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Home My WebLink About200-061 Ima~;)roject Well History'File Cove~ge 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. ~ OO ~_ L Well History File Identifier RESCAN DIGIT/~L DATA OVERSIZED (Scannable) Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [] Poor Quality Origi hals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: · ~ Other Project Proofing BY; BEVERLY ROBIN VINCENT SHERY~WINDY Scanning Preparation c:~x 30 = ~ ~) + BEVERLY ROBIN VINCENT SHERYL ~IJVINDY BY: DATE:~~,~S/ = TOTAL PAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ..~ YES ,,,,,,,.,, ,,,,....., ' Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPA,.I~3fE'~ERE FOUND: YES BY: BEVERLY ROB,N V,.CEN~ S.ERYL ~AR,{~'"~'~.~ (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN~II~31VIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) NO NO RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ~SI General Notes or Comments about this file: Quality Checked 12110102Rev3NOTScanned.wpd 15-12A (200-061) and 15-12B (206-087) . . Ladies, I am reviewing the 407 for 15-12B. Lots of work to get what looks like a really nice well. Would you please get with whoever does the drawings. According to the work summaries, the drawing sections below the EZSVjwhipstock are not correct. I am not sure that there is much benefit to be realized by redoing the drawings since that section of the wellbore has been effectively plugged, but an EZSV was set at -8284' with 15 bbls of cement spotted on top. Then the EZSVjwhipstock was installed at -5637'. The drawing submitted with the 15-12A 407 for abandonment does have both EZSVs listed, but no depth are entered. Thanks much for passing this on. Call or message with any questions. Tom Maunder, PE AOGCC .~ ~ c::a ~\,)..) \ ~ Ç: S \.) ~ \V\.tA- ~'f "'-O-'-.)(è 'o~~\, ,,\,~~c¿, wI -\-~c:.,. \"'-\D,"\I-~.c.~-;\\'ò1 If) ~ ,;2/1 -O~ì SCANNED fEB 0 1 2007 1 of 1 2/1/2007 10:21 AM 5-1/8" FMC FMC AXB..SON 15-12.mporary Suspension DRLG DRAFT COMMENTS ORIGINAL COM PLETION CTD SIDETRACK CORRECTIONS 15-12B (wp04) Side track 15-12B (w p05) Side track 15-12B Updated casing depths TREE = WB..LHËAß'= A CTUA TOR = KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD = Datum ND = 7,700'MD ~ \' ~\ t;:. <> Q.c...~oV\ O~ ~~'-.)..)\ ~':> hC \-<-O,~c.... \- S~<2: "\("JS -~f~, ~0Q'4... ~C)..\---r þ~ 1YV\';}-kC~ \s...\~ DATE 11/05/81 08/04/00 08/29/01 05/10/06 05/17/06 06/14/06 REV BY Cl-VKAK RLP RLP RLP DATE 08/14/06 08/19/06 2482' H 13-3/8" CSG, 72#, L-80, ID = 12.347" 2901' I., 4-1/2", 12.6#,L-80, IBT-M tbg kill string 2979' H 7" Scab LNR HGR 5471' H 7" Liner Hanger I 15637" 5654'1-1 9-5/8" Whipstock, rríllout window N/A H 9-5/8" EZSV N/A H Top of Cement 15 BBL N/A H 9-5/8" EZSV N/A H 5-1/2" TBG-PC, 17#. L-80, .0232bpf, 10=4.892" N/A I., 3-1/2" TBG, 93#, L-80, .0087bpf, ID = 2.992" 7"EZSV 7" CSG. 26#. L-80. .0383 bpf. ID = 6.276" 6.125" New Formation into fault with 500 bbVhr losses \S-\~ ß \S'-\'ð--!\ REV BY RLP TLH PRUDHOE BA Y UNIT WB..L: 15-128 PERMIT: API No: 50-029-20665-02 SEe 22, T11 N. R14E, 2113' FNL & 3803' FB.. COMMENTS Temporary secure & RDMO DEPTH CORRECTIONS BP Exploration (Alaska) Digit~l Wellfile .. Well Events for SuñaceWell - 15-12 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS3 -> 15 -> 15-12 Date Range: 19/Jun/2006 to 14/Aug/2006 Data Source(s): DIMS, AWGRS .. Page 1 of 3 Events Source Well Date Description DIMS 15-12 08/14/2006 RIH with kill string, land hanger, test hanger and TWC, N/D BOPE, N/U tree, freeze protect, J install and test BPV. 0 A W.GRS 15-12B 08/14/2006 PULLED A 4" CIW TWC THRU TREE-RIG COMPLETION. AWGRS 15-12B 08/14/2006 SET 4" CIW BPV FOR RIG TO MOVE OFF OF WELL ( DIMS 15-12 08/13/2006 RIH and set EZSV at 8,850', POH laying down dp, pull wear bushing, run 4-1/2" tubing kill C- DIMS string. 15-12 08/12/2006 Drill float equip, displace mud with 8.5 ppg Flo Pro, drill 42', lose eirc, POH, LD bha, RIH iF ~-- w/EZSV. ~ o )dIMS 15-12 08/11/2006 Wait on orders, POH w/klll string, P/U bha, RIH, Drill float equip and cement to 8,877'. ç' ~ DIMS 15-12 08/10/2006 Wait on orders from town, clean and paint pipe shed and inside derrick wind walls. J() o DIMS 15-12 08/09/2006 P/U bha, TIH, drill fit equip in scab liner, RIH to LC in 7" drlg liner, test 3,500 psi f/30 min, 0 Cb )dtMS POH, LID bha, RIH to 2,448' with dp, í 15-12 08/08/2006 Wait on orders, POH w/kill string, P/U bha ~ DIMS 15-12 08/07/2006 Lay down bha, RIH to 2,448' with kill string, wait on orders from town. o DIMS 15-12 08/06/2006 Test BOPE, P/U bha, TIH, drill cement to 5,370', POH, LID bha, RIH with mule shoe & 10 rb DIMS stands of dp, WOO. 15-12 08/05/2006 Pick up and run 7" scab liner, cement, set hanger and packer, POH with running tool, flush Ó ..... --- BOP. VJ DIMS 15-12 08/04/2006 RIH w/7" drilling liner, circ, cement and set. Circ out contaminated cement, POH, R/U to run rb 7" scab liner. - - t DIMS 15-12 08/03/2006 Circ hole clean, POH, repair pipe skate, LID bha, fix flow line leak, P/U and RIH w/7" drlg \.n liner. - DIMS 15-12 08/02/2006 TD intermediate hole at 8,957', short trip to window, pump high visc sweep,circulate hole clean. DIM~ 15-12 08/01/2006 Directional drilled 8-1/2" intermediate hole as per SSDS dd's. QIMS 15-12 07/31/2006 Condo mud 9.2 ppg, FIT, eirc. & Condo mud, Drill 8 1/2" hole 5686 -7314' DIMS 15-12 07/30/2006 CBU,FIT, Mad pass log w/MWD, POH w/mllls,LlD milling BHA, Flush Stack, M/U 8 1/2" drilling BHA, RIH, Run through window and drill 20' of new hole, CBU )dIMS 15-12 07/29/2006 P/U DC's, M/U Whipstock and Milling assembly, RIH, orient whipstock and set, Displace to 9.0 ppg milling fluid, Mill window, eirc. hole clean DIMS 15-12 07/28/2006 Set & test storm packer @ 35'md,N/D BOPE's, Change out 9 5/8" packoff and tubing spool, N/U BOPE's, Test new spool and packoff, Screw in & pull storm packer, LID, storm packer and running tools, POH with 34 stands of 4" DP DIMS 15-12 07/27/2006 Cement plug on top of # 1 EZSV, Circ. 120 deg brine in 9 5/8" csg @ 2500' to help vent OA (9 5/8" x 13 3/8"), R/U SWS, gauge ring run, SWS set EZSV @ 5662', Test EZSV plug to 3500 psi, R/D SWS, P/U 4" 102 joints DP DIMS 15-12 07/26/2006 Isolate casing leak with RTTS, Test casing, POH w/RTTS, R/U SWS WIREUNE, WOO, RIH with SWS wlreline and EZSV, abort EZSV run and RD SWS, P/U 3 1/2" cement stinger, RIH to 8282', eirc. hole and R/U to cement DIMS 15-12 07/25/2006 POH w/csg. scpr assembly, R/U and run SWS wlreline usit log and set EZSV @ 8287', R/D SWS and M/U RTTS and RIH to test casing, Perform casing intergrlty tests AWGRS 15-12B 07/25/2006 T/I/O=O/O/VAC, Temp=SI. OA FL (pre-LDS drill-out/OA FL Depress w/N2). OA FL @ 36' (2 bbls). Staged N2 rack for upcoming OA FL depress. DIMS 15-12 07/24/2006 P/u 9 5/8 csg. scpr. assembly & RIH, Circ. well clean, monitor well, service rig, cut drilling line POOH w/ csg. scpr. A WG..ßS 15-12B 07/24/2006 Lockdown Screw Drill-Out @ Nabors 27E Planning. Clint Miller from FMC, made Plan Forward. Met with Bill Decker to finalize operations, Andrea Hughes to review. QIMS 15-12 07/23/2006 Perforate & cut 3 1/2" tubing, L/D 3 1/2' tubing, LID 5 1/2" casing, R/U to test stack and test BOPE's AWGRS 15-12B 07/23/2006 Nabors Rig 27E on well, prep job for Lockdown Screws for drill out. Tuboscope, FMC, Cameron, and Colburn Machine. QIMS 15-12 07/22/2006 Finish circulating 5 1/2" casing, Flow check well(static), L/D 5 1/2" casing, Service Rig, Repair TDS compensator, LID 5 1/2"casing, (3 1/2" tubing stub in jt 190) Circ.,R/u SWS http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 9/1312006 ß~¿ '}Jf!o~ RECE\VED . STATE OF ALASKA . " ALASKA OIL AND GAS CONSERVATION COMW'SSION SEP 1 4 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Commission Alaska Oil & Gas Cons. . .- 1 a. Well Status: DOil DGas D Plugged l8I Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 l8I Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 7/27/2006 200-061 306-225 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 07/24/2000 50-029-20665-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 07/30/2000 PBU 15-12A 2113' FNL, 3803' FEL, SEC. 22, T11N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 3740' FNL, 2088' FEL, SEC. 22, T11N, R14E, UM 60' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 2398' FNL, 2235' FEL, SEC. 22, T11N, R14E, UM 10696 + 8852 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 677429 y- 5959402 Zone- ASP4 10730 + 8855 Ft ADL 028306 TPI: x- 679188 y- 5957818 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 679007 y- 5959155 Zone- ASP4 None MD DYes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1900' (Approx.) 21. Logs Run: MWD, MEM GR / CNL 22. CASING, LINER AND CEMENTING RECORD . . .. . SETTING DEP,HMb SETTING DEPTI-\TVO HOLE . .... ." '.' " .... S,ZE Wr·fuFT. GRADE Top BOTTOM Top BOTTOM SIZE ^ < 0; ....... ....... 'ULLo;:U 20" 91.5# H-40 Surface 80' Surface 80' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2482' Surface 2482' 17-112" 2500 sx Fondu 400 sx PF 'C' 9-5/8" 47# L-80 Surface 8697' Surface 8261' 12-1/4" 250 sx Class 'G' 7" 29# L-80 8367' 9101' 7944' 8652' 8-1/2" 300 sx Class 'G' 2-7/8" 6.5# L-80 8283' 10730' 7863' 8855' 4-1/8" 108 sx LARC 23. Perforations open to Production (MD + TVD of Top and 24. i....··.. ....>< UBING <.' .... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2",17#, L-BO x 4-1/2".12.6#, L-BO 7845' - 8445' 8348' MD TVD MD TVD 3-1/2",9.3#, L-80 7845' - 8280' 8252' SCìANNED SEP 2, 0 20GB 25. ACIIJ.. ,.. ',... .~Yc....'.·.······ ....... ...""y,,,.. , ...... . DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8287' Set EZSV 5770' P&A with 15 Bbls Class 'G' 5662' Set 2nd EZSV w/ Whipstock on Top 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS 8Ft SEP 1 9 2006 Form 10-407 Revised 1 (j0~ I GIN A L CONTINUED ON REVERSE SIDE G ~8. GEOLOGIC MARK 29. ORMATION TESTS NAME MD TVD Include and brie y summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 8694' 8259' None Shublik 8736' 8299' Sadlerochit 8800' 8361' Zone 1B 9251' 8779' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram Signed Terrie Hubble Title Technical Assistant Date Cfl ( r:j 0 PBU 15-12A Well Number 200-061 306-225 Permit No. / A roval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Ron Phillips, 564-5913 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Digital Wellfile . . Page 1 of 3 Well Events for SurfaceWell - 15-12 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS3 -> 15 -> 15-12 Date Range: 19/Jun/2006 to 14/Aug/2006 Data Source(s): DIMS, AWGRS Events Source Well Date DIMS 15-12 08/14/2006 AWGRS 15-12B 08/14/2006 AWGRS 15-12B 08/14/2006 DIMS 15-12 08/13/2006 DIMS 15-12 08/12/2006 DIM-.S 15-12 08/11/2006 DIMS 15-12 08/10/2006 DIMS 15-12 08/09/2006 DIMS 15-12 08/08/2006 DIMS 15-12 08/07/2006 DIMS 15-12 08/06/2006 DIMS 15-12 08/05/2006 DlMS 15-12 08/04/2006 DIMS 15-12 08/03/2006 DIMS 15-12 08/02/2006 DIMS 15-12 08/01/2006 DLM_S 15-12 07/31/2006 DIMS 15-12 07/30/2006 DIMS 15-12 07/29/2006 RIMS 15-12 07/28/2006 DIMS 15-12 07/27/2006 DIMS 15-12 07/26/2006 DIMS 15-12 07/25/2006 AWGRS 15-12B 07/25/2006 DIMS 15-12 07/24/2006 AWGRS 15-12B 07/24/2006 DIMS 15-12 07/23/2006 AWGRS 15-12B 07/23/2006 DIMS 15-12 07/22/2006 Description RIH with kill string, land hanger, test hanger and TWC, N/D BOPE, N/U tree, freeze protect, install and test BPV. PULLED A 4" CIW TWC THRU TREE-RIG COMPLETION. SET 4" CIW BPV FOR RIG TO MOVE OFF OF WELL RIH and set EZSV at 8,850', POH laying down dp, pull wear bushing, run 4-1/2" tubing kill string. Drill float equip, displace mud with 8.5 ppg Flo Pro, drill 42', lose eire, POH, LD bha, RIH w/EZSV. Wait on orders, POH w/kill string, P!U bha, RIH, Drill float equip and cement to 8,877'. Wait on orders from town, clean and paint pipe shed and inside derrick wind walls. P!U bha, TIH, drill fit equip in scab liner, RIH to LC in 7" drlg liner, test 3,500 psi f/30 min, POH, L/D bha, RIH to 2,448' with dp. Wait on orders, POH w/kill string, P/U bha Lay down bha, RIH to 2,448' with kill string, wait on orders from town. Test BOPE, P/U bha, TIH, drill cement to 5,370', POH, L/D bha, RIH with mule shoe & 10 stands of dp, WOO. Pick up and run 7" scab liner, cement, set hanger and packer, POH with running tool, flush BOP. RIH w/7" drilling liner, eire, cement and set. Circ out contaminated cement, POH, R/U to run 7" scab liner. Circ hole clean, POH, repair pipe skate, LID bha, fix flow line leak, P/U and RIH w/7" drlg liner. TD intermediate hole at 8,957', short trip to window, pump high vise sweep, circulate hole clean. Directional drilled 8-1/2" intermediate hole as per SSDS dd's. Condo mud 9.2 ppg, FIT, Circ. & Condo mud, Drill 8 1/2" hole 5686 -7314' CBU,FIT, Mad pass log w/MWD, POH w/mills,L/D milling BHA, Flush Stack, M/U 8 1/2" drilling BHA, RIH, Run through window and drill 20' of new hole, CBU P/U DC's, M/U Whipstock and Milling assembly, RIH, orient whipstock and set, Displace to 9.0 ppg milling fluid, Mill window, Circ. hole clean Set & test storm packer @ 35'md,N/D BOPE's, Change out 9 5/8" packoff and tubing spool, N/U BOPE's, Test new spool and packoff, Screw in & pull storm packer, LID, storm packer and running tools, POH with 34 stands of 4" DP Cement plug on top of #1 EZSV, Circ. 120 deg brine in 9 5/8" csg @ 2500' to help vent OA (9 5/8" x 133/8"), R/U SWS, gauge ring run, SWS set EZSV @ 5662', Test EZSV plug to 3500 psi, R/D SWS, P/U 4" 102 joints DP Isolate casing leak with RTTS, Test casing, POH w/RTTS, R/U SWS WIRELINE, WOO, RIH with SWS wireline and EZSV, abort EZSV run and RD SWS, P!U 3 1/2" cement stinger, RIH to 8282', Circ. hole and R/U to cement POH w/csg. scpr assembly, R/U and run SWS wireline usit log and set EZSV @ 8287', R/D SWS and M/U RTTS and RIH to test casing, Perform casing intergrity tests T/I/O=O/OjVAC, Temp=SI. OA FL (pre-LDS drill-out/OA FL Depress w/N2). OA FL @ 36' (2 bbls). Staged N2 rack for upcoming OA FL depress. P/u 9 5/8 csg. scpr. assembly & RIH, Circ. well clean, monitor well, service rig, cut drilling line POOH wI csg. scpr. Lockdown Screw Drill-Out @ Nabors 27E Planning. Clint Miller from FMC, made Plan Forward. Met with Bill Decker to finalize operations, Andrea Hughes to review. Perforate & cut 3 1/2" tubing, L/D 3 1/2' tubing, L/D 5 1/2" casing, R/U to test stack and test BOPE's Nabors Rig 27E on well, prep job for Lockdown Screws for drill out. Tuboscope, FMC, Cameron, and Colburn Machine. Finish circulating 5 1/2" casing, Flow check well(static), L/D 5 1/2" casing, Service Rig, Repair TDS compensator, L/D 5 1/2"casing, (3 1/2" tubing stub in jt 190) Circ.,R/u SWS http://digitalwellfile. bpweb. bp.com/W ellEvents/Home/Default.aspx 9/13/2006 Digital Wellfile DIMS AWGRS AWGRS AWGRS DIMS 15-12 15-12B 15-12B 15-12B 15-12 07/21/2006 07/21/2006 07/21/2006 07/21/2006 AWGRS 15-12B 07/20/2006 07/20/2006 DIMS 15-12 07/19/2006 DIMS 15-12 07/18/2006 AWGRS 15-12B 07/18/2006 DIMS 15-12 07/17/2006 DIMS DIMS AWGRS AWGRS 15-12 15-12 15-12B 15-12A 07/16/2006 07/15/2006 07/10/2006 07/09/2006 AWGRS 15-12A 07/09/2006 AWGRS 15-12A 07/07/2006 AWGRS 15-12A 07/07/2006 AWGRS 15-12A 07/07/2006 AWGRS 15-12A 07/06/2006 AWGRS 15-12A 07/05/2006 AWGRS 15-12A 07/04/2006 AWGRS 15-12A 07/03/2006 AWGRS 15-12A 07/03/2006 AWGRS 15-12A 07/02/2006 . . Page 2 of 3 N/u BOPE's & test, pull BP,BPV and storm packer, Pull 5 1/2 tbg hanger, Circ. hole Rig stabbed on to well. Installed 12 "Luckies" on stuck LDS's on upper casing hanger. PULLED A 5" FMC BPV THRU BOP'S ON RIG. Prep for Lockdown Drill out on Nabors Rig 27E. Job should be (7/23-7/24) All involved personnel gathering tools and needed equipment. Planning meeting with Co. Man Bill Decker to finalize procedure/plan forward on 7/22. Repair pipe skate, P/U DC's and Storm packer and set same, Test Storm packer, Set BPV, N/D BOPE's, Set Bp and work on tubing spool, N/U BOPE's Assist FMC with Lockdowns Screw drill out at Nabors Rig 27E. Bottom row of Tubing Head had (14) frozen pins, able to free (5) pins. All needed personnel and materials gathered. Applied solvent to void and gland nuts. Tuboscope to perform drill out. Will continue 7/21 ***STILL IN PROGRESS*** Circ. hole clean, flow check well, R/U csg. tongs and equip., LID hanger & 3 1/2" tubing, Repair drawworks brake pad, finish L/D 3 1/2" tubing, R/D tubing handling equip., R/U to P/U 3 1/2" DC's Nipple up and test BOPE, pull TWC, unseat hanger. Circ StS. PULLED A 3" CIW TWC THRU BOP'S ON RIG Rig up & pull BPV, C/O "0" ring in HP mud line,displace diesel, pump SAFE SURF 0, set TWC, test TWC. Move rig from 15-36B to 15-12B. Prepare rig for move to 15-12B. Set 3"ciwv bpv for pre rig.No problems T/I/O/OO= 10/10/20/0. S1. LDS drillout. Capped TBG & IA with N2. TBG FL @ 354', IA FL @ 372'. Bled OAP to 0 psi. Continue to assist Cameron, FMC and Tubo scope on LDS drillout. RDMO T/IA/OA=O/O/O Well head repair. LDS drill out with FMC and Tubo-scope back out [4] of [5] bad LDS [3] pulled and installed new LDS assy. [1] backed out 1-1/2" and froze up, enough for hanger to clear when pulled this LDS was cut of 1-1/4" from face of flange and new gland nut installed. Tubo-Scope drilled [1] LDS out and then installed new one. T/I/O/O= SI/20/0/0 Attempted to move 5 frozen lockdown screws. Used 4 x 1 torque multiplier. Snapped the square part of lockscrew off the first two that we tried to free. Filed the busted lockscrew and backed out the gland nut. Tried to move lockscrew with 48" pipe wrench. No luck. Twisted the second two lockdown screws on the square part of the lockscrew. Decided to stop at that point before we busted them off. Was able to back the 5th lockdown screw out. T/I/O/OO= 0+/0+/20/Vac. Temp= S1. WHP's post-bleed (pre-RWO). OAP increased 15 psi overnight. Integrals installed on IA and OA. T/IA/OA=SI/O/O Assist FMC hand Jerry Cox on trouble LDS on FMC Gen 2 casing spool, try and free [5] stuck LDS managed to break [4] and back [1] out. **** STILL IN PROGRESS**** T/I/O/OO = 50/140/330/vac. Temp = S1. Bleed WHPs to 0 psi (pre-RWO). IA FI @ surface. Bled lAP to 5 psi