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Home My WebLink About202-106 ( Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O.2. - 1 Q 0 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~escan Needed 111111111111111111 R]pCAN \7Í Color Items: 0 Greyscale Items": D~ITAL DATA v6 Diskettes, No. I 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: Scanning Preparation I x 30 = ~ 0 0 Other::. Dateq B1;' Lf /5/ 1M P 1111111111111111111 Date: c: ~. tJlf /5/ rnP + I t.t = TOTAL PAGES 't.~ ~a~~~tC¡¡;i? Ibff; I~¡;s~;t: NOTES: BY: Helen ~ri~ ) Project Proofing BY: Helen ~.~. BY: Helen~ Production Scanning Stage 1 Page Count from Scanned File: 1f5 (Count does include "/sheet) Page Count Matches Number in Scanning Preparation: V YE~ NO Helen e Date: Cf 3D 0 'f /5/ vwf I . YES NO BY: Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Helen Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc STATE OF ALASKA ALASKA~ AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~ 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ~ Abandoned ^ Suspended 20AAC 25.105 zoAa,c zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. e ass: ~ Developm~~~~ploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. , 6/22/2009 12. Permit to Drill Number 202-106 309-100 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 07/26/2002 13. API Number 50-029-21770-60-00 4a. Location of WeU (Governmental Section): Surface: ' ' 7. Date T.D. Reached 07/28/2002 14. Well Name and Number: PBU 07-28AL1 394 FNL, 339 FEL, SEC. 33, T11 N, R14E, UM Top of Productive Horizon: 360' FSI., 1815' FEL, SEC. 21, T11 N, R14E, UM g. KB (ft above MSL): 53.25' Ground (ft MSL): 22' 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1382' FSL, 3320' FEL, SEC. 21, T11N, R14E, UM 9. Plug Back Depth (MD+ND) 11896' 8994' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 675842 y- 5950523 Zone- ASP4 10. Total Depth (MD+~/D) 13725' 8969' 16. Property Designation: ADL 028309 & 028306 TPI: x- 674212 y- 5956521 Zone- ASP4 Total Depth: x- 672682 - 5957508 Zone- ASP4 11. SSSV DeN A(MD+ND) 17. Land Use Permit: y 18. Directional Survey ^ Yes ~ No Submit ele r ni nd rin d information r 20 AA 2. 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, MGR, CCL 22. CASING, LINER AND CEMENTING RECORD CASING SETfING DEPTH MD SETTING DEPTH ND HOLE AMOUNF ' WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PUIIED 20" 91.5# H-4 Surface 110' urface 110' 3" 253 # Pole t ~-~~~ 7 / L- 1~ ff8 ~ ~]- /" 3000 sx CS III, 600 sx'G'; Top Job: 200 sx CS I 9-5/8" 47# L-8 Surf 93' Surfa 804 ' 12-1/4" 75 sx CI s'G' 4 sx I 7" 26# L- 9847' 1 1' 79 2' 837 ' 8-1/2" 17 sx Cla s'G' 4-11" 12. # 1 419' 12 ' 1' 9' 4 1 x I '' 2-7/8" 6.16# L-8 12413' 13725' 8990' 8969' 3-3/4" Uncemented lotted Lin r 23. Open to production or inject ion? ^ Yes ~ No 24. Tueir~c RecoRo If Yes, list each i (MD+TVD of To & Bottom; Pe nterval open rForation Size and Number): $IZE ~EPTH .SET MD PACKER SET MD p 4-1/2", 12.6#, L-80 10401' 10346' MD ND MD TVD 2-7/8", 61.6#, L-80 11930' - 12410' 12410' ZS. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED b~~~;~~~ ~u~ e, ~,~ ~~~~ 11896' SetWhipstock ~; 11896' Pumped 07-286 Liner Cement 06/29/09 (P&A) (See 07-286 Completion Report for details) ZB. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: PRO~ucT~oN FoR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Cn~cuu~Te~ 24-HouR RnTe~ OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s A uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per,_20 A,~ 71. } c~~~~~~-rin~ None ,~- -09 ,~aG~~~ ~~~~~~~~~~~ JUL ~ ~ 2f~0~ ' re Form 10-407 Revised 02I2007 CONTINUED ON REVERSE ` M ~` ~~ .~j~ ~ a 2~~9 ~~~~ ~,~,~~ /' .r~~ f' V ZH. GEOLJGIC MARKERS ~LIST ALL FORMATIONS AND MA RS ENCOUNTERED~: 29. FORMATION TESTS NAME M 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. Kicked off in Zone 1A and None stayined in Zone 1A 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. Si d ~~1~ '~ ' gne Title Drilling Technologist Date 0 Terrie Hubble PBU 07-28AL1 202-106 309-100 Prepared By Name/Number. Terrie Hubble, 564-4628 Drilling Engineer: Cha-'les Reynolds, 564-5480 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 all types of lands and leases in Ataska. 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. Irena 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). 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. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. ITen~ 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed descriptiort and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only u • 07-28A / 07-28AL1, Well History (Pre Rig Sidetrack) Date Summary 3/24/2009 T/I/O = SSV/50/vac. Temp = SI. MITOA TO 2000 psi w/triplex PASSED (Pre-CTD). OA FL C~3 108' (7bbls). A/L disconnected. Used 6.9 bbls diesel to pressure OA to 2000 psi. OA lost 0 psi in 1 st 15 min and 20 psi in 2nd 15 min. Repressured OA to 2000 psi. OAP lost 0 psi in 1 st 15 min and 10 psi in 2nd 15 min for a total loss of 10 psi in 30 min. No change in IAP. Bled OAP to 0 psi. Final WHPs = SSV/50/0. SV, W V, SSV = C. MV = O. IA, OA = OTG. NOVP. 4/15/2009 WELL SHUT IN ON ARRIVAL. CURRENTLY RIH W/ 2.25" CENT & SAMPLE BAILER. 4/16/2009 DRIFTED W/ 2.25" CENT, S-BAILER TO DEV. AT 11,972' SLM. (no sample) LEFT WELL SHUT IN -- TURNED OVER TO DSO. 4/18/2009 T/I/0=2300/0/0 Temp=Sl Load Tbg (Pre CTD) Pumped down Tbg with 3 bbls of ineth followed with 200 bbls of crude to load for upcoming E-line job. FWHP's=Vac/0/520. SV, WV, SSV Shut. MV, IAV, OAV Open. 4/18/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/0=0/0/580 JET CUT 2-7/8" LINER STRADDLE WITH 2.125" SLB POWERCUTTER AT 11930'. WELL SHUT IN ON DEPARTURE. FINAL T/I/O = 0/0/0 JOB COMPLETE. 4/20/2009 T/I/0= 0/0/0 Pressure test tree valves to 5,000 psi. Pre Nordic. 5/4/2009 Service the tree 30%. Pressure tested swab at 5000 p.s.i. for 5 minutes, and it bled down 100 p.s.i. Pumped open SSV and pressure tested wing and master at 3000 p.s.i. for 5 minutes, and it bled down 100 p.s.i. All valves are in the closed position, flagged and master is locked out. 6/16/2009 T/I/0=0/0/0. Set 4-1/16" ISA BPV thru tree, pre Nordic 1. 1-2' ext used, tagged C~ 96". No problems. Page 1 of 1 . • RP Legal Well Name: 07-28 Common Well Name: 07-28 Spud Date: 1/22/1988 Event Name: REENTER+COMPLETE Start: 6/18/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase ' ' Description ofi Opera#ions 6/19/2009 00:00 - 10:30 10.50 MOB P PRE Move rig from G-16A to DS 07-28B. 10:30 - 13:00 2.50 RIGU P PRE Accept rig at 10:30. NU BOP. PU reel 13:00 - 15:00 2.00 BOPSU P PRE TEST BOP. Witnessing test waived by Bob Nobel of AOGCC. Install hard line in reel. 15:00 - 21:30 6.50 BOPSU P PRE Continue testing BOP. C/O B/S seais and grease HCR. Good test on all valves. 21:30 - 21:45 0.25 BOPSU P PRE SAFETY MEETING, re: MU & PT lubricator, puil BPV. 21:45 - 23:30 1.75 RIGU P PRE Pull BPV with lubricator. 23:30 - 23:45 0.25 RIGU P PRE SAFETY MEETING, re: Pulling coil across 23:45 - 00:00 0.25 RIGU P PRE RU to pull coii. 6/20/2009 00:00 - 01:45 1.75 RIGU P PRE Pull coil across. Install Baker slip on connector. PT and puil test CTC. PT hardline to tiger tank to 3000 psi. 01:45 - 03:00 1.25 RIGU P PRE RU to pump slack out of the coil. Pump 359' of eline out of coil. 03:00 - 04:00 1.00 BOPSU P PRE Pressure Test Inner Reel Valve 04:00 - 04:15 0.25 FISH P DECOMP SAFETY MEETING, re: PU Fishing Assembly 04:15 - 05:15 1.00 FISH P DECOMP PU Fishing Assembly with 4" GS Spear, Hyd Discon., Bi-Directional Jar, DBPV, & 2 jts 2-3/8" PH6. 05:15 - 10:00 4.75 FISH P DECOMP RIH no retums. Pumping 1.03 bpm. 55psi.. At 10300 up wt 49.5K, Dw Wt.20K. Circulate 39 bbl hi vis pill to perforations displace with 80 KCL ~ 2.57 bpm. Attempt to latch. Well on vac. Fluid rate sucking out of CT possibly preventing GS from latching up. Fill across the top of well allow CT to "U" tube. PU I wt 47 K. Weli Fuli 1.57/ 1.12 bpm. After multiple attempts No I ~ latch up . POH 10:00 - 12:00 2.00 FISH P DECOMP POH. I 12:00 - 13:30 1.50 FISH N DECOMP GS spera has 360 degree ring mark on nose 2.5" in diameter. Discuss with PE decide to RU slickline. Wait on LIB. 13:30 - 15:00 1.50 FISH P DECOMP RU slick line. Wait on LIB, Wait on angle drive for counter. 15:00 - 17:30 2.50 FISH P DECOMP Wait LIB . LIB not usable. Decide to run GS on slickline. 17:30 - 21:00 3.50 FISH P DECOMP Run 4" GS on slickline. Latch on to fish successfully. Jar up to release. POH LD slickline tools. RD slickline 21:00 - 21:15 025 FISH P DECOMP SAFETY MEETING, re: PU Fishing Assembly w/ Slickline 4" GS. (Shear down to release) 21:15 - 21:45 0.50 FISH P DECOMP PU Fishing Assembly with 2 jts 2-3/8" PH6, DBPV, Bi-Directional Jar, Hyd Discon., and 4" Slickline GS Spear. 21:45 - 23:30 1.75 FISH P DECOMP RIH 23:30 - 00:00 0.50 FISH P DECOMP Up Wt = 50k# ~ 10,200'. Fish Wt should be -9500#. Latch onto Fish ~ 10,402'. PU to 68k# 3 times; fish is not coming. PU to 68k# & Jar up; Jar up total of 5 times to free fish. 6/21/2009 00:00 - 02:15 2.25 FISH P DECOMP POOH with Fishing Assy. 02:15 - 02:30 0.25 FISH P DECOMP PJSM for LD of fishing BHA & 2-7/8" liner 02:30 - 05:45 3.25 FISH P DECOMP Stand back injector & LD fishing BHA & 2-7/8" liner. 05:45 - 09:00 3.25 EVAL N WEXIT Waiting on Slickline unit to complet activity on 7-14. 09:00 - 09:15 0.25 EVAL P WEXIT PJSM for RU of slickline. 09:15 - 09:45 0.50 EVAL P WEXIT RU slickline 09:45 - 10:30 0.75 EVAL P WEXIT RIH with 2.85 WL drift to top of liner fish at 11916 WLM'. 10:30 - 11:05 0.58 EVAL P WEXIT POH with drift. 11:05 - 11:50 0.75 EVAL P WEXIT LD drift and PU caliper. 11:50 - 13:05 1.25 EVAL P WEXIT RIH with caliper log. 13:05 - 13:33 0.47 EVAL P WEXIT Wait for fingers to open. rnniea: weai~u~a 3:V0:3/ rm ~ • BP Page 2 e~ Operations Summary Report Legal Well Name: 07-28 Common Well Name: 07-28 Spud Date: 1/22/1988 Event Name: REENTER+COMPLETE Start: 6/18/2009 End: Contractor Mame: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 6/21/2009 13:33 - 14:12 0.65 EVAL P WEXIT 14:12 - 15:30 1.30 EVAL P W EXIT 15:30 - 16:30 1.00 EVAL P W EXIT 16:30 - 17:00 0.50 EVAL P W EXIT 17:00 - 18:50 1.83 EVAL P WEXIT 18:50 - 21:00 2.17 EVAL P WEXIT 21:00 - 21:25 0.42 EVAL P W EXIT 21:25 - 22:15 0.83 EVAL P W EXIT 22:15 - 00:00 1.75 EVAL P WEXIT 6/22/2009 00:00 - 00:15 025 WHIP P WEXIT 00:15 - 00:50 0.58 WHIP P WEX~T 00:50 - 01:30 0.67 WHIP P WEXIT 01:30 - 04:40 3.17 WHIP P WEXIT 04:40 - 05:00 0.33 WHIP P 05:00 - 08:00 3.00 STWHIP P 08:00 - 09:00 1.00 STWHIP P 09:00 - 11:00 2.00 STWHIP P 11:00 - 11:35 0.58 STWHIP P 11:35 - 11:50 0.25 STWHIP P 11:50 - 12:05 0.25 STVVHIP P 12:05 - 12:30 0.42 STWHIP P 12:30 - 00:00 I 11.501 STWHIPI P W EXIT WEXIT WEXIT W EXIT W EXIT W EXIT WEXIT W EXIT W EXIT LOG out of hole 50' min. to 10,000. POH. ~ 150 ft/min. LD memory caliper. RD slickline unit. PU WS drifting Assy. Drift hole for WS to 11,930' POH Conduct PJSM for LD of WS drift BHA while POH LD WS drift BHA PJSM for Pumping slack & cutting coil Pump slack & cut coil Cut 375' of coil MU SLB CTC & test PJSA for PU of WS setting BHA PU WS BHA Test Baker tools ~ surface RIH with WS Log tie in -9' Start CCL Log ~ 11,592' to 11,911' Set WS 45deg LOHS ~ 11,911', Pressured up to 1500psi & set down W/2000k1bs TOWS C«~ 11,895' PT WS packer to 2,OOOpsi Swap well over to Milling fluid 2%KCL W/ 2ppb Biozan ~ 2.6bpm POH LD WS running tools. RIH Tag XN at 10 394' uncorrected. Mill XN nipple. 2.53/2.61 bpm ~ 1860 FS= 1760 psi. 2 stalls total. PU ream thru. Pu Run thru dry No problem. RIH to 11600'. Tie - in -7 correction RIH tag WS at 11896. 2.49/2.56 bpm 1900 psi Start time milling from 11894.4, See MW at 11894.5 get pattern established. Mill per time schedule .1ft per 6 min. time depth circ pressure DWOB 13:15 11894.5 2355 1.47 Start of continuous motor work. 14:04 11895.3 2208 1.61 15:05 11895.7 2175 1.82 16:15 11896.6 2205 2.90 17:10 11897.0 2219 3.38 ,19:10 11898.0 2216 3.76 Stacking weight, PU. FS = 1970. Mill from 11896' with 300-400psi of motor work. 21:00 11897.7 2360 3.30 21:50 11898.3 2260 3.42 22:00 11898.4 2250 3.42 22:35 11898.9 2305 4.01 22:50 11899.0 2280 4.01 23:30 11899.1 2285 3.95 rnncea: oicaic~vy o.voai rm NELLHEAD= FhAG IC'NAT(7R - AXELSOIV :B. F1.EV = 53.25` 3F. ELE1/ _ .~A (A} - 1488' A~x Ang~ = 9fi° ~ 1 ZQ28' ~tutn MD = 11559' Ydtuttr TVL3 = $8Qb' SS DRLG DRA~ 20"' COAIDL~Ct~R, 91.S~I. Ft 40, ~ =18.124" 3-318" CSG, 6$#, K-5~i (i 10tM1i1'), ~3 = 12.A9.ri" _ ____-- 13-3i8" CSG, 72#, L-80, W= 12.347" 3ZS2' ~it'1i~UCi1 ~~ = ~.~~`~ ~ "~"~,~J~~t ~~L.