _ BP EXPLORATION Operations Summary Report C-16 C-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Task Code NPT Phase 5/14/2006 10:30 - 11 :00 11 :00 - 12:40 12:40 - 13:20 13:20 - 13:30 13:30 - 13:35 : 5 - 14:30 18:15 - 18:20 18:20 - 18:30 18:30 - 18:35 18:35 - 18:40 18:40 - 18:55 18:55 - 21 :00 21 :00 - 22:30 22:30 - 23:00 23:00 - 23:15 5/15/2006 23:15 - 00:00 00:00 - 03:30 03:30 - 05:05 05:05 - 06:45 06:45 - 07:00 07:00 - 08:30 11:15-11:40 0.50 DRILL P 1.67 DRILL P 0.67 DRILL P 0.17 DRILL P 0.08 DRILL P 0.92 ILL P 0.17 DRILL P 0.33 DRILL P 3.25 DRILL P P P 0.25 DRILL 2.08 DRILL 1.50 DRILL P 0.50 DRILL P 0.25 DRILL P 0.75 DRILL 3.50 DRILL 1.58 DRILL N N N PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 1.00 DRILL N DPRB PROD1 1.75 DRILL N DPRB PROD1 0.42 DRILL N DPRB PROD1 Start: 5/10/2006 Rig Release: 5/21/2006 Rig Number: Spud Date: 5/11/1980 End: 5/21/2006 Description of Operations 3500psi - OK. M/U injector to BHA. RIH drilling BHA #3. SHT MWD @ 500' & orienter @ 3000' - OK. RIH to 9160'. Log down from 9160' to 9213' & tie-into Geology PDC log. Subtract 15' from CTD. RIH clean thru window with pumps down @ LS TF. Tag btm without pumps @ 9441'. Bring on pumps & establish frees pin @ 2.65bpm/3050psi. TF =179L. Up wt = 30k, Run-in wt = 18k. PVT = 281bbls. lAP = 680psi, OAP = 700psi. Orient TF 2 clicks to 155L. Begin drilling drop/build/turn section with 150L TF, 2.65/2.65bpm, 3050/3450psi, 3k WOB & 45fph aye ROP. Dril to 9469'. Saw RA PIP tag @ 9434'. Correct window depth s follows: TOWSfTOW = 9425' & BOW = 9430'. Drill to 9480' with 120L TF, 2.65/2.65bpm, 3050/34 WOB & 65fph aye ROP. Orient TF to 70L. Orient & drill to 9690' with 80-110L TF, 2. 2.65bpm, 3050/3450psi, 3k WOB & 95fph aye R . Meanwhile bleed down the lAP from 1000psi to 310 & OAP from 1000psi to 320psi. Orient TF to 40L. Drill to 9708' with 50L TF WOB & 135fph aye R Orient TF to 15L. Drill to 9735' wi 25L TF, 2.65/2.65bpm, 3050/3350psi, 3k WOB & 175 aye ROP. Orient TE 090R. Drill t 851' with 80R TF, 2.40/2.40bpm, 2800/3150psi, 3k W & 110fph aye ROP. OH to BHA POH w/ BHA, LD MWD-GR, mtr, and bit PJSM on PU and handling steerable Assy, discussed overlifting, new personnel to operations and good ommunication M bow tools, bit, MWD, Mtr, MHA and CTC Stab . RIH w/ Xbow steerable assy, tagged up at 9442' Made se ral attempts to work passed window without pumps, PU above w ow to 9375' 3X, performed 3 downlinks to Xbow tool to adjust p in different positions, after each downlink, shut down pumps, empted to RIH, unable to work past window POH to BHA #4 Held PJSM for UD SLB X-bd BHA. SIB injector. UD BHA#4. Check 't - had 2 chipped cutters on the face, grade 2/0/1 (must have ta up on TOWS). M/U drilling BHA #5 with 1.2degs X-tre motor, MWD/GRlRES, orienter & rerun Hycalog 4" RSX508SB1 PDC bit #4. Scribe tools & initialize resistivity I. M/U injector. RIH drilling BHA #5. SHT MWD @ 500' & oriente @ 3000' - OK. Wt check @ 9400' = Up - 38k, Run-in - 19k. C ck TF - @ 45L. SID pumps & RIH dry. Tag TOWS @ 9443'. Bring up pumps & confirm TF @ 45L. Orient TF around to Printed: 512212006 11 :58:05 AM Re: C-16A sundry 306-124 VJ '5 ... 0-14 Subject: Re: C-16A sundry 306-124 From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Tue, 02 May 2006 10:34:32 -0800 To: "Me hUn, S Sean.McLa lin@bp.com> CC: Dav Roby oby@admi ate.ak.us> Sean, Per 20 AAC 25.112 (i), AOGCC hereby approves alternate well plug placement in well PBU C-16A (PTD 203-084), as described below. All other sundry approval stipulations apply. Winton Aubert AOGCC 793-1231 McLaughlin, Sean M wrote: Winton, BP Exploration will be abandoning C-16A to sidetrack the well to a new bottom hole location. The top perforation in C-16A is at 9725' MD. BP would like to set a CIBP at 9440' and a whipstock at 9420'. The sidetrack will exit C-16A into the Ivishak (Zone 4). The primary cement job on C-16B will be brought to the top of the liner at 9380'. BP requests a waiver to 20 AAC 25.112(E) which states the following: (E) if the perforations are isolated from open hole below, a mechanical bridge plug set no more than 50 feet above the top of the perforated interval, and either a minimum of 75 feet of cement placed on top of the plug by the displacement method or a minimum of 25 feet of cement placed on top of the plug with a dump bailer. Regards, Sean Sean McLaughlin CTO Engineer 564-4387 Office 223-6784 Cell 564-5510 Fax ;.·f'&..~ii\.···f!:;t' ')V'~'\";'~f" ,r' 1. 1 of 1 5/2/2006 10:34 AM ~ { :0 . e (fùlT \ í7rE (ñl rE ' ~ ûL%u l!: JlJlF i e AI,ASIiA. OILAlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) PO Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 . "\i'>\\!':" , ;:;.{. ,/)}\\,-", ,,~;;:.... \J-W- ,,¡)\ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-16A Sundry Number: 306-124 'l.~ o<fi If ~Ov Dear Mr. McLaughlin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this.s- day of April, 2006 Encl. ,. ~t" lÆJq Æ- 4-/4-1 z..o D~ STATE OF ALASKA LJ/ðt RECEIVED ALASKA I. AND GAS CONSERVATION CO MISSION 1 2006 APPLICATION FOR SUNDRY APPROVAL MAR 3 20 AAC 25.280 Alaska Oil & Gas Cons. Commission . , 1. Type of Request: 181 Abandon o Suspend o Operation Shutdown o Perforate o Other o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development 0 Exploratory 203-084 / 3. Address: o Stratigraphic o Service 6. API Number: .' P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20438-01-00/' 7. KB Elevation (ft): 61.77' 9. Well Name and Number: PBU C-16A / 8. Property Designation: 10. Field / Pool(s): ADL 028305 Prudhoe Bay Field / Prudhoe Bay Pool 11« // ""'.,.i < ...../? ."/." ,X', .. .....' Total Depth MD (ft): Total Depth TVD (ft):1 Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10350 8973 10266 8978 None None Casinç¡ Lenç¡th Size MD / TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2691' 13-3/8" 2691' 2691' 4930 2670 Intermediate 8578' 9-5/8" 8578' 8278' 6870 4760 Production 5401' 7" 2672' - 8073' 2672' - 7773' 7240 5410 Liner 967' 7" 8073' - 9040' 7773' - 8740' 8160 7020 Liner 1456' 4-1/2" 8894' - 10350' 8594' - 8973' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: / Tubing Grade: I Tubing MD (ft): 9725' -10200' / 8984' - 8981' 4-1/2", 12.6# L-80 8905' Packers and SSSV Type: 7" x 4-1/2" BKR S-3 Perm Pkr Packers and SSSV MD (ft): 8848' / 12. Attachments: 13. Well Class after proposed work: / ~ Description Summary of Proposal 0 BOP Sketch o Exploratory ~ Development o Service o Detailed Operations Program 14. Estimated Date for May( ~06 15. Well Status after proposed work: Commencing Operations: OOil OGas o Plugged ~ Abandoned 16. Verbal Approval: Dare: o WAG OGINJ OWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name S~n MCLpu!1hJin Title CT Drilling Engineer ~ /l/~L[./L Date 3/~/o6 Prepared By Name/Number: Siç¡nature Phone 564-4387 Commission Use Only . Conditions of approval: Notify Commission so that a representative may witness I Sundry Number;~_ 1~4 , o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance othe, ApPYlßV U hH kA- 10 - 4-0 I V'7d t,,,. ç..;.,k 1Yt>--<.K- "..J2 /I C - lit, B . Subsequent Form Required: tDrn~ -r?:;Pr fhA COMMISSIONER APPROVED BY 1-5 -06 Approved By: THE COMMISSION Date Form 10-403 Revised 07/2005 tG\Ñt\r , Submit In Duplicate ":' .......~~ R8DMS ..~ OR 8fL APR 5 2006 ,) e e To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission Obp From: Sean McLaughlin CTD Engineer Date: March 27,2006 Re: C-16 Sundry Approval Sundry approval is requested for well C-16. The original well was a conventional ZlB/Z2A producer drilled in 1980. The well produced as a cycle well with GORs often above marginal up until 1998. A casing leak was discovered when cretaceous water appeared in a produced fluid sample in January /'- 1998. The well passed an MIT-T, but failed an MIT-IA. The well was shut-in due to the cretaceous leak. A rig work-over to fix the cretaceous leak was not recommended due to the high GOR expected upon re-completion and the competition with offset replacement wells C-42 and C-36A. In order to return the wellbore to production and establish wellbore integrity, a RST was completed in June of 2003. Initial well test rates were good. However, the well reached MGOR in 4 months and began to cycle. There was only about seven feet of standoff from the GOC when the well was drilled, which explains the initial strong production and the high gas rate. The well reached 50mmscfd within 3 months of producing and has remained high for the life of the well. C-16A has experienced multiple extended shut-in periods due to ann-com in the past. High IA pressure was noted in 2004 and was resolved when the GLVs were dummied in May. When the well was finally brought on-line in December, it healed to 30,000 GOR, but returned to 50,000 GOR in weeks. This past year, C-16A was shut-in for 4 months while a sheared IA valve was replaced and again returned to marginal immediately. REASON FOR SIDETRACK: For the last two years the well has been cycling with decreasing on-time, The well was shut-in for seven months in 2004 and 4 months in 2005, but the well returned to marginal immediately. During recent cycles, the well started at a GOR near 30k and quickly increased to 60k within a few days of coming online. Due to the low remaining value and lack of wellwork options available for C-16A, it is recommended that this well be sidetracked to access deeper Z 1 B reserves and utilize the wellbore. The sidetrack is planned on or around June 1. 2006. The sidetrack, C- 147m exit the existing 4-112" liner and kick off and land in zone ZlA. The existing perforations wi~s~lated by a CIBP and the / primary cement job. The following describes work planned and is submitted as an attachment to FOnTI 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: 1. 0 AC-LDS; AC-PPPOT-IC, T 2. S Caliper liner and tubing 3. S Set DGLV's 4. 0 MIT-IA and MIT-OA / 5. C Run dummy whipstock drift 6. C Run MGR/CCL tie in log 7. C Set CIBP at 9435' 8. 0 Bleed gas lift and production flowlines down to zero and blind flange 9. 0 Remove wellhouse, level pad The pre CTD work is slated to begin on May 1, 2006. T\..À. S lO - 4-0 s ~)f Y\N-vL e e Rig Work: / 1. MIRU and test BOPE to 250 psi low and }5ÜO)~si high. 2. Set Wfd LSX whipstock at 9420' (// 3. Mill XN nipple, 3.8" window at 9420', a~¿flO' of rat hole. Swap the well to Flo-Pro. 4. Drill Lateral: 4.125" OH, 2205' horizontal (12 deg/l00 planned), with resistivity 5. MAD pass with resistivity tools in memory mode 6. Run 3-3/16" 2-7/8" solid liner leaving TOL at 9380' 7. Pump primary cement leaving TOC at 9380', 24 bbl of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL/GR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions (~600') 11. Freeze protect well, RDMO Post-Rig Work: 1. Move wellhouse, Install production flowline 2. RunGLVs 3. Flowback well to separator Sean McLaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE = . WELLHEAD = ACTUA TOR = KB. ELBI = BF. ELBI = KOP= Max Angle = Datum MD = Datum lVD = 6" FMC FMC OTIS 63.70' 37.01' 2900' 97 @ 9500' 9167' 8800' SS e C-16A / I þNOTES: 2197' -1 4-112" HES X NIP, ID = 3.813" I I TOP OF 7" SCAB LNR I 2672' 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2673' -J 9-5/8" X 7" BKR ZXP LNR TOP PKR I GAS LIFT MANDRELS ST MD lVD OBI TYPE VLV LATCH PORT DATE 4 3887 3847 25 KBG-2 DMY BK 0 05/10/04 3 6393 6097 9 KBG-2 DMY BK 0 06/07/03 2 7925 7625 0 KBG-2 DMY BK 0 06/07/03 1 8761 8461 2 KBG-2 DMY BK 0 06/07/03 Minimum ID = 3.725" @ 8892' 4-1/2" HES XN NIPPLE I 7" LNR, 26#, L-80, .0383 bpf, ID = 6276" I 8073' 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8578' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 9475' 4-1/2"HESXNIP, 10=3.813" I 7" X 4-112" BKR S-3 PERM PKR. ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" I 4-1/2" HES XN NIP, ID = 3.725" I 4-1/2" WLEG, ID = 3.958" I 7" X 5" BKR ZXP LNR TOP PKR 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I TOP OF WHIPSTOCK I EZSV BRIDGE PLUG 8904' I MILLOUT WINDOW 9040' - 9062' PERFORA TION SUMMARY REF LOG: MWD GR ON OS/26/03 ANGLEATTOPPERF: 90@ 9725' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-7/8" 4 9725 - 9775 0 06/05/03 2-7/8" 4 9950 - 10200 0 06/05/03 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" DATE 06/12/80 06/07/03 06/19/03 09/15/03 05/10/04 RBI BY COMMENTS ORIGINAL COM PLETION DAV/KK RIG SIDETRACK (C-16A) JCrvvTLH GL V ClO CMO/TLP DATUM MD & REF LOG KSB/KAK GLV ClO DATE RBI BY COMMENTS PRUDHOE BAY UNrT WELL: C-16A PERMrT No: 2030840 API No: 50-029-20438-01 SEC 19, T11N, R14E;·-115.96' FNL & 1218.02' FEL BP Exploration (Alaska) , I Date: To: From: Subject: e - April 3, 2006 File,/:2-Ot~ Jane Williamso~ ,; ,ç~ Prudhoe C-16A BP has requested approval to plug-back Prudhoe C-16A in preparation for a rig sidetrack. The well is completed in Zone IB and 2A. The well has a casing leak in the Cretaceous and has also been on cyclic production due to high GOR. The sidetrack will access the same zone as the original (with standoff from the gas). I recommend approval ofthis sundry. OFM is not working right now so I can't provide production or decline curves. 8892' PERFORATION SUMMA RY REF LOG: MoNO 05/26/03 ANGLEAT TOP f'ERF: 90 to Prod 7 JU\J") ~~ ~)- DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030840 Well Name/No. PRUDHOE BAY UNIT C-16A Operator BP EXPLORATION (ALASKA) INC .ç~~¿ ~~ 1'1,.<~) API No. 50-029-20438-01-00 MD 10350/ ~'. /' Completion Date 617/2003 r Completion Status TVD 8973 -- -- - -- ---------------- - - --- ---- - ----- -~._- REQUIRED INFORMATION Mud Log No Samples No --- -- ---------- DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name í Rpt- D Asc Directional Survey ED D 11811 LIS Verification ED D 11810 LIS Verification Rpt Directional Survey Rpt D Asc Directional Survey i Rpt LIS Verification : Rpt Directional Survey : Rpt D LIS Verification Log Log Run Scale Media No final 3 2 final 2 3 "- ---~-- -- -- -- Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~. Daily History Received? Formation Tops Analysis Received? ~. __"__ _0__- __ --~---- Comments: 1-01L Current Status 1-01L UIC N Directior€u~ey y;:) -------.., (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received Comments 9002 9879 Open 7/1/2003 PB1 8811 10291 Open 7/24/2003 8811 9820 Open 7/24/2003 PB1 9687 1 0350 Open 7/1/2003 9002 9879 Open 7/1/2003 PB 1-MWD 8811 9820 Open 7/24/2003 PB1 9687 1 0350 Open 7/1/2003 PB1-MWD 8811 10291 Open 7/24/2003 Sample Set Number Comments ---' ~ ŒJN DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030840 Well Name/No. PRUDHOE BAY UNIT C-16A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20438-01-00 MD 10350 TVD 8973 Completion Date 617/2003 Completion Status 1-01L Current Status 1-01L UIC N -. ----- --------- ~ Date: (j ì J).;)~r ---- .-- ------ ---- Compliance Reviewed By: -~~- ~ 1 1:;fJ?lp - e ) ) 1-b3 -Dßtf \ 'Bll WELL LOG TRANSMI'ITAL To: State of Alaska Alaska Oil and Gas Conservation Connn. Attn.: Howard Okland 33 3 West 7th Avenue, Suite 100 Anchorage, Alaska JUly 18, 2003 RE: MWD Formation Evaluation Logs C-16A, AK-MW -2461818 1 LDWG fotmattedDisc with verification listing. API#: 50-029-20438-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAl, LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. AnRECÊ,~B8 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 JUL 24 2003 Date: Alaska O¡.