in 1hr, 30 min (6.5 bbls of diesel). SI, monitored for 30 min. No change in pressure. Tubing FL @ surface. Bled Tubing pressure to 0+ psi in 1 hr, 25 min (1.5 bbls of diesel) SI, monitored for 30 min. Tubing increased to 6 psi. OA FL @ 792'. Bled OAP to 0+ psi in 3.5 hrs (all gas). Tubing pressure and lAP increased to 20 psi. SI, monitored for 30 min. No change in pressure. Bled lAP to 0+ psi in 30 min (1.2 bbls of diesel). SI, monitored for 30 min. lAP increased to 8 psi. Bled Tubing pressure to 0+ psi in 30 min (1 bbl of diesel). OAP increased to 20 psi. SI, monitored for 30 min. Tubing pressure increased to 5 psi. Bled OAP to 5 psi in 30 min. SI, monitored for 30 min. No change in pressure. Final WHPs = 8/8/5/vac. T/I/0/00=50/80/330/vac. Temp=S1. WHP'S, TBG, IA & OA FLs, (post-Jet cut). TBG FL @ surface. IA FL @ surface. OA FL @ 792'. JET CUT THE TUBING AT 7845' IN THE MIDDLE OF A JOINT CORRELATED TO TUBING TALLY DATED 2-AUG-2000 AND REFERENCED TO TUBING PUNCH RECORD DATED 30-JUNE-2006. PREVIOUS TUBING PUNCH HOLES ARE 7832-7834'. ********JOB COMPLETE********* T/I/O/OO = 140/130/320/vac. Temp = S1. Bleed WHPs to 0 psi. (pre RWO). Tubing FL near surface. Bled Tubing pressure to 10 psi in 25 min (gas and 1.5 bbls of deisel). lAP decreased to 100 psi. OAP decreased to 280 psi. SI, monitored for 30 min. Tubing pressure increased to 60 psi. No change in lAP or OAP. Final WHPs = 60/100/280/vac. (continued from 7-2-06) Pumped 236 bbls 9.8 brine down tbgtaking returns in flowline pumped and u-tubed 45 bbls dsl MIT on OOA to 2000 psi passed on second attempt lost 50 psi in first 15 min and 0 psi in second 15 min Pumped 333 bbls 9.8 brine down OA FWHP=450/450/200/0 T/I/O/OO= 450/450/1250/0 Load dsl road to location standby for veco to rig up loop from IA http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 9/13/2006 Digital Wellfile . . Page 3 of 3 to FL (continued on 7-03-06) AW~RS 15-12A 06/30/2006 WELL SHUT-IN AT ARRIVAL. T/I/O/OO 500/600/0/500. RAN GYRO SURVEY FROM SURFACE TO 7700 FT. SHOT SMALL CHARGE TUBING PUNCHER FROM 7832'-7834'. NO CHANGE IN WHP'S FOR ENTIRE JOB. RDMO. NOTIFIED DSO OF DEPARTURE. AWGRS 15-12A 06/25/2006 RST GRAVEL PACK LOG. DID NOT FIND ANY FILL BEHIND 3-1/2" TUBING. GR IN ALL ZONES READ BETWEEN 300 - 500 GAPI WITH MINITRON ON. Job complete... AWGRS 15-12A 06/19/2006 ***WELL 5/1 ON ARRIVAL*** (pre sdtrck) DRIFT W/ 2.7" CENT AND 2.75" GAUGE RING TO 8250' SLM FOR TUBING CUT. (TARGET DEPTH = 8200" MD). ***GIVE WELL BACK TO DSO. LEFT 51*** AW<.iRS 15-12A 06/19/2006 T/I/O = 51/600/0 Attempted to function 5 lockdown screws on the casing head that are frozen. Used 4 x 1 torque multiplier. Used approximately 800 ft Ibs pressure and still no movement on lock screws. Will need to bleed down IA and OA to 0 psi before we can get rougher with the frozen lock screws. http://digitalwellfile. bpweb. bp.com/W ellEvents/Home/Default.aspx 9/13/2006 TREE = WELLHËA~= ACTUA TOR = KB. ELEV::: BF. ELEV = KOP= Max Angle = Datum MD = Datum ND = DATE 11/05/81 08/04/00 08/29/01 05/1 0/06 05/17/06 06/14/06 REV BY CI-VKAK RLP RLP RLP 5-1/8" FMC FMC AXELSON 7,700'MD 15-12Bamporary Suspension DRlG DRAFT 2482' 2901' 2979' H 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 4-1/2", 12.6#, L-80, IBT-M tbg kill string H 7" Scab LNR HGRI 5471' 1-1 7" Liner Hanger 1 15637' - 5654'1-1 9-5/8" Whipstock, millout window COMMENTS ORIGINAL COM PLETION CTD SIDETRACK CORRECTIONS 15-12B (wp04) Side track 15-12B (w p05) Side track 15-12B Updated casing depths DATE 08/14/06 08/19/06 REV BY RLP TLH N/A H 9-5/8" EZSV N/A I., Top of Cement 15 BBL N/A H 9-5/8" EZSV N/A H 5-1/2" TBG-PC, 17#, L-80, .0232bpf, ID=4.892" N/A I.., 3-1/2" TBG, 9.3#, L-80, .0087bpf, ID = 2.992" 8850' 7" EZSV 8954' 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 8999' 6.125" New Formation into fault with 500 bbVhr losses COMMENTS Temporary secure & RDMO DEPTH CORRECTIONS PRUDHOE BAY UNIT WELL: 15-12B PERMIT: API No: 50-029-20665-02 SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL BP Exploration (Alaska) R.~~c¡ v L-.Ù AUG 0 8 2006 Schlumberger ~ Oil & Gas Cons. Co~ NO. 3883 Anchorage Alaska Data & Consulting Services 2525 GambeJl Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth IE . .r..11U'G. ~J..' A. '.ìD06 SC^N~, Lr. ~ c.. Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 {)()O -()(µ/ Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD NK-43 11211388 PRoD PROFILe w/DeFT 04/02/06 1 NK-2:¿A 1u568415 t"KUU PKU-IL.. ..'.....r 02/26/u3 1 L4-12 N/A WFULDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20/04 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28/06 1 04·10 11211380 INJECTION PROFILE 03/23/06 1 17-21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18-03B 11057071 SBHP 12/02/05 1 X-15A 11212877 US IT 07/18/06 1 J-01 B 11511430 USIT 07/24/06 1 15·12A 11221595 USIT 07/25/06 1 Z-14B 11217268 USIT 07/29/06 1 S-400 10987564 CH EDIT PDC-GR OF USIT 01/26/06 1 D-03A 11217269 USIT 07/31/06 1 05-28A 11217267 US IT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/01/06 . . 15-128 changes to directional e e ~oo - 0 (q l Subject: 15-128 changes to directional From: "Phillips, Ron" <Ron.Phillips@bp.com> Date: Wed, 26 Jul2006 14:05:42 -0800 To: winton_aubert@admin.state.ak.us CC: "Wesley, Dave E" <Dave.Wesley@bp.com> Winton, We found our cretaceous leak in the 9-5/8" casing to be at 5,854' and we decided to kick off above it to prevent any losses while drilling ahead. The new directional shows us kicking off to drill 2,000' shallower at 5,700' MD. We will still set our 7" drilling liner and 4-1/2" production liner at the same depths. We will still run our 7" scab liner from the 7" drilling liner hanger to 500' below surface casing shoe to cover up any 9-5/8" cretaceous corroded casing. 80th the 7" drilling liner and the 7" scab liner will be fully cemented. When we pulled on our 5-1/2" casing it pulled out of the packer at 8,348'. We did not need to do a free point and jet cut at 7,825'. We set our lowest EZSV at 8,283' MD with 15 bbls (204') of 15.8 class G cement. Next EZSV will be placed at 5,700' with whipstock set on it per directional plan WP 08 attached. If you have any questions please call. «15-128 wp08.pdf» Thanks, ï r)n~"¡; (·f~'b.\\ì"1r:fJ ìUL 2: i L.\:UJ .)v."\.J.\<;'i~.. "-, Ron Phillips Operations Drilling Engineer GP8 Rotary Office (907) 564-5913 Cell (907) 748-7868 ---,,:,,-=:=---===::.:::-"i--:-=:::=--=====.:::==:-=-::-c-------------- -----::=::==-==--::O====C::=:=_==-==-==-=-~II I Content-Description: 15-128 wp08.pdf ~r"".,.m I 15-128 wp08. pd~ Content-Type: application/octet-stream I, ! Content-Encoding: base64 ': ii 1 of I 7/26/20062:19 PM Proposal to run 2nd EZSV instead of 100' cee in 9-5/8" e (A)(!) .... 0 r. I Subject: Proposal to run 2nd EZSV instead of 100' cement in 9-5/8" From: "Phillips, Ron" <Ron. . ips@bp.com> Date: Fri, 21 Jul2006 14 80 To: wint CC:NSUA Winton Aubert - AOGCC Approval is requested to change our approved plan to PIA the 15-12A. Current plan: Pulling the 3-1/2" tubing from 7,850'. ~CANNEa JUL 242006 Jet cut and pull the 5-1/2" tubing from 7,825'. Set EZSV at 7,800' Place 100' of cement on top of EZSV. Dress up cement with Mill assembly. Set 9-5/8" whipstock. Kick off at 7,700' and drill 8-1/2" intermediate section. Run and cement 7" drilling liner from 8,903' to 7,550' fully cemented with 15.8 class G. Run and cement 7" scab liner from 7,550' to 2,982' fully cemented with 15.8 class G. With the 9-5/8" casing and whipstock behind 7" and fully cemented up to 2,982', I request that we be allowed to replace the 100' cement cap with a second EZSV set at - 7,700'. This will save us the time it takes to trip in and out to 7,800' to cement and another trip in and out to dress up cement with a mill assembly. This will also give us a good hard surface to set our whipstock on. Proposed plan: Pulling the 3-1/2" tubing from 7,850'. Jet cut and pull the 5-1/2" tubing from 7,825'. Set EZSV at 7,800' Place a second EZSV at -7,700'. Dress up cement with Mill assembly. Set 9-5/8" whipstock. Kick off at 7,700' and drill 8-1/2" intermediate section. Run and cement 7" drilling liner from 8,903' to 7,550' fully cemented with 15.8 class G. Run and Cement 7" scab liner from 7,550' to 2,982' fully cemented with 15.8 class G. Thanks, Ron Phillips Operations Drilling Engineer GPB Rotary Office (907) 564-5913 Cell (907) 748-7868 I of I 7/24/20069:56 AM Well Job# Loa DescriDtion Date BL Color CD 15·12A lu:11420 R~ I ul<AVEL PACK o6/¡:5/ulI 1 17 -D8 11211509 INJEcTIUN PRUFILE 06/24/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13.-06A 11217266 INJECTION PROFILE 07/12/06 1 P2-o1 11223.106 STATIC PRESSURE/JEWELRY 03./25/06 1 L5-o8 11217256 PROD PROFILE W/GHOST & DEFT 06/06/06 1 16-04A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223.123. LDL 07/07/06 1 17-09 11211412 PROD PROFILE W/DEFT & GHOST 06/26/06 1 MPC-07 N/A SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 USIT 06/27/06 1 ù-51 11212873- USIT 06/28/06 1 04-3.1 11217264 US IT 07/07/06 1 D-14A 11217265 USIT 07/09/06 1 PSI·07 10703.93.7 MDT 10/13./03. 1 02-168 11209601 MCNL 04/25/06 1 1 L2-18A 1121723.4 MCNL 04/06/06 1 1 L5-o9 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/3.0/04 1 Sc~luIIIberger .! .~"'>.). þj\W~~) ~.,.:,\.. tt;.. f) I, Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth (9Cb -C)~ ( N " Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 07/19/06 NO. 3880 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay e e Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth I,'~i? :¡il :6 'I', i, i i IU';' i ( I L ' "~~ 1,1 ) ~, "~,i8' n " ,f~' ,\ ¡~:Iì' ,%:', ! j f£!,,~ I' " ì " (I I ", I I ¡ 18' ;', I : I ,." '.. '\ I " II' i I :' I ¡ "",' r ¡ 1'\ ! I ' 1 in \~/!I @;¡ \L[lJ ) ALASKA. OIL AlQ) GAS CONSERVATION COMMISSION / ! I / J FRANK H. MURKOWSKI, GOVERNOR Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 O~ólÞ\ ~O Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-12A Sundry Number: 306-225 ~CANN,ED JUN 2:3 2.006 Dear Mr. Wesley: 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, 0J1~ Dan T. Seamount Commissioner DATED thisZl day of June, 2006 Encl. (/fÍh~ ~ 'R~EÍVèbo 0" ) STATE OF ALASKA:' ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 2 2006 APPLICATION FOR SUNDRY APPROVIAJlOiI&GasCons.Commission 20 AAC 25 280 Anchoraae . Revised (Previously Approv~d): 06/22/06 1. Type of Request: IB1 Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate o Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Other o Change Approved Program 0 Operation Shutdown 0 Perforate 0 Time Extension 0 Re-Enter Suspended W 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Well Class Before Work: ~ Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 200-061 /306-208 t" 6. API Number: 50-029-20665-01-00 /' 99519-6612 60' 9. Well Name and Number: PBU 15-12A / 8. Property Designation: 11. Total Depth MD (ft): 10730 Casing Structural Conductor Surface Intermediate Production Liner 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): I Effective Depth TVD (ft): Plugs (measured): 8855 10696 8852 None Length Size MD TVD Burst Junk (measured): 8268 Collapse ADL 028306 Liner 80' 20" 80' 80' 1490 470 2482' 13-3/8" 2482' 2482' 4930 2670 8697' 9-5/8" 8697' 8261' 6870 4760 734' 7" 8367' - 9101' 7944' - 8652' 8160 7020 2447' 2-7/8" 8283' - 10730' 7863' - 8855' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9400' - 10680' 8851' - 8851' 4-1/2" x 5-1/2" & 3-1/2" L-80 8280' & 8446' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker packer; 5-1/2" x 3-1/2" Baker Packers and SSSV MD (ft): 8348'; 8252' 'SABL-3' packer 12. Attachments: ~ Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: o Exploratory ~ Development 0 Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Dave Wesley Title Senior Drilling Engineer Signature ~~7~ £./1 D!t"Qs(et Phone 564-5153 Commission Use Only June 15, 2006 Date: 15. Well Status after proposed work: DOil o Gas D WAG 0 GINJ o Plugged DWINJ 181 Abandoned o WDSPL Contact Ron Phillips, 564-5913 Date b/Ø?Æ Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance I Sundry Number:\.. i)ú> ·A.ól~ r~~+ Bo P f -to 4000 (J ~¿ , P~~~L(CH"t to ?-o A-M ?.-S. 11"l.. (l) I tJ.te.v~~ w-t-t! ~ COMMISSIONER "'1 't /11I '\ P ¡,O U1 ckt K 1\ CA.-ff WIt e,J RBDMS 8FL JUN 2 3 2006 Date ~~L~ate APPROVED BY THE COMMISSION Subsequent Form Required: ORIGINAl ) ) To: Winton Aubert - AOGCC Date: June 07, 2006 From: Ron Phillips - BPXA GPB Rotary Drilling Subject: Reference: 15-12A Application for Sundry Approval - Pre-Rig work for Sidetrack Operations API # 50-029-20665-01 Approval is requested for the proposed Pre-Rig work of PBU well 15-12A. Well 15-12 was drilled as a producer in October 1981 and was sidetracked June 2000 as a horizontal producer. The parent well had poor tubing with known leaks. In an attempt to save cost, two POGLM's were pulled from the well and the 5-1/2" tubing was left in place. This tubing had known communication between the 5-1/2" and the IA even before the POGLM's were pulled. The rig then ran 3-1/2" jointed pipe inside the damaged 5-1/2" tubing. Initial perfs were shot 9400'-9900' and 10,440'-10,680' and the well came on at 1500 BOPD. The well had stable production and has seen very little well work activity. On June 10, 2004 the well suddenly made 3000 BWPD that tested out to be Cretaceous water. The well was shut-in with production loss of 600 SOPD at 23,000 GOR. The well has 3-1/2" x 5-1/2" communication along with 5-1/2" x IA communication, and Cretaceous leak. Further diagnostics were not done since an economic fix was not anticipated. The well was sanded back to secure the well and prevent damaging cross flow into the Ivishak on July 1, 2004. Slickline hung up while trying to tag the sand top and ended up leaving the tools and wire in the hole. Braided line left more tools in the hole trying to fish out the slickline tools. Coil eventually got on the well and they too hung up and lost their BHA of jars, hydraulic disconnect, etc..... The wells group did not want to try and fish the junk and the well has been shut in since. 15-12A failed and M IT -OA with a 4.5 BPM leak rate on 4/29/05. The sidetrack is currently scheduled for Nabors rig 27E, beginning around July 10th 2006. The pre-rig work for this sidetrack will begin at the Well's Group's earliest convenience after sundry approval. Note: We will not be able to P&A this well until the drilling rig moves on the well and pulls both strings of tubing 3-1/2" and 5-1/2" and can set the 9-5/8" EZSV and set cement on top of it. We plan to cut and pull from 7,850', but need the RST Log first to see where we have fill on the backside of the tubing and a free- point to determine where the 5-1/2" will pull free from. Current Condition: ,/ Currently SI due to fish in 3-1/2" tubing at 8,295'. ,/ 28 BBL sand plug set at 8,800' to 10,680'. ,/ Perforations from 9,400' to 10,680'. ,/ 9-5/8",47#, L-80 casing landed at 8,697'. Cretaceous leaks. ,/ 5-1/2",17# X 4-1/2",12.6#, L-80 tubing landed at 8,445'. Cretaceous leaks. ,/ 3-1/2",9.3# at 8,280. Cretaceous leaks. ,/ 2-7/8",6.4# liner at 10,730'. ,/ 5-1/8 FMC tree. 15-12A Application for Sundry ~ J ~ ~ ~ fV\ ~ ~ ( ~ -- V' ~ ., ) Scope Pre-RiQ Operations: 1. RU E-Line wi Gyro and run surveys on both the 15-12 and 15-38 well bores. RD E-Line. 2. RU Sl and drift the 3Y2" tubing to 7,900' MD. This will confirm the tubing is clear to the required cut depth of 7,850' MD. RD SL. 3. RU E-Line wi RST to locate fill behind 3-1/2" tubing. 4. RIH with the appropriate jet cutter and cut the 3-1/2" tubing at -7,850' MD. RD E-Line. 5. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 6. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all lock Down Screws, repair or replace as needed. 7. Bleed casing and annulus pressures to zero. 8. Set a BPV. Secure the well. level the pad as necessary. RiQ Operations: 1. MI I RU Nabors rig 27E. Pull BPV. 2. Circulate out diesel freeze protection and displace the well to seawater. Set TWC and test to 1000psi. 3. Nipple down tree. Nipple up and test BOPE to 250 psi low and 4,OOOpsi high (due to a 3,434 psi "./ maximum surface pressure based upon BHP and a full column of gas from TD). Pull TWC. 4. Pull 3%" tubing from the cut at -7,850' MD. 5. RU Sl and drift the 5%" tubing to 7,840' MD. This will confirm the tubing is clear to the required cut depth of 7,825' MD. RD SL. 6. RU E-Line and RIH wi Free Point Indicator Tools. Verify tubing is free to -7,825' MD. / 7. RIH with the appropriate jet cutter and cut the 5-1/2" tubing at -7,825' MD. RD E-Line. /' 8. Pull 5%" tubing from the cut at -7,825' MD. 9. RU E-line. M/U gauge ring junk basket I CCl I GR. RIH and tag tubing stump. POOH. 10. RIH with HES EZSV on E-line. Set EZSV at -7,800' MD. RD E-Line. () 11. RIH wlopen ended drill pipe and tag EZSV. RU Cement Unit. Pic~ up off bottom and place a 7{9/ BBl cement cap (1 oott) on top of EZSV. POOH. RD Cement Unit. v 12. RU RTTS (1500psi compressive strength needed before testing) to test EZSV I cement plug to 3500psi for 30 minutes. 13. Using RTTS find shallowest depth of 9-5/8" casing leak. Once shallowest leak is found in 9-5/8" casing, verify by performing a 30minute test to 3500 psi. POOH wi RTTS. 14. PU and RIH with mill assembly to dress up cement plug (using the CCUGR log run prior to setting EZSV) to determine required depth to land the whip stock, to prevent milling on a casing collar. 15. ND the BOP and pull the existing tubing spool with the 9-5/8" pack off. The lower lDS are not functional, so the tubing spool and pack off will need to be replaced. Test the seals and pack off. 16. NU and test the BOP. Note: all operations before this point are on a 7day BOP test cycle until the whipstock is picked up. Once the whipstock is picked up the 14 day test cycle starts and continues until the rig moves off. 1 f. PU and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as required by directional plan. Shear off of whip stock at -7700. 