~EQ OtE~T SE~LRT BUSH~NG ~TOP ~F' 7" LNR ~-~ 9847 9-5/8" CSG, 47#, L-8Q, ID = 8.B81 " mili c~u# w indow "(i PERFQRATIU~! SlllhAhAARY E2EF La!G: E3FIC~ OAltl~f9!?l88 A h~LE AT TOP PERF; 94' ~ 12~2fl' Abte: Refer to Rrcrduction BB for h~storical pert data S~E ' SPF INTERVRL L3pnISc~ DATE ~^ s sz~2o-~~a~a ~ €rzra~r~s ~~ s ~ zsza~ ~~1 a ~ ~~rra~ r~s ~" 6 134&0-13540 O U7tE>'~ lf}9 ~~~`~ ~~ ~{~~{ WN BEI.C)W IBP. NE#!~ WELI_BVRE NtlT w ,4-1/2" 1BG, i2.~#. L-SU, •U152 bpf, lD = 3.9~8" ~--j '[(1~401~ j 7" LNR, 26#, L-80,. .03$3 bpf, ID - 5.276" 1~~61 ~ ~ TOP 3-1 /2„ 7C 3-3/96" X 2-7i8" LNf2 E-[ 1"15{J6' I 4-1 !2" TC)GK i flF 2-7l8" lNF2-CUT [ "[193(}' 11955`-12294' PERFS ~2-7lS" LNR, 6.16#, L-8{I, .QObS bpf, IQ = 2.372" ~ ~ 4-1 i?" LNR, 12.6#, L-8Q. .0152 bpf. ~= 3.g58" ~ ~e ~J ~4-1/2" CPkMGO SSSV N~, tD = 3.813" [ GA S LIFT' NW NDRELS S7 AI~ TVL1 DEV 7YPE VLV LATGH PORT DATE 1 38A~ 3~413 39 MMG €~4(Y RK 0 04/07 /08 2 74Q8 6Q~9 42 NAUIG DNh' RK 0 04/01/08 3 9743 7850 38 IWUI~ EMAY RK ff 44Idi /08 $$e~.7` --~9-518" x 8-114" BKI~ ZXP FItF2, ID - 7 500" 9881. $.s~ ~° sx~ ~wc ~~~, ~ = s.aso# 9$&7` 8.3i 3" X 7" XO, ID ~ 6.184" -~ 1Q~6' ~-W(7" X 4i12" BKR SB-3 PKR, ID =3.875., 14$79' 4112' NES XN N#', ID rr~iled tv 3.8t~.. 10$95' T' X 5-3/4" 8KR ZXP PKR w ~ ~.~ t ~~ ~~cic, i~ = a,~o„ '! 0401' 41 !2" WLEG, lt} = 3.958" ~~ ~tac~ rr ~vo~r ~occ~r~ 1040$~ T' X 5" t~AC HGR, IL} = 4.~0" '{ i?d.1 ~" 5" X 41l2" XO, ID = 3.937" 115Q0' 4-112" KB PKR WJ SEAL STEM, IQ = 2.377" 11506' 3-1/2" DEPLOYMQVT SLV, ID = 3.00" 9'15'13` N~esi out bushing iD = 2_30" 13739' PBTD ~$'~' 3-3116 x 2-718 XO, ID = 3.19" 'I24QT 1-'14-1/2" X 2-7t8" T1W KS A I~GI-IOR , ID = 2.371" 07-28A DATE ' T2EV BY CON~ITS DATE REV BY CON~TS PlZUDHOE BAY UM1IIT tt61201$8 ' T~t3WAN 41 OI~CsWAL CCIMP~ETION WEtI: 07-288 tt8hl8197 D141 ~[[~TRACK (0?-28A) ~MR ~: it7f31/02 Ni~1~C 1 +CTQ St[~TRAGK Q?•28AL.1 API h[o: 5t1-Q29-2177~-tl2 tt7l~2/D9 NOfif]IG '[ CTD S[t~TRAGK SD7-286~ SEG 33, T11 ht, R14E, 394' FM1IL 8~ 339' FEL Q7104f~ ?iSV DRLG HO GORRECTIONS 8R F~cntorattot~ fAlaskal • `J~lff~ L[~ ~~~~ ~~k~~`~, AI;ASSA ou Alum c~As CO1~T5ERQATIOI~T COAinIISSION John McMullen Engineering Team Leader BP Exploration Alaska Inc. • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 276-7542 PO Box 196612 Anchorage AK 99519-6612 ~ ~., ` Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-28AL1 Sundry Number: 309-100 Dear Mr. McMullen: 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, Daniel T. Seamount, Jr. j~ `f Chair DATED this ~ day of March, 2009 Encl. !~ STATE OF ALASKA "~ ~r 1~~ ~~ 1 ~~3'~ ALA OIL AND GAS CONSERVATION COMI'~ION ~~ °` ~,ti'~i 3 ~ APPLICATION FOR SUNDRY APPROVAL 'BAR 1 ~ ~,Y I i~. 20 AAC 25.2so =~Jask~ .~:~ ., _ 1. Type of Request: ®Abandon - ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Exte~is~OQnCa?f/~~R ~ , t~LJ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Sus~l 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 202-106 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21770-60-00 - 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 07-28AL1- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028309 & 028306- 53.25' 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): 13725' ~ 8969'- 13725'- 8969' - None None in Len h i MD TVD B rst olla Structural 11 2 11 11 14 47 rf 2 1' 13-3/8" 3291' 2995' 345 1 5 In rm i 9-5/8" 9993' 804 ' 6870 476 Pr i n Liner 714' 7" 9 47' - 1 61' 7932' - 8 79' 724 5410 Liner 1978' 4-1/2" 10419' - 12 7' 8313' - 89' 84 0 7500 'n -7/ " 1241 ' - 1 72 ' 1 4 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted: 12417' -13691' 8990' - 8968' 4-1/2", 12.6# L-80 10401' Packers and SSSV Type: 7" x 4-1/2" Baker'SB-3' packer; Packers and SSSV MD (ft): 10346 ; 2-7/8" Straddle Assembly 10392' -.12410' 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: March 20, 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 Charles Reynolds, 564-5480 Printed Name John cMu en Title Engineering Team Leader >>> Prepared By Name/Number: Signature Phone 564-4711 Date3 J7 O Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: _ ~©l Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~5`'~ ~C3.'+~"~.'>"T' ~a~V~~ i~\~`~'~`'~~1~ ~.t~h~1\U~. R~~ Subsequent. Form Required: f~O~ APPROVED BY ~ ~ COMMISSIONER THE COMMISSION Date A roved B : Form 10-403 Reblsed 06/2006 ~ y Submit In Duplicate • To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Chartes Reynolds CTD Engineer Date: March 11, 2009 Re: 07-28B Sundry Approval CC: Well File Sondra Stewman/Terrie Hubble • by Sundry approval is requested to abandon the existing 07-28A and 07-28AL.1 completions.. The parent well 07-28A was rotary sidetracked in Aug 1997 to Zone 1 A. Over half of the perfs were shot in poor quality sands or the Kavik shale. Production began at solution GOR and slowly rose un#il cycling began a year and a half later. It was a good cycle well with 40% on time. The lateral leg, 07-28AL1, was coil sidetracked from well 07-28A in Aug 2002. The lateral leg was drilled with an open junction (<10') in Zone 1A at _12400' MD and completed with slotted liner. The perfs in the parent well, 07-28A, up .hole of this junction were shot in/near the Kavik shale and would not produce. These perfs were tested after the whipstock was set prior to drilling the lateral leg in July 2002, and the well would not flow even when nitrogen lifted. 07-28AL1 was completed with a 2-7/8" straddle with a slickline-run toggle plug allowing flow from the parent, lateral, or commingled flow. At the time of drilling, the parent well was cycling with a moderate GOR. The commingled new leg increased the oil rate and signi#icantly decreased the GOR. The toggle plug was first run in March 2003 when the GOR increased above the marginal level and allowed only the lateral to produce. Production was toggled between the parent and Lateral to keep rates under marginal GOR for a couple years. During that time several modifications were made to the toggle due to difficulties pulling/running, but a videolog in Oct 2004 confirmed the liner top was not damaged. From Jan 2005 to Jan 2007, the toggle only flowed the lateral leg until the well was shut-in for high GOR (low oil rate). The toggle was switched to the parent on Feb 2007 with disappointing results after more than 2 years of shut-in time. The well cycled until the toggle switched production back to the lateral in Dec 2007. The oil rate fell rapidly and hit marginal GOR within 2 weeks. Finally, the toggle was pulled in March 2008 allowing commingled flow. The well is now producing above marginal GOR with minimal healing. During CTD screening in March/April 2008 the well received passing MIT-IA, MIT-OA, PPPOT-T & PPPOT-IC. A caliper indicated the tubing was in good-to-poor condition with a maximum wall penetration of 53%. The CTD screening was redone in Feb 2009 and a caliper was run into the 2-7/8" straddle in anticipation of a cut and pull. The liner is in good condition. REASON FOR SIDETRACK: Both completions, 07-28A and 07-28AL1, produce well above the marginal GOR. Sidetracking from this well will enable production of Zone 1 A reserves from within another portion of the reservoir that would otherwise remain at risk. It will also allow fora future sidetrack from the newly drilled lateral to recover other remaining reserves. ~~~~ 7/~ %it.c~ie`~ nr.s ~~~/ ;~19~e S~o~°o y ult~"~''~ ~«°~~r~ ~'°,~ `~~3 l,~ip~ r~~ S .~ho~ %H 1 i~ 'r ` ~~r7 Pre-Rig Work: (Scheduled to beg~n March 20, 2009) • 1. MIT-OA 2. .Drift well for jet cutter to 11,950' 3. Jet cut 2-7/8" straddle liner at 11,930' 4. Catch and Confirm 2-7/8" straddle liner is free 5. Set BPV 6. PT MV, SV, WV 7. Blind and bleed lines, remove well house, level pad Rig P&A and Sidetrack Operations: (Scheduled to begin on May 27, 2009 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Pull BPV 4. Pull 2-7/8" straddle Liner 5. Drift for 4-1/2" monobore whipstock and packer assembly 6. Set 4-1 /2" Baker monobore whipstock and packer at 11,895' 7. Mill out XN nipple at 10,379' 8. Mill 3.8"" window through 4-1/2" 9. Drill turn and lateral section to 13,630'. 10. Run and cement a 3-3/16" x 2-7/8" L-80 liner string to 11,500'. (This will abandon the existing perforations) 11. Make a cleanout run with mill, motor 12. Log well with SWS MGR-MCNL logging tool. 13. Perforate well 14. FP well to 2000' with McOH. 15. Set BPV. ND 7-1/i6" stack. FP tree and PT tree cap to 3500 psi. 16. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run gas lift design. 4. POP Well TREE _ ' FMC GEN 4 WELLHEAD= FMC • ACTUATOR= AXELSON KB. REV = 53.25' BF. ELEV = KOP (A) = 1488' 20" CONDUCTOR 110' Max Angle = 95° @ 13278' g1.5#, H-40, Datum MD = 11559' ID = 19 124„ Datum ND = 8800' SS 13-318" CSG, 68#, K-55 (1 JOINT), ID = 12.415" 80' 13-3/8" CSG, 72#, L-80, ID = 12.347" 3292' Minimum ID = 2.350" @ 12313' 2-7/8" XO JOINT TOP OF 7" LNR 07-28AL1 • 3.0"TM! PBR, ~ = 2.377° ~ 10392' 4-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10401' 3" X 2-7/8" XO, O = 2.372" 10402' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10564' 7" LNR, 26#, L-80„ .0383 bpf, ID = 6.276" i~ 10561' 2-718" LNR, 6.16#, L-80, .0055 bpf, ID = 2.372" PERFORATION SUMMARY REF LOG: BRCS ON 02/10/88 ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERF DATA NOTES: ORIGINAL WELLBORE NOT BELOW IBP. 14-1/2" CAMCO SSSV NIP, ID = 3.813" ~ CAA S I IFi' MA Nf~RFI R ST MD ND DEV NPE VLV LATCH PORT DATE 1 3840 3413 39 MMG DMY RK 0 04/01/08 2 7408 6099 42 MMG DMY RK 0 04/01 /08 3 9743 7850 38 MMG DMY RK 0 04/01/08 9-5/8" x 8-1 /4" BKR ZXP PKR, ID = 7.500" 8.313" BKR HMC HGR, O = 6.250" 8.313" X 7" XO, O = 6.184" 7" X 4-1 /2" BKR SB-3 PKR, ID = 3.875" 10379' I~ 4-1 /2" HES XN NIP, O = 3.725" 10~ 395' I 7" X 5-3/4" BKR ZXP PKR w / 7.11" TEBACK, O = 4.40" 10401' -I 4-1/2" WLEG, ID = 3.958" ~MD TT NOT LOGGED 10408' 7" X 5" HMC HGR ID = 4.40" 1~ 5" X 4-1/2" XO,ID = 3.937" 1936' -12313' ~- j 2-7/8" SOLID BLA ST JOINT, CSH 1345' -12405' 2-7/8" SOLD BLAST JO~VT, CSH 12413' 3.60" BKR DEPLOY SUB, ID = 3.00" 12416' 3-1/2" X 2-7/8" XO PIN, O = 2.377" _ _ _ _ _ L1 (ZA1) LENI WINDOW 45' Li (ZA1) ___ _ _ _~ 1239T - 12403 OPENING WIDTH = 3.715" 7' ~ 4-1/2" X 2-718" TNV KS ANCHOR , O = 2.371" DATE 06/20/88 REV BY ROWAN 41 COMMENTS ORIGINAL COMPLETION- DATE 05/08/08 REV BY OB/MCZ/PJ COMMENTS DRAWING CORRECTIONS 08/19!97 D141 SIDETRACK 07-28A 02/16/09 KDClSV PULL TOGGLE PLUG (03130/08) 07/31/02 NORDIC 1 CTD SIDETRACK (07-28AL1) 12!19/07 JCM/PJC TOGGLE PLUG (12/14/07) 04/06/08 JCM/SV GLV C/O 04/07/08 PJC DRAWING CORRECTIONS PRUDHOE BAY UNIT WELL: 07-28AL1 PERMIT No: 1971290 (2021060) API No: 50-029-21770-01 (60) SEC 33, T11N, R14E, 394' FNL i£ 339' FEL BP Exploration (Alaska) ~ 07-28AL1 ~ PERFORATION SUMMARY REF LOG: BRCS ON 02/10/88 ANGLE AT TOP PERF: @' Note: Refer to Production DB for historical pert data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 2-3/4" 4 ZA1 11955 - 12006 O 08/17/97 2-3/4" 4 12124 -12193 O 08!17/97 2-3/4" 4 12240 - 12294 O 08/17/97 2-314" 4 12537 - 12592 O 08/17/97 2-3/4" 4 12710 - 12752 O 08/17/97 2-3/4" 4 12854 - 12947 O 08/17/97 2-3/4" 4 13024 - 13113 O 08/17/97 2-3/4" 4 " 13163 - 13210 O 08/17!97 2-3/4" 4 13404 - 13680 O 08/17/97 2-3/4" 4 13720 - 13920 O 08/17/97 23/4" 4 13960 - 14290 O 08/17!97 2-7/8" PRE-DRILL ZA1 12418 -12482 O 07/28/02 2-7/8" 12501 - 13070 O 07/28/02 2-7/8" 13090 - 13691 O 07/28!02 12413' - 13725' 3-3/4" L1 (ZA1) 2-718" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" PBTD 14300' 10392'-12410' 6-3/4" 07-28A(ZONE?) 4-1(2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 14391' DATE REV BY COMMENTS DATE REV BY COMMENTS 06!20/88 ROWAN 41 ORIGINAL COMPLETION 05/08/08 OB/MCZ/PJ DRAWING CORRECTIONS 08/19/97 D141 SIDETRACK (07-28A) 02!16/09 KDC/SV PULL TOGGLE PLUG (03/30/08) 07!31/02 NORDIC 1 CTD SIDETRACK 07-28AL1 12/19/07 JCM/PJC TOGGLE PLUG (12/14/07) 04/06/08 JCM/SV GLV C/O 04/07/08 PJC DRAWING CORRECTIONS PRUDHOE BAY UNIT WELL: 07-28AL1 PERMIT No: 1971290 (2021060) API No: 50-029-21770-01 (60) SEC 33, T11N, R14E, 394' FNL & 339' FEL BP Exploration (Alaska) I Mtt = r NI(: ca'tN a LLM~.D= _FMC ~ ~ ~ ~~ ~ ~ M BELOW ~PIgNALWELL80RE NOT ACTUATOR= AXELSON KB_l~v =..,.,.._._ _ s3:zs Proposed CTD Sidetrack ~. ELEV = r KOP (A)._=........._....._..___._~ ~' 20" CONDUCTOR, 110' - ...._.._ Max Angle....=_._~ ~ 13278' 91.51, h~40, Datum MD = .. 