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Home My WebLink About203-142New 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 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 Image _oject 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. ~3_ - L lJ=. ~ Well History File Identifier Page Count from Scanned File: I 0 {¡; (Count does include cover sheet) Page Count Matches Number in scann7· 9 PrraratiOn: V YES ~ Date:/~ ¡if/os If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) o Two-sided III" 111111" 111111 R~CAN \)1' Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: BY: ~ Date/:;"} /4-jfÞ Datel B-/ JLf-! OS- 3 x 30 = qo + Date P-Î 'lflo<;- Project Proofing BY: r:;:) Scanning Preparation BY: ~ Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 111111111111111111I OVERSIZED (Scannable) D Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: D Other:: /s/ V11P 1111111111111' "III /s/ mP 15 = TOTAL PAGES / OS (Count does not include cover sheet) lIVJ_vl /5/ I ' I ,- 11111111111111" III NO WtP /5/ NO /5/ 11111111111I1111111 III 11111111111" III /s/ Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA ~AND GAS CONSERVATION COMMI ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ^ Oil ^ Gas ^ Plugged _~ Abandoned ^ Suspended 20AAC 25.105 zoaac zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ~ ~~, ,~ Developmen~ ~~~~oratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/17/2009 12. Permit to Drill Number 203-142 - 309-159 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/6/2003 13. API Number 50-029-20339-02-00 - 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/14/2003 14. Well Name and Number: PBU 07-14B ~ FNL, 314 FEL, SEC. 33, T11 N, R14E, UM 511 Top of Productive Horizon: 3936' FSL, 941' FWL, SEC. 27, T11N, R14E, UM 8• KB (ft above MSL): 64' ~ Ground (ft MSL): 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2438' FSL, 1460' FWL, SEC. 27, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 5001 4690 Oif Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 675869 y- 5950406 Zone- ASP4 10. Total Depth (MD+TVD) 12500 - 8978 - 16. Property Designation: ADL 028309' TPI: x- 677011 y_ 5954881 Zone- ASP4 Total Depth: x- 677568 y- 5953396 Zone- ASP4 11. SSSV Depth (MD+'n/D) (Nipple) 17. Land Use Permit: 18. Directional Survey ~ Yes ^ No Submit electronic and rinted inform i n r 2 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (ND): 1900' (Approx.) 21. Logs Obtained {List all logs here and submit electronic and printed information per 20 AAC 25.071): GR, EWR, MGR, CCL, CNL ZZ. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETfING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTfOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 urface 71' Surfa 71' 3" 243 sx Arc icset 1-/8" 7 rfa 2 2 6' 1-1 /" 2 I I 9-5/8" 47# -80/ urface ' rfa 8573' 12-1/4" 1200 sx Cla s'G' 3-vz° x 33/16° x za~e° a.a,u ~ s.zx ~ s.,sn L-80 9 4' 12500' 821 ' 8 7' 4-~~8° x 3-3/4° 147 sx Clas 'G' 23. Open to production or inje~t ion? ^ Yes ~ No 24. TueiNC RecoRo If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): Srze DePTH Ser MD PACKER .SET MD None 5-1/2", 17#, L-80 5597' - 9809' 9798' MD TVD MD TVD 4-1/2", 12.6#, N-80 9809' - 9913' ZS. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' ~' _y~~ ~?i~ ~ `? ~~`~'-'` DEPTH INTERVAL MD AMOUNT Hi KIND OF MATERIAL USED ~,r.~+~~%y~ ""`' ` P&A with 65 Bbls Class'G' 5023' Set 9-5/8" EZSV Bridge Plug 5001' Set Whipstock ZF). PRODUCTION TEST Date First Production: Not On Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: PROOUCrioN FoR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Ca,~cu~aTe~ 24-HouR Rnre~ OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: Z7. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No SidewaU Core s Ac uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~',(~fr 8~9 ~.°~I Baiiy ~ None ~~~~ ~ . ~:.,.~ ~~~~~~~~~ ~UG ~ 6 2~09 " ~ i~r~ Form 10-407 Revised 02/2007 CoN i u o gSE SIDE ~ . .~~i~ ~~J~, ~ „ 2009 ~ `~'``~-~'~' ~~?~r/` ~ ZS. ~`iEOLOGIC MARKERS ~LIST ALL FORMATIONS AND MARK S ENCOUNTERED~: Z9. FORMATION TESTS NAME MD TVD Well Tested? Yes ~ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top CGL / Zone 3 10403' 8606' None Base CGL / Zone 2C 10495' 8684' 23S6 / Zone 2B / 26N 10552' 8733' 22TS 10621' 8794' 21 TS / Zone 2A 10680' 8844' Zone 1 B 10739' 8889' Zone 1A 10824' 8937' Base Sadlerochit 12536' 8981' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra Ste man Title Drilling Technologist Date ~"~ - PBU 07-14B 203-142 309-159 Prepaied By Name/Number. Sondra Stewman, 564-4750 Drilling Engineer: Garret Staudinger, 564-4242 Well Number Permit No. / A roval No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on atl types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory info~mation required by 20 AAC 25.071. IreM 29: P~ovide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE= 4-1/8" 5000 Carbon WELLHEAD= ~.. GRAY ACTUATOR = KB. ELEV - 55.3' BF. ELEV - 25.7 KOP = 5001' Max Angle = 98.6/12002' Datum MD = 13058' Datum ND = 8985' ' 07-14 2~' ~~4-1l2" X NIPPLE ~s-sis~ w countts ~~ 2323' 8~ 2452' 13-3/8" CSG, 72#, L80, ID = 12.347" 2665~ Minimum ID = 2.377" a~ 11040" 2-7/8" STL PIN CONNECTION Whipstock ~ 5001' ' ¢SV 5023' GAS LIFf MANDRELS ST MD ND DEV TYPE VLV LATGH PDRT DATE 1 6905 5907 65 KBG DUM BK 0 Aug-09 2 3803 3756 27 MMG SHR RKP 0 Aug-09 3995' H7" Hanger / Liner Top Packer 10431' H 4-1/2" OTIS X NIP, ID= 3.813" I 10462' 7" x 4-1l2" S-3 PKR 10495' 4-1/2" OTIS X NIP, ID = 3.813" 10569' 4-1/2" OTIS XN NIP, ID = 3.725" 10581' 4-1/2", 12.6#, 13-CR, .D152 bpf, ID = 3.958" 10573' 4-1/2" Hanger / LTP PERFORATION SUMMARY REF LOG: SPERRY EVHR - GR ON 10/14/03 Note: Refer to Rroductan DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11,750 - 11,85Q O 08/03/09 2-7/8" 6 12,230 - 12,400 O 08/03/~9 2-7/8" 6 12,690 - 12,968 O 08/~3/09 ~ 10707~ 7", 26#, L-80, BTCM, 0.0383 bpf, ID = 6.276" PsTD ~-~ 12968' 13056~ 4-1/2", 12.6#, L-80, .0152 bpf, 1~3.958" I DATE REV BY COMMENTS DATE REV BY CAMMENTS 06/03/79 ORIGINAL COMPLETION 09/14/07 KSB/TLH GLV GO 08/01/98 SIDETRACK(07-14A) 04/01/08 DAV/SV GLV GO 11/22/03 CJS/TLH SIDETRACK(07-14B)(10/20/03 O6l25/08 RLMlPJC CALLAPSEDTBG (OS/31/08) 70/24/03 MH/TLH GLV GO 04/09/09 GJS 07-14C PROPOSAL 09/18/04 GJB/TLP GLV GO 08/05/09 AER/MS 07-14C Decomp/Sidetrack 08/04/07 DTR/SV GLV GO PRUDHOE BAY UNff WELL: 07-14C PERM~T No: ~2031420 API No: 50-029-20339-03 SEC 33, T11 N, R14E, 511.07' FEL & 313.93' FNL BP Exploration (Alaska) • • 07-14B Well History Date Summary 05/17/09 T/I/O=SSV/150/280, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RST. PPPOT-T: Stung into test port (100 psi), bled to 0 psi. Functioned LDS (Standard), all moved freely (.75"). Pressure void to 5000 psi for 30 minute test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bleed void to 0 psi. PPPOT-IC: Stung into test port (50 psi), bled to 0 psi. Functioned LDS (Standard) all moved freely (.75"). Pumped through void, clean returns. Pressure void to 3500 psi for 30 minute test, lost 100 psi in 15 min, lost 50 psi in 15 min (PASS). Bleed void to 0 psi. 05/26/09 T/I/O=SSV/360/280. Temp=Sl. WHP's & IA FL. (Rig sidetrack prep). IA FL @ 786' (35 bbl). OA FL @ Surface. SV, WV & SSV=CLOSED. MV=OPEN. IA & OA = OTG. NOVP. 05/26/09 INITIAL T/I/O = 100/150/300. RIH W/ PL TOOLS TO MAXIMUM TARGET DEPTH OF 9 500'. TIED-IN TO TUBING TALLEY. LRS LOAD TUBING AND IA. REVIEWED PROCEDURE WITH PE. PE SENT NEW PROCEDURE FOR CURRENT WELL CONDITIONS. 05/27/09 Assist E-line with LDL; Pumped 117 bbls of 1%KCL while e-line logged, Pumped 110 bbis crude to freeze protect IA. Did not freeze protect TBG due to results of E-line's fluid density test on fluid in TBG. FWHPs= 0/0/220 Valve positions at time of departure; SV shut, WV shut, SSV open, MV open, IA open, OA open 05/27/09 LOG FROM 9500 FT - SURFACE WHILE PUMPING 1 BPM ON IA. NO LEAKS DETECTED WITH SPINNER. FLUID IN TUBING IS ITYDROCARBON FROM 4600 FT - SURFACE. RD ELINE. SWAB, SSV, WING - CLOSED. MASTER - OPEN UPON DEPARTURE. FINAL T/I/O = 200/200/50 06/11/09 T/I/O = 200NAC/20. Temp = SI. T& IA FL (pre-FB P&A). Tbg FL C«3 1092' (25 bbls). IA FL C«~ 726' (32 bbls). SV, WV = Closed. SSV, MV - Open. IA & OA = OTG. NOVP. 0615/09 TAGGED COLLAPSED TBG @ 9585' SLM W/ 3.5" CENT & S-BAILER. 06/18/09 T/I/O = SSV/0+/20. Temp = SI. IA FL (pre FB). No AL. IA FL C~? 396' (17 bbis). SV, WV, SSV = Closed. MV = Open. IA & OA = OTG. NOVP. 06/19/09 T/I/0=0/0/0 Fullbore Bullhead Cement P&A (Pre SDTRCK) Fluid packed Tbg with 351 bbls of 1% KCI and 10 bbls chemical wash. Pumqed 65 bbls of 15.8 ppq "G" cement followed bv 2 bbls FW to flush lines. Launched two wiper balls (7" and 6") with 5 bbls of fresh water followed bv a total of 180 bbls of 75"F diesel C~ -5.0 bpm, had dropped pump rate to 1 bpm for the last 5 bbls diesel in attempt to squeeze cement. (Est. 13 bbls of cement behind pipe) Tbg pressure increased to 2500 psi. Monitored Tbg pressure for 30 mins. Est TOC C~3 8060' md. FWHP's=1002/1165/0+ 06/21/09 RAN 3.75" CENT. 3" S-BAILER. S/D C«~ 7724' SLM (RECOVERED -1/2 GALLON CEMENT) RAN 4.50" G-RING, S/D C~ 7724' SLM 06/21/09 T/I/0=440/380/40 CMIT-TxIA PASSED to 2500 psi, MIT-OA PASSED to 2000 psi. (Pre SDTRCK) Pumped 6 bbls 50*F crude down IA to reach 2500 psi for CMIT TxIA. Tbg slow to track IA, Rig down form IA and onto Tbg. Pumped 1.5 bbls crude to pressure up to 2500 psi. Rig down from Tbg and onto IA. Pumped 0.5 bbls 50*F crude to reach 2500 psi. T/IA lost 0/50 psi in the 1st 15 mins and 0/0 psi on ihe 2nd 15 mins for a total pressure loss of 0/50 in the 30 min test. Bled pressures back to initials. Page 1 of 2 . • 07-14B Well History Date Summary 06/22/09 MIT OA PASSED to 2000 psi. (Pre SDTRCK) Pumped 3 bbls 50"F crude to reach test pressure. OA lost 230 psi in the 1 st 15 mins. Bumped OA up to 2000 psi to re-test. OA lost 120 psi in the 1 st 15 mins and 20 psi in the 2nd 15 mins for a total pressure loss of 140 psi in the 30 min test. Bled pressures down to initials. Valve positions upon departure: Swab- closed, Wing- closed, SSV- closed, Master-Open, Casing valves open to gauges. Hardline off of IA to adjacent well SI. 06/22/09 TAGGED TD AT 7744'. FIRED MEDIUM TUBING PUNCHER FFiOM 7680' - 7682'. LRS CIRCULATED WELL. 06/22/09 T/I/0=0/0/0 Temp-SI Circ Out. Cire seawater down Tbg up IA thru Tbg punch @ 7700 ft to 07- 30 flowline. Pumped 731 bbls 110*F seawater, and 150 bbls 110*F diesel to Circ and place freeze protect. RD off of Tbg and onto IA, rig up jumper line for U-tube, freeze protect and SI hardline to 07-30. 06/23/09 E-line iet cut tubina at 5600'. CMIT TxIA FAILED to 1000 psi. Pumped 8 bbls 55*F diesel down IA during the three failing tests to 1000 psi. Pumped 0.5bbls diesel in one failing test to 500psi. Unable to estab~ish LLR at 1000psi (LLR < 0.25bpm)_ Bled pressures down to zero. Swab, Wing = shut. Master, SSV, IA, OA = open. FWHP's = 0/0/0 Safety *"Drill"", Man down, and coil fire. 06/23/09 INITIAL T/I/O = 0/ 0/ 0 PSI. LRS COMPLETED CIRC. JET CUT TUBING AT 5597' USING 3.65" SLB POWER CUTTER. WELL LEFT SHUT IN. TURNED OVER TO LRS. SWAB CLO ED, R LRS), MASTER OPEN. 07/06/09 T/I/0= 0/0/0 Set 5" Gray BPV #601, 1-2' Ext. used, Tag C«~ 108"; Pre rig (Nabors 7ES) 07/10/09 TI0=6V/3/10. SI. Bleed IA&OA. (Valve c/o). No flow Iine,AL line or scaffolding. Integral installed on IA. Bled IAP to 0 psi in <1 min, bled OAP to 0 psi in <2 mins. SI bleed monitor for 45 mins with no change in pressures. Final WHPs=6V/0/0 SV,WV=NA. SSV,MV=C. IA, OA=OTG. NOVP 07/11/09 T/I/0=0/0/0; Rolled Annulus Valves from Front side of wellhead to Back side replacing the existing O/A valve with a 3-1/8" FMC Model 120; T/I/0= SSV/0/0. Temp=Sl. Bleed OAP to 0 psi (OA valve C/O). Integral on IA. No FL, AL, scaffold. Unable to access SV, WV. SSV,MV=C. IA,OA-OTG. NOVP. Page2of2 # ~ BP EXPLORATEC7N' Page 1 ~ Operations Surnmary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 7ES Rig Number: _ . : I _ _ . ~ . . I _ . I ~ . I ..'__ I _. I ~ . .. . ,~ .. _ 7/15/2009 00:00 - 03:30 3.50 RIGU P PRE MIRU Nabors 7ES. Rig accepted at 00:00 on July 15, 2009. Rig up derrick equipment: Make up Hydraulic loop to TopDrive, connect kelly hose, unpin and hang bridle lines, and pin blocks to TopDrive. 03:30 - 07:00 3.50 RIGU P PRE Hl! and oressure test OA with diesel to 2000 psi for 10 minutes - ood test. 1 st 5 min - lost 80 psi, 2nd 5 min - lost 20 psi. ~ Bleed off OA. RU and pressure test IA to 1000 psi - failed. i in minutes. Bleed off IA. Clean derrick, install floor mats, pick up handling equipment. (Off critical path) 07:00 - 08:30 1.50 RIGU P PRE RU DSM lubricator, pressure test lubricator to 1000 psi - good test. Pull BPV. RD DSM. 08:30 - 11:00 2.50 RIGU P PRE Reverse circulate 51 bbls diesel freeze protect out of tubing with seawater at 250 gpm with 560 psi. Line up on tubing and circulate 96 bbls diesel freeze protect out of IA at 250 gpm with 400 psi. 11:00 - 13:00 2.00 BOPSU P PRE RU DSM lubricator and install BPV. Test below to 1000 psi - ood test. Cameron dry rod in test dart and test above to 3500 si for 10 min - ood test. 13:00 - 16:00 3.00 BOPSU P PRE ND tree and adapter flange. 16:00 - 19:30 3.50 BOPSU P PRE NU BOP. 19:30 - 21:00 1.50 BOPSU P PRE Pick up test handling tools. RU test equipment for testing BOPE. 21:00 - 00:00 3.00 BOPSU P PRE Test BOP equipment with 4" and 5 1/2" test joints to 250 psi / 3500 psi. Each test held for 5 minutes. Chuck Sheive of AOGCC waived witness of test. Test witnessed by Toolpusher Lenward Toussant, WSLs Travis Peltier and Carrie Williams. Note: Pre-spud meeting held with Clint PettiYs crew during change out. 7/16/2009 00:00 - 02:00 2.00 BOPSU P PRE Finish testing BOPE with 4" and 5 1/2" test jts. 02:00 - 03:00 1.00 BOPSU P PRE RD BOP test equipment. 03:00 - 04:00 1.00 BOPSU P DECOMP PU DSM Lubricator and test to 500 si - ood test. Use dry rod to ull the test dart from back ressure valve. Test dart fell from T bar while liftin~ to the rig floor. 04:00 - 05:30 1.50 BOPSU N SFAL DECOMP Wait for Baker Rep to bring magnet out to fish test dart off the BPV. 05:00 - 05:30 0.50 FISH N SFAL DECOMP Make u ma net to 't of 4" DP. RIH and retrieve test dart. 05:30 - 06:00 0.50 BOPSU P DECOMP RU DSM Lubricator and extension. Pull BPV. Ri Down DSM. 06:00 - 06:30 0.50 PULL P DECOMP PU Spear BHA: 2 7/8" Bullnose, Packoff Assembly, and 5 1/2" Shoulder Type Spear with 4.8 Nominal Grapple. Total length = 10'. 06:30 - 07:00 0.50 PULL P DECOMP RIH and spear 13 5/8" x 5 1/2" tbg hgr. Unseat hanger with 265k PUW 115k. 07:00 - 08:30 1.50 PULL P DECOMP Circulate 50 bbl Safe-Surf-O pill at 305 gpm with 420 psi. 08:30 - 15:30 7.00 PULL P DECOMP ~ LD han er. Pull and LD 5 1/2" 17# -80 8rd AB Mod lastic coated tubinq from 5596'. Recovered 4 Stainless steal bands, 26 metal clamps, 131 jts, 1 20' pup jt, 2 GLMs, 1 SSSV, and 21.87' cut jt. Rig down 5 1/2" handling equipment. Outside of tubing shows no sign of corrosion. Inside of tubing shows moderate oittina. Some of the ~in en s are missina Printed: S/3/2009 8:37:00 AM ~ ~ ' BP EXPLORATI(~N Pag~ 2 ' Operations S`ummary Report Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 7/15/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 7ES Rig Number: ' Date' Frr~m - To Hours Task Code NPT Phase Description of Operations 7/16/2009 08:30 - 15:30 7.00 PULL P DECOMP threads. Cut jt is slightly flaired. While LD tbg lost 5 bbls. 15:30 - 16:00 0.50 PULL P DECOMP Rig down 5 1/2" handling equipment. 16:00 - 17:00 1.00 PULL P DECOMP Test new derrick desend system with 200 Ibs - good test. Total descend time 18 sec. 17:00 - 17:30 0.50 BOPSU P DECOMP RU BOP test equipment. 17:30 - 19:00 1.50 BOPSU N SFAL DECOMP Test Bottom 2 7/8" x 5" variable rams - test failed. 19:00 - 20:00 1.00 BOPSU N SFAL DECOMP Change out bottom set of variables to 4" rams. 20:00 - 21:00 1.00 BOPSU P DECOMP Test 4" rams to 250 psi low and 3500 psi high for 5 min each - good test. 21:00 - 22:00 1.00 BOPSU P DECOMP RD BOP test equipment. Pull test plug. Install wear ring. 22:00 - 00:00 2.00 CLEAN P DECOMP PU Clean out BHA: 8 1/2" Used bit, 8 1/2" Upper string mill, 9 jts 6 i/2" DC, 12 jts 4" HWDP. Total length = 647'. 7/17/2009 00:00 - 00:30 0.50 CLEAN P DECOMP RIH with Clean out BHA from 647' to 740' picking up 4" DP. 00:30 - 02:00 1.50 CLEAN N SFAL DECOMP Troubleshoot problem with pipe skate. Change out bad switch on the upper ramp controls. 02:00 - 05:30 3.50 CLEAN P DECOMP Continue to RIH from 930' to 5536' picking up 4" DP. Rotate at 10 roms throuah FO collars at 2323' and 2452' with no roblems. 05:30 - 06:30 1.00 CLEAN P DECOMP CBU at 550 gpm with 2080 psi for a total of 323 bbls while reciprocating pipe. Monitor well -static. 06:30 - 08:30 2.00 CLEAN P DECOMP POH from 5536' to 647', stand back 4"DP, 4" HWDP, and 6 1/2" DCs. Monitor well - static. 08:30 - 09:30 1.00 CLEAN P DECOMP LD Clean out BFfA. All components in full gauge. Clean and clear rig floor. 09:30 - 11:00 1.50 DHB P DECOMP Rig up Schlumberger E line unit. Pick up Halliburton 9 5/8" EZSV bridge plug. 11:00 - 13:00 2.00 DHB P DECOMP RIH with brid e lu and set at 5023' to element). 13:00 - 14:00 1.00 DHB P DECOMP POH with E- Llne. Rig down Schlumberger unit. 14:00 - 14:30 0.50 DHB P DECOMP Ri u and test EZSV brid e lug x 9 5/8" csg to 3500 psi for charted 10 min - no bleed off -qood test. Rig down test equipment. 14:30 - 17:00 2.50 STWHIP P WEXIT Make u 9 5/8" Whipstock and Milling BHA with Bottom Trip Anchor, Baker Gen II 9 5/8" whipstock slide, 8 1/2" window mill, 8 3/8" lower string mill, 2- 8 1/2" upper sYring mills, float sub, 1 jt 5" HWDP, MWD, UBHO, 9 jts 6 1/2" DCs, and 12 jt 4" HWDP. Total lenght 740'. 17:00 - 20:30 3.50 STWHIP P WEXIT RIH with Whipstock and Milling BHA from 740' to 1205' and perform shallow hole test on MWD at 500 gpm with 895 psi - good test. Continue to RIH from 1205' to 5001'. 20:30 - 21:00 0.50 STWHIP P WEXIT Orient Whi stock 112 degrees left of high side. Tag top of EZSV at 5023' and SO 15k to set bottom trip anchor. PU to confirm set. Shear milis from slide with 50k down weight. 21:00 - 22:00 1.00 STWHIP P WEXIT Displace the well by pumping 100 bbls water, 50 bbls spacer pill with Flowzan, and chase with 9.0 ppg LSND milling fluid at 400 m with 83Q si. 22:00 - 00:00 2.00 STWHIP P WEXIT Mill 8 1/2" window in 9 5/8" casing with following parameters: WOB 2-5k, 400 gpm with 870 psi, 4k ft-Ibs torque on bottom at 75 rpm. PUW 125k, SOW 115k, and ROT 120k. Top of window at 5001'. 7/18/2009 00:00 - 02:30 2.50 STWHIP P WEXIT Continue to Mill 8 1/2" window in 9 5/8" casing with following parameters: WOB 2-5 k, 400 gpm with 870 psi, 7k ft-Ibs tq on, 4k ft-bls tq off, on bottom at 70 rpm. PUW 125k, SOW 115k, Printed: 8/3/2009 8:37:00 AM • ~ ~e~w { p~ ~ *~i~~l~ll~~~i~~~s~e- . . .. .. ~ NO. 5289 Alaska Data & Consulting Services ~°~ '~F a~~` ~ u i` ~` .t e; ~~~~ ~ 7525 Gambetl ;itreet, Suite 400 ~~`~`~''~'~'~~ "~~"' Company: Alaska Oil & Gas Cons Comm Rlnchorage, AK, 99503-2838 Attn: Christine Mahnke~n l1YTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 06/26/09 A-44 09AKA0048 OH MWD/LWD EDIT °* -~~ 04/26/09 2 1 4-04A/T-30 09AKA0040 OH MWD/LWD EDIT 03/28/09 2 1 18-01A B2WY-00003 MCNL 04/30/09 1 1 15-296 09AKA0143 OH MWD/LWD EDIT 05/30/09 2 1 05-35A 40017778 OH MWD/LWD EDIT ~U~S °' 09/10/08 2 1 V-115L2 11962618 OH WIRELINE - OS/22/08 1 1 MPS-41 11966289 OH WIRELINE ~-L~j /'"~ ~ 11/19/08 6 1 G-01A BOOR-00006 MCNL ~ y~ _~~ ~ ~'~1-- 04l01/09 1 1 4-Q4A/T-30 BOCV-00014 ~ CH EDI i rv~,~-GR (SCMT) (REVISE DATA) - ~ /27/09 1 05-35A AWJI-00008 CH EDIT PDCL-GR (MEM CORREIATION) .- ~ 12/03/08 1 07-14B AYQQ-00029 CH EDIT PDCL-GR (LDL) - L (~ 05/26/09 1 ~3-08 AWL9-00028 RST / 06/11/09 1 1 ~l C11G~L 11f~VI.IA\IIII re~r.~ r~~ ~~~r~r w~i w.~w~~. ..w ...~ ~~~..~.....~ ~~.~ ~~__" __ ~.. __ ---"~-".-~.....~..~.~v.w~ ~.rv~~~ ~ a~ ~ v~~.a~~~~~v e~~~v nc.1 Vn1~11Y1i VIYG VVr ~ CHlifl 1 V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage,AK 99503-2838 ~P~~~~I~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.5279 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD 06/16/09 14-23A AYKP-00016 USIT - 04/10/09 1 1 A-44 AP30-00036 SCMT 04/26/09 1 1 14-23A AYKP-00016 USIT 04/10/09 1 1 07-10A B1JJ-00022 MEM CN STP 05/26/09 1 1 07-146 AYQO-00029 LDL - L ~ 05/26/09 1 1 12-09 AYTU-00038 PRODUCTION PROFILE ~ 05/31/09 1 1 V-218 AVYS-00048 INJECTION PROFILE/WFL ~~' p 05/29/09 1 1 15-34A AWJI-00020 MCNL 04/20/09 1 1 A-44 AWLS-00017 CH EDIT PDCL-GR (SCMT) - 05/25/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EAGR TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~~, V ~~ ~ ~~ ~, } y 1 ~ o Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 i . • • SARAH PALIN, GOVERNOR AI.ASSA OII, A1~TD GAS CO1~T5ER~A~'IO1~T CObII~II551O1Q Robert Tirpack Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~Q~ Re: Prudhoe Bay Field, PBU 07-14B Well Sundry Number: 309-159 q ~ ~} Dear Mr. Tirpack: 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. Sincerely, DATED this ~ day of April, 2009 Daniel T. Seamount, Jr. Chair Encl. ~; ~,~ a 20 AAC 25.280 ~'~la` 1. Type of Request: ®Abandon - ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. - ®Development ^ Exploratory 203-142 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20339-02-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 07-146 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028309 - 64' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12500- 8978 ~ 12468 - 8975 - None None sin Len th ize M TVD ur Ila r ural n r 71' 71' 71' 15 Surf 2665' 13-3/8" 2665' 2665' 5 0 2670 In erme late 10524' - /8" 10 62' 573' 6870 47 0 Pr i n Liner 26 2' 3-1/2" x 3-3/16" x 2-7/8" 9848' - 125 821 ' - 8978' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10950' - 12465' 8960' - 8975' S-1/2", 17# x 4-1/2", 12.6# L-80 / N-80 9913' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 9798' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 12, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garret Staudinyer, 564-4242 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By Name/Number: 7jr Terrie Hubble, 564-4628 ~'' Phone 564-4161 Date `/ Signature ~ o Commission Use Onl Sundry Number: ~~~~,_ J ~- Conditions of approval: Notify Commission so that a representative may witness w~ ~~ ~ ~ ~~ r,®--a ~ ^ Plug Integrity ~, BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: c~-~ S t ~` ~ ~ s~v t1 fl.~~~1~Gr- .~7 s~laska Oil ~ Gas Cons. Commissiol~ Subsequent Form Required: Anchrarap~ APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date STATE OF ALASKA „o~, ALA OIL AND GAS CONSERVATION COMI'~ION ~~ 1/~ APPLICATION FOR SUNDRY APPROVAL Form 10-403 Re'1~2`d 01~/200Ei ~ ~ ~ ~ ~ ~ A ~ Submit In Duplicate //°~1 ,,~'/ y/o5 • by c,~ 07-14C Rig Sidetrack • Well Type: Producer Current Status: This well is completed with 3-3/16" liner inside 5-1/2" L-80 tubing inside 9-5/8" casing and is currently shut-in. Request: Abandon Reason for Sundry Application: As part of the rig sidetrack operation, the existing 07-14B perforations will be permanently abandoned as follows: - 51 bbls of 15.8 ppg Class G cement will be pumped from surface by means of fullbore pumping. The cement will be chased with a foam ball and a top of cement of 9300' will be targeted. The cement plug will be pressure tested to 2000 psi. - Additional isolation from the perfs will be achieved with the cement in the new 7" x 9 5/8" liner lap, and a liner top packer. Reason for Sidetrack: 07-14B is not operable due tb collapsed tubing at 9587' MD. This prevents the option of a coil sidetrack. Before the integrity problem, it produced with minimal on-time due to limited recharge and low rates. Therefore, a rig workover was not considered. ~. t d'~~ z~~~ ~~ Current Status: 07-14B was a coil sidetrack drilled in Oct 2003 and completed in Z1 A/Z1 B. When Nordic 1 re-entered the well, cement was encountered above the liner top suggesting the cement made it all of the way up the backside. They milled through the cement leaving a 3.80" cement sheath at 9600'-9850' MD. The well kicked off strong, but went to cycle quickly with limited recharge at low oil rates and low gas rates. During CTD sidetrack screening, a CT unit was unable to mill past 9595' CTMD. A downhole camera was run and showed collapsed tubing near GLM #9, 9587' MD. A MIT-OA passed to 2000 psi without bubbling at surface in Sept 2008. A production casing leak is not expected, but a CMIT-TxIA is not possible due to the collapsed tubing above the packer. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. • ~ • Scope of Work: Pump 51 bbls of cement from surface to TD, leaving TOC at 9,300' MD. Cut and pull the 5-1 /2" L-80 completion. MASP: 2360 psi Estimated Start Date: July 1, 2009 Pre-rig prep work: F 1 Fluid ack the tubin and inner annulus w/ seawater/diesel. E 2 RU, run STP to in arent well from 9,500' to surface. F 3 P & A the perforations in the 07-14B wellbore with cement from 12,468' MD up to 9,300' MD. Install tree saver to prevent cement from getting into tree/BPV profile. Ensure that IA and tubing are fluid packed. Perform infectivity test. Bullhead cement from surface into perforations and chase with foam ball. a. CEMENT CALCULATIONS i. 1446' of 2-7/8", 6.16# liner: .0058 bbls/ft = 8.4 bbls ii. 1174' of 3-3/16", 6.2# liner: .0076 bbls/ft = 8.9 bbls iii. 250' of 3.80" cement sheath: .0140 bbls/ft = 3.5 bbls iv. 300' of 9-5/8" csg w/ 5-1 /2" tbg .0671 bbls/ft = 20.2 bbls TOTAL (with 10 bbls excess) = 51 bbls Note: Do not use aggregate in slurry as ID of collapsed tubing is unknown. A squeeze can be done if possible, but it is not necessary to achieve a squeeze pressure. Target TOC at 9,300' MD. BHP (formation): 3240 psi BHT (formation): 200 deg F Min TOC: 10,000' MD Max TOC: 7,000' MD S 4 WOC. Drift for Jet Cutter. Ta To of cement lu . F 5 CMIT - TxIA to 2,500 si for 30 minutes F 6 MIT - OA to 2,000 si for 30 minutes E 7 Jet cut the 5-1/2" tubin in the middle of a full 'oint at 5600' MD. F 8 CMIT - TxIA to 2,500 si for 30 minutes F 9 Circulate the well to seawater. Freeze rotect the IA and tubin with diesel to 2,200'. D 10 Bleed all casin and annulus ressures to zero si. W 11 Function all tubing and casing LDS. Repair and replace as necessary. PPPOT - IC and PPPOT - T. V 12 Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well re aration cost on the handover form. Proposed Procedure: 1. MIRU. 2. Pull BPV. Circulate out freeze protection with 9.0 ppg brine and condition fluid as needed. Set a TWC and test from below to 2000 psi and above to 3500 psi. 3. Nipple down tree. Nipple up and test BOPE to 3500 psi. Pull TWC. 4. RU and pull the 5-1/2", 17#, L-80, 8 rd A-B Modified plastic coated tubing from the pre-rig jet cut at 5600' MD (steam wellhead prior to pulling hanger). Spool up the control line and count metal Hydril control line clamps (26 listed on tally) and stainless steel bands (5 listed on tally). Test the lower set of pipe rams. 5. PU 4" drillpipe and 9-5/8" clean-out assembly and clean-out well to the top of the tubing stub 5600' MD. Note: Do not run 9-5/8" casing scrapers due to the 9-5/8" FO collars at 2323' and 2452'. 6. With E-line, run a 9-5/8" EZSV for 47# casing. Set the EZSV at 5020' MD. Rig down E-line. 7. Pressure test the EZSV to 3500 psi for 10 minutes. 8. PU 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). ~• ..~ ~~ • 9. Hang weight of 9-5/8" whipstock assembly and set storm packer just below the wellhead. ' 10. Remove the existing Gray Gen 2 Tubing Spool. Change out the 9-5/8" pack-offs per Cameron. Install the New Standard Tubing Spool. 11. RIH to the top of the EZSV. Orient and set the whipstock. Swap the well over to 9.0 ppg fresh water LSND milling fluid. 12. Mill a window in the 9-5/8" casing from --5000' MD' plus 20' of formation from mid-window. 13. Perform an FIT to 12.5 ppg (a minimum FIT of 10.8 ppg is required to satisfy kick tolerance requirments). POOH for drilling BHA. 14. MU an 8-1/2" drilling BHA with DIR/GR/RES/PWD and ghost reamer behind the bit. RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the top of the Sag River. NOTE: The mud will need to be weighted up with spike fluid. Plan for one weight-up with the spike fluid to 10.2 ppg over several circulations prior to drilling the HRZ and Kingak shale. 15. Change to 7" casing rams and test. 16. Run and cement a 7", 26#, L-80, BTC-M drilling liner throughout the 8-1/2" hole and back into the 9- 5/8". Set TOL to cover cretaceous (cretaceous top at top SV1). Displace cement with mud and set hanger /liner top packer. POOH. 17. MU a 6-1/8" BHA with DIR/GR/RES/DEN/NEU and RIH to the 7" landing collar. Pressure test liner and casing to 3500 psi for 30 min. Drill out the shoe plus 20' of formation while swapping over to new Flo-Pro drilling fluid. Perform an FIT to 11.0 ppg. 18. Drill ahead per plan to the base of the conglomerates. POOH for bit and BHA change. 19. MU a 6-1/8" BHA with DIR/GR/RES/DEN/NEU and RIH. Verify with town geo to MAD pass build interval. Drill ahead the Ivishak Z2 horizontal per plan to TD. 20. CBU, short trip, circulate until clean and spot a liner running pill. MAD Pass where required. POOH. 21. Run and cement a 4-1/2", 12.6#, L-80, IBT-M liner from TD to 150' inside the 7" shoe. Set the liner top packer. 22. Run on DP 600' of 2-7/8" 2906 PJ HMX, 6 spf perf guns and shoot over balanced. Fire guns, POOH. LD remaining DP 23. RU and run 4-1/2", 12.6#, 13Cr-80, Vam Top completion, tying into the 4-1/2" liner top. 24. Reverse circulate to spot corrosion inhibited seawater. 25. Drop ball and rod. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. Shear DCK valve. 26. Set and test a TWC. 27. ND BOPE. NU and test the tree to 5,000 psi. Pull TWC. 28. Freeze protect the well with diesel to 2200' MD. Set a BPV 29. RDMO. D. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 2. Install gas lift valves. 3. Install wellhouse and flowlines. (S-Riser work will be required.) Drilling Engineer: Garret Staudinger (907)564-4242 Production Engineer: Alice Kaminski (907)564-5676 Geologist: Adam Van Holland (907)564-4477 ATTACH: Current Schematic Proposed Schematic LH~AD = _ GRAY CTUATOR = AX~SON B. ELEV = 64' F. ELEV = OP = 10360' x Angle = 95 @ 11429 um MD = 10705' um TVD = 8800' SS ~ 07-14B 9-518" FO COLLARS 2323' & 2452' 13-318" CSG, 72#, L80, ID = 12.347" 2665' Minimum ID = 2.377" aG~ 11040" 2-7/8" STL PIN CONNECTION COLLAPSED TBG (REF VIDEO LOG 05/31/08} ~-~ 9587' CMT SHEATH, ~ = 3.80" 9600'-9850' 5-112" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" H 9797' L4-1 /2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" H 9913' PERFORATION SUMMARY REF LOG: SPERRY EWR - GR ON 10/14/03 ABLE AT TOP PERF: 88 @ 1 Q950' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 2" 4 10950 - 11400 O 1020!03 2" 4 11445 - 11480 0 10/20/03 Z" 4 11640 - 11825 O 10/20/03 T 4 11890 - 12140 O 1020/03 2" 4 12295 - 12465 O 10/20/03 9-5/8" CSG, 47#, L-80/S-95, 10 = 8.681" 2-718" LNR, 6.5#, L-80, ID = 2.441 " 10524' 11881' SA OTES: COLLAPSED TBG ~ 9587' (REF VIDE 605131108) 5-1 /2 OTIS ROM SSSV NiP, ID = 4.562" GAS LIFE MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 2903 2903 7 OT1S C)nAY T2 0 0329/08 2 5186 4826 43 OTIS DMY RM 0 09/18104 3 7033 6139 45 OTiS DMY T2 0 03!29/08 4 8147 6993 38 OTIS D(1+P( RA 0 08/19/03 5 8829 7494 45 OTIS DMY RA 0 08!19103 8902 7545 46 OTIS DMY RA 0 08/19/OCi 7 9365 7868 45 OTIS DMY RA 0 08/19/03 8 9443 7923 45 OTIS DMY RA 0 08/19/03 9 9587 8025 45 OTIS DMY RA 0 08/19/03 10 9658 8076 45 OTIS DMY 12 0 08/19!03 9520' 5-1/2" OTIS SLIDING SLV --~ 9732' ~--j5-1/7' OTIS N NIP, ID = 4.455" (IN CMT SHEATH) - 9772' 5-12" BOT PBRASSY - 9798' 9-518" X 5-112" BKR SAB PKR 9809' 6-518" X 41 /2" XO (MILL OUT EXTENSION} ~- 9>348' 3-112" BKR DEPLOY SLV, ID = 3.00" 9858' 3-1/T' X NIP, ID = 2.813" 9869' (--13-1/2" X 3-3/15' XO, ID = 2.786" 9870' 4-1 /2" CA M DB-6 LAND NIP, ID = 3.813" (BEHIND CT LNR} 10120' TOP OF CEMENT' (RAMP) NnLLOUT CMT' WINDOW (07-148) 10360' - 10363' 11022' 3-1116" X 2-718" I XO, ID = 2.440" 3-3116" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" ~-j 11022' ~~ PBTD 12468' r 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 12600' DATE REV BY CONN®YTS DATE REV BY COMNENTS 06/03/79 ORIGINAL COMPLETION 09/14/07 KSB/TLH GLV GO 08101!98 11122/03 CJSITLH SIDETRACK(07-14A) SIDETRACK(07-148)(10120103) 04/01!08 06/25/08 DAV/SV RLfWPJC GLV GO COLLAPSEDTBG(05131/08) 10/24/03 MH(fLH GLV GO 09/18!04 GJB/TLP GLV GO 08/04/07 D1T2lSV GLV GO PRUDHOE BAY UNIT WELL: 07-148 PERMIT' No:'1031420 AF1 No: 50-029-20339-02 SEC 33, T11 N, R14E, 511.07' FEl & 313.93' FNL BP Exploration (Alaska) TREE _ WELLHEAD = ACTUATOR = KB. ELEV = 64' BF. ELEV = KOP = 5000' Max Angle = 90 @ 11578 Datum MD = 10705' Datum ND = 8800' SS ~9-5/8" FO COLLARS I-i 2323' 8. 2452' 13-318" CSG, 72#, L80, ID = 12.347" 2665' Minimum ID = 2.377" @ 11040" 2-718" STL PIN CONNECTION 9-518" Whipstock H 5000' 9-5/8" Ezsv 5020' 5-1/2" Jet Cut 5600' ESTIMATED TOC 9300' 5-1 /2" OTIS SLIDING SLV 9520' COLLAPSED TBG (REF VIDEO LOG 05/31/08) 9587' CMT SHEATH, ID = 3.80" 9600'85( 5-1/2" BOTPBRASSY 9772' 5-i/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 9797' 9-5/8" X 5-1/7' BKR SAB PACKER 9798' 6-5/8" X 41/2" XO (MILL OUf EXTENSION) 9809' 3-1 /2" BAKERDEPLOY SLEEVE, ID=3.00" 9848 41/7' TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" 9913' PERFORATION SUMMARY REF LOG: SPERRY EWR - GR ON 10/14/03 ANGLE AT TOP PERF: 88 @ 10950' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn7Sgz DATE 2" 4 10950 - 11400 O 10/20/03 SAF OTES: COLLAPSED TBG ~ 9587' (REF VIDE~G OS/31/08) 2200' 4-1/2" X NIPPLE GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 2903 2903 7 OTIS DMY T2 0 03/29/08 2 5186 4826 43 OTIS DUTY RM 0 09/18/04 3 7033 6139 45 OTIS DMY T2 0 03/29/08 4 8147 6993 38 OTIS DMY RA 0 08/19/03 4000' 7" Hanger /Liner 10432' 4-1/7' OTIS X NIP, ID = 3.813" 10462' T' x 4-1/2" S-3 PKR 10492' 4-112" OTIS X NIP, ID = 3.813" 10562' 4-112" OTIS XN NIP, ID = 3.725" 10572' 4-112", 12.6#, 13-CR, .0152 bpf, ID = 3.958" 10572' 4-1/7' Hanger / LTP 10722' T', 26#, L-80, BTCM, 0.0383 bpf, ID = 6.276" • PBTD {-{ 12395' 12475' f-41/2", 12.6#, L-80, .0152 bpf, ID=3.958" 9-5/8" CSG, 47#, L-80/S-95, ID = 8.681" I--1 10524' ~ ~ a ~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" 1110\22' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 12500' DATE REV BY COMMENTS DATE REV BY COMNENTS 06/03/79 ORIGINAL COMPLETION 09/14/07 KSB/TLH GLV C/O 08/01/98 SIDETRACK (07-14A) 04/01/08 DAV/SV GLV GO 11!22/03 CJS/TLH SIDETRACK (07-148)(10/20/03) 06/25/08 RLNUPJC COLLA PSED TBG (05/31 /OS) 10/24!03 MH/TLH GLV GO 04!09/09 GJS 07-14C PROPOSAL 09/18/04 GJB/TLP GLV C/O 08/04/07 DTR/SV GLV GO PRUDHOE BAY UNIT WELL: 07-14B PERMfT No:'2031420 API No: 50-029-20339-02 SEC 33, T11 N, R14E, 511.07' FEL 8 313.93' FNL BP Exploration (Alaska) GAXa~N P~po~d 07-14C 07-14B P&A ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 15, 2009 8:23 AM To: Greg Sarber Subject: FW: 07-14B (203-142) P8~A ~SC~'1-~~~~3 ~'~ Caa~: t~~c~~ ~~~ ~.~~ r~~~ ~ .~~ ~ ~o~~~ ps~ Greg, l Can you provide an answer to my question? ~`~J~n~ Thanks, ~~~~ Tom From: Maunder, Thomas E (DOA) Sent: Tuesday, April 14, 2009 10:05 AM To: 'Staudinger, Garret' SubjeCt: RE: 07-14B (203-142) P&A Thanks Garret, The regulatory requirement is to provide effective isolation. It appears that is possible to pump both ways so cement should be successtully placed. Based on the injection rates, it could take a bit of cement. I wiil place a copy of this message in the file. As I was looking for the permit number, I noted that there is a permit issued for a CT lateral 07-14BL1 (208-060). Have the plans been changed that BL1 will not be drilted? Call or message with any questions. Tom Maunder, PE AOGCC _ _ __. From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] . Sent: Monday, Apri! 13, 2009 4:41 PM ~~d~~~'~ ~~~~ ~;~ 2~~~ To: Maunder, Thomas E (~OA) Subject: RE: 07-14B P&A Tom, We will be setting the retainer in the 5-1/2" tubing pre-rig. A LLR of 4.7 bpm at 1250 psi has been established while pumping down the IA through the collapsed tubing. Service coil has pumped 2.5 bpm down the tubing, but did not establish an injection rate. We are able to pump past the collapse point, but the size of the collapse/split is unknown. Thanks, Garret From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 13, 2009 4:18 PM To: Staudinger, Garret Subject: RE: 07-14B P&A Here is the message. From: Maunder, Thomas E (DOA) 4/29/2009 07-14B P&A ~ ~ Sent: Monday, April 13, 2009 3:33 PM To: 'Staudfiger, Garre~' Subject: RE: 07-14B P8u4 Hi Garret, Sorry getting you and Mark mixed up. I'll bet that has never happened before!!! Will you be pulling the tubing and then setting the retainer or setting it in the 5-1/2"? I presume that you are able to pump past the collapse point? Tom Maunder, PE AOGCC From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] Sertt: Monday, April 13, 2009 3:25 pM To: Maunder, Thomas E (~OA) Subject: 07-14B P&A Tom, Page 2 of 2 I am planning a rotary sidetrack for 07-14B. The current 5-1/2" tubing is collapsed (schematic attached} and we are unable to get any tools past that point. Will placing a cement retainer above the coftapse and down squeezing satisfy state requirements for P&Aing the perf intervat? «07-14B Schematic.pdh> Thank you, Garret Garret Staudinger Operations Drilling Engineer BP Exploration Alaska, Inc. Work: (907} 564~242 Cell; (907) 440-6892 4/29/2009 • • _~. ,n MICROFILMED 03/0112008 DO NOT PLACE e .. _: W~qrqYy'~~~ ~l~_.' ...oN ANY NEW MATERIAL UNDER THiS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofilm Mazker.doc e fit WELL LOG TRANS MITT AL ~)D ?J.-- 14 ~ r35&:J- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 RE: MWD Formation Evaluation Logs 07-14B + PBl, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 07-I4B + PBI: LAS Data & Digital Log Images: 50-029-20339-02, 70 1 CD Rom ~~~ ,9'/ {) ølùw ),) NcvÀ~,ç DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Permit to Drill 2031420 Well Name/No. PRUDHOE BAY UNIT 07-14B Operator BP EXPLORATION (ALASKA) INC ),.~ ~ ÖJ-^--O\3 API No. 50-029-20339-02-00 MD 12500/ TVD 8978 /" Completion Date 10/21/2003 ~ Completion Status 1-01L Current Status 1-01L UIC N Mud Log No Samples No Di'ectiO"~-- REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: GR, EWR, MGR, CCL, CNL Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments . ,J(;t Directional Survey 11724 12500 1 0/27/2003 4 Directional Survey 10352 12400 1 0/27/2003 PB1 ;C~ ~ Ã'l\ 12306 Induction/Resistivity 9692 12470 Open 12/16/2003 GR, EWR4, ROP 12306 Rate of Penetration l D <.J~c·~¡; (.\A... i~ (' "- L [ ;t 9692 12470 Open 12/16/2003 GR, EWR4, ROP ...RSt Iprl11c.tiQn/Res.istivity 9692 12470 Open 12/16/2003 GR, EWR4, ROP ~ R",tp nf ;IOR"L, dllon "' 9f-"2 12470 Open 12.J~ G/2'Oœ ~I'\, l!!\7VrM, nOF ~ED D :x MS 12307 Induction/Resistivity 9692 12380 Open 12/16/2003 GR, EWR4, ROP - PB1 oiED D 12307 Rate of Penetration j.., (S U'"~'\-~'~~"" t.v~ Çr 9692 12380 Open 12/16/2003 GR, EWR4, ROP - PB1 J(pt Inrlll('tion/RQlfwthlity 9692 12380 Open 12/16/2003 GR, EWR4, ROP - PB1 i~ Rat~ af f"'e,\e'!'dliv"" ÇlGQ2 12300 O~n 1 ,211 ~/?IJ¡n r.R. I=WR4. ROP - PIìJ . ~C Asc 12322 Neutron 9499 12467 Case 12/22/2003 Compensated Neutron Log- ¿ Mem GRlCCL/CNL ì Neutron 2 Blu 9499 12467 Case 12/22/2003 Compensated Neutron L09- Mem GRlCCUCNL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2031420 MD 12500 TVD 8978 ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Y I N Analysis Received? ~ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Well Name/No. PRUDHOE BAY UNIT 07-14B Operator BP EXPLORATION (ALASKA) INC Completion Date 10/21/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? ~/N GN Formation Tops ~ Date: API No. 50-029-20339-02-00 UIC N Jc-t ~~ç . '. 07-14B (PTD #2031420) Classified as Problem Well Subject: 07-148 (>Ft*.;_l~~Ø~~~l~~ified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntcgrityEnginccr@BP.com> Date: Thu, 09 Scp 200414:40:02 -0800 To: "Cahalane, Tcd W" <CahalaTW@BP.eom>, "GPB, FS3 TL" <GPBFS3TL(àjBP.com>, "Rossberg, R Steven" <RossbcRS([~BP.com>, "NSU, AD\V Well Operations Supervisor" <NSUADWWcIlOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWcllsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)" <jim_regg@.admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <vv'inton_aubcrt@admin.state.ak.us>, "NSU, ADW WL & Completion Supervisor" <NSUADW\VL&CompletionSupervisor@BP.com>, "GPB, FS3 DS Operators" <GPBFS3DSOperators@BP.com> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntcgrityEngineer@BP.com>, "Reeves, Donald F" <ReevcsDf@BP.com>, "NSU, ADW WL & Completion Supervisor" <1\SUADWWL&CompletionSupcrvisor@BP.com> . All, Well 07-14B (PTD #2031420) has been found to have sustained casing pressure on the IA. A TIFL failed on 09/07/04 with initial T/I/O pressures of 2320/2350/0. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: GLV c/o 3. DHD: Re-TIFL A wellbore schematic has been included for reference. «07-14B.ZIP» The well has been classified as a Problem well. Please call if you have any questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 . Content-I>escription: 07-14B.Z1P Content-Type: application/x -zip-compressed Content-Encoding: base64 I of I 9/1 0/2004 9:46 AM .. TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = GRAY GEN2 GRAY AXELSON 64' ,., 07-148 I ~ - SAFETY NOTES: 10360' 95 @ 11429 10705' 8800' SS 19-5/8" FOCOLLARS -f 2323' & 2452' r--- 113-3/8" CSG, 72#, L80, ID = 12.347" -f 2665' r-J 2256' -f5-1/2 OTIS RQMSSSV NIP, ID=4.562" I GAS LIFT MANDRELS DEV TYPE VLV LATCH 7 OTIS DOME T2 43 OTIS S/O RA 45 OTIS DMY T2 38 OTIS DMY RA 45 OTIS DMY RA 46 OTIS DMY RA 45 OTIS DMY RA 45 OTIS DMY RA 45 OTIS DMY RA 45 OTIS DMY T2 PORT DA TE 16 10/23/03 20 10/23/03 o 08/19/03 o o o o o o o 08/19/03 . ~ ST MD TVD 1 2903 2903 2 5186 4826 3 7033 6139 4 8147 6993 5 8829 7494 6 8902 7545 7 9365 7868 8 9443 7923 9 9587 8025 10 9658 8076 - L I Minimum ID = 2.377" @ 11040" I 2-7/8" STL PIN CONNECTION 15-1/2" TBG-PC, 17#, L-80, .0232 bpf. ID = 4.892" -f 9797' I I 1 1 I I 9520' -f5-1/2" OTIS SLIDING SLV I t 9600'-9850' HGMT SHEATH, ID = 3.80" I 9732' -f5-1/2" OTIS N NIP, ID = 4.455" (IN GMT SHEATH) 9772' -f 5-1/2" BOT PBR ASSY I 9798' -f9-5/8" X 5-1/2" BKR SAB PKR I 9809' -f 6-5/8" X 4-1/2" XO (MILL OUT EXTENSION) 9848' -f3-1/2"BKRDEPLOYSLV,ID=3.00" I 9858' -f3-1/2" X NIP, ID = 2.813" I 9869' -f3-1/2" x 3-3/16" XO,ID= 2.786" I 9870' '14-1/2" CAM DB-6 LA ND NIP, ID = 3.813" I (BEHIND CT LNR) 14-112" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" H 9913' ~ I 10120' -f TOP OF CEMENT (RAMP) I PERFORATION SUMIIt1A RY REF LOG: SPERRY EWR - GR ON 10/14/03 ANGLE AT TOP PERF: 88 @ 10950' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10950 - 11400 0 10/20/03 2" 4 11445 - 11480 0 10/20/03 2" 4 11640 - 11825 0 10/20/03 2" 4 11890-12140 0 10/20/03 2" 4 12295 - 12465 0 10/20/03 19-5/8" CSG, 47#, L-80/S-95, ID = 8.681" H 10524' 12-7/8" LNR, 6.5#, L-80, ID = 2.441" H 11881' .... MILLOUT CMfWlNDOW (07-14B) 10360' - 10363' ~, .... I 11022' 113-1/16" X 2-7/8" I XO, ID = 2.440" ..~ '---/ 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" -f 11022' I PBTD H 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" H 12500' DATE 06/03/79 08/01198 11/22/03 10/24/03 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK (07-14A) CJS/TLH SIDETRACK (07-148)(10/20/03) MHlTLH GLV C/O DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 07 -14B PERMIT No: 2031420 API No: 50-029-20339-02 SEC 33, T11N, R14E, 511.07' FEL & 313.93' FNL BP Exploration (Alaska) 11/18/03 Schlumbepgep NO. 3045 Alaska Data & Consulting Services 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Color -- Date Blueline Prints CD 09/07/03 1 1 ~ "3r9è) 06/05/03 1 1 ~79~. \ 10/15/03 1 1 <~~~ 06/27/03 1 1 ¡ ~'::~!9, ~ - 09/19/03 1 1 Jd~¿X~ 06/14/03 1 1 ~ý 0l F-23A 19 q - fJ'1 Ll G-04A l q Fl. - Ii '" ~ 7-t..., @,6:3 -- ¡:\~ A-06 I" ~ -CJ \ 9( 07 -04A I q C).. -0 t () '1- 05-04A ) q it"' '(!)?S 9 10558573 10563450 10669982 10568460 10687646 10558553 MCNL MCNL MCNL RST-SIGMA RST-SIGMA MCNL -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Seth Date Delivered: n¡:-c ?? ?003 01::;: ..." Received b~\...'U.ý\. 0tC C~~~ ·~iê3k~ Oil & lias Cons. Commj!Sion 1~."chorlJge K~~ rv\ ~ . . ðcð ~J)/~ WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm, Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 15, 2003 RE: MWD Formation Evaluation Logs: 07-14B, AK-MW-2699461 1 LDWG formatted Disk with verification listing. llPI#: 50-029-20339-02 /ð ~ (¡:; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITI'AL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: '-, ...,. ~'- Signed: ~c::~ -~ ~~C::jy\' RECEIVED DEC 16 2003 Alaska Of! & G85 \,;Oos. Commi$Bìon AndlØ1'8ge . . ¿Y03~'/1f~ WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 12, 2003 RE: MWD Fonnation Evaluation Logs: 07-14B PB 1, AK-MW -2699461 1 LDWG fonnatted Disk with verification listing. } ,!9- 3 ð 't API#: 50-029-20339-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: Signed: · STATE OF ALASKA . ALASKÞi . AND GAS CONSERVATION COM ION WELL COMPLETION OR REcOMPLETION REPORT AND LOG 1a. Well Status: ~ Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 CASING, liNER AND CEMENTING RECORD SmlNGDmH HOI.E BotTOM SIZE 71' 30" 243 sx Arcticset 2665' 17-1/2" 4200 sxAS II 10362' 12-1/4" 1200 sx Class 'G' 12500' 4-1/8" x 3-3/4" 147 sx Class 'G' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a, Location of Well (Governmental Section): Surface: 511' SNL, 314' WEL, SEC, 33, T11 N, R14E, UM Top of Productive Horizon: 3936' NSL, 941' EWL, SEC. 27, T11 N, R14E, UM Total Depth: 2438' NSL, 1460' EWL, SEC. 27, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 675869 y- 5950406 Zone- ASP4 TPI: x- 677011 y- 5954881 Zone- ASP4 Total Depth: x- 677568 y- 5953396 Zone- ASP4 18. Directional Survey ~ Yes 0 No 21. Logs Run: GR, EWR, MGR, CCL, CNL 22, 20" 13-3/8" 9-5/8" 94# H-40 72# L -80 47# L-80/S00-95 8.81#/6.2#/6.16# L-80 Surface Surface Surface 9848' 23, Perforations op'en to Production (MD + rvD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2" Gun Diameter, 4 spf MD rvD MD rvD 10950' - 11400' 8960' - 8972' 11445' - 11480' 8969' - 8966' 11640' - 11825' 8968' - 8976' 11890' - 12140' 8978' - 8972' 12295' - 12465' 8969' - 8975' One Other 5, Date Comp., Susp" or Aband. 10/21/2003 6. Date Spudded 10/6/2003 7. Date T.D. Reached 10/14/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 64' 9, Plug Back Depth (MD+ rvD) 12468 + 8975 Ft 10. Total Depth (MD+rvD) 12500 + 8978 Ft 11. Depth where SSSV set (Nipple) 2256' MD 19. Water depth, if offshore N/A MSL 1 b, Well Class: ~ Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-142 13. API Number 50- 029-20339-02-00 14. Well Number PBU 07-14B 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028309 17, Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) SIZE 5-1/2", 17#, L-80 4-1/2", 12.6#, N-80 . 3-1/2" x 3-3/16" x 2-7/8" PACKER SET (MD) 9803' DEPTH SET (MD) 9809' 9809' - 9913' DEPTH INTERVAL (MD) 11335' - 11345' AMOUNT & KIND OF MATERIAL USED Perf for Liner Remedial Cement Job and Pumped 25 Bbls Class 'G' Freeze Protected with MeOH 2500' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 30,2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BSL GAs-McF WATER-BsL 11/23/2003 6.1 TEST PERIOD + 997 5,238 -0- Flow Tubing Casing Pressure CALCULATED + OIL-BsL GAs-McF WATER-BsL Press. 283 24-HoUR RATE 3,923 20,609 -0- 27. CORE DATA .. . Brief d~scription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (a~~ ~¥t! &:essary). Non:bmil~r;;ì;~"~ RBDMSBFL OEC 9 ~3 DEC -22003 I ~2..__! 0 R I G I N. A 'Alaska Oil & Gas Cons. ColTIßÌssion ".,.... ",...,.,,,,., . Anchorage Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE ~y CHOKE SIZE I GAS-OIL RATIO 84° 5,252 OIL GRAVITY-API (CORR) ,~ ", 28: GEOLOGIC MARKERS. 29. .... _,jRMATlON 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". Top CGL I Zone 3 Base CGL I Zone 2C 10403' 8606' None 10495' 8684' 23SB I Zone 2B I 26N 10552' 8733' 22TS 10621' 8794' 21TS I Zone 2A 10680' 8844' Zone 1 B 10739' 8889' Zone 1A 10824' 8937' Base Sadlerochit 12536' 8981' RECEIVED DEC - 2 2003 Alaska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble /fÔ~ ~ Title Technical Assistant Date I ~/ D~ 03 PBU 07-14B Well Number P~epared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 203-142 Permit No. I Approval No, INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion rE~port 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 iEI 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, Subme~sible, 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 2/2003 ORIGINAL ~' .. BP EXPLORATION Operations Sum,l'nary Re,port Rig released from G-12B @ 02:30Hrs on 9/30/2003. Cut CTC. Remove injector gooseneck & unstab coil. RID & store injector in stabbing box. Prep to move rig off well. SAFETY MEETING. Review procedure, hazards and mitigation for moving rig off well. Move off well. Set rig down on pad in front of well. Lay down wind walls and derrick. PRE-RIG MOVE SAFETY MEETING. Review rig move plan and power line crossings. Move Nordic 1 rig to DS 7. Spot rig on mats in front of tree DS mech fin remove reel drive motor transmission on DS and replace. Rig electrician replace shunt in accumulator system Safety mtg re: replace derrick load guy line Replace derrick load guy line Safety mtg re: raise derrick Raise derrick and scope out. Install guy wires. RD derrick stand, prep floor WO wind to subside prior to raise windwalls (at 20 mph wI gusts to 28 mph) W.O. wind to raise windwalls. Wind @ 15mph steady & 25mph gusts. Check WHP - 800psi. Mobilize Litttle Red pumping unit & 1 % KCL water to load well prior to moving in. Wind picks up again @ 22mph steady & 35mph gusts. Suspend well killing - will load well prior to moving in when wind subsides. Continue W.O. wind. Safety mtglTL Move vac trucks and LRS. Prep to raise windwalls Safety mtg re: raise windwalls Raise windwalls and pin Fin RU guy wires. Find oil on absorb in bottom of BOP stack and determine a slow leak in annular preventer. Track down replacement annular (at Kuparuk). RU bails to blocks Safety mtg re: liquid pack wellbore. MIRU LRS to tree cap. Load wellbore with 542 bbls 1% KCI at avg 4.7 bpm @ 1700 psi. Well on vac. RDMO LRS WO BOP stand and replacement bag ND annular and replace wI backup. Hook up hyd hoses Prep to move rig over well. Remove tree cap, remove mousehole & secure cellar. Jack up rig. PJSM for backing rig over well. Review rig back over well procedure, hazards & mitigation. Back rig over well & set down. N/U BOPE. Install lubricator. Meanwhile spot trailers & tanks. Accept rig at 10:00 Hrs on 10/2/2003. Pick up injector head. M/U guide arch & stab CT into injector head. Changeout packoff. Meanwhile fill rig pits with KCUbio water. RlU hardline to tiger tank & PIT to 4000psi. RlU to PIT BOPE. Hook-up annular pressure transducers: lAP - 155psi, OAP - 115psi. Flowline is disconnected. PJSM. Perform initial BOPE pressure/function test. AOGCC test witness waived by John Crisp. Test rig alarms. PJSM. RU and cut 130' CT. Install DS CTC. PT 38k. RU dart Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 07 -14 07 -14 REENTER+COMPLETE Start: NORDIC CALISTA Rig Release: NORDIC 1 Rig Number: From - To I Hours Task I Code NPT ¡Phase. ------...._....._~_. 