18. Displace the well to 10.8ppg lSND based milling fluid. Completely displace the well prior to beginning milling operations. 19. Mill a 20' window in 9-5/8" casing at ± 7,700' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 20. Pull up into 9 5/8" casing and conduct an FIT. (Notify ODE if 11.6 ppg FIT is not obtained). POOH. 21. MU 8%" Dir/GR/Res/PWD assembly. RIH, kick off and drill the 8%" intermediate section. 22. Continue drilling ahead in the 8Y2" hole section to the top of the Sag River, per directional plan. Circulate well clean, short trip to window. POOH. 23. Run and cement a 7", 26.0#, l-80 intermediate drilling liner. 24. Run and cement 7" scab liner from intermediate drilling liner top up to 500' from surface casing shoe. Assuming there are no shallow 9-5/8" leaks above this depth. 25. M/U 6-%" tri-cone bit Dir/GR assembly. 15-12A Application for Sundry ) ) 26. RIH to the 7" scab liner shoe track, test scab liner to 3500 psi for 5-10 minutes, drill out cement I float equipment. 27. RIH to the 7" liner shoe track, test drilling liner to 3500 psi for 30 minutes. 28. Drill out 7" drilling liner shoetrack. 29. Displace the well over to Flo-Pro drilling fluid prior to drilling 20' of new formation. 30. Pull up into the shoe and conduct a FIT. (Notify ODE if 10.0 ppg FIT is not obtained). Drill ahead through Zone 2, completing build section. POOH. 31. M/U 6-%" PDC drilling assembly with Dir/GR/Res/Denl Neu. RIH. Tag bottom and mad pass (den/Neu in record mode only) up to 50' above TCGL. 32. Drill ahead to TO (Denl Neu in real time mode for drilling). Fault just beyond TD! This fault is -200' away and has not been crossed before. 33. Circulate well bore clean, short trip to shoe, circulate. POOH. 34. Run and cement 4%",12.6#, L-80, IBT-M solid production liner. POOH. 35. Test 4-1/2" production liner to 3,500 psi for 30 minutes. 36. RIH with drill pipe conveyed perf guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalance. Perforate. POOH, LD DP and perf guns. 37. R/U and run a 4%", 12.6#, 13CR-80 tubing completion, stinging into the 4%" liner tie back sleeve. 38. Reverse circulate seawater and corrosion inhibitor. Drop the ball and rod, set the packer. 39. Individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. Pressure up on annulus to shear the OCR valve. Confirm two-way circulation. 40. Set a TWC and test to 1000 psi. 41. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 42. Pull TWC. Reverse in sufficient diesel to freeze protect to 2200 ft TVD. U-tube. 43. Install BPV and test. Secure well. RDMO. Post-Ria Operations: 1. MI I RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Timina: This sidetrack is scheduled for spud July 10, 2006. Estimated Pre-rig operations start date: Estimated Rig operations I spud date: 06/1 0106 07/1 0106 Ron Phillips Operations Drilling Engineer 564-5913 15-12A Application for Sundry TREE = 5-1/8" FMC ) WELLHEA~ = FMC ~ SAFETY NOTES: WELL> 70° @ 9370' 15-12A , ACTUA TOR = . AXELSON / AND> 90° @ 9560'. KB. ELEV = 60' BF. ELEV = NA ~ J KOP= 2950' ....". ., "'" 2097' l-i 3-1/2" HES X NIP, 10 = 2.813" 1 Max Angle = 94 @ 9785' Datum MD = NA 1- Datum NO = 8800'SS 2186' 5-1/2" OTIS ROM SSSV N, MILLED TO 4.80" 10 13-3/8" CSG, 72#, L-80, 10 = 12.347" l-i 2482' ~ Minimum ID = 2.372" @ 8292' 3-1/2" X 2-7/8" LNR CROSSOVER I FISH - 31.17' W/L TOOL STRING; 11.87' COIL l-i 8268' ~ 3-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 = 2.992" l-i 8280' 1 3.80" BKR LNR DEPLOY SLY, 10 = 3.00" l-i 8289' 1 TOP OF 2-7/8" LNR, 10 = 2.372" l-i 8293' 1 1 TOP OF BOT PBR ASSY I.., 8342' 1 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, -i 8354' 1 10 = 4.892" (BEHIND 2-7/8" LNR) I TOP OF 7" BOT PBR ASSY I.., 8322' 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, -i 8445' 10 = 3.958" (BEHIND 2-7/8" LNR) 9-5/8" CSG, 47#, L-80, 10 = 8.681" l-i 8697' ÆRFORA TION SUMMARY REF LOG: SWS GRlCNL ON 08/31/00 A NGLE AT TOP PERF: 79 @ 9400' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 4 9400 - 9900 0 09/02/00 2 4 1 0440 - 1 0680 0 09/02/00 I 7" LNR, 29#, L-80, 10 = 6.184" 1-; 9430' DA TE REV BY COMMENTS DA TE REV BY 11/05/81 ORIGINAL COM PLETION 08/04/00 CTD SIDETRACK 08/29/01 CI-ilKA K CORRECTIONS 09/11/03 CMOITLP DATUM MDITVD CORRECTIONS 06/12/04 RWUKAK GL V C/O 07/27/04 BJMcN/KK FISH ~ L ST MD NO 1 3136 3129 2 5795 5548 3 8198 7782 GAS LIFT MANDRELS DEV TYPE VLV LATCH 16 KBG-2-9 DMY INT 25 KBG-2-9 DMY INT 17 KBG-2-9 DMY INT PORT DA TE o 06/12/04 o 06/12/04 o 06/12/04 J 1 I 8251' l-i BKR KBH-22 SEAL ASSY, 10 = 3.00" 1 I 8252' l-i 5-1/2" X 3-1/2" BKR SABL-3 PKR, 10 = 2.78" ~l I 8267' l-i 3-1/2" HES XN NIP, 10 = 2.635" 1 ~ 8280' l-i 4-1/2" BKR LOCATOR SUB, 10 = 3.00" 1 I 8283' l-i 4.375" BKR LNR TIEBACK SLY, 10 = 4.00" I 8285' l-i BTM OF BKR SEAL ASSY, 10 = 3.00" 1 I 8292' l-i 3-1/2" X 2-7/8" LNR XO, 10 = 2.372" 1 ~ 1s I 8348' 1-1 9-5/8" X 5-1/2" BOT PKR (BEHIND LNR) ~ ~ 8354' l-i 5-1/2" X 4-1/2" XO (BEHIND LNR) 1 8383' 1-1 4-1/2" OTIS XN NIP, MILLED TO 3.80" l J I 8367' l-i 7" BTM LNR HGR 1 ...., I I 8446' 1-1 4-1/2" WLEG (BB-iIND LNR) 1 ~ ... 7" MILLOUT WINDOW 9111'-9118' ~ WHIPSTOCK @ 9100' RA TAG @ 9109' x x - ,. .. 'a, -- - I PBTD l-t 10696' 1 2-7/8" LNR, 6.4#, FL4S, .0058 bpf, 10 = 2.441" l-i 10730' COMM8\JTS PRUDHOE BA Y UNIT WELL: 15-12A PERMIT: 2000610 API No: 50-029-20665-01 SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL BP Exploration (Alas ka) TREE = WELLHEAQ = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD = 5-1/8" FMC FMC AXELSON 60' NA 2950' . . ",. . 94 @ 9785' NA 8800' SS DeJompletion 15-126)/ 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2482' r----.t Minimum ID = 2.372" @ 8292' 3-1/2" X 2-7/8" LNR CROSSOVER I FISH - 31.17' W/L TOOL STRING; 11.87' COIL 1-1 8268' t 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 1-1 8280' 1 3.80" BKR LNR DEPLOY SLV, ID = 3.00" 1-1 8289' 1 TOP OF 2-7/8" LNR, ID = 2.372" 1-1 8293' 1 I TOP OF BOT PBR ASSY 1-1 8342' 1 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, -I 8354' 1 ID = 4.892" (BEHIND 2-7/8" LNR) I TOP OF 7" BOT PBR ASSY 1-1 8322' 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, -I 8445' ID = 3.958" (BEHIND 2-7/8" LNR) 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 8697' ÆRFORA TION SUMMARY REF LOG: SWS GRlCNL ON 08/31/00 ANGLEAT TOP PERF: 79 @ 9400' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 4 9400 - 9900 0 09/02/00 2 4 1 0440 - 1 0680 0 09/02/00 I 7" LNR, 29#, L-80, ID = 6.184" 1-1 9430' DATE REV BY COMMENTS DATE REV BY 11/05/81 ORIGINAL COM PLETION 08/04/00 CTD SIDETRACK 08/29/01 CHlKAK CORRECTIONS 09/11/03 CMOITLP DATUM MDfTVD CORRECTIONS 06/12/04 RWLlKAK GLV C/O 07/27/04 BJfv1cNlKK FISH ~ 0: I ~\ 1 I I '0 I I ~ k ~ J J .4 ~ .. ) :.. .. 7700' 7800' 7825' 7850' 8251' 8252' 8267' 8280' 8283' 8285' 8292' SAFETY NOTES: WELL> 70° @ 9370' AND> 90° @ 9560'. 1-1 7.3 BBL cement 1-1 9-5/8" EZSV 1-1 5-1/2" TBG-PC, 17#, L-80, .0232bpf, ID=4.892" 1-1 3-1/2" TBG, 9.3#, L-80, .0087bpf, 10 = 2.992" 1-1 BKR KBH-22 SEAL ASSY, ID = 3.00" 1 1-1 5-1/2" X 3-1/2" BKR SABL-3 PKR, ID = 2.78" 1 1-1 3-1/2" HES XN NIP, ID = 2.635" 1 1-1 4-1/2" BKR LOCATOR SUB, ID = 3.00" 1 1-1 4.375" BKR LNR TIEBACK SLV, ID = 4.00" 1 1-1 BTM OF BKR SEAL ASSY, ID = 3.00" 1 1-1 3-1/2" X 2-7/8" LNR XO, ID = 2.372" 1 8348' 1-1 9-5/8" X 5-1/2" BOT PKR (BEHIND LNR) 8354' 1-1 5-1/2" X 4-1/2" XO (BEHIND LNR) 1 8383' 1-1 4-1/2" OTIS XN NIP, MILLED TO 3.80" 8367' 1-1 7" BTM LNR HGR 1 8446' 1-1 4-1/2" WLEG (BEHIND LNR) ... .. 7" MILLOUTWINDOW 9111'- 9118' WHIPSTOCK @ 9100' RA TAG @ 9109' I PBTD 1-1 10696' 1 I 2-7/8" LNR, 6.4#, FL4S, .0058 bpf, ID = 2.441" 1-1 10730' COMMENTS PRUDHOE BA Y UNIT WELL: 15-12A PERMIT: 2000610 API No: 50-029-20665-01 SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL BP Exploration (Alaska) TREE = ,~WELLHEJ.\O = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MO = Datum NO = 5-1/8" FMC FMC AXELSON 15-128 r )oposed Completion ) ,.,./' 7,700'MO I I I 2200' 1-1 4-1/2" HES X NIP, 10 = 2.813" 1 .4 ~I 2482' 1-1 13-3/8" CSG, 72#, L-80, 10 = 12.347" L I 2982' 1-1 7" Scab LNR HGRI x ~ ) ~ L 7550' 1-1 7" Liner Hanger 7700' 1-1 9-5/8" Whipstock, millout window ~ . k: - I 7700' l-i Top of Cement 7.33 BBL I 7800' 1-1 9-5/8" EZSV I 7825' 1-1 5-1/2" TBG-PC, 17#, L-80, .0232bpf, 10=4.892" I 7850' 1-1 3-1/2" TBG, 9.3#, L-80, .0087bpf, 10 = 2.992" I 8675' 1-1 4-1/2" HES X NIPPLE; 10=3.812" I 8696' 1-1 7" X 4-1/2" BAKER S-3 ÆRM PKR; 10=3.88" I 8720' 1-1 4-1/2" HES X NIPPLE; 10=3.812" I 8741' 1-1 4-1/2" HES XN NIPPLE; 10=3.725" I 8753' 1-1 4-1/2" TBG, 12.6#, 13CR-80 / WLEG 8 z ..I 1-1 .41 8753' 4- 1/2" LNR HGR/L TP w / 10' Tieback Sleeve 1 8903' l-i 7" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" '----I J J ...., .. \ 8697' 1-1 9-5/8" CSG, 47#, L-80, 10=8.681" ~ A ... .... .- - ~ I 11536' 1-1 4-1/2" CSG, 12.6#, L-80, .0152bpf, 10 =3.958" 1 OA TE REV BY COMMENTS 11/05/81 ORIGINAL COM PLETION 08/04/00 CTD SIDETRACK 08/29/01 CHlKAK CORRECTIONS 09/11/03 CMO/TLP DATUM MOI1VO CORRECTIONS 06/12/04 RWUKAK GLV C/O 07/27/04 BJMcN/KK FISH DATE 05/10/06 05/17/06 06/14/06 REV BY RLP RLP RLP COMMENTS 15-12B (w p04) Side track 15-12B (wp05) Side track 15-12B Updated casing depths PRUDHOE BA Y UNIT W8..L: 15-12B ÆRMIT: API No: 50-029-20665-02 SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL BP Exploration (Alaska) e e Æ\ J..I'"'"1 '. . u u FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA. OILAlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 d.v0D" ø (p I Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 15-12A Sundry Number: 306-208 ';':''''¡¡''M1~¡:t:;;iÎ'\ 111t\) ') ~\ 2nDS to:'Vd"'ie'tJ~~';,;.,;.t ~,t¡,JllJ 1.0..' ,oJ ,,",,',,, Dear Mr. Wesley: The Alaska Oil and Gas Conservation Commission ("Commission") hereby rescinds the approval of Sundry Number 306-208, dated June 14, 2006 for well PBU 15-12A (PTD 200-061). This action is taken without prejudice to future applications for sundry approvals for the subject well. Please resubmit a sundry application. Thank you for your attention to this matter. Daniel T. Seamount. Jr. Commissioner DATED this Z2.day of June, 2006 (R) í7 /";\\ lr rÞ: .~.'. \ l1.ì ..../' 11 \'" U· ." Lb', n:¿;, :i j' lflj'\' : " '"" .., '. , ~- ' ., . ~,ë,. i ¡ ~ . ()(JO-ö~ ( n1.' , J j ¡ , . ~ (~ rV7 lM æJ Ü~ lrù FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 15-12A Sundry Number: 306-208 Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisl!f day of June, 2006 Encl. fJrJ:j ,/,'~J ~\4\01P rf \v 6/( <t i fp~ ~/.3/~ ut}!.L4--0b STATE OF ALASKA . ALASKA L AND GAS CONSERVATION COMMISSION JUN 1 2 2006 APPLICATION FOR SUNDRY APPROV~I 'I&G C C .. 20 MC 25.280 masl\8Ì)1 as ons. Of11T1ISSlon Anchorage ~ú.A- Co' 14/ 2.0 0 l# RECEIVED 1. Type of Request: IBI Abandon o Repair Well o Plug Perforations o Stimulate o Alter Casing o Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension o Re-Enter Suspended W 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development 0 Exploratory 200-061 /' 3. Address: o Stratigraphic o Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20665-0 1-00 7. KB Elevation (ft): 60' 9. Well Name and Number: PBU 15-12A / 8. Property Designation: 10. Field / Pool(s): ADL 028306 Prudhoe Bay Field / Prudhoe Bay Pool ....·.ci·..·..cc>iCi/i.. .,c; "A. ···.··i··c. ·.i/;>;,;>.;;>.'. 'ii '''» ",C'CCi >iCiCi> ii Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10730 8855 10696 / 8852 None 8268 CasinQ LenQth Size . MD / TVD Burst Cølfapse Structural ./' Conductor 80' 20" 80' 80' 1490 /' 470 Surface 2482' 13-3/8" 2482' 2482' 4930 /' 2670 Intermediate 8697' 9-5/8" 8697' 8261' 6870 /' 4760 Production /' Liner 734' 7" 8367' - 9101' 7944' - 8652' .A'160 7020 Liner 2447' 2-7/8" 8283' - 10730' 7863' - 8855' ./' 10570 11160 "'" " ./' Perforation Depth MD (ft): I Perforation Depth TVD (ft): I )/: TUbin~~ Tubing Grade: Tubing MD (ft): 9400' -10680' / 8851' - 8851' 4; /2" x 5-1/" 3-1/2" L-80 8280' & 8446' Packers and SSSV Type: 9-5/8" x 5-1/2" Bilker teif~7r IPackers and SSSV MD (ft): 8348'; 8252' / 'SABL-3' packer 12. Attachments' ,,¡ ~ f~ . ~ell Class after proposed work: 181 Description Summary of propo? ~I"' Sketch Z *' ./ ~ 0 Exploratory 181 Development 0 Service o Detailed Operations Programl 14. Estimated Date for 0A P JUn"06 15. Well Status after proposed work: Com~ncing Ope ratio s OOil o Gas o Plugged 181 Abandoned 16. Ve~ ba Appr~ ~E- ~: o WAG OGINJ OWINJ o WDSPL cò.i n( ~sion resentative: 17. I hE~ by ~fy th~t the f~9 is true and correct to the best of my knowledge. Contact Ron Phillips. 564-5913 Prin ~d Name "ø¡¡\¡e We 0'1, " Title Senior Drilling Engineer Prepared By Name/Number: SiQnature j..r:'d;f·ç"Øtíf¿~~~· Phone 564-5153 Date 610 é¡ lr7b Terrie Hubble. 564-4628 /' / '-/ Commission Use Only ~~roval' Notify Commission so that a representative may whness I Sundry Number:t 3ò{tJ-ð2.0R o PI Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance T.e-t;. t BO}? E to -;500 r~' Ot(7~:y~t.u..(..t t-o to MH. VL (l t. L i tt.tZ¡l~tt ~t( y11~1r'~ fVOU ~k..( ;... ~:I}Þ~t~. Subsequent Form Required: lO-Œ;~ RBDMS 8Ft JUN J 4 2006 APPROVED BY 6-11/-66 Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revised 07/2005 ORíGmÃL' Submit In Duplicate · e ()bp GL~1ft" To: Winton Aubert· AOGCC Date: June 07, 2006 From: Ron Phillips - BPXA GPB Rotary Drilling Subject: Reference: 15·12A Application for Sundry Approval - Pre-Rig work for Sidetrack Operations API # 50-029-20665-01 Approval is requested for the proposed Pre-Rig work of PBU well 15-12A. Well 15-12 was drilled as a producer in October 1981 and was sidetracked June 2000 as a horizontal producer. The parent well had poor tubing with known leaks. In an attempt to save cost, two POGLM's were pulled from the well and the 5-1/2" tubing was left in place. This tubing had known communication between the 5-1/2" and the IA even before the POGLM's were pulled. The rig then ran 3-1/2" jointed pipe inside the damaged 5-1/2" tubing. Initial perfs were shot 9400'-9900' and 10,440'-10,680' and the well came on at 1500 BOPD. The well had stable production and has seen very little wellwork activity .On June 10, 2004 the well suddenly made 3000 BWPD that tested out to be Cretaceous water. The well was shut-in with production loss of 600 BOPD at 23,000 GOR The well has 3-1/2" x 5-1/2" communication along with 5-1/2" x IA communication, / and Cretaceous leak. Further diagnostics were not done since an economic fix was not anticipated. The well was sanded back to secure the well and prevent damaging cross flow into the Ivishak on July 1, 2004. Slickline hung up while trying to tag the sand top and ended up leaving the tools and wire in the hole. Braided line left more tools in the hole trying to fish out the slickline tools. Coil eventually got on the /' well and they too hung up and lost their BHA of jars, hydraulic disconnect, etc..... The wells group did not want to try and fish the junk and the well has been shut in since. 15-12A failed and MIT-OA with a 4.5 BPM leak rate on 4/29/05. The sidetrack is currently scheduled for Nabors rig 27E, beginning around July 10th 2006. The pre-rig work for this sidetrack will begin at the Well's Group's earliest convenience after sundry approval. Note: We will not be able to P&A this well until the drilling rig moves on the well and pulls both strings of tubing 3-1/2" and 5-1/2" and can set the 9-5/8" CIBP and set cement on top of it. We plan to cut and pull from 7,800', but need the RST Log first to see where we have fill on the backside of the tubing and a freepoint to determine where the 5-1/2" will pull free from. Current Condition: ./ Currently SI due to fish in 3-1/2" tubing at 8,295'. ./ 28 BBL sand plug set at 8,800' to 10,680'. ./ ./ Perforations from 9,400' to 10,680'. ./ 9-5/8",47#, L-80 casing landed at 8,697'. Cretaceous leaks. 5 ./ 5-1/2",17# X 4-1/2",12.6#, L-80 tubing landed at 8,445'. Cretaceous leaks. ./ 3-1/2",9.3# at 8,280. Cretaceous leaks. ./ 2-7/8",6.4# liner at 10,730'. ./ 5-1/8 FMC tree. 15-12A Application for Sundry . '- .t ~ ~ ~ ...... () v o V\ J r- . e Scope Pre-Ria Operations: 1. RU SL and drift the 3W' tubing to 7,850' MD. This will confirm the tubing is clear to the required cut depth of 7,800' MD. 2. R/U E-Line wi RST to locate fill behind 3-1/2" tubing. / 3. RIH with the appropriate jet cutter and cut the 3-1/2" tubing at -7,800' MD. 4. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 5. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 6. Bleed casing and annulus pressures to zero. 7. Set a BPV. Secure the well. Level the pad as necessary. RiQ Operations: 1. MI I RU Nabors rig 27E. Pull BPV. 2. Circulate out diesel freeze protection and displace the well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC. ,/ 4. R/U. Pull 3W' tubing from the cut at -7,800' MD. RU SL and drift the 5W' tubing to 7,800' MD. This will confirm the tubing is clear to the required cut depth of 7,750' MD. 5. RIH wi Free Point Indicator Tools. Verify tubing is free to -7,750' MD. 6. RIH with the appropriate jet cutter and cut the 5-1/2" tubing at -7,750' MD. 7. R/U. Pull 5W' tubing from the cut at -7,750' MD. 8. R/U E-line. M/U~gaUge ring I junk bas L. RIH and tag tubing stump. POOH. 9. RIH with HES ZSVon E-line. Set' at -7,722' MD, as required to avo~cu ing a casing collar while mi . g the wi,!!cW~J)la .3 BL cement cap (100ft) on top of. . POOH. R/U W 6A- RTTS to test·ea3t ireFll9ri~ ¡:RJg and de ine shallowest depth of 9-5/8" leak.. 1:$ v 10. P U and RIH with mill assembly to dress up cement plug to land whip stock on. POOH. 11. P/U and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly, Orient whip stock, as desired. Shear off of whip stock. 12. Displace the well to 10.8ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 13. Mill 20' window in 9-5/8" casing at ± 7,700' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 14. Pull up into 9 5/8" casing and conduct an FIT. (Notify ODE if 11.6 ppg FIT is not obtained). POOH. 15. M/U 8112" Dir/GR/Res/PWD assembly. RIH, kick off and drill the 8W' intermediate section. 16. Continue drilling ahead in the 8W' hole section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 17. Run and cement a 7",26.0#, L-80 intermediate drilling liner. 