¡ & Gas Cons. Commission Anchorage Signed: ~~ ~I ) ') .1-Ð::' "08Lt \ \ ~IO WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Camm. Attn.: Howard Okland 33 3 West 7th Avenue, Suite 100 Anchorage, Alaska July 18, 2003 RE: MWD Formation Evaluation Logs C-16A PBl, AK-MW-2461818 1 LDWG formatted Disc with verification listing. API#: 50-029-20438-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atln: Rob Kalish 6900 Arctic Blvd. AnchoReeef'1~D BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 JUL 24 2003 ~ D~a œ & Gas Cons. CommisaionSigned:("\. ~ c..... Mœ~ 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ') 1. Status of Well ŒI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 203-084 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20438-01 4. Location of well at surface 9. Unit or Lease Name 116' SNL, 1218' WEL, SEC. 19, T11 N, R14E, UM X = 664130, Y = 5961098 Prudhoe Bay Unit At top of productive interval 7581 NSL, 2891 WEL, SEC. 18, T11 N, R14E, UM X = 665037, Y = 5961992 10. Well Number At total depth 2881 SNL, 271' WEL, SEC. 19, T11 N, R14E, UM X = 665075, Y = 5960946 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 61.77' ADL 028305 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5/30/2003 6/3/2003 6/7/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10350 8973 FT 10266 8978 FT ŒI Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES Classification of Service Well C-16A 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2191' MD 19001 (Approx.) 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 20" X 30" Insulated Conductor Surface 1101 36" 13-3/8" 72# L-80 Surface 26911 17-1/2" 9-5/8" 47# L-80 Surface 85781 12-1/4" 1" 26# L-80 26721 8073' 7" 29# L-80 8073' 9040' 4-1/2" 12.6# L-80 8894' 103501 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) CEMENTING RECORD 12.9 cu yds Concrete 3720 cu ft Permafrost II 1160 cu ft Class IG', 130 cu ft Arcticset Scab Liner: 870 cu ft Class 'G' 401 cu ft Class IG' 225 cu ft Class IGI AMOUNT PUllED 8-1/2" 6" 25. 2-7/8" Gun Diameter, 4spf MD TVD 9725' - 9775' 8984' - 8985' 9950' - 10200' 8981' - 8980' SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 8905' PACKER SET (MD) 8848' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 20, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl 6/29/2003 4 TEST PERIOD 3,397 34,397 160 Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-BBl Press. 654 24-HoUR RATE CHOKE SIZE 65° GAS-Oil RATIO 10,125 Oil GRAVITY-API (CORR) 27.1 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit co,~~~(:: E, r· '\.; No core samples were taken. ~---¿¿~~;i~Ci~ I~~,~¡i ~r~~; . h t.,- ¡ .-..2 ¡ \j~jf¿D ! :._:~~~._~._-..J MDMS BFL GI~ l 2 'l 0),(\ n!) J U L 1 U ) fì in JU " ,. nn)·J tì~ 1 a s I~ :'\. :I:!, ~-~ Form 10-407 Rev. 07-01-80 OR\G\NAL Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 23S8 I Zone 2 9067' 8767' 22TS / Zone 2 9142' 8840' 21TS /22N 9234' 8916' 14N 9378' 8984' JLJL -~ 0 ?IJ03 31. List of Attachments: Summary of Daily Drilling Reports, Surveys ~2. I ~erebY certify that the for~oin~ is true and correct to the best of my knowledge Signed Terrie Hubble ~~}JU.J .J ~~ Title Technical Assistant Date 07 -ò9-Q.,3 C-16A 203-084 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number N Drilling Engineer: Phil Smith, 564-4897 Permit o. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the p~oducing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 nR'G\NAL Legal Name: C-16 Common Name: C-16A Test Date 5/26/2003 5/29/2003 FIT FIT Test Type Test Depth (TMD) 9,054.0 (ft) 9,040.0 (ft) BPEXPLQRATION Leak-OffTestSul111118ry Test Depth · (TVD) 8,754.0 (ft) 8,740.0 (ft) AMW 8AO (ppg) 8AO (ppg) Surface Pressure 910 (psi) 960 (psi) Leak OffPrE!ssÜre (BHP) 4,730 (psi) 4,774 (psi) EMW 10AO (ppg) 10.51 (ppg) _/ ---- Printed: 6/9/2003 11 :54:48 AM ) ) J Bp·EXPLORATION Operations ·Summary.Report Pagè1 of11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/18/2003 12:00 - 22:00 10.00 RIGU P PRE Move rig and associated equipment from well C-23B to C-16A 22:00 - 22:30 0.50 RIGU P PRE Rig accepted at 22:00 hrs. Pre-spud and enviromental meeting with crew. 22:30 - 00:00 1.50 BOPSUR P PRE Install second annular valve, bleed gas (300 psi) from annulas. 5/19/2003 00:00 - 01 :00 1.00 KILL P DECOMP Bleed gas from annulus from 300 psi to 150 psi. Recover 10 bbl fluid. 01 :00 - 02:00 1.00 WHSUR P DECOMP Rig up lubricator. Pull two-way check. 100 psi tubing pressure. Rig down lubricator. 02:00 - 08:00 6.00 KILL P DECOMP Rig up lines to well and test to 3500 psi. Kill well through choke. Pump 250 bbl sea water down tubing at 3 BPM with 400 psi. Mix and pump 45 bbl sea water with 55 gal Condent. Displace well to 9.6 ppg brine. Well taking fluid. 08:00 - 09:30 1.50 KILL P DECOMP Mix and spot LCM pill with 32 PPB LCM. Squeeze away 17 bbl at 170 psi. 09:30 - 10:30 1.00 KILL P DECOMP Circulate clean 9.6 ppg brine to surface. 10:30 -11:00 0.50 WHSUR P DECOMP Install back pressure valve and confirm set with 200 psi from below. 11 :00 - 12:30 1.50 WHSUR P DECOMP Nipple down tree and adapter flange. 12:30 - 14:00 1.50 BOPSUR P DECOMP Nipple up BOP. 14:00 - 15:30 1.50 BOPSURP DECOMP Change top rams to 7". 15:30 - 18:30 3.00 BOPSURP DECOMP Test BOP and associated equipment to 250 psi low and 3500 psi high. Witnessing of BOP test waived by AOGCC rep John Crisp. 18:30 - 19:30 1.00 WHSUR P DECOMP Rig up lubricator and pull two way check. Rig down lubricator. 19:30 - 20:00 0.50 WHSUR P DECOMP Back out tubing hanger lock-down screws. 20:00 - 21 :00 1.00 PULL P DECOMP Pull tubing hanger to floor. No over pull (125K). Lay down hanger and pup joints. Well taking fluid at 64 bbl/ hr. 21 :00 - 22:30 1.50 PULL P DECOMP Change handling equipment. Rig up control line spooler. Mix a 50 bbl LCM pill at 50 PPB of LCM. 22:30 - 23:00 0.50 PULL P DECOMP Pump 50 bbl LCM pill and displace to cut tubing at 7980'. Observe well, taking fluid at 15 bbl/ hr. 23:00 - 00:00 1.00 PULL P DECOMP POH. Lay down 41/2" tubing. 5/20/2003 00:00 - 02:00 2.00 PULL P DECOMP POH. Lay down 4 1/2" tubing. Recovered control line, 26 clamps and 5 stainless steel bands. Fluid lost to the well 15 bbl/ hr. 02:00 - 02:30 0.50 PULL P DECOMP Change out handling equipment. Rig down control line spooler. 02:30 - 07:00 4.50 PULL P DECOMP POH. Lay down 3 1/2" tubing. Recovered 187 joints, 5 GLM, 3 pup joints and 11.4' cut off. 07:00 - 08:00 1.00 PULL P DECOMP Rig down 3 1/2" handling equipment. Clear floor. 08:00 - 08:30 0.50 PULL P DECOMP Install wear bushing. 08:30 - 10:00 1.50 PULL P DECOMP Pick up fishing BHA, 9 x 6 1/4" DC, oil jars and bumper sub with 8 1/2" Overshot dressed with 3 1/2" grapple. 10:00 - 13:30 3.50 PULL P DECOMP RIH with fishing BHA. Pick up 159 joints 4" drill pipe. 13:30 - 14:30 1.00 PULL P DECOMP RIH with fishing BHA with stands to 7902'. 14:30 -15:30 1.00 FISH P DECOMP Wash down to top of fish at 7978'. Engage fish and pull free with 75K over pull. Monitor well, fluid loss at 5 bbl/ hr. 15:30 - 19:00 3.50 PULL P DECOMP POH to fishing BHA. 19:00 - 19:30 0.50 PULL P DECOMP Stand back BHA. 19:30 - 20:30 1.00 PULL P DECOMP Lay down fish. Cut off joint, 1 pup joint and seal assembly. 20:30 - 21 :30 1.00 PULL P DECOMP Clear floor. Lay down 8 1/2" overshot, pick up spear with 4" grappel. 21 :30 - 22:00 0.50 PULL P DECOMP RIH fishing BHA and spear. Printed: 6/9/2003 11 :54:55 AM ) ) BP EXPLORATION Operatio nsSu m 111 a ry Report Page 2of11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/20/2003 22:00 - 00:00 2.00 PULL P DECaMP RIH with fishing BHA on 4" drill pipe. 5/21/2003 00:00 - 00:30 0.50 PULL P DECaMP RIH with 4" spear fishing BHA on 4" drill pipe to 7963'. 00:30 - 01 :30 1.00 PULL P DECaMP Slip and cut 99' drilling line. 01 :30 - 02:30 1.00 PULL P DECaMP Service top drive. Inspect top drive and derrick due to jarring. 02:30 - 04:00 1.50 FISH P DECaMP Engage fish with spear at 8006'. Jar on fish with 350K. String came loose with 5K additional weight. 04:00 - 05:00 1.00 PULL P DECaMP Circulate bottoms up at 10 BPM. Gas at surface with bottoms up. 05:00 - 09:00 4.00 PULL P DECaMP POH to fishing BHA. 09:00 - 10:00 1.00 PULL P DECaMP Stand back BHA. 10:00 - 11 :00 1.00 PULL P DECaMP Attempt to release spear from fish. Lay down same. Recovered 19.91' of PBR with scoop guide. 11:00-12:00 1.00 PULL P DECaMP Make up 8 1/16" Short Catch overshot dressed with 4 1 /2" grapple, bumper sub and jars. 12:00 - 13:30 1.50 PULL P DECaMP RIH with fishing BHA. 13:30 - 16:30 3.00 PULL P DECaMP RIH to 8013'. Up weight 190K, down 145K. 16:30 - 18:00 1.50 FISH P DECaMP Wash over fish from 8013' to 8023' and engage fish. Work fish with 35K over-pull. Overshot slipping off of fish. Made several attempts. 18:00 - 19:00 1.00 PULL P DECaMP Circulate around 40 bbl high vis sweep at 12 BPM. 19:00 - 20:00 1.00 FISH P DECaMP Rig up Schlumberger Eline. 20:00 - 22:00 2.00 FISH P DECaMP RIH with 2 1/8" tubing punch. Shoot 9 holes in tubing below packer at 8034' to 8036'. 22:00 - 22:30 0.50 FISH P DECaMP Lay down tubing punch. Make up 14' x 1.7" 00 string shot. 22:30 - 00:00 1.50 FISH P DECaMP Run string shot and fire across 14' inteval (8035' to 8049'). POH with string shot. Gas in string, drill pipe pressure 250 psi. 5/22/2003 00:00 - 06:30 6.50 KILL N DPRB DECaMP Lubricate 9.6 ppg brine down drill pipe and bleed off gas. Drill pipe x 9 5/8" casing annulus static. Lubricate a total of 23 bbl 9.6 ppg brine into drll pipe with a final pressure of 790 psi. Shut in well. 06:30 - 08:30 2.00 KILL N DPRB DECaMP Change out to long bales to attempt picking up drill pipe. Secure Eline with clamp at pack-off. Remove Eline sheave from blocks. Gas to surface in drill pipe and leaking through the Eline pack-off. 08:30 - 09:30 1.00 KILL N DPRB DECaMP Shut-in perssure increased to 1150 psi. Start pumping down drill pipe. At 1530 psi annulus flowing. Continue circulating down drill pipe and up annulus at 72 SPM with 220 psi until gas to surface. 09:30 - 11 :30 2.00 KILL N DPRB DECaMP Shut well in. Kill well through choke with 9.6 ppg brine. Drill pipe and annulus dead. Lost 13 bbl to formation. 11 :30 - 12:00 0.50 KILL N DPRB DECaMP Observe well. Static. 12:00 - 15:00 3.00 KILL N DPRB DECaMP Circulate 9.6 ppg brine at 3 BPM with 256 psi. Monitor well. Static. 15:00 - 18:00 3.00 PULL N DPRB DECaMP Rig down Eline unit. 18:00 -18:30 0.50 FISH P DECaMP Engage fish at 8023'. Pick up to 20K over-pull. 18:30 - 19:30 1.00 FISH P DECaMP Rig up Schlumberger Eline. 19:30 - 20:00 0.50 PULL P DECaMP PJSM with rig and Schlumberger crews. Pick up 2 3/8" chemical cutter. 20:00 - 22:00 2.00 PULL P DECaMP Run CCL and 2 3/8" chemical cutter. Cut tubing at 8046'. POH with cutter. 22:00 - 22:30 0.50 PULL P DECaMP PJSM. Lay down fired chemical cutter. 22:30 - 23:00 0.50 PULL P DECaMP Rig down Schlumberger Eline unit. Printed: 6/9/2003 11 :54:55 AM ) ) BPEXPLORATION Operations Summary Report Page 3 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From - To HoUrs Task Code NPT Phase Description of Operations 5/22/2003 23:00 - 00:00 1.00 PULL P DECaMP Change to short bales. Attempt to engage fish, overshot slipping off fish at 20K over pull. 5/23/2003 00:00 - 04:00 4.00 PULL P DECaMP POH to fishing BHA. 04:00 - 04:30 0.50 PULL P DECaMP POH with overshot BHA. No recovery. Lay down overshot. 04:30 - 05:00 0.50 PULL P DECaMP Make up 3" fishing spear. 05:00 - 05:30 0.50 PULL P DECaMP RIH with fishing BHA. 05:30 - 08:00 2.50 PULL P DECaMP RIH with fishing BHA on 4" drill pipe to 8023'. Up weight 190K, down 145K. 08:00 - 09:00 1.00 FISH P DECaMP Engage fish with spear at 8023'. Jar on fish, pull free with 300K overpull. String weight increase by an additional 15K. 09:00 - 10:30 1.50 FISH P DECaMP Circulate bottoms up at 6 BPM with 3340 psi. Monitor well, static. 10:30 - 11 :30 1.00 PULL P DECaMP Inspect top drive and derrick after jarring operations. 11 :30 - 15:30 4.00 PULL P DECaMP POH with fish to BHA. 15:30 - 16:30 1.00 PULL P DECaMP POH with BHA. 16:30 - 17:00 0.50 PULL P DECaMP Lay down production packer fish and 3" fishing spear. Land 3 1/2 tubing in slips Tubing still attached at chemical cut section on production packer tail pipe. Chemical cut incomplete, 2" section uncut. 17:00 - 17:30 0.50 PULL P DECaMP Rig up 3 1/2" handling equipument. 17:30 - 19:00 1.50 PULL P DECaMP POH. Lay down 3 1/2" tubing. Recover 36 joints and 14' cut-off section. 19:00 - 20:00 1.00 PULL P DECaMP Rig down 3 1/2" handling equipment and clear floor. 20:00 - 20:30 0.50 PULL P DECaMP Rig up Schlumberger Eline unit. 20:30 - 22:30 2.00 PULL P DECaMP Run 6.059" gauge ring and junk basket to top of 31/2" tubing stub at 9116'. POH. Lay down junk basket. 22:30 - 00:00 1.50 PULL P DECaMP Make up 7" EZSV bridge plug and RIH on Eline. 5/24/2003 00:00 - 02:00 2.00 PULL P DECaMP Run 7" EZSV bridge plug on Eline. Locate casing collar at 9058', set bridge plug at 9054'. POH Eline. 02:00 - 02:30 0.50 PULL P DECaMP Rig down Schlumberger Eline unit. 02:30 - 03:00 0.50 STWHIP P DECaMP Make up "RTTS" test packer. 03:00 - 04:00 1.00 STWHIP P DECaMP RIH with RTTS test packer on 4" drill pipe to 2804'. 04:00 - 05:00 1.00 STWHIP P DECaMP PJSM with crew and Halliburton rep. Test 9 5/8" casing to 3500 psi for 30 minutes. Bleed off pressure. Unset test packer. 05:00 - 06:00 1.00 STWHIP P DECaMP POH with RTTS test packer and lay down same. 06:00 - 07:30 1.50 STWHIP P DECaMP Make up Baker 7.41" aD fluted polishing mill and BHA. 07:30 - 10:00 2.50 STWHIP P DECaMP RIH with polishing mill to 8073' top of 7" liner. 10:00 - 11 :00 1.00 STWHIP P DECaMP Polish 7" liner top tie back sleeve (PBR) from 8073' to 8080'. Set down 1 OK while rotating. Pressure increase from 220 psi to 440 psi. 11 :00 - 13:30 2.50 STWHIP P DECaMP POH to milling BHA. 13:30 - 16:00 2.50 STWHIP P DECaMP Lay down 6 1/4" drill collars, jars and polishing mill. No indication of top of liner on brass no-go 5.97' from base of polishing mill. 16:00 - 16:30 0.50 STWHIP P DECaMP Make up Baker 7.5" seal assembly. 16:30 - 19:30 3.00 STWHIP P DECaMP RIH with seal assembly on 4" drill pipe to 8073' 19:30 - 20:30 1.00 STWHIP P DECaMP Tag up on top of liner at 8073'. Work seal on top of liner, rotate and set down weight, unable to enter PBR. 20:30 - 21 :30 1.00 STWHIP P DECaMP Pick up above liner top. Slip and cut 100' drilling line. 21 :30 - 22:00 0.50 STWHIP P DECaMP Service top drive. 22:00 - 00:00 2.00 STWHIP P DECaMP POH with seal assembly. 5/25/2003 00:00 - 00:30 0.50 STWHIP P DECaMP POH with seal assembly and lay down same. Marks on seal Printed: 6/9/2003 11 :54:55 AM ) ') BP EXPLORATION Operations Summary Report Page 4 of11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From - To Hours Task Code NPT Phase Descri ption . of Operations 5/25/2003 00:00 - 00:30 0.50 STWHIP P DECaMP body indicating tool was on top of PBR but unable to enter. 00:30 - 01 :30 1.00 CASE P TIEB1 Rig up Schlumberger Eline unit. 01 :30 - 03:00 1.50 CASE P TIEB1 Run and set 7" EZSV bridge plug at 8088' on Eline. POH. 03:00 - 03:30 0.50 CASE P TIEB1 Rig down Schlumberger unit. 03:30 - 04:30 1.00 CASE P TIEB1 Rig up to run 7" casing. 04:30 - 05:00 0.50 CASE P TIEB1 Run 7" 26# L-80 BTC-M liner. Make up mule shoe pup joint, float collar and insert landing coller. Check float. 05:00 - 10:00 5.00 CASE P TIEB1 Run 130 joints 7" 26# L-80 BTC-M liner. Install centralizers as per program. Fill liner every 10 joints. 