11559' D =19:124" Datum TVD = 8800' SS 13.3!8" CSG. 68~, 1455 (1 JOINT), D = 12.415" 80' 13-318" CSG, 72*, L-80, D= 12.347" 3292' Minimum ID = 2.30" ~ 11,509' Milled out SELRT bushing TOP OF 7" LNR 9847' ~C-518" CSG, 47i~, L•80, D = 8.681" mill out w indomr I 10023' PERFORATION SUMMARY P.EF LC>G EHC~ OPJ 02tt 013E f;PJ=LF ~" ''P PEF= ~ ' Note: Refer to Production DB for historical data SIZE SPF ZONE INTERVAL OpnlSgz DATE 412" TBG. 12.6+x, L-80, .0152 bpi. D = 3.WS8" H 10401' 7" LNR, 26*, L-80,..0383 bpf, D = 6276" 70561' LNR 412" mobore backer whipstock I-'1 1 X412" CALACO SSSV NP, D = 3.813" ~ C;dS I ~ 1AAr$'1FiEl S T AAD TVD DEV TYPE VLV LATCH PORT DATE 1 3840 7408 3413 6099 39 42 M4tG MMG OMY DMY RK RK 0 0 04101A8 04!01108 3 9743 7850 38 MMG DMY RK 0 04/01108 9847' -19-518" x 8-114" BKR ZXP PKR. D = 7.500" 9861' 8.313" BKR HMC HGR, D =6250" 9867' 8.313"X7" XO, D = 6.184" 10346' -17" X 4112' BKR SB-3 PKR, D = 3.875" 10379' 10395' ~ 7" x 5-3/4" BKR ZxP PKR w/ 7.11 " TEBACK. ID = 4.40" 10401' 4112" W LEG, D = 3.958` EL6AD TT NOT LOGG~ 104 7"X5" HMC HGR. D = 4.40" 10415' ~~5" X 4112' X0, D = 3.937" ~ TSGR 10565' 5~ 11509' Milled out ro = 2.30" 3.3116" X2-718" cmt'ed and perfed x 2-718 J~ over B ~2-718" LNR, 6.16*. L-80, .0055 bpf, D = 2.372" ~ 412" LNR. 12.6/. L-80, .0152 bpf, D = 3.958" I 14391' ~ l 11936'-12313' 1~2-718" SOLD BLAST JOINT, CSH I ~__-____ A.L1----~ 12407' 412" x 2-718" T1W KS ANCFgR , D = 2.371" 07- DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDFIOE BAY U1+4T 0612618E ROWAN 41 ORIGINAL CON~LETION 05108108 ZR DRAWING CORRECTIONS WELL: 07-28~ 88Ml197 Di41 SI~TRACK 7-2EA 02M 6109 KDC15V PULL TOGGLE PLUG 03l30A8 PERMIT No: 87fd1182 NORDIC 1 CTD SDETRACK (07-28/1L1 03103109 MSE PROPOSED CTD SIDETRACK APt No: 50-029-21770-02 12119A7 JCMIPJC TOGGLE PLUG (12M 4A7) SEC 33 T11 N R14E 394' FNL 8339' FR 041~t08 JCMISV GLV C10 04107/08 PJC DRAWIdG CORRECTIONS BP E~lorrtan (Alaska) 412" HES XN NP, D milled to = 3.80" . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicl1e\CvrPgs _ Inserts\Microfilm _ Marlœr.doc )( ~\ ~~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 ", ~f'~ Àb Jvh ~ l.- API No. 50-029-21770-6t1-00 Permit to Drill 2021060 Well Name/No. PRUDHOE BAY UNIT 07-28AL 1 Operator BP EXPLORATION (ALASKA) INC - <. C4" MD 13725 ----- TVD 89ßô -- Completion Date 7/31/2002 Completion Status 1-01L Current Status 1-01L UIC N ~-~~~ ------~~~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes --------~-_.~-----,--~ ~-~--------- DATA INFORMATION Types Electric or Other Logs Run: GR, MGR, CCL Well Log Information: (data taken from Logs Portion of Master Well Data Maint) .-.. Log/ Electr Data Digital Dataset Type Med/Frmt Number Name re- C Pdf Lt17 41 See Notes ~D øED D t.RPf ~ Log Log Run Scale Media No 2,3 Interval OH / Start Stop CH 12413 13725 Open Received Comments ---~------- ROP, NGP MDnvD in .pdf and .emf with emf viewer ~ional Survey ~08 LJ,£ V'I iril;atron-' ~ t\. LIS Verification Directional Survey 12356 13725 Open 8/14/2002 12382 13695 ~2/11/2003 12382 13695 ~ 2/1112003 1 12356 13725 Open 8/14/2002 1,2 12382 13725 Open 5/13/2003 ~.- 25 Final 12413 13725 Open 5/13/2003 MWD - ROP, NGP - MD 5 Final 12413 8915 Open 5/13/2003 MWD - NGP - TVD ---~-----_._,---..~--- {DD CAse (11741 LJ§V~rjfiG8tiufï C Pdf /'11741 Rate of Penetration ED C Pdf J-1741 Gamma Ray Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received Well Cored? ADDITIONAL INFORMATION yG!) Daily History Received? '-6 N (-x. 1 N Formation Tops U Chips Received? '- Y I N Analysis Received? Comments: Y/N --_._----_._---~ ~--_.._--~---~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021060 Well Name/No. PRUDHOE BAY UNIT 07..28AL1 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21770-60-00 Compliance Reviewed By: c~n Date 7/31/2002 Completion Status 1-01L Current Status 1-~IL fD UIC N Date:~n~~i MD 13725 TVD 8983 ;tc:a I IDb WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage, Alaska 99501 May 08, 2003 RE: MWDFormation Evaluation Logs: 07-28A Ll, AK-MW-22125 07-28A Ll: Digital Log Images 50-029-21770-60 1 CD Rom I','-\-\ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY 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 LR2-1 900 E. Benson Blvd. J\nchorage, Alaska 99508 Date: G ' } D t D3 Signed: ~ x:J ' ~J- w1AY ì ~ ~~~~rv\~ a 0;1- 104:> I{~~ WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska February 07,2003 RE: MWD Formation Evaluation Logs 07-28AL1, AK-MW-22125 1 LDWG formatted Disc with verification listing. API#: 50-029-21770-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Artn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~{/~ RECEIVED FEB 11 2003 AI.. Oil & GIs Cons. Commiaeion Anclølge , ,r ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revision to Correct BHL 1. Status of Well IBI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 ~-,~..,. 4. location of well at surface .~~;.x'.r",.~V;¡ct/~:r" 394' SNl, 339' WEl, SEC. 33, T11 N, R14E, UM...,r .C<'Œ.iPLi:-"Tì.L.'Ff'l... t. :...,.,..~ .. ..' "':."'... .. .. ).~ At t~p of produ~tive interval j.. )~."Œ -ì E~.r_. 360 NSl, 1815 WEl, SEC. 21, T11N, R14E, UM .1., 7. ..~/J f.J4 ~.~.4!4.'. '.-.. á..': 10. Well Number At total depth .~ ~UF.lED i ;,. ...' : .~ ." i '..~. 07 -28AL 1 1382' NSl, 3320' WEL, SEC. 21, T11N, R14E, UM ,. _clJJ.' 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Oê'STyif~lörr1rrid Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 53.25' ADL 028306 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/26/2002 7/28/2002 7/31/2002 17. Total Depth (MO+TVO) 18. Plug Back Depth (MO+TVO) 19. Directional Survey 13725 8969 FT 13725 8969 FT IBI Yes 0 No 22. Type Electric or Other Logs Run GR, MGR, CCL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 91.5# H-40 Surface 110' 30" 2538 # Poleset 13-3/8" 68# /72# K-55/ L-80 Surface 3291' 17-1/2" 3OOOsxCSIII.600sx'G'. TopJob200sxCSI 9-5/8" 47# L-80 Surface 9993' 12-1/4" 875 sx Class 'G', 400 sx CS I 7" 26# L-80 9847' 10561' 8-1/2" 170 sx Class 'G' 4-1/2" 12.6# L-80 10419' 12397' 6" 401 sx Class 'G' 2-7/8" 6.16# L-80 12413' 13725' 3-3/4'1 Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and 25. TUSING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) . PACKER SET (MD) 2-7/8" Slotted Section Existing07-28A. 2-314" Guns. 4spf 4-1/2",12.6#, L-80 10401' 10346' MD TVD MD TVD 2-7/8", 13.5# /6.16#, L-80 10392' - 124101 12387' 12417' -12482' 8990' - 8992' (11 Intervals) 26 A F C S 12493' -13070' 8992' - 8982' . CID, RACTURE, EMENT QUEEZE, ETC. 13081' -136911 8982' - 8968' 11955' -14290' 9007'- 8990' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH Classification of Service Well 7. Permit Number 202-106 8. API Number 50- 029-21770-60 9. Unit or Lease Name Prudhoe Bay Unit 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 21731 MO 1900' (Approx.) AMOUNT PULLED (Rests outside Window) 27. Date First Production August 9, 2002 Date of Test Hours Tested 9/6/2002 6.1 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BSL TEST PERIOD 1713 OIL-BsL GAs-McF 24,483 GAs-McF W ATER-BsL -0- WATER-BsL CHOKE SIZE 59.78 OIL GRAVITY-API (CORR) GAS-Oil RATIO 14,293 ?8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. SEP 2 3 2002 ,oDMS 8Fl (, I::~ Form 10-407 Rev. 07-01-80 Submit In Duplicate ( (' 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. No new markers. Kicked off in Zone 1 A and stayed in Zone 1 A. EC I f~J (:, ;Jt; 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Surveys 32. I ~erebY certify that the f~oin~ is true and correct to the best of my knowledge Signed Terrie Hubble /} 0'1A..iR .J~. Title Technical Assistant 07 -28AL 1 202-106 Well Number Permit No. I Approval No. Date oq.rf1"0~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ( Well: Field: API: Permit: 07 -28AL 1 Prudhoe Bay Unit 50-029-21770-60 202-106 Rig Accept: 07/25/02 Rig Spud: 07/26/02 Rig Release: 07/31/02 Drilling Rig: Nordic #1 PRE-RIG WORK 03/10/02 DRIFT TBG W/2.83" DRIFT TO 10,391' SLM. DUMMY OFF GLM'S. PULL CATCHER SUB. 03/11/02 CALIPER TBG. GOOD DATA. RDMO. WELL LEFT SHUT IN. PDS CALIPER RESULTS: THIS CALIPER SHOWS THE TUBING IS MOSTLY IN GOOD CONDITION WITH MAXIMUM RECORDED PENETRATIONS IN EXCESS OF 20% WALL THICKNESS RECORDED IN ONLY 6 JOINTS. TWO ISOLATED PITS MEASURING 43% AND 41% LOSS OF WALL THICKNESS ARE THE MAXIMUM WALL LOSS RECORDED. 03/12/02 BLEED lA, PUMPED 294 BBLS CRUDE AND 36 BBLS DIESEL, NEVER PRESSURED UP. CALL FOR INSTRUCTIONS, RIG DOWN, MOVE OFF SITE, RETURN TO SHOP. 03/13/02 CK. STA 3-2-1 WI KOT & LIB TO MAKE SURE DGLV'S IN POCKETS LOOKS GOOD (POST MITIA FAILURE). LEAVE WELL SI. 03/14/02 MITOA TO 1000 PSI PASSED/PPPOT-T PASSED. 03/15/02 ATTEMPT TO SET PXN PLUG. 03/16/02 SET 4-1/2" PXN TTL PLUG & PRONG (PRONG 94" LONG, 1-3/4" FN). 03/18/02 TBG FL AND BLEED. 03/19/02 MIT-T PASSED TO 3000 PSI. (CTD SCREENING). WILL REPEAT THE MITIA. 03/20/02 MIT-IA PASSED TO 3000 PSI (CTD PREP). NOTE THE WELL WAS A MARGINAL PASS ON PRESSURE STABILIZATION, WILL CHECK IA FL AND POSSIBLY RE-MITIA USING A TRIPLEX. 03/22/02 PULL 4-1/2 PXN PLUG FROM XN-NIPPLE @ 10,353'. WELL TO REMAIN SHUT IN FOR MIT. 03/23/02 MITIA PASSED TO 3000 PSI. 03/28/02 RAN RST-SIGMA LOG FROM 11400 - 11900 (DEV), FIELD GOC PICK AT 11634'. NOTIFY PAD OPER OF STATUS - WELL SHUT IN. 07-28AL 1, Coil Tubing Drilling ( .Iateral Page 2 ( 04/04/02 PT MV PASSED TO 4500 PSI. 07/04/02 RIH W/3" JSN TO 13,000' CTM, POOH. RIH W/3.65" OD DRIFT & 1-11/16" MEM LOGGING TOOLS. LOG INTERVAL 12780' CTMD TO 10300' CTMD. FLAG PIPE AT 12375' CTMD. POOH. 07/05/02 POOH WITH LOGGING TOOLS. RIH WITH TIW 'KS-WS' WHIPSTOCK PACKER ASSY, CORRECT @ FLAG. SET TOP OF PKR AT 12,387'. GET ORIENTATION DATA FROM SPERRY TOOL, POOH. SET 4-1/2" WFD WHIPSTOCK - TOP OF TRAY AT 12,376', PIP TAG AT 12,385', ORIENTATION SET AT 45 DEG RIGHT OF HIGH SIDE. POOH. INJECTIVITY TEST 2.0 BPM @ 1500 PSIG, COMPARED TO PREVIOUS INJECTIVITY WIO WHIPSTOCK 4.3 BPM @1465 PSIG. RIH N2 LIFTING, MONITOR RETURNS. 07/06/02 LIFTING WITH N2. LIFT WELL DOWN TO 7000' MD. RETURNS WERE SPORADIC MIX OF KCL AND N2. WELL DOES NOT APPEAR TO HAVE ENOUGH ENERGY TO SUSTAIN FLOW ON ITS OWN. PUMPED A TOTAL OF 2650 GALS (246,715 SCF) OF N2 TOTAL. MONITORED WELL FLOW TO OPEN TOP TANK. SHUT IN WELL AND MONITOR SIWHP. SIWHP BUILT TO 760 PSIG. TUBING FLUID LEVEL SHOT AT 3735'. WELL PUT IN TEST AND DIED WITH NO MEASURABLE PRODUCTION. LIFTING WITH N2. LIFT WELL DOWN TO 7000' MD. RETURNS WERE SPORADIC MIX OF KCL AND N2. WELL DOES NOT APPEAR TO HAVE ENOUGH ENERGY TO SUSTAIN FLOW ON ITS OWN. PUMPED A TOTAL OF 2650 GALS (246,715 SCF) OF N2 TOTAL. MONITORED WELL FLOW TO OPEN TOP TANK. SHUT IN WELL AND MONITOR SIWHP. SIWHP BUILT TO 760 PSIG. TUBING FLUID LEVEL SHOT AT 3735'. WELL PUT IN TEST AND DIED WITH NO MEASURABLE PRODUCTION. FREEZE PROTECT CALLED IN. ( (' BP Operations Summary Report Page 1 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -28A 07 -28A REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/25/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 7/15/1997 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/25/2002 00:00 - 02:00 2.00 BOPSURP DECOMP Finish summer maintenance & move Nordic Rig #1 to OS 07-28A. No incidents. ACCEPT RIG @ 00:01 HRS, 07/25/02. N/U BOPE. Grease tree. Fill rig pits with bio-KCL water. 02:00 - 08:30 6.50 BOPSUR P DECOMP Perform initial pressure 1 function test of BOPE. Test witnessed by Chuck Scheave. Tested H2S and LEL alarms. All passed OK. Send test report to AOGCC. 08:30 - 09:00 0.50 STWHIP P WEXIT Held pre-operations safety meeting. Reviewed well plan I hazards & BHA M/U procedures. 09:00 - 09:30 0.50 STWHIP P WEXIT Cut coil. Install OS CTC. Pull test to 40klbs. 09:30 - 10:00 0.50 STWHIP P WEXIT Circulate & fill hole with 25 bbls bio-KCL water. 10:00 - 11 :00 1.00 STWHIP P WEXIT Load wiper dart, launch & displace with Biozan. Dart bumped @ 56.9 bbls. 11 :00 - 11 :45 0.75 STWHIP P WEXIT PfTest CTC to 3500 psi. PfTest inner reel valve & MHA to 4000 psi. 11 :45 - 12:30 0.75 STWHIP P WEXIT M/U window milling BHA # 1 with Weatherford straight motor, string reamer & HCC DSM. Stab injector on well. 12:30 - 15:20 2.83 STWHIP P WEXIT RIH with BHA #1. Fill hole with 20bbls bio-KCL water. Check wt up @ 12200' - 48k. Displace down 20bbls, 9.6ppg, 150k LSRV flopro pill to mill with @ 0.3bpm losses. 15:20 - 15:30 0.17 STWHIP P WEXIT Spot hi-vis, hi-wt pill on whipstock. Losses seems to heal up. Tag with minimum rate @ 12405' down & 12399' up. 15:30 - 16:30 1.00 STWHIP P WEXIT Shut down for White House Fellows Nordic-1 Rig tour. 16:30 - 16:45 0.25 STWHIP P WEXIT Retag whipstock with pumps on @ 12403.8'. Correct depth to the pinch point - top of whipstock @ 12376'. Park l' above pinch point @ 12375' & bring on pump to 2.5bpm with 2000psi free spin. Wt up - 48k & wt down - 17.5k. Flag CT at 12,375 ft. 16:45 - 18:00 1.25 STWHIP P WEXIT Stretch into milling. Mill to 12377.5' with 2.5/2.4bpm, 2000/2140psi & 2.3k WOB. 18:00 - 20:00 2.00 STWHIP P WEXIT Milling, 2.5/2.4 bpm, 1950 - 2300 psi, 2-3K WOB, Milled to 12,379.3 ft. 20:00 - 21:40 1.67 STWHIP P WEXIT Milling, 2.5 1 2.4 bpm, 1950 - 2300 psi, 2-3K WOB, Milled to 12,381.5 ft. Exit casing at 12,381.5 ft. Top of window at 12,376 ft. 21:40 - 23:00 1.33 STWHIP P WEXIT Mill formation at 10 fph. 2.6/2.5 bpm, 2150 psi, Mill formation to 12,392 ft. 23:00 - 00:00 1.00 STWHIP P WEXIT Back ream up thru window. Ream down. Back ream and ream down. Swap well to FloPro while reaming window. 