18. Run and cement 7" scab liner from intermediate drilling liner top up to 500' from surface casing / shoe. Assuming there are no shallow 9-5/8" leaks. 19. M/U 6-Ys" tri-cone bit Dir/GR/Den/Neu assembly. 20. Test 9-5/8" and 7" scab liner to 3500 psi. 21. RIH to the 7" scab liner shoe track, test scab, drill out cement I float equipment. 22. RIH to the 7" liner shoe track and test liner for 30 minutes and record, drill out. 23. Displace the well over to Flo-Pro drilling fluid, then drill 20' new formation. 24. Pull up into the shoe and conduct a FIT. (Notify ODE if 10.0 ppg FIT is not obtained). Drill ahead through Zone 2, completing build section. POOH. 25. M/U 6-Ys" PDC drilling assembly with Dir/GR/Res/Denl Neu. RIH. 26. Drill ahead to TD. Fault just beyond TD! 27. Circulate well bore clean, short trip to shoe, circulate. POOH. 28. Run and cement 4W', 12.6#, L-80, IBT-M solid production liner. POOH. 29. R/U and run perf guns. LD perf guns. 30. R/U and run a 4W', 12.6#, 13CR-80 tubing completion, stinging into the 4W' liner tie back sleeve. 31. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 32. Set a TWC. 33. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. 15-12A Application for Sundry · - 34. Freeze protect the well to -2,200' TVD. Secure the well. 35. Rig down and move off. Post-Ria ODerations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Timina: This sidetrack is scheduled for spud July 10, 2006. Estimated Pre-rig operations start date: Estimated Rig operations / spud date: 06/10/06 07/10/06 Ron Phillips Operations Drilling Engineer 564-5913 15-12A Application for Sundry TREE = ' WB..LHEAO = ACTUATOR '" KB. !;LEV = BF. B..EV = KOP= Max Angle = Datum MO = DatumTVO = 5-1/8" FMC FMC AXB..SON 60' NA 2950' 94 @ 9785' NA 8800'SS . 15-12A -- SAFETY NOTES: WELL> 70° @ 9370' AND> 90° @ 9560'. I I 2097' 2186' -1 3-1/2" HES X NIP, 10 = 2.813" I 5-112" OTIS RQM SSSVN, MILLED TO 4.80" 10 13-3/8" CSG, 72#, L-80, 10 = 12.347" I 2482' ..4 ~ Minimum ID = 2.372" @ 8292' 3-1/2" X 2-7/8" LNR CROSSOVER 1 ~ ST MO TVO 1 3136 3129 2 5795 5548 3 8198 7782 GAS LIFT IIt1ANORB..S OEV TYPE VLV LATCH 16 KBG-2-9 OMY INT 25 KBG-2-9 OMY INT 17 KBG-2-9 OMY INT PORT OA TE o 06/12/04 o 06/12/04 o 06/12/04 8251' H BKR KBH-22 SEAL ASSY, 10 = 3.00" I 8252' H 5-112" X 3-1/2" BKR SABL-3 A<R, 10 = 2.78" I I FISH - 31.17' W/L TOOL STRING; 11.87' COIL I 8268' .1--- __ __ I 8267' H 3-1/2" HES XN NIP, 10 = 2.635" I I I I't ~i-1 8280' H 4-1/2" BKR LOCATOR SUB, 10 = 3.00" I 3-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 = 2.992" 8280' I J 8283' H 4.375" BKR LNR TIEBACK SLY, 10 = 4.00" I I 3.80" BKR LNR DEA..OY SLY, 10 = 3.00" I 8289' I 8285' H BTM OF BKR SEAL ASSY, 10 = 3.00" I I TOP OF 2-7/8" LNR, 10 = 2.372" I 8293' I 8292' H 3-1/2" X 2-7/8" LNRXO, 10 = 2.372" I I I TOP OF BOT PBR ASSY I 8342' I ~ ~ H I ~ 8348' 9-5/8" X 5-1/2" BOT A<R (BB-fINO LNR) I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, 8354' I - 8354' H 5-112" X 4-112" XO (BB-fINO LNR) I """1 10 = 4.892" (BB-fINO 2-7/8" LNR) I TOP OF 7" BOT PBR ASSY I I 8383' H 4-1/2" OTIS XN NIP, MILLED TO 3.80" I 8322' I ~ ...H 8367' H 7" BTM LNR HGR I I 4-112" TBG-PC, 12.6#, L-80, .0152 bpf, 8445' I I H I 8446' 4-1/2" WLEG (BB-fINO LNR) 10 = 3.958" (BB-fINO 2-7/8" LNR) I 9-5/8" CSG, 47#, L-80, 10 = 8.681" I 8697' ..4 .. I PERFORA TION SUMIIt1ARY REF LOG: SWS GRlCNL ON 08/31/00 ANGLE AT TOP PERF: 79 @ 9400' Note: Refer to A'oduction OB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 4 9400 - 9900 0 09/02/00 2 4 10440 - 10680 0 09/02/00 ~ 7" MILLOUT WINDOW 9111' - 9118' WHIPSTOCK @ 9100' RA TAG @ 9109' I 7" LNR, 29#, L-80, 10 = 6.184" I 9430' I ~ y / I 2-7/8" LNR, 6.4#, FL4S, .0058 bpf, 10= 2.441" 1-1 I PBTO H 10696' I 10730' I OA TE REV BY COMMENTS OA TE REV BY 11/05/81 ORIGINAL COM PLETION 08/04/00 CTD SIDETRACK 08/29/01 CHlKAK CORRECTIONS 09/11/03 CMOITLP OA TUM MOITVO CORRECTIONS 06/12/04 RWL/KAK GLV C/O 07/27/04 BJMcN/K~ FISH COMMENTS PRUOHOE BA Y UNIT WB..L: 15-12A PERMIT: 2000610 API No: 50-029-20665-01 SEC 22, T11 N, R14E, 2113' FNL & 3803' FB.. BP Exploration (Alaska) ÏRæ= . 5-1/8" FMC De!Ompletion 15-121 WELLHEAD = FMC SAFETY NOTES: WELL> 70° @ 9370' ACTUATOR =. AXELSON AND> 90° @ 9560'. KB. ELEV = 60' BF. ELEV = NA KOP= 2950' Max Angle = 94 @ 9785' Datum MD = NA Datum 1VD = 8800'SS I 13-3/8" CSG, 72#. L-80, ID = 12.347" I 2482' ~ ~ Minimum ID = 2.372" @ 8292' .J 7700' 7.3 BB~nt I ~ 7800' 9-5/~'.<;;I8f'"J G ~ S " ¡,J6A- I 3-1/2" X 2-7/8" LNR CROSSOVER . , 8W 5-i72" TBG-PC, 17#, L-80, .0232bpf, ID=4.892" , A'8'5J>' H 3-1/2" TBG, 9.3#, L-80, .0087bpf. ID = 2.992" I L.---8251 , -1 BKR KBH-22 SEAL ASSY, ID = 3.00" I I 8252' H 5-1/2" X 3-1/2" BKR SABL-3 PKR, ID = 2.78" I FISH - 31.17' W/L TOOL STRING; 11.87' COIL 8268' 1---- ~I 8267' -- 3-1/2" HES XN NIP, ID = 2.635" I -f... -- 8280' -1 4-1/2" BKR LOCATOR SUB. ID = 3.00" I I 3-1/2" TBG, 9.3#, L-80. .0087 bpf, ID = 2.992" I 8280' - 8283' -- 4.375" BKR LNR TIEBACK SLV, ID = 4.00" I I 3.80" BKR LNR DEA..OY SL V, ID = 3.00" I 8289' r 8285' -- BTM OF BKR SEAL ASSY, ID = 3.00" I I TOP OF 2-7/8" LNR, ID=2.372" I 8293' r I 8292' -1 3-1/2" X 2-7/8" LNR XO, ID = 2.372" I I TOP OF BOT PBR ASSY I 8342' I g ~ I -- I 2S 8348' 9-5/8" X 5-1/2" BOT PKR (B8-\IND LNR) I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, 8354' I - 8354' 5-1/2" X 4-1/2" XO (B8-\IND LNR) I --., ID = 4.892" (B8-\IND 2-7/8" LNR) I 8383' H 4-1/2" OTIS XN NIP, MILLED TO 3.80" I I TOP OF 7" BOT PBR ASSY I 8322' ~ I 8367' H 7" BTM LNR HGR I ¡,¡¡ I 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, 8445' I I 8446' H 4-1/2" WLEG (B8-\IND LNR) I ID = 3.958" (B8-\IND 2-7/8" LNR) I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8697' ..j ~ I 7" MILLOUT WINDOW 9111' - 9118' PERFORA TION SUMMARY ~ WHIPSTOCK@ 9100' REF LOG: SWS GRlCNL ON 08/31/00 RA TAG @ 9109' ANGLE AT TOP ÆRF: 79 @ 9400' Note: Refer to A'oduction DB for historical perf data ~~QO SIZE SPF INTERV AL Opn/Sqz DATE 2 4 9400 - 9900 0 09/02/00 2 4 10440 - 10680 0 09/02/00 I PBTD H 10696' I .& I 7" LNR, 29#, L-80. ID = 6.184" I 9430' ~ ~ I- I I 2-7/8" LNR. 6.4#, FL4S, .0058 bpf, ID = 2.441" H 10730' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/05/81 ORIGINAL COM PLETION WELL: 15-12A 08/04100 CTD SIDETRACK PERMIT: 2000610 08/29/01 Ct-VKA K CORRECTIONS API No: 50-029-20665-01 09/11/03 CMOITLP DATUM MD/TVD CORRECTIONS SEC 22, T11 N, R14E, 2113' FNL & 3803' FEL 06/12/04 RWUKAK GL V C/O 07/27/04 BJMcNlKI< FISH BP Exploration (Alaska) -- 'JREE=, ' B...LI'iEJltO = ACTUA TOR = '¡(B. B...EV = BF. -B...EV = KOP= Max Angle = Datum MO = Datum TVO = 5-1/8" FMC FMC AXB...SON 4,000'MO 15-12Beoposed Completion e 2200' H 4-1/2" HES X NIP, 10 = 2.813" I 2482' H 13-3/8" CSG, 72#, L-80, 10 = 12.347" 2982' H 7" Scab LNR HGRI 7550' 1-1 7" Liner Hanger 7700' 1-1 9-5/8" Whipstock, millout window DATE REV BY COMMENTS 11/05/81 ORIGINAL COM PLETION 08/04/00 CTD SIDETRACK 08/29/01 CH/KAK CORRECTIONS 09/11/03 CMOITLP DATUM MonvO CORRECTIONS 06/12/04 RWUKA GLV C/O 07/27/04 BJMcN/K FISH DATE 05/10/06 05/17/06 REV BY RLP RLP COMMENTS 15-12B (w p04) Side track 15-12B (w p05) Side track PRUDHOE BA Y UNIT WB...L: 15-12B PERMIT: API No: 50-029-XXXXX-XX SEC 22, T11N, R14E, 2113' FNL & 3803' FB... 7700' H Top of Cement 7.33 BBL 7800' H 9-5/8".QBP- E:: è S \J "'-'6"" 7825' H 5-1/2" TBG-PC, 17#, L-80, .0232bpf, 10=4.892" 7850' H 3-1/2" TBG, 9.3#, L-80, .0087bpf, 10 = 2.992" 8672' H 4-1/2" HES X NIPPLE; 10=3.812" 8683' H 7" X 4-1/2" BAKER S-3 PERM A<R; 10=3.88" 8708' H 4-1/2" HES X NIPPLE; 10=3.812" 8729' H 4-1/2" HES X NIPPLE; 10=3.812" 8740' H 4-1/2" TBG, 12.6#, 13CR-80 8740' H 4- 1/2" LNR HGR/L TP w / 10' Tieback Sleeve 8890' -! 7" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" 8697' 1-1 9-5/8" CSG, 47#, L-80, 10=8.681" 11536' H 4-1/2" CSG, 12.6#, L-80, .0152bpf, 10 =3.958" I BP Exploration (Alaska) RE: 15-12A P&A difficulties . e Thank you Winton. We'll include greater detail in the application for Permit to Drill. regards, Dave Wesley, Jr. GPB Sr. Drilling Engineer (90?) 564-5153 From: Winton Aubert [mailto:winton_aubert@admin.state,ak.us) Sent: Wednesday, May 24, 2006 3:41 PM To: Wesley, Dave E Subject: Re: 15-12A PM difficulties Dave, Under the circumstances, the Commission win not require you to plug 15-12A past the obstructions. I presume both 3-1/2" and 5-1/2" tubings will be pulled and a 9-5/8" CIBP set as deep as possible, then capped with cement and tested. Pursuant to 20 MC 25.112 (i), upon your request the Commission can approve this variance to normal plugging requirements. Winton Aubert AOGCC 793-1231 Wesley, Dave E wrote: Sorry Winton. I believe you can open a .pdf file. If not, please let me know and I'll fax a copy over. thanks, Dave Wesley, Jr. GPB Sr. Drilling Engineer (90?) 564-5153 From: Winton Aubert [mailto:winton aubert@admin.state.ak.us] Sent: Wednesday, May 24,20067:17 AM To: Wesley, Dave E Subject: Re: 15-12A PM difficulties Dave, Can you resend the schematic in a different format? We don't support Canvas. Thanks, Winton 10f2 6/14/20067:25 AM RE: 15-12A P&A difficulties . - , Wesley, Dave E wrote: Winton, DS 15-12A is a candidate for sidetrack. Current condition: Coil sidetrack with 2 7/8" liner, perfs from 9,400' to 9,900' and 10,440 to 10,680'. This production liner has been sanded back to approximately 8,800'. While attempting to tag the sand top,lost wireline tools. Fishing attempts left additional wireline tools. Following with coil made it worse,... ...Ieft a coil fish on top of the others. Several attempts were made to fish all the junk with a rig, without success. The issue now is that we have no way to access the 2 7/8" liner to pump P&A cement. With the sand on the perfs and the multiple fish, it is unlikely we will be able to downsqueeze cement from above. There is a cretaceous leak through the 9 5/8" and the 5 1/2" and 3 1/2" tubing. We suspect we may have fill from this leak. Our current plan is to determine at what depth we can cut and pull tubing, then set a cast iron bridge plug above the junk. KOP for the sidetrack will be determined by the depth of decompletion. Best I can determine, the top of cement behind the 9 5/8" casing from the original job is approximately 8,200'md. This is best case, only 250 sks was pumped. As our options are limited, can you tell us if this will be acceptable as an abandonment? Many thanks, «Original Completion 15-12A.ZIP» Dave Wesley, Jr. GPB Sr. Drilling Engineer (907) 564-5153 20f2 6/14/20067:25 AM MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permitto Drill 2000610 DATA SUBMITTAL COMPLIANCE REPORT 91912002 Well Name/No. PRUDHOE BAY UNIT 15-12A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20665-01-00 MD 10730 ~ TVD 8855 _ Completion Dat 9/2/2000 J Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N._~o Sample N_go Directional Survey N._~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments ED D GR Gamma Ray T ED D ~amma Ray ED D (gf~"~m m a Ray D ~ c L ~ MWD Survey Report J MWD Survey Report.~"f 10065 (.~um a I Neutron 2 GPJMCNL I 9121 10078 Open 11/9/2001 10488 8800 10696 Case 4/26/2001 10065 8800-10696 I 9082 10078 Open 11/29/2001 10523.~" 1 9077 10730 Open 11/29/2001 10522 -' FINAL 2/2/2001 Digital Data FINAL 9645 10730 2/2/2001 9645-10730 Paper Copy FINAL 8800 10696 ch 5/3/2001 10065 8800-10696 Digital Data FINAL 8800 10696 oh 5/3/2001 8800-10696 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received ?.~-~"71~-'~ Analysis R P.c.~.iv~.d ? Daily History Received? ~1 Formation Tops (~ N Comments: Permitto Drill 2000610 MD 1073O TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/9/2002 Well Name/No. PRUDHOE BAY UNIT 15-12A Operator BP EXPLORATION (ALASKA) INC 8855 Completion Dat 9/2/2000 Completion Statu 1-OIL Current Status 1-OIL Date: APl No. 50-029-20665-01-00 UIC N Transmittal Form BAKER HUGI4E$ Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference :WELL: 15-12A Prudhoe Bay North Slope, Alaska Contains the following: 1 LAS Format disk 1 Film 1 Measured Depth GR print 1 TVD-GR print LAC #: 15483 Sent By: B~.~~ING Received ByC~ ,~ _x~'~ ~ ~._ / Date: NOV. 23,2001 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9* Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVED k'o~/2 ~ 2001 Alaska Oil & Gas Cons. CommJ~on ,A~chorage BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference :WELL: 15-12APB1 Prudhoe Bay North Slope, Alaska Contains the following: 1 LAS Format disk 1 Film 1 Measured Depth GR print 1 TVD-GR print g---g [ Sent By: BRENT KING Date: NOV. 23,2001 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-92 Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVED I~:'..,-' ?_ 9 2001 Alaska 0ii & Gas Cons. Commission Anchorage 04/26/01 Schlumberg Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 1102 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 5-25B ~C')0-tc/-7 20472 MCNL 10/29/00 I 1 1 D.S. 15-12A~ Ob-~(0 1 20372 MCNL 08/31100 I I 1 1 .. ,, .... PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED At~,a Oil & 6a~ Coas. Q~'~a .. Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Rece~ ~ STATE OF ALASKA ALAS( .... .OIL AND GAS CONSERVATION COMIC" ~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~'~ C'-~.~ D S"--r~2ended r"] Abandoned r~ Service ~ -,,,1 2. Name of Operator : ~T~)I~'I 7. Permit Number BP Exploration (Alaska), Inc. ¥~.,, 200-061 3. Address~ ~,) 8. APl Number P. O. Box 196612, Anchorage, AK 99519-6612 8. H,,~. 50-029-20665-01 4. Location of well at surface ---'-,,----,,.,.~ L 9. Unit or Lease Name 2113' FNL, 3803' FEL, Sec. 22, T11 N, R14E, UM (asp's 677429, 5959402) L... ~.,,~ ~ ,:. :,~?~ . Prudhoe Bay Unit At Top Producing Interval [ __~_:~).~_Z ,__4~_ 10. Well Number At Total Depth3738' FNL, 2085' FEL, SEC 22, T11N, R14E, UM (asp's 679190, 5957819) I__~1 V2.~!~:: !.'_' k*~[ 11. Fiold and Poo11'~'12A 2397' FNL, 2234' FEL, SEC 22, T11N, R14E, UM (asp's 679006, 5959155) ~ ............. "J Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 60 feetI ADL 28306 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions July 24, 2000 July 30, 2000 September 2, 2000 I N/A lea MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10730' MD /8855' TVD 10681' MD /8851' TVD YES [] No r'lI 2097, feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD & Mem GR/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 80 32" 300 sx PF 13-3/8" 72# L-80 Surface 2482' 17-1/2" 2500 sx Fondu & 400 Sx PFC 9-5/8" 47# L-80 Surface 8697' 12-1/4" 250 Sx Glass C 7" 29# L-80 8367' 9101' 8-1/2" 300 Sx Class C 2-7/8" 6.5# L-80 8283' 10730' 4-1/8" 23 bbls 15.8 ppg LARC 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 8354' 8342' 4-1/2" 8446' 8252' 9400' - 9900' MD; 8851' - 8846' TVD; @ 4 SPF 3-1/2" 8281' 10440' - 10680' MD; 8849' - 8851' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 0 R I G! NAL (See Sidetrack Summary for details) , 27. PRODUCTION TEST !Date First Production Method of Operation (FloWing, gas lilt, etc.) September 8, 2000 Gas Lift Date o! Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 9/11/2000 3.0 Test Pedod >I 3703 :Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') Press. -330 psi 24-Hour Rate > 1499 5552 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED * This 10-407 is submitted as directed per the 10-401 form approved May 23, 2000 (Permit ~200-061) SEP 22. 2000 ,~ssf~ 0~*i & Gas Cons. Commi~si Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Sag River Sand 8694' 8259' Top of Shublik 8736' 8299' Top of Sadlerochit 8800' 8361' Top of Zone 1 B 9251' 8781' 31. LIST OF ATTACHMENTS Summary of 15-12A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed '~.JJ~~ t~, _~.j~./~~Title CoilTubin,qDrillin,qEn.qineer Date Lamar L. Gantt Prepared by Paul Rauf 564-5799. 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 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. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 15-12A c)ESCRIPTION OF WORK COMPLETE COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 7116/2000: MIRU CTU (service unit). PT BOPE. Attempted twice to mill SSSV RQM nipple to 4.8" - no Success. 711712000: Made third attempt to mill out SSSV nipple @ 2186' MD - no success. RIH & milled XN nipple to 3.8"@ 8374' MD. Milled cement f/9075' to 9100'. Milled window through the 7" liner off the whipstock f/9101' - 9108'. Dressed window interval & drilled OH to 9121 '. POOH laying in Biozan. FP'd well. RD CTU. 7/21/2000: MIRU Nabors 3S. 7122/2000: MIRU CTU#4. 7/23/2000: PT'd BOPE. RU E-line coil. 7/24/2000: RIH & drilled OH to 9135'. Performed LOT to EMW of 9.54 ppg. Drilled to 9137' & POOH. RIH & drilled to 9312'. 7/2512000: Drilled to 9431' & POOH. RIH & drilled to 9535'. POOH. 7/26/2000: RIH & drilled to 9905'. POOH. 7/27/2000: 7/28/2000: RIH & drilled to 10010'. POOH. RIH & began OH ST @ 9620'. CT stuck. Spotted Crude & freed CT. Completed OH ST. Drilled to 9800' & POOH. RIH & drilled to 9880' MD. 7/29/2000: Drilled to 10713'. 7/30/2000: Revised TD to 10730' MD. Conditioned OH f/liner. POOH. MU 2-7/8" FL4S liner. 7/31/2000: 8/01/2000: 8102/2000: 8/03/2000: RIH w/liner & landed it @ 10730'. TOL = 8283'. PBTD @ 10696'. Pumped 23 bbls of 15.8 ppg LARC to cement liner in place. Dropped dart. Bumped plug. Press liner to 3000 psi. Unstung f/liner. Full returns entire job. Contaminated Cement w/Biozan & jetted contaminated Cement from the wellbore. POOH. PT'd BOPE. RIH & milled RQM SSSV Nipple @ 2170'. Completed milling RQM Nipple & flow couplings. POOH. RIH w/CT nozzle & made cleanout run. POOH. NU FMC coil tbg head on wellhead. RIH & drifted completion w/GLM assembly. POOH. Displaced well to water. RDMOL CTU#4. MIRU 3S pipe shed. Prep'd floor f/running completion. PT'd new FMC spool to 2000 psi - passed. RIH w/new 3-1/2" 9.3# L-80 Mod EUE Tubing completion (included a 3-1/2" x 5-1/2" Baker SABL-3 Packer @8252' & a 3-1/2" SSSV X nipple @ 2097'). Stung into liner top. PT'd tubing to 1500 psi f/30 min - held. Began space out of tubing prior to landing. RECEIVED Sidetrack Summary Page I SEP 22. 