9/30/2003 02:30 - 05: 15 2.75 RIGD P PRE 05:15 - 07:00 1.75 MOB P PRE 07:00 - 07: 15 0.25 MOB P PRE 07:15 - 08:00 0.75 MOB P PRE 08:00 - 11 :15 3.25 MOB P PRE 11:15-11:30 0.25 MOB P PRE 11 :30 - 20:00 8.50 MOB P PRE 20:00 - 22:00 2.00 MOB P PRE 22:00 - 22:15 0.25 MOB P PRE 22:15 - 00:00 1.75 MOB P PRE 10/1/2003 00:00 - 00: 15 0.25 RIGU P PRE 00:15 - 04:00 3.75 RIGU P PRE 04:00 - 10:00 6.00 RIGU N WAIT PRE 10:00 - 12:00 2.00 RIGU N WAIT PRE 12:00 - 18:00 6.00 RIGU N WAIT PRE 18:00 - 18:20 0.33 RIGU P PRE 18:20 - 20:15 1.92 RIGU P PRE 20: 15 - 20:25 0.17 RIGU P PRE 20:25-21:15 0.83 RIGU P PRE 21:15 - 23:30 2.25 RIGU P PRE 23:30 - 00:00 0.50 RIGU N RREP PRE 1 0/2/2003 00:00 - 06:00 6.00 RIGU N RREP PRE 06:00 - 07:15 1.25 MOB P PRE 07:15 - 07:30 0.25 MOB P PRE 07:30 - 08:00 0.50 MOB P PRE 08:00 - 11 :00 3.00 BOPSURP PRE 11 :00 - 13:30 2.50 RIGU P PRE 13:30 - 14:00 0.50 BOPSURP PRE 14:00 - 19:30 5.50 BOPSUR P PRE 19:30 - 21 :00 1.50 KILL P DECOMP 9/26/2003 10/21/2003 N1 Page 1 of 20 Spud Date: 5/17/1979 End: Description of Operations Printed: 10/27/2003 11:37:45AM ~ . sp EXPLORATION Q'perations Summary Report Page2öf 20 Legal Well Name: 07-14 Common Well Name: 07-14 Spud Date: 5/17/1979 Event Name: REENTER+COMPLETE Start: 9/26/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 10/21/2003 Rig Name: NORDIC 1 Rig Number: N1 i I Phase I Date From - Tö ! Hours Task Code " .. I Description of Operations NPT I 10/2/2003 19:30-21:00 1.50 KILL P DECOMP catcher 21 :00 - 22:00 1.00 KILL P DECOMP Fill CT w/ KCI wI bio water and pump dart. Check well for pressure and had 550 psi. Dart hit at 59.3 bbls. PT CTC and inner reel valve at 3500 psi. Bleed off pressures 22:00 - 00:00 2.00 PULL N FLUD DECOMP WO vac trucks to rekill before MU BHA Service injector 10/3/2003 00:00 - 02:20 2.33 KILL P DECOMP Open up to well to pump thru kill line w/ both pumps. WHP initial 580, IA 150, OA 85 Begin liquid pack with 1% KCI at est 5.0 bpm. Pump #1 rate and totalizer not working. Max WHP 1540 psi, ending WHP 1150, IA 125, OA 200. SD pumping after 580 bbls. ISIP 420, 5 min 70. Bleed down and had gassy retu rns 02:20 - 02:50 0.50 PULL P DECOMP SI @ master. MU shorty fishing BHA. Open master 02:50 - 03:30 0.67 PULL P DECOMP RIH wI BHA #1 (4" GS wI jars) wI well SI pumping min rate down CT 0.2/40 to let residual gas migrate PVT 266 03:30 - 04: 15 0.75 KILL P DECOMP Open well to circ at 4000'. No returns initially except gas pockets. Pump 2.0 bpm at 950 psi while RIH. Got returns after 25 bbls. Continue RIH circ'ing 1.7/1.0 at 730 psi. Started getting gassy returns and incr'd out rate at 7000' 04:15 - 05:00 0.75 KILL P DECOMP At 9000', SI at choke when returns got too gassy. Let WHP build to 500 psi then open choke to tiger tank and maintain 200 psi while circ out gas. Park at 9700' 38k Circ 2.3/1760 then 2.8/2230 holding 200-250 psi BP with no returns except gas 05:00 - 06: 15 1.25 KILL P DECOMP CTP stable 2.8/2810. Open choke and continue circ 2.8/2650 holding 100 psi bp (induced by friction in hardline to tiger tank). Check and have gassy KCI returns, but appear to be gaining ground 06: 15 - 06:35 0.33 KILL P DECOMP Continue circ KCL water taking returns to the pits @ 2.5/2.0bpm & 1480psi - no gas in returns. 06:35 - 06:40 0.08 PULL P DECOMP RIH BHA#1 circ @ 1.6/630psi with clean returns. Tag TOF @ 9823' & set down on fish. 06:40 - 06:45 0.08 PULL P DECOMP P/U & confirm liner engagement with 41 k up wt. 06:45 - 08:10 1.42 PULL P DECOMP POOH with liner fish, liquid packing wellbore down the kill line @ 1.25bpm/350psi. 08: 1 0 - 08:25 0.25 PULL P DECOMP OOH. SID pump & flowcheck well - stable. 08:25 - 08:40 0.25 PULL P DECOMP PJSM. Review procedure for UD liner, well control procedures & requirement for Norm testing. 08:40 - 11 :30 2.83 PULL P DECOMP SIB injector. RIU safety joint. Fill well across the WHD with C-pump. UD BHA #1 & recovered 100% of cut liner assembly consisting of BKR deploy sub & 23.5 jts of 2-7/8" FL4S tbg. Test all retrieved pipe for Norm - normal @ 1-2uRem/hr. 11:30 -12:15 0.75 EVAL P WEXIT M/U MWD tie-in BHA #2 with Sperry MWD, BHI straight motor & used D331 mill. Stab injector on well. Loss rate - 8bbls/hr. 12:15 - 14:15 2.00 EVAL P WEXIT RIH with BHA #2. SHT - OK. Up wt check @ 10500' = 38klbs. Continue RIH BHA#2 to cut 2-7/8" Inr tagged @ 10569'. P/U clean & retag @ same depth. Correct -23' to the CCL cut depth of 10546'. 14:15-19:20 5.08 EVAL P WEXIT Log up GR from 10546' to 9700' (into tubing) @ 2.6/2.5bpm, 2550psi & +1-200fph. Swap to pump #1 at 9850' due to poor signal from pump #2-needs work 19:20 - 20:55 1.58 EVAL P WEXIT Flag at 9600' EOP. POOH for cementing assy 20:55 - 21 :30 0.58 EVAL P WEXIT LD logging assy. MU cementing assy 21:30-23:15 1.75 ZONISO P WEXIT RIH wI BHA #3. MIRU DS cementers Printed: 10/27/2003 11:37:45AM ... . BP EXPLQRAJ10N:> Operations Summary Report Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N1 Phase' ¡ WEXIT Safety mtg re: cement Batch up 40 bbls. Cmt to wt at 2300 hrs. TT 4:20 (too long by 2 hrs) Corr to flag -13'. RIH WEXIT Stop at 10450'. PUH 39k and park at 10420'. PT DS at 3500 psi. DS load CT w/40 bbls 17.2# G cement 1.9/1.8/1680 WEXIT Displace with rig pump using bio water. RIH to 10440'. PUH 52k WEXIT Lay in cement from 10420' at 2.0/400 pulling 5'/min 53k. After 15 bbls out nozzle started losing returns 2.0/1.6/275 at 10'/min. After 30 bbls out nozzle @ 10320' 2.0/1.3/600 20'/min. PLF from 10200' 1.5/0.8/400 and last bbl out at 10100'. PUH to safety. Est lost 10 bbls to formation (est TOC @ 9990') CIP 0015 hrs Park at 9500', circ 0.5/0.35/490 and wait for cmt to settle. Returns steadily improved to 0.50/0.45/510 SI at choke. Pressure up wellbore to 200 psi and lost 100 psi in 5 min. Bleed off press RIH jetting biozan 3.0/1600 to 10000' POOH jetting 3.5/1830 and displacing wellbore to bio water. Dumped cement contaminated fluid w/ max density of 12 ppg LD cement assy. MU swizzle stick. Jet stack on top of closed swab WOC Work on pump #2 and accumulator system Still W.O.C. Meanwhile crew watch BP Lifting Immersion General Training videos # 2 & 3. Lab reports 100psi compressive strength on UCA cement sample @14:30- should be @ 2000psi in ca. 2hrs. WEXIT PJSM. M/U cement milling BHA #4 with 3.80" HC D331 mill, 2-7/8" motor with 1.25deg ABH, GR-DIR MWD, orienter & MHA (OAL = 64.87'). Scribe tools. M/U injector. WEXIT RIH cement milling BHA #4. SHT @ 1000' - OK. Lab reports 2000psi compressive strength on UCA cement sample @16:00. Close choke & allow WHP to increase to 1000psi. PIT cement plug to 1000psi for 1 Omins - held jug tight. Continue RIH & correct -15' @ flag. Wt check @ 9900', up- 40k & down - 20k. See cmt bubbles from 10117'. Ream in hole & found soft cement @ 10120'. Log up GR from TOC to 10050' (in 9-5/8" csg). Subtract 6' from CTD. Orient TF to 2R. RIH reaming w/little resistance (100# diff) 2.7/2.7bpm, 2300/2350psi 120'/hr 5R 10120-200' 10200' PUH 44k Chk FS 2.7/2180/25R Drill cement from 10200-213' w/200# diff, 800# WOB 60'/hr. Stall at 10213'. Drill med firm cement 10213-258" 2.7/2170/21 L 30-40'/hr wI 150# diff 1500-2000# WOB 10258' PUH 44.4k Chk FS 2.7/2190/20R Drill hard cement from 10258-300' w/ 250# diff 1500-2500# WOB 21 L 20-30'/hr 10300' PUH 45.1 k, get a click. Orientor got three instead. Orient around Chk FS 2.75/2390/13R Drill hard cement from 10300- wI 250-300# diff 1500-2500# WOB 10303' FS 2.75/2390/ Continue drill hard cement wI 250-350# Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -14 07 -14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 ¡ Date From- To Hours Task Code NPT ¡ --'--"'.".--.. ----.-------------...- 10/3/2003 21:30-23:15 1.75 ZONISO P 23:15 - 23:50 0.58 ZONISO P 23:50 - 00:00 0.17 ZONISO P 10/4/2003 00:00 - 00:25 0.42 ZONISO P 00:25 - 01 :00 0.58 ZONISO P WEXIT 01 :00 - 01: 1 0 0.17 ZONISO P WEXIT 01: 1 0 - 01 :30 0.33 ZONISO P WEXIT 01:30 - 03:10 1.67 ZONISO P WEXIT 03:10 - 03:30 0.33 ZONISO P WEXIT 03:30 - 12:00 8.50 ZONISO P WEXIT 12:00 - 14:30 2.50 ZONISO P WEXIT 14:30 - 15:20 0.83 STWHIP P 15:20 - 17:35 2.25 STWHIP P 17:35 - 18:10 0.58 STWHIP P WEXIT 18:10 - 18:20 0.17 STWHIP P WEXIT 18:20 - 19:05 0.75 STWHIP P WEXIT 19:05 - 20:40 1.58 STWHIP P WEXIT 20:40 - 22:30 1.83 STWHIP P WEXIT 22:30 - 23:30 1.00 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT Page 3 of 20 Spud Date: 5/17/1979 End: Description of Operations ___________n_._.________n.__ ..._._____n_____..___.___O. u_____. ".. ... __..., _...._.. __. _ ____ Printed: 1012712003 11:37:45AM · '. Page 4 of 20 BP EXPLORATION GJ)perations Summary Report Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N1 Phase I·· Legal Well Name: 07 -14 Common Well Name: 07-14 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Dat~ From - To Hours Task ¡Code NPT 10/4/2003 23:30 - 00:00 0.50 STWHIP P 10/5/2003 00:00 - 01 :25 1.42 STWHIP P 01 :25 - 01:40 0.25 STWHIP P 01 :40 - 02:05 0.42 STWHIP P 02:05 - 03:50 1.75 STWHIP P 03:50 - 04:50 1.00 STWHIP P 04:50 - 06:50 2.00 STWHIP P 06:50 - 07:15 0.42 STWHIP P 07:15 - 08:15 1.00 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 08:15 - 09:00 0.75 STWHIP P WEXIT 09:00 - 18:03 9.05 STWHIP P WEXIT 18:03 - 20:00 1.95 STWHIP P WEXIT 20:00 - 22:20 2.33 STWHIP P WEXIT 22:20 - 00:00 1.67 STWHIP P WEXIT 1 0/6/2003 00:00-01:15 1.25 STWHIP P WEXIT 01:15-02:50 1.58 STWHIP P WEXIT 02:50 - 03:40 0.83 STWHIP P WEXIT 03:40 - 05:25 1.75 STWHIP P WEXIT 05:25 - 05:40 0.25 STWHIP P WEXIT 05:40 - 05:50 0.17 STWHIP P WEXIT 05:50 - 06:10 0.33 STWHIP P WEXIT 06: 10 - 06:45 0.58 STWHIP P WEXIT 06:45 - 07:00 0.25 STWHIP P WEXIT 07:00 - 08:15 1.25 STWHIP P WEXIT 08:15 - 09:15 1.00 STWHIP P WEXIT 09: 15 - 09:50 0.58 STWHIP P WEXIT 09:50 - 09:55 0.08 STWHIP P WEXIT 09:55 - 10:35 0.67 STWHIP P WEXIT Spud Date: 5/17/1979 End: Description of Operations d iff 1500-2500# WOS 30'/h r to 10316' Continue drilling hard cement high side 2.7/2400/15L-30R w/ 300-400# diff 1000-3000# WOS 25-35'/hr from 10316-350' Orient to low side Drilllowside to casing contact 2.65/2340/178L from 10350-360' and saw CW movement in TF POOH for one step mill LD pilot mill assy. MU one step milling assy RIH wI SHA #5 (3 deg motor) & correct -24' @ flag. Wt check @ 9800', up - 43k & down - 17k. Continue RIH to 10090' Log up GR to 10070' (in 9-5/8" csg). Subtract 2.5' from CTD. RIH without pump & stack out @ 10350' (TOCR). PUH & check TF - @ 140R. SID pumps & RSIH & tag @ 10357'. PUH 8' & check TF - @ 113L. PUH & orient TF to 112R. SID pumps & RSIH & tag @ 10359'. PUH 8' & check TF - @ 174R. RSIH & tag 10361.8'. See MW & flag pipe. P/U 1'. TF @ 157R - grab 1 click to 174R. Begin extended time milling schedule. Mill from 10360.7' to 10360.8' with 179R-169L TF, 2.5/2.5bpm, 2400/2500psi. Swap the well to new bio-KCL water. Mill from 10360.8' to 10363.9' with 169L TF, 2.6/2.6bpm, 2000/2200psi. Mill begining to take wt. Mill from 10363.9' by schedule 2.6/2220/164L Drill open hole from 10365.5' and slow going 10368.2' Chk FS/wt 45k, 2.5/2150/164L Continue drilling open hole w/1 00-350# diff/2-5k WOS Continue to drill open hole from 10369.7' w/2.5/2150/134R wI 200-400# diff, 1500-5000# WOB. Stall at 10370.2' Drill to 10371.0' 2.5/2150/170R POOH for tapererd mill Window depths are TOW 10361.8', SOW 10365.5', TD 10371.0' LD one step assy. Mill was 3.79" OD and had center wear. MU tapered mill assy (2.25 deg motor and WII 3.78 dia mill) RIH w/ SHA #6 SHT. Corr -24' at 9600' flag Begin tie-in up from 10090' 2.8/2530/58R 44k, no corr RIH and tag w/o pump at 10362' PUH to 10300' and orient to low side. RSIH & stack ouUstall @ 10360'. PUH 10' & RSIH to stack pI. Ream window area to 10365.3' with 176L TF, 2.6/2.6bpm 2150/2200psi. Stall 5x while reaming window. TF flop to 135L. PUH & orient TF to 126R. SID pumps & RSIH to 10364'. TF @ 172L. Ease back & ream window area to 10366.3' with 178L TF, 2.6/2.6bpm 2150/2200psi. Stall2x@ 10366.3'. P/U & ease back into reaming from 10365'. Ream to 10369' with 176R TF, 2.6/2.6bpm 2150/2200psi. See 600psi MW @ 10369'. Sackream up thru window to 10357' @ 179R TF, 2.6/2250psi. No MW observed - window looks clean. RIH circ@ min rate & tag @ 10369'. Grab 3 clicks. Sackream up thru window to 10357' @ 130L TF, 2.6/2250psi. Getting metal shavings over the shakers. Printed: 10/27/2003 11:37:45AM . . BP EXPLORATION ".' Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -14 07 -14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT Phase -----.-..--.----.-.... ._~...__._._--_. 1 0/6/2003 10:35 - 10:40 0.08 STWHIP P WEXIT 10:40 - 11 :45 1.08 STWHIP P WEXIT 11 :45 -12:05 0.33 STWHIP P WEXIT 12:05 - 12:40 0.58 STWHIP P WEXIT 12:40 - 12:45 0.08 STWHIP P WEXIT 12:45 - 12:50 0.08 STWHIP P WEXIT 12:50 -13:10 0.33 STWHIP P WEXIT 13:10 -13:15 0.08 STWHIP P WEXIT 13:15 - 14:50 1.58 STWHIP P WEXIT 14:50 - 16:10 1.33 DRILL P PROD1 16:10 -17:40 1.50 DRILL P PROD1 17:40-18:15 0.58 DRILL P PROD1 18:15 - 20:00 1.75 DRILL P PROD1 20:00 - 21 :40 1.67 DRILL P PROD1 21:40-23:10 1.50 DRILL P PROD1 23:10 - 00:00 0.83 DRILL P PROD1 10/7/2003 00:00 - 01 :55 1.92 DRILL P PROD1 01 :55 - 02:25 0.50 DRILL P PROD1 02:25 - 04:30 2.08 DRILL P PROD1 04:30 - 05:30 1.00 DRILL P PROD1 05:30 - 07:00 1.50 DRILL P PROD1 07:00 - 07:30 0.50 DRILL P PROD1 07:30 - 08: 15 0.75 DRILL P PROD1 08:15 -10:00 1.75 DRILL P PROD1 10:00 - 10:20 0.33 DRILL P PROD1 10:20 - 10:30 0.17 DRILL P PROD1 10:30 -11:00 0.50 DRILL P PROD1 11 :00 - 12:00 1.00 DRILL P PROD1 Page 5 of 20 Start: Rig Release: Rig Number: Spud Date: 5/17/1979 End: 9/26/2003 10/21/2003 N1 Description of Operations .. -----.....-- RIH circ @ min rate & tag @ 10368.6'. Drill/extend rathole to 10373.5' with 150R TF, 2.6/2.6bpm 2200/2800psi. Sweep hole with 23bbls hi-vis pill. Orient TF to 11 OR. Backream clean up thru window to 10357' @ 11 OR TF, 2.6/2250psi. SID pumps & dry drift window - looks clean. POOH to 10090' for tie-in log. Log up GR to 10070' (in 9-5/8" csg). Add 1.5' to CTD. Paint EOP flag @ 10000' & POOH for drilling BHA. Pill @ shakers with metal shavings & formation sample. OOH. Changeout MWD probe. UD window dressing BHA. Diamond 'crayola' mill guage 3.78". PJSM. M/U drilling BHA #7 with used 3-3/4" x 4-1/8" Smith bicenter bit, 2-7/8" motor with 2.83deg bend, GR-DIR MWD, orienter & MHA. Scribe tools. M/U injector. RIH with drilling BHA #7 & correct -20' @ flag. Wt check @ 9800', up - 41k & down -18k. Continue RIH to 10090'. Log up GR in 9-5/8" csg. 2.6/2540/4R Add 1.0'. RIH thru window w/o pump and tag at 10374'. PUH 44k Chk TF 160L. Start drilling 2.75/2620/170L and start fresh Flo Pro mud. Drill ahead while gradually working TF up the left side at 2.7/3000/100L to 10404' Ran into a brick wall at 10404' and tough to make progress-acts like 23 a little early Drilled to 10417' and going nowhere fast. Can't hold TF either. POOH for bit Change bit, orientor RIH wI BHA #8 (tricone insert bit w/ 2.83 deg motor). Corr 23.8' at flag. RIH thru window clean and tag TD at 10417' Chk TF and orient around from 51 L Drill from 10417-476' 2.5/2800/90-120L at 25-70'/hr wI surveys to chk azm and clicks as necessary. Probably out of the hard stuff, last 5' was 70'/hr and base of 23 at 10495' Survey, then orient around-three times. Had to go to big hole to get clicks, then orientor flopped 180 deg on reaching TD POOH for bi bit and orientor OOH. Check MWD - OK. Changeout orienter. UD tricone bit - 3-5-1/16" undergauge. PJSM. M/U drilling BHA #9 with new 3"3/4" x 4-1/8" Smith bicenter bit, 2-7/8" motor with 2.83deg bend, GR-DIR MWD, new orienter & MHA. M/U injector. RIH with BHA #9. SHT MWD - OK. Continue RIH. Did not see flag. Correct -21' to CTD. Wt check @ 10090', up - 41 k & down - 20k. Log up GR in 9-5/8" csg. Subtract 13' from CTD. Orient TF to 20R. SID pump. RIH clean thru window & tight hole @ 10429'. Ream in hole with 2.5/2.5bpm, 2560/2600psi & 250fph. See 200psi MW @ 10474'. Backream & ream the 3-3/4" hole section until clean. Drill to 10500' with 95L TF, 2.7/2.7bpm, 2900/3200psi & 35fph ave ROP. Lost 2bbls @ 10475'. Printed: 10/27/2003 11 :37:45 AM ...... .. S:þ,EXPLORA TION Øperatio~s Summary Report Drill to 10520' with 90L TF, 2.7/2.7bpm, 2900/3200psi & 45fph ave ROP. Drilling thru top of zone-2. Orient TF around to 100L - flops back to 90L. Wipe hole to 10400' & reorient TF - flops around again. RBIH & reorient 3x to 11 OL. PVT = 268bbls. Drill to 10559' with 110L TF, 2.7/2.7bpm, 2800/3100psi & 55fph ave ROP. Orient TF to 90R. Drill from 10559-577' at 2.7/2820/120R Wiper to window to get clicks Drill from 10577' 2.7/2900/120L Started losing angle quicker than expected. Drill from 10600' 2.7/2900/70L to 10653' Orient around Drill from 10653' 2.7/2920/110L to 10668', ROP very low, and suddenly we have losses. Drilling at 2.7/1.34/3100 psi. Tool faces have been holding steady. Lack of TF changes is not suggestive of a fault. Pit vol=242 bbls. Driller checks flow path. All losses are confirmed to be downhole. 10674', Losses healing up slightly. 2.8/2.0/3100 psi. Called for clean truck to round trip us mud from MI. IAP=400 psi, OAP=880 psi. 10690', Continuing to drill, losses are healing. 2.7/2.4/2870 psi. Free spin=2800 psi. Bleeding lAP and OAP down. 10703', Losses continuing to heal up. 2.7/2.5/2850 psi. Pit level=222 bbls. 10737', Losses mostly healed up. 2.6/2.45/2890 psi. Pit Vol=195 bbls. Taking on 100 bbls of new mud from Vac truck, then holding rest on standby. 10750', Wiper trip to the shoe. PU @ 37 klbs. Finish wiper trip to shoe, clean trip with no problems. Resume drilling. 2.65/2.5/3300 psi. 10753', Drilling ahead. 2.7/2.6/3180 psi. Pit vol=292 bbls. 10800', orient to 50R. Resume drilling. 2.64/2.5/3200 psi. Pit vol=287 bbls. This bit does not seem to cut in the shales very well. It does fine in the sands, but ROP is consistently low in the shale. Typically 10-20 fph. This is slower than expected. PROD1 10849', BHA length wiper. Still very slow ROP. We are currently drilling in a thin shale. Geo reports we should break out at any time. We will bang our heads against the wall for a little while more before tripping for a bit. Drill ahead. 2.6/2.512960 psi. Pit vol=275 bbls. Taking on mud to top off pits prior to releasing Vac truck. Orient around to 40R. Drill l' from 10855' 2.75/2.60/3170/60R and too slow of progress. Need to orient around again POOH for bit Change bit (0-3-1 wI 3 nose jets plugged). Chk orientor and motor RIH wI BHA #10 (2.83 deg motor, DS100 bit). Corr -30' at 9900' Log up from 10090' 2.4/2550/105L Corr -7' RIH thru window, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-14 07 -14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT ¡ Phase -----..----.... 10/7/2003 12:00 - 12:25 0.42 DRILL P PROD1 12:25 - 13:25 1.00 DRILL P PROD1 13:25 - 14:15 0.83 DRILL P PROD1 14:15 - 15:15 1.00 DRILL P PROD1 15:15-15:55 0.67 DRILL P PROD1 15:55 - 17:00 1.08 DRILL P PROD1 17:00 - 18:15 1.25 DRILL P PROD1 18:15-18:50 0.58 DRILL P PROD1 18:50 - 19:45 0.92 DRILL P PROD1 19:45 - 20:00 0.25 DRILL P PROD1 20:00 - 20: 15 0.25 DRILL P PROD1 20:15 - 20:30 0.25 DRILL P PROD1 20:30 - 22:20 1.83 DRILL P PROD1 22:20 - 23:00 0.67 DRILL P PROD1 23:00 - 23:30 0.50 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 10/8/2003 00:00 - 00:55 0.92 DRILL P PROD1 00:55 - 01 :20 0.42 DRILL P PROD1 01 :20 - 05:30 4.17 DRILL P PROD1 05:30 - 05:40 0.17 DRILL P 05:40 - 05:50 0.17 DRILL P PROD1 05:50 - 06:30 0.67 DRILL P PROD1 06:30 - 06:40 0.17 DRILL P PROD1 06:40 - 08: 15 1.58 DRILL P PROD1 08:15 - 08:55 0.67 DRILL P PROD1 08:55 - 10:40 1.75 DRILL P PROD1 10:40 - 11 :00 0.33 DRILL P PROD1 Page 6 of 20 Start: Rig Release: Rig Number: Spud Date: 5/17/1979 End: 9/26/2003 10/21/2003 N1 Description of Operations Printed: 10/27/2003 11:37:45 AM . . BP EXPLOR~ TION Operations Summary Report Page 7 of 20 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date -.----..--- 10/8/2003 10/9/2003 10/10/2003 07-14 07-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N1 Spud Date: 5/17/1979 End: From - To Hours Task·.·. Code NPT I Phase Description of Operati(jns . ; ..-------- 10:40 - 11 :00 0.33 DRILL P PROD1 clean 11:00-11:25 0.42 DRILL P PROD1 Ream 3.75" hole 15'/min, then RIH to TD tagged at 10852' 2.7/3000/94R PVT 290 11:25-12:00 0.58 DRILL P PROD1 Orient around 12:00 - 12:35 0.58 DRILL P PROD1 Drill from 10852' 2.7/2.65/3000/30-50R at 60-150'/hr to 10924' and landed at 90 deg 8894' TVD 12:35 - 13:40 1.08 DRILL P PROD1 Orient around to left side. Wiper to window to get clicks 13:40 - 14:50 1.17 DRILL P PROD1 Drill from 10924' 2.7/2.65/30001 80L to 11000' wI several wipers to remove dogleg PVT 270 14:50 - 15:20 0.50 DRILL P PROD1 Orient around 15:20 - 16:45 1.42 DRILL P PROD1 Drill from 11000' 2.7/2.7/3030/110L to 11074' 16:45 - 17:05 0.33 DRILL P PROD1 Wiper while w/o DD/geo/SS to decypher surveys and decide to where to pull 17:05 -17:30 0.42 DRILL P PROD1 Drill from 11074' 2.8/3250/30L to 11090' (8899' TVD) 17:30 -18:00 0.50 DRILL P PROD1 Wiper to window 18:00 -19:30 1.50 DRILL P PROD1 Flag at 10000' EOP. POOH 19:30 - 20:15 0.75 DRILL P PROD1 Tag up at surface, lay down drilling BHA. Hycalog bit recovered at 1,4,JD. 20: 15 - 20:30 0.25 BOPSUR P PROD1 Safety meeting prior to starting weekly BOP test. 20:30 - 00:00 3.50 BOPSUR P PROD1 Perform weekly BOP test. Witness waived by State of Alaska, AOGCC, Chuck Sheve. 00:00 - 02:45 2.75 BOPSURP PROD1 Continue with weekly BOP test. 02:45 - 03:00 0.25 DRILL P PROD1 Safety meeting prior to making up BHA #11. 03:00 - 04:45 1.75 DRILL P PROD1 MU BHA #11. Hycalog DS49 bit, 1.04 deg motor, Sperry RES, GR, Directional tool. Read/program RES tool. MU Injector. 04:45 - 06:45 2.00 DRILL P PROD1 RIH with BHA #11. Shallow hole test at 500'. Corr -35' at flag 06:45 - 07:00 0.25 DRILL P PROD1 Log tie-in up from 10100', corr -2.5' 07:00 - 07:25 0.42 DRILL P PROD1 Precautionary ream to TD and tag at 11092' 07:25 - 10:30 3.08 DRILL P PROD1 Log MAD pass wI res tool 11092-10700' 120'/hr 2.5/2620/83R Log recorded data to 10385' 10:30 -11 :00 0.50 DRILL N SFAL PROD1 Park and reboot PC's due to data acquisition problem from adding generator this am 11:00 -11:30 0.50 DRILL P PROD1 RIH to TD PVT 256 11:30 -12:15 0.75 DRILL P PROD1 Orient around 12:15 - 14:20 2.08 DRILL P PROD1 Drill from 11092' 2.7/2.7/3000/98-85L to 11189' and losing angle 14:20 - 14:35 0.25 DRILL P PROD1 Orient to HS 14:35 - 15:20 0.75 DRILL P PROD1 Drill from 11189' 2.60/2.55/3020/34L to 11239' 15:20 - 16:00 0.67 DRILL P PROD1 Wiper to window prior to orient around 16:00 - 16:40 0.67 DRILL P PROD1 Orient around PVT 237 16:40 - 18:30 1.83 DRILL P PROD1 Drill from 11239' 2.8/2.75/3050/11 0-80L to 18:30 - 18:45 0.25 DRILL P PROD1 11357', orient to 45R. 18:45 - 19:20 0.58 DRILL P PROD1 Resume drilling. 2.7/2.6/3390 psi. Pit vol=233 bbls. IAP=310 psi, OAP=330 psi. Free spin = 3000 psi at 2.7 bpm. 19:20 - 20:20 1.00 DRILL P PROD1 Wiper trip to the shoe. 20:20 - 20:25 0.08 DRILL P PROD1 Resume drilling. 20:25 - 20:40 0.25 DRILL P PROD1 11411', Orient to 80R. 20:40 - 22: 15 1.58 DRILL P PROD1 Resume drilling, pit vol=223 bbls. 22: 15 - 22:45 0.50 DRILL P PROD1 11525', Orient to 80R. 22:45 - 22:55 0.17 DRILL P PROD1 Resume drilling. 22:55 - 00:00 1.08 DRILL P PROD1 11550', Wiper trip to the shoe. 00:00 - 00:50 0.83 DRILL P PROD1 11550', Resume drilling. 2.6/2.6/3350 psi. Taking on new mud for mud swap. Printed: 10/27/2003 11:37:45AM ~. .. page 8 of 20: BPEXPLORA TION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -14 07 -14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date, , From-To I Hours Task 'Code NPT Phase 10/1 0/2003 00:50 - 01 :30 0.67 DRILL P 01 :30 - 03:15 1.75 DRILL P 03:15 - 03:50 0.58 DRILL P 03:50 - 04: 15 0.42 DRILL P 04:15 - 04:40 0.42 DRILL P 04:40 - 04:50 0.17 DRILL P 04:50 - 05:45 0.92 DRILL P 05:45 - 06:15 0.50 DRILL P 06:15 - 06:40 0.42 DRILL P 06:40 - 07:30 0.83 DRILL P 07:30 - 08:20 0.83 DRILL P 08:20 - 08:45 0.42 DRILL P 08:45 - 09:30 0.75 DRILL P 09:30 - 09:45 0.25 DRILL P 09:45 - 10:45 1.00 DRILL P 10:45 - 11 :55 1.17 DRILL P 11 :55 - 12:30 0.58 DRILL P 12:30 - 13:40 1.17 DRILL P 13:40 - 14:15 0.58 DRILL P 14:15 - 14:45 0.50 DRILL P 14:45 - 15:35 0.83 DRILL P 15:35 - 16:00 0.42 DRILL P 16:00 - 16:45 0.75 DRILL P 16:45 - 17:00 0.25 DRILL P 17:00 - 17:35 0.58 DRILL P 17:35 - 17:55 0.33 DRILL N 17:55 - 18:30 0.58 DRILL P 18:30 - 19:45 1.25 DRILL P 19:45 - 22:05 2.33 DRILL P 22:05 - 22:30 22:30 - 00:00 10/11/2003 00:00 - 01 :00 0.42 DRILL P 1.50 DRILL P 1.00 DRILL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 SFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 01:00-01:10 0.17 DRILL PROD1 01:1 0 - 01 :45 0.58 DRILL PROD1 01 :45 - 03:30 1.75 DRILL PROD1 03:30 - 04:30 1.00 DRILL PROD1 04:30 - 04:45 0.25 DRILL PROD1 04:45 - 06:15 1.50 DRILL PROD1 Start: Rig Release: Rig Number: Spud Date: 5/17/1979 End: 9/26/2003 10/21/2003 N1 Description of Operations ...._ .__.__h_.____ _.. _ .... .....m.__.__.~._ ... ~._._._.___________._.__..~_...__. _____ 11606', Orient around to 90R. Getting inconsistent clicks from the orienter. Sometimes get 10 deg, sometimes 20 deg clicks. Resume drilling. Still taking new mud into pits. IAP=240, OAP=303 psi. 11647', Orient around to 90R again. Resume drilling. Mud swap completed. Pit Vol=262 bbls. 11686', Orient around. Drill ahead. 