7/26/2002 00:00 - 00:30 0.50 STWHIP P WEXIT Ream window from 12,376-12.382 ft. Ran thru window with no pump. Clean window. Back ream. Well turned over to FloPro. TO at 12,392'. 00:30 - 02:45 2.25 STWHIP P WEXIT POH with milling BHA #1. Flag CT at 12,200' EOP. 02:45 - 03:15 0.50 STWHIP P WEXIT Layout milling BHA. Mill and string reamer at 3.71" gauge 03: 15 - 03:30 0.25 DRILL P PROD1 SAFETY MEETING. Pre Spud Meeting with crew. Review well plan and hazards with night crew. Review BHA M/U procedure and hazard mitigation. 03:30 - 04:15 0.75 DRILL P PROD1 M/U MWD BHA #2 with 1.04 deg motor and 3.70" Hycalog DS49 Bit #2. 04: 15 - 06:45 2.50 DRILL P PROD1 RIH with MWD BHA #2. Shallow test tools and Orienter. RIH to 12303' & tie-into EOP flag (-38' correction). Printed: 8/5/2002 12:18:01 PM ( BP Operations Summary Report Page 2 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -28A 07 -28A REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/25/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 7/15/1997 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/26/2002 06:45 - 07:45 1.00 DRILL P PROD1 Log down from 12265' for GR tie-in. Tie-into BHCS/GR & added 23' to CTD. 07:45 - 08:00 0.25 DRILL P PROD1 Run thru window slick with pumps down @ 25R TF. Tag at 12413'. As per geologist, depths are corrected as follows: TOWS & TOW @ 12397', BOW @ 12402.5' & RA tag for future tie-ins @ 12406' BKB. P/U clean @ 40klbs. Kick on pumps free spin = 2900 psi @ 2.5 bpm. 08:00 - 08:30 0.50 DRILL P PROD1 Orient to TF to below 90R. 08:30 - 08:45 0.25 DRILL P PROD1 Drill to 12450' with 123R TF, 2.1bpm & 148fph. Observe RA PIP tag on depth @ 12406'. Drill to 12465' with 60-130R TF, 2.5bpm & 20fph. Observe orienter not functioning properly. Seeing a lot of vibrations with inclination reading swinging from 147 degs to 80 degs & no consistent G-totals. MWD rep suspects DS49 bit could be out of balance & causing excessive dowhole vibration. 08:45 - 09:45 1.00 DRILL N DFAL PROD1 Troubleshoot MWD. Toggle tool & try different flowrates - still not getting good or consistent G-totals. Pull above window & retry - no luck. RBIH. Pulled heavy @ 12446'. Continue troubleshooting MWD. Getting 0.5 G-totals, 87 degs inclination while RIH & 143 degs inclination while PUH. Hycalog confirms that DS-49 Bit is well balanced. Decide to POOH to 10000' @ 42 degs inclination similar to SHT angle. 09:45-10:15 0.50 DRILL N DFAL PROD1 POOH to 10000'. 10:15 -10:30 0.25 DRILL N DFAL PROD1 Shoot MWD surveys & get G-total of 1.0003 & inclination of 41-46 degs @ 9958'-9988'. Original survey @ this depths gave @ 41.6 degs inclination. Check orienter - clicking OK. Seems like we have a downhole vibration problem @ 90 degs hole inclination. Decide to RBIH to check if problem still exists. 10:30 - 11 :00 0.50 DRILL N DFAL PROD1 RBIH to btm. 11 :00 - 11: 15 0.25 DRILL N DFAL PROD1 Orient 2 clicks. Shoot MWD survey & get G-total of 1.0000 & inclination of 92.06 degs @ 12422.54' as expected. However, next 3 surveys gave 83-85 degs @ 12429'-12448' with G-totals of 1.063-1.221. Decide to drill +1- 15' to see if surveys will steady up. 11: 15 - 11 :40 0.42 DRILL P PROD1 Drill to 12467' with HS TF, 2.6/2.6bpm, 3000/3240psi & 24fph ave ROP. Continue drilling to 12481' with 67RTF, 2.6/2.6bpm, 3000/3300psi & 20fph ave ROP. Still getting inconsistent/bad G-totals with 82-84 degs angle. Call it quit! POOH to swap out BHA. 11 :40 - 13:45 2.08 DRILL N DFAL PROD1 POOH BHA#2. 13:45 - 14:45 1.00 DRILL N DFAL PROD1 OOH. PJSM. LID BHA#2. Inspect DS49 bit - nothing amiss, however will still change it out. M/U BHA #3 with new 3.70" Hycalog DS49 bit #3, new 1.37 deg motor & new MWD probe. 14:45 -17:15 2.50 DRILL N DFAL PROD1 RIH with BHA #3. SHT MWD - OK with good G-totals. Continue RIH smoothly thru window without pumps. Tag btm @ 12500'. Correct depth to 12481'. Bring on pumps & check TF @ 50R. 17:15 -17:30 0.25 DRILL P PROD1 Orient & drill to 12491' with 30R TF, 2.6/2.6bpm, 3000/3340psi & 50fph ave ROP. Getting good & consistent G-totals. 17:30 - 17:50 0.33 DRILL N SFAL PROD1 PUH into window to fix leak on inlet crossover from swivel to CT reel. Changeout O-ring on hardline connection. RBIH to btm. 17:50 - 18:20 0.50 DRILL P PROD1 Drilling @ 90R TF, 2.6/2.6bpm, 3000/3400psi. Hit hard spot @ 12505' with various stalls. Continue drilling to 12507'. Printed: 8/5/2002 12:18:01 PM ( BP Operations Summary Report Page 3 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -28A 07 -28A REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/25/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 7/15/1997 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/26/2002 18:20 - 18:40 0.33 DRILL P PROD1 Orient to TF to 32R. 18:40 - 20:00 1.33 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3150 psi, 32R TF, 44 fph, Drilled to 12,544 ft. 20:00 - 21 :50 1.83 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3150 psi, 83R TF, 50-80 fph, Drilled to 12,612 ft. Getting overpulls, stacking wt. Added 1 % lubetex and 2 ppb Klaygard. 38K up wt, 18K dwn wt. 21 :50 - 22:30 0.67 DRILL P PROD1 Wiper trip to window. RIH. 22:30 - 00:00 1.50 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3250 psi, 100R TF, 40 fph, 160 api shale. Drilled to 12,667' 7/27/2002 00:00 - 01 :40 1.67 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3200 psi, 90R, Stacking wt. Overpulls. Drilled to 12720'. 01 :40 - 02:00 0.33 DRILL P PROD1 Wiper trip to window. Overpull in shale at 12620'. Added 2 ppb Klaygard. RIH. 02:00 - 03:30 1.50 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3150 I 3500 psi, 90R, Drilling in 40-50 API sand from 12,700'. Drilled to 12,803 ft. 03:30 - 03:40 0.17 DRILL P PROD1 Orient TF to 120L. 03:40 - 04:30 0.83 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3150 I 3600 psi, 120L. Drilled to 12,900 ft. 04:30 - 05:00 0.50 DRILL P PROD1 Wiper trip to window. 05:00 - 05:45 0.75 DRILL P PROD1 Log Tie-in to RA tag at 12,406 ft. Added 9 ft to CTD. 05:45 - 06:00 0.25 DRILL P PROD1 RIH clean to TO. Tagged TO at 12,908 ft. 06:00 - 06:35 0.58 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3150 I 3500 psi, 90L, Drilled to 12944'. Drilling 40-50 api sand from 12920'. 06:35 - 06:40 0.08 DRILL P PROD1 Orient 1 click while PUH. Attempt to orient 1 more click - pulling heavy with 30k Olpull. Temporarily stuck @ 12900'. Suspect differential sticking with 1 for 1 returns & no up/down movement. 06:40 - 07:00 0.33 DRILL N STUC PROD1 SID pumps to lower ECD, stack down 3.5k & wait for 20 mins. 07:00 - 07:20 0.33 DRILL N STUC PROD1 Work pipe up to 80k pulls - no success. Call for crude & lubetex. Meanwhile circulate 40bbls around @ 2.7bpm. 07:20 - 07:50 0.50 DRILL N STUC PROD1 SID pumps again & maintain string in neutral wt. 07:50 - 08:00 0.17 DRILL N STUC PROD1 Slack off to 0 indicated wt & work pipe up to 90k pull ... no success. Circulate @ 2.3/2.3bpm & maintain 80k on string. 08:00 - 08:30 0.50 DRILL N STUC PROD1 Crude tanker arrive site. Conduct vapor test. R/U to pump crude. 08:30 - 09:00 0.50 DRILL N STUC PROD1 Pump 10 bbls of crude & displace with mud @ 2.5/2.5bpm, 3480psi with 80k on CT. With 5 bbls of crude out the bit, SID pumps, & soak crude for 5mins with CT @ neutral wt. Work pipe without pumping & pull free with 85k. 09:00 - 10:50 1.83 DRILL P PROD1 PUH 30'. RBIH 30'. Wiper trip clean to 10000' (40 degs) chasing crude to surface. RBIH clean to btm. Drill solids up to 0.7%. Call for new mud. 10:50 - 11 :00 0.17 DRILL P PROD1 Orient TF to 90L. 11 :00 - 11 :20 0.33 DRILL P PROD1 Drill to 12968' with 90-100L TF, 2.5/2.4bpm, 3150/3500psi & 90fph ave ROP. Pulling heavy & stacking wt. P/U & attempt to go down - differentially stuck again. 11 :20 - 11 :40 0.33 DRILL N STUC PROD1 SID pumps & maintain string in neutral wt. 11 :40 - 11 :45 0.08 DRILL N STUC PROD1 Slack off to 0 indicated wt & work pipe up to 80k pull ... no success. 11 :45 - 12:20 0.58 DRILL N STUC PROD1 Pump 10 bbls of crude & displace with mud @ 2.5/2.5bpm, Printed: 8/5/2002 12:18:01 PM ( BP Operations Summary Report Page 4 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -28A 07 -28A REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/25/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 7/15/1997 End: Date From - To Hours Task Code. .NPT Phase Descri ptionof. Operations 7/27/2002 11 :45 - 12:20 0.58 DRILL N STUC PROD1 3550psi. SID pumps with 5 bbls of crude out the bit & soak crude for 5mins with CT @ neutral wt. Work pipe with 85k max pull without pumping & unstuck pipe. 12:20 - 13:00 0.67 DRILL P PROD1 Wiper trip clean to window. 13:00 - 13:30 0.50 DRILL P PROD1 Drill to 13008' with 90-100L TF, 2.6/2.6bpm, 3350/3700psi & 120fph ave ROP. Stacking wt & not seeing motor work. Drill thru hardspot @ 13010'. 13:30 - 15:20 1.83 DRILL P PROD1 Continue drilling to 13100' with 11 OL TF, 2.6/2.6bpm, 3400/3800psi & 56fph ave ROP. Having occastional wt stacking & pulling heavy. Start new mud (with 3% lubetex & 8 ppb Kla-Gard) downhole. 15:20 - 15:35 0.25 DRILL P PROD1 With new mud @ bit, take off drilling to 13120' with 75L TF, 2.6/2.6bpm, 3350/3700psi & 120fph ave ROP. 15:35 -16:10 0.58 DRILL P PROD1 Wiper trip clean to window. 16:10 - 16:20 0.17 DRILL P PROD1 Orient TF to 60R. 16:20 - 16:40 0.33 DRILL P PROD1 Drill to 13138' with 55R TF, 2.6/2.6bpm, 3350/3700psi & 85fph ave ROP. 16:40 - 16:45 0.08 DRILL P PROD1 Orient TF to 90R. 16:45 - 17:05 0.33 DRILL P PROD1 Drill to 13171' with 75R TF, 2.6/2.6bpm, 3200/3700psi & 100fph ave ROP. 17:05 - 17:10 0.08 DRILL P PROD1 Orient TF to 150R. 17:10 -18:20 1.17 DRILL P PROD1 Drill into hard spot @ 13188'. Stacking wt. Drill with -ve wt & punch thru @ 13202'. Drill ahead to 13213' with 115R TF, 2.6/2.6bpm, 3200/3700psi & 100fph ave ROP. 18:20 - 18:50 0.50 DRILL P PROD1 Orient TF to 80R. 18:50 -19:15 0.42 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3200 - 3600 psi, 70R, 110 fph ROP. Drilled to 13,250 ft. 19:15 -19:45 0.50 DRILL P PROD1 Wiper trip to window. 19:45 - 20:00 0.25 DRILL P PROD1 Log tie-in with RA tag. Zero correction. 20:00 - 20:30 0.50 DRILL P PROD1 RIH to TO. Clean hole. Tag TD at 13,250 ft. 20:30 - 23:00 2.50 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3200 - 3600 psi, 100R, 60-80 fph ROP. Stacking wt. Overpulls. Drilled to 13,393 ft. 23:00 - 23:45 0.75 DRILL P PROD1 Wiper trip to window. Overpulls bottom 50 ft. Rest of hole was clean. 40K up wt. RIH. Dwn Wt = 19K. 23:45 - 00:00 0.25 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3200 - 3600 psi, 100R, 100 fph ROP. Drilled to 13,400 ft. 7/28/2002 00:00 - 00:45 0.75 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3200 - 3600 psi, 100R. Drilled to 13,451 ft. 00:45 - 01 :00 0.25 DRILL P PROD1 Orient TF to 90L. 01 :00 - 02:40 1.67 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3200 - 3600 psi, 90L. 100 fph. Drilled to 13,540 ft. 02:40 - 03:40 1.00 DRILL P PROD1 Wiper trip to window. Some overpull in shales. Mostly clean hole. RIH. 18K dwn wt. 03:40 - 04:00 0.33 DRILL P PROD1 Orient TF to 1 OOL. 04:00 - 05:30 1.50 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3200 - 3600 psi, 120L. 100 fph. Overpulls after drilloffs. Drilling clean 30-50 API sand. Drilled to 13,625 ft. 05:30 - 06:00 0.50 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3200 -3600 psi, 100L. 100 fph. Drilled to 13,653 ft. 06:00 - 07:00 1.00 DRILL P PROD1 Wiper trip to window. Small overpulls in shales. Good hole. RBIH. Printed: 8/5/2002 12:18:01 PM { BP Operations Summary Report Page 50f9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -28A 07 -28A REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/25/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 7/15/1997 End: Date From- To Hours Task Code NPT Phase Description of Operations 7/28/2002 07:00 - 08:30 1.50 DRILL P PROD1 Orient & drill with 75-90L TF, 2.5/2.5bpm, 3350/3800psi & 80fph ave ROP. O/pullls after drilloffs. 40K up wt. Own Wt = 14K. TO well @ 13721'. 08:30 - 09:05 0.58 DRILL P PROD1 Wiper trip to window. 09:05 - 09:30 0.42 DRILL P PROD1 Log & tie-into RA PIP tag (+4' CTD correction). 09:30 - 10:00 0.50 DRILL P PROD1 RBIH clean & tag TO @ 13725'. P/U clean & reconfirmed TO @ 13725'. 10:00 - 10:35 0.58 DRILL P PROD1 POOH drilling BHA for liner circulating @ 2.6bpm/3400psi. Paint EOP flag @ 12300'. POOH clean to window. 