2000 Alaska 0~; & Gas C~n,~. Commiss~or~ Anchorage 15-12A ~ESCRIPTION OF WORK COMPLETE COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 8/04/2000: 8/05/2000: 8/21/2000: 8/22/2000 - 8/24/2000: 08/30/2000: 8/31/2000: 9/01/2000 - 9/02/2000: Space out tubing. Circulated out 5-1/2" x 9-5/8" annulus w/Diesel to 3200'. Cimulated out 3- 1/2" x 5-1/2" annulus w/inhibited SW. FP'd 3-1/2" x 5-1/2" annulus & 3-1/2" tubing w/Diesel. Landed tubing hanger. PT'd 3-1/2" x 5-1/2" liner to 2000 psi - passed. RDMOL. 3S dg released 0400 hrs. Completed RD. Pressured up to 4500 psi to set packer @ 8252'. MIT tubing to 3500 psi - passed. IA to 3500 psi - passed. Completed GLV work. MIRU Nordic 1. Accepted rig 1330 hrs. Weather delay. Completed Nordic 1 RU. PT' BOPE. RIH w/Mem GR/CNL logging tools. Tagged PBTD @ 10681' & logged well to 8800'. POOH w/logging tools. RIH w/Perf guns to PBTD & shot 740' of Initial Perforations f/: 9400'- 9900' MD (Zone lB) 10440' - 10680' MD (Zone lB) Used 2" carriers & shot all Perfs @ 4 SPF, random orientation, & overbalanced press. POOH w/guns. ASF. FP'd well. RDMOL. Placed well 15-12A on initial production & obtained a valid well test. RECEIVED SEP 22 2000 Alaska C~ & Gas Co~,s, ~mmission Anchorage Sidetrack Summary Page 2 BP Amoco WELLPATH DETAILS 1~.12A 500292066501 PwentWellpath: 15-12APBI Tie on MD: 9645.00 Vwtlc~l SecfJon Origin: Slot o 12 (0.00,0,00) Vertical Section Angle: 357.00° R~g: Nabors 3S Depfh Reference: 20:12 10/19/1981 00:00 REFERENCE INFORMATICN Co.(xdinate (N/E) Refem~sa: Well Centre: 15-12. Tree Norlh VmtJcal ('WD) Refemflce: Fmld * Mean Ssa Level Section (VS) Reference: Sbt- 12 (O.00,O.00) Measured D~plfl Reference: 20:1210/19/198100:00 60.o above Msan Ssa Level ANNOTATIONS NO, TVO MO Annutatk,n i 84~3.7e 9000.00 Tie-in Paint 879~.209646.00 K~k-~ff Polnl 3 8794.54 10730.c0 Pn3JecledtoTD 34 TARC.~-T No, ~ +N~ +E/-W Target · 0.00 .1603.42 1748.89 15-12APo~ge~3,1 2 88~0.00 -1370.49 1839.,50 15o12AT~1 8860.00 -760.51 1678.60 15-1~ T3.2 6840.60 -160.11 1542.12 15-12A T3.3OTD 16-12 (16-12AF~l) HUGH INTEQ / ~ Azimuths to Tree North Magnetic Ninth: 26.96° Ivlallne~c Field Stmnsth: 57481nT Dip An~le~ 80.79° Dale: 9/~/2000 Model: BGOM2000 Wlllpllh: Cml~d By: Br~ {'UI~{, Dale: - ............................ i:::::::::::::::: ......................... . ooo ................................ · -{ ....................... ~/: ' X i 1.1~T3.1' ~ ~ -~5oo---~ ............................ ~ .......................................................... ~ ........................................................... : ........................................................... ~ ............................................................................... ~ ............... ~ -! ............................ ~ ........................................................... ~ ........................................................... ~ ........................................................... ~ ...................................... I ~ ~a.~ I .............................. i ~ ..... ~ ........... , .......... ~ .......... ,- ........ , ........... ~ .......... ~ ........... ~ .......... , ........... ~ .......... ~ .......... ~--'--~ ......... ~ .......... ~--------~ .......... , ........... ~ ........... ~ ........... , ........... ~ .......... ~ .......... ~ .......... ~ .......... ~ .......... ~ ........... ~ .......... i ........... ~ .......... ~ .......... ~ .......... ~ .......... i ........ 0 500 10~ 15~ 2000 25~ ~00 'T"" i .... ...... ......... ............ ...... ~ : .................. ~ ....... ......... ........ ........ ...... ~ .... " .... :" ' ~'" .... '' "~' "~ i i ~ ...... ! ........ 88oo-...-.{ ........... ~ .......... .-.....-./ ............. ~ ..... ; ..... ~ .................. ::-.-::::::::-- :::~ ........... ; .... ; ~'"--'"~.--.-.:~ ........ ~ ........ ...... ~; ~ ~ ~ ; ..... ~- ~ · · --{ ~. /.. : ~ , ,ff~., .~,~,~,~.,,), ,,~,~3.~.~ ~ ~ ~ ~ ./ · ..t,~2(~) ~...-: ............. ~ ..... .......... ......... ..... ~ .... ..... .... ....... ......... f ....... ......... ...... ............ ~ ...... : ........ ....... ~ ~ ....... t .... ~ ~ -1800 -1600 -1400 -1200 -1000 -800 -600 Ve~l S~aon at 3~.~' [2~n] Prepared by Baker Hughes INTEQ nd of Well Survey Calculati ss Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLANE Company: Field: Well: Job No: AFE No: API No: BHI Rep: BP Exploration Alaska, Inc. Prudhoe Bay Unit 15-12A 48638 AP-1533 50-029-20665-01 Rig: Nabors 3S RKB Height: 60.000 Vertical Sect. Plane: 356.990 Mag. Declination: 27.200 Grid Correction: 1340 Job Start Date: !~l~ii~:ii::ii::::ii:::i:i:~iiii::::i~i ................................ Survey Date: ::i2~;I~..~../:!::ii!i!::iii~:::::iiii!::::ii:::: ................................ Survey Type: :::::::::5::5:):::::::::::::::::::::::5:::::::::: Meas. Depth (ft) 9645.00 Incl. Angle (deg) 91.50 (det~) 24.60 TRUE V. Depth (ft) 8853.20 Subsea TVD (ft) 8793.20 9678.00 88.30 23.10 8853.26 8793.26 9707.00 88.90 14.40 8853.97 8793.97 9740.00 92.10 5.20 8853.68 8793.68 9785.00 93.60 356.10 8851.44 8791.44 9819.00 92.70 352.30 8849.57 8789.57 9848.00 91.80 349.70 8848.43 8788.43 9889.00 91.60 347.00 8847.22 8787.22 9923.00 90.90 344.40 8846.47 8786.47 9948.00 86.50 342.90 8847.04 8787.04 9980.00 86.00! 340.50 8849.13 8789.13 10012.00 87.701 338.00 8850.89 8790.89 90.20 329.50 10047.00 10082.00 90.90 327.10 10155.00 91.90 321.50 10181.00 10211.00 318.3( 92.30 90.70 321.20 10247.00 88.30 325.00 10289.00 91.80 330.30 10328.00 92.60 334.70 10361.00 88.80 338.60 10390.00 88.00 342.60 10420.00 87.40 347.20 10454.00 88.30 350.70 10480.00 89.30 354.0( 355.60 91.20 10509.00 10540.00 91.60 357.50 10570.00 90.30 351.40 10600.00 348.00 91.00 347.00 87.20 8851.54 8851.20 8849.42 8848.46 8791.54 8791.20 8789.42 8788.46 8847.68 8787.68 8847.99 8787.99 8847.95 8787.95 8846.46 8786A6 8846.05 8846.86 8848.07 8849.34 8849.89 10651.00 8849.76 8786.0: 8786.8~ 8788.0' 8789.34 8789.89 8789.76 8849.00 8789.00 8848.51 8788.51 8848.17 8848.97 8788.17 8788.97 10678.00 85.70 346.10 8850.64 8790.64 10730.00 85.70 346.10 8854.54 8794.54 Coords. - True N(+)/S(-) (ft) -1291.24 -1261.06 -1233.63 -1201.16 E(+)/W(-) (a) 1853.15 1866.49 1875.80 1881.41 -1156.26 1881.93 -1122.49 1878.50 -1093.88 1873.96 -1053.74 1865.69 -1020.81 1857.29 -996.83 1850.26 -966.52 1840.23 -936.64 1828.91 -905.29 1813.45 -875.51 -816.27 1795.06 1752.49 -796.40 1735.76 -773.51 1716.39 -744.73 1694.78 -709.27 1672.32 -674.71 1654.32 -617.09 -588.16 -554.82 1641.25 1631.62 1623.82 1617.31 -529.06 1613.85 -500.18 1611.22 Coords.- ASP N(+)/S(-) Lat. (Y) 5958154.83 5958185.31 5958212.95 5958245.55 5958290.44 5958324.11 E(+)fW(-) DeF. (X) 679311.99 679324.61 679333.27 679338.11 679337.56 679333.34 Dogleg Severity (°/100ft) 0.00 10.71 30.06 29.51 20.47 11.47 Vertical Section (ft) -1386.45 -1357.02 -1330.11 -1297.98 -1253.17 -1219.27 5958352.61 679328.13 9.48 -1190.45 5958392.54 679318.91 6.60 -1149.94 5958425.26 679309.74 7.92 -1116.61 5958449.07 679302.14 18.59 -1092.30 5958479.13 679291.41 7.65 -1061.50 5958508.73 679279.39 9.44 -1031.08 25.31 7.14 5958539.71 5958569.04 679263.19 679244.10 679200.15 5958627.25 -998.96 -968.26 7.79 -906.87 5958646.72 679182.95 12.40 -886.15 5958669.15 679163.05 11.04 -862.28 5958697.41 679140.77 12.48 -832.411 5958732.33 679117.47 15.12 -795.82 5958766.45 679098.67 11.46 -760.37 5958796.41 679084.89 16.50 -729.44 5958823.51 679074.62 14.06 -701.64 5958852.25 679066.13 15.45 -672.34 5958885A3 679058.84 10.62 -638.70 5958911.10 679054.77 13.26 -612.80 5958939.90 679051.46 8.57 -583.8~ -469.25 1609.35 5958970.78 679048.87 6.26 -552.83 -439.41 1606.45 5959000.54 679045.27 20.79 -522.88 -409.90 1601.09 5959029.92 679039.21 11.57 -493.13 5959079.41 679027.00 7.70 -442.85 5959105.47 679020.12 6.48 -416.3z -360.12 1590.06 1583.79 679006.48 5959155.49 -333.91 -283.58 0.00 1571.33 -365.43 RECEIVED [nd of Well Survey Calculatio(i s Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLANE Company: Field: Well: Job No: AFE No: AP1 No: BltI Rep: BP Exploration Alaska, Inc. Prudhoe Bay Unit 15-12APB1 48638 AP-1533 50-029-20665-70 Rig: Nabors 3S RKB Height: 60.000 Vertical Sect. Plane: 356.990 Mag. Declination: 27~00 Grid Correction: 1340 Meas. Depth 9000.00 Incl. Angle (deg) 14.75 (del~) 141.00 TRUE V. Depth (ft) 8553.78 9100.00 14.25 142.00 8650.59 9146.00 22.60 130.00 8694.21 9193.00 40.60 117.20 8734.12 9233.00 40.10 88.20 8764.87 9264.00 44.60 63.90 8787.93 9308.00 59.60 45.00 8815.04 9340.00 64.7( 30.10 9378.00 70.40 16.50 9396.00 77.00 8.50 9425.00 89.90 358.40 9454.00 90.30 8.90 9497.00 87.60 11.90 9520.00 88.00 15.00 9556.00 89.80 22.50 9583.00 91.70 22.00 9615.00 91.60 21.10 91.50 92.40 9645.00 24.6( 9671.00 29.9O 9700.00 91.20 33.80 9731.00 90.60 37.60 9761.00 89.00 34.60 9791.00 87.90 31.50 9821.00 89.10 29.30 8830.05 8844.61 8849.67 8852.98 8852.93 8853.T 8854.60 8855.29 8854.94 8854.O2 8853.20 8852.32 8851.41 8850.92 8851.02 8851.84 8852.62 9852.00 86.80 26.4( 8853.73 9886.00 85.70 25.90 8855.95 9913.00 85.90 18.80 8857.93 9950.00 89.00 11.10 8859.58 9982.00 93.60 1.50 8858.86 10014.00 90.40 353.70 8857.74 10043.00 346.20 346.20 93.40 93.40 10078.00 8856.77 8854.7O Subsea (It) 8493.78 8590.59 Coords.-True N(+)/S(-) (n) -1578.58 -1598.17 8634.21 -1608.34 8674.12 -1621.25 8704.87 -1626.85 8727.93 -1621.71 8755.04 8770.05 8784.61 8789.67 8792.98 8792.93 8793.72 -1601.26 -1578.88 -1546.70 -1529.85 -1501.19 -1472.29 -1430.01 8794.60 -1407.66 8795.29 -1373.61 8794.94 -1348.62 8794.02 -1318.87 8793.20 -1291.24 E(+)/w(-) (n) 1638.01 Coords.- ASP N(+)m(-) Lat. (Y) 5957862.51 E(+)/w(-) Dep. (X) 679103.70 Dogleg Severity (°/100ft) 0.00 Vertical Section -1662.14 1653.60 5957843.29 679119.74 0.56 -1682.52 1663.87 5957833.37 679130.26 19.85 -1693.21 1684.59 5957820.95 679151.27 40.68 1709.26 1729.16 1756.76 1773.86 1787.62 -1707.19 5957815.94 679176.06 46.66 -1714.07 5957821.54 679195.83 54.49 -1709.98 5957842.63 679222.94 47.84 -1691.01 5957865.41 679239.51 44.10 -1669.55 5957897.91 679252.51 36.29 -1638.14 5957914.84 5957943.53 679255.82 679256.84 56.23 56.31 -1621.51 -1592.97 5957972.46 679258.00 36.23 -1564.21 5958014.91 679264.76 9.38 -1522.39 5958037.38 679269.57 13.58 -1500.36 5958071.70 679280.33 21.42 -1466.95 5958096.91 679289.96 7.28 -1442.53 5958126.93 679301.00 2.83 -1413.44 5958154.83 679311.99 11.67 -1386.45 5958178.19 679323.33 20.66 -1364.02 1791.33 1793.03 1794.87 1802.63 1807.98 1819.54 1829.76 1841.51 5958203.16 679338.04 679355.52 679372.62 679388.37 5958228.75 1853.15 5958253.39 14.06 12.41 11.33 5958278.90 8792.32 -1268.14 1865.05 8791.41 -1243.53 1880.34 8790.92 -1218.36 1898.42 8791.02 -1194.13 1916.10 8791.84 -1168.99 1932.45 8792.62 -1143.13 1947.62 8793.73 -1115.74 1962.09 8795.95 -1085.29 1977.05 8797.93 -1060.40 1987.28 -1340.23 -1316.05 -1292.77 5958516.74 679444.24 27.84 -1035.60 5958550.46 679435.11 0.00 -1001.28 8796.77 -932.53 1993.92 8794.70 -898.60 1985.59 8799.58 -1024.72 1996.80 5958424.65 679449.30 22.41 -1127.82 8798.86! -992.96 2000.31 5958456.47 679452.05 33.25 -1096.29 8797.74i -961.04 1998.97 5958488.35 679449.96 26.33 -1064.34 10.96 -1268.53 5958305.12 679402.93 8.35 -1243.49 5958332.84 679416.75 11.93 -1216.90 5958363.63 679430.98 3.55 -1187.27 5958388.75 679440.62 26.24 -1162.95 ObP ( BP Amoco ( mtl Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco !~!: Pruch~ Bay S#e: PB DS 15 wen: 15-12 Weapath: 15-12APB1 Dat~: 1/22/2001 Time: 11:13:47 I've: ! Oe-eralaa~ ~mace: Well: 15-12, True Norlh Vmllml ('ll/'B) Refm'ence: 20: 12 10/19/1981 00:00 60.0 SecUre ~ ~ We# (0.00E,0.00N,357.(g)Azi) Smvey Calemlatlem Mdlml: Minimum Curvakge Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagaetie Model: BGGM2000 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easttng: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft Latitude: 70 17 35.236 N 676296.98 fl: Longitude: 148 34 21.213 W North Reference: True Grid Convergence: 1.34 deg Well: 15-12 Slot Name: 12 15-12 WeliPositton: +N/-S 537.85 ft Northing: 5959401.88 ft Latitude: 70 17 40.525 N +E/-W 1145.01 ff F. asttng: 677428.99 ff Longitude: 148 33 47.842 W Position Uncertainty: 0.00 ft Wellpath: 15.12APB1 Drmed From: 15-12 500292066570 Tie-on Depth: 9100.00 ft Current Datum: 20: 12 10/19/1981 00:00 Height 60.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/8/2000 Declination: 26.96 deg Field Strength: 57481 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ft ff deg 0.00 0.00 0.00 357.00 Survey: MWD Start Date: 7/27/2000 Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation MD TVD 9100.00 8650.59 Kick-off Point 10078.00 8854.70 Projected to TD Survey inel Azbn :MapK VS deg; ~ it, ~lOOit ft 9100.00 14.25 142.00 8650.59 8590.59 -1598.17 1653.60 5957843.29 679119.74 0.00 -1682.52 9146.00 22.60 130.00 8694.21 8634.21 -1608.34 1663.87 5957833.37 679130.26 19.85 -1693.21 9193.00 40.60 117.20 8734.12 8674.12 - 1621.25 1684.59 5957820.95 679151.27 40.68 - 1707.19 9233.00 40.10 88.20 8764.87 8704.87 -1626.85 1709.26 5957815.94 679176.06 46.66 -1714.O7 9264.00 44.60 63.90 8787.93 8727.93 -1621.71 1729.16 5957821.54 679195.83 54.49 -1709.98 9308.00 59.60 45.00 8815.04 8755.04 -1601.26 1756.76 5957842.63 679222.94 47.84 -1691.01 9340.00 64.70 30.10 8830.05 8770.05 - 1578.88 1773.86 5957865.41 679239.51 44.10 - 1669.55 9378.00 70.40 i6.50 8644.6i 8784.61 -1546.70 1787.62 5957897.91 679252.51 36.29 -1638,14 9396.00 77.00 8.50 8849.67 8789.67 -1529.85 1791.33 5957914.84 679255.82 56.23 -1621.51 9425.00 89.90 358.40 8852.98 8792.98 -1501.19 1793.03 5957943.53 679255.84 56.31 -1592.97 9454.00 90.30 8.90 8852.93 8792.93 -1472.29 1794.87 5957972.46 679258.00 36.23 -1564,21 9497.00 87.60 11.90 8853.72 8793.72 -1430.01 1802.63 5958014.91 679264.76 9.38 -1522,39 9520.00 88.00 15.00 8854.60 8794.60 -1407.66 1807.98 5958037.38 679269.57 13.58 -1 500.36 9556.00 89.80 22.50 8855.29 8795.29 -1373.61 1819.54 5958071.70 679280.33 21.42 -1466,95 9583.00 91.70 22.00 8854.94 8794.94 -1348.62 1829.76 5958096.91 679289.96 7.28 -1442.53 9615.00 91.60 21.10 8854.02 8794.02 -1318.87 1841.51 5958126.93 679301.00 2.83 -1413.44 9645.00 91.50 24.60 8853.20 8793.20 -1291.24 1853.15 59581 54.63 679311.99 11.67 -1386.45 9671.00 92.40 29.90 8852.32 8792.32 -1268.14 1865.05 5958178.19 679323.33 20.66 -1364.02 O BP Amoco bp Baker Hughes INTEQ Survey Report Site: PB DS 15 Wen: 15-12 Wenpn,,,: 15-12.Ad:q~1 Survey MI) Iud Mira TVI) ~$Tv'D N/~ r,/W AhpN MapE D~ vs R ~ ~ R R : R R R R ~1~ R Date:. 1/22/2001 Ttm= 11:13:47 Page: Ce-er4b=le(Ng) l~re~ce: Walk 15-12, True Norlh Yediml (TVD) Reiweaee: 20:12 10119/1981 00:00 60.0 Set4bn (rS) Re~ We~ (0.00E,0.00N,357.00Azi) 9700.00 91.20 33.80 8851.41 8791.41 -1243.53 1880.34 5958203.16 679338.04 14.06 -1340.23 9731.00 90.60 37.60 8850.92 8790.92 -1218.36 1898.42 5958228.75 679355.52 12.41 -1316.05 9761.00 89.00 34.60 8851.02 8791.02 -1194.13 1916.10 5958253.39 679372.62 11,33 -1292.77 9791.00 87.90 31.50 8851.84 8791.84 -1168.99 1932.45 5958278.90 679388.37 10.98 -1268.53 9821.00 89.10 29.30 8852.62 8792.62 -1143.13 1947.62 5958305.12 679402.93 8.35 -1243.49 9852.00 86.80 26.40 6853.73 8793.73 -1115.74 1982.09 5958332.84 679416.75 11.93 -1216.90 9886.00 85.70 25.90 8855.95 8795.95 -1085.29 1977.05 5958363.63 679430.98 3.55 -1187.27 9913.00 85.90 18.80 6857.93 8797.93 -1060.40 1987.28 5958388.75 679440.62 26.24 -1162.95 9950.00 89.00 11.10 8859.58 8799.58 -1024.72 1996.80 5958424.65 679449.30 22.41 -1127.82 9982.00 93.60 1.50 6858.86 8798.68 -982.96 2000.31 5958456.47 679452.05 33.25 -1096.29 10014.00 90.40 353.70 6857.74 8797.74 -981.04 1998.97 5958488.35 679449.98 26.33 -1064.34 10043.00 93.40 346.20 6856.77 8796.77 -932.53 1993.92 5958516.74 679~.24 27.84 - 1035.60 10078.00 93.40 346.20 6854.70 8794.70 -898.60 1985.59 5958550.46 679435.11 0.00 -1001.28 BP Amogo WELLPA TH DETAILS ~5-12A 500292068501 Paint Wellpa~: 1E. t2APB1 Tie on MD: 9~45.50 VeStal Secl~on Origin: Slot. 12 (0.00,0.00) Vertical Secilen Angle: 357.00* Rig: Nabom 3S Depih Reflmmce: 30:12 1011911981 00.~0 REFERENCE INFORMATION Co~rclnale (N~E) Relerence: Well Cenlre: 15-12, True ~ VedJcel (T~D) Relemnce: Field - Mean Sea Level Sec~n (VS) Relermce: Sk:t - 12 (0,00,0,00) Meel~ad DepU1R~*~-,c~. 20:12 10/1g/1g61 0GO0 60.0 at:x3ve Meal Sea Level ANNOTATIONS No. ~ MD AnnoMIion 1 8493.76 g~)0.00 T~e4nPoint 2 6793.20 9~15.00 Kk~-offPoint 6?94.54 10730.00 Proje~edtoTD TARGET DETAILS No. ~ +N/*S *E/-W Target t5-12AP o,3.1 88~0.00-1370.49 1839.50 1678.60 3 8800.00 -766.51 15-12AT3.2 8840.00 -188.11 1542.12 15-12AT3.30'fD BPAmo¢o LEGEND Aziltluths to True Nolth !I Wcllpalh: {15-1211:~-12A) -- 15-12,15-12A, Plen#3 ,'-~'" I~dasnctic North: 26.96°1 ¢'rra.d By: Brij POIIiS I)IK: 9/1~2000 BAKER / '~"'"~";' ' HUGI4ES1 '~-'~* j/ S~rcngth: 574#1nT1 /'~f',, Dip Angle: 80.79°1 ~ Date: 9/8/20001 INTEQ [ '+: ,~o~,,: ~,,ooo! :/ : -- / -1500- / ' p Tia-i~ Phil d 0 500 1000 1500 2000 2500 30( We~t(-)/East(+) [S00ft/in] ~ ~.,.._ .-"/J! Ki~rJ[.affl Pcinl ~ .. .jl~?'hi'~-I ~,4 16 TB I '" --~ ~ I 15-12 ~ 1 c.-'121 - -1800 -1600 -1400 -1200 -1000 -800 -800 -400 -200 0 Vertical Section at 357.00* [20Oft/in] Plot 1/22/2001 11:15 AM ObP BP Amoco Baker Hughes INTEQ Survey Report INTEQ Field: Prta:llx~ Bay Site: PB DS 15 We~: 15-12 Wmpath: 15-1ZA D~ie: 1/22/2001 ~ 11:14:36 P~e: Co-ordinate(NE) Reference: Well: 15-12, True North YL,,r~k~ (TYI)) Re~eremce: 20: 12 10/19/1081 00.'00 60.0 Section (rs) ltt4nuce: Wall (0.00E,0.00N,35'/.00Azf) SurveyCaicuhtJon-Metbod: Mirdmum Gurvattre Db:. Oracle FieM: Prudh(~ Bay North Slope UNITED STATES Map System:US Slate Plane Cxx)rdinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft Latitude: 70 17 35.236 N 676296.98 ff Longitude: 148 34 21.213 W North Reference: True Grid Convergence: 1 Well: 15-12 Slot Name: 12 15-12 Well Position: +NI-S 537.85 ft Northing: 5959401.88 ft Latitude: 70 17 40.525 N +E/-W 1145.01 ff Easttng: 677428.99 ff Longitude: 148 33 47.842 W Position Uncertainty: 0.00 ft Wellpath: 15-12A Drilled From: 15-12APB1 500292066501 Tie-on mpth: 9645.00 ft Current Datum: 20: 12 10/19/1981 00:00 Height 60.