11700', Wiper trip to tubing tail at 9913' to clean the 9-5/8" casing out. Tie in pass up from 10115'. Add 3.0' RIH to TD with one set down at 10635' Orient around from 162R Drill from 11700' 2.6/2.55/2980/90R to 11778' and stacking w/ overpulls Wiper to 11575' Drill from 11778' 2.7/2.65/3050/1 05R to 11830' and can't hold 88.5 deg to follow 1.5 deg dip Orient to lowside Drill from 11830' 2.7/2.65/2940/155R to 11849' in a shale Wiper to window Orient around Drill from 11849' 2.8/2.76/3070/90R to 11942' Orient around Drill from 11942' 2.4/2.35/2860/80-90R to 12000' Wiper to window Log tie-in up from 10110' 2.5/2720/157R, no corr RIH to TD PVT 245 Orient to left Drill from 12000' 2.7/2.66/3040/90-110L to 12058' Work to reprogram MWD by cycling tool Drill from 12058' 2.5/2.48/3000/80-90L to 12070', Drilling ahead at 2.6/2.6/3200 psi. Pit vol=238 bbls. IAP=475 psi, OAP=525 psi. 12150', Wiper trip to tubing tail to clean cuttings out of 9-5/8" casing. Clean up to ttail. Set down at 11627' while RIH. Big shale at this depth. PU and fell thru it ok. Orient to 80L. Resume drilling. 12225', Continue drilling ahead. 2.7/2.7/3370 psi. IAP=240, OAP=281 psi. Pit vol=251 bbls (Had an additional 50 bbls delivered at 23:00, increasing lubetex to 3% and flo-Iube to 1.5%). 12254', orient to straight up to get out of shale. Resume drilling. 12265', Wiper trip to the shoe. Resume drilling. Having to snub at -10000 Ibs to get it to drill. We are very near coil lockup with this mud. (Mud was at 0.5% drilling solids at midnight). 12293', orient to 80L. Resume drilling. Swap to a new mud system with 3% lubetex, 1.5% flo-Iube, and 12#/bbl Kla-gard. Drill to 12320' 2.6/2.58/3690 and stacking/overpulling. FS is too high even for Printed: 1 0/27/2003 11: 37: 45 AM -. ~ .. Þage:$ of20 sp: EXPLORATION· Operatibns Summary:Report -- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-14 07-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT Phase -.-------.-. -_........~.. 10/11/2003 04:45 - 06: 15 1.50 DRILL PROD1 06:15 - 07:20 1.08 DRILL P PROD1 07:20 - 08:50 1.50 DRILL P PROD1 08:50 - 11 :40 2.83 DRILL P PROD1 11:40 - 13:40 2.00 DRILL P PROD1 13:40 - 14:00 0.33 DRILL P PROD1 14:00 - 15:00 1.00 DRILL P PROD1 15:00 -15:15 0.25 DRILL P PROD1 15:15 - 15:45 0.50 DRILL P PROD1 15:45 - 16:20 0.58 DRILL P PROD1 16:20 - 16:35 0.25 DRILL P PROD1 16:35 - 17:25 0.83 DRILL P PROD1 17:25 - 18:30 1.08 DRILL N DPRB PROD1 18:30 - 20:35 2.08 DRILL N DPRB PROD1 20:35 - 20:45 0.17 DRILL N WAIT PROD1 20:45 - 22:00 1.25 STKOH X WAIT PROD1 22:00 - 22:30 0.50 STKOH C PROD1 22:30 - 22:45 0.25 STKOH C PROD1 22:45 - 23:00 0.25 STKOH C PROD1 23:00 - 00:00 1.00 STKOH C PROD1 10/12/2003 00:00 - 01 :00 1.00 STKOH C PROD1 01 :00 - 01 :25 0.42 STKOH C PROD1 01 :25 - 02:45 1.33 STKOH X DPRB PROD1 Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N1 Spud Date: 5/17/1979 End: Description of Operations ·..··___....._._.___._______h.. _..._... ____ new mud. Still in shale and building angle to get out of shale (at 93 deg). This BHA won't be able to drill to TD extension (200') of 12700' even wI new mud Wiper to window POOH to change BHA Change everything except the bit. Download and LD res tool. Change MWD probe and orientor. Motor was too tite (source of high pressure). Add agitator tool. Cut off 10' CT. Install new DS CTC. PT 35k, 3500 psi RIH wI BHA #12 (1.04 deg motor) SHT, orientor too Corr -35' at 10135'. Log up from 10090'. Corr -3.5' RIH and clean to TD tagged at 12324' 2.4/3400/160L Log MAD pass up from TD to 12300' to get GR data missed when res tool removed Orient Drill from 12324' 2.5/3500/80L to 12358' and see 91 deg where it should be 93 deg Wiper while check offset and MWD data. Orient 2 clicks Drill from 12358' 2.6/3600/23L and continue to lose angle. Orient to HS. Drilled to 12400' and can't recover angle-holding 90.5 deg and still in shale Wiper to window prior to POOH for either OH WS (recommended) or bigger motor (bad idea). Had 20k overpulls thru 12410-60'. Also had 10k overpull thru 11830-50' and at 11635' Paint flag at 9900' EOP. POH. Confer with town to decide which direction to go. Tag up at surface, stand back injector, rig down BHA. Bit recovered graded at 1,2. Stand by on decision from town geology about plan forward. Town confirms that plan forward is to set an OH whipstock. Notify Weatherford to head to rig with neccessary equipment. Wait on WF. PU WF OH aluminum Billet whipstock and other items to rig floor. Safety meeting prior to picking up OH whipstock. MU WF OH Whipstock. RIH with WF OH Whipstock, BHA #13. Continue RIH with WF OH Whipstock. Stop at flag, make -42' correction. Weight check up=35k Ibs. RIH smooth thru the window, smooth in OH down to 11095', then set down. Try to work whipstock deeper. Note, that this depth is the spot were we switched from 4.125" bit to 3.75" bit. PU/Set down numberous times. Worked it up and down for 20-30 times at different speeds and set down weights. Finally managed to break it free. Looked like something was in front of the whipstock being shoved. Mudball, chert pebble, cement chunk? Who knows? Finally with great difficulty pounded it down in stages; 11149', 11194', 11254', 11305', 11580', 11620', 11646',11655', 11727', 11733', 11765'. At final set down, worked up and down several times. Finally started getting a heavy pull on PU. Time to set this thing. Converse with DD Printed. 10/27/2003 11:37:45AM ,~ - ~ .. Page 1Q:,of 20 ,m BP EXPLORATION Qperatipns Summary, Report' and Geo. This will work for the sidetrack. Drop 5/8" ball to set OH whipstock. Chase with mud. Ball on seat at 55 bbls away. Coil vol=59.3 bbls. Good indication of set. Set back down on WS. Tagged up on top. Confirmed set. Depth of bottom of WS at 11763', Top of billet is at 11748'. PROD1 POH, Pumping 0.8 bpm. PROD1 Tag up at surface, stand back injector, layout WF setting tools. Whipstock was still on setting tool. Whipstock did not set properly, and was retrieved with tool. WAIT PROD1 Troubleshoot failed WF setting tool. No problems found. The setting ball was on seat as expected. Send WF eq. back to Deadhorse shop for further troubleshooting. Problem found to be a BHA set up incorrectly by WF. Had the wrong ball seat below a diverter sub. Crew XO/Safety mtg re: wellbore cleanout MU drilling assy (MWD w/1.04 deg motor/bi bit) RIH wI BHA #14 SHT. Chk orientor at 4000' and pressure too high 2.5/4200 POOH to check BHA Chk BHA and found motor too tite. Change it out RIH w/ BHA #14RR. SHT 2.5/3600 Rig evacuation drill-discuss Resume RIH wI BHA #14RR. Corr -42' at flag RIH thru window, clean. Precautionary ream 18'/min to 11600' 2.55/3170 with TF 180 out from drilled TF. Set down at 11600' Orient around, twice to drilled TF of 90-110R Continue slow ream at 5'/min at 2.5/2900/150R and clean thru 11600-11650'. Continue ream in hole and set down at 11825'. Ream thru at 2.5/2850/151 R to 11880' and backream clean. Ream from 11800' to 12050', clean Backream from 12050' and clean to 11550' RIH wI pump at min rate and set down at 11610', but end up working easily to 11700'. Backream was clean. RIH w/ pump and set down at 11630'-TF flopped 180 deg Orient from 90L to 90R and can't get TF to hold Ream in hole from 11600' 2.6/3000/5R and let TF follow hole. Minor motor work and wt bobbles to 11650'. RIH to 12050' and shale at 11830' was clean. Start 50 bbl hi vis pill Backream OOH with pill exiting at 11700' and continue wiper to window. No overpulls or motor work-hole as clean as we can get it Log tie-in up from 10090'. Add 5.0'. Flag at 10000' EOP POOH Tag up at surface with clean out BHA. Stand back injector. Lay down bit, motor, MWD. IAP=105 psi, OAP=116 psi. Pit vol=204 bbls. Bit recovered graded at 0,1. Make up WF OH whipstock. RIH with WF OH whipstock. Stop at flag make -34' to get on depth. Check weight, up at 36klbs, continue RIH. Smooth thru the window. Loss of weight thru 11600-11650' shale. Set down at 11714', 11763', 11772'. Probably pushing something in front of us again. Set down and sticking at 11779'. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-14 07 -14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From ,," To Hours Task Code NPT! Phase _._.._____O_n_._. . 1 0/12/2003 01 :25 - 02:45 1.33 STKOH X DPRB PROD1 02:45 - 03:30 0.75 STKOH C PROD1 03:30 - 05:30 05:30 - 05:45 2.00 STKOH C 0.25 STKOH C 05:45 - 06:00 0.25 STKOH X 06:00 - 06: 15 0.25 STKOH X DPRB PROD1 06: 15 - 07:30 1.25 STKOH X DPRB PROD1 07:30 - 08:20 0.83 STKOH X DPRB PROD1 08:20 - 09:00 0.67 STKOH X DFAL PROD1 09:00 - 09:40 0.67 STKOH X DFAL PROD1 09:40 - 09:50 0.17 STKOH X DFAL PROD1 09:50 -10:15 0.42 STKOH X DFAL PROD1 10:15 - 12:00 1.75 STKOH X DPRB PROD1 12:00 - 12:50 0.83 STKOH X DPRB PROD1 12:50 - 13:35 0.75 STKOH X DPRB PROD1 13:35 - 14:30 0.92 STKOH X DPRB PROD1 14:30 - 14:50 0.33 STKOH X DPRB PROD1 14:50 -15:10 0.33 STKOH X DPRB PROD1 15:10-15:35 0.42 STKOH X DPRB PROD1 15:35 - 16:00 0.42 STKOH X DPRB PROD1 16:00 - 17:00 1.00 STKOH X DPRB PROD1 17:00 - 17:30 0.50 STKOH X DPRB PROD1 17:30 - 18:50 1.33 STKOH X DPRB PROD1 18:50-19:15 0.42 STKOH X DPRB PROD1 19:15 -19:30 0.25 STKOH X DFAL PROD1 19:30 - 21 :50 2.33 STKOH X DFAL PROD1 Start: Rig Release: Rig Number: Spud Date: 5/17/1979 End: 9/26/2003 1 0/21/2003 N1 Description of Operations .... ...- ..--...- ---- . - _. .______d"__. Printed: 10/27/2003 11 :37:45 AM .... . Page 11 of 20 BP EXPLORATION Operations Summary Report DFAL PROD1 Working pipe trying to get whipstock down. Problem appears to be the same as the first WS run. We are pushing a clay ball or other debris ahead of us, and can not circulate to the bottom of the BHA. Continue to work it down. Getting sticky pickups, finally got stuck. Worked it free by pulling maximum safe wt on whipstock. We had better set this here, and take what we can get before getting badly stuck. Top of fill is at 11763'. DFAL PROD1 PU to ball drop depth. Drop 1/2" ball to set whipstock. Position bottom of WS at 11760'. (Top at 11745'). Coil vol=59.3 bbls. Drop/chase ball with mud. Ball on seat at 58.5 bbls away. PU, then set back down and got good inidcation of set. POOH with WF OH WS setting tool. Continue POH with the WF setting tools. Tag up, stand back the injector. Lay down WF setting tools. All tools recovered properly. The whipstock was left in the hole this time. Good set. Make up sidetrack BHA RIH with BHA #16 to sidetrack off of whipstock. Shallow hole test of orienter, worked ok. Continue RIH. Log tie in pass over GR character at 10050'. Make -39' corection, which is consistent with previous runs. Continue RIH to begin drilling sidetrack. Tag top of whipstock at 11750', begin drilling sidetrack at 80L. Free spin 2.5/2.5/2970 psi. IAP=106 psi, OAP=101 psi. Pit vol=243 bbls. Have a few stalls getting started, then Start making new hole. Drill from 11751' 2.5/3000/80L to 11777'. Backream/ream thru sidetrack area, clean Orient around Drill from 11777' 2.5/2.48/2990/124L to 11803' Orient to rig ht Drill from 11803' 2.5/3000/60-85R trying to hold in this 3-5' TVD sand to 11898' Wiper to window. Clean with TF at 90R by OH WS on upream. Shale at 11600' okay too. Orient to 83L to go by OH WS on down ream Orient from 80L to 80R Drill from 11898' 2.5/3000/85R to 11910' and can't get drill offs. In a shale, stacking full wt. Need a different bit Wiper to window POOH for bit Change bit (1-1-1), orientor, add agitator RIH wI BHA #16 SHT, orientor tool Corr -35' at 10135'. Log up from 10090' 2.5/3600/24L. Corr -10' RIH thru window, then precautionary ream to TD Orient to 40R. 11910', Back to drilling. Free spin 3400 psi at 2.4 bpm. Drilling at 2.35/2.35/3700 psi. Pit vol = 211 bbls, IAP=183 psi, OAP=208 psi. Making 70 fph in shale. Good weight transfer. Drilling at +15000 string weight at surface. Called for mud swap. Current mud at 0.7 % solids. It will take 4 hours to get new mud to location. Want to have new mud in the hole for the liner. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -14 07-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours ¡ Task Code NPT: Phase _·._~_....m._. 10/12/2003 21 :50 - 22:10 0.33 STKOH X 22:10 - 22:40 0.50 STKOH X 22:40 - 00:00 1.33 STKOH X DFAL PROD1 10/13/2003 00:00 - 00: 15 0.25 STKOH X DFAL PROD1 00:15 - 00:30 0.25 STKOH X DFAL PROD1 00:30 - 01 :15 0.75 STKOH C PROD1 01:15 - 03:05 1.83 STKOH C PROD1 03:05 - 04:05 1.00 STKOH C PROD1 04:05 - 04:55 0.83 STKOH C PROD1 04:55 - 06:15 1.33 STKOH C PROD1 06: 15 - 06:35 0.33 DRILL C PROD1 06:35 - 07:00 0.42 DRILL C PROD1 07:00 - 07:20 0.33 DRILL C PROD1 07:20 - 08:00 0.67 DRILL C PROD1 08:00 -10:10 2.17 DRILL C PROD1 10:10 - 12:00 1.83 DRILL C PROD1 12:00 - 12:20 0.33 DRILL C PROD1 12:20 - 12:45 0.42 DRILL C PROD1 12:45 - 13:30 0.75 DRILL C PROD1 13:30 - 14:45 1.25 DRILL C PROD1 14:45 - 15:30 0.75 DRILL C PROD1 15:30 - 17:20 1.83 DRILL C PROD1 17:20 - 17:40 0.33 DRILL C PROD1 17:40 - 18:30 0.83 DRILL C PROD1 18:30 - 18:40 0.17 DRILL C PROD1 18:40 - 19:55 1.25 DRILL C PROD1 Start: Rig Release: Rig Number: Spud Date: 5/17/1979 End: 9/26/2003 10/21/2003 N1 . . Description of Operations Printed: 10/27/2003 11 :37:45 AM ..... . Page 12 of 20 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -14 07 -14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date I From - Tö Hours Task ¡ Code NPT Phase .....-...---.----- 10/13/2003 19:55 - 20: 15 0.33 DRILL X SFAL PROD1 20: 15 - 20:50 0.58 DRILL X SFAL PROD1 20:50 - 21 :40 0.83 DRILL C 21 :40 - 21 :50 0.17 DRILL C 21:50-22:10 0.33 DRILL C 22:10 - 22:30 0.33 DRILL C 22:30 - 22:45 0.25 DRILL C 22:45 - 00:00 1.25 DRILL C 10/14/2003 00:00 - 00:25 0.42 DRILL C 00:25 - 00:35 0.17 DRILL C 00:35 - 00:45 0.17 DRILL C 00:45 - 01 :00 0.25 DRILL C 01 :00 - 01 :40 0.67 DRILL C 01 :40 - 01 :55 0.25 DRILL C 01 :55 - 03:20 1.42 DRILL C 03:20 - 04:25 1.08 DRILL C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 04:25 - 05: 15 0.83 DRILL C PROD1 05:15 - 05:50 0.58 DRILL C PROD1 05:50 - 06:20 0.50 DRILL C PROD1 06:20 - 06:50 0.50 DRILL C PROD1 06:50 - 07:10 0.33 DRILL C PROD1 07: 1 0 - 07:40 0.50 DRILL C PROD1 07:40 - 07:55 0.25 DRILL C PROD1 07:55 - 08: 15 0.33 DRILL C PROD1 08:15-09:15 1.00 DRILL C PROD1 09:15 - 09:40 0.42 DRILL C PROD1 09:40 - 10:40 1.00 DRILL C PROD1 10:40 -11:10 0.50 DRILL C PROD1 11 :10 - 12:00 0.83 DRILL C PROD1 12:00 - 13:30 1.50 DRILL P PROD1 13:30 - 14:50 1.33 DRILL P PROD1 14:50 - 15:50 1.00 DRILL P PROD1 15:50 - 16:30 0.67 DRILL P PROD1 Start: Rig Release: Rig Number: 9/26/2003 10/21/2003 N1 Spud Date: 5/17/1979 End: Description of Operations 11968', Problem with SWS counter head. Need to PU off bottom and make a repair. Stop at 11800', keep pumps on. Repair counter head. Log tie in pass over GR spike at 11830' to confirm that there is no depth accuracy problem. Found we were 16' off depth. Add 16'. 11983', Resume drilling. 12018',300' wiper. Resume drilling. 12046', orient straight down. Starting swap to new mud. 12072', Wiper trip to shoe. Shut pumps down to 0.5 bpm when pulling thru OH WS area. Hung up at WS, then popped thru. Continue wiper trip back in hole. Orient to 80L to get thru OH WS. Continue wiper trip into hole. Orient to 80R. 12072', resume drilling. 2.5/2.5/3820 psi. Taking on new mud. IAP=184 psi, OAP=242 psi. Making 100 fph in zone 1B. 12154', Orient to 80L Drill ahead. 12221', Wiper trip to the shoe. Clean PU off bottom. Pulled weight coming thru the the OH whipstock with pumps down. Popped free once we got thru the WS. Cuttings? Continue wiper trip to shoe clean with no problems. Run back in the hole. Did not orient to go past OH WS. Just dropped pumps to 0, and let orienter flop. Went thru slick without a bobble. Kicked pumps on and ran to bottom. 12221', Resume drilling. 2.5/2.5/3834 psi. Pit vol=245 bbls. IAP=225 psi, OAP=245 psi. TF=O, Driling at 90 fph in zone 1 B. 12251', orient to 80L. Drill from 12251' 2.5/3480/80L to 12286' and stacking and overpulling 100' wiper Drill from 12286' 2.5/3480/120L and penetration rate indicates a sand, GR later shows 40-60 api. Dig to 12335' Wiper while SS reboots PC Drill from 12335' 2.4/3280/145L to 12355' Wiper to window prior to orient. Overpull in minishale at 11830'. OH sidetrack point was clean Log tie-in up from 10090'. Add 4.0' RIH thru window, clean. Precautionary ream to TD. Wt loss at 11620', OH sidetrack was clean. Wt loss and pull heavy at 12260'. Ream thru shale and RIH to TD tagged at 12354' Orient Drill from 12354' 2.5/3500/90L trying to stay in sand until TD (revised back to 12500'). Drill to 12400' Drill from 12400' 2.5/3500/54L to 12495' uncorrected TD Wiper to window. Overpull at 12240'. OH sidetrack point was clean Log tie in pass over GR spike at 10050'. Pit vol=187 bbls. IAP=444 psi, OAP=450 psi. Made a +7.5' depth correction. RIH to make final tag ofTD. Set down at 12285'. Printed: 10/27/2003 11 :37:45 AM ~ . Page 13 of 20 BP EXPLORATION OperatioAS .Summary Report·. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 07 -14 07 -14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 i From "':To Hours I Task Code NPT Phase 10/14/2003 16:30 - 16:45 PROD1 0.25 DRILL P 16:45 - 18:00 1.25 DRILL P 18:00 - 21 :30 3.50 DRILL P 21 :30 - 22:00 0.50 DRILL P 22:00 - 22:30 0.50 CASE P 22:30 - 00:00 1.50 CASE P 1 0/1512003 00:00 - 03:00 3.00 CASE P PROD1 PROD1 PROD1 COMP COMP COMP 03:00 - 03:30 0.50 CASE P COMP 03:30 - 06:30 3.00 CASE P COMP 06:30 - 07:05 0.58 CASE P COMP 07:05 - 09:45 2.67 CASE P COMP 09:45 - 10:05 0.33 CEMT P COMP 10:05 - 10:25 0.33 CEMT P COMP 10:25 - 11 :25 1.00 CEMT P COMP Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N1 Spud Date: 5/17/1979 End: Description of Operations Work pipe to get thru tight spot at 12285'. No heavy overpulls on pickups. Finally popped thru. Tagged bottom at 12500'. PU off bottom, back ream shale at 12230'-12285' until it pulls clean up and down. POOH to run liner. LD BHA. RU to run liner. PJSM for running liner. Run 46 joints 2 7/8", 6.16#, STL liner with inline cementralizers Continue to run liner. Run a total of 47 joints of 27/8",6.16#, STL, LSL sub, and 37 joints of 33/16", 6.2#, TCII, X Nipple, Baker deployment sleeve MU Baker CTC. Pull test to 35,000 Ibs and pressure test to 3,500 psi. RIH w/liner. PU=53K, SO=18K. Slight bobble running through cement ramp at 10,298', running through shale at 11,600', OHWS at 11,750',11,865',12,150',12,250'. Work liner in hole from 12,250' to 12535'. Tag bottom 2x at 12543' CTM. (Correction has been running -40 to -45 during drilling of well) This depth is consistent with previous runs. Liner is on bottom at 12500 ELM depth. PU wt is 56 klbs. Drop 5/8" ball to release liner from CTLRT. Chase ball with mud. Coil vol=59.3 bbls. Ball on seat at 50.7. Good indication of ball shear. PU at 31 klbs. Confirmed released from liner. Circulate the well to KCL. Final circulation rate with KCL in well 2.95/2.65/2930 psi. Returns = 89%. Hold PJSM with SWS, cementers, Nordic, Veco, Baker prior to mixing and pumping cement. Continue to pump KCL at minimum rate while mixing cement and biozan in pill pit. 1.0/0.7/300 psi. Cement up to weight at 10:20 AM. SI rig pumps. Line up to cementers. Pump 5 bbls water to warm lines. SI, PT cement lines to 4000 psi, ok. Come on line with cement. Staging off of rig MM, confirming with SWS cementers tub and MM. Pump 30 bbls of Class G cement, additives as per proceedure. (27 bbls calc cement vol to 10090', +10% excess for losses). SD, launch dart. Follow with 30 bbls biozan with rig pumps. Continued to have 10% losses while displacing dart. Displaced first 13.4 bbls of cement out the float shoe and had 7.4 bbls of returns for 55% return rate. At 13.4 bbls away, had 100% losses. It looked like we packed off around the liner and returns went to 0, coil pressure built up to 4100 psi. Continued displacing cement trying different rates and surging pumps to reestablish returns with no success. Dart landed on liner wiper plug and sheared correctly. Liner wiper plug landed on schedule. Bumped plug, floats held. Estimated cement top behind pipe is at 11560', assuming 40% excess in open hole. CIP @ 11:25. Printed: 10/27/2003 11 :37:45 AM ~ . Page 14 of 20 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-14 07-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date. . From - To Hours Task Code NPT Phase ...------..-- ______..n..¥" . . .. - ..._. 'n.. 10/15/2003 11 :25 - 12:40 1.25 CEMT P COMP 12:40-13:10 0.50 CEMT P COMP 13:10 - 14:15 1.08 EVAL P COMP 14:15 - 14:30 0.25 EVAL COMP 14:30 - 16:45 2.25 EVAL P COMP 16:45 - 18:10 1.42 EVAL P COMP 18:10 - 20:45 2.58 EVAL P COMP 20:45 - 22:00 1.25 EVAL P COMP 22:00 - 23:00 1.00 EVAL P COMP 23:00 - 23: 15 0.25 EVAL P COMP 23:15 - 23:30 0.25 REMCM-N CEMT COMP 23:30 - 00:00 0.50 REMCM-N CEMT COMP 10/16/2003 00:00 - 00:30 0.50 REMCM-N CEMT COMP 00:30 - 00:45 0.25 REMCM-N CEMT COMP 00:45 - 02:45 2.00 REMCM-N CEMT COMP 02:45 - 03: 15 0.50 REMCM-N CEMT COMP 03:15 - 04:30 1.25 REMCM-N CEMT COMP 04:30 - 05:30 1.00 REMCM-N CEMT COMP 05:30 - 06:00 0.50 REMCM-N CEMT COMP 06:00 - 06:40 0.67 REMCM-N CEMT COMP 06:40 - 08:20 1.67 REMCM-N CEMT COMP 08:20 - 10:10 1.83 REMCM-N CEMT COMP 10:10 - 10:50 0.67 REMCM-N CEMT COMP 10:50 -13:30 2.67 REMCM-N CEMT COMP Start: Rig Release: Rig Number: Spud Date: 5/17/1979 End: 9/26/2003 10/21/2003 N1 DescriptiÓn of Operations ...---..----- ...-. ---.--... POH with CTLRT, laying in biozan to replace pipe voidage. Tag up at surface, stand back injector, lay down Baker CTLRT. All recovered ok. PU SWS memory CNL-GR-CCL logging eq to rig floor. Safety meeting prior to picking up SWS memory tools. Clear rig floor. Stab SWS tool and install radioactive source. Fill hole. Took 2 bbls to fill. It appears to be taking fluid. Make up 88 joints of 1-1/4" CS hydril work string. Drifting each joint as it is picked up. Stop half way thru to fill hole. It took 2 more bbls to fill, despite the pipe displacement. The hole is definately taking fluid. Possibly into old loss zone at 10680'. Stab on injector, RIH with SWS MCNL logging tools on CSH and coil tubing. Make down logging pass at 60 fpm, pumping 1.5 bpm to clean bio out of liner. Log from 9500' CTM to TO. Log up from PBTD to 9,500' at 30 fpm. POOH with logging tools to CSH. PJSM. Stand backCS Hydril. LD logging tools. PJSM for PU perf gun. PU 10' 2", 6spf, 60 deg, PJ2006 HMX perf gun. RIH w/ CSH from derrick. RIH wI 25 stands of CSH. PU injector. RIH wI perf gun. Place gun on depth. Drop 5/8" ball and circulate 0[1 seat. No losses. Pressure up to 3,000 psi to fire gun. Perferate from 11,335' - 11,345' with 2", 6spf, 60 deg, HMX guns. POOH to CSH. Stand back injector. RU elevators. Stand back 25 stands of CSH. PJSM. LD perf gun. Crew change, and Safety meeting about plan forward for this tour, and making up cementing BHA. MU cement BHA, C/O packoffs. RIH with Baker cement stinger BHA. Pit vol = 180 bbls, IAP=42 psi, OAP=50 psi. Stop at 9800', Make weight check up at 36 klbs. Set pumps to minimum rate, stab into deployment sleeve. Tag up at 9849', expected top of liner at 9848', we are on depth. We got good indication of pump pressure building, and returns went to zero, indicating seals are holding and confirming that we are stabbed in. Pressure up to shear ball seat and establish circulation. Seat is pinned for 2400 psi. Good indication of shear. We now have circulation after the ball seat shears. Circulation is presumed to be down the coil, down the liner, thru the liner perfs, and up the back side. Getting reasonable returns. Pumping 0.94/0.90/200 psi. Still have losses of about 5%. Call for cementers, and mud balance pill. Notify town of results. Standby on cementers. Standing by, waiting on cementers. Pit vol=213 bbls, IAP=45 psi, OAP=55 psi. Continuing to circulate at 1 bbl/min with 10% losses. Printed: 10/27/2003 11:37:45AM . . Page 15 of 20 BP EXPLORATION Operation~Summary Report .... Legal Well Name: 07-14 Common Well Name: 07-14 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To Höürs,J Task Code , "'1' ...... ..._. ._.On _.".______0_..__0____._. 10/16/2003 13:30 - 14:30 1.00 REMCM-N 14:30 - 15:15 0.75 REMCM-N 15:15 - 15:30 15:30 - 16:00 16:00 - 17:00 0.25 REMCM-N 0.50 REMCM-N 1.00 REMCM-N NPT Phase CEMT COMP CEMT COMP CEMT COMP CEMT COMP CEMT COMP 17:00 - 18:30 1.50 REMCM-N CEMT COMP 18:30 - 19:00 0.50 REMCM-N CEMT COMP 19:00 - 00:00 5.00 BOPSURP COMP 10/17/2003 00:00 - 04:30 4.50 BOPSUR P COMP 04:30 - 05:45 1.25 CLEAN N CEMT COMP 05:45 - 06:00 0.25 CLEAN N CEMT COMP 06:00 - 07:10 1.17 CLEAN N CEMT COMP 07:10 - 08:10 1.00 CLEAN N CEMT COMP Start: Rig Release: Rig Number: Spud Date: 5/17/1979 End: 9/26/2003 10/21/2003 N1 Description of Operations Cementers on location. Waiting on dirty vac truck for cementers clean up. Ordered truck at 10:30, we have been waiting 3 hours. Vac with KCL on location. Top pits of with KCI, turn this truck around and make it a dirty vac when finished. Safety meeting prior to pumping cement. Wait while cementers batch up. Cement up to weight at 15:50. Final circulation with KCL 0.98/0.94/220 psi. SI rig pumps, on line with cementers. Pump 5 bbls water to warm lines. PT cementers hard lines to 4400 psi. No leaks. On line with class G cement at 15.8 ppg, same additives as use on the initial liner job, as per proceedure. Pump 25 bbls at 2 bbls/min. Initial cir rate 1.95/1.8/885 psi. Final circ rate while pumping cement 2.02/2.0/1659 psi. Shut down after 25 bbls, SI standing iron, suck back cementers line with the vac truck while using 15.8 ppg mud to clean lines. Line up to coil, pump 15.8 ppg barite/flopro gel mud. 0 spacer between cement and mud. Pump 10 bbls mud. Mud measured 15.9 on rig MM meter. Pumped mud at 2.04/1.95/1172 psi. Swap to bio, pump 30 bbls of biozan at 8.56 ppg. After 30 bbls, swap to 2% KCL in pits. Displace fluid at 2 bpm until cement at the perfs, and while displacing for first 18 bbls cement thru perfs. Returns were 60%. slowed rate to 1 bpm, and returns improved to 90%. Staged cmUmud so that 1 bbl of cement was left inside liner. Mud to top of liner. Pumped 24 bbls of cement thru perfs. Left 1 bbl inside liner. Lost 6 bbls to formation, got 19 bbls behind pipe. Estimated top of cement behind pipe is at 9985'. CIP @ 16:50. POOH with cementing BHA. String in biozan replacing coil void age only. Tag up at surface. Stand back injector. Lay down Baker tools. RU to test BOPE. Test BOPE to 250 I 3,500 psi as per AOGCC regulations and BP policy. Test witnessed by John Crisp of AOGCC. Failed HCR test. Replace packing in HCR stem. Continue to test BOPE. Call out grease crew to grease master and wing valves. RD BOP testing equipment. PJSM for MU motor and running CSH. MU Baker Xtreme motor with 2.3" parabolic mill. Run 44 stands of CSH from derrick. RD elevators. PU injector. RIH. Pit level 278 bbls, IAP=40 psi, OAP=50 psi. Getting 1 for 1 returns while RIH. Cement compressive strength on squeeze cement is 2100 psi at 06:30. 