10:35 -13:15 2.67 DRILL P PROD1 Continue POOH drilling BHA#3 circulating @ max rate. Paint another EOP flag @ 11000'. 13:15 -14:00 0.75 DRILL P PROD1 PJSM. LID drilling BHA. 14:00 -14:15 0.25 CASE P COMP R/U to run liner & fill hole with 4 bbls of mud. 14:15 - 14:45 0.50 CASE P COMP PJSM for running liner. Fill hole with 1 bbl of mud. 14:45 - 17:00 2.25 CASE P COMP M/U 1 jt of 2-7/8" 6.16# L-80 STL solid & 39 jts of 2-7/8" 6.16# L-80 STL pre-drilled liners with shoe, O-ring sub, pups, cementralizers. 17:00-17:15 0.25 CASE P COMP R/U & PJSM for P/U 1-1/4" CSH tbg & SWS Memory GR/CCL tools. 17:15 -18:40 1.42 CASE P COMP P/U SWS GR/CCL with 5 jts of 1-1/4" CSH tbg. M/U CTLRT & coil. 18:40 - 20:45 2.0.8 CASE P COMP RIH with 2-7/8" Pre-Drilled liner. Drilled holes in liner are 3/8" each at 4 holes per ft. Liner total length = 1,312.42 ft. Correct depth to flag at 12,321 ft. [-14 ft CTD]. 46K up wt. 18K Own Wt. 20:45 - 21 :15 0.50 CASE P COMP Run 2-7/8" Liner out window at 12,403 ft. with no wt loss. Run in open hole at 60 fpm. Tag TO with liner at 13, 724 ft. CTD. Pick up 2 times and land at same TO each time. 2-7/8" Liner landed at TO of 13,725 ft BKB. Liner ran to TO very easy. Hole was in good condition. 21:15 - 21 :45 0.50 CASE P COMP Insert 5/8" steel ball. Displace with FloPro. Ball on seat at 51.7 bbls, sheared at 3000 psi. Pulled free at 43K up wt. Indicating liner left on btm. Top of liner deployment sleeve at 13,412.5 ft, which is 10 ft outside the window in the 4-1/2" Liner. 21 :45 - 23:00 1.25 CASE P COMP Log up with SWS Memory GRlCCL at 26 fpm to 12,000. ft. Log up at 50 fpm to 10,000 ft. 23:00 - 00:00 1.00 CASE P COMP POH with BKR CTLRT and SWS GR/CCL. 7/29/2002 00:00 - 00:30 0.50 CASE P COMP POH with BKR CTLRT and SWS GR/CCL. 00:30 - 01 :00 0.50 CASE P COMP LlO BHA. 01 :00 - 01 :20 0.33 FISH P COMP M/U 3.2" 00 jet side jetting nozzle with 1 jt, 2-3/8" PH6 and MHA. BHA = 39.74'. 01 :20 - 04:00 2.67 FISH P COMP RIH with jetting BHA to clean up whipstock area. SWS CCLI.GR shows top of liner at 12,406' reference RA tag. Bottom of window was at 12,402.5 ft ref. RA tag. 04:00 - 05: 15 1.25 FISH P COMP RIH while pumping 3.6 bpm at 2750 psi, from 12,300ft down to 12,424' and tagged top of 2-7/8" liner. Clean pick up. Up wt. = 34K, Own wt = 18K. Pull up to 12400', RIH to 12,423' while jetting at 3.6 bpm. Reciprocate total of 4 times jetting at 3.6 bpm. 05:15 - 08:00 2.75 FISH P COMP POH with nozzle while pumping 3.1 bpm at 2300 psi. 08:00 - 08:30 0.50 FISH P COMP PJSM. LlO nozzle BHA#5. Printed: 8/5/2002 12:18:01 PM ( BP Operations Summary Report Page 6 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -28A 07 -28A REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/25/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 7/15/1997 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/29/2002 08:30 - 09:00 0.50 FISH P COMP R/U for RIH Weatherford whipstock retrieval assembly. Decide to run MWD for better depth tracking. Call out MWD reps. 09:00 - 09:30 0.50 FISH P CaMP R/U MWD. 09:30 - 10:00 0.50 FISH P CaMP PJSM for RIH whipstock retrieval assembly with MWD. 10:00 - 10:30 0.50 FISH P COMP P/U whipstock retrieval BHA# 6, with Weatherford hydraulic overshot, pull disconnect, 2-7/8" PDM, upldown jar, accelerator, MHA & CTC. 10:30 - 11 :30 1.00 FISH P COMP Cut coil. Install Weatherford slip-type CTC. Pull test to 37k & pressure test to 4k - OK. 11:30-12:00 0.50 FISH P COMP Nordic Crew change & pre-tour safety meeting. 12:00 - 13:30 1.50 FISH P COMP Modify BHA#6 - decide to go with a whipstock retrieving hook. LlO the hydraulic overshot & 2-7/8" PDM & M/U BHA#6 with a Weatherford self-aligning hook, pull disconnect, jar, wt bar, accelerator, MWD, orienter, MHA & CTC. 13:30 - 13:45 0.25 FISH P CaMP Scribe MWD to fishing hook. 13:45 -14:00 0.25 FISH P CaMP M/U & surface test Weatherford orienter - get 3 for 3 clicks. 14:00 -14:10 0.17 FISH P COMP M/U Coil & stab injector. 14:10 -16:30 2.33 FISH P CaMP RIH with fishing BHA#6. SHT MWD & orienter @ 1384' - OK. Continue RIH to 12200'. 16:30 -17:15 0.75 FISH P COMP Log down from 12200' for GR tie-in. Tie-into SWS GR/CCL log & subtract 11' to CTD. Check TF - @ 164L. 17:15-18:00 0.75 FISH P COMP RIH & wt chk @ 12387' - up wt = 38k, dwn wt = 17k, Get a click & orient to 130L (Slot should be @ 180-45 = 135L). RIH gently & tag @ 12399' (hook slot is 2' from TOW). P/U & observe no catch. Try & set again @ 12399'. P/U & observe no catch. Try 3 more times, saw no bobbles & had no catch. Kill pump & try agian to 12402' - No luck. 18:00 -18:15 0.25 FISH P COMP PUH & orient TF to 140R. 18:15 - 20:00 1.75 FISH P COMP Attempt to hook whipstock tray from 140R going clockwise in 30 deg increments, 140R, 170R, 160L, 130L, No luck. Orienter working OK. 20:00 - 20:40 0.67 FISH P COMP Position hook at 12,399' and orient around trying to catch profile, no luck. Position hook at 12,399.6' and orient around trying to catch profile, no luck. 20:40 - 21:40 1.00 FISH P CaMP Hook at 102L, work up and down. No Luck. Try to hook with 1.6 bpm and 0 bpm. Hook at 74L, work up and down. No luck. Orient around. Hook at 164L, work up and down. . Set hook at 130L, work up and down, no luck. 21 :40 - 22:00 0.33 FISH P COMP Log down and Tie-in with SWS GR/CCL log of 7/29/02. Added 0.5' to CTD. 22:00 - 22:45 0.75 FISH P COMP RIH with hook at 135L and tried to catch at varying FPM. Orient to 105L and try a few more times. No luck, no overpulls at all. 22:45 - 00:00 1.25 FISH P COMP Flag CT and POOH for Hyd. Overshot fishing BHA. 7/30/2002 00:00 - 01 :00 1.00 FISH P COMP POH with MWD hook fishing BHA. No luck latching whipstock. 01:00 - 01:15 0.25 FISH P COMP LlO Sperry MWD and hook fishing BHA. No marks or damage to hook. 01:15 - 01:30 0.25 FISH P COMP SAFETY MEETING. Review procedure, hazards and mitigation for Fishing BHA M/U. 01 :30 - 02:00 0.50 FISH P COMP M/U Weatherford 3.69" Hydraulic Overshotwith 3/8" circ. port, Printed: 8/5/2002 12:18:01 PM BP Operations Summary Report Page? of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -28A 07 -28A REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/25/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 7/15/1997 End: Date From - To Hours Task Code NPT Phase Description .of Operations 7/30/2002 01 :30 - 02:00 0.50 FISH P COMP pull discon, motor, jars, wt bar, acceler and MHA. Total length = 42.38 ft. 02:00 - 04:15 2.25 FISH P COMP RIH with Hydraulic Overshot I motor fishing BHA. No wt loss going thru XN nipple or at top of 4-1/2" Liner. Correct -16 ft CTO at CT Flag. RIH. 04:15 - 05:15 1.00 FISH P COMP Up Wt. = 41K, Own WT = 19K, at 12,350 ft. Pump 0.7 bpm to turn motor and ease in hole at 1.2 FPM from 12,385 ft.. Free spin = 1375 psi at 0.7 bpm. and 1900 psi at 1.5 bpm. Saw motor work at 12395 ft. ease in and stack wt to 15 K. Pick up to 42K, stk wt to 10K and pull to 45K. with 1.5 bpm, stk wt to 5K and got all wt back to 20K at 12399 ft. Overshot had wedged between whipstock and window and fell thru into open of sidetrack. Pick up to 15 ft above whipstock with minimal overpull. 05: 15 - 06:00 0.75 FISH P COMP RIH with no pump to try and get overshot over lip of fish. Ran down to 12,403 ft and stacked wt to 15K. Pumped 1.5 bpm and stacked wt to 5K. Stop pump and pick up with no overpull. Overshot went thru window again. 06:00 - 06:30 0.50 FISH P COMP RIH Several times with and without pump, overshot sliding over top edge of whipstock into open hole each time. Stack wt on deploy sleeve at 12,405 ft. Clean pickups. Try RIH fast and bounce on whipstock. No Luck. Need better lip guide to get under top edge of whipstock. Flag CT at 12,000 ft EOP. 06:30 - 08:30 2.00 FISH P COMP POH to modify leading edge of overshot. 08:30 - 09:30 1.00 FISH P COMP L/O Weatherford hydraulic overshot. No marks on the inside of the overshot. Observe some scratches on the outside (possibly from going thru the window). Weatherford P/U overshot for modification. Shut swab valve (23-1/4 turns). 09:30 - 09:45 0.25 FISH P COMP R/U for cutting coil. 09:45 - 10:00 0.25 FISH P COMP PJSM for cutting coil. 10:00 - 10:45 0.75 FISH P COMP Cut 353' of CT. Meanwhile carried out ASA (#2002-ASA-277479) with satisfactory observations. 10:45 - 11 :00 0.25 FISH P COMP PJSM for RIH whipstock retrieval tools. 11 :00 - 11 :45 0.75 FISH P COMP P/U modified Weatherford hydraulic overshot with cut-lip guide, pull disconnect & new 2-7/8" POM. Simulate fish engagement with spare whipstock on catwalk & decide not to run the string reamer centralizer above motor. 11 :45 - 12:45 1.00 FISH P COMP Install new Weatherford slip-type CTC. Pull test to 28k & pressure test to 3.5k - OK. 12:45 - 15:10 2.42 FISH P COMP RIH with hydraulic overshot & motor fishing BHA#8. No bobbles @ XN & TOL. Tie-into EOP Flag (correct -20.4' to CTO). RIH. Up wt. = 40K. Own Wt = 20K. Free spin at 1.5 bpm = 1740 psi. 15:10 - 15:45 0.58 FISH P COMP Ease in hole from 12,385 ft at 1.0 bpm, 1450 psi. Saw 300-500 psi motor work at 12390'. Stack wt to 10K and inc pump to 1.5 bpm, Stop pump, pick up to 42K, RIH, pump 1.5 bpm and stack 15K, stop pump, pick up to 46K, RIH, Pump 2.0 bpm, stack wt to OK, Stop pump. PU to 50K. Have good bite. RIH, stack wt and jar down 1 time to set overshot better. Pick up to 62K and pull release whipstock. Pull up slow with 44K up wt. [earlier up wt was 40K]. Appears we have whipstock inside overshot. Printed: 8/5/2002 12:18:01 PM ( BP Operations Summary Report Page 8 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -28A 07 -28A REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/25/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 7/15/1997 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/30/2002 15:45 -18:15 2.50 FISH P COMP POH filling well from backside. Up wt = 44K. 18:15 - 18:35 0.33 FISH P COMP Safety meeting prior to rigging down fishing BHA. Had attendance from SWS, Nordic, TIW, WF, BP. 18:35 - 19:30 0.92 FISH P COMP Recover WF whipstock, it was fully inside overshot, bumped up against no-go [16" of swallow], made up very tight, apparently threads made-up as designed. Layout all of WF tools. 100% recovery. 19:30 - 19:45 0.25 CLEAN P COMP M/U 2.20" side jetting nozzle, 1 jt 1-1/4" CSH, OS MHA. BHA = 44.72 ft. 19:45 - 22:00 2.25 CLEAN P COMP RIH with side jetting nozzle BHA. Up Wt. at 12400 ft = 41 K. 22:00 - 22:45 0.75 CLEAN P COMP RIH thru TIW PKR at 12,407 ft with 2.2" nozzle and 1-1/4" CSH to 12,438 ft. Land XO at top of PKR. Recip across packer while jetting at 3.0 bpm. Circ. 25 bbl, very high viscosity FloPro pill. No overpulls while recip inside packer. Appears clean. 22:45 - 23: 15 0.50 CLEAN P COMP Circ. well to 2% KCL water with friction reducer. Recover FloPro and ship to MI plant for reconditioning. 23: 15 - 00:00 0.75 CLEAN P COMP POH with nozzle BHA while recovering FloPro. 7/31/2002 00:00 - 02:30 2.50 CLEAN P COMP POH while swapping well to 2% KCL with friction reducer and cleaning rig pits. Flag CT at 10,200 ft EOP. 02:30 - 03:15 0.75 CLEAN P COMP LlO nozzle BHA. Prep rig floor to run 2-7/8" WF Straddle Assembly. 03:15 - 03:30 0.25 RUNCOrvP COMP SAFETY MEETING. Review procedure, hazards and mitigation to run 2-7/8" tubing Straddle Assembly. 03:30 - 06:00 2.50 RUNCOrvP COMP M/U TIW KS-WS Anchor with 9000# shear pins, Swivel, 3 blast jts, XO, 1 jt 2-7/8" STL tbg, XO, 19 Blastjts, 49 jts, 2-7/8" STL Tbg, 2 pups,2-7/8" STL and TIW fluted Set Collar with 3.00" PBR. Straddle Assembly total length = 2018.38 ft. 06:00 - 06: 15 0.25 RUNCOrvP COMP Crew change and safety meeting prior to continuing to run straddle BHA. 06: 15 - 08:20 2.08 RUNCOrvP COMP Continue making up straddle BHA. 08:20 - 09: 10 0.83 RUNCOrvP COMP Make up logging BHA on 4 joints of CSH. 09: 1 0 - 09:35 0.42 RUNCOrvP COMP Make up SWS MHA, and injector. 09:35 - 11 :25 1.83 RUNCOrvP COMP RIH with straddle assembly. 11 :25 - 11 :40 0.25 RUNCOrvP COMP Stop at EOP flag from previous run. Should be at 12228.25'. Made -27' correction to get on depth. RI weight =23klbs, PU weight=49klbs. RIH, set down at 12400', stacked out weight, PU clean at 49klbs, not latched. PUH 20', RIH saw same tag up depth. PU to normal weight, then slacked off immediately. Tried to PU, and are latched. PU 4000# over normal up weight, and confirmed latched. Slack back off to neutral weight. 11 :40 - 12:00 0.33 RUNCOrvP COMP Stack 10klbs on GS spear. Kick on pumps to 1.5 bpm, PU at 38klbs, straddle is free of the GS spear. Start log, pull up hole logging at 30 fpm. NOTE - POST JOB PLAYBACK OF MEMORY GR/CCL DATA INDICATED THAT THE DISTANCE FROM THE XN NIPPLE TO THE TOP OF THE STRADDLE DEPLOYMENT SLEEVE IS 7.0'. 12:00 - 13:40 1.67 RUNCOrvP COMP Logging pass completed, POOH. FP top 2000# of hole with Printed: 8/5/2002 12:18:01 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 9 of 9 BP Operations Summary Report 07 -28A 07 -28A REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Date From - To Hours Task Code NPT Phase 7/31/2002 12:00 - 13:40 1.67 RUNCOrvP COMP 13:40 - 14:05 0.42 RUNCOrvP COMP 14:05 - 15:30 1.42 RIGD P COMP 15:30 - 16:30 1.00 RIGD P COMP 16:30-17:15 0.75 RIGD P CaMP 17:15 -18:15 1.00 MOB P PRE 18:15 - 18:30 0.25 MOB P PRE 18:30 - 20:00 1.50 MOB P PRE 20:00 - 20:15 0.25 MOB P PRE 20:15 - 00:00 3.75 MOB P PRE Start: 7/25/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 7/15/1997 End: Description of Operations 50/50 methanol/H20. Tag up at surface, stand back injector, rig down logging tools. Stab back on tree with nozzle. Blow down coil with N2. Stand back injector, rig down gooseneck, stab injector into stabbing box. Nipple down tree, nipple up tree cap. PT same. All looks good. RIG RELEASE AT 16:00 HRS 7-31-2002. Total of 6 days, 16 hours on well. Lay down derrick in preparation for move to DS 18-18. Safety meeting prior to moving off well. Move rig forward 40 ft. Set down and prepare to Lay down wind walls. Safety meeting prior to laying down wind walls and derrick. Lay down wind walls, Scope down and lay down derrick. Super Suck cuttings tank to move. Rig down Flow back tank, berm and hardline. Plan for pre-rig move meeting at 00:00 hrs, followed by rig move to DS 18-18B. Printed: 8/5/2002 12:18:01 PM qOd-/Oto 14-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 07 -28L 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,356.68' MD Window / Kickoff Survey 12,397.00' MP (if applicable) Projected Survey: 13,725.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attach ment( s) RECEIVED AUG 1 4 2002 AlalkaOil&GasQms.Commi8ion Anc1lf89l J -r- r-..P'ItI..~' j\f fT' V - - g í ~ i .. < I iI <. ~ lZ ~i ft - North Slope Alaska BPXA PBU_EOA DS 07, Slot 07-28 07-28 - 7-28AL 1 Job No. AKMW22125, Surveyed: 28 July, 2002 .-,., SURVEY REPORT 13 August, 2002 Your Ref: API 500292177060 Surface Coordinates: 5950523.12 N, 675841.74 E (700 16' 13.5881" N, 148034' 40.1395" W) Kelly Bushing: 53.25ft above Mean Sea Level sp.I'I'Y-SUI1 DRILLtNG SGAVIc:ès A Halliburton Company Survey Ref: svy11271 Sperry-Sun Drffling Services . Survey Report for 07-28 - 7-28AL 1 Your Ref: API 500292177060 Job No. AKMW22125, Surveyed: 28 July, 2002 BPXA North Slope Alaska PBU EOA DS 07 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (° /1 OOft) 6179.10 N 2050.62 W 5956652.63 N 673647.32 E 5601.4 7 Tie On Point -< 12356.68 93.200 276.400 8937.37 8990.62 12397.00 90.020 275.120 8936.23 8989.48 6183.15 N 2090.71 W 5956655.73 N 673607.14 E 8.501 5634.39 Window Point 12423.68 88.230 279.420 8936.64 8989.89 6186.52 N 2117.17W 5956658.49 N 673580.62 E 17.455 5656.57 12488.85 87.520 285.260 8939.06 8992.31 6200.43 N 2180.76 W 5956670.91 N 673516.72 E 9.021 5713.69 12534.73 91.670 293.570 8939.38 8992.63 6215.67 N 2223.98 W 5956685.13 N 673473.15 E 20.242 5756.30 12566.68 93.510 299.550 8937.94 8991.19 6229.93 N 2252.52 W 5956698.72 N 673444.29 E 19.564 5787.20 12599.05 92.640 305.700 8936.20 8989.45 6247.35 N 2279.73 W 5956715.50 N 673416.68 E 19.161 5819, 16 12629.93 92.460 310.970 8934.83 8988.08 6266.48 N 2303.92 W 5956734.06 N 673392.05 E 17.059 5849.96 12663.38 90.220 317.830 8934.04 8987.29 6289.86 N 2327.79 W 5956756.88 N 673367.63 E 21.567 5883.32 12700,33 90.610 323.980 8933.77 8987.02 6318.52 N 2351.08 W 5956784.99 N 673343.68 E 16.677 591971 12731.80 91.760 331.190 8933.12 8986.37 6345.06 N 2367.94 W 5956811.13 N 673326.21 E 23.195 5949.84 12768.30 92.190 338.530 8931.86 8985.11 6378.06 N 2383.42 W 5956843.76 N 673309.96 E 20.132 5983,18 12805.00 92.550 344.900 8930.34 8983.59 6412.86 N 2394.92 W 5956878.28 N 673297.65 E 17.370 6014.69 12844.35 91.580 337.690 8928.92 8982.17 6450.08 N 2407.52 W 5956915.20 N 673284.18 E 18.476 6048.62 12874.50 90.180 331.010 8928.46 8981.71 6477.24 N 2420.57 W 5956942.04 N 673270.51 E 22.634 6076.28 12901.58 88.330 328.200 8928.81 8982.06 6500.60 N 2434.26 W 5956965.07 N 673256.27 E 12.422 6101.94 12933.75 86.570 321.340 8930.25 8983.50 6526.83 N 2452.79 W 5956990.87 N 673237.13 E 21.994 6133.13 12965.35 89.380 314.840 8931.36 8984.61 6550.32 N 2473.87 W 5957013.85 N 673215.51 E 22.396 6164.45 12998.10 91.930 307.810 8930.99 8984.24 6571.93 N 2498.45 W 5957034.88 N 673190.43 E 22.831 6197.18 13031.73 92.020 302.530 8929.83 8983.08 6591.28 N 2525.91 W 5957053.59 N 673162.52 E 15.693 6230.60 13069.13 90.440 293.570 8929.02 8982.27 6608.84 N 2558.88 W 5957070.38 N 673129.16 E 24.321 6267.00 13117.38 93.080 286.170 8927.54 8980.79 6625.23 N 2604.20 W 5957085.69 N 673083.47 E 16.275 6311,95 13158.98 94.830 289.880 8924.67 8977.92 6638.06 N 2643.65 W 5957097.61 N 673043.72 E 9.841 6350.15 13205.50 90.350 298.490 8922.56 8975.81 6657.08 N 2685.99 W 5951115.63 N 673000.95 E 20.843 6394.59 13246.98 93.080 307.630 8921.32 8974.57 6679.67 N 2720.70 W 5957137.41 N 672965.72 E 22.985 6435.60 13277.78 95.270 314.140 8919.08 8972.33 6699.77 N 2743.92 W 5957156.95 N 672942.05 E 22.246 6466,30 13308.83 94.920 319.230 8916.32 8969.57 6722.26 N 2765.12 W 5957178.95 N 672920.32 E 16.367 6497,07 13348.60 94.040 328.020 8913.20 8966.45 6754.15 N 2788.61 W 5957210.28 N 672896.09 E 22.145 6535,72 13379.91 91.230 333.650 8911.76 8965.01 6781.45 N 2803.85 W 5957237.22 N 672880.22 E 20.078 6565,12 13409.83 89.380 337.340 8911.60 8964.85 6808.67 N 2816.25 W 5957264.14 N 672867.18 E 13.795 6592 34 ------_._---~_. 13 August, 2002 - 10:01 Page 2 0'4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 07-28 - 7-28AL 1 Your Ref: API 500292177060 Job No. AKMW22125 Surveyed: 28 July, 2002 . BPXA North Slope Alaska PBU - EOA DS 07 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 13441.80 87.71 0 343.140 8912.42 8965.67 6838.74 N 2827.05 W 5957293.94 N 672855.68 E 18.873 6620.22 13496.73 88.680 333.820 8914.15 8967.40 6889.75 N 2847.17 W 5957344.47 N 672834.38 E 17.050 6668.87 13528.63 92.810 329.250 8913.74 8966.99 6917.78 N 2862.37 W 5957372.14 N 672818.53 E 19.306 6698.73 13559.98 94.480 323.280 8911.74 8964.99 6943.79 N 2879.73 W 5957397.73 N 672800.57 E 19.736 6728.90 13593.21 90.180 318.530 8910.39 8963.64 6969.54 N 2900.66 W 5957422.99 N 672779.04 E 19.270 6761.59 13633.23 86.750 315.370 8911.46 8964.71 6998.77 N 2927.96 W 5957451.57 N 672751.06 E 11.651 6801.37 13667.80 86.570 309.570 8913.48 8966.73 7022.06 N 2953.41 W 5957474.26 N 672725.08 E 16.757 6835.85 13692.00 88.590 306.930 8914.50 8967.75 7037.03 N 2972.39 W 5957488.78 N 672705.75 E 13.728 6860.00 13725.00 88.590 306.930 8915.31 8968.56 7056.85 N 2998.76 W 5957507.98 N 672678.92 E 0.000 6892.91 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 311.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13725.00ft., The Bottom Hole Displacement is 7667. 57ft. , in the Direction of 336.977° (True). ---- - . -_._..._--~_...~-------~-- 13 August, 2002 - 10:01 Page 3 of4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 07.28 . 7.28AL 1 Your Ref: API 500292177060 Job No. AKMW22125, Surveyed: 28 July, 2002 . North Slope Alaska BPXA PBU_EOA DS 07 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12356.68 12397.00 13725.00 8990.62 8989.48 8968.56 6179.10 N 6183.15 N 7056.85 N 2050.62 W 2090.71 W 2998.76 W Tie On Point Window Point Projected Survey Survey tool program for 07-28 - 7-28AL 1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 9971.64 0.00 9971.64 8026.64 13725.00 8026.64 Good Gyro (07-28) 8968.56 MWD Magnetic (7 -28A) 13 August, 2002 - 10:01 Page 4 0(4 DrillQuest 2.00.08.005 J ~J&\rŒ I:;} ~~~~~L% A.IfASIiA OIL AND GAS CONSERVATION COMMISSION / ! / ¡ / TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: PBU 07-28AL1 BP Exploration (Alaska), Inc. Pennit No: 202-106 Sur Loc: 394' SNL, 339' WEL, Sec. 33, T11N, R14E, UM BtmholeLoc. 1332' NSL, 3318' WEL, Sec. 21, T11N, R14E, UM Dear Mr. Stagg: Enclosed is the approved application for penn it to redrill the above referenced well. The pennit to redrill does not. exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. The pennit is for a new wellbore segment of existing well PBU 7-28A, Pennit No 197-129, API 5-029-21770-01. Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (ßA1JM..J~.1-ë ;~;cbèchsli Taylor Chair BY ORDER OF THE COMMISSION DATED this~day of May, 2002 jj c/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 3-3/4" (' STATE OF ALASKA . ALASKA C..... AND GAS CONSERVATION COM~ JION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 53.25' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028306 7. Unit or Property Name r Prudhoe Bay Unit 8. Well Number 07 .28AL 1 9. Approximate spud date 07101/02 I Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13675' MD I 8911' TVDss 0 17. Anticipated pressure {S;e 20 AAC 25.035 (e) (2)} 93 Maximum surface 2244 psig, At total depth (TVD) 8800' / 3300 psig Setting Depth Top Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staae data) 1285' 12390' 8936' 13665' 8911' Uncemented Slotted Liner ./ v.JGI!- '51/1oL ~ ,~,+fÐ:>- Multilateral 1 a. Type of work IJ Drill II Redrill 0 Re-Entry IJ Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 394' SNL, 339' WEL, SEC. 33, T11N, R14E, UM At top of productive interval 363' NSL, 1818' WEL, SEC. 21, T11 N, R14E, UM At total depth 1332' NSL, 3318' WEL, SEC. 21, T11N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028309,1332' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 12380' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weioht Grade CouplinQ 2-7/8" 6.16# L-80 ST-L 11. Type Bond (See 20 AAC 25.025) I Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Su rface Intermediate Production Liner Liner 14392 feet 8992 feet 14300 feet 8990 feet Length Plugs (measured) RECE~VED Junk (measured) 0 2002 Size Cemented Alaska Oil & Gu~(mS, CommissipÐD Anchorage 110' 3291' 9993' 110' 2995' 8043' 110' 20" 3291' 13-3/8" 9993' 9-5/8" 714' 7" 3972 4-1/2" 2538# Poleset 3000 sx CS III, 600 sx 'G', Top Job 200 sx CS I 875 sx Class 'G', 400 sx CS I 170 sx Class 'G' 401 sx Class 'G' 9847' - 10561' 7932' - 8379' 10419' - 14391' 8313' - 8992' 11955' - 12006', 12124' - 12193', 12240' - 12294', 12537' - 12592', 12710' - 12752', 12854'- 12947', 13024' - 13113', 13163' - 13210', 13404' -13680', 13720' - 13920', 13960' - 14290' true vertical 9007' - 9011', 9002' - 8999', 8998' - 8995', 8990' -8988', 8986' - 8986', 8991' - 8994', 8997' - 8999', 8999' - 8998', 8992' - 8982', 8983' - 8982', 8983' - 8990' II Filing Fee IJ Property Plat II BOP Sketch IJ Diverter Sketch II Drilling Program II Drilling Fluid Program IJ Time vs Depth Plot IJ Refraction Analysis IJ Seabed Report IJ 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge . Signed ~ed s~. . .~.... .'... .............. .. .... ......1ïtl,~ .?~~~IIi~~:,n_g!~e~r . '.' , '.. ?~t~ .... . ~~.~.. . ,,"',,' '.'.'."'.""",...., ..';'.','":,.",.".,:.,>.",.,\,:./.\:",,"";:,/,,';::,;,." ".i ::><r';:..<,)':r)i,:.Ç9#îmj~~jq:"t~eiø:~"~::.'::;;,,><':"\,', ,', "", ::' '¡;":',,,:,"i'<::':,.....,: "'1':::':)'(!,",":" ' Permit Number API Number Approval Date See cover letter 202-- /(5 ~ 50- 029-21770-60 5 I J\.\ .0 ,:2- for other reQuirements Conditions of Approval: Samples Required 0 Yes )š'1 No Mud Log Required 0 Yes J:3 No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required J8I Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other:leS t ß..oP E -~ '3 ~ 00 P).t'. v.J6A- bnglnal Signed By by order of ~;~O~~~i Rev. 12-01.85 Cammy~iTaÕ ~ \ G \ ~m~Lner the commission 20. Attachments Perforation depth: measured Date C-)') If 10(:) Submit In Triplicate BP 7 -28AL 1 CTD Sidetrack Summary of Operations: A CTD through tubing sidetrack is planned for 7 -28A. ¡The coil sidetrack, 7 -28AL 1, will be completed with a unique design that will provide for selective production from either 7 -28A and/or 7 -28AL Y This will be accomplished by using a retrievable whipstock and a through-tubing straddle assembly. Production will be toggled between the 2 legs by installing a sleeve with slickline. Prior to sidetracking, the lower 7 -28A perfs will be isolated by the retrievable w~stock and the existing Zone 1 A perfs will be production tested to confirm that they are not gassed out. Following a successful production test, the 7 -28AL 1 lateral will be drilled and completed with a pre-drilled liner placed just outside the window. The whipstock will then be retrieved and the through-tubing straddle installed. The top of the straddle will be located a few feet below the XN nipple in the tubing tail. Using the XN nipple, slickline will V'"' then be able to install an open sleeve to produce 7 -28A or a plugged and. side-ported sleeve to produce 7- 28AL 1 alone. Both legs can be produced with no sleeve in the straddle..t'The objective is to enable one leg to produce while the other is "off cycle" . Phase 1: Prep work. Planned for June 1 0-20, 2002. 