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/8~2000 Declination: 26.96 dug Field Strength: 57481 nT Mag DIp Angle: 80.79 deg Vertical Section: Depth From (TVD) +NI-S +E/-W Direction fl ff fl dug 0.00 0,00 0,00 357.00 Survey: MWD Start Date: 7/29/2000 Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation 9645.00 0053,20 KiCk,off pOint ~ I 10730.00 8854.54 Projected to TD Survey Iad ~ TY]) SSTYD N/S E/W MapN MapE DLS VS ft deg ft ft ft ~100ft ft 9645.00 91.50 24.60 8853.20 8793.20 -1291,24 1853.15 5958154.83 679311.99 0.00 -1386.45 9678,00 88,30 23.10 8853,26 8793.26 -1261,06 1866.49 5958185.31 679324.61 10,71 -1357.02 9707.00 88.90 14.40 8853.97 8793.97 -1233.63 1875.80 5958212.95 679333.27 30.06 -1330,11 9740.00 92.10 5.20 8853.68 8793.68 -1201.16 1881.41 5958245.55 679338.11 29.51 -1297.98 9785.00 93.60 356.10 8851.44 8791.44 -1156.26 1881.93 5958290.44 679337.56 20.47 -1253.17 9819,00 92.70 352.30 8849.57 8789.57 -1122.49 1878.50 5958324.11 679333.34 11.47 -1219.27 9848.00 91,80 349.70 8848.43 8788.43 -1093.88 1873.96 5958352.61 679328.13 9.48 -1190.45 9889.00 91.60 347.00 8847.22 8787.22 -1053.74 1865.69 5958392.54 679318.91 6.60 -1149.94 9923.00 90.90 344.40 8846.47 8786.47 -1020.81 1857.29 5958425.26 679309.74 7.92 -1116.61 9948.00 86.50 342.90 8847.04 8787.04 -996.83 1850.26 5958449.07 679302.14 18.59 -1092.30 9980.00 86.00 340.50 8849.13 8789.13 -966.52 1840.23 5958479.13 679291.41 7.65 -1061.50 10012.00 87.70 338.00 8850.89 8790.89 -936.64 1828.91 5958508.73 679279.39 9.44 -1031.08 10047.00 90.20 329.50 6851.54 8791.54 -905.29 1813.45 5958539.71 679263.19 25.31 -998.96 10082.00 90.90 327.10 6851.20 8791.20 -875.51 1795.06 5958569.04 679244.10 7.14 -968.26 10155.00 91.90 321.50 8849.42 8789.42 -816.27 1752.49 5958627.25 679200.15 7.79 -906.87 10181.00 92.30 318.30 8848.46 8788.46 -796.40 1735.76 5958646.72 679182.95 12.40 -886.15 10211.00 90.70 321.20 8847.68 8787.68 -773.51 1716.39 5958669.15 6791 63.05 11.04 -862.28 10247.00 88.30 325.00 8847.99 8787.99 -744.73 1694.78 5958697.41 679140.77 12.48 -832.41 ObP BP Amoco Baker Hughes INTEQ Survey Report INTEQ Cempa=y: BP Amoco Fiekl: Prudlx)e Bay ~ PB DS 15 We.: 15-12 Wellmm: 15-12A Date: 1/22/2001 Time: 11:14:36 Pak~ C.e-ordiaa~ P~,~m~e: Well: 15-12, True Norlh Yertteal (TVD) ib~eremee: 20: 12 10/19/1961 00:00 60.0 Se~'am,, (rs) ~ We~ (0.00E,0.00N,35~.00Az~) Survey MD [md ~ TVI) ~TVD N/S E/W MapN MapE DLS VS 10289.00 91.80 330.30 8847.95 8787.95 -709.27 1672.32 5958732.33 679117.47 15.12 -795.82 10328.00 92.60 334.70 8846.46 8786.46 -674.71 1654.32 5958766.45 679098.67 11.46 -760.37 10361.00 88.80 338.60 8846.05 8786.05 -644.43 1641.25 5958796.41 679064.89 16.50 -729.44 10390.00 88.00 342.60 8846.86 8786.86 -617.09 1631.62 5958823.51 679074.62 14.06 -701.64 10420.00 87.40 347.20 8848.07 8788.07 -588.16 1623.82 5958852.25 679066.13 15.45 -672.34 10454.00 88.30 350.70 8849.34 8789.34 -554.82 1617.31 5958885.43 679058.64 10.62 -638.70 10480.00 89.30 354.00 8849.89 8789.89 -529.06 1613.85 5958911.10 679054.77 13.26 -612.80 10509.00 91.20 355.60 8849.76 8789.76 -500.18 1611.22 5958939.90 679051.46 8.57 -583.82 10540.00 91.60 357.50 8849.00 8789.00 -469.25 1609.35 5958970.78 679048.87 6.26 -552.83 10570.00 90.30 351.40 8848.51 8788.51 -439.41 1606.45 5959000.54 679045.27 20.79 -522.88 10600.00 91.00 348.00 8848.17 8788.17 -409.90 1601.09 5959029.92 679039.21 11.57 -493.13 10651.00 87.20 347.00 8848.97 8788.97 -360.12 1590.06 5959079.41 679027.00 7.70 -442.85 10678.00 85.70 346.10 8850.64 8790.64 -333.91 1583.79 5959105.47 679020.12 6.48 -416.34 10730.00 85.70 346.10 8854.54 8794.54 -283.58 1571.33 5959155.49 679006.48 0.00 -365.43 BP Amoco , WELLPA TH DETAILS 15.12A 500292066501 Panini We#path: 15.12APBf Tie on MD: 9645.00 Vertical Section Origtn: Slot - 12 (0o00,0.00) Veltical Section Angle: 357.00° R~: Nabom 3S Depth Reference: 20:12 1011911981 00:00 [NTEQ / REFERENCE INFORMATIC~N Coo'dk~le (N~) Rderence: Well Cenb'e: 15-12, ~e ~ V~ ~) ~: F~ - M~ ~ ~ ~ ~) Rd~: ~ - 12 (0.~,0~) M~~ ~; 12 1W1Wl~1~ ~.0~e~ ~ ~a ~ M~: ~ ~e ANNOTATIONS No. TVD IVD Annotalion 0493.76 9000.00 Tie-inPoint 2 6793.20 9645.00 Kick.offPoint 8794.54 10730.00 Projec~dtoTD BPAmoco LEGEND 15.12,15.12.A,l:lk;rl ~ 15-12 (15-t2) 15-12 ( 15.-12/~°B1 ) 15-12~ -150~ i · . ] ' ' i ' i : ' ' I I ~ I I ! ' 0 500 1000 1500 2000 2500 300 We~t(-)/East(+) [S00fUin] ' [ R'i~ATRd i,rl.i,'~lt.r~t,}iPl.tl ItRtgATR':I '-----i I: I ' I -1800 -1600 -1400 -1200 -1000 -800 -600 400 -200 Vertical Section at 357.00° [20Oft/in] Plot 1/22/2001 11:15 AM ALASILA OIL AND GAS CONSERVATION CO~[ISSION TONY ffNOWLE$, G~VERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Lamar L. Gantt AAI Coil Tubing Drilling Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99501-0360 Re~ Prudhoe Bay Unit 15-12A ARCO Alaska, Inc. Permit No: 200-061 Sur Loc: 2113'FNL, 3803'FEL, Sec. 22, T1 IN, R14E, UM Btmhole Loc. 2304'FNL, 2308'FEL, Sec. 22, T1 IN, R14E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. 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. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this '5 73 ~' J day of May, 2000 dlf/Enclosures cci Department of Fish & Game. Habitat Section w/o encl. Department of Enviromnental Conservation w/o encl. ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drar-I Redtilr~l I lb. Type of well. Exploratory r"! stratigraphicTestr=l Re-entry D Deepen r~ I Service D Development Gas D Single Zone [~] 2. Name of Operator 5. Datum elevation (DF or KB) RECEIVED APR 20 aaka Oa & Gas Cons. Commi.lml Developmehr~l~l~ Multiple Zone D 10. Field and Pool ARCO Alaska, Inc. RKB 60 feet 3. Address 6. Property Designation Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28306 Prudhoe Bay Oil Pool 4. Location of well at surface 2113' FNL, 3803' FEL, Sec. 22, T11N, R14E, UM At top of productive interval 3655' FNL, 2200' FEL, SEC. 221T11N, R14E, UM At total depth 2304' FNL, 2308' FEL, Sec 22, T11N, R14E, UM 12. Distance to nearest properly line ADL 28307, 2308' OTD feet I 13. Distance to nearest well No Close Approach 16. To be completed for deviated wells Kickoff depth: 9150' MD Maximum hole angle 90° FL4S feet 7. Unit or property Name Prudhoe Bay Unit 8. Well number 15-12A 9. Approximate spud date June 1,2000 14. Number of acres in property 2560 11. Type Bond (see 20 AAC 25.0251) Statewide Number #U-630610 Amount $200,000 18. Casing program size Hole 4-1/8" 2-7/8" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary 15. Proposed depth (MD and TVD) 10965 MD / 8898 TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2450 p~9 N total depth (3'VD) Settin Bottom TVD 8898' 3300 psig ~ 8800' Quantity of Cement (include sta~le data) 25 bbls15.8 ppg Cement Total Depth: measured 9430 feet tree vertical 8971 feet Plugs (measured) Tagged PBTD @ 9315' MD on 1/29/1998. Effective Depth: measured 9315 feet tree vertical 8859 feet Casing Length Size Cemented Conductor 80' 20" 300 Sx PF Surface 2422' 13-3/8" 2500 Sx Fondu & 400 Sx PFC Production 8637' 9-5/8" 250 Sx Glass C Liner 1063' 7" 300 Sx Class C Perforation depth: measured 9268' - 9292'; 9294' - 9328'. Junk (measured) Measured depth 80' 2482' 8697' 9430' tree vertical 8814' - 8837'; 8839' - 8872'. . True Vedicaldepth 80' 2482' 8257' 8967' 20. Attachments Filing lee J~i Property Plat D BOP Sketch r~J Dive.er Sketch D Drilling program r~J Drilling lluid program Time vs depth plot D Refraction analysis D ~ Seabed report D 20 AAC 25.050 requirements D 21. I hereby certify that the foregoing is true and correct to the best o! my knowledg~ SignedLam~arL Gt~J~. ~)e. ~ Title: AAICoilTubingDrillingSupervisor Questions? Call Dan Kara@ 263-4837. Date Cf~/ I'~ /~ Prepared by Paul Rauf 265-4.q90 Commission Use Only PermitNumber,~.~:~__~..,~)~:~/I APInumber ~ Appetite, J See cover letter 5m ~.-?--, ~ ~:~-- ~'~,,) Jfor other requirements Conditions of approval Samples required. D Yes~;~ No Mud log required D Yes~ No Hydrogen sulfide measu res J~es D No Directional survey required ,~ Yes D No Required working pressure for BOPE [~I2M; D 3M; D 5M; D lOM;D {~13500 psi for CTU Other. ORIGINAL SIGNE~D BY byorderof Approved by D Taylor Seamount commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 15-12A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore, ff scheduling permits, a service CTU will mill window in 7" casing. Directionally drill a horizontal well from the existing wellbore. Run and cement 2-7/8" liner. Perforate and produce. Intended Procedure: Service CTU · Set whipstock top at --9150' md. Cement squeeze and plugback the existing completion to -- 9140' md. · RU CTD unit and test BOPE. Mill window in 7" casing at -9150' md. CT Drilling Rig · Drill 10' of formation with 8.5 ppg Flopro fluid and perform Leak off test to 9.0 ppg. Directionally drill 4.125" x 1500' horizontal well to produce from Zone lB. Build angle to -90° and then drop to 84° at TD. Total openhole --1816'. · Run and cement 2-7/8" liner to TD. Test liner top to 2000 psi. · Perforate selected intervals. · Place well on production. NOTE: Drill cuttings will be disposed of at GNI and drilling mud will be disposed at GNI or Pad3. RECEIVED APR 20 2000 Alaska Oil & Gas Cons. Commission April 19, 2000 DS 15-12A Potential Drilling Hazards POST ON RIG H2S production is not anticipated from this well. Continue to ensure all H2S monitoring equipment is operational. BHP: 3300 psi @ 8800' ss (7.2 ppg EMW), BHT 200 °F (estimated pressure). No over-pressured zones are anticipated. Maximum anticipated WHP w/full column of gas: 2450 psi. High perm intervals are expected across the Sadlerochit. No major faults are anticipated. The well will be drilled with 8.5 ppg mud. RECEIVED APR 20 2000 Alaska Oil & Gas Cons. Commission Anchorage April 19, 2000 15-' 2A Propose l CT Sidetrack Horizontal 5-1/2" Tubing 5-1/2" Otis RQM Nipple@ 2186' 5-1/2" AVA POGLM @ 3204' Packer @ 8342' 7" Liner Top 8367' 4-1/2" XN Npl @ 8383' TOC in 7" 8950' Whipstock set and cemented in place with top @ ~9150' of 2-7/8" @ - 8400' Liner in 4-1/2" Tbg Tail @ 8300' 9-5/8" Casing shoe @ 8697' Initial Perfs Window cut in 7" at ! -9150 - 9155' / 4-1/8" Open hole Current perforations cement squeezed 2-7/8" liner TD @ - 1O965' 7"Casing Shoe @ 943O' RECEIVED APR 20 ?.000 ~aska 0il & Gas Cor~s. Commission Ar~orage 8100- 8200 _ 83004 8400 ~ Position r-~ 8500 · ~ 8600 '~~ t ~~k °ff P°int 8700 ~ ~L23 4 5 I--- 8800 15-12 #1 8900 9000 ARCO Alaska, Inc. Structure : D.S. 15 Slot : 15-12 Field : Prudhoe Bey Locofion : North Slope, Alaska Creoted ~y potn;e Dote plotted: 1B-Apr-2000 I Plot Reference ~ Ib-12A verlliOn ~1. Coordln~tel ore in feet reference 15-12. True Vert;col Depths ore ¢lference RKB - MSL - 57.74~'T. --- aak~ Huehll I~EO --- Eosf (feet) -> 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 2 I002250 2400 I ~ t I I I I I I I I I t I I I I I I I I I I I I I I T.D. -12 #3 Kick off Point 67 15-12 #2 ------------. T.D. 15-12 #3 15o 300 450 6OO 0 750 1700 1 BOO 1900 2000 i i i , i , ~ ~ i i i i i i , i , i t i i i , , I , i , i , i i I i i i , 200 1 O0 0 1 O0 200 300 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 1600 Vedicol Section (feet) -> Azimuth 354.00 with reference 1578.58 S, 1638.01 E from 15-12 900 1050 I 1200 35O 1500 650 1800 RECEIVED APR 20 2000 Alaska Oil & Gas Cons. Commission Anchorage INTEQ Cmnpany: Well: Calculation Method: Vertical Sect. Plane: Vertical Sect. Plane: Measured Depth from: True Vertical Depth: ARCO Alaska, Inc. 15-12A Minimum Curvature 354.000 TRUE 352.900 GRID RKB Sea level Proposal Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN Rig: Nabors 3s Field: Mag. Declination: Grid Correction: 1.100 Total Correction: Dip: RKB Height: 57.70 Prudhoe Bay, Alaska Coords. - ASP Coords. - GRID N(+)/S(-) E(+)/W(-) E(+)/W(-) Lat, (Y) -1578.58 5957862.10 679103.40 -1539.70 1674.40 -1583.51 5957857.24 679107.48 ,1544.56 1678.48 -1588.42 5957852.42 679111.53 -1549.38 1682.53 -1593.29 5957847.62 679115.54 -1554.18 1686.54 -1598.14 5957842.85 679119.52 -1558.95 1690.52 -1602.96 1657.61 5957838.11 679123.46 -1563.69 1694.46 -1607.75 1661.42 5957833.39 679127.37 -1568.41 1698.37 -1611.34 1666.65 5957829.89 679132.66 -1571.91 1703.66 -1612.54 1674.65 5957828.85 679140.68 -1572.95 1711.68 -1611.31 1685.24 5957830.28 679151.25 -1571.52 1722.25 -1610.90 1687.11 5957830.73 679153.11 -1571.07 1724.11 -1609.50 1693.19: 5957832.25 679159.16 :-1569.55 1730.16 -1608.28 1698.48 5957833.57 679164.42 -1568.23 1735.42 -1604.56 1714.58 5957837.59 679180.45i -1564.21 1751.45 -1600.26 1733.20 5957842.25 '679198.99 -1559.55 1769.99 -1595.47 1753.93 5957847.43 679219.62 -1554.37 1790.62 -1592.27 1767.80 5957850.90 679233.43 ~1550.90 1804.43 -1590.31 1776.32 5957853.03 679241.91 -1548.77 1812.91 -1584.87 1799.87 5957858.92 679265.35 -1542.88 1836.35 -1584.66 1800.79 5957859,15 679266.27 -1542.65 1837.27 -1578.27 1823.77 5957865.98 679289.12 -1535.82 1860.12 -1573.97 1835.99 5957870.51 679301.26 -1531.29 1872.26 -1569.32 1847.09 5957875.37 679312.27 -1526.43 1883.27 -1557.18 1868.92 5957887.92 679333.86 1904.86 -1541.95 1888.72 5957903.54 679353.36 -1498.26 1924.36 -1523.95 1906.03 5957921.87 679370.32 1941.32 -1503.58 1920.49 5957942.51 679384.38 1955.38 -1481.29 1931.76 5957965.01 679395.23 1966.23 -1457.58 1939.61 5957988.87 679402.62 1973.62 -1432.97 1943.86 5958013.56 679406.40 -1388.24 1977.40 -1408.00 1944.41 5958038.54 679406,47 1977.47 -1383.22 1941.26 5958063.25 679402.84 1973.84 -1370.00 1938.00 5958076.40 679399.33 1970.33 -1359.05 1934.90 5958087.29 679396.02 1967.02 -1334.87 1928.54 5958111.34 679389.20 -1290.46 1960.20 -1310.54 1922.82 5958135.56 679383.01 1954.01 -1286.06 1917.74 5958159.94 679377.46 -1241.86 1948.46 -1261.46 1913.30 5958184.45 679372.55 1943.55 Job No: AFE No: AP1 No: BHI Rep: Job Start Date: Job End Date: 0.00 0.32 0.32 0.32 0.36 0.32 0.36 -126.28 -80.12 -46.24 -34.36 0.~ 0.~ 0.~ 0.~ 0.~ 0.~ -20.92 -20.60 -34.05 -34.12 -34.08 -34.12 -34.08 -34.08 -34.12 -34.08 -34.08 -34.12 -34.07 5.98 6.~ 6.~ 6.~ Comments Tie in Position Kick off Point 1 2 3 4 Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Vertical Tool Face Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Commen~' (de~) (de~) (de~) (~) LaL (Y) Dep. (X) Lat (Y) Dep. (X) I.~ (Y) Dep. (X) (°/100ft) (°/100fl) (°/100ft) 9781.26 90.00 350.90 349.80 8800.01 -1255.28 1912.29 5958190.61 679371.42 -1211.19 1942.42 6.00 292.86 -90.00 0.00 6.07 5 9800.00 90.00 349.78 348.68 8800.01 -1236.80 1909.14 5958209.02 679367.92 -1192.78 1938.92 6.00 311.56 -90.00 0.00 -5.98 9825.00 90.00 348.28 347.18 8800.01 ~1212.26 1904.39 5958233.46 679362.69 -1168.34 1933.69 6.00 336.47 -90.00 0.00 -6.00 9850.00 90.00 346.78 345.68 8800.01 -1187.85 1898.99 5958257.77 679356.83 -1144.03 1927.83 6.00 361.31 -90.00 0.00 ~6.0~ 9875.00 90.00 345.28 344.18 8800.01 -1163.59 1892.95 5958281.91 679350.33 -1119.89 1921.33 6.00 386.07 -90.00 0.00 -6.0~ 9900.00 90.001 343.78 342.68 8800.01 -1139.50 1886.28 5958305.87i 679_343.20 -1095.93 1914.20 6.00 410.73 -90.00 0.00 -6.0(] 9925.00 90.001 342.28 341.18 8800.01 -1115.59 1878.99 5958329.631 679335.45 -1072.17 1906.45 6.00 435.27 -90.00 0.00 -6.0~ 9950.00 90.00 340.78 339.68 8800.01 -1091.88 1871.07 5958353.19 679327.07 -1048.61 1898.07 6.00 459.68 -90.00 0.00 -6.0~ 9975.00 90.001 339.28 338.18 8800.01 -1068.38 1862.53 5958376.52 679318.08 -1025.28 1889.08 6.00 483.94 -90.00 0.00 -6.0~ 10000.00 90.00 337.79 336.69 8800.01 -1045.12 1853.38 5958399.60 679308.49 -1002.20 1879.49 6.00 508.03 -90.00 0.00 -5.96 10025.00 90.00 336.29 335.19 8800.01 -1022.10 1843.63 5958422.43 679298.30 -979.37 1869.30 6.00 531.94 -90.00 0.00 -6.0(] 10050.00 90.001 334.79 333.69 8800.01 -999.34 1833.28 5958444.98 679287.51 -956.82 1858.51 6.00 555.66 -90.00 0.00 -6.00 10075.00 90.00 333.29 332.19 8800.01 -976.86 1822.34 5958467.24 679276.14 -934.56 1847.14 6.00 579.15 -90.00 0.00 -6.00 10100.00 90.00 331.79 330.69 8800.01 -954.68 1810.81 5958489.20 679264.19 -912.60 1835.19 6.00 602.42 -90.00 0.00 -6.0~ 10125.00 90.00 330.29 329.19 8800.01 -932.81 1798.70 5958510.84 679251.67 -890.96 1822.67 6.00 625.44 -90.00 0.00 -6.0~ 10150.00 90.00i 328.79 327.69 8800.01 -911.26 1786.03 5958532.14 679238.58 -869.66 1809.58 6.00 648.20 -90.00 0.00 -6.00 10175.00 90.001 327.29 326.19 8800.01 -890.05 1772.80 5958553.091 679224.94 -848.71 1795.94 6.00 670.67 -90.00 0.00 -6.0(] 10200.00 90.00 325.80 324.70 8800.01 -869.19 1759.02 5958573.68 679210.76 ~828.12 1781.76 6.00: 692.86 -90.00 0.00 -5.96 10225.00 90.00 324.30 323.20 8800.01 -848.70 1744.69 5958593.89 679196.05 -807.91 1767.05 6.00 714.73 -90.00 0.00 -6.0~ 10250.00 90.00 322.80 321.70 8800.01 -828.59 1729.84 5958613.71 679180.82 -788.09 1751.82 6.00 736.28 -90.00 0.00 -6.0~ 10275.00 90.00 321.30 320.20 8800.01 -808.88 1714.47 5958633.13 679165.07 -768.67 1736.07 6.00 757.49 -90.00 0.00 -6.00 10300.00 90.00 319.80 318.70 8800.01 -789.57 1698.58 5958652.12 679148.82 ,-749.68 1719.82 6.00' 778.35 -90.00 0.00 -6.0(] 10325.00 90.00 318.30 317.20 8800.01 -770.69 1682.20 5958670.69 679132.07 -731.11 1703.07 6.00 798.84 -90.00 0.00 -6.00 10331.30 90.00 317.92 316.82 8800.01 -766.00 1677.99 5958675.29 679127.78 -726.51 1698.78 6.00i 803.95 -117.00 0.00 -6.03 6 10350.00 89.31 316.60 315.50 8800.12 -752.27 1665.30 5958688.78 679114.82 -713.02 1685.82 8.00! 818.93 -117.00 -3.69 -7.06 10358.41 89.00 316.00 314.90 8800.24 -746.19 1659.49 5958694.75 679108,90 -707.05 1679.90 8.00 825.58 96.00 -3.69 -7.13 7 10375.00 88.83 317.48 316.38 8800.56 -734.11 1648.12 5958706.61 679097.30 -695.19 1668.30 9.00 838.79 96.00 -!.02 8.92 10400.00 88.57 319.72 '318.62 8801.12 -715.36 1631.60 5958725.03 679080.42 -676.77 1651.42 9.00 859.16 96.00 -!.04 8.96 10425.00 88.32 321.96 320.86 8801.80 -695.99 1615.82 5958744.10 679064.27 -657.70 1635.27 9.00 880.08 96.00 -1.00 8.96 10450.00 88.07 324.20 323.10 8802.59 -676.01 1600.81 5958763.79 679048.88 -638.01 1619.88 9.001 901.51 96.00 -i.00 8.96 10475.00 87.82 326.43 325.33 8803.49 -655.47 1586.59 5958784.05 6790.34.27 -617.75 1605.27 9.00i 923.43 96.00 -l.00 8.92 10500.00 87.58 328.67 327.57 8804.49 -634.39 1573.19 5958804.87 679020.46 -596.93 1591.46 9.00 945.79 96.00 -0.96 8.96 10525.00 87.34 330.91 329.81 8805.60 -612.81 1560.62 5958826.21 679007.49 -575.59 1578.49 9.00i 968.57 96.00 -0.96 8.96 10550.00 87.101 333.15 332.05 8806.81 -590.76 1548.91 5958848.03 678995.35 -553.77 1566.35 9.00 991.73 95.00 -0.96 8.96 10575.00 86.871 335.39 334.29 8808.13 -568.27 1538.07 5958870.31 678984.09 -531.49 1555.09 9.00 1015.23 95.00 -0.92 8.96 10600.00 86.641 337.64 336.54 8809.54 -545.38 1528.13 5958893.00 678973.70 -508.80 1544.70 9.00 1039.03 95.00 -0.92 9.00 10625.00 86.42 339.88 338.78 8811.05 -522.12 1519.09 5958916.08 678964.22 -485,72 1535.22 9.00! 