9500' check up weight at 9500'= 31klbs. RIH, tag up at 9571' on GLM 9. Worked through it. Tagged up again at 9658', GLM #10. Tagged up several times, making footage each time. Looks like some cement or barite that we are on. Kick on the pumps, and mill down thru it at 96 fph. 9701', able to mill ahead at 300 fph. Pump 10 bbl biozan sweep. 9717', ROP slowed down to 175 fph. Printed: 10/27/2003 11:37:45AM ~ . BP EXPLORATION Operations::'Sumrrfary Repprt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -14 07-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 .. I Date From - To Hours Task Code i NPT Phase -......-..-... ----- 10/17/2003 08:10 - 08:30 0.33 CLEAN N CEMT COMP 08:30 - 09:20 0.83 CLEAN N CEMT COMP 09:20 -10:15 0.92 CLEAN N CEMT COMP 10:15-10:50 0.58 CLEAN N CEMT COMP 10:50 - 12:00 1.17 CLEAN N CEMT COMP 12:00 - 12:20 0.33 CLEAN N CEMT COMP 12:20 - 14:00 1.67 CLEAN N CEMT COMP 14:00 - 14:30 0.50 CLEAN N CEMT COMP 14:30 - 14:45 0.25 CLEAN N CEMT COMP 14:45 -15:35 0.83 CLEAN N CEMT COMP 15:35 - 16:10 0.58 CLEAN N CEMT COMP 16:10 - 16:35 0.42 CLEAN N CEMT COMP 16:35 - 17:00 0.42 CLEAN N CEMT COMP 17:00 - 17:10 0.17 CLEAN N CEMT COMP 17:10-17:40 0.50 CLEAN N CEMT COMP 17:40 - 17:55 0.25 CLEAN N CEMT COMP 17:55 - 21 :20 3.42 CLEAN N CEMT COMP 21:20-23:15 1.92 CLEAN N CEMT COMP 23: 15 - 23:45 0.50 CLEAN N CEMT COMP 23:45 - 00:00 0.25 CLEAN N CEMT COMP 10/18/2003 00:00 - 01 :00 1.00 CLEAN N CEMT COMP 01:00 - 01:15 0.25 CLEAN N CEMT COMP 01: 15 - 02:40 1.42 CLEAN N CEMT COMP 02:40 - 04:20 1.67 CLEAN N CEMT COMP 04:20 - 05: 1 0 0.83 CASE P COMP Page 16 of 20 Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N1 Spud Date: 5/17/1979 End: Description of Operations ---...--.--.. 9795', Need to gel up system to carry cuttings better. Pump the remaining 20 bbls of 2# biozan. Add 6 buckets of flo-vis L to pit 3, pump 100 bbls of that. 9794', tag up hard. Possibly on PBR. 9794', Check returns. PH confirms that we were on cement at the start of milling at 9701'. The volume calculates to be 3.1 bbls cement on top of liner. To avoid leaving a large cement donut in the hole, the plan is to POOH, pick up a 3.80" mill, and mill to the top of the liner. Then run the 2.125' motor and 2.3" mill to clean out inside the liner. Tag up at surface, stand back the injector, hold PJSM to discuss pulling CS hydril work string. Trip CS hydril work string OOH. Lay down 2.125" X-treme motor and mill. MU BHA #21,2.875" X-treme mud motor and 3.80" D331 DSM. RIH with BHA #21 to clean cement out of 4-112" and 5-1/2" tubing. 9500', weight check=38klbs. Kick on pumps, free spin=1700 psi at 2.6 bpm. RIH, had a little weight bobble at 9562', able to RIH at 450 fph with no motor work. Started getting light motor work at 9600', but able to mill down at 150 fph. Milling with 2#/bbl biozan. 9650', Clean PU. Free spin 1760 @ 2.65 bpm. Resume milling at lightning speed, 190 fph. Probably on contaminated cement. Milling at 2.7/2.7/1850 psi, getting 1 for 1 returns. 9671', The cement is a bit harder, ROP=50 fph for 5', then back up to 150 fph. 9740', ROP down to 70 fph. 2.5/2.5/1820 psi. 9785', ROP down to 30 fph. 2.5/2.5/1908 psi. This is the typical ROP we get with this mill in hard well consolidated cement. This does not look like contaminated cement. 9792', Stall, pickup clean at 38 klbs. Resume milling hard cement. 2.6/2.6/2200 psi. 9795', ROP picking up. Now 75 fph. 2.55/2.55/2100 psi. 9807', 116 fph. 9808', Weight check pickup clean at 37 klbs. Resume milling. 9808.5', Slow ROP. Probably at 5-1/2 x 4-1/2" crossover, and are on low side of the pipe, side loading the mill. Work it slow. 9809', ROP picking up. We are off the crossover, and back on cement. 30 fph. Drilling at 2.6/2.6/2100 psi. Mill cement to top of liner. Tag liner top on depth. POOH. Stand back injector. LD BHA. RU to run CSH. PJSM for running CSH. TIH wI 44 stands of CSH. RD elevators. PU injector. RIH. Correct to 6,800 EOP flag. -33' correction. PU=36K, SO=14K. Tag cement at 9,852' (liner top). Mill at 1.45/1.45/2,882 psi. Off bottom pressure 2,750 psi. Mill cement to 9,878' at 30 fph. Torqued up at 9,878' then broke through. Wash down to 9,900'. Pull up to 9,544'. Pressure test liner to 2,000 psi for 30 minutes. Good test. Printed: 10/27/2003 11 :37:45 AM . . BP 'tXPlORA TION .. . OperationsSur;nmary Report . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-14 07 -14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT . Phase 10/18/2003 05:10 - 06:00 0.83 CLEAN N CEMT COMP 06:00 - 06:25 0.42 CLEAN N CEMT COMP 06:25 - 07:30 1.08 CLEAN N CEMT COMP 07:30 - 07:45 0.25 CLEAN N CEMT COMP 07:45 - 08:30 0.75 CLEAN N CEMT COMP 08:30 - 08:50 0.33 CLEAN N CEMT COMP 08:50 - 10:00 1.17 CLEAN N CEMT COMP 10:00 - 12:45 2.75 CLEAN N CEMT COMP 12:45-13:10 0.42 CLEAN N CEMT COMP 13:10 - 14:50 1.67 CLEAN N CEMT COMP 14:50 - 16:45 1.92 CLEAN N CEMT COMP 16:45 - 17:50 1.08 CLEAN N CEMT COMP 17:50 - 20:35 2.75 CLEAN N CEMT COMP 20:35 - 22:30 1.92 CLEAN N CEMT COMP 22:30 - 23:30 1.00 CLEAN N CEMT COMP 23:30 - 00:00 0.50 CLEAN N CEMT COMP 10/19/2003 00:00 - 00:35 0.58 CLEAN N CEMT COMP 00:35 - 00:45 0.17 CLEAN N CEMT COMP 00:45 - 03:30 2.75 CLEAN N CEMT COMP 03:30 - 04:30 1.00 CLEAN N CEMT COMP Page 17 of20 Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N1 Spud Date: 5/17/1979 End: Description of Operations RIH to 9,900'. Clean out liner at 1.37/1.37/2,714 psi, 50 fph. 9950', Washing thru 15.8 ppg mud. RIH at 120 fph. Free spin=2750 psi at 1.35 bpm. Milling at 1.37/1.4/3000 psi. Pit vol=284 bbls. 9968', Stall, clean PU, resume milling. Looks like hard stringer, popped right thru, continue milling. 10013', Wiper trip up to 9900', clean. Drilling surprisingly hard dessicated mud, with the occasional cement stringer. We will catch the next bottoms up sample to confirm. Resume milling. Assuming this is barite, we should be able to mill at a faster ROP than we are currently able to make. 10023', Down on some hard material. Milling at 20 fph. This is some hard stuff. pH of the bottoms up from 9960 shows PH of 11 +. Th is may be cement. 10024', POOH. ROP is too slow. It will take us 2 days to clean out at this rate. POOH for a different BHA. Plan is to change the mill to something more aggressive. Clean PU and pull in 2.3" hole. Tag up at surface. Stand back injector. Drop 5/8" ball to open circ sub to pull dry. Hold PJSM. Stand back 44 stands of 1-1/4" CS hydril. Safety meeting prior to running next BHA back in the hole, Trip back in the hole with 2.7" mill, 2.125" motor, jars on CS hydril. PU SWS MHA. PT MHA to 4500 psi, all was ok. PT CTC, pass ok. MU to CSH, Stab injector, RIH. 9800', weight check at 33 klbs. Make a -29' correction at flag from last run. Kick on pumps. Free spin 1.4 bpm, 2840 psi. RIH past liner top at 300 fph looking to tag cement sheath left from last run (2.7" mill vs 2.3" mill). Didn't see anything! Went past the 10024' spot that we had stopped at on the previous run w/o seeing anything. There should have been a cement sheath all the way down from the top of the liner. We did not see any motor work at all. Continue RIH at 200 fph, with no motor work past 10050'. 10139', starting to get some motor work. About 100 Ibs when RIH at 250 fph, went thru it pretty quick. Back to RIH at free spin at 400 fph. Stall at 10,930'. RIH to LSL sub. Tag twice and correct depth. -13' correction. POOH. Flag pipe at 6,800' EOP. Stand back CSH. Inspect BHA. No wear on 2.7" mill. Change mill to 2.3" drag mill. RIH w/ CSH. Continue TIH wI CSH. Run 44 stands. Remove elevators. PU Injector. RIH. Correct depth to 6,800 EOP. -29.4' correction. RIH to 10,926'. PU=39.4K, SO=14.5K. 1.4/1.4/3,150 psi. Tag up on LSL sub at 11,021 '. PU=40K. Try to get through three times with pump on. No luck. Shut off pump and set down on LSL sub. Bring on pump and got through. Inside 2 7/8" liner PU=39K, SO=14K 1.43/1.43 3,260 psi. RIH to 11,320'. Start getting motor work at 11,320'. Stalled at 11,335' (perf holes from 11,335' - 11,345'). Mill at 1.42/1.42 I 3,370psi, 25 Printed: 10/27/2003 11 :37:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ . BP EXPLORATION Operation's SUmm,EU!)' Report 1.00 CLEAN N 1.50 CLEAN N CEMT COMP CEMT COMP 07-14 07-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Page ,18 of 40 Start: Rig Release: Rig Number: Spud Date: 5/17/1979 End: 9/26/2003 10/21/2003 N1 From - To Hours Task Code NPT Phase 10/19/2003 03:30 - 04:30 04:30 - 06:00 06:00 - 06:35 06:35 - 06:50 06:50 - 07:15 07:15-10:35 0.58 CLEAN N CEMT COMP 0.25 CLEAN N CEMT COMP 0.42 CLEAN N CEMT COMP 3.33 CLEAN N CEMT COMP 10:35 -13:00 2.42 CLEAN N CEMT COMP 13:00 - 13:30 0.50 CLEAN N CEMT COMP 13:30 - 15:00 1.50 PERF P COMP 15:00 -15:30 0.50 PERF P COMP 15:30 - 18:45 3.25 PERF P COMP 18:45 - 19:30 0.75 PERF P COMP 19:30 - 21:30 2.00 PERF P COMP 21:30-22:15 0.75 PERF P COMP Description of Operations fph, down to 11,363'. Continue RIH. At 1,2250' Start pumping perf pill and chase with clean 2% KCI. Tagged bottom. Picked up, try to tag again, can't go down. PU 20', can't go down. PU 20' more can't go down. Got bit stuck. PU, can't get free. Jar up 1 lick at 8000# over, popped free. PUH to above LSL sub to flush any debris up hole. 11000', run back in hole. Hung up 3 times at LSL sub, finally popped thru. RIH pumping maximum rate of 1.5 bpm. Perf pill now used as a sweep. RIH, no motor work. Set down at 12438', PU 65 klbs, popped free. Kicked on pumps, work down hole easy at maximum rate from 12420'. Work debris down hole, trying to push it to bottom, or flush it up hole. Possibly perf debris left from the sqz perfs, or cement chunks pushed down hole. Pushed it down to 12430', set down, pulled free at 65klbs, continue pushing to bottom. Based on weight character SWS operator thinks we are pushing something in front of us. Run in pumps on to 12465', SD pumps. Dry tag at 12471', PU clean. PU, pumping full rate with KCL. Swap to perf pill #2. Yo-Yo pipe unitl sweep to bit. PUH laying in perf pill. Stop at 10990', Drop 1/2" ball to open circ sub. Continue POH. 1 for 1 returns through out the clean out and trip OOH. Liner lap and sqz perfs are holding good. Increase rate to 2 bpm once ball on seat at 9300' while POH. Tag up at surface, stand back injector. Hold tool box talk about plan forward. Lay down 1 single. Stand back 20 stands, lay out the remaining 43 joints. Rig down milling BHA. Lay down Baker Milling BHA. All recovered ok, with no obvious marks on side of BHA to indicate what was hanging us up in the hole. 1/2" circ ball recovered in circ sub. Bring SWS perf guns into pipe shed and layout. Make up safety joint. Hold PJSM with SWS perforators prior to picking up perf guns. Pick up SWS perf guns. Perforation intervals as per final perf memo of 10-17. TIH w/ 20 stands of CSH. RD elevators. PU injector. RIH wI perf guns. -32' correction at 6,800' EOP flag. -7' correction at 9,600' EOP flag. Tag PBTD. Correct depth to 12,467'. PU=53K, SO=16K. Retag. Pump 7 bbls perf pill. Drop 5/8" ball to fire perf guns. Pump ball down 2.6 bpm, 3,200 psi. Slow pump rate to .86 bpm, 450 psi at 44 bbs pumped. Ball on seat. Start moving pipe at 1.5 fpm. After pipe started moving, pressure up to 3,100 psi to fire guns. Guns fired. Increase PU rate and pulled to 78K. Guns are stuck! Perforation depths wI SWS 2" guns, 4 spf: 10,950' - 11,400' 11,445' - 11,480' 11,640' - 11,825' 11,890' - 12,140' Printed: 10/27/2003 11:37:45 AM ~ : ~::. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I Date I From - To ... ..._---_...~.... 10/19/2003 21 :30 - 22: 15 22:15 - 23:00 ~ . BP EXPLO~1fJON Operations'Sumniary Report 07 -14 07-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours' Task Code NPT Phasè 0.75 PERF P 0.75 PERF N COMP STUC COMP 23:00 - 00:00 1.00 PERF N STUC COMP 1 0/20/2003 00:00 - 01 :30 1.50 PERF N STUC COMP 01 :30 - 02:00 0.50 PERF N STUC COMP 02:00 - 04:30 2.50 PERF N STUC COMP 04:30 - 06:00 1.50 PERF N STUC COMP 06:00 - 06:30 0.50 PERF N STUC COMP 06:30 - 07:15 0.75 PERF N STUC COMP 07: 15 - 07:45 0.50 PERF N STUC COMP 07:45 - 08:05 0.33 PERF N STUC COMP 08:05 - 09:15 1.17 PERF N STUC COMP 09:15 -10:45 1.50 PERF N STUC COMP 10:45 -11:15 11:15-12:30 12:30 - 12:50 12:50 - 13:50 0.50 PERF N STUC COMP 1.25 FISH N STUC COMP 0.33 FISH N STUC COMP 1.00 FISH N STUC COMP 13:50 - 14:05 0.25 FISH N STUC COMP 14:05 - 14:20 0.25 FISH N STUC COMP 14:20 - 14:36 0.27 FISH N STUC COMP Start: 9/26/2003 Rig Release: 10/21/2003 Rig Number: N1 Page 19 of20 Spud Date: 5/17/1979 End: Description of Operations ..--.-.--.----.--..- 12,295' - 12,465' Able to circulate down coil. 1 for 1 returns. Work pipe up to 78K several times. No pipe movement. Line up to pump down kill line. Pump.5 bpm /1,000 psi. Work pipe. Increase rate to 1.5 bpm, 1,985 psi. Work pipe. Circulate down coil and wait on crude. Pump 10 bbls of crude down coil. Circulate crude to firing head. SI returns. Bull head cude. Work pipe. Pump 3/4" ball for Baker disconnect, 2.64/2.64 I 3,420 psi. Pressure up to 4,300 psi and disconnect. Left Firing head and perf guns in hole. POOH. Stand back CSH. PU fishing tools. Shut down for crew change. MU remaining stands of CS Hydril. Discuss plan forward with town. Safety meeting with rig crew about plan forward. MU upper BHA, new coil tubing connector. Pull test to 35 klbs, PT to 3500 psi. Stab on injector. RIH with fishing BHA. Stop at 1000', to shallow hole test tools. Kick on pumps. At 1 bpm got first indication of vibration from andergage tool. At 2 bpm the vibration was significant at surface. Reduce rate to minimum, start high vis flo-pro sweep down hole, continue RIH. Make -35' correction at 6800' EOP flag. RIH down thru top of cement sheath and liner pumping high LSRV Flo-pro to clean out any debris. Weight check at 10800'=49klbs. Consistent to what they saw with perf guns. Reduce pumps to 1 bpm. Wash into fish. Tagged up at 10927'. Calculated top offish was 10924'. SI pumps, PU, popped out of fishing neck. Set down dry, popped out again. Set down a third time, and latched in, which was confirmed by pulling 5k over on PU. Commence down jarring with 6500# down weight at surface. Down jar for numerous licks for over 1 hour. No indication of fish movement. Kick on pumps, agitate with down weight trying to move fish down. Pumping 1.8 bpm, getting good rocking action on weight cell. Slowly varying the pump rate to change the frequency of the vibration down hole. No indication of fish movement. SD pumps, PU 5000 Ibs over, at 60 klbs string weight. Let jars go off, kick on the pumps to restart agitator in the up direction. Agitated for 5 minutes, then the GS released. RIH and latch back up. Pull up to 10klbs over at 65 klbs. Kick on pumps. Agitate in the up direction. Seem to get the best indication of surface vibration at 2700 psi pump pressure at 1.6 bpm. Keep pumps on and agitator running. Pull up to 70klbs, 15 klbs over up weight with gun string. Still getting good vibrations at surface. Pull up to 76 klbs. 20 klbs over up weight with gun string. May have moved it a couple of feet. Difficult to say. Hold and agitate at this weight. Pull up to 80 klbs, pumping with the agitator at 1.6 bpm. Printed, 10/27/2003 11:37:45AM - . Page 20 of:20 BP -EXPLORATION Operatio'ns Summary'R~pºrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -14 07 -14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date Task! Code NPT i From - To Hours 10/20/2003 14:36 - 14:56 0.33 FISH N 14:56 - 15:25 0.48 FISH N 15:25 - 17:00 1.58 FISH P 17:00 - 17:15 0.25 FISH P 17:15 - 17:30 0.25 FISH P 17:30 - 18:00 0.50 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 19:15 0.75 FISH N 19:15 - 00:00 4.75 FISH P 10/21/2003 00:00 - 00:30 0.50 FISH P 00:30 - 01 :00 0.50 FISH P 01 :00 - 02:30 1.50 FISH P 02:30 - 03:45 1.25 WHSUR P 03:45 - 04:20 0.58 RIGD P 04:20 - 04:30 0.17 RIGD P 04:30 - 06:00 1.50 RIGD P 06:00 - 08:15 2.25 RIGD P 08: 15 - 09:30 1.25 RIGD P 09:30 - 10:00 0.50 RIGD N ¡ Phase ' STUC COMP STUC COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP POST POST POST POST POST RREP POST Start: Rig Release: Rig Number: Spud Date: 5/17/1979 End: 9/26/2003 10/21/2003 N1 Description of Operations .........- ..-.....---...... Pull up to 90 klbs. Held for 15 minutes while pumping/agitating. SD pumps, RIH try to get a jar lick down, didn't get one. Also, we are 17' shallower now than when we were stacked out and jarring down earlier today. May have moved it up 17'! Pull back up for an attempted jar lick, pulled 17 Ibs over string weight may have gotten 1 jar lick, and pulled fish free. Pulling up at 60+ klbs, ratty heavy pulls. After 300', tension gradually cleaned up, and pulled smoother at 52 klbs. This is very close to the pickup weight prior to perforating. POOH, We probably have the fish. POOH to see if it is there! Tag up at surface. String weight is 5000# heavier than RIH. Good indication of fish. Stand back injector. Safety meeting with rig crews and SWS to discuss safety in standing back CSH and laying down perf guns. Stand back CSH. PJSM for LD fishing tools and LD perf guns. LD fishing tools. RU to LD perf guns. LD perf guns. Continue to LD perf guns. All guns recovered. No debris or abnormal guns observed. RD handling tools. Clear floor. Run CSH in hole from derrick. POOH sideways. PU injector. RIH to 2,266' to freeze protect well. Lay in MeOH at 60%. Stop at 350' and cap off well with 100% MeOH. Clean pits. RU to blow down reel with Nitrogen. PJSM for blowing down reel. Pressure test lines to 3,500 psi. Slow down reel with Nitrogen. Take return through choke to tiger tank. Unstab coil, secure to rig floor. Stab injector into stabbing box. Nipple down the SOP stack, NU tree cap. PT TC to 3500 psi. Work to get a motor on line so we can move ahead a few feet to install the tree cap. Rig Released at 10:00. Further entries will be on S-102 DIMS reports. Printed: 10/2712003 11:37:45AM e e 8C¡3-/1/~ 22-0ct-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 7-14 B Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,724.24' MD 11,750.00' MD 12,500.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) :>"'~ ~.!'M ·i"~'ò L f \.J ì.:: r'~ !(p,;f ~c""~. .~ m- ~ 1_ ¡¡".¿' '~ \. -i',~~:w, ¥' --~ ~ --' ('\ f" 'r t~¡ '...j Iv \ t.. ;.:·c:'1m¡5.~on l\!1Chorti!gt1 ~.'.( -' ~"~~\'í,\¡~ ¿ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 07 07-14 - 7-14B Job No. AKMW0002699461, Surveyed: 14 October, 2003 Survey Report 20 October, 2003 Your Ref: API 500292033902 Surface Coordinates: 5950406.37 N, 675869.48 E (70016' 12.4337" N, 148034' 39.4116" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 950406.37 N, 175869.48 E (Grid) Surface Coordinates relative to Structure Reference: 2297.00 N, 1460.59 W (True) Kelly Bushing: 64.00ft above Mean Sea Level Elevation relative to Project V Reference: 64.00ft Elevation relative to Structure Reference: 64.00ft SP'E!ï'ï'Y-SU:f1 bAIL.L.ING seAvn::es A Halliburton Company DEF'NiTiV . . Survey Ref: svy4113 '" Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 07 - 07-14 - 7-14B Your Ref: API 500292033902 Job No. AKMW0002699461, Surveyed: 14 October,. 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11724.24 88.550 162.670 8907.71 8971.71 3699.94 N 1614.12 E 5954143.01 N 677396.70 E 4003.25 Tie On Point 11750.00 89.240 166.250 8908.21 8972.21 3675.13 N 1621.01 E 5954118.37 N 677404.18 E 14.151 3985.52 Window Point 11777.81 87.930 157,380 8908.89 8972.89 3648.74 N 1629.68 E 5954092.20 N 677413.46 E 32.231 3967.35 11811.06 85.810 156.850 8910.71 8974.71 3618.16 N 1642.59 E 5954061.92 N 677427.08 E 6.572 3947.76 11843.01 86.170 160.200 8912.94 8976.94 3588.50 N 1654.26 E 5954032.55 N 677439.44 E 10.520 3928.33 . 11882.03 89.600 162.670 8914.38 8978.38 3551.55 N 1666.67 E 5953995,89 N 677452.71 E 10.829 3903.01 11923.42 91.810 164.960 8913,88 8977.88 3511.80 N 1678.20 E 5953956.43 N 677465.17 E 7.688 3874.86 11964.24 91.920 170.610 8912.55 8976.55 3471.95 N 1686.83 E 5953916,78 N 677474.72 E 13,837 3845.12 11999.22 92.690 172.540 8911.14 8975.14 3437.37 N 1691.95 E 5953882.34 N 677480.65 E 5.936 3818.10 12037.23 92.690 172.540 8909.35 8973.35 3399.73 N 1696.88 E 5953844.82 N 677486.46 E 0.000 3788.35 12084.34 89.510 180,110 8908.45 8972.45 3352.76 N 1699,90 E 5953797.94 N 677490,57 E 17.424 3749.62 12116.71 90.660 181.520 8908.40 8972.40 3320.40 N 1699.44 E 5953765.57 N 677490.87 E 5.621 3721.63 12144.88 90.900 183.460 8908.02 8972.02 3292.26 N 1698.21 E 5953737.41 N 677490.30 E 6.939 3696.87 12178.91 88.550 180.470 8908.18 8972.18 3258.25 N 1697,05 E 5953703.39 N 677489.93 E 11.175 3667.11 12207.86 89.430 178.000 8908.69 8972.69 3229.31 N 1697.43 E 5953674.46 N 677490.99 E 9.056 3642.48 12238.20 92.250 177,570 8908,25 8972,25 3199.00N 1698.61 E 5953644.19 N 677492.87 E 9.402 3617,09 12274,32 94.270 173.590 8906.19 8970.19 3163.06 N 1701.38 E 5953608.32 N 677496.49 E 12.340 3587.69 12308.46 93.300 166.900 8903.94 8967.94 3129.50 N 1707.15 E 5953574.91 N 677503.04 E 19.758 3561.89 12341.58 89.910 166.070 8903,01 8967,01 3097,32 N 1714.89 E 5953542.91 N 677511.53 E 10.538 3538.26 12368.89 86,780 164.890 8903.80 8967.80 3070.90 N 1721.73 E 5953516.66 N 677518,99 E 12.248 3519.12 12419.17 85.700 162.140 8907.09 8971.09 3022.79 N 1735,97 E 5953468.90 N 677534.34 E 5.865 3485.19 . 12456.62 85.020 154.040 8910.13 8974.13 2988.19 N 1749.88 E 5953434.63 N 677549.06 E 21.634 3462.67 12500.00 85.020 154.040 8913.89 8977.89 2949.33 N 1768.80 E 5953396.23 N 677568.88 E 0.000 3439.07 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 30.950° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12500.00ft., The Bottom Hole Displacement is 3439.07ft., in the Direction of 30.952° (True). 20 October, 2003 - 10:43 Page 2 of 3 Dri/lQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 07 - 07-14 - 7-14B Your Ref: API 500292033902 Job No. AKMW0002699461, Surveyed: 14 October, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastin9s (ft) (ft) (ft) Comment 11724.24 11750.00 12500.00 8971.71 8972.21 8977.89 3699.94 N 3675.13N 2949.33 N 1614.12 E 1621.01 E 1768.80 E Tie On Point Window Point Projected Survey . Survey tool program for 07-14 - 7-148 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10352.00 0.00 10352.00 8566.23 12500.00 8566.23 BP High Accuracy Gyro - AK-1 BP _HG (07-14) 8977.89 MWD Magnetic (7-14BPB1) . 20 October, 2003 - 10:43 Page 3 of 3 DrillQuest 3.03.02.005 e e f)ð3-)4~ 22-0ct-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 7-14 B PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,352.00' MD 10,352.00' MD 12,400.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager n n"""~ ~ \J!iP=~. 11 > J b.U AUachment(s) 01"'''- ,.., ...." 't~ ¡ ¿ / t;fJmmis/!ion ~~"\) ',\",. ~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 07 07-14 - 7-14BPB1 Job No. AKMW0002699461, Surveyed: 11 October, 2003 Survey Report 20 October, 2003 Your Ref: API 500292033970 Surface Coordinates: 5950406.37 N, 675869.48 E (70016'12.4337" N, 148034' 39.4116" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 950406.37 N, 175869.48 E (Grid) Surface Coordinates relative to Structure Reference: 2297.00 N, 1460.59 W (True) Kelly Bushing: 64.00ft above Mean Sea Level Elevation relative to Project V Reference: 64.00ft Elevation relative to Structure Reference: 64.00ft SpE!r""r""Y-SUï'! DAta...L.tNG ·SERVtc:es A Halliburton Company DEFINITIVE . . Survey Ref: svy4112 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 07 - 07-14 - 7-14BPB1 Your Ref: API 500292033970 Job No. AKMW0002699461, Surveyed: 11 October, 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) 10352.00 45.000 23.500 8502.23 8566.23 4484.89 N 1355.29 E 5954921.71 N 677119,60 E -3846.58 Tie On Point MWD Magnetic 10383.04 36.920 14.090 8525.68 8589.68 4504.05 N 1361.95E 5954941,02 N 677125.82 E 32.692 -3862.74 10421.73 34.630 358.660 8557.13 8621.13 4526,36 N 1364.53 E 5954963.38 N 677127.87 E 23.999 -3883.16 10450.74 29.660 343.950 8581.72 8645,72 4541.53 N 1362.35 E 5954978.50 N 677125.33 E 31.853 -3898.27 . 10483.55 30.310 312.270 8610,32 8674.32 4554.99 N 1353.92 E 5954991.75 N 677116.60 E 47.831 -3913.67 10513.04 32.160 296.770 8635.57 8699.57 4563.54 N 1341.39 E 5955000.01 N 677103.87 E 27.898 -3925,68 10543.94 32.160 277.910 8661.80 8725.80 4568.39 N 1325.86 E 5955004.49 N 677088.23 E 32.383 -3935.08 10575.60 26.700 280.550 8689.36 8753.36 4570.85 N 1310.51 E 5955006.60 N 677072.83 E 17.722 -3942.17 10609.53 27.140 256.060 8719.71 8783.71 4570.38 N 1295.46 E 5955005.78 N 677057,79 E 32.505 -3946.38 10640.87 31.370 239.670 8747.09 8811.09 4564.53 N 1281.45 E 5954999.60 N 677043.92 E 28.790 -3945.14 10673.44 34.190 221.170 8774.54 8838.54 4553.33 N 1268.07 E 5954988.09 N 677030.81 E 31.833 -3938.62 10708.30 39.820 205.670 8802.43 8866.43 4535.85 N 1256.76 E 5954970,34 N 677019.91 E 31.155 -3925.49 10739.17 44.230 193.510 8825.40 8889.40 4516.43 N 1249.94 E 5954950.77 N 677013.55 E 29.940 -3909.12 10772.06 52.330 183.810 8847.29 8911.29 4492.21 N 1246.39 E 5954926.48 N 677010.56 E 32.983 -3887.19 10803,71 62.110 178.000 8864.42 8928.42 4465.65 N 1246.04 E 5954899.92 N 677010.84 E 34.521 -3862.04 10834.20 68.370 184.520 8877.19 8941.19 4438.01 N 1245.40 E 5954872.27 N 677010.84 E 28.247 -3835.95 1 0867.28 75.240 195.440 8887.55 8951.55 4407.14 N 1239.90 E 5954841.28 N 677006.07 E 37.589 -3808.29 10897.01 83.440 202.670 8893.05 8957.05 4379.58 N 1230.36 E 5954813.50 N 676997.17 E 36.480 -3785.03 10933.70 88.720 194.740 8895,56 8959.56 4344.95 N 1218.64E 5954778.60 N 676986.26 E 25.918 -3755.71 10968.39 90.960 185.770 8895.66 8959.66 4310.85 N 1212.47 E 5954744.37 N 676980.89 E 26.650 -3725.18 10996.02 90.620 175.850 8895,27 8959.27 4283.26 N 1212.08 E 5954716.78 N 676981,15 E 35.921 -3699.07 . 11031.86 86.580 168.580 8896.15 8960,15 4247.79 N 1216.93E 5954681.43 N 676986.82 E 23.197 -3663.84 11069,77 86.700 160.910 8898.38 8962.38 4211.30 N 1226.88 E 5954645,19 N 676997.62 E 20.200 -3626.06 11099.53 91.890 155.270 8898.74 8962.74 4183,72 N 1237.97 E 5954617.87 N 677009.36 E 25.749 -3596.40 11133.89 89.780 152.270 8898.24 8962.24 4152,90 N 1253.16 E 5954587.42 N 677025.26 E 10.673 -3562.40 11158.91 87.750 146.810 8898.78 8962.78 4131,35 N 1265.83 E 5954566.17 N 677038.43 E 23.276 -3537.99 11190.22 86.340 143.290 8900.40 8964.40 4105.73 N 1283.74 E 5954540,97 N 677056.93 E 12.097 -3508.08 11223.91 89.690 140.820 8901.56 8965.56 4079.18 N 1304.44 E 5954514,92 N 677078.25 E 12.351 -3476.44 11257.38 88.280 135.180 8902.16 8966.16 4054.32 N 1326.82 E 5954490,59 N 677101.20 E 17.367 -3445.88 11286.19 87.220 133.070 8903.29 8967.29 4034.28 N 1347.48 E 5954471.03 N 677122.33 E 8.191 -3420.43 20 October, 2003 - 10:37 Page 2 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services , Survey Report for PBU_EOA DS 07 - 07-14 -7-14BPB1 Your Ref: API 500292033970 Job No. AKMW0002699461, Surveyed: 11 October, 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) 11325.21 85.900 128.480 8905.63 8969.63 4008,85 N 1376.97 E 5954446.30 N 677152.40 E 12,219 -3387.13 11364.57 87.490 125.140 8907.90 8971.90 3985.31 N 1408.43 E 5954423,50 N 677184.40 E 9.385 -3355,03 11400.55 92.510 127.780 8907.90 8971.90 3963.94 N 1437.35 E 5954402.81 N 677213.82 E 15.763 -3325.76 11429.49 94.540 130.070 8906.12 8970.12 3945.79 N 1459.82 E 5954385.19 N 677236.70 E 10.563 -3301.56 11464.74 94.270 134.300 8903.41 8967.41 3922.20 N 1485.86 E 5954362,21 N 677263.29 E 11 .989 -3271.07 . 11493.21 92.510 138.180 8901.73 8965.73 3901.67 N 1505.51 E 5954342.16 N 677283.41 E 14.943 -3245.48 11529.34 89.520 142.050 8901.09 8965.09 3873.96 N 1528.67 E 5954314.99 N 677307.21 E 13,534 -3211.97 11565.78 89.960 149.450 8901,25 8965.25 3843.86 N 1549.16 E 5954285.38 N 677328.40 E 20.343 -3177.01 11596.62 87.670 152.100 8901.89 8965.89 3816.96 N 1564.21 E 5954258.84 N 677344.08 E 11.355 -3146.77 11641.04 87.400 154.210 8903.80 8967.80 3777.36 N 1584.25 E 5954219.72 N 677365.04 E 4.784 -3102.93 11675.79 86.870 157.210 8905.54 8969,54 3745.73 N 1598.53 E 5954188.43 N 677380.05 E 8.756 -3068.43 11701.84 87.220 162.670 8906.88 8970.88 3721.31 N 1607.45 E 5954164.22 N 677389.54 E 20.975 -3042.44 11724.24 88.550 162.670 8907.71 8971.71 3699.94 N 1614.12 E 5954143.01 N 677396.70 E 5.938 -3020.06 11758.74 89.480 167.460 8908.30 8972.30 3666.62 N 1623.00 E 5954109.91 N 677406.36 E 14.141 -2985.63 117.90.25 89.520 171.660 8908.58 8972.58 3635.64 N 1628,71 E 5954079.07 N 677412.79 E 13.329 -2954.40 11824.76 88.810 173.420 8909,08 8973.08 3601.43 N 1633.19 E 5954044.97 N 677418.07 E 5.499 -2920.48 11855.22 86.780 175.890 8910.25 8974.25 3571.12 N 1636.03 E 5954014.75 N 677421.62 E 10.491 -2890.78 11885.86 86.700 179.590 8912.00 8976.00 3540.56 N 1637.23 E 5953984.22 N 677423,54 E 12.059 -2861.34 11916.47 86.260 184.870 8913.88 8977.88 3510.04 N 1636.04 E 5953953,68 N 677423.06 E 17.277 -2832.69 11950,18 86.610 186.460 8915.97 8979.97 3476.57 N 1632.72 E 5953920.14 N 677420.52 E 4.821 -2801.87 11980.36 86.780 191.040 8917.71 8981.71 3446.79 N 1628.14 E 5953890.27 N 677416.64 E 15.161 -2774.97 12011.24 85.810 190.690 8919.71 8983.71 3416.53 N 1622.33 E 5953859.88 N 677411.54 E 3.339 -2747.99 . 12040.53 83.260 187.690 8922.50 8986.50 3387.75 N 1617,67 E 5953831.00 N 677407.55 E 13.406 -2722.06 12086.50 84,320 184.520 8927.47 8991.47 3342.32 N 1612.82 E 5953785.46 N 677403.76 E 7.233 -2680.35 12123.75 87.490 179.060 8930.13 8994.13 3305.20 N 1611.66E 5953748.33 N 677403.47 E 16.915 -2645.40 12154,67 90.220 177.120 8930,75 8994,75 3274.31 N 1612,69 E 5953717.47 N 677405.22 E 10.830 -2615.71 12195.88 90.130 173.420 8930.63 8994.63 3233.25 N 1616.09E 5953676.50 N 677409,58 E 8.981 -2575.60 12224.16 89.430 169.370 8930.73 8994.73 3205.29 N 1620.32 E 5953648.65 N 677414.46 E 14.533 -2547.71 12254.66 90.130 165.840 8930.85 8994.85 3175.51 N 1626.86 E 5953619.03 N 677421.70 E 11 .799 -2517.36 12285,07 92.510 164.260 8930.15 8994.15 3146.14N 1634.71 E 5953589.85 N 677430.23 E 9.393 -2487.00 12318.41 92.780 161.080 8928.61 8992.61 3114,35 N 1644.63 E 5953558.30 N 677440.89 E 9.562 -2453.71 12349.26 90,660 156.330 8927.69 8991.69 3085.63 N 1655.82 E 5953529.85 N 677452.75 E 16.854 -2422.93 12376.59 90.570 156.150 8927.39 8991.39 3060.62 N 1666.83 E 5953505.10 N 677464.34 E 0.736 -2395.74 12400.00 90.570 156.150 8927.16 8991.16 3039.21 N 1676.30 E 5953483.92 N 677474.30 E 0.000 -2372.45 Projected Survey 20 October, 2003 - 10:37 Page 3 of 4 DrillQuest 3.03.02.005 ~ Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 07 - 07-14 -7-14BPB1 Your Ref: API 500292033970 Job No. AKMW0002699461, Surveyed: 11 October, 2003 BPXA North Slope Alaska 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 162.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12400,OOft., The Bottom Hole Displacement is 3470.84ft., in the Direction of 28.879° (True), . Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10352.00 12400.00 8566.23 8991.16 4484.89 N 3039.21 N 1355.29 E Tie On Point 1676.30 E Projected Survey Survey tool program for 07-14 - 7-14BPB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) . 0.00 10352.00 0.00 8566.23 10352.00 12400.00 8566.23 BP High Accuracy Gyro - AK-1 BP _HG (07-14) 8991.16 MWD Magnetic (7 -14BPB 1) 20 October, 2003 - 10:37 Page 4 of 4 DrillQuest 3.03.02.005 . . FRANK H. MURKOWSKI, GOVERNOR .AI,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 07-14B BP Exploration (Alaska), Inc. Permit No: 203-142 Surface Location: 511' SNL, 314' WEL, Sec.33, TllN, RI4E, UM Bottomhole Location: 2530' NSL, 1397' EWL, Sec. 27, T11N, R14E, UM Dear Mr. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ß.-d¡ ~~- Randy Ifuedrich ~ Commissioner BY ORDER OF THE COMMISSION DATED this I 'f day of August, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section _ STATE OF ALASKA e ALASKA Wft.. AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 11b, Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5, Bond: IBI Blanket 0 Single Well Bond No, 2S100302630-277 6. Proposed Depth: MD 12775' TVD 8910' 7, Property Designation: ADL 028309 o Drill III Redrill 1 a, Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P,O, Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 511' SNL, 314' WEL, SEC. 33, T11N, R14E, UM Top of Productive Horizon: 4235' NSL, 1020' EWL, SEC. 27, T11N, R14E, UM Total Depth: 2530' NSL, 1397' EWL, SEC. 27, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-675869 y-5950406 Zone-ASP4 16. Deviated Wells: Kickoff Depth 10570 ft Maximum Hole Angle Specifications Grade CouplinQ L-80 TCIII Hole 3-3/4" CasinQ WeiQht 3-3/16" x 6.2# 1 '- - 1/8 iI ~ 8. Land Use Permit: 9. Acres in Property: 2560 ~ f/ß/¿OO3 / Of". .. I ( <'>111/ ;:; '!>II -. III Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11, Well Name and Number: PBU 07-148 / 12. Field 1 Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 13. Approximate Spud Date: 10101/03 ," 14. Distance to Nearest Property: 21,120' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): KBE = 64' feet 15-13A is 425' away at 10750' /' 17. Anticipated pressure (see 20 AAC 25.035) ../ 900 Max. Downhole Pressure: 3250 psig. Max, Surface Pressure: 2194 psig Setting Depth .. .. ..... QuantitY bf Cement Top Bottom (c.f. or sacks) LenQth MD TVD MD TVD (includinQ staQe data) 2925' 9850' 8147' 12775' 8910' 93 sx Class 'G' 19. PRESEN1'WELLCONOI1'ION SUMt\AA.~Y (To bêéOmpleted forRedrill·AND~e"'el'ltryOperàtibI'1S) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD 11947' 8920' 11600' 11600' 8930' Structural Conductor 71' 20" 243 sx Arcticset 71' 71' Surface 2665' 13-3/8" 4200 sx Arcticset II 2665' 2665' Intermediate 10524' 9-5/8" 1200 sx Class 'G' 10524' 8687' Production Liner 2074' 2-7/8" 70 sx Class 'G' 9805' -11879' 8180' - 8924' Perforation Depth MD (ft): 10676' - 11869' 20, Attachments IBI Filing Fee IBI BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 8799' - 8924' IBI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 0 Drilling Fluid Program IBI 20 AAC 25.050 Requirements Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mary Endacott Title CT Drilling Engineer S;gnature W11!ii1UJ1:l Permit To Drill I API Number: Number: .2. o. ~ - ! Y:L.. 50- 029-20339-02-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures Other:T"€~ + Bo P E fe ~SOc> f>t'. Approved Bv: ~ Form 10-401 Re~sed- 3/;013 Phone 564-4388 Commission Use Only I Permit AP.R!ZO al<tf". I See cover letter for Date: f:i I () t!J other requirements D Yes ~ No Mud Log R quire DYes ø No ~ Yes 0 No Directional Survey Required ~ Yes D No Contact Mary Endacott, 564-4388 Date 'í//I /6 '3 Prepared By Name/Number: Terrie Hubble. 564-4628 ~ .I ' BY ORDER OF ~~·~~I ... .c M~.....IS.SIO. NER. ..;tffF~~~I~S..¡IOA Date ... !.~ ur\¡tJlr~· I . .. .. J__ ~!/ 'lID 3 Submit In Duplicate e e 8P 7-148 CTD Sidetrack Summary of Operations: Phase 1: Prep work - integrity testing set CIBP Cut 2 7/8" liner at believed top of cement Check if free Phase 2: Pull 2 7/8" liner, set open hole whipstock Phase 3: Drill and Complete sidetrack / Mud Program: · Phase 2: Seawater · Phase 3: Flo-Pro (8.6 - 8.7 ppg) / Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 33/16" 6.2# L-80 TC-II x 2 7/8" 6.4# ST-L L-.8~ 9850' (-8147 TVDSS) to 12,775'. / · The liner will be cemented with a minimum O~IS to bring cement up to top of liner. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. ./ · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to Nearest Well Within Pool: / closest approach is 425ft to 15-13A at 10,750' in planned wellpath · Distance to Nearest Property: 21,120' to Prudhoe Unit Boundary Logging · MWD Gamma Ray and resistivity will be run in the open hole section. · Memory CNL will be run inside the liner. Hazards ~ · The maximum recorded H2S on OS 7 i 7.5PR . · No faults are expected Reservoir Pressure · Res. press. is estimated to be 3250 psi at 8800' ss (7.1 ppg emw) - estimated. · Max. surface pressure with gas (0.12 psi/ft) to surface is 2194 psi. / TREE = GRA Y GEN 2 WELLHEAD = GRAY ~,W~'''''~'m~',w,w,,_N''~MN'~'~m~Nm'm~'¥o,w,',~m~~mm ACTUATOR = AXELSON KB. ELEV ='·'64' mm~~~_-u.w.·,·,··, BF, ELEV = ~=m~~mm===~~~~·_~=,_~_wm_·~_·.V___'__~__, KOP = 3000' '=mmm==,w_wmm___·_WNN_~.", ..~~../\r1.!;JI~~ ........~~..~..1.1.6~!.' Datum MD = 10766' wW.','.',.w.""W.""W.'.'.'.'.','"w Datum lVD = 8800' SS e 113-3/8" CSG, 72#, L80, ID = 12.347" !-i 07 -148 e SAFETY NOTES: LDL INDICATES LNR LAP IS LEAKING. Proposed CTD Sidetrack 2665' rJ 2256' !-i5-1/2 OTIS ROM SSSV NIP, ID = 4.562" I . GAS LIFT MANDRELS ST MD lVD DEV 1YPE VLV LATCH PORT DAlE 1 2903 2903 7 011S T2 2 5186 4826 43 011S RA ~ 3 7033 6139 45 011S T2 4 8174 6993 38 011S RA 5 8829 7494 45 011S RA l 6 8902 7545 46 011S RA 7 9365 7868 45 011S RA 8 9443 7923 45 011S RA 9 9587 8025 45 011S RA 10 9658 8076 45 011S T2 ..LL 1 9520' !-i5-1/2" OTIS SLIDING SLV I I 9732' !-i5-1/2" 011S N NIP, ID = 4.455" I ~ ~ 9772' !-i5-1/2" BOTPBRASSY I 9803' !-i9-5/8" X 5-112" BKR SAB PKR I TOPOF2-7/8" LNR!-i 9804' r- 9809' 1-i6-5/8" x 4-1/2" XO I 15-1/2" lBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" Ii 9809' I ~ 9850' I-iTOp of 3-3116" Liner 1 TOP OF 4-1/2" lBG H 9809' I =4,'::::1::::-:: -i 9850' I-iTOp of Cement /' - - I 9870' !-i4.1/2" CAM OB-6 LANO NIP, ID = 3.813" I 1 TOP OF CEMENT l-i 9892' i 9933' !-i 4-1/2" BKR SHEA ROUT SUB I 14-112" lBG-NPC, 12.6#, N-80, .0152 bpf, 10 = 3.958" l-i 9934' 1 9934' !-i4.1/2" TUBING TAIL I I 9907' !-i ELMO TT LOGGED 07/14/89 1 ÆRFORA TION SUMMARY REF LOG: CNL MWD GR ON 11/10/98 ANGLEAT TOP ÆRF: 31 @ 10676' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz OA lE 2" 6 10676 - 10690 Isolated propose<i 2" 4 10980 - 11130 Isolated propose<i 2" 4 11290 - 11445 Isolated propose¡) 2" 4 11470 - 11530 ísolated propos6c 2" 4 11665 - 11869 isolated propos6o I MILLOUTWINDOW 10524' 19-518" CSG, 47#, L-80, ID = 8.681" H 10524' 1 / 1 0570' I...J "'.,. ..', '. ' . ,. . I I ' ~:." I ,I" . .'1, "~, ¡{~:,'" 1 :¡ .¡.' i)" \ / '1i" ,1",' l-i 12,775' 1 '''~==-~=I:C''::::~)'-T " :) <:, ,) .0 -"""''''1\ / -..._-~ ; ~) 1 I 11000' !-i3-3!16 x 2-7í8 X-over 10500' -Cut and PuIl2-7í8" liner 1 0650' - CIBP I 11600' - HES CIBP (SET 03/07102) 11849' !-i FISH - 2-7/8" FASDRILL PLUG 12-7/8"LNR,6.5#,L-80,.00579bPf,ID=2.441" H 11879' I DAlE 06/03179 08/01/98 01/12/01 02/13/01 09/23/01 03/07/02 REV BY COMMENTS ORIGINAL COMPLE110N SIOETRACK SIS-SLT CONVERlED TO CANVAS SIS-MD FINAL RNnP CORREC110NS PWE/TLH SET CIBP DAlE REV BY COMMENTS 06122/02 GRCltlh PERF CORREC110NS 03/07/03 RUTP ADD PERF PRUDHOE SAY UNIT WELL: 07-14A PERMIT No: 98-{)72 API No: 50-029-20339-01 Sec. 33, T11N, R14E, 5220.78 FEL 606.71 FNL BP Exploration (Alaska) BP Amoco 64.6Oft ." , § : t : Magnetic Field Strength: 57572nT D~a~gi7~~~M; Model: bggm2003 T ""~ m 1 [50ft/in) e BP-GDB Baker Hughes INTEQ Planning Report Company: Field: Site: Well: Well path: BP Amoco Prudhoe Bay PB DS 07 07-14 Plan#8 07-14B 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 Site: PB DS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948144.78 ft 677382.28 ft e --------~-- LNTEQ Date: 7/30/2003 Time: 09:14:33 Page: Co-ordinate(NE) Reference: Well: 07-14, True North Vertical (rVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,162.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Latitude: 70 15 Longitude: 148 33 North Reference: Grid Convergence: ..-. ----------- Alaska, Zone 4 Well Centre bggm2003 49.847 N 56.934 W True 1.35 deg Well: 07-14 Slot Name: 14 07-14 Well Position: +N/-S 2296.75 ft Northing: 5950406.37 ft Latitude: 70 16 12.434 N +E/-W -1459.19 ft Easting : 675869.48 ft Longitude: 148 34 39.412 W Position Uncertainty: 0.00 ft Wellpath: Plan#807-14B 500292033902 Current Datum: 23: 145/17/197900:00 Magnetic Data: 7/29/2003 Field Strength: 57572 nT Vertical Section: Depth From (TVD) ft 37.00 Targets Name Description Dip. Dir. 07-14B Polygon3.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8888.00 8894.00 8911.00 07-14B Fault 1 -Polygon 1 -Polygon 2 07-14B Fault 3 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 07-14B Fault 2 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 07-14B T8.1 07-14B T8.2 07-14B T8.3 Height 64.00 ft +N/-S ft 0.00 +N/-S ft 4636.27 4636.27 4843.72 4167.81 2952.33 2917.83 3324.62 4263.89 4452.20 4452.20 3323.12 4871.82 4871.82 3538.82 3319.45 3538.82 4898.10 4898.10 4653.97 4205.11 4653.97 4662.70 4046.13 3041.82 +F./-W ft 1024.19 1024.19 1564.22 1593.43 1810.11 1574.22 1503.70 1120.52 339.65 339.65 1353.62 1859.97 1859.97 1968.86 1938.73 1968.86 1805.57 1805,57 1764.85 1709.34 1764.85 1219.87 1406.53 1705.16 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Map Map Northing Easting ft ft 5955065.00 676784.99 5955065.00 676784.99 5955285.00 677319.99 5954610.00 677364.99 5953400.00 677609.99 5953360.00 677374.99 5953765.00 677294.99 5954695.00 676889.99 5954865.00 676104.99 5954865.00 676104.99 5953760.00 677144.99 5955320.00 677614.99 5955320.00 677614.99 5953990.00 677754.99 5953770.00 677729.99 5953990.00 677754.99 5955345.00 677559.99 5955345.00 677559.99 5955100.00 677524.99 5954650.00 677479.99 5955100.00 677524.99 5955096.00 676979.99 5954484.00 677180.99 5953487.00 677502.99 07-14A 10567.50 ft Mean Sea Level 25.66 deg 80.84 deg Direction deg 162.00 <- Latitude --> Deg Min Sec 70 16 58.031 N 70 16 58.031 N 70 17 0.070 N 70 16 53.422 N 70 1641.468 N 70 1641.129 N 70 16 45.130 N 70 16 54.368 N 70 16 56.221 N 70 16 56.221 N 701645.115N 70 17 0.346 N 70 17 0.346 N 70 16 47.235 N 70 16 45.078 N 70 16 47.235 N 70 17 0.604 N 70 17 0.604 N 70 16 58.203 N 70 16 53.789 N 70 16 58.203 N 70 16 58.290 N 70 16 52.226 N 70 1642.348 N <-- Longitude -> Deg Min See -----.-- 148 34 9.579 W 148 34 9.579 W 148 33 53.847 W 148 33 53.000 W 148 33 46.698 W 148 33 53.567 W 148 33 55.619 W 148 34 6.774 W 148 34 29.518 W 148 34 29.518 W 148 33 59.990 W 148 33 45.232 W 148 3345.232 W 148 33 42.070 W 148 33 42.949 W 148 3342.070 W 148 33 46.816 W 148 33 46.816 W 148 33 48.004 W 148 33 49.624 W 148 33 48.004 W 148 34 3.878 W 148 33 58.445 W 148 33 49.753 W e BP-GDB e Baker Hughes INTEQ Planning Report ~--~.~._- h'iTRQ Company: BP Amoco Date: 7/30/2003 Time: 09:14:33 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07-14. True North Site: PB DS 07 Vertical (TVD) Reference: System: Mean Sea Level Well: 07-14 Section (VS) Referencc: Well (0.00N,O.00E,162.00Azi) Wellpath: Plan#8 07-14B Survey Calculation \h'llIod: Minimum Curvature nil: Oracle ---.- .....-..- Annotation MD TVD ft ft 10567.50 8652.71 TIP 10570.00 8654.41 KOP 10580.00 8661.04 3 10620.00 8682.95 4 10997.76 8887.41 5 11647.76 8893.02 6 12097.76 8900.69 7 12347.76 8904.75 8 12597.76 8908.26 9 12775.00 8910.47 TO Plan: Plan #8 Date Composed: 7/29/2003 Identical to Lamar's Plan #8 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/1000 deg/100ft deg/10OO deg --.-- 10567.50 47.28 8.00 8652.71 4628.88 1409.45 0.00 0.00 0.00 0.00 10570.00 46.99 7.13 8654.41 4630.69 1409.69 28.02 -11.60 -34.80 245.25 10580.00 49.99 7.13 8661.04 4638.12 1410.62 30.00 30.00 0.00 0.00 10620.00 63.48 358.71 8682.95 4671.41 1412.13 38.00 33.72 -21.06 330.00 10997.76 90.00 204.68 8887.41 4664.97 1211.64 38.00 7.02 -40.77 227.50 11647.76 89.17 126.69 8893.02 4082.69 1360.20 12.00 -0.13 -12.00 269.15 12097.76 89.03 180.69 8900.69 3694.13 1552.33 12.00 -0.03 12.00 90.60 12347.76 89.16 150.69 8904.75 3454.68 1613.40 12.00 0.05 -12.00 270.00 12597.76 89.27 180.69 8908.26 3215.22 1674.48 12.00 0.05 12.00 90.00 12775.00 89.32 159.42 8910.47 3041.65 1704.91 12.00 0.03 -12.00 270.00 Survey MD Incl Azim Sys TVD N/S. E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1 000 deg ----..-- ......-......--... .-.---- 10567.50 47.28 8.00 8652.71 4628.88 1409.45 5955066.61 677170.30 -3966.78 0.00 0.00 TIP 10570.00 46.99 7.13 8654.41 4630.69 1409.69 5955068.44 677170.50 -3968.43 28.02 245.25 KOP 10575.00 48.49 7.13 8657.77 4634.37 1410.15 5955072.12 677170.87 -3971.78 30.00 0.00 MWD 10580.00 49.99 7.13 8661.04 4638.12 1410.62 5955075.88 677171.26 -3975.21 30.00 360.00 3 10600.00 56.66 2.59 8672.98 4654.09 1411.95 5955091.88 677172.21 -3989.99 38.00 330.00 MWD 10620.00 63.48 358.71 8682.95 4671.41 1412.13 5955109.20 677171.98 -4006.40 38.00 332.72 4 10625.00 62.20 357.12 8685.24 4675.85 1411.97 5955113.64 677171.72 -4010.68 38.00 227.50 MWD 10650.00 56.14 348.60 8698.06 4697.12 1409.35 5955134.83 677168.61 -4031.71 38.00 228.22 MWD 10675.00 50.74 338.85 8712.97 4716.37 1403.80 5955153.94 677162.60 -4051.74 38.00 232.60 MWD 10700.00 46.29 327.63 8729.55 4733.07 1395.45 5955170.44 677153.87 -4070.20 38.00 238.43 MWD 10725.00 43.09 314.89 8747.36 4746.75 1384.54 5955183.87 677142.64 -4086.59 38.00 245.88 MWD 10750.00 41.45 300.96 8765.90 4757.06 1371.36 5955193.87 677129.23 -4100.46 38.00 254.95 MWD 10775.00 41.56 286.60 8784.67 4763.70 1356.29 5955200.15 677114.00 -4111.44 38.00 265.29 MWD 10800.00 43.41 272.79 8803.14 4766.50 1339.72 5955202.56 677097.38 -4119.21 38.00 276.06 MWD 10825.00 46.79 260.23 8820.82 4765.37 1322.12 5955201.02 677079.81 -4123.57 38.00 286.28 MWD 10850.00 51.38 249.21 8837.22 4760.34 1303.97 5955195.57 677061.78 -4124.40 38.00 295.16 MWD 10875.00 56.87 239.63 8851.89 4751.56 1285.77 5955186.37 677043.79 -4121.68 38.00 302.40 MWD 10900.00 63.01 231.24 8864.42 4739.27 1268.01 5955173.66 677026.32 -4115.48 38.00 308.03 MWD 10925.00 69.59 223.75 8874.47 4723.80 1251.18 5955157.80 677009.87 -4105.96 38.00 312.24 MWD 10950.00 76.46 216.89 8881.78 4705.57 1235.75 5955139.22 676994.87 -4093.40 38.00 315.26 MWD 10975.00 83.51 210.41 8886.13 4685.09 1222.14 5955118.44 676981.74 -4078.13 38.00 317.27 MWD 10997.76 90.00 204.68 8887.41 4664.97 1211.64 5955098.07 676971.71 -4062.23 38.00 318.40 5 11000.00 90.00 204.42 8887.41 4662.93 1210.71 5955096.01 676970.83 -4060.58 12.00 269.15 MWD 11025.00 89.95 201.42 8887.43 4639.90 1200.98 5955072.77 676961.64 -4041.69 12.00 269.15 MWD 11050.00 89.91 198.42 8887.46 4616.40 1192.46 5955049.07 676953.67 -4021.97 12.00 269.15 MWD e BP-GDB e Baker Hughes INTEQ Planning Report ~-~.~- lNTEQ Company: BP Amoco Date: 7/30/2003· Time: 09:14:33 Pajte: 3 Field: Prudhoe Bay Co-ordinatc(NE) Reference: Well: 07-14, True North Site: PB DS 07 Vertical (TVD) Reference: System: Mean Sea Level Well: 07-14 Section (VS) Reference: Well (O.OON,O.OOE, 162,OOAzi) Wellpath: Plan#8 07-14B. Survey Calculation Method: Minimum Curvature Db: Oracle ____.w Survey MD Incl Azim Sys TVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/10ot! deg .- 11075.00 89.86 195.42 8887.51 4592.49 1185.19 5955025.00 676946.96 -4001.47 12.00 269.16 MWD 11100.00 89.82 192.42 8887.58 4568.22 1179.18 5955000.60 676941.52 -3980.25 12.00 269.16 MWD 11125.00 89.78 189.42 8887.66 4543.68 1174.44 5954975.95 676937.36 -3958.37 12.00 269.17 MWD 11150.00 89.73 186.42 8887.77 4518.92 1171.00 5954951.12 676934.50 -3935.89 12.00 269.18 MWD 11175.00 89.69 183.42 8887.90 4494.01 1168.86 5954926.18 676932.94 -3912.86 12.00 269.19 MWD 11200.00 89.65 180.42 8888.04 4469.03 1168.02 5954901.18 676932.68 -3889.36 12.00 269.21 MWD 11225.00 89.61 177.42 8888.20 4444.04 1168.49 5954876.21 676933.74 -3865.45 12.00 269.23 MWD 11250.00 89.57 174.42 8888.38 4419.11 1170.27 5954851.33 676936.10 -3841.19 12.00 269.24 MWD 11275.00 89.53 171.42 8888.57 4394.30 1173.35 5954826.60 676939.76 -3816.64 12.00 269.27 MWD 11300.00 89.50 168.42 8888.79 4369.69 1177.73 5954802.10 676944.71 -3791.88 12.00 269.29 MWD 11325.00 89.46 165.42 8889.01 4345.34 1183.39 5954777.89 676950.93 -3766.98 12.00 269.31 MWD 11350.00 89.43 162.42 8889.26 4321.32 1190.31 5954754.05 676958.42 -3742.00 12.00 269.34 MWD 11375.00 89.40 159.42 8889.51 4297.70 1198.48 5954730.62 676967.14 -3717.01 12.00 269.37 MWD 11400.00 89.37 156.42 8889.78 4274.54 1207.88 5954707.69 676977.07 -3692.07 12.00 269.40 MWD 11425.00 89.34 153.42 8890.07 4251.90 1218.47 5954685.30 676988.19 -3667.27 12.00 269.43 MWD 11450.00 89.31 150.42 8890.36 4229.85 1230.24 5954663.53 677000.47 -3642.66 12.00 269.47 MWD 11475.00 89.28 147.42 8890.67 4208.44 1243.14 5954642.44 677013.87 -3618.31 12.00 269.50 MWD 11500.00 89.26 144.42 8890.98 4187.74 1257.15 5954622.07 677028.36 -3594.30 12.00 269.54 MWD 11525.00 89.24 141.42 8891.31 4167.80 1272.22 5954602.49 677043.89 -3570.67 12.00 269.58 MWD 11550.00 89.22 138.42 8891.65 4148.67 1288.31 5954583.74 677060.42 -3547.51 12.00 269.62 MWD 11575.00 89.21 135.42 8891.99 4130.42 1305.39 5954565.89 677077.92 -3524.88 12.00 269.66 MWD 11600.00 89.19 132.42 8892.34 4113.08 1323.39 5954548.98 677096.32 -3502.82 12.00 269.70 MWD 11625.00 89.18 129.42 8892.70 4096.71 1342.28 5954533.06 677115.58 -3481.42 12.00 269.74 MWD 11647.76 89.17 126.69 8893.02 4082.69 1360.20 5954519.46 677133.82 -3462.54 12.00 269.78 6 11650.00 89.17 126.95 8893.06 4081.34 1361.99 5954518.16 677135.65 -3460.71 12.00 90.60 MWD 11675.00 89.14 129.95 8893.43 4065.80 1381.56 5954503.08 677155.58 -3439.88 12.00 90.60 MWD 11700.00 89.11 132.96 8893.81 4049.25 1400.30 5954486.97 677174.69 -3418.35 12.00 90.55 MWD 11725.00 89.08 135.96 8894.21 4031.75 1418.14 5954469.89 677192.93 -3396.19 12.00 90.51 MWD 11750.00 89.06 138.96 8894.61 4013.33 1435.04 5954451.88 677210.26 -3373.46 12.00 90.46 MWD 11775.00 89.04 141.96 8895.03 3994.06 1450.95 5954432.98 677226.62 -3350.21 12.00 90.41 MWD 11800.00 89.02 144.96 8895.45 3973.98 1465.83 5954413.26 677241.96 -3326.51 12.00 90.36 MWD 11825.00 89.01 147.96 8895.88 3953.15 1479.64 5954392.75 677256.25 -3302.43 12,00 90.31 MWD 11850.00 89.00 150.96 8896.31 3931.62 1492.34 5954371.53 677269.45 -3278.04 12.00 90.26 MWD 11875.00 88.99 153.96 8896.75 3909.46 1503.90 5954349.65 677281.53 -3253.39 12.00 90.21 MWD 11900.00 88.98 156.96 8897.20 3886.73 1514.28 5954327.17 677292.43 -3228.56 12.00 90.15 MWD 11925.00 88.98 159.96 8897.64 3863.48 1523.46 5954304.14 677302.15 -3203.61 12.00 90.10 MWD 11950.00 88.97 162.96 8898.09 3839.78 1531.41 5954280.64 677310.65 -3178.62 12.00 90.05 MWD 11975.00 88.98 165.96 8898.54 3815.71 1538.10 5954256.72 677317.91 -3153.65 12,00 89.99 MWD 12000.00 88.98 168.96 8898.98 3791.31 1543.53 5954232.46 677323.90 -3128.77 12.00 89.94 MWD 12025.00 88.99 171.96 8899.43 3766.66 1547.67 5954207.92 677328.62 -3104.05 12.00 89.88 MWD 12050.00 89.00 174.96 8899.87 3741.83 1550.52 5954183.16 677332.04 -3079.56 12.00 89.83 MWD 12075.00 89.01 177.96 8900.30 3716.88 1552.06 5954158.26 677334.17 -3055.35 12.00 89.78 MWD 12097.76 89.03 180.69 8900.69 3694.13 1552.33 5954135.52 677334.97 -3033.63 12.00 89.73 7 12100.00 89.03 180.42 8900.73 3691.89 1552.31 5954133.28 677335.00 -3031.51 12.00 270.00 MWD 12125.00 89.03 177.42 8901.15 3666.90 1552.77 5954108.31 677336.05 -3007.60 12.00 270.00 MWD 12150.00 89.03 174.42 8901.58 3641.97 1554.55 5954083.43 677338.41 -2983.34 12.00 270.06 MWD 12175.00 89.04 171.42 8902.00 3617.17 1557.63 5954058.71 677342.07 -2958.80 12.00 270.11 MWD 12200.00 89.05 168.42 8902.42 3592.56 1562.00 5954034.21 677347.01 -2934.04 12.00 270.16 MWD 12225.00 89.06 165.42 8902.83 3568.22 1567.66 5954010.01 677353.24 -2909.14 12.00 270.21 MWD 12250.00 89.08 162.42 8903.23 3544.20 1574.58 5953986.16 677360.72 -2884.16 12.00 270.26 MWD 12275.00 89.09 159.42 8903.63 3520.58 1582.75 5953962.74 677369.44 -2859.17 12.00 270.31 MWD 12300.00 89.11 156.42 8904.03 3497.42 1592.15 5953939.81 677379.37 -2834.24 12.00 270.35 MWD 12325.00 89.13 153.42 8904.41 3474.78 1602.74 5953917.42 677390.49 -2809.44 12.00 270.40 MWD e BP-GDB e Baker Hughes INTEQ Planning Report I.N'fEQ Company: BP Amoco Date: 7/30/2003 Time: 09:14:33 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07-14, True North Site: PB DS 07 Vertical (TVD) Reference: System: Mean Sea Level Well: 07-14 Section (VS) Reference: Well (O.OON,O.00E,162.00Azi) Wellpath: Plan#8 07-14B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD loci Azim Sys TVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1 000 deg 12347.76 89.16 150.69 8904.75 3454.68 1613.40 5953897.58 677401.62 -2787.02 12.00 270.45 8 12350.00 89.16 150.96 8904.78 3452.72 1614.50 5953895.65 677402.76 -2784.83 12.00 90.00 MWD 12375.00 89.16 153.96 8905.15 3430.56 1626.05 5953873.76 677414.83 -2760.18 12.00 90.00 MWD 12400.00 89.16 156.96 8905.52 3407.82 1636.43 5953851.28 677425.74 -2735.35 12.00 89.95 MWD 12425.00 89.17 159.96 8905.88 3384.57 1645.61 5953828.25 677435.45 -2710.40 12.00 89.91 MWD 12450.00 89.18 162.96 8906.24 3360.88 1653.56 5953804.75 677443.95 -2685.41 12.00 89.86 MWD 12475.00 89.19 165.96 8906.60 3336.80 1660.26 5953780.83 677451.21 -2660.43 12.00 89.82 MWD 12500.00 89.20 168.96 8906.95 3312.40 1665.68 5953756.57 677457.20 -2635.55 12.00 89.78 MWD 12525.00 89.21 171.96 8907.30 3287.75 1669.83 5953732.02 677461.92 -2610.83 12.00 89.74 MWD 12550.00 89.23 174.96 8907.64 3262.92 1672.67 5953707.27 677465.35 -2586.33 12.00 89.69 MWD 12575.00 89.25 177.96 8907.97 3237.97 1674.22 5953682.36 677467.47 -2562.13 12.00 89.65 MWD 12597.76 89.27 180.69 8908.26 3215.22 1674.48 5953659.62 677468.27 -2540.41 12.00 89.61 9 12600.00 89.27 180.42 8908.29 3212,98 1674.46 5953657.38 677468.30 -2538.28 12.00 270.00 MWD 12625.00 89.27 177.42 8908.61 3187.98 1674.93 5953632.41 677469.36 -2514.37 12.00 270.00 MWD 12650.00 89.27 174.42 8908.93 3163.05 1676.71 5953607.53 677471.72 -2490.11 12.00 270.04 MWD 12675.00 89.28 171.42 8909.24 3138.25 1679.79 5953582.81 677475.37 -2465.57 12.00 270.08 MWD 12700.00 89.29 168.42 8909,56 3113.64 1684.16 5953558.31 677480.32 -2440.81 12.00 270.12 MWD 12725.00 89.30 165.42 8909.87 3089.29 1689.82 5953534.10 677486.54 -2415.91 12.00 270.16 MWD 12750.00 89.31 162.42 8910.17 3065.27 1696.74 5953510.25 677494.02 -2390.93 12.00 270.19 MWD 12775.00 89.32 159.42 8910.47 3041.65 1704.91 5953486.83 677502.74 -2365.94 12.00 270.23 TO e Nordic 1 bighole . All Measurements are from top of Riser 8/11/2003 ~ CD en .- cr: top of bag BAG 71/16" 5000psi bttm of bag middle of slips Blind/Shears .......................... middle of pipes 23/8" combi ram/slips TOTs / I.................········· 7 1/16" 5000psi middle of flow cross .....---.. r-- Mud Cross Mud Cross .......... 7 1/16" 5000psi '---' I r variable bore pipe 3 1/2"-27/8" ........................ / 1 TOTs 2 3/8" combi ram/slips I...............········· 7 1/16" 5000psi .' middle of blindlshears middle of pipe/slips Flow Tee e e P 055113 DATE 7/14/2003 I I CHECK NO. 055113 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 7/14/2003 INV#P~071003C PERMIT TO DRILL FEE H b^7 -' t L{ D AUG 1 2 2003 iE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ ·0551t3 CONSOLIDATED COMM~FÌciAL ACCOUNT AMOUNT July 14,2003 *******$100.00*******1 NOT VALlDI'FTFR 1?n nAY!,; ·:~\:·'~:':>':'::.~~:::~·~¿p.~~:~~':;/iS~;;~:~~\;::~~~:/:\~<})I "." ... "'¡i~:'~,Ó~' .... "",,-. ....... ~/\/S~~·~Š.· ·..~:~~~\·~:i~:~~~{~:·t/:<r~dj 111055. .~.. .:01..20 3Rq 51: 012?B C¡bò1' ~~"PERMrr¢HE~ll!ST Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT 07-14B PTD#: 2031420 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Initial ClasslType DEV 11-01L GeoArea 890 Administration 1 Permittee attach~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ 2 lease number appropriate _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _UÐique welln_arne_and lJu.mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeUIQcated in_ad_efil'!edpooL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeJUQcated proper _distance_ from driJling ul'!itboUl'!d<iIY_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WellJQcated proper distance from Qtberwells_ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7S_utficiel'!t _acreag.e_ayail<ible in_drilJilJg. unJt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 8 Jtdevi<!ted, Js_ weJlbQre pl<!UlJcJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ 9 _Oper_ator ol'!l~ affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _Oper_ator bas_appropriateJ).ond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Permit c_an Þe issu.ed wJtbQut conservatiol'! order _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 Permit can Þe issu.ed witbQut <!d_mil'!istratille_approvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ RPC 8/13/2003 13 Can permit be approved before 15-day wait Yes 14 WelUQcated withil'! <!rea <!Ild_strataauthorized byJlJjectiolJ Order # (puUO# in_cornm_elJts) (FQr _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 AJlwelJsJ1vitJ1inJl4JlJite_area_ofreyiewidelJtlfied(ForservJCJ:¡-,^,-ellOI'!I~)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 16 Pre-produced injector; dur<itiQn of pre-produGliol'! less than 3 mOl'!ths_ (For _ser:vice welt QnJy) _ _ NA _ 17 ACMP_ fil'ldjngof Consistency has Þeen issued_ for this project _ _ _ _ _ _ _ _ _ NA Unit Program DEV 11650 On/Off Shore ~ Well bore seg Annular Disposal - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- Engineering 18C_onductor stril'lgprQvided _ . NA 19Surfacecasil'lg protects allknowll USDWs _ NA 20 _CMT vot adeQuateJo circulate oÐcol'lductor_ 8< surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA 21CMT vot adeQuateJo tie-inlQng _string tosurt ~g _ _ _ _ _ _ _ _ _ _ NA 22CMT will coyera]l !<oowÐproductiye bQri¡!:Olls _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ 23 _C_asing de_signs ad_eQuaJe for C,T, B&(.1ermafr_ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24A.dequ<itetankage_or re_ser:ve pit _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ CTDU. _ _ _ _ _ _ _ 125 JtaJe-drilt has_a 10A03 fQr <ibandOllment beelJ apprQved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ 8/13/2003. 26 Adequate_wellbore sep<!ratioÐProposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdivecter required, dQes it meet reguJatiol'!s_ _ NA _ _ _ _ _ Sidetrack. _ _ _ _ _ _ _ _ 28 _DriUilJgfJuid(.1rog.ramschematic_&equiplistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _MaxMW_8J.ppg, 29 BOPEs, do they meet reguJatiol'l _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 30 _BOPE_press raJing appropriate; Jest toJpu_t psig in _comrneots)_ _ _ _ _ _ _ _ _ _ _ _ Yes _ 31 _C_hoke_manjfold cQmpJies_ w/APIRF'-53 (May 84L _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ 32 WQrk will occw withoutoperatjon _sbutdo-,^,-n_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Yes _ 33 Js pres.ence_ Qf H2S g<!s_ (.1fob_aÞle _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ 34 Mechanicalcoodit[on of wells withil'! ,ð,08. yerified (Fots_erv]ce welJ only) _ _ _ _ _ _ _ _ _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - Appr Date WGA 8/13/2003 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . . . Test to 3500_ (.1sLMSF' 2194 psi. - - - - - ~ - - - - - - - - - - - - - .15ppm. . - - - - - - - - - - - Geology 35 Permit ca[1 be tssu.ed wlo hydrogen sulfide measures_ 36 _D_ata_preseoted on_ pote_ntial overpres.sure _zOl'les_ 37 _Setsmic_analysjs_ Qf shaJlow gas_zones_ _ _ _ _ _ _ _ _ _ _ _ _ 38 _SeabedcOl'lditioo survey (if off-shore) . 39 _ CQnta_cll'lamelphOlleJQrweelsly progress_reports [exploratol)' _onlYl - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ _ _ _ _ _N9_ _ _ _ _ _ _ _ _ _ _ _ __ .......... ........... NA _ _ _ _ _ _ _ _ __ _ _ _ _ _ NA_ .........NA . _ _ _ _ _ __ . _ NA _ _ _ _ _ _ _ _ _. - - - - - - - ~ - - - ~ - - - - - - - - - ~ - - ~ - - - - - - - - - - - - - - - - - - - - - - Appr RPC Date 8/13/2003 " - - - - - - - ~ - Geologic Commissioner: Public ç),7k:) Commissioner ð-=-. :....---~ Date Engineering Commissioner: Date: Date ~ 0~ D D e e e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, infonnation of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of infonnation. Sperry-Sun Dri4llbg Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 15 09:32:23 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: MWD RUN 1 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 4 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 7 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 12 MW0002699461 S. LATZ SEVCIK/SARBE ~03-/r~ò~ RECEIVED DEC 16 2003 Alasktl Ojl &: Gas Cons. Commis5'ion I\.rlt;:hot'!ge Scientific Technical Services Scientific Technical Services 7-14B 500292033902 BP Exploration (Alaska) Sperry-Sun Drilling Services 15-DEC-03 MWD RUN 2 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 5 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 8 MW0002699461 S. LATZ SEVCIK/SARBE MWD RUN 13 MW0002699461 S. LATZ SEVCIK/SARBE 33 11N MWD RUN 3 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 6 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 9 MW0002699461 S. LATZ SEVCIK/SARBE RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: . 14E 511 . 314 MSL 0) 64.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.770 9.625 10365.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS EFFECTED BY DRILLING OFF OF AN OPENHOLE WHIPSTOCK WITHIN THE RUN 9 INTERVAL. THE TOP OF THE WHIPSTOCK WAS AT 11750'MD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) WITH SCINTILLATION DETECTORS. THIS WAS A TIE-IN RUN, MADE PRIOR TO PULLING THE LINER. THESE SGRD AND SROP DATA WERE MERGED WITH THE SUBSEQUENT MWD DATA. 5. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH PCG. RUN 2 MILLED THE CEMENT RAMP; RUN 3 MILLED THE WINDOW; AND RUN 4 DRESSED THE WINDOW AND MADE 6' OF NEW HOLE. 6. MWD RUNS 5 - 9, 12 & 13 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) , UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 9 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD PASS DATA OVER THE INTERVAL 11096.5'MD - 10389'MD (SHIFTED BIT DEPTHS)WERE ACQUIRED WHILE POOH AFTER THE COMPLETION OF RUN 9. THESE MAD PASS DATA ARE MERGED WITH THE MWD DATA FOR THIS PRESENTATION. MWD RUN 11 WAS A CLEANOUT TRIP PRIOR TO POSITIONING THE WHIPSTOCK - NO DATA ARE PRESENTED. 7. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN 7-14B ON 15 OCTOBER 2003. THESE PDC DATA WERE PROVIDED TO SSDS BY KURT COONEY (BP) ON 22 OCTOBER 2003. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 8. MWD RUNS 1 - 9, 12 & 13 REPRESENT WELL 7-14B WITH API#: 50-029~39-02. ,. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12500'MD/8914'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . $ RESISTIVITY (EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP File Header Service name.... ........ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 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 FET RPD RPM RPS RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9692.0 9721. 0 10357.5 10357.5 10357.5 10357.5 10357.5 STOP DEPTH 12470.5 12499.0 11755.0 11755.0 11755.0 11755.0 11755.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9692.0 9694.0 9712.0 9716.5 9721.0 9727.5 973 0.0 9735.5 9737.5 9747.5 9763.5 9783.5 9787.5 9799.0 9802.0 9805.5 9809.0 9813.0 GR 9690.5 9692.5 9711. 0 9716.0 9721. 0 9726.5 9731.0 9735.5 9738.0 9745.5 9762.0 9782.5 9787.0 9798.0 9801.5 9805.0 9807.5 9810.0 9830.0 9881.0 9884.5 9905.5 9915.5 9918.5 9923.0 9931.0 9934.0 9936.0 9946.5 9961. 0 9966.5 10007.5 10014.0 10041.5 10046.0 10048.5 10067.0 10090.5 10095.0 10099.0 10103.0 10119.0 10122.0 10124.0 10130.5 10133.0 10137.5 10140.5 10148.0 10167.5 10180.5 10183.5 10185.0 10189.0 10203.0 10211.0 10237.0 10248.5 10280.0 10303.0 10332.0 10350.0 10362.0 10367.5 10375.0 10381.5 10385.0 10405.0 10409.5 10420.0 10423.5 10425.0 10427.5 10459.5 10468.5 10475.5 10482.0 10521.5 10528.5 10534.0 10538.0 10548.5 10558.5 10567.5 10573.5 10581.5 9828.5. 9880.0 9884.0 9905.0 9915.5 9918.0 9922.5 9930.0 9933.0 9935.5 9946.0 9960.0 9965.0 10007.5 10015.5 10041.5 10045.5 10048.5 10065.5 10090.5 10094.0 10098.0 10102.5 10119.0 10122.0 10124.0 10130.5 10133.0 10137.5 10141.0 10148.0 10167.5 10181.0 10183.5 10185.5 10189.5 10202.5 10210.5 10236.5 10247.5 10279.0 10301. 5 10330.0 10349.0 10361. 5 10366.5 10375.0 10381.5 10384.5 10405.0 10408.5 10418.0 10420.5 10421.5 10424.0 10458.5 10466.0 10473.5 10480.0 10518.5 10525.5 10531. 0 10536.0 10546.0 10556.5 10565.0 10571.0 10579.0 . 10590.5 10604.5 10620.5 10626.0 10639.0 10649.5 10654.5 10663.0 10672.0 10675.0 10689.0 10698.0 10701.5 10720.0 10726.0 10728.0 10736.0 10738.5 10743.0 10751.5 10757.5 10762.5 10773.0 10780.0 10792.5 10802.0 10824.0 10830.0 10836.5 10842.5 10846.5 10850.0 10856.0 10868.0 10873.0 10887.0 10893.5 10897.5 10907.0 10909.0 10926.5 10945.0 10950.0 10955.0 10958.5 10964.5 10975.0 10976.5 10984.0 10988.5 10994.0 10999.5 11005.0 11040.0 11060.5 11074.0 11087.0 11114.0 11122.0 11130.5 11138.0 11163.5 11178.5 11230.0 11235.0 11241. 5 11263.5 11266.0 10587.5. 10603.0 10618.5 10623.0 10636.5 10647.0 10652.5 10659.0 10671.0 10674.5 10688.0 10698.0 10700.5 10718.0 10724.5 10726.0 10734.0 10737.5 10743.0 10751.0 10754.5 10760.0 10770.5 10777.0 10789.5 10801.5 10824.0 10828.0 10832.5 10839.0 10844.0 10846.5 10852.5 10864.5 10871.5 10885.5 10891.0 10896.0 10905.0 10907.0 10925.0 10943.5 10948.5 10952.0 10956.5 10962.0 10971.0 10973.5 10980.5 10984.5 10989.5 10996.5 11004.5 11039.0 11060.5 11074.5 11087.0 11112.0 11120.0 11127.5 11134.0 11160.5 11177.5 11228.0 11233.0 11239.5 11263.0 11265.5 . 11325.0 11337.0 11342.0 11349.0 11353.0 11371.5 11377.5 11436.5 11443.5 11491.0 11562.5 11597.5 11610.5 11617.5 11632.5 11641. 5 11648.0 11673.5 11685.0 11722.5 11729.5 11752.0 11762.0 11776.0 11794.5 11796.0 11798.0 11806.0 11811.5 11813.5 11825.0 11829.0 11842.5 11854.0 11861.0 11866.0 11881.5 11897.0 11902.5 11908.5 11929.5 11945.0 11956.5 11995.0 11999.0 12004.5 12019.0 12026.5 12029.0 12039.5 12053.5 12065.0 12067.5 12089.0 12091.5 12115.0 12122.0 12132.0 12145.5 12151. 5 12155.5 12164.5 12169.5 12177.0 12181. 5 12187.5 12193.0 12194.5 11323.5. 11335.0 11340.0 11347.5 11351.0 11371.5 11377.5 11432.5 11439.0 11486.5 11557.0 11592.5 11605.5 11613 . 0 11627.0 11635.5 11643.0 11669.0 11680.0 11718.0 11723.5 11746.0 11759.0 11773.5 11792.5 11795.5 11797.5 11808.5 11813.5 11816.0 11828.0 11833.5 11848.0 11857.0 11863.5 11870.0 11886.0 11904.5 11910.0 11914.5 11936.0 11950.0 11962.5 12002.0 12006.5 12011.0 12026.0 12033.5 12038.0 12049.0 12059.5 12072.0 12074.0 12097.5 12098.5 12119.0 12125.5 12132.5 12144.0 12152.5 12156.5 12164.5 12172.0 12180.5 12184.0 12188.0 12193.0 12195.0 . 12202.5 12212.0 12215.0 12221.5 12239.5 12241.5 12251.5 12255.5 12261.5 12268.5 12270.5 12281.0 12292.5 12300.5 12303.5 12313.0 12327.0 12330.0 12331.0 12334.5 12339.5 12354.0 12366.5 12371.5 12382.5 12386.5 12394.5 12401.5 12411.5 12424.5 12427.0 12433.0 12439.5 12445.0 12447.5 12499.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ # REMARKS: 12203.5. 12213.0 12217.0 12222.0 12239.5 12241.0 12250.5 12253.0 12260.5 12267.0 12270.0 12278.5 12288.0 12298.0 12302.0 12314.5 12326.0 12329.0 12330.5 12337.0 12341.5 12355.5 12368.0 12372.0 12380.5 12384.0 12393.5 12400.0 12412.0 12423.0 12426.5 12432.5 12438.5 12445.0 12448.0 12499.0 BIT RUN NO 1 2 3 4 5 6 7 8 9 12 13 MERGED MAIN PASS. $ . MERGE TOP 9690.5 10120.0 10360.0 10369.0 10375.0 10417.0 10473.0 10855.5 11090.0 11750.5 11910.5 MERGE BASE 10120.0 10360.0 10369.0 10375.0 10417.0 10473.0 10855.5 11090.0 11750.0 11910.5 12499.0 # 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Si"sam 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 9692 12499 11095.5 5615 9692 12499 ROP MWD FT/H 0.04 1861.09 98.0467 5557 9721 12499 GR MWD API 14 379.62 60.8578 5558 9692 12470.5 RPX MWD OHMM 2.89 2000 36.1034 2796 10357.5 11755 RPS MWD OHMM 0.79 2000 38.698 2796 10357.5 11755 RPM MWD OHMM 0.21 2000 43.341 2796 10357.5 11755 RPD MWD OHMM 0.03 2000 80.7955 2796 10357.5 11755 FET MWD HOUR 0.24 99.1 19.4313 2796 10357.5 11755 First Reading For Entire File......... .9692 Last Reading For Entire File.......... .12499 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 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...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RAT $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 9690.5 9721.0 STOP DEPTH 10102.5 10120.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 03-0CT-03 Insite DOWNHOLE SOFTWARE VERJIIt: 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 PCG $ BOTTOM) TOOL TYPE Natural 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: 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT RAT MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 7.75 Memory 10120.0 9690.5 10120.0 . .0 .0 TOOL NUMBER TLG009 3.770 10365.0 Water .00 .0 .0 o .0 .000 .000 .000 .000 .0 145.9 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9690.5 10120 9905.25 860 9690.5 10120 RAT MWD010 FT/H 10 187 163.88 799 9721 10120 GR MWD010 API 14 131.61 54.6627 825 9690.5 10102.5 . First Reading For Entire File......... .9690.5 Last Reading For Entire File.......... .10120 . File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 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...... .03/12/15 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 GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 10103.0 10120.5 STOP DEPTH 10330.0 10360.0 # 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: 05-0CT-03 Insite 7.75 Memory 10362.0 10120.0 10362.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG009 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.770 2665.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): KCL-Biozan 8.50 .0 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: 11.0 17000 .0 . .000 .000 .000 .000 .0 129.0 .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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD020 MWD020 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10103 10360 10231.5 515 10103 10360 ROP MWD020 FT/H 2.17 361. 22 74.845 480 10120.5 10360 GR MWD020 API 15.48 226.74 36.0029 455 10103 10330 First Reading For Entire File......... .10103 Last Reading For Entire File.......... .10360 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 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...... .03/12/15 Maximum Physical Record. ..35 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 10330.5 10360.5 STOP DEPTH 10341.0 10369.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural 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: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O 06-0CT-03 Insite 7.75 Memory 10369.0 10362.0 10369.0 .0 .0 TOOL NUMBER TLG009 3.800 2665.0 KCL-Biozan 8.50 .0 9.5 17000 .0 .000 .000 .000 .000 .0 137.5 .0 .0 Logging Direction....... .411..... . 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. ..0 . Service Order Units FT FT/H API Size 4 4 4 Rep 68 68 68 Name DEPT ROP GR MWD030 MWD030 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10330.5 10369 10349.8 78 10330.5 10369 ROP MWD030 FT/H 0.04 1. 85 0.750556 18 10360.5 10369 GR MWD030 API 19.38 28.88 22.8627 22 10330.5 10341 First Reading For Entire File......... .10330.5 Last Reading For Entire File.......... .10369 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type......... . . . . . . .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10341.5 10369.5 STOP DEPTH 10346.5 10375.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 06-0CT-03 Insite 7.75 DATA TYPE (MEMORY OR REAJlltME) : 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 PCG $ BOTTOM) TOOL TYPE Natural 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: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 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 DEPT ROP MWD040 GR MWD040 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Memory 10375.0 10369.0 10375.0 .0 .0 TOOL NUMBER TLG009 3.770 10365.0 Biozan 8.40 .0 .0 o .0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . Water .0 129.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10341.5 10375 10358.3 68 10341.5 10375 ROP MWD040 FT/H 0.11 255.65 46.7058 12 10369.5 10375 GR MWD040 API 21.13 24.44 22.9264 11 10341.5 10346.5 First Reading For Entire Filtlt....... .10341.5 Last Reading For Entire File.......... .10375 . File Trailer Service name............ .STSLIB.005 service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name. ........... .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 10347.0 10375.5 STOP DEPTH 10389.0 10417.0 # 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: 06-0CT-03 Insite 4.3 Memory 10417.0 10375.0 10417.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER 72829 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 10365.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: Flo Pro 8.50 .0 9.5 MUD CHLORIDES (PPM): tit 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: 19000 9.0 . .000 .000 .000 .000 .0 120.2 .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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD050 MWD050 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10347 10417 10382 141 10347 10417 ROP MWD050 FT/H 0.08 50.25 19.1999 84 10375.5 10417 GR MWD050 API 22.72 57.27 38.4429 85 10347 10389 First Reading For Entire File......... .10347 Last Reading For Entire File.......... .10417 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type.......... . . . . . .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name........... ..STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type................4IIÞ Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 7 . header data for each bit run in separate files. 6 .5000 START DEPTH 10389.5 10417.5 STOP DEPTH 10445.0 10473.0 # 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 GM $ BOTTOM) TOOL TYPE Dual GR # 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.....O Logging Direction................ . Down 07-0CT-03 Insite 4.3 Memory 10473.0 10417.0 10473.0 29.7 45.0 TOOL NUMBER 72829 3.750 10365.0 Flo-pro 8.50 60.0 9.5 19000 9.0 .000 .000 .000 .000 .0 120.2 .0 .0 Optical log depth units. .tIt.... ..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 tit Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD060 MWD060 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10389.5 10473 10431.3 168 10389.5 10473 ROP MWD060 FT/H 0.79 70.05 34.2294 112 10417.5 10473 GR MWD060 API 18.93 77.33 30.4889 112 10389.5 10445 First Reading For Entire File......... .10389.5 Last Reading For Entire File....... ....10473 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name... ......... .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 8 header data for each bit run in separate files. 7 .5000 START DEPTH 10445.5 10473.5 STOP DEPTH 10828.0 10855.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 08-0CT-03 Insite 4.3 Memory . 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 GM $ BOTTOM) TOOL TYPE Dual GR # 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.....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 DEPT ROP MWD070 GR MWD070 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 10855.0 10473.0 10855.0 26.7 68.4 TOOL NUMBER 72829 4.125 10365.0 Flo Pro 8.60 65.0 8.5 18600 8.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 131.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10445.5 10855.5 10650.5 821 10445.5 10855.5 ROP MWD070 FT/H 0.09 125.72 52.7265 765 10473.5 10855.5 GR MWD070 API 19.76 162.6 44.8612 766 10445.5 10828 First Reading For Entire File......... .10445.5 Last Reading For Entire FilJllt....... .10855.5 . File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.009 Physical EOF File Header Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 9 header data for each bit run in separate files. 8 .5000 START DEPTH 10828.5 10856.0 STOP DEPTH 11062.0 11090.0 # 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: 08-0CT-03 Insite 4.3 Memory 11090.0 10855.0 11090.0 75.2 91. 0 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER 72829 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.250 10365.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): Flo Pro 8.60 65.0 8.5 18600 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: . 8.0 . .000 .0 .000 131.0 .000 .0 .000 .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 ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD080 MWD080 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10828.5 11090 10959.3 524 10828.5 11090 ROP MWD080 FT/H 0.7 1113.06 140.587 469 10856 11090 GR MWD080 API 43.04 364.03 82.5238 468 10828.5 11062 First Reading For Entire File......... .10828.5 Last Reading For Entire File.......... .11090 File Trailer Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.010 Physical EOF File Header Service name............ .STSLIB.010 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type.......... . . . . . .LO Previous File Name...... .~LIB.009 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS RPX RPM RPD FET GR ROP $ 10 . header data for each bit run in separate files. 9 .5000 START DEPTH 10357.0 10357.0 10357.0 10357.0 10357.0 11062.5 11090.5 STOP DEPTH 11750.0 11750.0 11750.0 11750.0 11750.0 11750.0 11750.0 # 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 GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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: $ 11-0CT-03 Insite 4.3 Memory 11750.0 11090.0 11750.0 83.3 94.5 TOOL NUMBER 82758 126589 3.750 10365.0 Flo Pro 8.80 65.0 8.5 19200 6.6 .180 .090 .220 .230 70.0 150.0 70.0 70.0 . 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 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 MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10357 11750 11053.5 2787 10357 11750 ROP MWD090 FT/H 1. 5933 1861.09 110.101 1320 11090.5 11750 GR MWD090 API 32.29 379.62 72.7149 1376 11062.5 11750 RPX MWD090 OHMM 2.89 2000 35.6332 2787 10357 11750 RPS MWD090 OHMM 0.79 2000 38.9688 2787 10357 11750 RPM MWD090 OHMM 0.21 2000 43.4935 2787 10357 11750 RPD MWD090 OHMM 0.03 2000 81.0069 2787 10357 11750 FET MWD090 HOUR 0.24 99.1 19.4367 2787 10357 11750 First Reading For Entire File......... .10357 Last Reading For Entire File.......... .11750 File Trailer Service name............ .STSLIB.010 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.011 Physical EOF File Header Service name............ .STSLIB.011 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/12/15 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 12 . .5000 START DEPTH 11750.5 11750.5 STOP DEPTH 11882.5 11910.5 # 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 GM $ BOTTOM) TOOL TYPE Dual GR # 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.....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 . 13 -OCT- 03 Insite 4.3 Memory 11910.0 11750.0 11910.0 85.8 89.6 TOOL NUMBER 72829 3.770 10365.0 Flo Pro 8.70 65.0 8.5 20000 8.0 .000 .000 .000 .000 .0 145.0 .0 .0 service Order Units FT FT/H API seNsam 4 1 4 1 4 1 Code Offset o 4 8 Channel 1 2 3 . Name DEPT ROP GR MWD120 MWD120 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11750.5 11910.5 11830.5 321 11750.5 11910.5 ROP MWD12 0 FT/H 0.05 413.98 69.6951 321 11750.5 11910.5 GR MWD120 API 24.9 240.87 56.2501 265 11750.5 11882.5 First Reading For Entire File......... .11750.5 Last Reading For Entire File......... ..11910.5 File Trailer Service name............ .STSLIB.011 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.012 Physical EOF File Header Service name............ .STSLIB.012 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.011 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 12 header data for each bit run in separate files. 13 .5000 START DEPTH 11883.0 11911.0 STOP DEPTH 12471. 0 12499.0 # 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: 14 -OCT- 03 Insite 4.3 Memory 12500.0 11910.0 12500.0 85.0 94.3 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTT. TOOL TYPE Dual GR # 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.....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 DEPT ROP GR Service Order Rep 68 68 68 Code Units FT FT/H API Size 4 4 4 Nsam 1 1 1 MWD 13 0 MWD 13 0 TOOL NUMBER. 72829 3.770 10365.0 FLO-PRO 8.70 65.0 8.5 19800 7.2 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 .0 155.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11883 12499 12191 1233 11883 12499 ROP MWD130 FT/H 0.79 684.66 83.2175 1177 11911 12499 GR MWD 13 0 API 32.58 239.7 68.8173 1177 11883 12471 First Reading For Entire File......... .11883 Last Reading For Entire File.......... .12499 File Trailer Service name........... ..STSLIB.012 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/12/15 Maximum Physical Record.~35 File Type.......... . . . . . .LO Next File Name.......... .STSLIB.013 . Physical EOF Tape Trailer Service name....... . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/15 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 Date. . . . . . . . . . . . . . . . . . . . .03/12/15 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 --I Sperry-Sun Dr~ng Services LIS sca~ility $Revision: 3 $ LisLib $Revision: 4 $ Fri Dec 12 08:49:08 2003 ~)3' J1~ 11 ~~ î Reel Header Service name..... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/12 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. . . . . . . . . . . . . . . . . . . . .03/12/12 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 Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: MWD RUN 1 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 4 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 7 MW0002699461 B. JAHN EGBEJIMBA / MAD RUN 9 MW0002699461 S. LATZ SEVCIK/SARBE 7-14Bpb1 500292033970 BP Exploration (Alaska) Sperry-Sun Drilling Services 12-DEC-03 MWD RUN 2 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 5 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 8 MW0002699461 S. LATZ SEVCIK/SARBE MWDRUN 10 MW0002699461 S. LATZ SEVCIK/SARBE 33 llN MWD RUN 3 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 6 MW0002699461 B. JAHN EGBEJIMBA / MWD RUN 9 MW0002699461 S. LATZ SEVCIK/SARBE 'r' . 14E 511 . RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 314 MSL 0) 64.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.770 9.625 10365.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS EFFECTED BY DRILLING OFF OF A CEMENT RAMP, THE TOP OF WHICH WAS AT 10352'MD. THE TOP OF THE WINDOW WAS AT 10362'MD AND THE BOTTOM WAS AT 10365.5'MD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) WITH SCINTILLATION DETECTORS. THIS WAS A TIE-IN RUN, MADE PRIOR TO PULLING THE LINER. THESE SGRD AND SROP DATA WERE MERGED WITH THE SUBSEQUENT MWD DATA. 5. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH PCG. RUN 2 MILLED THE CEMENT RAMP; RUN 3 MILLED THE WINDOW; AND RUN 4 DRESSED THE WINDOW AND MADE 6' OF NEW HOLE. 6. MWD RUNS 5 - 10 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) , UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 9 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD PASS DATA OVER THE INTERVAL 11096.5'MD - 10389'MD (SHIFTED BIT DEPTHS) WERE ACQUIRED WHILE POOH AFTER THE COMPLETION OF RUN 9. THESE MAD PASS DATA ARE PRESENTED SEPARATELY. 7. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN 7-14B ON 15 OCTOBER 2003. THESE PDC DATA WERE PROVIDED TO SSDS BY KURT COONEY (BP) ON 22 OCTOBER 2003. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 8. MWD RUNS 1 - 10 REPRESENT WELL 7-14B PB1 WITH API#: 50-029-20339-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF , r 12400lMD/89~SS. . SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . RESISTIVITY (EXTRA RESISTIVITY (SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP $ CURVE MNEMONICS WITH AN 'M' SUFFIX DENOTE MAD PASS DATA. File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 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 FET RPX RPS RPD RPM $ 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 9692.0 9721. 0 11060.5 11060.5 11060.5 11060.5 11060.5 STOP DEPTH 12380.5 12406.5 12298.5 12298.5 12298.5 12298.5 12298.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9694.0 9712.0 9716.5 9721.0 9727.5 9730.0 9735.5 9737.5 9747.5 9763.5 9783.5 9787.5 9799.0 9802.0 9805.5 9809.0 9813.0 GR 9692.5 9711.0 9716.0 9721.0 9726.5 9731.0 9735.5 9738.0 9745.5 9762.0 9782.5 9787.0 9798.0 9801.5 9805.0 9807.5 9810.0 1 , 9828.. 9880.0 9884.0 9905.0 9915.5 9918.0 9922.5 9930.0 9933.0 9935.5 9946.0 9960.0 9965.0 10007.5 10015.5 10041.5 10045.5 10048.5 10065.5 10090.5 10094.0 10098.0 10102.5 10119.0 10122.0 10124.0 10130.5 10133.0 10137.5 10141.0 10148.0 10167.5 10181.0 10183.5 10185.5 10189.5 10202.5 10210.5 10236.5 10247.5 10279.0 10301.5 10330.0 10349.0 10361.5 10366.5 10375.0 10381. 5 10384.5 10405.0 10408.5 10418.0 10420.5 10421.5 10424.0 10458.5 10466.0 10473.5 10480.0 10518.5 10525.5 10531.0 10536.0 10546.0 10556.5 10565.0 10571.0 10579.0 . 9830.0 9881.0 9884.5 9905.5 9915.5 9918.5 9923.0 9931.0 9934.0 9936.0 9946.5 9961.0 9966.5 10007.5 10014.0 10041.5 10046.0 10048.5 10067.0 10090.5 10095.0 10099.0 10103.0 10119.0 10122.0 10124.0 10130.5 10133.0 10137.5 10140.5 10148.0 10167.5 10180.5 10183.5 10185.0 10189.0 10203.0 10211.0 10237.0 10248.5 10280.0 10303.0 10332.0 10350.0 10362.0 10367.5 10375.0 10381.5 10385.0 10405.0 10409.5 10420.0 10423.5 10425.0 10427.5 10459.5 10468.5 10475.5 10482.0 10521. 5 10528.5 10534.0 10538.0 10548.5 10558.5 10567.5 10573.5 10581.5 , , 10587.5. 10603.0 10618.5 10623.0 10636.5 10647.0 10652.5 10659.0 10671.0 10674.5 10688.0 10698.0 10700.5 10718.0 10724.5 10726.0 10734.0 10737.5 10743.0 10751.0 10754.5 10760.0 10770.5 10777.0 10789.5 10801.5 10824.0 10828.0 10832.5 10839.0 10844.0 10846.5 10852.5 10864.5 10871.5 10885.5 10891.0 10896.0 10905.0 10907.0 10925.0 10943.5 10948.5 10952.0 10956.5 10962.0 10971.0 10973.5 10980.5 10984.5 10989.5 10996.5 11004.5 11039.0 11060.5 11074.5 11087.0 11112.0 11120.0 11127.5 11134.0 11160.5 11177.5 11228.0 11233.0 11265.5 11323.5 11335.0 . 10590.5 10604.5 10620.5 10626.0 10639.0 10649.5 10654.5 10663.0 10672.0 10675.0 10689.0 10698.0 10701.5 10720.0 10726.0 10728.0 10736.0 10738.5 10743.0 10751.5 10757.5 10762.5 10773.0 10780.0 10792.5 10802.0 10824.0 10830.0 10836.5 10842.5 10846.5 10850.0 10856.0 10868.0 10873.0 10887.0 10893.5 10897.5 10907.0 10909.0 10926.5 10945.0 10950.0 10955.0 10958.5 10964.5 10975.0 10976.5 10984.0 10988.5 10994.0 10999.5 11005.0 11040.0 11060.5 11074.0 11087.0 11114.0 11122.0 11130.5 11138.0 11163.5 11178.5 11230.0 11235.0 11266.0 11325.0 11337.0 11342.0 11349.0 11353.0 11436.5 11443.5 11491.0 11562.5 11597.5 11610.5 11617.5 11632.5 11641.5 11648.0 11722.5 11729.5 11752.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ # REMARKS: 11340.. 11347.5 11351.0 11432.5 11439.0 11486.5 11557.0 11592.5 11605.5 11613.0 11627.0 11635.5 11643.0 11718.0 11723.5 11746.0 BIT RUN NO 1 2 3 4 5 6 7 8 9 10 MERGED MAIN PASS. $ MERGE TOP 9690.5 10120.0 10360.0 10369.0 10375.0 10417.0 10473.0 10855.5 11090.0 12320.0 . MERGE BASE 10120.0 10360.0 10369.0 10375.0 10417.0 10473.0 10855.5 11090.0 12320.0 12400.5 # 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 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 9692 12406.5 11049.3 5430 9692 12406.5 ROP MWD FT/H 0.04 1861.09 97.8812 5372 9721 12406.5 GR MWD API 14 379.62 66.0517 5378 9692 12380.5 RPX MWD OHMM 6.93 1938.31 36.2703 2477 11060.5 12298.5 RPS MWD OHMM 7.38 213.09 33.4631 2477 11060.5 12298.5 RPM MWD OHMM 8.2 108.72 32.541 2477 11060.5 12298.5 RPD MWD OHMM 15.76 93.38 39.3185 2477 11060.5 12298.5 FET MWD 0.2. HOUR 19.44 1.55388 2477 First Reading For Entire File..... .... .9692 Last Reading For Entire File.......... .12406.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 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...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPM RPD RPS RPX FET RAT $ 2 .60.5 12298.5 and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 10345.0 10358.5 10358.5 10358.5 10358.5 10358.5 10389.0 # MERGED DATA SOURCE PBU TOOL CODE MWD $ STOP DEPTH 11052.5 11064.5 11064.5 11064.5 11064.5 11064.5 11096.5 MAD RUN NO. MAD PASS NO. MERGE TOP 9 1 10343.5 # REMARKS: MERGED MAD PASS. $ # 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O MERGE BASE 12320.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT . 1 68 0 1 . RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10345 11096.5 10720.8 1504 10345 11096.5 RAT MAD FT/H 87 687 389.074 1416 10389 11096.5 GR MAD API 9.76 386.27 58.963 1416 10345 11052.5 RPX MAD OHMM 2.89 2000 31. 2007 1413 10358.5 11064.5 RPS MAD OHMM 0.79 2000 38.3165 1413 10358.5 11064.5 RPM MAD OHMM 0.21 2000 48.3322 1413 10358.5 11064.5 RPD MAD OHMM 0.03 2000 113.393 1413 10358.5 11064.5 FET MAD HOUR 14.65 99.1 36.6589 1413 10358.5 11064.5 First Reading For Entire File........ ..10345 Last Reading For Entire File.......... .11096.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 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...... .03/12/12 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 GR RAT $ 3 header data for each bit run in separate files. 1 .5000 START DEPTH 9690.5 9721.0 STOP DEPTH 10102.5 10120.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 03-0CT-03 Insite 7.75 DATA TYPE (MEMORY OR REALtIIME) : 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 PCG $ BOTTOM) TOOL TYPE Natural 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: 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT RAT MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Memory 10120.0 9690.0 10120.0 .0 .0 TOOL NUMBER TLG009 3.770 10365.0 Water .00 .0 .0 o .0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 145.9 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9690.5 10120 9905.25 860 9690.5 10120 RAT MWD010 FT/H 10 187 163.88 799 9721 10120 GR MWD010 API 14 131.61 54.6627 825 9690.5 10102.5 First Reading For Entire Filtlt....... .9690.5 Last Reading For Entire File.......... .10120 . File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 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...... .03/12/12 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: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 2 .5000 START DEPTH 10103.0 10120.5 STOP DEPTH 10330.0 10360.0 # 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: 05-0CT-03 Insite 4.3 Memory 10362.0 10120.0 10362.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG009 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.770 2665.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: KCL-Biozan 8.50 .0 11. 0 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: 17000 .0 . .000 .000 .000 .000 .0 129.0 .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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD020 MWD020 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10103 10360 10231.5 515 10103 10360 ROP MWD020 FT/H 2.17 361.22 74.845 480 10120.5 10360 GR MWD020 API 15.48 226.74 36.0029 455 10103 10330 First Reading For Entire File......... .10103 Last Reading For Entire File.......... .10360 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/12/12 Maximum Physical Record..65535 File Type... . . . . . . . . . . . . .. Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 . header data for each bit run in separate files. 3 .5000 START DEPTH 10330.5 10360.5 STOP DEPTH 10341.0 10369.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural 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: 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 06-0CT-03 Insite 4.3 Memory 10369.0 10362.0 10369.0 .0 .0 TOOL NUMBER TLG009 3.800 2665.0 KCL-Biozan 8.50 .0 9.5 17000 .0 .000 .000 .000 .000 .0 137.5 .0 .0 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 . Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD030 MWD030 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10330.5 10369 10349.8 78 10330.5 10369 ROP MWD030 FT/H 0.04 1. 85 0.750556 18 10360.5 10369 GR MWD030 API 19.38 28.88 22.8627 22 10330.5 10341 First Reading For Entire File......... .10330.5 Last Reading For Entire File.......... .10369 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 header data for each bit run in separate files. 4 .5000 START DEPTH 10341.5 10369.5 STOP DEPTH 10346.5 10375.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 06-0CT-03 Insite 4.3 Memory 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 PCG $ BOTTOM) TOOL TYPE Natural 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: 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 10375.0 10369.0 10375.0 .0 .0 TOOL NUMBER TLG009 3.770 10365.0 Biozan 8.40 .0 .0 o .0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . Water .0 129.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10341. 5 10375 10358.3 68 10341.5 10375 ROP MWD040 FT/H 0.11 255.65 46.7058 12 10369.5 10375 GR MWD040 API 21.13 24.44 22.9264 11 10341.5 10346.5 First Reading For Entire File......... .10341.5 Last Reading For Entire FilJllt....... .10375 . File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name....... ... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 7 header data for each bit run in separate files. 5 .5000 START DEPTH 10347.0 10375.5 STOP DEPTH 10389.0 10417.0 # 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: 06-0CT-03 Insite 4.3 Memory 10417.0 10375.0 10417.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER 72829 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 10365.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): Flo Pro 8.50 .0 9.5 19000 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: . 9.0 . .000 .0 .000 120.2 .000 .0 .000 .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... ..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 Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD050 MWD050 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10347 10417 10382 141 10347 10417 ROP MWD050 FT/H 0.08 50.25 19.1999 84 10375.5 10417 GR MWD050 API 22.72 57.27 38.4429 85 10347 10389 First Reading For Entire File......... .10347 Last Reading For Entire File.......... .10417 File Trailer Service name. ........... .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type........... . . . . .LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .4ItLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 8 . header data for each bit run in separate files. 6 .5000 START DEPTH 10389.5 10417.5 STOP DEPTH 10445.0 10473.0 # 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 GM $ BOTTOM) TOOL TYPE Dual GR # 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.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet 07-0CT-03 Insite 4.3 Memory 10473.0 10417.0 10473.0 29.7 45.0 TOOL NUMBER 72829 3.750 10365.0 Flo-pro 8.50 60.0 9.5 19000 9.0 .000 .000 .000 .000 .0 120.2 .0 .0 Data Reference Point.... .4IÞ.... ..Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order DEPT ROP MWD060 GR MWD060 Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10389.5 10473 10431. 3 168 10389.5 10473 ROP MWD060 FT/H 0.79 70.05 34.2294 112 10417.5 10473 GR MWD060 API 18.93 77.33 30.4889 112 10389.5 10445 First Reading For Entire File......... .10389.5 Last Reading For Entire File.......... .10473 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.009 Physical EOF File Header Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 9 header data for each bit run in separate files. 7 .5000 ST~T DEPTH 104415.5 10473.5 STOP DEPTH 10828.0 10855.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 08-0CT-03 Insite 4.3 Memory 10855.0 . 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 GM $ BOTTOM) TOOL TYPE Dual GR # 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.....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. ..0 Name Service Order DEPT ROP MWD070 GR MWD070 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 10473.0 10855.0 26.7 68.4 TOOL NUMBER 72829 4.125 10365.0 Flo Pro 8.60 65.0 8.5 18600 8.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 131.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10445.5 10855.5 10650.5 821 10445.5 10855.5 ROP MWD070 FT/H 0.09 125.72 52.7265 765 10473.5 10855.5 GR MWD070 API 19.76 162.6 44.8612 766 10445.5 10828 First Reading For Entire File......... .10445.5 Last Reading For Entire File.......... .10855.5 . . File Trailer Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.010 Physical EOF File Header Service name............ .STSLIB.010 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.009 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 10 header data'for each bit run in separate files. 8 .5000 START DEPTH 10828.5 10856.0 STOP DEPTH 11062.0 11090.0 # 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: 08-0CT-03 Insite 4.3 Memory 11090.0 10855.0 11090.0 75.2 91. 0 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER 72829 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.250 10365.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Flo Pro 8.60 65.0 8.5 18600 8.0 RESISTIVITY (OHMM) AT ~PERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 . .0 131.0 .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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD080 MWD080 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10828.5 11090 10959.3 524 10828.5 11090 ROP MWD080 FT/H 0.7 1113 .06 140.587 469 10856 11090 GR MWD080 API 43.04 364.03 82.5238 468 10828.5 11062 First Reading For Entire File......... .10828.5 Last Reading For Entire File.......... .11090 File Trailer Service name............ .STSLIB.010 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.011 Physical EOF File Header Service name............ .STSLIB.011 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.010 . . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 11 header data for each bit run in separate files. 9 .5000 START DEPTH 11060.5 11060.5 11060.5 11060.5 11060.5 11062.5 11090.5 STOP DEPTH 12292.5 12292.5 12292.5 12292.5 12292.5 12275.0 12320.0 # 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: 11-0CT-03 Insite 4.3 Memory 12320.0 11090.0 12320.0 83.3 94.5 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER 82758 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 10365.0 # 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: Flo Pro 8.80 65.0 8.5 19200 6.6 .180 .090 .220 .230 70.0 150.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ .4IÞ......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 MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11060.5 12320 11690.3 2520 11060.5 12320 ROP MWD090 FT/H 0.95 1861.09 97.4855 2460 11090.5 12320 GR MWD090 API 22.3 379.62 76.7185 2426 11062.5 12275 RPX MWD090 OHMM 6.93 1938.31 36.388 2465 11060.5 12292.5 RPS MWD090 OHMM 7.38 213.09 33.5417 2465 11060.5 12292.5 RPM MWD090 OHMM 8.2 108.72 32.6045 2465 11060.5 12292.5 RPD MWD090 OHMM 15.76 93.38 39.3655 2465 11060.5 12292.5 FET MWD090 HOUR 0.2 19.44 1.55321 2465 11060.5 12292.5 First Reading For Entire File......... .11060.5 Last Reading For Entire File.......... .12320 File Trailer Service name............ .STSLIB.011 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.012 Physical EOF File Header Service name............ .STSLIB.012 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type......... . . . . . . .LO Previous File Name...... .STSLIB.011 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 12 header data for each bit run in separate files. 10 .5000 # FILE SUMMARY VENDOR TOOL CODE GR ROP $ . START DEPTH 12275.5 12320.5 STOP DEPTH 12374.5 12400.5 # 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 GM $ BOTTOM) TOOL TYPE Dual GR # 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................ ..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 . 11-0CT-03 Insite 4.3 Memory 12400.0 12320.0 12400.0 90.6 92.8 TOOL NUMBER 72829 3.770 10365.0 Flo Pro 8.70 65.0 8.5 20000 6.2 .000 .000 .000 .000 .0 152.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 GR MWD100 FT/H API . 4 1 68 1 68 2. 3 4 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12275.5 12400.5 12338 251 12275.5 12400.5 ROP MWD100 FT/H 1.37 103.32 47.6634 161 12320.5 12400.5 GR MWD100 API 112.45 161. 35 131. 372 199 12275.5 12374.5 First Reading For Entire File......... .12275.5 Last Reading For Entire File.......... .12400.5 File Trailer Service name............ .STSLIB.012 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.013 Physical EOF File Header Service name............ .STSLIB.013 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/12 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.012 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX RAT $ 13 header data .5000 9 1 START DEPTH 10343.5 10358.0 10358.0 10358.0 10358.0 10358.0 10388.5 # 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): for each pass of each run in separate files. STOP DEPTH 11052.0 11064.5 11064.5 11064.5 11064.5 11064.5 11096.0 11-0CT-03 Insite 4.3 Memory 11096.5 10389.0 11096.5 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: . # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # 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................ ..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 83.3 94.5 . TOOL NUMBER 82758 3.770 10365.0 Flo Pro 8.80 65.0 8.5 19200 6.6 .180 .090 .220 .230 70.0 150.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD091 FT/H 4 1 68 4 2 GR MAD091 API 4 1 68 8 3 RPX MAD 0 91 OHMM 4 1 68 12 4 RPS MAD091 OHMM 4 1 68 16 5 RPM MAD091 OHMM 4 1 68 20 6 RPD MAD 0 91 OHMM 4 1 68 24 7 FET MAD 0 91 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10343.5 11096 10719.8 1506 10343.5 11096 RAT MAD091 FT/H 87 687 388.64 1416 10388.5 11096 GR MAD091 API 9.76 386.27 58.9537 1418 10343.5 11052 RPX MAD091 OHMM 2.89 2000 32.7899 1414 10358 11064.5 RPS MAD091 OHMM 0.79 2000 39.8575 1414 10358 11064.5 RPM RPD FET MAD091 OHMM MAD091 OHMM MAD091 HOUR 0.21. 0.03 14.65 2000 2000 99.1 49.8179 114.126 36.5386 1414 1414 1414 .10358 10358 10358 11064.5 11064.5 11064.5 First Reading For Entire File......... .10343.5 Last Reading For Entire File.......... .11096 File Trailer Service name............ .STSLIB.013 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/12/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.014 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/12 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 Date. . . . . . . . . . . . . . . . . . . . .03/12/12 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