10:00 - 10:30 0.50 CASE P TIEB1 Make up Baker Flex-Lock Hydraulic liner hanger with ZXP liner top packer and tie-back sleeve. Pick up weight 155K down 145K. Rig down liner running equipment. 10:30 - 11 :00 0.50 CASE P TIEB1 Circulate one liner volume at 7 BPM with 300 psi. 11 :00 - 12:30 1.50 CASE P TIEB1 RIH with 7" liner on 4" drill pipe to 8073'. Fill pipe every 10 stands. 12:30 - 13:00 0.50 CASE P TIEB1 Make up cementing head and lines. Break circulation at 4 BPM with 450 psi. 13:00 - 15:30 2.50 CEMT P TIEB1 PJSM. Prime cement pumps. Pump 5 bbl water and test lines to 4,500 psi. Pump 10 bbl water. Pump 10 bbl Mud-Pushat 10.5 ppg. Mix and pump 100 bbl (312 sx) 13.5 ppg 'G' cement lead slurry. Mix and pump 55 bbl (266) sx) 15.8 ppg 'G' cement tail slurry. Wash lines. Drop dart. Displace with 9.6 ppg brine with cementing unit at 7 BPM. Total displacement 233 bbl. Bump plug with 2900 psi. Increase perssure to 4200 psi to set the hanger. Bleed and check floats. O.K. CIP at 15:18 hours. 15:30 - 16:00 0.50 CEMT P TIEB1 Release from hanger. Increase drill pipe pressure to 1,000 psi. Unsting from hanger. Circulate bottoms up at 12 BPM with 1100 psi, 13 bbl contaminated cement return. 16:00 - 16:30 0.50 CEMT P TIEB1 Rig down cementing head and lines. 16:30 - 17:30 1.00 CEMT P TIEB1 POH liner hanger running tools and lay down same. 17:30 - 19:00 1.50 BOPSURP TIEB1 Pull wear busbing. Change top rams to 3 1/2" to 6" variables. 19:00 - 22:00 3.00 BOPSURP TIEB1 Test BOP and associated equipment to 250 psi low and 3500 psi high. Install wear bushing. Chuck Scheve of AOGCC waived witnessing the test. 22:00 - 00:00 2.00 STWHIP P TIEB1 Make up clean out BHA with 6 blade mill, watermelon mill, junk subs and jars. 5/26/2003 00:00 - 00:30 0.50 STWHIP P TIEB1 Make up clean out BHA with 6 blade mill, watermelon mill, junk subs and jars. 00:30 - 02:00 1.50 STWHIP P TIEB1 RIH with clean out milling BHA on 4" drill pipe to 6683' 02:00 - 02:30 0.50 STWHIP TIEB1 Service top drive. 02:30 - 03:00 0.50 STWHIP P TIEB1 RIH to 8051'. 03:00 - 03:30 0.50 CASE P TIEB1 Test casing to 3000 psi for 15 minutes. 03:30 - 07:30 4.00 STWHIP P TIEB1 Drill floats and cement from 8056' to 8096'. Drill EZSV bridge plug at 8096' 07:30 - 08:30 1.00 STWHIP P TIEB1 RIH with drill pipe to lower EZSV bridge plug at 9054' 08:30 - 09:30 1.00 CASE P TIEB1 Test casing to 3500 psi for 30 minutes. 09:30 - 11 :00 1.50 STWHIP P TIEB1 Displace 9.6 ppg brine in hole with 8.4 ppg Quick Drill mud at 12 BPM with 2400 psi. 11 :00 - 14:00 3.00 STWHIP P TIEB1 POH to clean out BHA. 14:00 - 15:30 1.50 STWHIP P TIEB1 Lay down 6" mill and junk subs. Recover 20 Ibs junk. 15:30 - 17:30 2.00 STWHIP P TIEB1 Pick up Whipstock and mills. 17:30 - 21 :30 4.00 STWHIP P TIEB1 RIH with Whipstock BHA to 9054'. Printed: 6/9/2003 11 :54:55 AM ') ) BP EXPLORATION Operations SUl11mary Report Page 5 . of11· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/26/2003 21 :30 - 22:00 0.50 STWHIP P TIEB1 PJSM with rig crew, Schlumberger and GyroData on rigging up and handling tools. 22:00 - 00:00 2.00 STWHIP P TIEB1 Rig up to run surface read-out gyro on Schlumberger Eline to orient Whipstock. 5/27/2003 00:00 - 02:30 2.50 STWHIP P WEXIT Orient Whipstock at 277 deg azimuth with surface read-out gyro on Schlumberger Eline. Set bottom trip anchor on Whip stock BHA. Verify orientation. POH with gyro tools. 02:30 - 03:00 0.50 STWHIP P WEXIT Rig down Schlumberger logging unit and gyro tools. 03:00 - 12:00 9.00 STWHIP P WEXIT Shear pin on Whipstock. Mill window from 9,040' to 9,048' with 6"mill. Top of window at 9040'. P/U weight 190K, S/O weight 155K, Rot weight 170K. Torque 4 - 5K Had trouble at 9,048', stalling. 12:00 - 14:30 2.50 STWHIP P WEXIT Trouble milling window, P/U and have trouble slacking back off to bottom. Ream and work through window. 14:30 - 20:00 5.50 STWHIP P WEXIT Mill window from 9,048' to 9,052'. Chert and Pyrite cuttings. P/U weight 192K, S/O weight 155K, Rot weight 170K. Torque 4 - 6K ROP declined to zero. 20:00 - 20:30 0.50 STWHIP P WEXIT Work window and pump dry job. 20:30 - 23:30 3.00 STWHIP P WEXIT POOH from 9,052' to 1,070'. 23:30 - 00:00 0.50 STWHIP P WEXIT Handle BHA. 5/28/2003 00:00 - 00:30 0.50 STWHIP P WEXIT LID starter mill, lower string mill, and upper string mill. Starter mill and lower mill appear to be approximately 40% worn; upper mill in gauge. P/U new starter mill and upper string mill. 00:30 - 01 :30 1.00 STWHIP P WEXIT M/U BHA to 1,063'. 01 :30 - 02:00 0.50 STWHIP P WEXIT RIH from 1,063' to 3,397' with drill pipe. Fill pipe. 02:00 - 02:30 0.50 STWHIP P WEXIT Service top drive. 02:30 - 05:00 2.50 STWHIP P WEXIT RIH from 3,397' to 9,040'. Install blower hose. 05:00 - 12:00 7.00 STWHIP P WEXIT Ream from 9,040' to 9,052'. Mill window from 9,052' to 9,055'. P/U weight 180K, S/O weight 160K, Rot weight 170K. WOB 15 - 30K, torque 5,000 ft-Ibs. 12:00 - 00:00 12.00 STWHIP P WEXIT Mill window from 9,055' to 9,059'. P/U weight 180K, S/O weight 160K, Rot weight 170K. WOB15 - 30K, torque 5,000 ft-Ibs. 5/29/2003 00:00 - 05:00 5.00 STWHIP P WEXIT Mill window from 9,059' to 9,062'. P/U weight 180K, S/O weight 1550K, Rot weight 170K. WOB 30K, torque 5,400 ft-Ibs. 05:00 - 06:00 1.00 STWHIP P WEXIT Pump sweep. CBU at 8 bpm and 1,800 psi at 9,062'. Work window clean. 06:00 - 06:30 0.50 STWHIP P WEXIT Pull above window to 9,425'. Perform FIT with 8.4ppg QuickDrilN mud to 960 psi. (10.5 ppg EMW) 06:30 - 07:00 0.50 STWHIP P WEXIT Slug pipe at 9,425', blow down surface equipment, remove blower hose. 07:00 - 10:00 3.00 STWHIP P WEXIT POOH with drill pipe from 9,425' to 1,063'. 10:00 - 11 :30 1.50 STWHIP P WEXIT LID BHA from 1,063'. Upper mill full gauge. Clear rig floor. 11 :30 - 13:00 1.50 DRILL P PROD1 Pull wear bushing, flush stack. Install wear bushing, clear rig floor. 13:00 - 14:30 1.50 DRILL P PROD1 M/U 6" drilling BHA and orient. Shallow pulse test. 14:30 - 17:00 2.50 DRILL P PROD1 RIH from 206' to 8,980'. P/U 33 joints. Fill pipe every 30 stands. Printed: 6/9/2003 11 :54:55 AM ) ) BP EXPLORATION Operations Summary· Report Page 6 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From- To Hours Task Code NPT Phase Descriþtion of Operations 5/29/2003 17:00 - 18:30 1.50 DRILL P PROD1 Slip and cut 105' drilling line. Service top drive. 18:30 - 19:30 1.00 DRILL P PROD1 PJSM. R/U SWS, side entry sub and Gyrodata. Surface test gyro. O.K. 19:30 - 21 :30 2.00 DRILL P PROD1 RIH with gyro. Shallow test gyro. O.K. Having problems with mode switch to steering mode at deeper test. 21 :30 - 22:30 1.00 DRILL P PROD1 Trouble obtaining consistent TF. Attempt to flush seat. Pack off leaking. C/O packing rubbers. 22:30 - 00:00 1.50 DRILL P PROD1 Orient Toolface. Attempt to obtain consistent TF readings. 5/30/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Attempting to obtain consistent TF reading. Pump and work pipe. C/O packing on side entry sub. Orient at 9,012' and slide through window. No problems. 01 :00 - 02:00 1.00 DRILL P PROD1 Ream undergauge hole to 9,062'. Slide to 9,063'. Perform check shots. Concerned about lack of consistency in TF readings. Elect to POH for replacement tool. ART = 0.00 hrs, AST = 0.23 hrs, ADT = 0.23 hrs 02:00 - 03:30 1.50 DRILL N DFAL PROD1 POH with gyrodata tool. 03:30 - 06:30 3.00 DRILL N DFAL PROD1 R/D side entry sub. Surface check tool. Confirm all tool connections tight. Tool gave incorrect TF reading while positioned high side. Apparent shift of 130 degrees. C/O gyrodata tool. Trouble shoot new tool; difficulties establishing communication. 06:30 - 09:00 2.50 DRILL N DFAL PROD1 R/U side entry sub. M/U TD. SWS RIH with gyrodata tool. Stop at 5,000' and test tool. Good readings and mode switch to steering mode. 09:00 - 12:00 3.00 DRILL P PROD1 Directional drill from 9,063' to 9,094'. ART = 0.00 hrs, AST = 2.64 hrs, ADT = 2.64 hrs Slide at Gyro TF 214. Flow rate 225 gpm, on btm 1,850 psi, off btm 1,750 psi. WOB 8 -12 K, ROP 20 fph 12:00 - 18:30 6.50 DRILL P PROD1 Directional drill from 9,094' to 9,269'. ART = 0.00 hrs, AST = 4.85 hrs, ADT = 4.85 hrs Slide from 9,094' to 9,120' at Gyro TF 214. Flow rate 225 gpm, on btm 1,850 psi, off btm 1,750 psi. WOB 8 - 12 K, ROP 20 fph Slide from 9,120' to 9,269' at Gyro TF 20R - 30L. Flow rate 245 gpm, on btm 2,050 psi, off btm 1,850 psi. WOB 15 - 25 K, ROP 40 fph 18:30 - 19:00 0.50 DRILL P PROD1 POH with drill pipe from 9,269' to 9,011'. Function MWD tools. No response. 19:00 - 20:30 1.50 DRILL P PROD1 SWS POH with gyrodata tools. RID side entry sub. UD Gyrodata tool and RID SWS. Flow check MWD. O.K. 20:30 - 21 :00 0.50 DRILL P PROD1 Service top drive. 21 :00 - 21 :30 0.50 DRILL P PROD1 RIH from 9,011' to 9,269'. Take MWD check shots. 21 :30 - 00:00 2.50 DRILL P PROD1 Directional drill from 9,269' to 9,340'. ART = 0.00 hrs, AST = 1.28 hrs, ADT = 1.28 hrs P/U weight 180K, S/O weight 150K Slide 71' (9,269' - 9,340') at TF 20L. Printed: 6/9/2003 11 :54:55 AM ) ) BP EXPLORATION Operations Summary Report Pc¡ge 70f1.1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From -To Hours Task Code NPT Phase Description of Operations 5/30/2003 21 :30 - 00:00 2.50 DRILL P PROD1 Flow rate 270 gpm, on btm 1,950 psi, off btm 1,750 psi. WOB 25 K, ROP 50 fph 5/31/2003 00:00 - 12:00 12.00 DRILL P PROD1 Directional drill from 9,340' to 9,502'. ART = 0.00 hrs, AST = 8.65 hrs, ADT = 8.65 hrs P/U weight 180K, S/O weight 150K Slide 162' (9,340' - 9,502') at TF 20L- 80L. Flow rate 270 gpm, on btm 1,950 psi, off btm 1,750 psi. WOB 25 K, ROP 15 - 50 fph Contacted the 14N shale at 9,378' md (8,922' ss). Continued build, bottom out in 14N at 9,436' md (8,928' ss) 12:00 - 13:00 1.00 DRILL P PROD1 Directional drill from 9,502' to 9,510'. ART = 0.00 hrs, AST = 0.79 hrs, ADT = 0.79 hrs P/U weight 180K, S/O weight 150K 13:00 - 14:00 1.00 DRILL P PROD1 CBU at 9,510' at 275 gpm and 1,700 psi. Monitor well, static. BID surface equipment. 14:00 - 18:30 4.50 DRILL P PROD1 POOH from 9,510'. Overpull of 30K - 35K from 9,350' to 9,320'. MAD pass from 9,062' to 8,850'. POOH with drill pipe to 206'. Wet pipe. 18:30 - 20:00 1.50 DRILL P PROD1 Flush BHA with water. Stand back NMFDC. Down load MWD. LID MWD tools. Clear rig floor. Pull wear bushing. Set test plug. 20:00 - 23:30 3.50 BOPSURP PROD1 Test BOPE and all related valves to 250 psi low and 3,500 psi high. Test witnessed by John Spaulding of the AOGCC. 23:30 - 00:00 0.50 BOPSURP PROD1 Pull test plug, set wear bushing. BID surface equipment. 6/1/2003 00:00 - 02:30 2.50 DRILL P PROD1 M/U BHA to 82'. Upload MWD. M/U BHA to 212' and surface test MWD at 116 spm and 730 psi. 02:30 - 06:00 3.50 DRILL P PROD1 RIH with drill pipe to 9,452'. Fill pipe every 3,000'. Wash down to 9,510'. Took -20K weight from 9,340' to 9,350' and from 9,435' to 9,450'. 06:00 - 12:00 6.00 DRILL P PROD1 Directional drill from 9,510' to 9,815'. ART = 1.36 hrs, AST = 2.43 hrs, ADT = 3.79 hrs P/U weight 180K, S/O weight 145K, Rot weight 165K Slide 30L. Flow rate 325 gpm, on btm 2,200 psi, off btm 1,850 psi. WOB 12 K, ROP 30 - 40 fph Rotate at 60 rpm Flow rate 325 gpm, on btm 2,200 psi, off btm 1,850 psi. WOB 12 K, ROP 100 - 150 fph Torque on btm 6,500 ft-Ibs. 12:00 - 13:00 1.00 DRILL P PROD1 Directional drill from 9,815' to 9,879'. ART = 0.30 hrs, AST = 0.32 hrs, ADT = 0.62 hrs P/U weight 180K, S/O weight 145K, Rot weight 165K Slide 160L. Flow rate 325 gpm, on btm 2,200 psi, off btm 1,850 psi. WOB 12 K, ROP 60 fph Rotate at 60 rpm Flow rate 325 gpm, on btm 2,200 psi, off btm 1,850 psi. Printed: 6/9/2003 11 :54:55 AM ) ) BP EXPLORATION Operations Summary Report Page.Söf 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From - To Hours Task Code NPT Phase Descriptiorlof Operations 6/1/2003 12:00 - 13:00 1.00 DRILL P PROD1 WOB 12 K, ROP 60 fph Torque on btm 8,500 ft-Ibs. 13:00 - 13:30 0.50 DRILL P PROD1 Drill string torqued up, instantaneously, to -10,000 ft-Ibs. Lost 600 psi pump pressure. Check surface equipment. Monitor well. 13:30 - 14:00 0.50 DRILL N DFAL PROD1 POOH with drill pipe from 9,815' to 8,989'. 14:00 - 14:30 0.50 DRILL N DFAL PROD1 Drop circ sub dart at 8,989'. Shear circ sub at 2,800 psi. Remove blower hose. BID surface equipment. 14:30 - 17:30 3.00 DRILL N DFAL PROD1 POOH with drill pipe from 8,989' to 212'. Wet pipe. 17:30 - 18:00 0.50 DRILL N DFAL PROD1 Flush BHA with water at 212'. Stand back NMFDC. Inspect MWD tools. Bit and ABlleft in hole. 19.25' of motor housing recovered. Rotor remains in hole. Fish consists of 14.19' of lower motor housing, with ABI, and bit, plus -12' of rotor extended above top of motor housing. 18:00 - 19:00 1.00 DRILL N DFAL PROD1 Download MWD tools and LID. Clear rig floor. 19:00 - 19:30 0.50 DRILL N DFAL PROD1 Service top drive. 19:30 - 21 :00 1.50 DRILL N DFAL PROD1 PJSM with Baker regarding P/U fishing BHA. M/U fishing BHA to 749'. 21 :00 - 23:30 2.50 DRILL N DFAL PROD1 RIH with dril pipe from 749' to 9,845'. Wash and rotate down. P/U weight 182K, S/O weight 150K, Rot weight 170K. Torque off btm 4,500 Tag fish at 9,855'. 23:30 - 00:00 0.50 DRILL N DFAL PROD1 Engage fish at 9,855' at 26 spm and 420 psi. 6/2/2003 00:00 - 00:30 0.50 FISH N DFAL PROD1 Work O/S over TOF. Pump pressure increasing 20 - 30 psi. Torque increasing erratically to 8,500 ft-Ibs. Set down to 25K WOB. Pick up to 190K. Allow jar to release. Stage up, straight pull, in 5K intervals and hold momentarily. At 25K overpull, came free. Weight indicator showing -182K. Set back down on bottom to 35K WOB. 00:30 - 02:00 1.50 FISH N DFAL PROD1 POH from 9,855' to above window. Overpull of up to 25K on first two stands. At 9,603', encountered overpull of 35K. M/U top drive and pump stand out at 26 spm and 440 psi. Overpull to 30K. Continued with 5 - 15K overpull to window. No problems coming through window. 02:00 - 05:00 3.00 FISH N DFAL PROD1 POH with drill pipe from 8,960' to 749'. 05:00 - 07:00 2.00 FISH N DFAL PROD1 LID BHA from 749'. No fish recovery. Service break O/S assemby. Clear rig floor. 07:00 - 08:30 1.50 DRILL N DFAL PROD1 M/U SIT BHA to 82'. Upload MWD, M/U BHA to 212'. Surface test MWD at 102 spm and 900 psi. O.K. 08:30 - 12:30 4.00 DRILL N DFAL PROD1 RIH with drill pipe from 212' to 9,515'. Fill pipe every 3,000'. 12:30 - 14:30 2.00 DRILL N DFAL PROD1 Wash and ream from 9,515' to 9,732'. Shale stringers. RIH to 9,825' to confirm fish had not been dragged up hole. POH from 9,825' to 9,735'. 14:30 - 17:00 2.50 DRILL N DFAL PROD1 Orient at TF 160 and build trough from 9,713' to 9,735' for open hole sidetrack. 17:00 - 00:00 7.00 DRILL N DFAL PROD1 Time drill from 9,735'. P/U weight 185K, S/O weight 145K, Rot weight 160K. Torque off btm 5K Slide from 9,735' to 9,793' at TF 130R -70R. Flow rate 255 gpm, on btm 1,950 psi. off btm 1,700 psi. WOB 5 - 25 K, ROP 10 - 25 fph Printed: 6/9/2003 11 :54:55 AM ) ) BP EXPLORATION Operations Summary Report Page 9 of 11· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From - To Hours Task Codë NPT Phase Description of Operations 6/2/2003 17:00 - 00:00 7.00 DRILL N DFAL PROD1 ART = 0.00 hrs, AST = 6.87 hrs, ADT = 6.87 hrs 6/3/2003 00:00 - 14:30 14.50 DRILL P PROD1 Directional drill from 9,793' to 10,350'. Slide 70R 9,793' - 9.800' Flow rate 275 gpm, on btm 2,100 psi, off btm 1,900 psi. WOB 20K, ROP 20 fph Slide HS 9,800' - 9,845' Flow rate 275 gpm, on btm 2,100 psi, off btm 1,900 psi. WOB 20K, ROP 30 fph Slide 130L 9,845' - 9,860' Flow rate 275 gpm, on btm 2,100 psi, off btm 1,900 psi. WOB 20K, ROP 50 fph Rotate at 30 RPM 9,860' - 9,920'. Flow rate 275 gpm, on btm 2,000 psi, off btm 1,900 psi. WOB 15 K, ROP 60fph Torque on 6 - 7K, Torque off 4- 5K Slide 90 -160L 9,920'-10,053' Flow rate 275 gpm, on btm 2,200 psi, off btm 1,950 psi. WOB 25K, ROP 50 fph Rotate at 30 RPM 10,053' - 10,197'. Flow rate 275 gpm, on btm 2,200 psi, off btm 1,950 psi. WOB 25 K, ROP 80fph Torque on 6 - 7K, Torque off 4- 5K Slide 20R 10,197' - 10,212' Flow rate 275 gpm, on btm 2,200 psi, off btm 1,950 psi. WOB 25K, ROP 50 fph Rotate at 30 RPM 10,212' - 10,350'. Flow rate 275 gpm, on btm 2,200 psi, off btm 1,950 psi. WOB 25 K, ROP 80fph Torque on 6 - 7K, Torque off 4- 5K ART = 4.72 hrs, AST = 6.23 hrs, ADT = 10.95 hrs 14:30 - 15:30 1.00 DRILL P PROD1 Pump Hi Vis sweep at 10,350'. CBU at 275 gpm and 2,000 psi. Reciprocate and rotate. Monitor well, static. 15:30 - 16:30 1.00 DRILL P PROD1 POOH with drill pipe from 10,350' to 8,983'. 25K overpull at 9,840', 40K at 9,730'. 16:30 - 17:00 0.50 DRILL P PROD1 Service top drive. 17:00 - 18:30 1.50 DRILL P PROD1 RIH from 8,983'. Tag fish at 9,846'. POH to 9,650'. Orient to lowside TF. RIH with drill pipe from 9,650' to 10,350'. No fill. 18:30 - 20:30 2.00 DRILL P PROD1 Pump Hi Vis sweep at 10,350'. CBU twice at 280 gpm and 1,900 psi. Monitor well, static. 20:30 - 22:00 1.50 DRILL P PROD1 POOH with drill pipe from 10,350' to 8,983'. No problems. RIH with drill pipe from 8,983' to 9,640'. T/D up and orient to lowside at 9,640'. Slide through srr point with pumps off. No problems. RIH to 10,350'. Took 20 - 25K weight at 9,846' (Dogleg transition). P/U and work through. No fill on bottom. Printed: 6/9/2003 11 :54:55 AM ) ) BP EXPLORATION Op.erations Summary. Report Page·10of11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/3/2003 22:00 - 00:00 2.00 DRILL P PROD1 Pump Hi Vis sweep. CBU twice at 278 gpm and 1,950 psi. 6/4/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Circulate hole clean at 278 gpm and 1,950 psi. Spot open hole volume liner running pill. 01 :00 - 01 :30 0.50 DRILL P PROD1 POOH with drill pipe from 10,350' to 8,990'. Overpull of 10- 15K. 01 :30 - 02:00 0.50 DRILL P PROD1 Drop 1 7/8" dart to P~S, shear open with 2,400 psi, pump dry job. Blow down top drive. Drop 2.38" dp rabbit. 02:00 - 05:00 3.00 DRILL P PROD1 POOH with drill pipe from 8,990' to 212'. 05:00 - 06:30 1.50 DRILL P PROD1 LID BHA from 212' to 175'. Flush BHA with water. LID BHA from 175'. Download MWD. Clear rig floor. 06:30 - 07:30 1.00 CASE P COMP R/U 41/2" casing equipment. PJSM. 07:30 - 08:00 0.50 CASE P COMP M/U 4 1/2" float equipment and check floats. O.K. 08:00 - 09:30 1.50 CASE P COMP M/U and RIH with 41/2",12.6#, L-80 IBT-M liner to 1,430'. Run a total of 35 joints 4 1/2", 12.6#, L-80 IBT-M liner. Average M/U torque 3,900 ft-Ibs. 09:30 - 10:00 0.50 CASE P COMP M/U 7" Baker HMC liner hanger and ZXP liner top packer. P/U 1 stand of drill pipe to 1,559'. 10:00 - 10:30 0.50 CASE P COMP Circulate liner volume at 6 bpm and 130 psi. Up weight and Down weight 45K. 10:30 - 14:30 4.00 CASE P COMP RIH with liner on drill pipe from 1,559' to 9,027'. Fill pipe every 10 stands. 14:30 - 15:00 0.50 CASE P COMP Circulate drill pipe and liner volume at 9,027' at 5 bpm and 670 psi. Up 170K, On 147K. Blow down surface equipment. 15:00 - 15:30 0.50 CASE P COMP RIH with liner on drill pipe from 9,027' to 10,334'. Took 25K weight at 9,438', 45K at 10,134'. 15:30 - 16:00 0.50 CASE P COMP R/U rotary cement head, valves and circulating lines. 16:00 - 18:00 2.00 CASE P COMP Circulate at 2 bpm and 540 psi. RIH from 10,334' and tag bottom at 10,350'. No fill. Stage pump to 6 bpm and 1,230 psi. Slow pump rate to 4.5 bpm and 930 psi. Condition hole. Up weight 180K, On weight 150K. 18:00 - 20:00 2.00 CEMT P COMP PJSM. Batch mix cement. Pump 5 bbl water and test lines to 4,500 psi. Pump 10 bbl CW100, 25 bb19.5 ppg Mud PUSH, and 36 bb115.8 ppg cement slurry. Wash lines. Drop dart. Displace with 50 bbl perf pill, followed by 53.9 bbl mud. Total displacement 103.9 bbl. Bump plug to 3,800 psi. CIP at 19:53 hours, 06/04/2003. Check floats, O.K. 20:00 - 21 :00 1.00 CEMT P COMP Release from hanger with 15 RH rotations. Pressure drill pipe to 1 ,OOOpsi. Sting out. CBU at 12 bpm and 2,600 psi. Estimate 8 bbl cement in returns. Set down 1 OOK to set liner top packer. Repeat twice with rotation. 21 :00 - 22:00 1.00 CEMT P COMP Pump Dirt Magnet sweep. Displace well to sea water at 8,894' at 12 bpm and 3,050 psi. 22:00 - 22:30 0.50 CEMT P COMP RID rotary cement head, valves and hoses. Slug pipe. POOH with one stand. 22:30 - 00:00 1.50 CEMT P COMP Slip and cut drilling line. Service top drive. 6/5/2003 00:00 - 04:00 4.00 CASE P COMP POOH with drill pipe from 8,894' to 1,583'. Stand back 95 stands. LID remaining drillpipe. 04:00 - 05:30 1.50 CASE P COMP LID 4" drill pipe from 1,583'. Service break and LID running tool, clear floor. 05:30 - 06:30 1.00 PERF P COMP RlU 2 7/8" handling equipment. Printed: 6/9/2003 11 :54:55 AM ) ) BPEXPLORA TION Operations Summary..Report Page 11 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-16 C-16A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/18/2003 Rig Release: 6/7/2003 Rig Number: Spud Date: 5/11/1980 End: 6/7/2003 Date From..; To Hours Task Code NPT· Phase Description of Operations 6/5/2003 06:30 - 07:30 1.00 EVAL P COMP Test 9 5/8" x 7" X 4 1/2" to 3,500 psi for 30 minutes. Record test. 07:30 - 08:30 1.00 PERF P COMP PJSM. M/U perf guns to 502'. 08:30 - 09:30 1.00 PERF P COMP M/U 2 7/8" drill pipe from 502' to 1,425'. Up and Dn weight 40K. 09:30 - 14:00 4.50 PERF P COMP C/O handling euipment. RIH with 4" drill pipe from 1,425'. Tag LlC at 10,265'. Space out perf guns with bottom shot at 10,200' and top shot at 9,725'. P/U weight 174K, S/O weight 150K. 14:00 - 14:30 0.50 PERF P COMP PJSM with all personnel. Shut well in. Pump down drill pipe and annulus to 3,OOOpsi. Hold 1 minute. Bleed off pressure. Open well up. Good indication guns fired. Well perforated from 9,725' to 9,775' and from 9,950' to 10,200' with 4 spf. Initial loss of 6 bbls. 14:30 -15:30 1.00 PERF P COMP POOH from 10,203' to 8,805'. Monitor well for 15 minutes. Static. 15:30 - 16:30 1.00 PERF P COMP CBU at 8,805' at 7 bpm and 1,600 psi. Monitor well, static. Slug pipe. Blow down surface equipment. 16:30 - 22:30 6.00 PERF P COMP POOH LID drill pipe from 8,805' to 4,430'. RIH with stands from the derrick from 4,430' to 5,802'. LID drill pipe from 5,802' to 1,425'. 22:30 - 00:00 1.50 PERF P COMP R/U 2 7/8" tubing handling equipment. LID 2 7/8" tubing from 1 ,425' to 627'. 6/6/2003 00:00 - 02:00 2.00 PERF P COMP LID perf guns. All shots fired. 02:00 - 03:00 1.00 RUNCOIVP COMP Clear rig floor. P/U handling equipment. Pull wear bushing. 03:00 - 11 :00 8.00 RUNCOIVP COMP PJSM. P/U WLEG joint. M/U tubing tail and S-3 packer. Baker-Lok connections below packer. RIH with 41/2", 12.6#, L-80,IBT-M tubing. Run a total of 213 joints 4 1/2", 12.6#, L-80, IBT-M tubing. Average M/U torque 3,800 ft-Ibs. 11:00-12:00 1.00 RUNCOIVP COMP Tag bottom of Tie Back Sleeve at 8,906' (tubing measurement). P/U 2 feet. Determine no spacer pups required. M/U tubing hanger. 12:00-13:00 1.00 RUNCOIVP COMP Land hanger. RILDS. 13:00 - 13:30 0.50 RUNCOIVP COMP R/U circulating lines and test to 3,500 psi. 13:30 - 15:30 2.00 RUNCOIVP COMP Reverse circulate 135 bbl clean sea water. Pump 93 bbl corrosion inhibited sea water. Chase with 165 bbl clean sea water at 3 bpm and 200 psi. 15:30 - 17:30 2.00 RUNCOIVP COMP Drop 1 7/8" ball and rod. Pressure to 3,500 psi to set packer. Test tubing to 3,500 psi for 30 minutes. Bleed tubing pressure to 1,500 psi. Pressure annulus to 3,500 psi and test for 30 minutes. Bleed tubing pressure to shear DCR valve. 17:30 -18:00 0.50 WHSUR P COMP Dry rod in TWC with FMC. Test from below to 1,000 psi. O.K. Blow down surface equipment. 18:00 - 19:00 1.00 WHSUR P COMP N/D BOPE. 19:00 - 21 :00 2.00 WHSUR P COMP N/U tree and adapter flange. 21 :00 - 21 :30 0.50 WHSUR P COMP Test tree and adapter flange to 5,000 psi. 21 :30 - 22:00 0.50 WHSUR P COMP Pull TWC with DSM. 22:00 - 00:00 2.00 WHSUR P COMP PJSM. RlU LRHOS and test lines. Displace sea water with diesel for freeze protect. 6/7/2003 00:00 - 02:00 2.00 WHSUR P COMP Continue to displace sea water with 155 bbls diesel at 2.5 bpm and 1,800 psi. U-tube diesel. RID LRHOS. 02:00 - 02:30 0.50 WHSUR P COMP Install BPV and test to 1,000 psi, from below. 02:30 - 03:30 1.00 RIGD P COMP Remove secondary annulus valve, secure well. RELEASE rig at 03:30 6/07/2003. Printed: 6/9/2003 11 :54:55 AM ) ) 13-Jun-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well C-16 A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 9,687.45' MD Window / Kickoff Survey: 9,738.27' MD (if applicable) Projected Survey: 10,350.00' MD ~o 3 '- [) 23 Ý. Please call me at 273-3545 if you have any questions or concerns. RECEIVED ~ . JUL 0 1 2003 R~ëE;G&~C~i~~^"~¡¡fr ~1- ~ JUN Regards, William T. Allen Survey Manager Attachment(s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA C Pad C-16A Job No. AKZZOOO2461818, Surveyed: 3 June, 2003 Survey Report 12 June, 2003 Your Ref: API 500292043801 Surface Coordinates: 5961098.00 N, 664130.00 E (70018' 00.1757" N, 148040'14.2987" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 961098.00 N, 164130.00 E (Grid) Surface Coordinates relative to Structure Reference: 3843.84 N, 1664.33 E (True) Kelly Bushing: 61.77ft above Mean Sea Level Elevation relative to Project V Reference: 61. 77ft Elevation relative to Structure Reference: 61. 77ft 5pe!r'rty-SUI! DRILLING SeAVICeS A Halliburton Company DEF NITIVE ~/ ~~' Survey Ref: 5vy4042 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-16A Your Ref: API 500292043801 Job No. AKZZOO02461818, Surveyed: 3 June, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9687.45 89.690 173.200 8921.92 8983.69 471.16N 824.24 E 5961587.05 N 664943.75 E 930.56 Tie On Point 9722.19 90.190 173.460 8921.96 8983.73 436.66 N 828.27 E 5961552.64 N 664948.54 E 1.622 923.54 9738.27 88.330 173.730 8922.17 8983.94 420.68 N 830.07 E 5961536.71 N 664950.68 E 11.688 920.22 Window Point 9752.22 87.290 176.140 8922.70 8984.47 406.79 N 831.30 E 5961522.85 N 664952.21 E 18.804 917.03 9780.10 88.520 181.170 8923.72 8985.49 378.95 N 831.95 E 5961495.03 N 664953.4 7 E 18.561 908.90 9814.10 92.410 185.080 8923.44 8985.21 345.01 N 830.10 E 5961461.06 N 664952.36 E 16.220 896.47 ..~ 9845.06 93.330 182.390 8921.89 8983.66 314.16 N 828.08 E 5961430.17 N 664951.02 E 9.172 884.86 9873.04 91.610 184.050 8920.69 8982.46 286.25 N 826.51 E 5961402.24 N 664950.06 E 8.539 874.60 9907.23 91.910 182.670 8919.64 8981.41 252.14 N 824.51 E 5961368.09 N 664948.81 E 4.129 861.97 9938.37 90.800 177.320 8918.90 8980.67 221.02 N 824.51 E 5961336.98 N 664949.49 E 17.541 852.20 9966.48 90.190 171.900 8918.66 8980.43 193.05 N 827.15 E 5961309.07 N 664952.74 E 19.402 845.91 10000.57 89.380 169.330 8918.79 8980.56 159.42 N 832.71 E 5961275.57 N 664959.03 E 7.904 840.61 10018.28 89.140 167.510 8919.02 8980.79 142.07 N 836.27 E 5961258.30 N 664962.96 E 10.365 838.54 10031.77 89.570 163.880 8919.17 8980.94 129.00 N 839.60 E 5961245.31 N 664966.58 E 27.095 837.59 10059.51 89.630 160.030 8919.36 8981.13 102.63 N 848.19 E 5961219.13 N 664975.74 E 13.880 837.46 10152.05 89.940 160.570 8919.71 8981.48 15.51 N 879.38 E 5961132.71 N 665008.83 E 0.673 839.69 10246.96 92.840 161.980 8917.41 8979.18 74.34 S 909.84 E 5961043.55 N 665041.25 E 3.397 840.36 10305.28 93.710 162.220 8914.07 8975.84 129.75 S 927.74 E . 5960988.55 N 665060.35 E 1.547 839.93 10350.00 93.710 162.220 8911.18 8972.95 172.24 S 941.36 E 5960946.36 N 665074.90 E 0.000 839.51 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). "-" Vertical Section is from Well Reference and calculated along an Azimuth of 71.680° (True). Magnetic Declination at Surface is 25.859°(22-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10350.000., The Bottom Hole Displacement is 956.99ft., in the Direction of 100.369° (True). 12 June, 2003 - 13:39 Page 20f3 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad· C-16A Your Ref: API 500292043801 Job No. AKZZOD02461818, Surveyed: 3 June, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 9687.45 9738.27 10350.00 8983.69 8983.94 8972.95 471.16 N 420.68 N 172.24 S 824.24 E 830.07 E 941.36 E Tie On Point Window Point Projected Survey ~ Survey tool program for C-16A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9002.57 0.00 9002.57 8702.29 10350.00 8702.29 BP High Accuracy Gyro (C-16) 8972.95 AK-6 BP _IFR-AK (C-16APB1) '-' 12 June, 2003 - 13:39 Page 3 of3 DrillQuest 3.03.02.005 ) ) 13-Jun-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-16 A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 9,687.45' MD Window / Kickoff Survey: 9,738.27' MD (if applicable) Projected Survey: 10,350.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, ~03 ~b 3c+ RECE\VEO William T. Allen Survey Manager JUL 0 1 LOC3 oal,. r\..'. iI. I~;¡I:; C··r¡¡H,i..··. Cüm(r1¥~n Aiau.\~ ~i ".¡, '-'......, ~..... ~~ Attachment(s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA CPad C-16A MWD -- Job No. AKMW0002461818, Surveyed: 3 June, 2003 Survey Report 12 June, 2003 Your Ref: API 500292043801 Surface Coordinates: 5961098.00 N, 664130.00 E (70018' 00.1757- N, 148040' 14.2987" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 961098.00 N, 164130.00 E (Grid) Surface Coordinates relative to Structure Reference: 3843.84 N, 1664.33 E (True) Kelly Bushing: 61. 77ft above Mean Sea Level Elevation relative to Project V Reference: 61. 77ft Elevation relative to Structure Reference : 61. 77ft spe!r'....Y-sUf1 DRILLING SERVices A Halliburton Company Survey Ref: 5vy4044 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-16A MWD Your Ref: API 500292043801 Job No. AKMW0002461818, Surveyed: 3 June, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9687.45 89.690 173.510 8921.93 8983.70 472.76 N 820.93 E 5961588.58 N 664940.41 E 927.92 Tie On Point 9722.19 90.1 90 173.900 8921.96 8983.73 438.23 N 824.74 E 5961554.14 N 664944.97 E 1.825 920.68 9738.27 88.330 173.950 8922.17 8983.94 422.24 N 826.44 E 5961538.20 N 664947.02 E 11.571 917.27 Window Point 9752.22 87.290 176.410 8922.70 8984.47 408.35 N 827.61 E 5961524.33 N 664948.50 E 19.133 914.02 9780.10 88.520 183.940 8923.72 8985.49 380.51 N 827.53 E 5961496.50 N 664949.02 E 27.348 905.19 9814.10 92.410 185.310 8923.45 8985.22 346.63 N 824.79 E 5961462.57 N 664947.02 E 12.130 891.94 -. 9845.06 93.330 182.630 8921.90 8983.67 315.79 N 822.64 E 5961431.68 N 664945.55 E 9.142 880.21 9873.04 91.610 184.110 8920.69 8982.46 287.89 N 821.00 E 5961403.75 N 664944.52 E 8.106 869.88 9907.23 91.910 183.220 8919.64 8981.41 253.78 N 818.82 E 5961369.61 N 664943.08 E 2.746 857.09 9938.37 90.800 177.720 8918.90 8980.67 222.66 N 818.56 E 5961338.49 N 664943.50 E 18.013 847.06 9966.48 90.190 172.270 8918.66 8980.43 194.67 N 821.01 E 5961310.56 N 664946.57 E 19.508 840.59 10000.57 89.380 169.420 8918.79 8980.56 161.02 N 826.44 E 5961277.03 N 664952.72 E 8.691 835.16 10018.28 89.140 167.950 8919.02 8980.79 143.66 N 829.91 E 5961259.75 N 664956.58 E 8.410 833.00 10031.77 89.570 164.250 8919.17 8980.94 130.57 N 833.15 E 5961246.73 N 664960.10 E 27.611 831.96 10059.51 89.630 160.380 8919.36 8981.13 104.14 N 841.58 E 5961220.50 N 664969.10 E 13.952 831.66 10152.05 89.940 161.200 8919.71 8981.48 16.76 N 872.02 E 5961133.80 N 665001.45 E 0.947 833.09 10246.96 92.840 161.300 8917.41 8979.18 73.08 S 902.52 E 5961044.65 N 665033.90 E 3.057 833.81 10305.28 93.710 160.910 8914.08 8975.85 128.17 S 921.37 E 5960989.99 N 665053.95 E 1.634 834.39 10350.00 93.710 160.910 8911.18 8972.95 170.34 S 935.97 E 5960948.15 N 665069.47 E 0.000 834.99 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). .-- Vertical Section is from Well Reference and calculated along an Azimuth of 71.680° (True). Magnetic Declination at Surface is 25.859°(22-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10350.000., The Bottom Hole Displacement is 951.34ft., in the Direction of 100.314° (True). 12 June, 2003 - 13:45 Page 2 of 3 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad· C-16A MWD Your Ref: API 500292043801 Job No. AKMW0002461818, Surveyed: 3 June, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9687.45 9738.27 10350.00 8983.70 8983.94 8972.95 472.76 N 422.24 N 170.34 S 820.93 E 826.44 E 935.97 E Tie On Point Window Point Projected Survey ;~./ Survey tool program for C-16A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9002.57 0.00 9002.57 8702.29 10350.00 8702.29 BP High Accuracy Gyro (C-16) 8972.95 MWD Magnetic (C-16APB1 MWD) --' 12 June, 2003 - 13 :45 Page 3 of 3 Dril/Quest 3.03.02.005 ) AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well C-16 A PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 9,002.57' MD Window / Kickoff Survey: 9,040.00' MD (if applicable) Projected Survey: 9,879.39' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) 13-Jun-03 d03 --Dßt.+ f'~ F 1"'\, r-' I '\~ ! ~,...c.~ ,""..0:", , ij= ~ ~ ~""" ~ ì!J !be, l.a.4t L- "C ¡L¡ J I I! ^.¡ "" ^ -. VL -.J í L.\\.: Al~ n~ ~ C:~~¡.i:' . -.'r": ~'.. ';';:"~ ~.:.~ ~~':' .:.~ o\;~:·*" "·r~,'·,. ~ ' riì4." Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA C Pad C-16APB1 Job No. AKZZOO02461818, Surveyed: 1 June, 2003 Survey Report 12 June, 2003 Your Ref: API 500292043870 Surface Coordinates: 5961098.00 N, 664130.00 E (70018' 00.1757" N, 148040' 14.2987" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 961098.00 N, 164130.00 E (Grid) Surface Coordinates relative to Structure Reference: 3843.84 N, 1664.33 E (True) Kelly Bushing: 61. 77ft above Mean Sea Level Elevation relative to Project V Reference: 61.77ft Elevation relative to Structure Reference: 61. 77ft 5peær-'.....y-SLJr1 DRILLING seRVices A Halliburton Company )EF N T VE .-, __f Survey Ref: svy4041 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-16APB1 Your Ref: API 500292043810 Job No. AKZZ0002461818, Surveyed: 1 June, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9002.57 1.080 315.900 8640.52 8702.29 921.27 N 971.73 E 5962040.27 N 665081.38 E 1212.05 Tie On Point AK-6 BP _IFR-AK 9040.00 1.100 309.720 8677.95 8739.72 921.75 N 971.21 E 5962040.74 N 665080.84 E 0.318 1211.71 Window Point 9054.00 3.160 278.920 8691.94 8753.71 921.89 N 970.72 E 5962040.88 N 665080.36 E 16.325 1211.30 9083.00 6.520 222.410 8720.84 8782.61 920.80 N 968.82 E 5962039.74 N 665078.48 E 18.801 1209.15 9117.00 14.680 215.380 8754.24 8816.01 915.86 N 965.02 E 5962034.72 N 665074.78 E 24.255 1203.98 ~ 9147.60 22.320 220.030 8783.24 8845.01 908.23 N 959.03 E 5962026.96 N 665068.96 E 25.410 1195.90 9191.93 33.250 225.730 8822.40 8884.17 893.26 N 944.87 E 5962011.68 N 665055.13 E 25.348 1177.75 9223.30 41.910 224.910 8847.24 8909.01 879.81 N 931.29 E 5961997.94 N 665041.85 E 27.651 1160.63 9254.26 49.690 221.690 8868.81 8930.58 863.64 N 916.11 E 5961981.45 N 665027.03 E 26.206 1141.14 9285.41 57.590 216.370 8887.27 8949.04 844.15 N 900.38 E 5961961.61 N 665011.73 E 28.836 1120.08 9312.81 65.230 213.570 8900.37 8962.14 824.44 N 886.62 E 5961941.60 N 664998.40 E 29.288 1100.82 9347.51 70.400 211.110 8913.47 8975.24 797.29 N 869.45 E 5961914.09 N 664981.83 E 16.280 1075.99 9378.68 78.160 208.120 8921.92 8983.69 771.22 N 854.65 E 5961887.71 N 664967.60 E 26.550 1053.75 9406.46 83.440 204.880 8926.36 8988.13 746.69 N 842.42 E 5961862.92 N 664955.91 E 22.219 1034.43 9440.48 90.990 199.680 8928.01 8989.78 715.28 N 829.56 E 5961831.23 N 664943.74 E 26.931 1012.34 9471.40 96.000 192.940 8926.12 8987.89 685.69 N 820.90 E 5961801.46 N 664935.72 E 27.122 994.82 9500.15 96.870 187.290 8922.90 8984.67 657.58 N 815.88 E . 5961773.24 N 664931.32 E 19.761 981.22 9533.59 93.520 182.240 8919.87 8981.64 624.40 N 813.12 E 5961740.02 N 664929.29 E 18.069 968.17 9564.59 88.400 178.780 8919.35 8981.12 593.42 N 812.84 E 5961709.04 N 664929.69 E 19.931 958.17 9593.27 88.210 174.850 8920.20 8981.97 564.81 N 814.44 E 5961680.46 N 664931.90 E 13.713 950.69 9687.45 89.690 173.200 8921.92 8983.69 471.16N 824.24 E 5961587.05 N 664943.75 E 2.353 930.56 9736.62 92.160 173.450 8921.13 8982.90 422.33 N 829.95 E 5961538.36 N 664950.53 E 5.049 920.64 ~/ 9781.03 92.410 172.870 8919.36 8981 .13 378.28 N 835.24 E 5961494.43 N 664956.77 E 1.421 911.80 9879.39 92.410 172.870 8915.22 8976.99 280.76 N 847.43 E 5961397.21 N 664971.10 E 0.000 892.73 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 71.680° (True). Magnetic Declination at Surface is 25.8600(22-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 9879.39ft., The Bottom Hole Displacement is 892.73f1., in the Direction of 71.670° (True). 12 June, 2003 - 13:32 Page 20f3 DrillQuest 3.03.02.005 North Slope Alaska Comments Measured Depth (ft) 9002.57 9040.00 9879.39 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-16APB1 Your Ref: API 500292043870 Job No. AKZZD002461818, Surveyed: 1 June, 2003 BPXA Station Coordinates TVD Northings Eastings ~) ~) ~) 8702.29 8739.72 8976.99 Comment 921.27 N 921.75 N 280.76 N 971.73 E 971.21 E 847.43 E Tie On Point Window Point Projected Survey -' Survey tool proQram for C-16APB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 9002.57 12 June, 2003 - 13:32 0.00 8702.29 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 9002.57 9879.39 8702.29 BP High Accuracy Gyro (C-16) 8976.99 AK-6 BP _IFR-AK (C-16APB1) '-' Page 3 of 3 DrillQuest 3.03.02.005 ) ') 13-Jun-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-16 A PB 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 9,002.57' MD Window / Kickoff Survey: 9,040.00' MD (if applicable) Projected Survey: 9,879.39' MD Please call me at 273-3545 if you have any questions or concerns. Regards, ~03 -034- 'w ""'1;, ;?;;"1"'"~~ ~: v' '" !l t -::.. . '''''', ~'1;: ~""" Il ,.,,~:~,",' ~) I.' ij~" ~ V U 1'... ,!t'::,'!¡:",: ...~ ~n;\tt"';I ~ W ~,~:,'~'l ~1.....::,\,'. William T. Allen Survey Manager JU~_ () î c.:, .': ~ J~.¡¿I~;h:J~;;: t':' ,'¿, ....,:;:(::;,~.:,~;>; Attachment(s) ð¡,~,··"",···· . \"--'., 0-.~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA C Pad C-16APB1 MWD '........,/ Job No. AKMW0002461818, Surveyed: 1 June, 2003 Survey Report 12 June, 2003 Your Ref: API 500292043870 Surface Coordinates: 5961098.00 N, 664130.00 E (70° 18' 00.1757" N, 148040'14.2987" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -' Surface Coordinates relative to Project H Reference: 961098.00 N, 164130.00 E (Grid) Surface Coordinates relative to Structure Reference: 3843.84 N, 1664.33 E (True) Kelly Bushing: 61. 77ft above Mean Sea Level Elevation relative to Project V Reference: 61. 77ft Elevation relative to Structure Reference: 61. 77ft spe.......,y-su., DRILLING SERVices A Halliburton Company Survey Ref: svy4043 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-16APB1 MWD Your Ref: API 500292043870 Job No. AKMWOO02461818, Surveyed: 1 June, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9002.57 1.080 315.900 8640.52 8702.29 921.27 N 971.73 E 5962040.27 N 665081.38 E 1212.05 Tie On Point MWD Magnetic 9040.00 1.100 309.720 8677.95 8739.72 921.75 N 971.21 E 5962040.74 N 665080.84 E 0.318 1211.71 Window Point 9054.00 3.160 278.920 8691.94 8753.71 921.89 N 970.72 E 5962040.88 N 665080.36 E 16.325 1211.30 9083.00 6.520 222.410 8720.84 8782.61 920.80 N 968.82 E 5962039.74 N 665078.48 E 18.801 1209.15 9117.00 14.680 215.380 8754.24 8816.01 915.86 N 965.02 E 5962034.72 N 665074.78 E 24.255 1203.98 -' 9147.60 22.320 220.030 8783.24 8845.01 908.23 N 959.03 E 5962026.96 N 665068.96 E 25.410 1195.90 9191.93 33.250 226.250 8822.40 8884.17 893.34 N 944.79 E 5962011.76 N 665055.05 E 25.478 1177.70 9223.30 41.910 225.560 8847.24 8909.01 880.03 N 931.07 E 5961998.15 N 665041.63 E 27.638 1160.49 9254.26 49.690 222.640 8868.81 8930.58 864.08 N 915.67 E 5961981.87 N 665026.57 E 26.018 1140.86 9285.41 57.590 217.250 8887.27 8949.04 844.83 N 899.63 E 5961962.28 N 665010.96 E 28.922 1119.58 9312.81 65.230 214.200 8900.38 8962.15 825.31 N 885.61 E 5961942.45 N 664997.37 E 29.542 1100.14 9347.51 70.400 211.930 8913.48 8975.25 798.38 N 868.10 E 5961915.16 N 664980.45 E 16.082 1075.05 9378.68 78.160 208.570 8921.92 8983.69 772.48 N 853.01 E 5961888.93 N 664965.94 E 26.968 1052.59 9406.46 83.440 205.4 70 8926.36 8988.13 748.06 N 840.56 E 5961864.24 N 664954.02 E 21.966 1033.09 9440.48 90.990 200.160 8928.01 8989.78 716.77 N 827.41 E 5961832.67 N 664941.55 E 27.115 1010.77 9471.40 96.000 193.360 8926.12 8987.89 687.25 N 818.51 E 5961802.96 N 664933.31 E 27.278 993.04 9500.15 96.870 187.990 8922.90 8984.67 659.19 N 813.22 E 5961774.79 N 664928.63 E 18.805 979.20 9533.59 93.520 182.270 8919.87 8981.64 626.03 N 810.25 E 5961741.58 N 664926.38 E 19.760 965.96 9564.59 88.400 179.180 8919.35 8981.12 595.06 N 809.86 E 5961710.60 N 664926.67 E 19.288 955.85 9593.27 88.210 174.820 8920.20 8981.97 566.43 N 811.36E 5961682.02 N 664928.79 E 15.210 948.28 9687.45 89.690 173.510 8921.93 8983.70 472.76 N 820.93 E 5961588.58 N 664940.41 E 2.098 927.92 9736.62 92.160 173.250 8921.13 8982.90 423.93 N 826.60 E 5961539.88 N 664947.14 E 5.051 917.95 9781.03 92.410 173.130 8919.36 8981 .13 379.87 N 831.86 E 5961495.95 N 664953.36 E 0.624 909.10 '-' 9879.39 92.410 173.130 8915.22 8976.99 282.30 N 843.61 E 5961398.66 N 664967.25 E 0.000 889.59 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 71.680° (True). Magnetic Declination at Surface is 25.859°(22-May-03) Based upon Minimum Curvature type calculations. at a Measured Depth of 9879.39ft., The Bottom Hole Displacement is 889.60ft., in the Direction of 71.498° (True). 12 June, 2003 - 13:43 Page 2 of 3 DrillQuest 3.03.02.005 North Slope Alaska Comments Measured Depth (ft) 9002.57 9040.00 9879.39 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8702.29 8739.72 8976.99 921.27 N 921.75 N 282.30 N 971.73 E 971.21 E 843.61 E Survey tool program for C-16APB1 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 9002.57 12 June, 2003 - 13:43 0.00 8702.29 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-16APB1 MWD Your Ref: API 500292043870 Job No. AKMW0002461818. Surveyed: 1 June. 2003 BPXA Comment Tie On Point Window Point Projected Survey --.,/ To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 9002.57 9879.39 8702.29 BP High Accuracy Gyro (C-16) 8976.99 MWD Magnetic (C-16APB1 MWD) -/ Page 3 of 3 Dri/lQuest 3.03.02.005 ) @:r Itr=--=> 1: ~ UW ~ 1: ~. Í !Æ ~!Æ~~~!Æ FRANK H. MURKOWSKI, GOVERNOR ~ AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit C-16A BP Exploration (Alaska), Inc. Permit No: 203-084 Surface Location: 116' SNL, 1218' WEL, Sec. 19, T11N, RI4E, UM Bottomhole Location: 355' SNL, 300' WEL, Sec. 19, T11N, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional pennits or approvals rèquired 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 North Slope petroleum field inspector at 659-3607 (pager). Sincerely, tc...~ ~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this-+-- day of May, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ~6A- 5/C:O/wo?:, ALASKA STATE OF ALASKA 1 AND GAS CONSERVATION COMrv¡, 110N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan KBE = 63.7' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028305 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / C-16A 9. Approximate spud date.- 05/25/03 /" Amount $200,000.00 14. Number of acres in property 15. ProPQsed depth (MD and TVD) 2560 /1 0400' MD / 8993' TVD 17. Anticipated pressure {s~20 AAC 25.035 (e) (2)} 90 0 Maximum surface 236á psig, At total depth (TVD) 8800' / 3240 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 5423' 2650' 2650' 8073' 7773' 1520' 8880' 8580' 10400' 8993' 11. Type Bond (See 20 AAC 25,025) 1 a. Type of work 0 Drill III Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 664130, Y = 5961098 116' SNL, 1218' WEL, SEC. 19, T11N, R14E, UM At top of productive interval x = 664925, Y = 5961742 510' NSL, 407' WEL, SEC. 18, T11N, R14E, UM At total depth x = 665054, Y = 5960879 355' SNL, 300' WEL, SEC. 19, T11 N, R14E, UM Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well / ADL 028285,4651' MD C-36Ais 277'awayat9190'MD 16. To be completed for deviated wells Kick Off Depth 9030' MD Maximum Hole Angle 18, Casing Program S 'f' t' Size peel lea Ions Casina Weiaht Grade Couplina 7" 26# L-80 BTC-M 4-1/2" 12.6# L-80 IBT 6" Quantity of Cement (include staae data) 871 cu ft Class 'G' 90 cu ft Class 'G' Hole 8-1/2" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9480 feet 9180 feet 9369 feet 9069 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 110' 20" x 30" 2691' 13-3/8" 8578' 9-5/8" 1402' 7" 12.9 cu yds Permafrost 3720 cu ft Permafrost II 1160 cu ft Class 'G', 130 cu ft AS 110' 2691' 8578' 110 2691' 8278' 401 cu ft Class 'G' 8073' - 9475' 7773' - 9175' RECEIVED Perforation depth: measured Open: 9275' - 9278', 9290' - 9313', 9313' - 9325' MA Y 06 2003 Sqzd: 9204' - 9212', 9220' - 9248', 9258' - 9275' true vertical Open: 8975' - 8978', 8990' - 9013', 9013' - 9025' Alaska Ot¡ & Gas Cons. CQmmilsion Sqzd: 8904' - 8912', 8920' - 8948', 8958' - 8975' Anchorage 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I ~erebY certify that the fore~1" i~'.,...ncýcorreqt to the best of my knowledge . ! Signed Bill Isaacson 1f> f . V '" ÎS\'T. VA. , , Title Semo, Dnlhng Englnee' Date S· c h-S \ ~~ V Commission Use Only ,..., Permit Number API Number -Zð:3 - CJ ~ <l 50- 029-20438-01 Conditions of Approval: Samples Required 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Required Working Pressure for BOPE 0 2K Other: ',es+- '150 PE fc 3'500 r{. t' - ~ ~ _ _/ __ . by order of Approved By ,-~ CO~.· i)~ .... td-W ~,ommission Form 10-401 Rev. 12-01-85 ..' " I~ M _ App}oval Date See cover letter f L 7/ ù~ for other reauirements Mud Log Required 0 Yes ð1 No Directional Survey Required þg Yes 0 No o 3K D4K D5K D10K D15K 0 3.5K psi for CTU -II Date Sí ~/ 0) Subrh'it In Triplicate ') ) I Well Name: I C-16A /' Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 2A Bottom Hole Location: x = 664,130 116' FNL, 1218' FEL X = 664,925 510' FSL, 407' FEL X = 665,054 355' FNL, 300' FEL Y = 5,961,098 Sec. 19, T11N, R14E Umiat Y = 5,961,742 TVDss 8925 Sec. 18, T11 N, R14E Umiat Y = 5,960,879 TVDss 8930 Sec. 19, T11 N, R14E Umiat I AFE Number: 1 PBD4P2048 I 1 Estimated Start Date: 105/25/03 I Rig: 1 Nabors 2ES /' /' 1 I Operating days to complete: 117.5 1 MD: 110,400' I I TVD: 18,993' I 1 BF/MS: 135.18' I I KB: 128.5' 1 I KBE: 163.7' I Well Desian (conventional, slim hole, etc.): I Horizontal Sidetrack I Objective: 1 Zone 2A CasinQlTubinQ pro£ram Hole Size Csgl WtlFt Tbg O.D. 7" 4 %" Slotted x Solid 4 Y2" 8 Y2" 6" Tubing Directional KOP: I 9030' MD Maximum Hole Angle: Close Approach Well: Survey Program: Grade Conn Length Top 8tm /' /' MDITVD MDITVD L-80 8TC-M -5,420' 2650' / 2650' 8,073/7,773' ~' L-80 18T -1 ,520' 8880' / 8580' 10,400'/ 8,993' L-80 18T -8,850' GL 8880' / 8580' 26# 12.6# 12.6# -340 at 4400' MD (above window) _10 at the whipstock setting depth -900 in 6" horizontal section A close approach with C-36A at 9190' MD passes minor risk criteria for 1/200. The wells are at 277' center-center distance with 249' allowable /' deviation when minor-risk based. MWD plus IFR/Cassandra. Gyro to set whipstock and until kicked off. LOQging Program 6" Production: Sample Catchers - over entire interval, samples described and discarded. Drilling: MWD Dir/GRlRes- Real time GR/Res throughout entire interval. Open Hole: None Cased Hole: None C-16A Sidetrack Page 1 ) ) Formation Markers Formation Tops (wp05) MD TVDss TVDbkb Comments SV2 3634 3550 3614 SV1 4060 3938 4002 UG4 4630 4419 4483 WS2 6055 5701 5765 WS1 6252 5894 5958 CM3 6468 6107 6171 THRZ 7793 7429 7493 BHRZ 7988 7624 7688 LCU 7995 7631 7695 TJC 8366 8002 8066 TJA 8590 8226 8290 SAG RIVER 8678 8314 8378 SHUBLIK 8713 8349 8413 TSADITZ4 8789 8425 8489 TCGLITZ3 8940 8576 8640 BCGLITZ2C 9027 8663 8727 23SBITZ2BU 9068 8704 8768 JIÇ.JPi 22TSITZ2BL 9149 8782 8846 3240psi @ 8800 (± 7.1 ppg emw) 21 TSITZ2A 9226 8846 8910 PGOC 9284 8883 8947 HOT 8950 9014 Not Penetrated TZ1B 9430 8921 8985 TD 10,400 TD Criteria: Plan TD (10,400' MD) to maintain adequate standoff (-100') to fault #2 at 10550'MD. Mud Proaram Section MillinQ Mud Properties: QUIKDRIL-n Density (ppg) Viscosity PV 8.4 - 8.5 45 - 55 4 - 7 I Whip Stock Window 7" 29# YP MBT pH 25 - 30 <3 8.5 - 9.0 API FI N/C Production Mud Properties: QUIKDRIL-n Density (Ppg)j' Viscosity PV 8.4 - 8.5 45 - 55 4 - 7 I 6" hole section YP MBT pH 20 - 28 <3 8.5 - 9.0 API FI N/C Cement Proaram Casing Size r 7" Scab lJ{1er I \ Basis: Lead: Bas~d 34~O' of 7" x 9 5/8" annulus with 15% excess Lead TOC: 2675"MD Tail: Base o~åoo' of 7" x 9 5/8" annulus with 0% excess, plus 80' of 7" shoe. Tail TOC: - 075' MD Fluid Sequence & Volumes: Pre 10 bbls Fresh water Flush Spacer Lead Tail 10 bbls MUdPus~t 10.5 ppg 100 bbll 562 ft.j I .__ .' 'sks of Dowell 'G' at 13.5 ppg & 1.80 cflsk, 55 bbll 309 ft3 I 2 - sks of Dowell 'G' at 15.8 ppg & 1.16 cf/sk, C-16A Sidetrack Page 2 ') ) Casing Size I 4 Y2" 12.6#, L-80 Solid x Slotted (Bonzai) Liner Basis: Lead: None Tail: Based on 720' of 4 Y2" x 6" open hole annulus with 20% excess + 150 liner lap Tail TOC: 8880' MD /8580' TVD-bkb Fluid Sequence & Volumes: Pre 15bbls CW100 Flush Spacer Lead Tail 20 bbls MudPUSH XL at 9.5 ppg None LJ 16 bbls, 90 ft3'(2"sacks Class G @ 15.8 ppg, 1.17 ft3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blindlshear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Planned completion fluids 13-5/8", 5M, 3 MPL Gates with Annular (Hydril - 13-5/8" GK) 3240 psi (7.1 ppg @ 8800' TV D) ./,.,' 2360 psi (.10 psilft gas gradient to surface) Infinite / Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure 8.6 ppg Seawater I 7.2 ppg Diesel /' Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Complete Procedure SUmmary Pre-riQ Operations: A Schlumberger RST log on 4/30103 reveal 42' of fill on top of the upper packer from the cretaceous leak. 1. Test the FMC 9-518" pack-off and tubing hanger seals. Cycle the tubing hanger LDS. 2. Rig up slickline, pull the SSSV, drift and tag TD. Set a PXX plug in the tailpipe at 9285'. Replace all live GL Vs with dummy GL Vs. 3. Fluid-pack the tubing annulus and tubing with seawater, freeze protect to 2100' with diesel. 4. Chemical cut the 3 Y2" tubing at 9140' in the center of the first full joint above the 7" packer. And at 7980', the center of the first full joint above the 9 5/8" packer. 5. Circulate the well to seawater and freeze protect to 2100' with diesel. Set a BPV. 6. Remove the well house. If necessary, level the pad. C-16A Sidetrack Page 3 ) ) Riç, Operations: 1. MIRU Nabors 2ES. 2. Pull BPV, circulate out freeze protection with seawater and reverse circulate the well with 9.6 NaCI brine. Set TWC. ; 3. Nipple down tree. Nipple up and test BOPE. /, 4. Pull 4 Y2" x 3 Y2" tubing from the cut at 7980'. "/ 5. RIH with overshot and jars and recover the tubing stub from the PBR. 6. RIH with spear and recover the upper packer and tubulars below to the tubing cut (straight-pull 65K .-/ Ibs release retrievable packer). . 7. RU e-line and run GR/JB to top of fish at ±9100'. Set EZSV bridge plug on E-line (set as needed to// avoid cutting casing collar). 8. RIH with 9-5/8" test packer to -2675' MD and test 9-5/8" casing back to surface to verify integrity (for / upcoming tie-back liner to repair Cretaceous leak). POH. 9. RIH with 7" tieback receptacle polishing mill and polish the liner top 8,073' MD. 10. Run and cement a 7" 26# L-80 tie-back liner to cover Cretaceous interval. Liner is planned to extend from top of the existing drilling liner up to -2700' MD (surface casing shoe). / 11. MU milling BHA and mill the wiper plug and landing collar. Drift down through to the BP setting depth. Test the casing to 3500 psi, Change the well over to 8.4 ppg drill-in mud, POH. 12. RIH with 7" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Mill window in 7" casing at ±9,030' MD plus 20' minimum open hole below ~ window top. Perform FIT to 10.5 ppg EMW. Change the well over to 8.4 ppg Drill-In fluid, POH. 13. RIH with 6" directional assembly. Drill the 6" production section as per directional plan to an estimated // TD of 10,400' MD. CBU, POH. 14. Run a 4 Y2", 12.6# L-80 solid and slotted liner "Bonzai" production liner with inner cementing strjRg. Cement the liner in place, and displace well to clean seawater above liner top. POH LD DP. /' 15. Run 4-1/2",12.6# L-80 completion tying into the 4-1/2" liner top. 16. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes./, 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to -2200' and secure the well. 19. Rig down and move off. / Post-Riç, Work: 1. Install wellhouse and flow lines. 2. MIRU slickline. Pull the ball and rod 1 RHC plug from landing nipple below the production packer. Install gas lift valves. C-16A Sidetrack Page 4 ) '~ Job 1: MIRU Hazards and Contingencies );;> No wells will require shut-in for the rig move onto C-16A. The well is located on the northern end of the pad on 110' centers between wells C-17 A and C-15. C-17 A is a producer and the northern most well on the pad. It was producing at 1700 BOPD and 5000 GOR at last test. C-15 is shut-in due to TxlA communication is scheduled for a RWO. );;> C Pad is not an H2S site. Recent H2S data from the pad is as follows: ~/ Closest SHL Wells: C-15 None Recorded C-17 None Recorded Closest BHL Wells: C-36A None Recorded C-42 None Recorded The maximum level recorded of H2S on the pad in recent history was 10 ppm on C-26A and C-27A in 10/2000. )ì;> Post Permit to Drill in camp prior to spud. Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP .1".. ¡, /, ,.i':Im,~,:,I,:,I,~,:m,:,:,:m,I'.I,:,ln,:,I,I),I,IJ,1I,:",I,I.I.IJ,:,;':,:,:.I',:,:.;,I}',:,:,I.!,:'.:':;.;,:,:'':,:,:',,:¡.I,'.:.IJ.',:).:,;,;.~:,):I;I;:;':,;,;':':;.:;,)::~:,:;..,.,;..,:,:.:,:,.",;;..;;...":...:¡¡,.,I,.....,:,,..,.,.¡..',w.., ~:;:,;.::,.,:;.:.:,:~:.:,:,.".,:';,:,,:,:,",'I.',~ Job 2: De-complete Well Hazards and Contingencies );;> The cretaceous leak in the 9 5/8" casing will by isolated by the tubing hanger and BPV and, after circulating, kill-weight fluid only. Monitor the well to ensure the fluid column is static, prior to ND the tree and prior to pulling the completion. );;> NORM test all retrieved well head and completion equipment. );;> The existing wellhead is a BP original FMC big bore and has 7" IJ4S running threads on the tubing hanger. Inspect the tubing hanger after NO the tree to verify the thread type and ensure the threads are in good condition. Be prepared with necessary equipment to remove. );;> The exact balance mud weight for the cretaceous interval has not been determined. Typically the cretaceous is balanced at ±9.3 ppg. After circulating the well to seawater for the pre-rig work, the balance mud weight can be determined. Until the cretaceous pressure can be more accurately defined 9.6 ppg working fluid weight is assumed to be adequate. Reference RP .:. "De-completions" RP \ :11: _~:m.;."'I_!l:"U Job 6: Install 7" Tieback Liner Hazards and Contingencies );;> Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. );;> If fluid losses to the cretaceous leak continue with mud and light LCM, the cement design may be modified to a light-weight lead and tail slurry. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP C-16A Sidetrack Page 5 ) ) Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP ~:::~I:I: ::-.~~·\i:-I:I::II- -:1:1- -~::C_:_!:_!I_~_:lc__a_I__:__II:I1::!l'.Iln:l:aln:II_C::_11:!:nllll~:II_,.:I::I~__'__a__:__I_L_I~~I:t:lla_l:tllt1::'II!_mIIII11:11:11:IIII_mllll:III'_oI1:m::orm:::I_~;;~=;~¡~;;m~rm::I:mll~:!--IT:--'-:I: .'It'IICII__I:I'. _II~IIII::I~_ _1__II~la'I_I:II:lt~~:I:IWI_-:: I___-:I~~::- ,m:ra,m1Imnrlmltll«< Job 7: Drill 6" Production Hole Hazards and Contingencies ~ C-16A lies in a moderate risk area of the field for lost circulation. Only 4 loss circulation events were encountered in the Sadlerochit in 35 nearby wells. However, one fault crossing is expected so the risk of loss circulation events for C-16A is placed as average. It will be important to identify the fault while drilling, as it will be crossed just before landing in the horizontal. This fault (15-20 ft throw) will be crossed perpendicularly at about 9575 ft MD. A second fault (10ft throw) is present about 150 feet beyond the planned TO of the well at 10400 ft MD. In order to avoid placing the slotted liner completion too close to this fault the well should not be drilled beyond 10400 ft MD unless specifically directed to do so by the Town Geologist. Polygon lines are also hard lines to the east and west. A small fault parallels the well bore about 180 feet to the west of the proposed well. Another small fault tip-out zone is present about 150 feet to the east at about 9900 ft MD. If evidence of this fracture zone is apparent during drilling, the slotted liner completion should avoid this section. ~ The target polygon extends 360 feet beyond the second fault to permit the possibility of additional drilling in order to achieve the necessary pay section length of 300'. If the well is drilled through this second fault, or if the standoff to the GOC is inadequate, the slotted liner completion will be replaced by a cemented and perforated completion. Should the faults cause losses, follow the Lost Circulation Decision Tree. ~ One close approach has been identified with C-36A at planned depth of 9190' MD. The 277' center-center distance passes minor risk criteria of 1/200 with allowable deviation of 249'. Watch for indications of magnetic interference at this depth. Cease drilling and contact the drilling manager if wellbore interference is detected. ~ Zone 2 chert may wear the gauge on the first bit prior to completing the high-dogleg directional work. To avoid an added bit trip the directional plan forward should be reviewed for possible dogleg reduction so the second drilling BHA may finish the well. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP ~...... --- ~ oJ- "'._.......~, ,.....:...'!o.-I!I:';..... ~_.A Job 9: Install 4 Y2" Slotted Production Liner Hazards and Contingencies ~ The completion design includes a 4 Y2", 12.6#, L-80 solid x slotted liner throughout the production interval. Solid liner will be placed across the build section and first fault, as determined by the subsurface team. C-16A Sidetrack Page 6 ) ') )ò>- A relatively tortuous path through the reservoir coupled with a high differential pressure between hydrostatic and reservoir create concern for stuck pipe while running the liner. Ensure that the well is particularly clean prior to the final trip out of the hole and minimize connection time while running liner. )ò>- Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. )ò>- Sufficient 4 Y2" liner will need to be run to extend -150' back up into the 7" intermediate liner. Reference RPs .:. See Baker 'Inner-String Bonzai' Procedure ~_~' -,.!AAI,~¡';¡;",.~"'~:flln¡lf't"ff_ 11.\ .;¡¥_"¡'~'_-,U""~-it-'¡¡';'~.....,.\'I'-.,.\.:.,"I""¡'¡"¡;;'¡'¡K,:tT-t,\I~~;M;"'~!,I;¡';';'¡';';"¡"¡"W'W,(~.".:i'f.~¡';"¡;;";"¡¡'¡;.,4.~""....~~¡';';~;"¡/~~¡,"\,¡¡';'-".,. ~~~/W,Ii\~¡¡.)iI,~¡:fj.t#!~I;" ~-.r-.-,---'-.,\.'¡I'!'i'."~1«,M;;;,>¡¡';';','>;,I,.(~,(l:.Ä)"';";~~/Io,-,r¡.¡!iW,I;¡';',~ Job 12: Run Completion Hazards and Contingencies )ò>- Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP -~-"'" ""'X'«-'-v"".w..__,~ Job 13: ND/NU/Release Riq Hazards and Contingencies ~ There are no identified hazards particular to this phase of the operation. Reference RP .:. "Freeze Protecting an Inner Annulus" RP C-16A Sidetrack Page 7 6"FMC FMC ..............-,.~" ~ ~,~....,'w"........ ,",,, .,,~~"~ ~ OTIS 59.23' 35.18' ···············3206;· ... .......·..m 'à4@44oói '9160' 8800' SS 1REE = WELLHe:AD= "",~....... . .... ,,,,,,.~,.,....,, AClUATOR= ...."...."...~,...,."'w...".....,. ......,'~ ,",',~ "^ . "'" ,_·,'",·...,,,,"w....., ,.... KB. ELEV = ....;""."...,~".," " " BF. 8..EV = i(6Þ;;;;'" 'Kïiax'A'ngïë";;" öatÙinMb ;; "oàtüm TV 0; 4-1/2" lEG, 12.6#, L-80, 0.0152 bpf, ID= 3.958" H 1 TOPOF 3-1/2" TBG 1-1 13-3/8" CSG, 72#, L-80, ID = 12.347" H Minimum ID = 2.75 II @ 9166' 3·1/2" OTIS SLIDING SLEEVE 1 TOPOF 7" LNR 1-1 8073' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1--1 ) 2093' 2093' 2691' 8578' C-16 e é' f i.1 "'~ 8 :111 r--A II ~ D~ I ~ ~ 3-1/2" TBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992" 1--1 9286' 1 PERFORATION SUMI'v'\A. RY REF LOG: CBL ON 06/1 0180 ANGLEA TTOP ÆRF: 1 @ 9204' flbte: Refer to R"oductbn œ for historical perf data SIZE SFf' INTERVAL Opn/Sqz DATE 3-3/8" 4 9204-9212 S 08/23/89 3-318" 4 9220-9248 S 08/23/89 3-318" 4 9258-9275 S 08/23/89 3-318" 4 9275-9278 0 10/12/89 3-318" 4 9290-9322 0 10/12/89 2-1/8" 4 9274-9277 0 08/16/97 PBTD 1--1 7" LNR. 29#, L-80, 0.0371 bpf, ID= 6.184" H DATE 06/12/80 01/25/90 01/31/01 03/09/01 09/06/01 REV BY COM~NTS ORIGINAL CCHv'PLErION LA STWORKOVER 00 NVERfED TO CANVAS ANAL OORRECnONS SI8-lsl SIS-LG RN'TP 9369' 9475' DA. TE ~ REV BY ) / 2068' 1- 4-1/2" SSSV, CAMOO BAL-O LANDNG NIP, ID = 3.813" 2093' H 4-1/2" X 3-112" XO 1 GAS LIFT MANDRELS ~ ST MD TVD DEV TYPE VLV LATa-i PORf DATE 5 2992 2998 7 MERLA RA 4 5006 4801 29 MERLA RA 3 6995 6699 3 MERLA RA 2 7486 7199 0 MERLA RA 1 7944 7595 0 MERLA RA L ~I'"'~I." ì 7965' 1--1 3-1/2" OllS X NIP, ID = 2.750"? 8000' 1--1 TBG SEAL ASSY 1 8024' 1--1 9-5/8" X 3-112" BA Kffi H3 ROT PKR, ID = 3.00" 9144' 1--1 MARKER JOINT I 9166' 1--1 3-1/2" OllS SLIDING SLEEVE, D = 2.750" 9190' 1--1 BLAST JOINTS TOP 1 9278' 1--1 BLAST JOINTS BTM 1 9279' 1-1 7" X 3-1/2" BAKER 3H-7 PKR, D = 3.25" I 9285' 1-1 3-1/2" OllS X NIP, ID = 2.750"? 1 9286' 3-1/2" TLBING TAIL I 9287' ELMD TT LOGGED 07/15/97 ~ I , 00 rvTv18'JTS FRUDHOE SA Y UNIT W8...L: C-16 ÆRMIT No: 80-0100 APII\b: 50-029-20438-00 Sec.19,T11N,R14E 8P Exploration (Alaska) TREE = WB.lHEAD = ".~,,",,~'" "",, ""~",',., ,..,,,",,,...~.. "-"",,, ".,''''''''~'''''' ACTUA TOR = . '. '......"."............"......""".., KB. ELEV = BF. ELEV = ,.'~..".'."." .~...".".,~"...",",o<..".,~".,,."'"'' ,'" KOP= .~..~.~.~!.:.:.._... """""""'"''.--''''''-''''-''' Datum MD = [)atürn·iVtf;·····..··········..·..······,······8'äÖÕ;·š·S 6" HAC FI\I1C OTIS .....,,,,,.'....,'"..-,,,.,.....,,..,,......... 59.23' 35.18' ...".."....,".".".-....."."..., .,......"",,,.,,,..,,"....,,.....,..,,"..'..... 3200' , "...... .'~.,..,~....".",",..,..."""".'._"..,,".,,,._,-,'",.~. Horizontal ) C-16A Proposed 4-1/2" TBG. 12.6#. l-80, 0.0152 bpf, ID = 3.958" l-i Top of 7" 26# scab liner l-i 13-3/8"CSG, 72#, l-80,ID= 12.347" l-i 2093' ~ 2675' Irl 2691' I/~ I Minimum ID = 3.725 II @ 4-1/2" XN Nipple ,'.. "'~ 41 I TOP OF 7" LNR l-i 8073' -- ¡£ g 9-5/8" CSG, 47#, l-80, ID = 8.681" l-i 8578' ~ I 4 1/2" Bonzai Liner Top l-i 8,880' I I Whipstock / top of 7" Window l-i 9,030' I Rsh: 3-1/2" TBG, Sliding Sleeve. Blast Joints l-i 9100' PERFORATION SUMMARY REF lOG: CBl ON 06/10/80 ANGLE AT TOP ÆRF: 1 @ 9204' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9204-9212 S 08/23/89 3-3/8" 4 9220-9248 S 08/23/89 3-3/8" 4 9258-9278 S 08/23/89 3-3/8" 4 9290-9322 S 10/12/89 3-3/8" 4 9274-9277 Zone 2 10/12/89 2-1/8" 4 9290-9325 Zone 1 08/16/97 PBTD 1-1 9369' 7" LNR, 29#, L-80. 0.0371 bpf, 10 = 6.184" l-i 9475' DATE 06/12/80 01/25/90 01/31/01 03/09/01 09/06/01 REV BY SIS-lsl SIS-LG RNlTP COMMBITS ORIGINAL COMA..ErION LAST WORKOVER CONVERTED TO CANV AS FINAL CORRECTIONS DATE 03/24/03 ~} J, ~ ~ ~ ~ ª 2.. I> 117: w¡~ . ~, 4\. ~.. " ,eli, " '\ . v. .. ..". _. v. . - D~ 8: 8: ~ ~ . ~'~ . J ~ ST ~ : L: ~ ~"! f 1 .,:J ~ If!) ~: . ;;:,'.1 . iiJ ~ REV BY PGS COMM:NTS Proposed Sidetrack ) ..// 2100' 1- 4-1/2" "X" Landing Nipple ID = 3.813" GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORT RA RA RA RA RA DATE 8820' 88401 8860' 8870' 8880' 4 1/2" X Nipple 7" X 4-1/2" BAKER S-3 Permanent Packer 4 1/2" X Nipple 4 1/2" XN Nipple 4 1/2"~ ..16! H 4 112" ECPISolid Line' I ·¡:·:,:"",.~·...:':'I::i:x:.··.:'::,::.~::I:i.£5<:] _ _ _ _ _ _ , :i~'\I~ - - - - - .1' 1 10,400' l-i 41/2" Slotted Liner 92861 l-i 3-1/2" TUBING TAL I Greater Prudhoe Bay WELL: C-16A PERMIT No: 80-0100 API No: 50-029-20438-01 Sec. 19.T11N,R14E BP Exploration (Alaska) bp ~~f'r. ~...~~ ... COMPANY DETAILS HI) Ank"Cfl Cakul.1t¡'\1I ~kllkld: Minimw11 CI..W\'Jtun: Em'r S)'sh:m: ISCWSA $(-3n Mclhod: Tr.w ("ylild:r<North Error Su,fa¡;~: Ellirtk:3 . Casing. WantUIF- M":lhod: Ruk-s Ih~...J All TVD depths are ssTVD plus 63. 68'for RKBE. 8600- g 8800 ~ Slart Oir 12/100' : 9030' MO, 8729.72'TVD . .' /' Start Oir 18/100': 9050' MO, 8749.7'TVD ßCaL --1/ . ¡ .. Start Oir 25/100': 9080' MO, 8779.56'TVD 23SB. --1¿ ~W_ . \~tJ,0 22TS "'-\0 <,'¡; \~ . 2; TS-"\' ~, ~ . > "'^<·f~ j pabc ,....0..,~ ~ c. Ö ] ';:: -> '" ¡:: 9000 -200 REFERENCE [t,'FORMATION C~rdina~ (N'E) Reference: Well Centre: C-]6. Trœ- North Vertical (IVD) Reference: 63_68" 63.68 s.."tion (VS) Refen,nce: U.." Defiœd (921.59N.97 U8E) M(';bLIr\.>d 1À'P1h Referenr..--e: 63.68' 63.68 Cakulatîl.'o[] Method: Minimum Curvature o IOifJ I gr/ "eI I I 11< I ¡i , rfJOO 000 II SURVEY PROGRAM Plan: C-I6A wp05 (C-I6IPlan C-16A) Depth Fm D.:pth To Survey/Plan 9030.00 1(}00.00 Plann<d: C-16A "-1'05 V8 Tool Created B}c Ken Allen Checked: Dale: Dale: 3/20/2003 MWD Revie\ved : Date. WELL DETAILS Narœ ~NI.s ~E!-W Latirnie Longitude Slot Northing Easting C-16 3844.48 166359 5961098.00 664130.00 70oI8'oo.l76N 14S"4O'14.299W 16 TARGET DETAILS Narœ TV!) +Nf·S ~E!-W Northing Easting Shape C-16A 1st ~ll 8988.68 595.84 74825 5% 1710.00 664865.00 Polygon C-I6A 10400' 8992.76 -23954 918.79 5960878.60 665053.74 Point C-16A Pol)"gon 8993.68 510.86 74639 5961625.00 664865.00 Polygon C-16A 1st 001 8993.68 494.55 806.05 5%1610.00 664925.00 Point SECTION DETAILS Sec MD Inc Azi TVD +NI-S +EI-W DLeg TFace VSec Target I 9030.00 1.09 31 \.24 8729.72 921.59 971.38 0.00 0.00 0.00 2 9050.00 3.25 278.49 8749.70 921.80 970.68 12.00 -47.00 -0.18 3 9080.00 7.97 248.75 8779.56 92 I.I 7 967.90 18.00 -47.00 0.57 4 9402.29 86.62 208.27 8983.42 740.61 850.94 25.00 -41.06 186.25 5 9410.34 86.62 208.27 8983.89 733.53 847.13 0.00 0.00 193.49 6 9657.30 89.00 171.27 8993.68 494.55 806.05 15.00 -87.17 434.09 C-16A 1st dnl 7 9675.37 90.08 I7 \.2 7 8993.82 476.69 808.79 6.00 -0.07 451.80 8 10400.00 90.08 171.27 8992.76 -239.54 918.79 0.00 0.00 1162.32 C-16A 10400' --- FORMATION TOP DETAILS No. TYDPath MDPath Formation I 8726.68 9026.96 BCGL 2 8767.68 9068.03 23SB 3 8845.68 9148.89 22TS 4 8909.68 9225.75 2ITS 5 8946.68 9283.30 PGOC 6 8979.68 9372.18 TZIB CASING DETAILS No. TVD MD Name Size 8992.76 10399.99 4 II2" 4.500 <000 /Ooo~~ s§> '/000 ~ End Dir : 9402.29' MD, 8983.42' TVD Start Oir 15/100': 9410.34' MD. 8983.89'TVO Start Dir 611 00' : 9657.3' MD, 8993.68'TVD I JE~dD~, :..9675.37:MO' ~9,~3~~2'.~~~ ----- I I I I I I I I I I I I I I I I I I I I I I Vertical Section at 182.59° [200ft/in] I I I 1400 I I I ]600 Plan: C-I6A wpO; (C-16/Plan C-I6A) Created By: Ken Allen Date: 3/20/2003 Date: Date: Tool MWD SURVEY PROGRAM D<ptJ1I'm Dc>pth T" Sur"')'iPbn 9030.00 I 0-100.00 Planned: C-I6A wp05 V8 Checked : Reviewed: WELL DETAILS EastiDg 661130.00 LongibJd;: Slot 148"40H299W 16 Shape Polygo Point Polvrt!o Poiñi Easting 661865.00 665053.74 661&65.00 664925.00 Targe VSee 0.00 -0.18 0.57 186.25 193.49 434.09 451.80 162.32 Lalituœ 700¡8"OO.I76N TARGET DETAILS +N!·S +FJ-W Northing 61710.00 60878.60 61625.00 61610.00 TF~e QOO 4~OO 4~OO 41.M QOO -87.17 ~~ QOO DLeg 0.00 12.00 18.00 25.00 0.00 15.00 6.00 0.00 7482 918.7 7463 806.0 SECTION DETAILS +N/-S +E/- W 921.59 921.80 921.1 7 740.61 733.53 494.55 476.69 -239.54 Northing 5961098.00 TI'D 8988.68 C·I6A I(}JOO' 8992.76 C-16A Polygon 8993.68 C·16A 1st dnl 8993.68 971.3 8 970.68 967.90 850.94 847.13 806.05 808.79 918.79 95.84 3954 10.86 9455 TVD 8729.72 8749.70 8779.56 8983.42 8983.89 8993.68 8993.82 8992.76 ~FJ·W 16635 -Nl-S Nan., Azi 311.24 278.49 248.75 208.27 208.27 171.27 171.27 171.27 Nan., Ine 1.09 3.25 7.97 86.62 86.62 89.00 90.08 90.08 MD 9030.00 9050.00 9080.00 9402.29 9410.34 9657.30 9675.37 0400.00 See I 2 3 4 5 6 7 8 REFERENCE INFORMATION C(K)cdinate (N'E) Refen."11œ: Well Centre: C-16. Trn: North Vertical (1VD) Reference: 63.68' 63_68 Section (VS) Reference: User Defmed (92159N.9713SE) Meosun:d Depth Refcrcnœ: 63.6S· 63.68 Cak:u1ation Methcd: Mi:nimum Cur....ature - ./ C-36A (C-36A) ir 12/100': 9030' MD. 8729.72'TVD ir 18/100': 9050' MD, 8749.7'TVD r 25/100' : 9080' MD. 8779.56'TVD " MD, 8983.42' TVD 9410.34' MD, 8983.89'TVD bp ~..¡..o~lI~.. .0 '... ~~..t ";:Ik:uJ:lIion M~,;11)L.J: MmlffiWll CwyatlJfl: EmIr Syst~m: ISCWSA &30 ~h:lhod; Trav C'ilin&.:r Nonh Errl\r Surf.lce: Elliptkåt ~ Ca....ing \Vamin~. Mdlk-.J: Rules Ibs....... 200- ~ ~ C-36APBI (C-36APB I I I I 900 dr 040~ Fonnation BCGL 23SB 22TS 2ITS PGOC TZIB Size 4.500 I C-16A C-I6A FORMATION TOP DETAILS No. TVDPath I 8726.68 2 8767.68 3 8845.68 4 8909.68 5 8946.68 6 8979.68 CASING DETAILS Name 41/2' MDPath 9026.96 9068.03 9148.89 9225.75 9283.30 9372.18 MD 0399.99 TVD 8992.76 - o ,rI I I .,,1 I I ~ I rI ,I /1 TVD depths are ssTVD plus 63. 68'jor RKBE. Depth: 10400' MD. 8992.76' TVD 600 300 ~ ~ : õ VJ I 500 I 1200 West(-)/East(+) [300ft/in] -300 -600 ) BP KW A Planning Report MAP \ , Company: Fiëld: Site: Wëll: WeUpath: BP Amoco Prudho.e Bay PB C Pad C~16 Plan .C~ 16A . . . Date: 3/20/2003 Time: 14:19:38 Page: Co-ordinate(NE) Rëferencë: Well: C-16, True North Vertical (TVD) Reference: 63;68' 63.7 SeCtion (VS) Rëferëncë: User (921.59N,971.38E, 182.59Azi) Survey Calculation Mdhod: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957218.72 ft 662550.03 ft Latitude: Longitude: North Reference: Grid Convergence: Alaska, Zone 4 Well Centre BGGM2002 70 17 22.367 N 148 41 2.797 W True 1.24 deg Well: C-16 Slot Name: 16 C-16 Well Position: +N/-S 3844.48 ft Northing: 5961098.00 ft Latitude: 70 18 0.176 N +E/-W 1663.59 ft Easting : 664130.00 ft Longitude: 148 40 14.299 W Position Uncertainty: 0.00 ft Well path: Plan C-16A Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 971.38 Current Datum: Magnetic Data: Field Strength: Vertical Section: 63.68' 12/5/2002 57537 nT Depth From (TVD) ft 0.00 +N/-S ft 921.59 Height 63.68 ft Plan: C-16A wp05 Date Composed: Version: Tied-to: Principal: Yes Casing Points C-16 9030.00 ft Mean Sea Level 26.02 deg 80.82 deg Direction deg 182.59 3/20/2003 8 From: Definitive Path 10399.99 8992.76 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 9026.96 8726.68 BCGL 0.00 0.00 9068.03 8767.68 23SB 0.00 0.00 9148.89 8845.68 22TS 0.00 0.00 9225.75 8909.68 21TS 0.00 0.00 9283.30 8946.68 PGOC 0.00 0.00 9372.18 8979.68 TZ1B 0.00 0.00 Targets Map Map <--- Latitude --> <--- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft C-16A 1st Fit 8988.68 595.84 748.25 5961710.00 664865.00 70 18 6.035 N 148 39 52.483 W -Polygon 1 8988.68 595.84 748.25 5961710.00 664865.00 70 18 6.035 N 148 39 52.483 W -Polygon 2 8988.68 476.14 1190.77 5961600.00 665310.00 70 18 4.858 N 148 39 39.582 W C-16A 10400' 8992.76 -239.54 918.79 5960878.60 665053.74 70 17 57.819 N 148 39 47.514 W C-16A Polygon 8993.68 510.86 746.39 5961625.00 664865.00 70 18 5.200 N 148 39 52.538 W -Polygon 1 8993.68 510.86 746.39 5961625.00 664865.00 70 18 5.200 N 148 39 52.538 W -Polygon 2 8993.68 186.02 734.29 5961300.00 664860.00 70 18 2.005 N 148 39 52.891 W -Polygon 3 8993.68 -146.43 842.06 5960970.00 664975.00 70 17 58.735 N 148 39 49.751 W ·Polygon 4 8993.68 -746.33 828.96 5960370.00 664975.00 70 17 52.835 N 148 39 50.134 W ) BP \ I KW A Planning Report MAP Company: BP Amoco Date: 3/20/2003 Time: 14:19:38 Page: 2 Field: Prud hoe Bay Co-ordinate(NE) Reference: Well: C~16. True North Site: PSC Pad Vertical (TVD)Reference: 63.68' 63.7 Well: C-16 Section (VS) Reference: User (921.59N;971.38E.182.59Azi) Wellpatb: Plan C-t6A . Survey Calcuhition Method: Minimum Curvature Db: Oracle Targets Map Map <---- Latitude· ----> <--- Longitude ---> Name Description TVD +N/-S +E/- W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft -Polygon 5 8993.68 -751.25 1053.92 5960370.00 665200.00 70 17 52.786 N 148 39 43.577 W -Polygon 6 8993.68 -150.58 1032.03 5960970.00 665165.00 70 17 58.694 N 148 39 44.213 W -Polygon 7 8993.68 227.63 890.25 5961345.00 665015.00 70 18 2.414 N 148 39 48.344 W -Polygon 8 8993.68 467.70 890.49 5961585.00 665010.00 70 18 4.775 N 148 39 48.337 W C-16A 1st dn1 8993.68 494.55 806.05 5961610.00 664925.00 70 18 5.039 N 148 39 50.798 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build. . Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9030.00 1.09 311.24 8729.72 921.59 971.38 0.00 0.00 0.00 0.00 9050.00 3.25 278.49 8749.70 921.80 970.68 12.00 10.76 -163.75 -47.00 9080.00 7.97 248.75 8779.56 921.17 967.90 18.00 15.76 -99.15 -47.00 9402.29 86.62 208.27 8983.42 740.61 850.94 25.00 24.40 -12.56 -41.06 9410.34 86.62 208.27 8983.89 733.53 847.13 0.00 0.00 0.00 0.00 9657.30 89.00 171.27 8993.68 494.55 806.05 15.00 0.97 -14.98 -87.17 C-16A 1st dn1 9675.37 90.08 171.27 8993.82 476.69 808.79 6.00 6.00 -0.01 -0.07 10400.00 90.08 171.27 8992.76 -239.54 918.79 0.00 0.00 0.00 0.00 C-16A 10400' Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/100ft deg 9026.96 1.09 311.79 8726.68 8663.00 5962040.49 665081.00 0.03 0.00 0.00 BCGL 9030.00 1.09 311.24 8729.72 8666.04 5962040.53 665080.95 0.00 0.35 280.20 MWD 9050.00 3.25 278.49 8749.70 8686.02 5962040.72 665080.25 -0.18 12.00 313.00 MWD 9068.03 5.95 254.96 8767.68 8704.00 5962040.52 665078.84 0.05 18.00 313.00 23SB 9075.00 7.12 250.92 8774.60 8710.92 5962040.27 665078.09 0.32 18.00 336.47 MWD 9080.00 7.97 248.75 8779.56 8715.88 5962040.03 665077.48 0.57 18.00 340.48 MWD 9100.00 12.19 233.02 8799.25 8735.57 5962038.19 665074.54 2.48 25.00 318.94 MWD 9120.00 16.84 225.56 8818.61 8754.93 5962034.81 665070.85 5.95 25.00 334.44 MWD 9140.00 21.64 221.29 8837.48 8773.80 5962029.91 665066.46 10.95 25.00 341.66 MWD 9148.89 23.80 219.93 8845.68 8782.00 5962027.26 665064.28 13.65 25.00 345.69 22TS 9160.00 26.51 218.53 8855.74 8792.06 5962023.53 665061.38 17.44 25.00 346.95 MWD 9180.00 31.42 216.57 8873.23 8809.55 5962015.72 665055.66 25.39 25.00 348.22 MWD 9200.00 36.36 215.10 8889.83 8826.15 5962006.54 665049.34 34.72 25.00 349.93 MWD 9220.00 41.30 213.94 8905.41 8841.73 5961996.06 665042.4 7 45.36 25.00 351.16 MWD 9225.75 42.73 213.64 8909.68 8846.00 5961992.81 665040.39 48.65 25.00 352.06 21TS 9240.00 46.26 212.98 8919.84 8856.16 5961984.35 665035.10 57.24 25.00 352.28 MWD 9260.00 51.22 212.17 8933.03 8869.35 5961971.51 665027.29 70.26 25.00 352.75 MWD 9280.00 56.19 211.47 8944.86 8881.18 5961957.63 665019.09 84.32 25.00 353.29 MWD 9283.30 57.01 211.36 8946.68 8883.00 5961955.25 665017.71 86.73 25.00 353.70 PGOC 9300.00 61.16 210.85 8955.26 8891.58 5961942.83 665010.58 99.32 25.00 353.76 MWD 9320.00 66.13 210.28 8964.13 8900.45 5961927.21 665001.81 115.14 25.00 354.03 MWD 9340.00 71.11 209.75 8971.42 8907.74 5961910.89 664992.86 131.67 25.00 354.28 MWD 9360.00 76.09 209.26 8977 .07 8913.39 5961893.99 664983.78 148.77 25.00 354.47 MWD 9372.18 79.12 208.97 8979.68 8916.00 5961883.48 664978.22 159.42 25.00 354.61 TZ1B 9380.00 81.07 208.78 8981.03 8917.35 5961876.65 664974.65 166.33 25.00 354.68 MWD 9400.00 86.05 208.32 8983.27 8919.59 5961859.00 664965.54 184.19 25.00 354.71 MWD 9402.29 86.62 208.27 8983.42 8919.74 5961856.97 664964.50 186.25 25.00 354.76 MWD 9410.34 86.62 208.27 8983.89 8920.21 5961849.81 664960.85 193.49 0.00 0.00 MWD 9425.00 86.73 206.07 8984.74 8921.06 5961836.64 664954.45 206.80 15.00 272.83 MWD 9450.00 86.93 202.32 8986.13 8922.45 5961813.66 664944.73 230.00 15.00 272.96 MWD 9475.00 87.14 198.57 8987.42 8923.74 5961790.09 664936.52 253.76 15.00 273.16 MWD 9500.00 87.37 194.82 8988.62 8924.94 5961766.03 664929.87 277.98 15.00 273.36 MWD ) BP ) KW A Planning Report MAP Company: BP Amoco Date: 3/20/2003 Time: 14:19:38 Page: 3 . Field: Prudhoe Bay Co~ordinate(NE)·Reference: Well: C-16, True North Site: PB C Pad Verticål(TVD) Reference: 63.68'63;7 Well: C~16 Section (VS) Reference: User (921.59N,971.38E,182.59Azi) Wellpatb: Plan C-16A Survey Calculation Method: Mihimum Curvature Db: Oracle Survey lile! Azim TVD Sys TVD MapN Map.E VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/100ft deg 9525.00 87.60 191.08 8989.72 8926.04 5961741.57 664924.81 302.54 15.00 273.54 MWD 9550.00 87.85 187.33 8990.71 8927.03 5961716.84 664921.36 327.35 15.00 273.70 MWD 9575.00 88.11 183.59 8991.59 8927.91 5961691.93 664919.52 352.30 15.00 273.85 MWD 9600.00 88.37 179.84 8992.36 8928.68 5961666.95 664919.32 377.28 15.00 273.98 MWD 9625.00 88.64 176.10 8993.01 8929.33 5961642.00 664920.75 402.19 15.00 274.10 MWD 9650.00 88.92 172.36 8993.55 8929.87 5961617.20 664923.80 426.91 15.00 274.20 MWD 9657.30 89.00 171.27 8993.68 8930.00 5961610.00 664925.00 434.09 15.00 274.28 C-16A 1st dn1 9675.37 90.08 171.27 8993.82 8930.14 5961592.21 664928.13 451.80 6.00 359.93 MWD 9700.00 90.08 171.27 8993.79 8930.11 5961567.95 664932.40 475.95 0.00 0.00 MWD 9800.00 90.08 171.27 8993.64 8929.96 5961469.48 664949.74 574.00 0.00 0.00 MWD 9900.00 90.08 171.27 8993.49 8929.81 5961371.00 664967.07 672.06 0.00 0.00 MWD 10000.00 90.08 171.27 8993.35 8929.67 5961272.52 664984.40 770.11 0.00 0.00 MWD 10100.00 90.08 171.27 8993.20 8929.52 5961174.04 665001.74 868.16 0.00 0.00 MWD 10200.00 90.08 171.27 8993.05 8929.37 5961075.56 665019.07 966.21 0.00 0.00 MWD 10300.00 90.08 171.27 8992.91 8929.23 5960977.08 665036.41 1064.27 0.00 0.00 MWD 10400.00 90.08 171.27 8992.76 8929.08 5960878.60 665053.74 1162.32 0.00 0.00 C-16A 10400' P055055 DATE 4/4/2003 INVOICE I CREDIT MEMO INV# CK0401 03E THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 . ANCHORAGE, AK.99519-6612 PAY: TO THE ORDER OF: DATE 4/4/2003 CHECK NO. 055055 DESCRIPTION GROSS VENDOR DISCOUNT NET PERMIT TO DRILL FEE Q. \loA- F~:o F {:~ ::~ r ~./ (¡ i ..J-~;·r:;~:ê: -~~:< E~ Gf':.i- ~-~-~~~~-_. ;-:i'-: ~_Y-~~ ::~ ~'-_. ~ - TOTAL ~ No~ 'p 05505<5 CONSOLIDATED COMMERCIAL ACCOUNT B..?..!......p. ····...f. ·.---'lA. .... ..:......:.(..J...u........~.:...1...:.:.t.:. tlilt¡ ~.CJ ." .~. ~'. :.. UIL.·.ln¡¥ ,w", '-. -." --' "d-... . -. .',', -. .-'-''- '- ~-' :-::- .-..;:.'-- ; "-....,". .' _:. -'~'-< . '- .-- ',..:' ""-' -: :-:.-.-; " _." . _ d_. _':. .'_ "" __'n . .. . ,_,-_ '_n"' "--.:..:: -,:: _: -'- -- :_" ..-.--'." -'-' '- .-,' "'-... -:'- -._-:-- '- -'-"- _."- :-:":'.-,- . _'c· . '.' "--- ';,--",_ . .... -.- -' .-...' ALASKA OIL & GAS CONSÊR\l.ðTION 333 W 7TH AVENUE· SUITE 100 ANCHORAGE,AK 99501-3539 0":": _,; - -;-,--. '- -;'::' ::-.-."-";.'-.,. .-.. --- - - --..-. -. ".". . ..-.-- --... --' -'-- -.-' .. -' ".-. -~-::.-::.: :, - --.:::' -.---, -'-. :-:::-:-:: - - - - ~._: -:":- .- .:~:: ;::~:: .' -": '. - -.-:. - - . - - -- -- N;VAL~:t~:~/{~~~~~¡?jt~;.~:;~~~:t':;\?j '. .... ....... ''':~i~;~ ...... ..... ..-- ....... .... . ... <t't'" f;'},fÝ{:i~+¥i,~:;J~::¡;¡;;~i;\S?; III 0 5 5 0 5 Sill I: 0 ~ . 2 0 :I 8 ~ 5 I: O. 2 7 8 ~ b III H '-' --- ) ) . TRANSMJT AL LETTER CHECK· LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 C\jody\templates The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception tbat may occur. All dry ditch sample sets submitted to the Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intenrals througb target zones. WELL PERMIT CHECKLIST COMPANY ßP *' WELL NAME (ß(..I (- - / b A PROGRAM: Exp _ Dev...)t.. Redrll:;zš..- Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL b '-j 6 1 5"0 INIT CLASS LJ lU/ / ~ ð// GEOL AREA ~ 7 t'~ UNIT# / / b S ð ON/OFF SHORE ~.v ADMINISTRATION 1. Permit fee attached. ......... ........... ~ N 2. Lease number appropriate. . . . . .. ........... Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . Y N /),0/ 5 ~/03 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . Y N Af..(,.L. ï~ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . U/ N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ ~ N~ ¡:¡ I (Service Well Only) 14. All wells w/in ~ mile area of review identified. . . . . . . . .. Y. N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . Y N 16. Surface casing protects all known USDWs. . . . . . . . . . Y N . 17. CMT vol adequate to circulate on conductor & surf csg. . . . -¥--.-N- AliA- 18. CMT vol adequate to tie-in long string to surf csg. . ~.N- AI/It- 19. CMT will cover all known productive horizons. . . . . . . . . é:tI-. N 20. Casing designs adequate for C, T, B & permafrost. . . . . . ~. N Ai _ I "4J 0 'Z.G- S . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . N ¡..--S 22. If a re-drill, has a 10-403 for abandonment been approved. . ® N 23. Adequate wellbore separation proposed.. . . . . . . . . . . . @ N 24. If diverter required, does it meet regulations. . . . . . . . . . -¥-N- ¡Ú/~ , 25. Drilling fluid program schematic & equip .Iist adequate. . . . . j N fJ1 R,{/ rY/ w &, 7 (J Pq . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N " 27. BOPE press rating appropriate; test to 3500 psig. . N flit c.,.p 2..3&0 p£¿ '. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . éí2 N 29. Work will occur without operation shutdown. . . . . . . . . . . (J/ N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-M"" NI Æ- 32. Permit can be issued wlo hydrogen sulfide measures. . . . . ly fÑ) 33. Data presented on potential overpressure zones. . . . . . . . Y 'i\ú 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y ;1./, A . 35. Seabed condition survey (if off-shore). . . . . .. ...... Y N 36. Contact namelphone for weekly progress reports. ...... N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP~ APPR DATE WGA- 5/(0103 (Service Well Only) GEOLOGY APPR DATE If;, S-~/03 ?~XPloratory Only) Rev: 07/12/02 UIC ENGINEER TEM JDH JBR SFD_ WGA / MJW G:\geology\perm its\checklist.doc COMMISSIONER: COT DTS ~ t ,{ Comments/Instructions: ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennilling Process but is part of the history file. To improve the readability of the Well History file and to sim,plify finding infonnation, infomlalion 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. Sperry-Sun Dr __'ling services LIS Scan Utility ) ~·3 -oel.þ \\2>\\ $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 01 14:05:09 2003 Reel Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/07 / 0 1 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER WOA/PBU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA C-16A 500292043801 BP EXPLORATION Sperry-Sun Drilling Services 01-JUL-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002461818 J. BOBBITT J. RALL MWD RUN 2 MW0002461818 J. BOBBITT J. RALL MWD RUN 3 MW0002461818 J. BOBBITT J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 14E 116 1218 61.77 35.18 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 9040.0 # REMARKS: ) ) 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS EFFECTED BY MEANS OF AN OPEN-HOLE SIDETRACK AT 9730'MD WITHIN THE RUN 2 INTERVAL OF THE C-16A PB1 WELLBORE. THIS SIDETRACK WAS NECESSITATED DUE TO AN UNRETRIEVABLE FISH IN C-16A PB1. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THE WHIPSTOCK (THE TOP OF WHICH WAS AT 9040'MD/8740'TVD IN THE PB1 WELLBORE) WAS POSITIONED AND THE WINDOW MILLED PRIOR TO RUN 1. TIE-IN SGRC DATA OVER THE INTERVAL 88061MD TO 9018'MD (BIT DEPTHS) WERE ACQUIRED WHILE POOH AFTER RUN 1 AND ARE PRESENTED WITH RUN 1 DRILLED DATA. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DGR¡ ELECTROMAGNETI WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND AT-BIT INCLINATION (ABI). 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED 4.5' DEEPER PER E-MAIL FROM D. SCHNORR DATED 6/9/03. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 1 - 3 REPRESENT WELL C-16A WITH API#: 50-029-20438-01. THIS WELL SEGMENT REACHED A TOTAL DEPTH (TD) OF 10350'MD/8973ITVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves¡ all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH 8811.0 9045.0 9459.5 9459.5 9459.5 9459.5 9459.5 ) STOP DEPTH 10291.5 10354.5 10298.5 10298.5 10298.5 10298.5 10298.5 ) # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8811.0 10354.5 $ GR 8806.5 10350.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 # REMARKS: MERGED MAIN PASS. $ MERGE TOP 8806.5 9510.0 9730.5 MERGE BASE 9510.0 9730.0 10350.0 # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR Min 8811 0.02 8.8 5.04 5.57 7.24 8.42 0.4 MWD MWD MWD MWD MWD MWD MWD Max 10354.5 679.49 193.82 77.16 137.98 2000 2000 35.81 Mean 9582.75 62.6724 44.2791 16.3483 18.5694 41.3974 45.7761 3.77489 First Reading For Entire File......... .8811 Last Reading For Entire File.......... .10354.5 Nsam 3088 2620 2962 1679 1679 1679 1679 1679 First Reading 8811 9045 8811 9459.5 9459.5 9459.5 9459.5 9459.5 Last Reading 10354.5 10354.5 10291.5 10298.5 10298.5 10298.5 10298.5 10298.5 ') ) File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 8806.5 9040.5 STOP DEPTH 9467.5 9510.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 31-MAY-03 Insite 4.3 Memory 9510.0 9062.0 9510.0 1.1 96.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER 69706 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 9040.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): QUICK-DRILL 8.40 46.0 9.0 400 20.0 RESISTIVITY (OHMM) A1 .)MPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: ) .000 .000 .000 .000 .0 115.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8806.5 9510 9158.25 1408 8806.5 9510 ROP MWDOI0 FT/H 0.02 641.47 53.4932 940 9040.5 9510 GR MWD010 API 8.8 193.82 36.8555 1323 8806.5 9467.5 First Reading For Entire File......... .8806.5 Last Reading For Entire File.......... .9510 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record..65535 File Type............. ...LO Previous File Name...... .STSLIB.002 ) Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX RPS GR ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 9455.0 9455.0 9455.0 9455.0 9455.0 9468.0 9510.5 STOP DEPTH 9730.0 9730.0 9730.0 9730.0 9730.0 9730.0 9730.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 01-JON-03 Insite 66.37 Memory 9730.0 9510.0 9730.0 88.2 96.9 TOOL NUMBER 184054 159436 6.000 9040.0 QUICK-DRILL 8.40 46.0 9.0 400 20.0 1.900 .930 1.860 1.920 70.0 150.0 70.0 1.9 S . f·, ") d Data Format pecl lcatlon R~~or Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9455 9730 9592.5 551 9455 9730 ROP MWD020 FT/H 2.05 187.72 93.5539 440 9510.5 9730 GR MWD020 API 27.03 158.94 88.5252 525 9468 9730 RPX MWD020 OHMM 5.47 77.16 14.5757 551 9455 9730 RPS MWD020 OHMM 6.02 137.98 17.7007 551 9455 9730 RPM MWD020 OHMM 8.19 2000 83.9536 551 9455 9730 RPD MWD020 OHMM 9.39 2000 96.0755 551 9455 9730 FET MWD020 HOUR 0.4 22.42 5.31176 551 9455 9730 First Reading For Entire File......... .9455 Last Reading For Entire File.......... .9730 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name. ........... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 4 header data for each bit run in separate files. 3 DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ ') .5000 START DEPTH 9730.5 9730.5 9730.5 9730.5 9730.5 9730.5 9730.5 STOP DEPTH 10294.0 10294.0 10294.0 10294.0 10287.0 10350.0 10294.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type. ....0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN ) 03-JUN-03 Insite 66.37 Memory 10350.0 9730.0 10350.0 87.3 93.7 TOOL NUMBER 184054 159436 6.000 9040.0 QUICK 8.40 41.0 9.0 400 6.0 DRILL 1.900 1.040 1.860 1.920 70.0 133.0 70.0 70.0 record. . . . ) . . . . . . . Undefined ) Max frames per ,I Absent value. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9730.5 10350 10040.3 1240 9730.5 10350 ROP MWD030 FT/H 1.08 679.49 58.6728 1240 9730.5 10350 GR MWD030 API 14.13 155.18 32.2434 1114 9730.5 10287 RPX MWD030 OHMM 5.04 36.35 17.2142 1128 9730.5 10294 RPS MWD030 OHMM 5.57 39.46 18.9937 1128 9730.5 10294 RPM MWD030 OHMM 7.24 37.53 20.6097 1128 9730.5 10294 RPD MWD030 OHMM 8.42 36 21.206 1128 9730.5 10294 FET MWD030 HOUR 0.57 35.81 3.02417 1128 9730.5 10294 First Reading For Entire File......... .9730.5 Last Reading For Entire File.......... .10350 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/07 / 0 1 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.... . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/07 / 0 1 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF ) ) " Physical EOF End Of LIS File Sperry-Sun D...., 1ing Services LIS Scan Utility ') . $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 01 10:01:40 2003 lDB -OB«t \ , ß \0 Reel Header Service name.. . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name..... . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/07 1 0 1 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER WOA/pBU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA C-16A PB1 500292043870 BP EXPLORATION Sperry-Sun Drilling Services 01-JUL-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002461818 J. BOBBITT J. RALL MWD RUN 2 MW0002461818 J. BOBBITT J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 14E 116 1218 1218 MSL 0) 61.77 35.18 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 9040.0 # REMARKS: ) ') 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THE WHIPSTOCK (THE TOP OF WHICH WAS AT 9040'MD/8740'TVD) WAS POSITIONED AND THE WINDOW MILLED PRIOR TO RUN 1. TIE-IN SGRC DATA OVER THE INTERVAL 8806'MD TO 9018'MD (BIT DEPTHS) WERE ACQUIRED WHILE POOH AFTER RUN 1 AND ARE PRESENTED WITH RUN 1 DRILLED DATA. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND AT-BIT INCLINATION (ABI). 4. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED 4.5' DEEPER PER E-MAIL FROM D. SCHNORR DATED 6/9/03. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 5. MWD RUNS 1 & 2 REPRESENT WELL C-16A PB1 WITH API#: 50-029-20438-70. THIS WELL SEGMENT REACHED A TOTAL DEPTH (TD) OF 9879'MD/8977'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type............ . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPM RPS 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 8811.0 9045.0 9459.5 9459.5 9459.5 STOP DEPTH 9820.5 9883.5 9827.5 9827.5 9827.5 RPX FET $ 9459. 9459.5 ) 9827.5 9827.5 ) # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8811.0 9883.5 $ GR 8806.5 9879.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 8806.5 9510.0 MERGE BASE 9510.0 9879.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8811 9883.5 9347.25 2146 8811 9883.5 ROP MWD FT/H 0.02 641.47 82.7957 1678 9045 9883.5 GR MWD API 8.8 193.82 49.15 2020 8811 9820.5 RPX MWD OHMM 5.47 77.16 17.4243 737 9459.5 9827.5 RPS MWD OHMM 6.02 137.98 19.5142 737 9459.5 9827.5 RPM MWD OHMM 8.19 2000 68.8264 737 9459.5 9827.5 RPD MWD OHMM 9.39 2000 77.6684 737 9459.5 9827.5 FET MWD HOUR 0.4 22.42 4.10999 737 9459.5 9827.5 First Reading For Entire File......... .8811 Last Reading For Entire File.......... .9883.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Next File Name. . . . . . . . . . '~SLIB. 002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name..... ..STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ') header data for each bit run in separate files. 1 .5000 START DEPTH 8806.5 9040.5 STOP DEPTH 9467.5 9510.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 31-MAY-03 Insite 4.3 Memory 9510.0 9062.0 9510.0 1.1 96.0 TOOL NUMBER 69706 6.000 9040.0 QUICK-DRILL 8.40 46.0 9.0 400 20.0 .000 .0 .000 115.0 .000 .0 .000 .0 HOLE CORRECTION (IN). ') ') # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT Rap MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8806.5 9510 9158.25 1408 8806.5 9510 Rap MWD010 FT/H 0.02 641.47 53.4932 940 9040.5 9510 GR MWD010 API 8.8 193.82 36.8555 1323 8806.5 9467.5 First Reading For Entire File......... .8806.5 Last Reading For Entire File.......... .9510 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . La Next File Name.......... .STSLIB.003 Physical EOF File Header Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 3 header data for each bit run in separate files. 2 .5000 FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ ) START DEPTH 9455.0 9455.0 9455.0 9455.0 9455.0 9468.0 9510.5 STOP DEPTH 9823.0 9823.0 9823.0 9823.0 9823.0 9816.0 9879.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 ) 01-JUN-03 Insite 66.37 Memory 9879.0 9510.0 9879.0 88.2 96.9 TOOL NUMBER 184054 159436 6.000 9040.0 QUICK-DRILL 8.40 46.0 9.0 400 20.0 1.900 .930 1.860 1.920 70.0 150.0 70.0 1.9 Depth Uni t s . . . . . . . . . . . . . ). . . . . . . . ) Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9455 9879 9667 849 9455 9879 ROP MWD020 FT/H 2.05 275.93 120.119 738 9510.5 9879 GR MWD020 API 17.43 158.94 72.4868 697 9468 9816 RPX MWD020 OHMM 5.47 77.16 17.4243 737 9455 9823 RPS MWD020 OHMM 6.02 137.98 19.5142 737 9455 9823 RPM MWD020 OHMM 8.19 2000 68.8264 737 9455 9823 RPD MWD020 OHMM 9.39 2000 77.6684 737 9455 9823 FET MWD020 HOUR 0.4 22.42 4.10999 737 9455 9823 First Reading For Entire File......... .9455 Last Reading For Entire File.......... .9879 File Trailer Service name............ .STSLIB.003 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/07/01 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .03/07/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 07/ 0 1 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF ) ) End Of LIS File