1063.11 95.00 -0.88 8.96 10650.00 86.20 342.12 341.02 8812.66 -498.53 1510.97 5958939.51 678955.65 -462.29 1526.65 9.00i 1087.41 95.00 -0.88 8.96 10675.00 85.99 344.37 343.27 8814.37 -474.65 1503.78 5958963.25 678948.00 -438.55 1519.00 9.00 1111.92 95.00 -0.84 9.00 85.78 346.62 345.52 8816.16 -450.51 1497.53 5958987.26 678941.29 -414.54 1512.29 9.00 1136.58 95.00 -0.84 9.00 10700.00 85.59 10725.00 348.87 347.77 8818.04 -426.15 1492.24 5959011.52 678935.53 -390.28 1506.53 9.00 1161.35 94.00 -0.76 9.00 10750.00 85.39 351.11 350.01 8820.01 -401.61 1487.91 5959035.97 678930.73 -365.83 1501.73 9.00 1186.21 94.00 -0.80 8.96 10775.00 85.211 353.36 352.26 8822.06 -376.93 1484.54 5959060.59 678926.89 -341.21 1497.89 9.00 1211.12 94.00 -0.72 9.0~I 10800.00 85.03 355.62 354.52 8824.18 -352.13 1482.15 5959085.33 678924.02 -316.47 1495.02 9.00 1236.02 94.00 -0.72 9.04 10825.00 84.861 357.87 356.77 8826.39 -327.27 1480.74 5959110.16i 678922.13 -291.64 1493.13 9.00 1260.90 94.00 -0.68 9.00 10850.00 84.70 0.12 -0.98 8828.66 -302.38 1480.30 5959135.04i 678921.22 -266.76 1492.22 9.00 1285.70 94.00 -0.64 9.00 10875.00 84.55 2.38 1.28 8831.00 -277.50 1480.84 5959159.921 678921.28 -241.88 1492.28 9.00 1310.39 93.00 -0.60 9.04 10900.00 84.40 4.63 3.53 8833.41 -252.66 1482.36 5959184.78~ 678922.33 -217.02 1493.33 9.00 1334.93 93.00 -0.60 9.00 10925.00 84.27 6.89 5.79 8835.88 -227.91 1484.86 5959209.58 678924.35 -192.22 1495.35 9.00 1359.28 93.00 -0.52 9.04 10950.00 84.14 9.15 8.05 8838.40 -203.29 1488.33 5959234.27~ 678927.35 -167.53 1498.35 9.00 1383.41 93.00 -0.52 9.04 10965.59 84.06 10.56 9.46 8840.01 -188.01 1490.98 5959249.59 678929~71 -152.21 1500.71 9.00 1398.33 0.00 -0.51 9.04 T.D. C T Drilling BOPE Methanol Injection Otis 7" WLA Quick Connect .... ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ,1~ I '"- 7" Riser I I I I Annular BOP (Hydril),7-1/ ~ ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams 2" Pump-In :~Tubing Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Inner Annulus Outer Annulus RECEIVED APR 20 000 Ataska Oi~ & Gas Cons. Commission Anchorage WSSSV- Tu~ng-PC Ca~ng Ca~ng POGLM Gas Lift MandrelNalve I PBR PKR XO Tubing-PC NOGO Liner SOSUB 'rrL Peri ...... SQZ . Perf ...... SQZ FISH RECEIVED APR 20 2000 ~ska 0ii & Gas Cons. Comm~saon Anchorage 15-12 15-12 APl: 1500292066500 H2S:I SSSV Type:I Annular Fluid: I Diesel/9.4 NaCI Reference Log: I BHCS I Last Tag:J Re~ Reason: J APERF Elevations Well Type: I PROD Spud: J 10119/81 Orig Cornpltn: 11115/81 Last WIO:111/5/81 Ref Log Date:111/2/81 Last Tag Date:I Last Update: 14116/98 RKB: J 60 ft KOP: J 0.00 ttKB PBTD: j 9430.00 ffKB 'rD: 19430.0o lES Max Hole Angle:127 deg ~ 3700 I 'Aag~e ~ TS:115 deg. ~ 6800 Angle ~ TD:114 ~ {~ 9378 KB 60 f Off Grd 0fl 0 ff KB-Grd 60 fl ~=.) - All Ty~e WSSSV POGLM Cas Flng Tub Head PBR Description Other (Dlugs~ equip., e' DepthjlD ] J 218614'562 1320412.340 J 8322J 0.000 / I 8342J0.000 J 83841o.ooo I / 8383/3.725 I s~s/o-ooo / 844610.000 General Notes 5-1/2" Otis ROM SSSV Nipple 5-1/2" AVA DWP POGLM (Set 10/81/95) Hole in Tubing 3211-3213' 5-1/2"BOTPBRAssemb~ PKR 9-5/8" x 5-1/2" BOT Packer XO Crossover 5-1/2" x 4-1/2" NOGO SOSUB TTL 4-1/2" Otis XN Nipple 4-1/2" BOT Shearout Sub 4-1/2" Tubing Tail Date Note AVA POGLM (Set 10/31195) FRAC ZN1 08/30/92,ZN1 09/05/92 3204 Min ID = 2.340" (5-1/2" AVA DWP POGLM (Set 10/31/95)) TTL ELM ~ 8435: ELM Tubing Tail (Logged 12/22/81 ) Daterun: 1981-11-05 Fish- FISH Depth Description FISH: Comment j 9373 FISH 2-1/2" Packer Rubbers (Left 08/25/95) Casing String -SURFACE Item TOPo J Btm I ~ (in) (ftKB).00 (ftKB) J 13.375 in Casing 2482.00 J 72.00 Casing ~String- PRODUCTION Item Top Btm (in) (ftKB[.00 (ftKB) 9.625 in Casing 8697.00 Grd L-80 47.00 L-80 Casing "String .: LINER Item ] Top I Btm I WtI Grd (in) (ftKB) (ftKB) 7.000 in Liner 8367.00 9430.00 29.00 L-80 TUbing'String "TUBING ' Item (in) 5.500 in Tubing-PC 4.500 in Tubing-PC GaS. Lift Mandrels/Valves · MD Man Mfr Man Type 3204 AVA-DWP PerforatiOns Summary Interval : 9216 - 9220 9248 - 9264 i9268-9286 ;9286-9288 9288-9292 9294-9297 Zone ~.ONE 2 ZONE 2,ZONE lB ZONE lB ZONE lB ZONE lB ZONE lB 9297 - 9300 ZONE lB 9300 - 9305 ZONE lB 9305 - 9306 ZONE lB 9306 - 9328 ZONE lB stimulationS & Treatments Top J Bottom (ftKa)0.001 (ftKB) 8354.00 8354.00~ 8446.00 vi~ Mfr Vlv Type HES ODM-14R 83 17.00 L-80 12.60...I L-80 J Latch J Vlv t VIv TRO'I Vlv Run Port I BK 0.375 9999.0 J 11/1/97 'StatU~' FeetI SPFI Date I Type jC J 4J 0J 11/1/97 JSqz , J 161 0111/1'97 I O J 18J 4J 10/7188 J RPERF O J 2J 8 2/8/98 J APERF O J 4J 4J2/8/98 JAPERF O ~ 3J 4J 10/7/88 J RPERF O ! 3J 8J2/8/98 JAPERF O J 5J 4J2/8/98 JAPERF 0 ! 1t 8/ 2/8/98 /APERF O J 22/ 4J 10/7/88 J RPERF Comment Interval 9216-9322 I Date J Type I Comment 6/7188 9216-9264 reque~' ~ 1. Type of STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2113' FNL, 3803' FEL, Sec. 22, T11 N, R14E, UM At top of productive interval 3655' FNL, 2200' FEL, SEC. 22, T11N, R14E, UM At effective depth At total depth 3765' FNL, 2113' FEL, Sec. 22, T11N, R14E, UM 5. Type of Well: Development __X Exploratory _ Stratigraphic __ (asp's 677429, 5959402) (asp's 679073, 5957901) (asp's 679161, 5957790) 6. Datum elevation (DF or KB feet) RKB 60 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-12 9. Permit number / approval number 181-146 10. APl number 50-029-20665 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2422' Production 8637' Liner 1063' Size 20' 13-3/8" 9-5/8" 7" 943O 8971 9315 8859 feet Plugs (measured) feet feet Junk (measured) feet Cemented 300 Sx PF 2500 Sx Fondu & 400 Sx PFC 250 Sx Glass C 300 Sx Class C Tagged PBTD @ 9315' MD on 1/29/1998. Measured Depth True vertical Depth 80' 80' 2482' 2482' 8697' 8257' 9430' 8967' Perforation depth: measured 9268' - 9292'; 9294' - 9328'. true vertical 8814' - 8837'; 8839' - 8872'. Tubing (size, grade, and measured depth 5-1/2", 17#, L-80 PCT @ 8354' MD; 4-1/2", 12.6#, L-80 PCT @ 8446' MD. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" BOT PACKER @ 8342' MD. 5-1/2" OTIS RQM SSSV @ 2186' MD. APR 20 2000 Oil & 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation May 7, 2000 16. If propOsal was verbally approved Name of approver Date approved Oil __X Gas u Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedLamar~~tJ~ ~, ~L. Gantt Title: AAI Coil Tubing Drilling Supervisor FOR COMMISSION USE ONLY Questions? Call Dan Kara @ 263-4837. Prepared b~ Paul Rauf 263-4990 Conditions of approval: Notify Commission so representative may witness Plug integdfy _ BOP Test _ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Commissioner -- Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. PRUDHOE BAY UNIT DISBURSEMENT P.O. BOX 102776 ANCHORAGE, AK 99510-2776 JNT PAGE I OF 1 FEBRUARY 18, 2000 TRACE NUMBER: 225127216 CHECK NUMBER: 225127216 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION CO~I 3OO1 PORCUPINE DRIVE ANCHORAGE AK 99501 AMOUNT PAID: $100.00 PAY ENTITY: 0201 VENDOR NO: N00072020221 INQUIRIES:(907) 263-4422/4988 (FAX) P.O. BOX 103240 ANCHORAGE, AK 99510-3240 INVOICE DATE INVOICE NUMBER VOUCHER VRO21500SUD01 GROSS AMOUNT DISCOUNT/ADJUSTMENT $1OO.OO PERMIT TO DRILL SIDE NET AMOUNT $100.00 VED 2000 Commission PLEASE ..DETACH.. BEFORE..DEPOS!T!NG. CHECK ..................................................................................................................................................... ~g.:.... .................... :,.... .... :...::?::..... ....... :....:.?:...:....~... .,..:.:...:.:~::..,: ..... ..~:..,. ....... ..?.. ..:..: . . ....., . · :2':.~' ' : ' '.': "~:...,. ...:..:.'..':/..~::2..'.:/... . ... :..... . ....: -::'.-..... , .: · :.'.(,,:'.~., · : :: ::. .,'2.,.:',. :,..~ ..... . . . WELL PERMIT CHECKLIST FIELD & POOL COMPANY ~--~/~-~---~ WELL NAME /5-' / ~ PROGRAM: exp INIT CLASS . ....~='V' ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. A~ Dp~TE 12. ENGINEERING Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... dev GEOL AREA A~.PI:{. ': DATE 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 ....... (~ N 20. Adequate tankage or reserve pit ................. (~) N 21. If a re-drill, has a 10-403 for abandonment been approved... (~ N 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... -Y---N ~ 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ (~ N 26. BOPE press rating appropriate; test to .~ ~'~ (~ psig. 27. Choke manifold complies w/APl.RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. (3~ N GEOLOt~Y 30. 32. · ,4~D' 34. (N N N v/' redrll v"' serv wellbore seg ANNU~ DISPOSAL35. ' ~. APPR ~' DATE Permit can be issued w/o hydrogen sulfide measures ..... Y~)~ Data presented on potential overpressure zones ....... Y ~ Seismic analysis of shallow gas zones ............. /~~ N Seabed condition survey (if off-shore).. .......... .~v, Y N Contact name/phone for weekly progress reports [explor, o,~ry only] Y N With proper cementing records, this plan (A) will conta~ waste in a suitable receiving zone; ....... Y N (13) will not c,~ntamina[e fre~Cwcat~; or cause drilling w_~3~'... Y N to surfa/be; / / ~- ~ (C) will no/Y'~t~grity o~.th~well used for di~.~... N (D) will n on or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N UNIT# ~)/L/ ~:~:~'"~) ON/OFF SHORE ann. disposal para req GEOLOGY: ENGINEERING: UlC/Annular COMMISSION: Comments/Instructions: O Z c:\msoffiCe\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify, finding 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 category of information. .o **** REEL HEADER **** MWD 01/11/21 BHI 01 LIS Customer Fonmat Tape **** TAPE HEADER **** MWD 01/10/31 48638 01 1.75" NaviGa~na - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: -Well Information Block #MAFEM.UNIT STRT. FT STOP FT STEP FT NULL COMP WELL FLD LOC CNTY STAT SRVC TOOL DATE API CWLS log ASCII Standard -VERSION 1.20 One line per frame Data Type Information ............. 9077.0000: Starting Depth 10730.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMPANY: BP EXPLORATION WELL: 15-12A FIELD: Prudhoe Bay Unit LOCATION: 2113' FNL, 3801' FEL COUNTY: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray LOG DATE: 27-Jul-00 API NYUMBER: 500292066501 ~Parameter Information Block #MNEM.UNIT Value Description #- SECT. 22 : Section TOWN.N liN : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 60 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 60 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 15-12A was drilled to 10714' MD (8793' SSTVD). After a depth tie-in TD was shifted to 10730' MD (8794' SSTVD). (5) The interval from 10702' MD (8792' SSTVD) to 10730' MD (8794' SSTVD) was not logged due to sensor to bit offset. (6) The data presented here is final and has been depth shifted to a PDC (7) (Primary Depth Control) supplied by BPX (SWS, 08-31-00). A Magnetic Declination correction of 26.96 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: SENSOR OFFSETS: RUN GAMMA DIRECTIONAL RUN GAMMA DIRECTIONAL 8 27.27 ft. 32.97 ft. 9 27.24 ft. 32.94 ft. CURVE SHIFT DATA BASELINE 9074 92 9082 79 9086 14 9096 63 9109 82 9114 54 9120 44 9128.02 9131.79 9141.10 9144.45 9154.29 9165 81 9178 99 9182 93 9196 11 9200 24 9204 18 9209 49 9214 73 9217 88 9228 71 9235 20 9237 76 9249 76 9252 32 9262 93 9271 98 9277 69 9296.38 9303.27 9306.02 9313.36 9318.47 9325.36 9332.64 9340 31 9345 82 9359 82 9362 18, 9374 38, 9385 00, 9391 78, 9400 64, 9406 44, 9418 35, 9431 59, 9440 08, MEASURED, 9076.89, 9089.68, 9092.63, 9097 81, 9109 42, 9113 75, 9119 85, 9128 02, 9131 39, 9140 91 9143 66 9154.09 9165.02 9178.40 9182.34 9195.72 9200.44 9204.38 9209 10 9215 32 9218 87 9228 90 9234 41 9238 54 9248 97 9252 51 9262..93 9271 19 9277 69 9296 58 9303 46 9306 81 9313 55 9318.87 9324.57 9333.23 9339.72 9346.42 9359.82 9362.18 9375.16 9384.80 9391.59 9399.26 9409.59 9421.89 9432.18, 9436.34, DISPLACEMENT 1.96777 6.88672 6.49316 1.18066 -0.393555 -0.787109 -0.589844 0 -0 393555 -0 196289 -0 787109 -0 196289 -0 787109 -0 589844 -0.589844 -0.393555 0.196289 0.196289 -0.393555 0.589844 0.983398 0.197266 -0.787109 0.787109 -0.787109 0.197266 0 -0.787109 0 0.197266 0.196289 0.787109 0.197266 0.393555 -0.787109 0.589844 -0.589844 0'.59082 0 0 0.787109 -0.197266 -0.196289 -1.37793 3.14844 3.54199 0.589844 -3.73828 9602.61, 9643.10, 9653.29, 9657.02, 9680.31, 9682.48 9793.81 9805.82 9821.95 9870.20 9882 54 9892 38 9896 77 9899 53 9913 70 9923 92, 9926 48, 9930.61, 9947.92, 9951.46, 9970.54, 9992.48, 10000.7, 10007.8, 10012.8, 10037.4, 10039.5, 10044 0, 10050 1, 10064 8, 10067 8, 10070 3 10075 4 10098 7 10117 6 10126 4 10157 2 10177 2 10181.1 10189 4 10192 1 10214 0 10227 4 10242 6 10249 5 10259 3 10267 2 10271.1 10278.2 10280.7 10300.3 10303.8 10315.8 10318.0 10327.5 10329.3 10332.2 10335.4 10341.6, 10351.4, 10421.6, 10425 6, 10546 0, 10556 6 10561 1 10599 9 10606 7 10622 2 10635 2 10638 4 10648.9 10670.7 10672.9 10678.2 EOZ END 9603.00, 9642.90, 9652.11, 9654.47, 9682.09, 9683.66, 9793.02, 9804.44, 9821.36, 9870.59 9882.94 9889.04 9896 58 9897 95 9910 94 9919 98 9925 69 9927 46 9946 34 9949 30 9971 13 9993 86 10000.7 10008.4 10012.2 10034.6 10037.9 10044.8 10049.2 10064.8, 10067.9, 10069.3, 10074.0, 10098 6, 10121 2, 10126 2, 10156 0 10175 2 10177 6 10186 8 10190 1 10213 4 10224 3 10242 4 10249 1 10256.7 10265.6 10271.5 10276 4 10278 8 10300 1 10303 8 10314 4 10317 8 10326 3 10328 7 10331 4 10334.4 10341.2 10349.0 10423.4 10426.3 10547.1 10557.3 10561.9 10600.0, 10606.3, 10621.7, 10640.3, 10643.5, 10653.6, 10667.2, 10669.9, 10679.0, 0.393555 -0.196289 -1.18066 -2.55762 1.77148 1.18066 -0.787109 -1.37793 -0.589844 0.393555 0.393555 -3.3457 -0.196289 -1.57422 -2.75488 -3.93555 -0.786133 -3.14844 -1.57422 -2.16406 0.589844 1.37695 0 0.59082 -0.589844 -2.75391 -1.57422 0.787109 -0.984375 0 0.197266 -0.984375 -1.37793 -0.196289 3.54199 -0.196289 -1.18066 -1.96777 -3.54199 -2.55859 -1.96777 -0.589844 -3.14844 -0.196289 -0.393555 -2.55859 -1.57422 0.393555 -1.77051 -1.9668 -0.196289 0 -1.37695 -0.197266 -1.18066 -0.589844 -0.787109 -0.984375 -0.393555 -2.36133 1 77148 0 787109 1 18066 0 787109 0 787109 0 196289 -0.393555 -0.59082 5.11523 5.11523 4.72266 -3.54199 -2.95215 0.787109 Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 191 records... 8 bytes 132 bytes 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP EXPLORATION WN 15-12A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 31-Aug-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX14 0.0 ROP ROPS14 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 API 4 4 2 ROP MWD 68 1 F/HR 4 4 Total Data Records: 40 Tape File Start Depth = 9077.000000 Tape File End Depth = 10730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 49 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** F~LE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP EXPLORATION WN 15-12A FN Prudhoe Bay Unit COLIN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPES 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 1 API 4 2 ROPS MWD 68 1 F/HR 4 Total Data Records: 40 Tape File Start Depth = 9077.000000 Tape File End Depth = 10730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 49 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/10/31 48638 01 Length 4 4 8 **** REEL TRAILER **** MWD 01/11/21 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile Tape Subfile DEPTH 9077.0000 9077.5000 9100.0000 9150.0000 9200.0000 9250.0000 9300.0000 9350.0000 9400.0000 9450.0000 9500.0000 9550.0000 9600.0000 9650.0000 9700.0000 9750 0000 9800 0000 9850 0000 9900 0000 9950 0000 10000 0000 10050 0000 10100 0000 10150 0000 10200 0000 10250 0000 10300 0000 10350.0000 10400.0000 10450.0000 10500.0000 10550.0000 10600.0000 10650.0000 10700.0000 10730.0000 1 is type: LIS 2 is type: LIS CR -10.9611 13 8770 31 8645 29 0871 32 0380 30 6679 32 3191 34 1036 67 8716 54 7783 52 6560 54.9281 59.5274 64.0317 58 8814 56 7496 79 1438 50 4938 101 3230 73 3925 113 6721 81 4688 67.9608 72.0309 101.5863 86.6567 94.8830 48.0398 38.2873 56.2682 54.1903 54.6083 54.0609 60.5785 86.1854 -999.2500 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = Tape Subfile 3 is type: LIS DEPTH 9077.0000 9077.5000 9100 0000 9150 0000 9200 0000 9250 0000 9300 0000 9350 0000 9400 0000 9450 0000 9500 0000 9550 0000 9600 0000 9650 0000 9700 0000 9750 0000 9800 0000 9850 0000 9900 0000 9950.0000 10000.0000 10050.0000 10100.0000 10150.0000 GRAX 14 15 34 28 32 29 32 34 66 56 52 55 59 65 60 56 81 5O 88 84 114 82 68 71 8690 1600 1580 6280 3630 3550 1620 5360 4070 4300 5780 8730 1270 7850 .3930 .7330 .0070 .5260 .0800 .5560 .8350 .3260 .5950 .9360 ROP -999.2500 -999.2500 -999.2500 23 5254 37 2612 56 9358 43 2822 65 6608 21 6817 94.4141 74.8618 91.3554 90.5976 2.6452 42.5887 90.2801 9.4617 117 5395 15 0352 57 9074 100 1661 85 7385 98 4250 87 2021 22 8683 112 6013 68 2643 137 9338 167 1370 112 4987 179.6350 115.1529 167.1629 44.9014 86.6427 -395.2797 9077.000000 10730.000000 0.500000 feet ROPS -999.2500 -999.2500 -999.2500 24.6870 38.7250 55.9760 42.9490 67.2990 21.9710 78.2190 76.3230 93 3680 90 1600 3 4290 42 4660 90 1600 87 1700 117 5230 90 0110 61 8920 104 9980 84 4560 98.4250 90.7380 10200.0000 108.0670 50.6910 10250.0000 82.8140 113.0270 10300.0000 94.8830 76.5610 10350.0000 47.2150 137.2860 10400.0000 37.9220 167.1370 10450.0000 56.7860 108.5530 10500.0000 56.6260 169.2750 10550.0000 55.0620 130.5090 10600.0000 54.3310 167.1370 10650.0000 51.8330 109.9290 10700.0000 88.5290 82.0720 10730.0000 -999.2500 -999.2500 Tape File Start Depth = 9077.000000 Tape File End Depth = 10730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS 00--- / **** REEL HEADER **** MWD 01/11/21 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/11/01 48638 01 1.75" NaviGan~na - Gamma Ray RECEIVED 2 9 2001 Alaska Oil & Gas Cons. Commission Anchorage *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame #MNEM.UNIT Data Type Information STRT.FT 9082.0000: Starting Depth STOP.FT 10078.