1. Well has just passed a drift, caliper and all mechanical integrity testing. 2. Service coil will clean out fill to 100' below the whipstock anchor setting depth. /" 3. Service coil will set the whipstock anchor/packer and install the tray to effect a temporary plug. 4. Upper Zone 1A perfs in 7-28A will be production tested to confirm low GOR../ Phase 2: Mill window, Drill and Complete sidetrack: Planned for July 1, 2002. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Maximum hole angle will be 93 degrees. ./ Mud Program: . Phase 1: Seawater . Phase 2: Mill with seawater/biozan, drill with 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: The 7-28AL 1 production liner will be 27/8" pre-drilled liner from TD to just outside the window at 12,390' (8936ss). A 27/8" straddle will be installed from a packer at 12,400 (8936ss) to a seal bore at 10,385' (8242ss). Well Control: . BOP diagram is attached. ~ . Pipe rams, blind rams and the CT pack off will be pressure teste!ito 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 93 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . MWD Gamma Ray will be run over all of the open hole section. Hazards ( . The maximum recorded H2S of DS7 is 75 ppm on well 7-22. The closest BHL, well 7 -13a, shows an H2S level of 23 ppm. / No faults are mapped along the well path and no lost circulation is expected. Retrieval of the whipstock tray is essential to a successful multi-Iat completion. A tray with two retrieval options was chosen to improve conditions for retrieval. . . Reservoir Pressure Res. press. is estimated to be 3300 psi at 8800'ss (7.0 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2244 psi. ¡ TREE = , WELLHEAD = ACTUÀ TOR "= . ~ -'. -~ ... ,- ~ KB. ELEV = -. " - BF. ELEV = KOP= Max Angle, = Datum MD = . . . - Datum TVD = FMC GEN 4 FMC - .. eo-. AXELSON 53' ( 1488' 97 @ 1~1f' 11558' . - '. 8800' SS 07-28A L 1 I ( . SAFETY NOTES Proposed CTD Sidetrack , - 2173' l-4-1/2" CAMCO BAL-O SSSV NIP, ID = 3.813" 1 113-3/8" CSG, 72#, L-80, ID = 12.347" l-I 3292' ~ Minimum ID = 3.72588 @ 10379' HES XN NIPPLE 1 TOP OF 7" LNR 1-1 9847' ~ GAS LIFT MANDRELS DEV 1YÆ VLV LATCH 39 CA-MMG RK 42 CA-MMG RK 37 CA-MMG RK -1 ST MD TVD 1 3840 3414 2 7408 6100 3 9743 7850 PORT DA TE ~ 5ð t- 9847' 1-1 BAKER ZXP A<R, ID = 7.500" I 1 10200' 1-1 Upper 4.5 x 2-7/8"straddle Pkr I I 10300' 1-1 2-7/8" Flow Control Sleeve I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9993' ~ I X-Lock w Iported sleeve and seal stem 1-1 10379' I 1 Seal Bore 1-1 10385' I 1 TOP OF 4-1/2" LNR H 10419' 1 MILLOUT WINDOW 10023' - 10031' ÆRFORA TION SUMMARY REF LOG: BHCS ON 02/10/88 ANGLEATTOPÆRF: 80 @ 11955' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4 4 11955-12006 0 08/17/97 2-314 4 12124-12193 0 08/17/97 2-314 4 12240-12294 0 08/17/97 2-3/4 4 12537-12592 0 08/17/97 2-3/4 4 12710-12752 0 08/17/97 2-3/4 4 12854-12947 0 08/17/97 2-3/4 4 13024-13113 0 08/17/97 2-3/4 4 13163-13210 0 08/17/97 2-3/4 4 13404-13680 0 08/17/97 2-3/4 4 13720-13920 0 08/17/97 2-3/4 4 13960-14290 0 08/17/97 1 4-112" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 14391' DATE 06/19/88 08/19/97 12/11/00 .02/14/01 09/26/01 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK CONVERTED TO CANVAS FINAL CORRECTIONS SIS-MD SIS-MD RNITP DA TE REV BY ~ :8 1 10346' l-i 7" X 4-1/2" BAKER SB-3 PKR, ID = 3.875" 1 ~ J' 1 10379' l-i 4-1/2" HES XN NIP, ID = 3.725" 1 I 10401' 1-1 4-1/2" TUBING TAIL WLEG, ID = 3.958" 1 ¡ ¡~ 1--1 ELMD TT NOT LOGGED I 10395' l-i BAKER ZXP A<R, ID = 4.40" 1 10385'. -i 2-7/8" STL Tubing 11940' I ~I 10561' H 7' LNR, 26#, L-SO, 0.0383 bpI, ID = 6.276" I . 11940' l-i 3" seal bore & seal stem 1 ~ 11945'. -1 2-7/8" Blast Joints I 0 ~ 12395' rl 12380' l-i 4-1/2" window fromretrievablew/s 1 ~I 12390' H Top 01 2-7/S" A"e-drilled liner I f¡ fi ~ ~ I 2-7/8" Pre-drilled liner l-i 13665' iI~ ~ ooooooooooo~ ~ ~r 12400' H Lower 4.5 x 2-7/S"straddle A<r I ~-i 14299' I COMMENTS PRUDHOE BAY UNIT WELL: 07-28A ÆRMIT No: 97-1290 API No: 50-029-21770-01 SEe 33 T11 N R14E 4365.6 FEL 4434.09 FNL BP Exploration (Alas ka) 7 -28aL 1 Completion x x I ~' '- "'-,-, "- X-lock (2.62" i.d.) in existing XN nipple '~ ~ l--- ported sleeve X r-';i=~~=~_== seal stem (TIW - 2.355" i.d., Baker 2.375" i.d.) At .. -'---------- seal bore (TIW - 3.00" Ld., Baker - 3.00" Ld.) ~-- ._---------~~_.~..... -.. -'--------~----- Â2000' 2-7/8" ST-L tubing (2.377" pin Ld.) , ~~-,- seal bore & seal stem (TIW - 2.355" Ld., Baker - 2.375" Ld.), pinned to pull latch out of packer t~- . 0 0 0 '. ..~""",',' . . . . . . ',,- -] '- '",''-''-''--- 2-7/8"blast joint (3.22"o.d., 2.441" Ld.) ~ ~ ~ --''---,--, -"--" . '-- latch (TIW - 2.355" Ld., Baker - 1.00" Ld.) ~, --'-'-'---- anchor/packer (TIW - 2.375" Ld., Baker - 1.90" Ld.) ... .. WELLPATH DETAILS Plan#3 07..2aAL 1 800292177080 bp -----------~~------._--~ - -~_.._._._----_.~---~--~~--~-_._-------_._----~--~ 'aNnt W.II~th; Tie on MD; INTEQ ~----______I lEGEND T - g~:~g Ig~:~gk) ^ M 15-01A(15-01A) ¿ 15-02 (15-02) 15-02A(15-02A) 15-02APB1 (15-02AOB1) 15-23 (15-23) Plan#3 07-28Al1 Plan #3 Azimuths to True North Magnetic North: 26.44. Magnetic Field Strength: 57508nT Dip Angle: 80.79. Date: 3/22/2002 Model: BGGM2001 Plan: Plan #3 (07-28/Plan#3 07-28Al1) Crealed By: Bnj Potnis Date: 3/22/2002 BP Amoco Conlact Information: Ria' R.f. Datum: V.Sectlon Anale 311.00' 07.28A 12380.00 Nordic 1 07.28A Direct: (907) 267,6613 E-mail: brij.potnis@intcqcom Baker Hughes INTEQ: (907) 26l'6600 ~~-_.~------_._~_._-------~ ---- ~r:1¿; ~~= :::=i~D +EI-W OLea TFace V8ec Target 7400 ----,~ ~1j§.=QI~n~.õ1~)ì REFERENCE INFORMATION Co-ordinate (N/E¡ Reference: Well Centre: 07-28, True North v~~~¿r~~) ~:~:;:~:: ~r~t~2~ %~~3J.g~~¡e1 Measured Depth Reference: 07-28A 53.25 Calculation Method: Minimum Curvature SECTION DETAILS 1 12" 83.20 278.40 8837.37 8178.t1 .2050.48 0.00 0.00 8332.10 2 t "'.20 2711.81 .838.48 8181.53 ..2073.65 8.3D 203.&9 8348.38 3 1 82.81 278.83 .138.15 818201 .2083.58 20.00 45.00 8352.52 : ~ . ::: =~~ ::=:~~ :m~ii :~!æ ~t.gg 1:::: :::: ! 1æti! 5:: ==: ==:: 8401 88 .2410.05 U:gg ~:gg :;;:::= :0 ~:;k: =:~ ~:::~ ::;::~~ ;æ~ii ::::~ :::: ~i:5 ~5:!! ~. ANNOTATIONS TVD MD 8937.37 123M.58 TIP 8938M 12380.00 KOP 8938.18 12380.00 1 8938.59 12400.00 2 8938.31 12480.80 3 8t39..8 12801.53 4 8935..0 12801.83 5 8928.52 13001.83 8 8918.33 13251.83 7 8910.71 13575.00 TD +E1-W Shape 07-28AU P~on31 0,00 6841.46 -3066.62 ~n I¡~i¡~¡ . ifi i~ ~mfi ~i ---- '~"""'." '", \ -4000 -3900 -3800 -3700 -3600 -3500 -3400 -3300 -3200 -3100 -3000 -2900 -2800 -2700 -2600 -2500 -2400 -2300 -2200 -21 00 -2000 -1900 -1800-1700 -1600 -1500 -1400 West(-)/East(+) [100ft/in] ~ " - --+<,,-- - - -, ''OO~çr~2J \fI~~QH8Æ:J: \ )-T~1 ,\; J!f,(11!.~LjJJ4J '+~ !OH"((07:~8~)J - 5750 5800 5850 5900 5950 6000 6050 6100 6150 6200 6250 6300 6350 6400 6450 6500 6550 6600 6650 6700 6750 6800 6850 6900 6950 7000 7050 Vertical Section at 311.00° [50ft/in] -~~---~-~-----~-----------------~----_._--_._~-- _.~------_._--------- - 3/22/2002 3:50 PM- Company: I Field: Site: Well: , Wellpatb: ObP BP Baker Hughes INTEQ Planning Report BP Amoco Prudhoe Bay PB OS 07 07-28 Plan#3 07 -28Al1 ( 8.. - ...... INTEQ Date: .., 3/22/2002 Time: 15:52:11 CCHJrdinate(NE) Reference: Well: 07..28, True North Vertical (TVD)Reference: System: Mean Sea level Seetion(VS) Reference: Well (0.00N,0.00E,311.00Azi) S_urv!~~.!'lc~tion Method: M!nimum Curvature Db: -----'----""~-'--,~--- ----.-- Field: , .-.,,-.--.-..-.,---. -"---'---_.'------'--'-'---'---"'--'-'---'-----~---'-- _._,-_._~.__._---- - ----- Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Datum: Mean Sea level Map Zone: Coordinate System: Geomagnetic Model: --""".~--------"-'-'-- ---------------- 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 ¡------_..,- Well: Page: Oracle .------.-- Alaska, Zone 4 Well Centre BGGM2001 5948144.78 ft 677382.28 ft Latitude: Longitude: North Reference: Grid Convergence: 70 15 49.847 N 148 33 56.934 W True 1.35 deg ----""-",- -------.-.-.-------..---.-------.----------- ---"---_.._-'-- 07-28 07-28 Well Position: Latitude: Longitude: 28 70 16 13.588 N 148 34 40.140 W Slot Name: +N/-S 2414.13 ft Northing: 5950523.12 ft +E/-W -1484.18 ft Easting: 675841.74 ft Position Uncertainty: 0.00 ft ----------- ---'--''"-'--'''_..._-_.__.--~---------~---- Wellpath: Plan#3 07-28AL 1 500292177060 Current Datum: 07-28A Magnetic Data: 3/22/2002 Field Strength: 57508 nT Vertical Section: Depth From (TVD) ft ----'---"---'..'-_._--_.~ 0.00 Targets Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Height 53.25 ft +N/-S ft ~..__..._.._~-----------~_._-~.~._-"._-,--_.-.- 0.00 ---~--'---_..'--- ------,-------~ Map Map Description TVD +N/-S +E/-W Nor:tbing Easting Dip. Dir. ft . ft ft ft ft ~-~._---_.~------- ---~------------------_._--~--------~--~------ 07-28AL1 Polygon3.1 0.00 6841.46 -3066.62 5957290.63 672616.33 -Polygon 1 0.00 6841.46 -3066.62 5957290.63 672616.33 -Polygon 2 0.00 7165.33 -3013.97 5957615.62 672661.40 -Polygon 3 0.00 6875.73 -2610.66 5957335.54 673071.34 -Polygon 4 0.00 6380.00 -2162.18 5956850.45 673531.24 -Polygon 5 0.00 6234.98 -2375.67 5956700.50 673321.21 -Polygon 6 0.00 6639.32 -2766.28 5957095.57 672921.29 07 -28AL 1 T3.4 Annotation Name 07 -28Al1 T3.3 07 -28AL 1 T3.2 8910.00 7014.43 -3003.88 5957465.00 672675.00 8915.00 6833.04 -2733.03 5957290.00 672950.00 8935.00 6424.36 -2367.45 5956890.00 673325.00 8940.00 6291.70 -2255.51 5956760.00 673440.00 07 -28A 12380.00 ft Mean Sea Level 26.44 deg 80.79 deg Direction deg 311.00 <--- Latitude..--:> <-- , Longitude--,.> Deg. Min. See DegMin See -~-~---- 70 17 20.868 N 148 36 9.493 W 70 17 20.868 N 148 36 9.493 W 70 17 24.053 N 148 36 7.963 W 70 17 21.206 N 148 35 56.208 W 70 17 16.332 N 148 35 43.136 W 70 17 14.905 N 148 35 49.355 W 70 17 18.881 N 148 36 0.740 W 70 17 22.569 N 148 36 7.667 W 70 17 20.786 N 148 35 59.773 W 70 17 16.768 N 148 3549.117 W 70 17 15.463 N 148 3545.855 W 12356.68 12380.00 12390.00 12400.00 12450.90 12601.53 12801.53 13001.53 13251.53 13675.00 _.__._-,~_.-_.__.-._- 07 -28AL 1 T3.1 ------ 8937.37 8936.48 8936.15 8935.69 8936.31 8939.96 8935.80 8928.62 8915.33 8910.71 TIP KOP 1 2 3 4 5 6 7 TO ObP ( BP B.8 SA- ...... Baker Hughes INTEQ Planning Report LN'TEQ BP Amoco Date: 3/2212002 Time: 15:52:11 Page: 2 Prudhoe Bay C&-ordinate(NE).Reference: Well:. 07-28, True North PB DS.07 Vertical (fVD) Reference: System: Mean Sea Level 07-28 Section (VS) Reference: Well (0.OON,0.OOE,311.00Azi) Plan#3 07 -28AL 1 Survey Calculation Method: Minimum Curvature Db: Oracle -~"'-'-'-"---'---'-~----- Plan #3 Date Composed: 3/22/2002 Identical to Lamar's Plan #3 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Azim TVD +N/-S +EI-W DLS Build Turn TFO Target ft deg deg ft ft ft degl10Oft. deg/100ft .deg/100ft deg - 12356.68 93.20 276.40 8937.37 6179.11 -2050.48 0.00 0.00 0.00 0.00 12380.00 91.20 275.51 8936.48 6181.53 -2073.65 9.39 -8.58 -3.82 203.99 12390.00 92.61 276.93 8936.15 6182.61 -2083.59 20.00 14.14 14.16 45.00 12400.00 92.61 278.43 8935.69 6183.94 -2093.49 15.00 -0.01 15.02 90.00 12450.90 86.00 282.25 8936.31 6193.07 -2143.52 15.00 -12.99 7.50 150.00 12601.53 91.25 304.24 8939.96 6252.13 -2280.98 15.00 3.49 14.60 77.00 12801.53 91.08 334.24 8935.80 6401.86 -2410.05 15.00 -0.08 15.00 90.00 13001.53 92.94 304.28 8928.62 6551.59 -2538.98 15.00 0.93 -14.98 274.00 13251.53 92.94 341.83 8915.33 6747.56 -2686.36 15.00 0.00 15.02 89.00 13675.00 88.18 278.47 8910.71 7006.73 -2993.77 15.00 -1.12 -14.96 266.50 Survey ft ft ft ft deg/10Oft deg ---_._---'------'---_._-----'-------~'- ---'------~'----------------------'-'. ---- 12356.68 93.20 8937.37 6179.11 -2050.48 5956652.24 673647.60 5601.37 0.00 0.00 TIP 12375.00 91.63 8936.60 6181.04 -2068.68 5956653.74 673629.36 5616.38 9.39 203.99 MWD 12380.00 91.20 8936.48 6181.53 -2073.65 5956654.11 673624.37 5620.45 9.39 /"203.96 KOP 12390.00 92.61 8936.15 6182.61 -2083.59 5956654.96 673614.42 5628.66 20.00 45.00 1 12400.00 92.61 8935.69 6183.94 -2093.49 5956656.06 673604.49 5637.01 15.00 90.00 2 12425.00 89.36 280.30 8935.26 6188.01 -2118.15 5956659.55 673579.74 5658.28 15.00 150.00 MWD 12450.00 86.12 282.18 8936.24 6192.88 -2142.64 5956663.85 673555.14 5679.97 15.00 150.03 MWD 12450.90 86.00 282.25 8936.31 6193.07 -2143.52 5956664.02 673554.26 5680.75 14.97 149.96 3 12475.00 86.82 285.77 8937.82 6198.89 -2166.86 5956669.29 673530.80 5702.18 15.00 77.00 MWD 12500.00 87.68 289.43 8939.02 6206.44 -2190.65 5956676.28 673506.83 5725.10 15.00 76.78 MWD 12525.00 88.56 293.08 8939.84 6215.49 -2213.94 5956684.79 673483.34 5748.61 15.00 76.60 MWD 12550.00 89.44 296.72 8940.27 6226.01 -2236.61 5956694.78 673460.44 5772.62 15.00 76.48 MWD 12575.00 90.32 300.37 8940.33 6237.96 -2258.56 5956706.21 673438.21 5797.03 15.00 76.42 MWD 12600.00 91.20 304.01 8940.00 6251.27 -2279.71 5956719.02 673416.75 5821.73 15.00 76.41 MWD 12601.53 91.25 304.24 8939.96 6252.13 -2280.98 5956719.85 673415.47 5823.24 15.00 76.46 4 12625.00 91.25 307.76 8939.45 6265.92 -2299.96 5956733.19 673396.17 5846.62 15.00 90.00 MWD 12650.00 91.24 311.51 8938.91 6281.86 -2319.21 5956748.68 673376.56 5871.60 15.00 90.08 MWD 12675.00 91.23 315.26 8938.37 6299.02 -2337.37 5956765.41 673358.00 5896.57 15.00 90.16 MWD 12700.00 91.21 319.01 8937.84 6317.34 -2354.37 5956783.32 673340.58 5921.41 15.00 90.24 MWD 12725.00 91.19 322.76 8937.32 6336.73 -2370.14 5956802.34 673324.37 5946.03 15.00 90.32 MWD 12750.00 91.16 326.51 8936.81 6357.11 -2384.60 5956822.37 673309.43 5970.32 15.00 90.40 MWD 12775.00 91.12 330.26 8936.31 6378.39 -2397.70 5956843.34 673295.84 5994.17 15.00 90.47 MWD 12800.00 91.09 334.01 8935.83 6400.49 -2409.38 5956865.15 673283.65 6017.48 15.00 90.55 MWD 12801.53 91.08 334.24 8935.80 6401.86 -2410.05 5956866.51 673282.95 6018.88 15.00 90.62 5 12825.00 91.33 330.73 8935.31 6422.67 -2420.88 5956887.06 673271.63 6040.71 15.00 274.00 MWD 12850.00 91.58 326.99 8934.67 6444.06 -2433.81 5956908.14 673258.21 6064.50 15.00 273.93 MWD 12875.00 91.83 323.24 8933.93 6464.55 -2448.10 5956928.29 673243.44 6088.73 15.00 273.83 MWD 12900.00 92.07 319.50 8933.08 6484.07 -2463.69 5956947.44 673227.40 6113.30 15.00 273.72 MWD 12925.00 92.30 315.75 8932.13 6502.52 -2480.53 5956965.49 673210.14 6138.11 15.00 273.59 MWD 12950.00 92.52 312.01 8931.08 6519.83 -2498.53 5956982.37 673191.74 6163.05 15.00 273.45 MWD 12975.00 92.73 308.26 8929.93 6535.92 -2517.62 5956998.02 673172.28 6188.02 15.00 273.29 MWD 13000.00 92.93 304.51 8928.70 6550.73 -2537.72 5957012.35 673151.84 6212.90 15.00 273.12 MWD 13001.53 92.94 304.28 8928.62 6551.59 -2538.98 5957013.18 673150.56 6214.42 15.00 272.94 6 13025.00 92.99 307.80 8927.41 6565.38 -2557.93 5957026.52 673131.30 6237.77 15.00 89.00 MWD 13050.00 93.04 311.56 8926.09 6581.32 -2577.14 5957042.01 673111.72 6262.72 15.00 89.18 MWD 13075.00 93.07 315.31 8924.76 6598.48 -2595.26 5957058.74 673093.20 6287.66 15.00 89.38 MWD 13100.00 93.09 319.07 8923.41 6616.79 -2612.22 5957076.65 673075.82 6312.48 15.00 89.58 MWD ~-----------,..- .--""-----------.----- --.._____ _1 ObP ( BP .iï8 .... Baker Hughes INTEQ Planning Report L"fTEQ Company: BP Amoco Date: 312212002 Time: 15:52:11 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07-28. True North . Site: PB OS 07 Vertical(fVD) Reference: System: Mean Sea Level . Well: 07-28 Section (VS) Referenee: Well (0.ooN,O.00E,311.00Azi) Wellpatb: Plan#3 07-28AL 1 Survey Calculation Method: Minimum Curvature Db: Oracle ---"-'-"'---_.__._-~- --,---~_._--_._--- Survey MD Incl Azim SSTVD NIS EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft degl100ft deg --.---.-- -,- ,-- 13125.00 93.10 322.82 8922.06 6636.17 -2627.95 5957095.66 673059.64 6337.06 15.00 89.78 MWD 13150.00 93.10 326.58 8920.71 6656.54 -2642.37 5957115.68 673044.75 6361.31 15.00 89.99 MWD 13175.00 93.08 330.34 8919.36 6677.82 -2655.43 5957136.64 673031.20 6385.12 15.00 90.19 MWD 13200.00 93.05 334.09 8918.03 6699.90 -2667.06 5957158.45 673019.05 6408.39 15.00 90.39 MWD 13225.00 93.00 337.85 8916.71 6722.69 -2677.23 5957181.00 673008.36 6431.01 15.00 90.59 MWD 13250.00 92.94 341.60 8915.41 6746.11 -2685.88 5957204.20 672999.17 6452.90 15.00 90.79 MWD 13251.53 92.94 341.83 8915.33 6747.56 -2686.36 5957205.64 672998.65 6454.22 15.00 90.98 7 13275.00 92.72 338.31 8914.17 6769.59 -2694.35 5957227.48 672990.15 6474.70 15.00 266.50 MWD 13300.00 92.47 334.57 8913.04 6792.48 -2704.33 5957250.13 672979.64 6497.25 15.00 266.33 MWD 13325.00 92.22 330.82 8912.02 6814.67 -2715.79 5957272.05 672967.67 6520.46 15.00 266.16 MWD 13350.00 91.95 327.08 8911.11 6836.07 -2728.67 5957293.14 672954.29 6544.22 15.00 266.00 MWD 13375.00 91.68 323.34 8910.32 6856.59 -2742.92 5957313.31 672939.56 6568.44 15.00 265.87 MWD 13400.00 91.39 319.60 8909.65 6876.14 -2758.49 5957332.49 672923.54 6593.01 15.00 265.75 MWD 13425.00 91.11 315.86 8909.10 6894.63 -2775.30 5957350.58 672906.30 6617.83 15.00 265.65 MWD 13450.00 90.81 312.12 8908.68 6911.98 -2793.28 5957367.51 672887.92 6642.79 15.00 265.57 MWD 13475.00 90.52 308.38 8908.39 6928.13 -2812.36 5957383.21 672868.48 6667.78 15.00 265.50 MWD 13500.00 90.22 304.64 8908.23 6943.00 -2832.45 5957397.60 672848.04 6692.70 15.00 265.46 MWD 13525.00 89.92 300.90 8908.20 6956.53 -2853.47 5957410.64 672826.72 6717.43 15.00 265.44 MWD 13550.00 89.62 297.16 8908.30 6968.66 -2875.32 5957422.25 672804.59 6741.89 15.00 265.43 MWD 13575.00 89.33 293.43 8908.53 6979.34 -2897.92 5957432.40 672781.75 6765.95 15.00 265.45 MWD 13600.00 89.03 289.69 8908.88 6988.53 -2921.16 5957441.04 672758.30 6789.52 15.00 265.48 MWD 13625.00 88.74 285.95 8909.37 6996.17 -2944.96 5957448.13 672734.33 6812.49 15.00 265.53 MWD 13650.00 88.46 282.21 8909.98 7002.25 -2969.19 5957453.64 672709.96 6834.77 15.00 265.61 MWD 13675.00 88.18 278.47 8910.71 7006.73 -2993.77 5957457.54 672685.29 6856.26 15.00 265.70 TO -~----_._- -.'-'--'----'--.--"'-'---------'"'-'-----'- All Measurements are from top of Riser L- CD en .- a:: top of bag bttm of bag middle of slips Blind/Shears middle of pipes 2 3/8" combi ram/slips --'- middle of flow cross Mud Cross ......-- middle of blind/shears variable bore pipe 3 1/2".27/8" middle of pipe/slips I 2 3/8" combi ram/slips Flow Tee '."""................. ~-_......-_......- ~' '-- ....................... _.........../-~ ( 5/9/2002 BAG TOTs Mud Cross TOTs H206704 DATE Oi1-/ i 1 /02 CHECK NO. 00206704 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS too. 00 VENDOR DISCOUNT ALASKAOILA NET l()O,OO 00 040902 CK040902F PYMT COMMENTS: HANDL:NG INST: PERMIT TO DRILL FEE SfH - TERRIE HUBBLE X4628 ö'l.?ßA LI THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) .INC. P.O. BOX 196612 ANCHORAGE,ALASKA99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 206704 CONSOLIDATED COMMERCIAL ACCOUNT PAY 56-389 412 ~" 0020670.q. t-.! 00/100************************************* US DOLLAH 0 ILAND GAS CONSERVATIONCOMMISSTON 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE DATE 04/11/02 AMOUNT $100- O() To The ORDER Of NOT VALID AFTER 120 DAYS AK ç¿~.__r![í!;L(~~ III 20 b ? 0 1.111 .: 0... ~ 20 3811 51: 008 I. I. ~ 11118 CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL Rev: 5/6/02 C\jody\templates '. TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME/ð4 O)-2?A¿ I CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL "CLUE" The permit is for a new wellbore segment of existing well I'j,LI 7- 2.--f:A., Permit N°,/17../2.1API No.Se -<:>2..1-.:J../77"-ó I (If API number last two (2) Production should continue to be reported as a function of digits are between 60-69) the original API number stated above. v PILOT HOLE (PH) In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD <-> SP ACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. /?~q WELL PERMIT CHECKLIST COMPANY NX WELLNAMEð?-Z~~¿/ , FIELD & POOL ~7'.ð~~A INITCLASS /:)P,V /-oJ J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . .. . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . .. . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to ~Soo psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . ~R Ç>j\T9 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ¡f{f":, $//{/07 - 34. Contact name/phone for weekly progress reports [exploratory 0 ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. GEOLOGY: ENGINEERING: UIC/Annular: COMM ",'L .~ \fJ6k ~Rø~ ENGINEERING APPR DA"~J Wb1\- Slj~OL /!{;!1Yr¡ 5(,..... 0::> GEOLOGY APPR DATE $$~ ~ COT DTS OJ/Iv G:\geology\permits \checklist.doc PROGRAM: Exp - Dev - Redrll - Serv - Wellbore seg -X Ann. disposal para req - GEOLAREA <?7/j UNIT# //h.,é(5 ON/OFF SHORE ~N ~~ Y N Y N 'Y N Y N Y N Y N Y N Y N Y N '0N -y N ~¡J/A- '~. 51¡p~i d N & N c:r ¡;)lÁ --¥-N- ? f.t ~ ( \t1 v') e-¡.;' S .þtYj ~. éÐN c9 ~ /\LIt\- ~ ~ ¡"v¡S (l > U<I<f (J ç¿ . ~N æN (j) N ~~ eAly...C.. û)N Y N Y ~ j Æ~fl~ Comments/Instructions: Well H ¡story 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 information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special'effort has been made to chronologically organize this Cfltegory of information. aca-/o0 II 50g Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 07 08:39:40 2003 Reel Header Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 02 / 07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/02/07 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 7-28AL1 500292177060 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 06-FEB-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22125 S. LATZ EGBEJIMBA/WH MWDRUN 2 AK-MW-22125 S. LATZ EGBEJIMBA/WH # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 11N 14E 394 339 MSL 0) 53.25 24.10 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.700 4.500 12397.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT APPROXIMATELY 12397'MD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 8/29/02, 6. MWD RUNS 1 & 2 REPRESENT WELL 7-28AL1 WITH API#: 50-029-21770-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13725'MD/8915'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .03/02/07 Maximum Physical Record. .65535 F i 1 e Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 12382.5 12413.5 STOP DEPTH 13695.5 13725.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 12382.5 2 12481.0 MERGE BASE 12481.0 13725.5 ( $ # REMARKS: MERGED MAIN 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 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12382.5 13725.5 13054 2687 12382.5 13725.5 ROP MWD FT/H 0.65 3135.09 119.892 2625 12413.5 13725.5 GR MWD API 26.08 283.06 69.381 2627 12382.5 13695.5 First Reading For Entire File....... ...12382.5 Last Reading For Entire File.. ....... ..13725.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/07 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...... .03/02/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Cormnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 2 header data for each bit run in separate files. 1 .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 12382.5 12413.5 STOP DEPTH 12451.0 12481.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG 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 26-JUL-02 Insite 3.30 Memory 12481.0 12413.0 12481.0 87.6 90.0 TOOL NUMBER TLG002 3.700 12397.0 Flo Pro 8.60 52.0 9.3 23000 11.6 .000 .000 .000 .000 .0 162.0 .0 .0 ( ( Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12382.5 12481 12431.8 198 12382.5 12481 ROP MWD010 FT/H 8.15 462.82 72.369 136 12413.5 12481 GR MWD010 API 40.33 259.22 67.7437 138 12382.5 12451 First Reading For Entire File......... .12382.5 Last Reading For Entire File.......... .12481 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation. ..... .03/02/07 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...... .03/02/07 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 12451.5 12481.5 STOP DEPTH 13695.5 13725.5 # 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 28-JUL-02 Insite 3.30 Memory 13725.0 12481.0 13725.0 ( MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG 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 ( 86.6 95.3 TOOL NUMBER TLG033 3.700 12397.0 Flo Pro 8.60 52.0 8.9 23000 9.2 .000 .000 .000 .000 .0 171.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12451.5 13725.5 13088.5 2549 12451.5 13725.5 ROP MWD020 FT/H 0.65 3135.09 122.489 2489 12481.5 13725.5 GR MWD020 API 26.08 283.06 69.4718 2489 12451.5 13695.5 First Reading For Entire File......... .12451.5 Last Reading For Entire File.......... .13725.5 ( ( File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/07 Maximum Physical Record. .65535 File Type........ ....... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 02 / 07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........ ....... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments... ..... ........ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 02 / 07 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