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP EXPLORATION WELL. WELL: 15-12APB1 FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 2113' FNL, 3801' FEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: 26-Jul-00 API. API NYUMBER: 500292066570 ~Parameter Information Block #MNEM.UNIT Value Description SECT. 22 : Section TOWN.N llN : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 60 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 60 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 -Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) Ail depths are Bit Depths unless otherwise noted. (3) Ail Gamma Ray data (GRAX) presented is realtime data. (4) Well 15-12APB1 was kicked off @ 9100' MD (8591' SSTVD) from the wellbore of Well 15-12. (5) Well 15-12APB1 was drilled to 10078' MD (8795' SSTVD). (6) The interval from 10032' MD (8797' SSTVD) to 10078' MD (8795' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has been depth shifted to a PDC (Primary (8) Depth Control) supplied by BPX (SWS, 08-31-2000). A Magnetic Declination correction of 26.96 degrees has been applied to the Directional Surveys. MArEMONICS: GRAX -> Gar~ma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: SENSOR OFFSETS: RUN GAMMA DIRECTIONAL RUN GAMMA DIRECTIONAL 3 28.93 ft. 34.93 ft 4 29.00 ft. 34.00 ft 5 28.00 ft. 33.00 ft 6 7 CURVE BASELINE 9109 20 9128 00 9154 02 9359 29 9385 26 9431 56 9461 44 9907 11 EOZ END 28.00 ft. 33.00 ft. 28.00 ft. 33.00 ft. SHIFT DATA MEASURED, 9109.71 9128.52 9154.28 9359.80 9384.23 9431.82 9461.19 9888.56 DISPLACEMENT 0.515625 0.515625 0.257812 0.515625 -1.03027 0.257812 -0.257812 -18.5469 Tape Subfile: 1 81 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS FINEM VALU WDFN mwd.xtf LCC 150 CN BP EXPLORATION. WN 15-12APB1 FN COUN STAT Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 31-Aug-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ROP GR GRAXll 0.0 ROP ROPSll 0.0 FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GR MWD 2 ROP MWD Code Samples Units Size 68 1 API 4 68 1 F/HR 4 Total Data Records: 24 Tape File Start Depth = 9082.000000 Tape File End Depth = 10078.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 33 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** ~ .002 Length 4 4 8 1024 * ** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP EXPLORATION. WN 15-12APB1 FN Prudhoe Bay Unit COLIN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROPS ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 API 2 ROPS MWD 68 1 F/HR Size 4 4 Total Data Records: 24 Tape File Start Depth = 9082.000000 Tape File End Depth = 10078.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Length 4 4 8 Tape Subfile: 3 Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 01/11/01 48638 01 33 records... 54 bytes 4124 bytes **** REEL TRAILER **** MWD 01/11/21 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 9082 0000 9082 5000 9100 0000 9150 0000 9200 0000 9250 0000 9300 0000 9350.0000 9400.0000 9450.0000 9500.0000 9550.0000 9600.0000 9650.0000 9700.0000 9750.0000 9800.0000 9850.0000 9900.0000 9950.0000 10000.0000 10050.0000 10078.0000 GR -999.2500 18.8037 19.1392 28.2265 31.6548 29.0890 32.5136 34.0461 65.1604 56.4073 51.9357 58 1012 53 4932 63 1437 62 8321 56 6466 66 1942 88.7030 144.6246 124.6471 114.4273 -999.2500 -999.2500 ROP -999.2500 -999.2500 -999.2500 24 9342 35 5351 55 6844 43 6950 65 4429 31 1522 78.5465 75.4978 90.9286 86.9439 123.6760 117.8433 95.1246 85.8587 50.9830 69.1748 45.7029 43.0926 32.7613 -999.2500 Tape File Start Depth = 9082.000000 Tape File End Depth = 10078.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 9082 0000 9082 5000 9100 0000 9150 0000 9200 0000 9250 0000 9300.0000 9350.0000 9400.0000 9450.0000 9500 0000 9550 0000 9600 0000 9650 0000 9700 0000 9750 0000 9800 0000 9850 0000 9900 0000 9950 0000 10000 0000 10050 0000 10078.0000 GRAX 20 1670 14 8300 34 1580 28 6280 32 3630 29 3550 32 1620 34 5360 66 4070 56.4300 52.5780 55.8730 59.1270 69 4300 58 1740 61 4990 51 5870 90 2950 66 9850 134.2950 112.8240 113.3400 -999.2500 ROPS -999.2500 -999 2500 -999 2500 24 6870 38 7250 55 9760 42 9490 67.2990 21.9710 78.2190 76.3230 93.3680 90.1600 98.4250 44.4580 114 6700 102 7050 65 8000 35 1180 27 7930 40 1650 33 1420 25 9580 Tape File Start Depth = 9082.000000 Tape File End Depth = 10078.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS v Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 9121.0000 9121.5000 9150.0000 9200.0000 9250.0000 9300.0000 9350.0000 9400.0000 9450.0000 9500.0000 9550.0000 9600.0000 9650 0000 9700 0000 9750 0000 9800 0000 9850 0000 9900 0000 9950 0000 10000 0000 10050 0000 10078 0000 GR 34.2580 34.8875 28.2265 31.6548 29 0890 32 5136 34 0461 65 1604 56 4073 51 9357 58.1012 53.4932 63.1437 62.8321 56.6466 66 1942 88 7030 144 6246 124 6471 114 4273 -999 2500 -999 2500 ROP 147.4292 121.5211 24.9342 35.5351 55.6844 43.6950 65.4429 31.1522 78.5465 75.4978 90.9286 86.9439 123 6760 117 8433 95 1246 85 8587 50 9830 69 1748 45 7029 43 0926 32 7613 -999 2500 Tape File Start Depth = 9121.000000 Tape File End Depth = 10078.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet v Tape Subfile 3 is type: LIS DEPTH 9121 9121 9150 9200 9250 9300 9350 9400 9450 9500 9550 9600 9650 9700 9750 9800 9850 9900 9950 10000 10050 10078 GRAX .0000 34 .5000 52 .0000 28 .0000 32 .0000 29 .0000 32 .0000 34 .0000 66 .0000 56 .0000 52 .0000 55 .0000 59 .0000 69 .0000 58 .0000 61 .0000 51 0000 90. 0000 66. 0000 134. 0000 112. 0000 113. 0000 -999. ROPS 9050 120.6640 1800 94.3160 6280 24.6870 3630 38.7250 3550 55.9760 1620 42.9490 5360 67.2990 4070 21.9710 4300 78.2190 5780 76.3230 8730 93.3680 1270 90.1600 4300 98.4250 1740 44.4580 4990 114.6700 5870 102.7050 2950 65.8000 9850 35.1180 2950 27.7930 8240 40.1650 3400 33.1420 2500 25.9580 Tape File Start Depth = 9121.000000 Tape File End Depth = 10078.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS RECEIVED NOV 9 2001 Amska Oil & Gas Co~s. Commission Anchorage **** REEL HEADER **** MWD 01/11/01 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/11/01 48638 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block ~MNEM.UNIT Data Type STRT.FT 9121.0000: STOP.FT 10078.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: ~Parameter Information Block #MNEM.UNIT Value' SECT. TOWN.N RANG. PDAT. EPD .F LMF FAPD F DMF EKB F EDF F EGL F CASE F OS1 -Remarks CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value PHILLIPS Alaska, Inc. 15-12APB1 Prudhoe Bay Unit 2113' FNL, 3801' FEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 22-Jul-00 500292182901 Description 22 : Section liN : Township 14E : Range MSL : Permanent Datum 0 : Elevation Of Perm. Datum RKB : Log Measured from 60 : Feet Above Perm. Datum KB : Drilling Measured From 60 : Elevation of Kelly Bushing N/A : Elevation of Derrick Floor N/A : Elevation of Ground Level N/A : Casing Depth DIRECTIONAL : Other Services Line 1 (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 15-12APB1 was kicked off @ 9121' MD (8610' SSTVD) from the wellbore of Well 15-12. (5) Well 15-12APB1 was drilled to 10078' MD (8795' SSTVD). (6) The interval from 10050' MD (8796' SSTVD) to 10078' MD (8795' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has been depth shifted to a PDC (Primary (8) Depth Control) supplied by Phillips Alaska (SWS, 08-31-2000). A Magnetic Declination correction of 26.96 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWI)-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: SENSOR OFFSETS: RUN GAMMA DIRECTIONAL RUN GAMMA DIRECTIONAL 3 28.93 ft. 34.93 ft. 4 29.00 ft. 34.00 ft. 5 28.00 ft. 33.00 ft. 6 28.00 ft. 33.00 ft. 7 28.00 ft. 33.00 ft. 7 28.00 ft. 33.00 ft. CURVE SHIFT DATA BASELINE 9109.20 9128 00 9154 02 9359 29 9385 26 9431 56 9461 44 9907 11 EOZ END MEASURED, 9109.71, 9128.52, 9154.28, 9359.80, 9384.23, 9431.82, 9461.19, 9888.56, DISPLACEMENT 0.515625 0.515625 0.257812 0.515625 -1.03027 0.257812 -0.257812 -18.5469 Tape Subfile: 1 82 records... Minimum record length: Maximum record length: 8 bytes 132 bytes FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS FINEM VALU WDFN mwd.xtf LCC 150 CN Phillips Alaska, Inc. WN 15-12APB1 FN COUN STAT Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 31-Aug-00. *** INFORMATION TABLE: CIFO MA[EM CHAN DIMT CNAM ODEP GR GR GRAXll 0.0 ROP ROP ROPSll 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 API 2 ROP MWD 68 1 F/HR Size 4 4 Total Data Records: 23 Tape File Start Depth = 9121.000000 Tape File End Depth = 10078.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 32 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 Length 4 4 8 1024 * ** INFORMATION TABLE: CONS MNEM VALU __ WDFN mwd. xtf LCC 150 CN Phillips Alaska, Inc. WN 15-12APB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROPS ROPS ROPS 0.0 FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 API 4 4 2 ROPS MWD 68 1 F/HR 4 4 Total Data Records: 23 Tape File Start Depth = 9121.000000 Tape File End Depth = 10078.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 Minimum record length: Maxinunu record length: **** TAPE TRAILER **** MWD 01/11/01 48638 01 32 records... 54 bytes 4124 bytes **** REEL TRAILER **** MWD 01/11/01 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes T~ape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR 9121,0000 52,7323 9121,5000 86,3191 9150,0000 29,0871 9200,0000 32,0380 9250,0000 30,6679 9300,0000 32,3191 9350,0000 34,1036 9400,0000 67,8716 9450,0000 54,7783 9500,0000 52,6560 9550,0000 54,9281 9600,0000 59,5274 9650,0000 64,0317 9700,0000 58,8814 9750,0000 56,7496 9800,0000 79,1438 9850,0000 50,4938 9900,0000 101.3230 9950,0000 73,3925 10000,0000 113,6721 10050,0000 81,4688 10100,0000 67,9608 10150,0000 72,0309 10200,0000 101.5863 10250,0000 86,6567 10300,0000 94,8830 10350,0000 48.0398 10400,0000 38,2873 10450,0000 56,2682 10500,0000 54,1903 10550,0000 54,6083 10600,0000 54,0609 10650,0000 60.5785 10700,0000 86,1854 10730,0000 -999,2500 Tape File Start Depth = Tape File End Depth Tape File Level Spacing = Tape File Depth Units Tape Subfile 3 is type: LIS DEPTH GRAX 9121,0000 34,9050 9121,5000 52,1800 9150,0000 28,6280 9200,0000 32,3630 9250,0000 29,3550 9300,0000 32,1620 9350,0000 34,5360 9400,0000 66,4070 9450,0000 56,4300 9500,0000 52,5780 9550,0000 55,8730 9600,0000 59,1270 9650,0000 65,7850 9700,0000 60,3930 9750,0000 56,7330 9800,0000 81,0070 9850,0000 50,5260 9900,0000 88,0800 9950,0000 84,5560 10000,0000 114,8350 10050,0000 82,3260 10100,0000 68,5950 10150,0000 71,9360 10200,0000 108,0670 10250,0000 82,8140 ROP 93,3570 35,0409 23,5254 37,2612 56,9358 43,2822 65,6608 21,6817 94,4141 74,8618 91,3554 90,5976 2,6452 42,5887 90.2801 9,4617 117,5395 15.0352 57,9074 100,1661 85,7385 98,4250 87,2021 22,8683 112,6013 68,2643 137,9338 167,1370 112,4987 179,6350 115,1529 167,1629 44,9014 86,6427 -395,2797 9121,000000 10730,000000 0.500000 = feet ROPS 120,6640 94,3160 24,6870 38,7250 55,9760. 42,9490 67,2990 21,9710 78,2190 76,3230 93,3680 90,1600 3,4290 42,4660 90,1600 87,1700 117,5230 90,0110 61,8920 104,9980 84,4560 98,4250 90,7380 50,6910 113,0270 RECEIVED NOV 9 2001 AfP~ska Oli& Gas Cons. c. ommms~o~ ~ 10300.0000 10350.0000 10400.0000 10450.0000 10500.0000 10550.0000 10600.0000 10650.0000 10700.0000 10730.0000 94 8830 47 2150 37 9220 56 7860 56 6260 55 0620 54.3310 51.8330 88.5290 -999.2500 76.5610 137.2860 167.1370 108.5530 169.2750 130.5090 167.1370 109.9290 82.0720 -999.2500 Tape File Start Depth = 9121.000000 Tape File End Depth = 10730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS **** REEL HEADER **** MWD 01/10/31 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/10/31 48638 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block #MNEM.UNIT Data Type STRT FT STOP FT STEP FT NULL COMP WELL FLD LOC CNTY STAT SRVC TOOL DATE API CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ............... 9121.0000: Starting Depth 10730.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMPANY: PHILLIPS Alaska, Inc. WELL: 15-12A FIELD: Prudhoe Bay Unit LOCATION: 2113' FNL, 3801' FEL COUNTY: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray LOG DATE: 27-Jul-00 API NYUMBER: 500292066501 ~Parameter Information Block #MNEM.UNIT Value Description #- SECT. 22 : Section TOWN.N liN : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LNF . RKB : Log Measured from FAPD.F 60 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 60 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 -Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 15-12A was drilled to 10714' MD (8795' SSTVD). After a depth tie-in TD was shifted to 10730' MD (8795' SSTVD). (5) The interval from 10702' MD (8794' SSTVD) to 10730' MD (8795' SSTVD) was not logged due to sensor to bit offset. (6) The data presented here is final and has been depth shifted to a PDC (7) (Primary Depth Control) supplied by Phillips Alaska (SWS, 08-31-00). A Magnetic Declination correction of 29.17 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: SENSOR OFFSETS: RUN GAMMA DIRECTIONAL RUN GAMMA DIRECTIONAL 8 27.27 ft. 32.97 ft. 9 27.24 ft. 32.94 ft. CURVE SHIFT DATA BASELINE, MEASURED, 9074.92, 9082.79, 9086.14, 9096 63, 9109 82, 9114 54, 9120 44, 9128 02, 9131 79, 9141 10, 9144 45, 9154.29, 9165.81 9178.99 9182.93 9196.11 9200.24 9204.18 9209.49 9214.73 9217.88 9228.71 9235.20 9237.76 9249 76 9252 32 9262 93 9271 98 9277 69 9296 38 9303 27 9306 02 9313 36 9318 47 9325 36 9332 64 9340 31 9345 82 9359 82 9362 18 9374 38 9385 00 9391 78 9400 64 9406 44 9418 35 9431 59 9440 08 9076 89 9089 68 9092 63 9097 81 9109 42 9113 75 9119 85 9128.02 9131.39 9140.91 9143.66 9154.09 9165.02 9178.40 9182.34 9195.72 9200.44 9204 38 9209 10 9215 32 9218 87 9228 90, 9234 41, 9238 54, 9248 97, 9252 51, 9262 93, 9271 19, 9277 69, 9296 58, 9303 46 9306 81 9313 55 9318 87 9324.57 9333.23 9339.72 9346.42 9359.82 9362.18 9375.16 9384.80 9391.59 9399.26 9409.59 9421.89 9432.18 9436.34 DISPLACEMENT 1.96777 6.88672 6.49316 1.18066 -0.393555 -0.787109 -0.589844 0 -0.393555 -0.196289 -.0.787109 -0.196289 -0.787109 -0.589844 -0.589844 -0.393555 0.196289 0.196289 -0.393555 0.589844 0.983398 0.197266 -0.787109 0.787109 -0.787109 0.197266 0 -0.787109 0 0.197266 0.196289 0.787109 0.197266 0.393555 -0.787109 0.589844 -0.589844 0.59082 0 0 0.787109 -0.197266 -0.196289 -1.37793 3.14844 3.54199 0.589844 -3.73828 9602 61 9643 10 9653 29 9657 02 9680 31 9682 48 9793 81 9805.82 9821.95 9870.20 9882.54 9892 38 9896 77 9899 53 9913 70, 9923 92 9926 48 9930.61 9947.92 9951.46 9970.54 9992.48 10000.7 10007.8 10012.8 10037.4 10039.5 10044.0 10050 1 10064 8 10067 8 10070 3, 10075 4, 10098 7, 10117.6, 10126.4, 10157.2, 10177.2, 10181.1, 10189.4, 10192.1, 10214.0, 10227.4, 10242 6, 10249 5 10259 3 10267 2 10271 1 10278 2 10280 7 10300 3 10303 8 10315 8 10318 0 10327 5 10329 3 10332 2 10335 4 10341 6 10351.4 10421.6 10425.6 10546.0 10556.6 10561.1 10599 9 10606 7 10622 2 10635 2 10638 4 10648 9 10670 7 10672 9 10678.2 EOZ END 9603.00 9642.90 9652.11 9654.47 9682.09 9683.66 9793.02 9804.44 9821.36 9870.59 9882.94 9889.04 9896.58 9897.95 9910.94 9919.98 9925.69 9927.46 9946.34 9949.30 9971.13 9993.86 10000 7, 10008 4 10012 2 10034 6 10037 9 10044 8 10049 2 10064 8 10067 9 10069 3 10074.0 10098.6 10121 2 10126 2 10156 0 10175 2 10177 6 10186 8, 10190.1 10213.4 10224.3 10242.4 10249.1 10256.7 10265.6 10271.5 10276.4 10278.8 10300.1 10303.8, 10314.4, 10317.8, 10326 3, 10328 7 10331 4 10334 4 10341 2 10349 0 10423 4 10426 3 10547 1 10557 3 10561 9 10600 0 10606 3 10621 7 10640 3 10643 5 10653 6 10667.2 10669.9 10679.0 0.393555 -0.196289 -1.18066 -2.55762 1.77148 1.18066 -0.787109 -1.37793 -0.589844 0.393555 0.393555 -3.3457 -0.196289 -1.57422 -2.75488 -3.93555 -0.786133 -3.14844 -1.57422 -2.16406 0.589844 1.37695 0 0.59082 -0.589844 -2.75391 -1.57422 0.787109 -0.984375 0 0.197266 -0.984375 -1.37793 -0.196289 3.54199 -0.196289 -1.18066 -1.96777 --3.54199 -2.55859 -1.96777 -0.589844 -3.14844 -0.196289 -0.393555 -2.55859 -1.57422 0.393555 -1.77051 -1.9668 -0.196289 0 -1.37695 -0.197266 -1.18066 -0.589844 -0.787109 -0.984375 -0.393555 -2.36133 1.77148 0.787109 1.18066 0.787109 0.787109 0.196289 -0.393555 -0.59082 5.11523 5.11523 4.72266 -3.54199 -2.95215 0.787109 Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 191 records... 8 bytes 132 bytes 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN Phillips Alaska, Inc. WN 15-12A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by Philllips Alaska 3. The PDC used is a Schlumberger Gamma Ray dated 31-Aug-00. *** INFORMATION TABLE: CIFO FiNEM CHAN DIMT CNAM ODEP 1 GR GRAX14 0.0 2 ROP ROPS14 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 API 2 ROP MWD 68 1 F/HR Total Data Records: 39 Size Length 4 4 4 4 8 Tape File Start Depth = 9121.000000 Tape File End Depth = 10730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 48 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** ~ .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN Phillips Alaska, Inc. WN 15-12A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 ROPS 0.0 2 ROPS * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0. 500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 1 API 4 2 ROPS MWD 68 1 F/HR 4 Total Data Records: 39 Tape File Start Depth = 9121.000000 Tape File End Depth = 10730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 48 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/10/31 48638 01 Length 4 4 8 **** REEL TRAILER **** MWD 01/10/31 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes