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Home My WebLink About201-018 • • RECEIVE7:, ! Post Office Box 244027 ,JULAnchorage, AK 99524-4027 Hilcorp Alaska,LLC U3 0 201}) 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 aofro1F Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 3 Re: Duck Island Unit Well Renaming Request � H�� AUG 2201E Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I"followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp I • Orig • New API_WeIINo PermitNumber WellName WellNumber I WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 :50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 A 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 150029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 150029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E Imag~ ~roject Well History File Cover{ age 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. ~.0 L- ;~) L ~ Well History File Identifier Organizing (~o,,~t [] RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA , [~""~Diskettes, No. J [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation ~ x 30 =~----'/~ ,, BY: BEVERLY ROBIN VINCENT SHERYL~INDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO IF NO IN STAGE I~ PAGE(S) DISCREPA~CI'~REFOUND:/ ~~YES ,~-~. NO III Illllllllll II III RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS~ Quality Checked 12/10/02Rev3NOTScanned.wpd e e ~~'- <" "" . . \ \ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiçhc\CvrPgs_ Inserts\Microfilm _Marker. doc "-'" STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REC~qMPJ-ETIONREPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator ~ 7. Permit201.018Number/302_3~3 BP Exploration (Alaska)Inc. .~,,-~r,c~F'~ I~ ~ .~ ~.~[~3,,' ,.' 3. Address ~"t'~'~"~"-- 8. APl Number(' ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029218~'~ 4. Location of well at surface 9. Unit or Lease Name 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E, UM X = 258967, Y = 5982474 Duck Island Unit/Endicott At top of productive interval N/A l ~ ,,~ ~, 10. Well Number ~ At total depth. ~.r.~,~-' ~r, 2-28A/O-19 2350' SNL,,~5~ W~-L, o~-,-,. 36, T12N, R16E, UM X = 259510, Y = 5982050 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Endicott Field / Endicott Pool KBE = 55.00' ADL 034633 12. Date Spudded2/27/2001 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband' 115' Water depth' if'°ffs'h'Ore 116' NO' of C°mpletions3/7/2001 03/21/2003 6 - 12 MSL I Zero 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set121. Thickness of Permafrost 10223 10086 FTI 8490 8460 FTI [] Yes [] NoI N/A MDI 1465' (Approx.) 22. Type Electric or Other Logs Run MWD / LWD, PWD, GR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Surface 131' Drive 13-3/8" 68# NT-80 Surface 2504' 17-1/2" 3687 cu ft Permafrost 9-5/8" 47# NT-80S / NT95H Surface 9644' 12-1/4" 575 cu ft Class 'G' 7" 29# SM-110 9382' 9665' 8-1/2" 517 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD 'I'VD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8490' Set EZSV Plug 8286' Se~Kick Plug with 39 Bbls Class 'G' 27. 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 I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE co. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~AY 0 9 7_003 ~~'i ~~' 2003Alaska 0il & Gas Cons. Commission .~ ', ;~ I~)MS BFL Iii, AY ~. ~ Anchorage ;~ .... ~ .,: Form 10-407 Rev. 07-01-80 ORiGi[:' AL Submit In Duplicate 129' Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. K3B 9823' 9772' FI 9935' 9870' K3A / S3A4 9990' 9914' S3A2 10090' 9985' KSB 10163' 10042' BgA 6 2003 RECEIVED MAY 0 9 2003 Alaska 0il & Gas Cons. Commission Anchorage S1. List of Attachments: Summary of Daily Drilling Reports and a Pre-Rig Work Summary Report. 32. I hereby cert~~correct to the best of my knowledge ~ Title Technical Assistant Date ~,_~-~~ Signed So 2-28A/O-19 201-018 302-353 PreparedBy Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. /Approval No. D#//ing Engineer: Walter Quay, 564-4178 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1 .' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL Well: Field: APl: Permit: Date 2-28 B/O- 19 Accept: 03-18-03 Endicott Field / Endicott Pool Spud: 03-25-03 50-029-21847-02 Release: 04-06-03 203-006 Rig: Doyon 15 PRE-RIG WORK 12/27/02 4.5" TUBING CUT @ 9050'. RAN TUBING PUNCH PRIOR CHEMICAL CUT TO EQUALIZE PRESSURE BETWEEN IA AND TUBING AT CUT DEPTH (PUNCHED 9 HOLES FROM 9080' TO 9082'). RAN STRING SHOT TO CLEAN THE PIPE BEFORE CUTTING. TD TAGGED @ 9149'. TIE-IN TO GLM'S FROM WELL SCHEMATIC. RAN CHEMICAL CUTTER. POSITION TOOL WITH SEVERING HEAD AT 9050, FIRE, GOOD INDICATION OF FIRING. POOH, DID NOT RECOVER FULL TOOL STRING. ASSEMBLY PARTED AT FIRING HEAD, ~EF:I- FISI~t~I:~DLE: FIRING HEAD, ANCHOR BODY, CHEMICAL TUBES, SEVERING HEAD AND CENTRALIZER (13.5'.) 12/29/02 RAN l'X 2-1/8" STEM & 3.50" LIB. SAT DOWN @ 9116' SLM. (IMPRESSION OF TOP OF CHEMICAL CUTTER) ~'~J~_~ ,~¥ '~ ~' ~ ~ 01101103 LOG GRADIO PASS FROM SURFACE TO 9090' (AVOID TOP OF FISH AT 9116' SLM). FLUID LEVEL AT 150'. FLUID INTERFACE FP/11 PPG BRINE AT 1680'. BRINE TO BOTTOM. TOOL CAME BACK CLEAN. FIRED STRING SHOT ON INTERVAL 9030'-9044'. FIRED CUTTER AT 9042'. TOOLSTRING PARTED AT SAFE ADAPTOR. FISH LEFT IN HOLE. APPROX 161.6" LONG, CONTAINING SPENT EXPLOSIVES AND HAZARDOUS CHEMICAL. TOP OF FISH SHOULD BE EXPECTED AT APPROX 9100'. 01/13/03 CUT 4.5" TUBING AT 8870' USING 3 5/8" CHEMICAL CUTTER. BEFORE CUTTING, FIRED STRING SHOT OVER INTERVAL: 8859.5' TO 8871.5' TO CLEAN PIPE FOR BOTH ANCHOR BODY AND SEVERING HEAD. 01/30/03 PRE-RIG MOVE BLEED DOWN AFTER CEMENT PLUG BACK AND CUTTING THE TUBING. BLED TUBING DOWN FROM 750 PSIG TO 0 PSIG. BLED IA DOWN FROM 1750 PSIG TO 250 PSIG BLED OA DOWN FROM 300 PSIG TO 0 PSIG 02/13/03 PRE-RIG SIDETRACK. TBG 0 PSI- IA 150 PSI- OA-0 PSI. LOOP LIFT GAS FROM ADJACENT WELL TO IA. PRESSURE UP IA TO 1400 PSI. TBG CAME UP TO 400 PSI. CONFIRM IA CLEAR AND IN COMMUNICATION WITH TBG. RD LEAVE PRESSURE ON WELL FOR UPCOMING BPV SET/PT. 02/15/03 RIG UP DRILL MAINTENANCE AND SET BPV FOR UPCOMING SIDETRACK. 02/23/03 TEST BPV TO 2000 PSI, PASSED BP EXPLORATION Page 1 of 13 Operations summa Report : · iLegal Well Name: 2-28B/O-19 Common Well Name: 2-28B/O-19 Spud Date: 3/18/2003 Event Name: REENTER+COMPLETE Start: 3/18/2003 End: 4/6/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 4/6/2003 Rig Name: DOYON 15 Rig Number: Date From - To Hours Task Code NPT~ -Phase: ' - DescriPtion of,'OPerations · . . 3118/2003 03:00 - 04:00 1.00 MOB p PRE SKID RIG FLOOR - LIFT SUB FEET 04:00 o 05:00 1.00 MOB p PRE MOVE PIT COMPLEX FROM SUB - SPOT COMPLEX FOR RIG MOVE 05:00 - 06:00 1.00 MOB p PRE MOVE SUB COMPLEX FROM WELL 3-17E - SPOT FOR RIG MOVE 06:00 - 08:00 2.00~ MOB p PRE MOVE SUB - PIT COMPLEX FROM SDI TO MPI 08:00 - 10:00 2.00 MOB p PRE LAY DOWN HERCULITE - SET RIG MATS FOR MOVE ON OF SUB - PIT COMPLEXS 10:00 - 11:00 1.00 MOB p PRE MOVE SUB COMPLEX OVER WELL 2-28B 11:00 - 11:30 0.50 MOB p PRE MOVE PIT COMPLEX TO SUB 11:30 - 12:00 0.50 MOB p PRE LOWER FEET ON SUB AND SECURE 12:00 - 14:00 2.00 MOB p PRE SKID RIG FLOOR - CLOSE UP CELLAR 14:00 - 15:00 1.00 MOB p PRE RIG UP STEAM, AIR, WATER, GYLCOL LINES -WELD ON ~ NEW DRAIN LINES NIPPLES ' 15:00 - 16:30 1.50 MOB p I PRE RIG DOWN GAS LINE @ SDI - RIG UP GAS LINE TO RIG - i I CONTINUE RIGGING UP 18:30 2.00 MOB I p I PRE BERM UP AROUND RIG - SPOT ROCK WASHER AND 1 6:3O I BERM UP SAME 18:30 - 19:30 1.00 VIOB p :PRE TAKE ON SEA WATER IN PITS -CONTINUE RIGGING UP 19:30 - 20:30 1.00 MOB p PRE RIG UP DSM LUBICATOR - PULL BPV - RIG DOWN LUBICATOR - NO PRESSURE ON TUBING 20:30 - 22:00 1.50 MOB p PRE CONTINUE RIGGING UP - CIRCULATING WATER - AIR - STEAM - THROUGH OUT RIG - ACCEPT RIG @ 22:00 HRS ! ON 3/18/2003 22:00 - 00:00 2.00 CLEAN p DECOMP INSTALL HERCULITE OVER WELL HOUSES UNDER SUB- ', I RIG UP HARD LINE FROM 2-28 ANNULUS TO 2-32 FLOW LINE TO CIRCULATE FREEZE PROTECT AND BRINE OUT .............. ~,.,,.-,-. OF WELL 311912003 00:00 - 01:30 1.50 RIGU :) DECOMP HELD PJSM RIGGED UP HARD LINE WITH DSM - TESTED TO 3,000 PSI 01:30 - 06:00 4.50 CLEAN p DECOMP TESTED INJECTION LINE TO 3,000 PSI - ESTABLISHED CIRCULATION DISPLACED FREEZE PROTECTION AND '- BRINE STAGING UP AT 2 BPM 300 PSI ~'A~ED J~¥ ~'. ~ 20031 ,4BPM1100PSI I 5 BPM 1450 PSI PUMP 265 BBLS - SHUT DOWN 30 MINS - CONTINUED J DISPLACING AT J 2 BPM - 700 PSI j 4 BPM - 1100 PSI J 6 BPM - 1800 PSI J PUMP 265 BBLS - SHUT DOWN 30 MINS - CONTINUED DISPLACING AT 2 BPM 500 PSI 4 BPM 900 PSI 6 BPM 1400 PSI DISPLACED WELL WITH TOTAL OF 800 BBLS OF 8.6 # SEAWATER 06:00- 06:30 0.50 CLEAN p DECOMP DISCONNECTED CIRC LINES- BLEW DOWN 06:30 - 07:00 0.50 CLEAN p DECOMP FLOW CHECKED WELL - WELL STATIC 07:00 - 07:30 0.50 WHSUR p DECOMP INSTALLED TWC - TESTED TO 1,000 PSI FROM BELOW FOR 15 MINS 07:30 - 09:00 1.50 WHSUR p DECOMP N / D TREE AND ADAPTER FLANGE. CHECKED THREADS BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: 2-28B/O-19 , ;~ 2003 Spud Date: 3/18/2003 Common Well Name: 2-28B/O-19 - Event Name: REENTER+COM PLETE Start: 3/18/2003 End: 4/6/2003 Contractor Name: DOYEN DRILLING INC. Rig Release: 4/6/2003 Rig Name: DOYEN 15 Rig Number: Date From - To Hours Task Code NPT :phase ' Descr!Ptio'n-Of Operations 3/1912003 07:30 - 09:00 1.50 WHSUR P DECOMP IN TUBING HANGER. SOME THREAD DAMAGE DUE TO PREVIOUS 'I-rRD OPERATION. 09:00 - 13:00 4.00 BOPSUF P DECOMP N / U 13-5/8" DOPE w/ANNULAR, 3-1/2" x 6" VARIABLE RAMS IN TOP, BLIND RAMS AND 4-1/2" x 7" VARIABLE RAMS IN THE BOTTOM. 13:00 - 14:00 1.00 RIGU P DECOMP CREWS ATTENDED BP SAFETY INDUCTION 14:00 - 17:30 3.50 BOPSUI; P DECOMP CONTINUED N I U - DOPE - RISER - FLOWLINE - INSTALLED MOUSE HOLE - BLEED OFF LINE. 17:30 - 19:00 1.50 RIGU P DECOMP RIGGED UP TEST JOINT - FLOOR VALVES - TESTED SUB FOR TOP DRIVE - FILLED STACK ! CHOKE MANIFOLD 19:00 - 00:00 5.00 BOPSUI; P DECOMP TESTED DOPE - TESTED TOP PIPE RAMS - CHOKE MANIFOLD - KILL I CHOKE HCR'S - KILL / CHOKE MANUAL VALVES - FLOOR VALVES - UPPER I LOWER IBOP - TESTED LOWER PIPE RAMS HINGE PIN LEAKING HYD OIL ON ODS - NO TEST - REPLACED 2 SEALS ON RAMS IN HINGE PIN FLUID HOUSING. 3/20/2003 00:00 - 02:00 2.00 BOPSUI~ P DECOMP HELD PJSM. TESTED ANNULAR TO 250 LOW 3,000 HIGH 5 MINS EACH TEST - TESTED LOWER PIPE RAMS - BLIND RAMS 250 LOW 4,500 HIGH 5 MINS EACH TEST - ACCUMULATOR TEST - RIGGED DOWN TEST JOINT 02:00 - 02:30 0.50 PULL P DECOMP BLEW DOWN CHOKE / KILL LINE - CHOKE MANIFOLD - NIPPLED UP SECONDARY VALVE ON WELL HEAD 02:30 - 04:00 1.50 PULL P DECOMP HELD PJSM. PICKED UP SHOOTING FLANGE - PICKED UP LUBRICATOR - PULLED TWC - RIGGED DOWN LUBRICATOR 04:00 - 05:00 1.00 PULL P ~DECOMP HELD PJSM. M / U BAKER DOUBLE SPEAR w/4.020" MAX CATCH 3.947" NOMINAL CATCH GRAPPLES, 2 JTS 5" DP. 05:00 - 05:30 0.50 PULL P DECOMP RIH w/SPEAR ASSEMBLY, M / U TO TOP DRIVE. SPEAR ASSEMBLY WOULD NOT PASS THROUGH HANGER. POOH w/TO CHECK GRAPPLES. REA'I-I'EMPTED TO ENGAGE SPEAR, SPEAR ASSEMBLY WOULD NOT PASS THROUGH HANGER. 05:30 - 07:00 1.50 PULL N i DPRB DECOMP POOH TO CHANGE OUT GRAPPLES. PERFORMED DERRICK INSPECTION. 07:00 - 07:30 0.50 PULL N DPRB DECOMP DRESSED SPEAR w/3.958" MAX CATCH 3.885" NOMINAL CATCH GRAPPLES, RIH, TOOK 30,000# DOWN WEIGHT TO PASS THROUGH TUBING HANGER, P / U AND ENGAGED GRAPPLES. 07:30 - 08:00 0.50 PULL 'P DECOMP CHECKED ANNULUS FOR PRESSURE, ZERO PRESSURE. BOLDS. 08:00 - 09:00 1.00 PULL P DECOMP PULLED ON SPEAR ASSEMBLY w/165,000~, TUBING HANGER CAME FREE, PULLED TUBING HANGER TO FLOOR, STRING WEIGHT UP 150,000~. TERMINATED CONTROL LINES, BROKE OUT AND L / D SPEAR ASSEMBLY AND TUBING HANGER. 09:00 - 11:00 2.00 PULL :) DECOMP HELD PJSM. M I U HEAD PIN, XO AND CIRCULATING HOSE. CIRCULATED 2 x BOTTOMS UP PUMP RATE 10 BPM, 750 PSI. NO GAS. R / U CAMCO CONTROL LINE SPOOLING EQUIPMENT. 11:00-13:00 2.00 PULL :) DECOMP POOH, LID38JOINTSOF4-112"12.6~L-80BTCTUBING, SPOOLED UP CONTROL LINE. RECOVERED 19 CONTROL LINE CLAMPS AND 4 STAINLESS STEEL BANDS. 13:00 - 13:30 0.50 PULL :) DECOMP R / D CAMCO CONTROL LINE SPOOLING EQUIPMENT. Printed: 4/8/2003 8:58:52 AM BP EXPLORATION Page 3 of 13 Operations Summa Report Legal Well Name: 2-28B/O-19 Common Well Name: 2-28B/O-19 ~F~~F~ ~JA¥ ~ ~ ~_00~ Spud Date: 3/18/2003 Event Name: REENTER+COMPLETE Start: 3/18/2003 End: 4/6/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 4/6/2003 Rig Name: DOYON 15 Rig Number: Date From - To Hours Task Code NPT Phase 'DesCdpti°n of OPerations' i3/20/2003 13:00 - 13:30 0.50 PULL :) DECOMP BROKE OUT AND L / D SSSV ASSEMBLY. 13:30-21:00 7.50 PULL :~ DECOMP POOH, L / D 225 JOINTS OF 4-1/2" 12.6~L-80BTCTUBING + CUT OFF JOINT 34.62 21:00 - 22:00 1.00 PULL P DECOMP CLEARED FLOOR OF TUBING EQUIPMENT - XO'S 22:00 - 23:30 1.50 PULL p 3ECOMP PJSM - SCHLUMBERGER - PICKED UP 9 5/8" EZVS BRIDGE PLUG TO FLOOR - RIGGED UP SCHLUMBERGER EQUIPMENT - 23:30 - 00:00 0.50 PULL P DECOMP RIH WITH -GR / CCL / JB / GAUGE RING 8.5" 3/2112003 00:00 - 03:00 3.00 EVAL P DECOMP PJSM. RIH TO 8800' WITH CCL I GR ! JB I DRIFT 8.5 - LOGGED UP TO 8000' - POH WITH TOOLS - (NO JUNK IN JUNK BASKET) 03:00 - 03:30 0.50 EVAL p DECOMP ~PJSM - MADE UP 9 5/8" EZSV BRIDGE PLUG ON E-LINE . RUNNING TOOL 03:30 - 04:30 1.00 EVAL p 'DECOMP RIH WITH 9 5/8" EZSV PLUG TO 8490' - SET PLUG RELEASE OFF SE'l-rING TOOL 04:30 - 06:30 2.00 EVAL P DECOMP POH WITH SE'i-rING TOOL - SHUT BLIND RAMS TEST CASING TO 3000 PSI FOR 10 MINS - TEST GOOD - RIG DOWN SCHLUMBERGER 06:30- 07:30 1.00 STMILL p WEXIT INSTALL WEAR RING 07:30 - 08:00 0.50 STMILL p WEXIT SERVICE TOP DRIVE - CROWN - RIG 08:00 - 08:30 0.50 STMILL p WEXIT PJSM - PREPARE FOR PICKING UP 5" DP FROM PIPE SHED 08:30 - 17:30 9.00 STMILL p WEXIT PICK UP 5" DRILL PIPE FROM SHED - RIH TO 7275'. 17:30 - 18:30 1.00 STMILL p WEXIT PULL 20 STANDS S-135 DP - RACK BACK FOR DRILLING - FROM 7275' TO 5325' 18:30 - 21:00 2.50 STMILL :) WEXIT CONTINUE PICKING UP 5" DRILL PIPE FROM PIPE SHED FROM 5325' TO 8394' 21:00 - 21:30 0.50 STMILL ~ WEXIT BREAK CIRCULATION 60 SPM - 200 PSI - WASH FROM 8394' TO 8484' TAG BRIDGE PLUG DRILL PIPE MEASUREMENT - PICK UP 10 FEET TO 8474' 21:30 - 22:00 0.50 STMILL :) WEXlT RIG UP DISPLACEMENT LINE FROM 2-28 TO 2-32 - TEST TO 2000 PSI 22:00 - 22:30 0.50 STMILL :) WEXIT PRODUCTION NOT ABLE TO TAKE RETURNS DOWN FLOW LINE - BLOW DOWN LINE - RIG DOWN LINE -- PREPARE TO DISPLACE INTO ROCK WASHER 22:30 - 23:30 1.00 STMILL p WEXIT DISPLACE 8.6 BRINE WITH 9.7 MILLING FLUID @ 93 SPM - 2100 PSI - PUMP 50 BBL FRESH WATER SPACER - DISPLACED 565 BBLS 23:30 - 00:00 0.50 STMILL p WEXIT SPOT 20 BBL 18 PPG PILL ON BTM - PICK UP WEIGHT 195K - SLACK OFF WEIGHT 195K - ROTATING WEIGHT 195K- RPM 90 -TORQUE 5500K 3/22/2003 00:00 - 00:30 0.50 STMILL p WEXIT CONTINUE TO SPOT 18 PPG PILL ON BTM 00:30 - 01:00 0.50 STMILL p WEXIT i PJSM - PULL 5 STANDS FROM 8474' TO 8009' 01:00 - 02:00 1.00 STMILL p WEXIT PJSM - CUT DRILLING LINE - RIG SERVICE - RIG SERVICE TOP DRIVE 02:00 - 06:00 4.00 STMILL p WEXIT POOH w/5" DP FROM 8,009' TO MULE SHOE. 06:00 - 06:30 0.50 STMILL p ;WEXIT CLEARED AND CLEANED RIG FLOOR. 06:30 - 09:00 2.50 STMILL p WEXIT HELD PJSM. M I U SECTION MILL BHA: #7 LOCK-O-MATIC - JET SUB - CIRCULATING SUB - 9 x 6-1/4" DC - JARS - 15 x 5" HWDP. BHA LENGTH 757.35'. 09:00 - 14:00 5.00 STMILL p WEXIT RIH w/SECTION MILL BHA ON 5" DP TO 8,284'. Printed: 4/~ Permit to Drill 2010180 DATA SUBMITTAL COMPLIANCE REPORT 411612003 Well Name/No. DUCK IS UNIT MPI 2-28AJ019 Operator BP EXPLORATION (ALASKA) INC MD 10223 -~, TVD 10086~ Completion Dat 3/14/2001 -- Completion Statu SUSP Current Status SUSP UIC N APl No. 50-029-21847-01-00 REQUIRED INFORMATION Mud Log N..~o Sample N._~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Ype Media Fmt Interval Log Log Run Name Scale Media No Start Stop Directional Survey FINAL 9634 9634 10165 1O165 10165 10165 Directional Survey FINAL 10278 FINAL 9634 LIS VERIFICATION FINAL 10297 FINAL 9634 (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Case 9/18/2001 ~;:~)297 Open 917/2001 ~ 4/12/2001 ~L12/2001 o. OH 9/712001 OH 9/18/2001 ~,,97 Comments 9634-10165 Directional Survey Digital Data Directional Sruvey Paper Copy 9634-10165 DIGITAL DATA LIS VERIFICATION 9634-10165 Digital Data ~ Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis R ~.r~.iv~.d ? Interval Start Stop Sent Received Daily History Received? Formation Tops Dataset Number Comments Comments: Permit to Drill 2010180 MD 10223 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4116~2003 Well Name/No. DUCK IS UNIT MPI 2-28A/019 Operator BP EXPLORATION (ALASKA) INC 10086 Co~n~.~le,~n· Dat 3/14/2001 Completion Statu SUSP APl No. 50-029-21847-01-00 Current Status SUSP UIC N Date: / "~ '~,,~~ ~' ~,,- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Suspend [] Repair Well [] Operation Shutdown 5. Type of well: [] Development [] Exploratory r"l Stratigraphic [] Service I-I Plugging [] Time Extension [] Perforate [] Pull Tubing [] Variance [] Other /'" [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 6. Datum Elevation (DF or KB) KBE = 55.00' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 4. Location of well at surface 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E, UM At top of productive interval N/A At effective depth 2270' SNL, 1950' WEL, SEC. 36, T12N, R16E, UM At total depth 2350' SNL, 1683' WEL, SEC. 36, T12N, R16E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10223 feet Plugs (measured) 10086 feet 9342 feet Junk (measured) 9297 feet Casing Structural Conductor Surface Intermediate Production Liner 2-28A/O-19 I9.~e//~ Number 'T0:'~PI Number I50-02921847-01 11. Field and Pool Endicott Field / Endicott Pool Whipstock at 9675'; Perf Abandonment Cement below Whipstock (03/01) 3 Bowspring Leafs at 10448' 3-1/2" tailpipe cut and dropped to bottom (03/01) Length Size Cemented M D TVD 92' 30" Driven 131' 131' 2465' 13-3/8" 3687 cu. ft. Permafrost 2504' 2503' 9605' 9-5/8" 575 cu. ft. Class 'G' 9644' 9597' 1144' 7" 517 cu. ft. Class 'G' 9383'- 9675' 9338' -9627' Perforation depth: measured None - Abandoned Perf's for Sidetrack Operation. true vertical None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 9339' RECEIVED NOV 1 8 2002 Naslm 0il-& Gas ~ns. Commission Packers and SSSV (type and measured depth) 9-5/8" Baker 'SAB' packer at 9339'; 4-1/2" SSSV Landing N~~5' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation//' December 2, 2002" 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Walter Quay, 564-4178 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Sondra Stewman, 564-4750 17. I hereby certify that the f~ego~g ~ t~e and correct to the best of my knowledge Signed Fred Johnson ~/',~,~/~~l,~ Title Senior Drilling Engineer Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- p ORIGINAL SIGNED BY A proved by order of the Commission ~'%~'i~ ~,'-',,-~, ,, ~ ,~ ,',, .! ~..,';",.~'~... !,,i'/', .r.. Form 10-403 Rev. 06/15/88 RBDNS BFL ....,, ,,, ...... ... " ' ~' I ~ ~.', ~ ~ ~...~ Approval No....~Z)~, Commissioner 2u~em ~4ri~~at'~' NOV 2 5 2,0P,,~ it Endicott 2-28/O-19 To: From: Subject: Reference: Winton Aubert - AOGCC Date: November 15, 2002 Walter Quay Endicott 2-28/O-19 Application for Sundry Approval - Reenter for Sidetrack Operations APl # 50-029-21849-1 Approval is requested for the proposed sidetracking of 2-28/O-19 to a new bottom hole location as a conventional producer targeting Kekiktuk zone 2 reserves. The proposed path forward is to cut the 4-1/2" tubing above the producti,o, xn~packer at -9,050' MD. The rig would then move on, pull the tubing above the cut, set a bridge plug @ -8,425', section mill the 9-5/8" casing @ -8,275' to 8,325' then sidetrack the well to the new bottom hole location, and run a 4-1/2" liner cemented back into the 9- 5/8" casing. See attached schematics for details. ' The sidetrack is currently scheduled for~yon~.~lS'~beginning around March 1, 2003, after the completion of the proposed 3-25 sidetrack. The pre-ri w~~for this sidetrack is planned to begin as soon as the a?,.ached Application for Sundry is approved, with the target date to commence pre-rig work on December 2, 2002. Version 1.0 15 Nov 2002 Endicott 2-28/O-19 Sidetrack and Complete Procedure Summary Pre-Riq Work: 1. Test the FMC 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. Ria 1. 2. 3. COMPLETE (10/10/01): Packoff passed test to 3000 psi, Tubing hanger passed test to 5000 psi. All lock-down screws functioned. 2. Test the integrity of the cement plug w/1000 psi inside t~tubing. This plug was previously verified and tested with 2000 psi and by setting 30K # of weight. 3. Rig up slickline, tag and document top of cement and drift tubing for up.~p, coming tubing cut @ -9,050'. Tubing was drifted(3.625") and cement tagged @ 9126' WL on 11/10102. 4. Pull one of the lower DGLMs. Displace the well to clear, seawater by circulating down tubing lower GLM. Freeze protect top 1500,,' MD with diesel. 5. RU E-line. Cut the 4 Y2 L-80 tubing at approximately .~.~.. MD using either a jet or chemical cutter. 6. Bleed tubing and annuli pressures to zero. Set a BPV ~n the tubing hanger and test from below to 1000 psi. If necessary, level the pad. Operations: MIRU Doyon 15. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. Nipple down tree. Ali.qnment marks should be made before removinq the old tree. Nipple up and test BOPE to 250 / 5000 psi. Pull TWC. 4. Pull and lay down 4-1/2" tubing from E-line cut and above. 5. RU WL. Run gauge ring/junk basket to -8500' Run and set a bridge plug on WL @ '- 8,425' 6. MU 9-5/8" window section milling assembly and RIH with 5" DP to the bridge plug. Displace well to milling fluid. 7. SpOt a balanced 18.0 ppg mud pill from -8,425' to 8,275'. 8. Section mill window from 8,275' to 8,325'. POOH. 9. MU cementing mule-shoe and TIH to 8,425'. Circulate and condition. 10. Mix and pump cement kickoff plug. POOH. 11. MU 8-1/2" PDC drilling assembly including MWD/GR RIH to top of cement. Clean out cement to kick-off point. 12. Kick-off and drill the 8-1/2" hole section as per directional plan to TD at +/-11,025' MD (10,325' TVD). Condition hole for running liner, spot liner running pill, and POOH. 13. Run and cement a 4 ½", 12.6# 13 Cr80 production liner. Release from liner and set liner top packer. Test wellbore to 1000 psi to verify liner top packer is set. 14. Run 4-1/2", 12.6# 13 Cr-80 gas lift completion. Space-out tubing so the WLEG is inside the 4-1/2" liner tie- back sleeve. 15. Drop ball/rod & set packer. Test the tubing to 3000 psi and annulus to 3000 psi for 30 minutes. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect and secure the well. 18. Rig down and move off. Post-Rig Work: 1. RU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the production packer. Install gas lift valves. 2. RU e-line. Perforate -50' of Kekituk interval with 2-7/8" guns. Version 1.0 2 15 Nov 2002 TREE:~k1/16" / 5000 psi / McEVOY 'RT. ELEV= 55.0' WELL~13-5/8" ,5000 psi/McEVOY BF. ELEV = 15.8' -- MAX. DEV. = 13:33 8000' MD NT-80 CYHE, BTRS. CSG. .,~ __ SSSV LANDING NIPPLE 1555' OTIS (3.813" MIN. ID) I 2504' Iv-- · · W/SSSV MIN I.D. 2" ~ I~-- 4-1/2", I 2.6#/ft, L-80, BTRS NB Mod. TUBING GAS LIFT MANDRELS (MERLA) NO. TVDSS M D-BI~T Planned K0P 8275' MD ~ -- ~----- #6 4148' 4204' #5 6337, 6393, #4 7776' 7845' NT95HS #2 8911' 9007' ~-----"'"-~-~ ~4/t'~- C~I~Z~''~'1 9057' 9155' I -I SLIDING SLEEVE CAMCO "= ~3.75" ID confirmed by PDS survey I 9265 (] r~-~-- BAK ER "S BP" (12' I GnU)I 9324' · I 9339' iX X X )1 Set 15.8 ppg cemen~ plu~'~ 9-5/8" 47#/ft ' ' , , X X X >1 , f/ 9912-9335. Wt'd tested w/30K# NT951~S, ' I 9644' I~ I ( X X X ~.11~ pressure tested w/2000 psi. - - _ ~ "~~~ BHA f/9691-9912' I Baker Thru-,'13:)g whipstock I i~ ,F_~u~ lin g ~[fho rat,on s / PERFORA'rlO. SUMMARY ] ~. REF: LOG: DLL-GR (08-13-88) lJ ~ SIZE SPF INTEE:{VA L S' FATUS ~ ~ J ~ / ~-~/~ . ~o~.'-~o~o' SOlD ~ / 2-1/8 6 10145' - 1 0157' O~N ~ / ,, , 2-1/8 4 lOleO'- 102oo' SQZD Drilled 3.70 hole to 10223 MD 2-1/8 4 10188'- 10213' OPEN I I Stuck BHA on trip @ 9912'. 2-1/8 4 10216'- 1 0246' OPEN Attempted unsuccessf~ully to free BHA. I I Backed off & BHA. / Cemented back to packer @ 9335' MD. ~ 3 BOWS PPI NG PBTD I 10,448' I '~~' - ~ LEAFS 7" - 29 #/ft, SM-110,I 10,527' I~ BTRS-TKC DATE REV. BY COMMENTS ENDICOTT WELL 2-28A/O-1~ 1/9/01 JLH Temporary Abandonment ~_LI~L~_;..__~ 0 =029- 21847-01 Temporary Abandonment Schematic BP EXPLORATION, INC. SIZE SPF INTERVAL S' FATUS 2-1/8 4 10114'- 10160' SQTD 2-1/8 6 10145' - 10157' OPEN 2-1/8 4 10180' - 10200' SQZD 2-1/8 4 10188' - 1 021 3' OPEN 2-1/8 4 10216' - 1 0246' OPEN ' ed Completion 2-28b10-19 M~. D~. = 13:33 @~ 8000' M~ TREE: V~ELLHEAD: 4- 1/16" / 5000 psi ! IVcEVOY 13-5/8" / 5000 psi / IVcEVOY 13- 3/8", 68#1 f t, NT- 80 CYHE, BTRS. CSG 2504' SSSV LAI~DI NG NIPPLE OTIS (3.813" MN, I~D)1555' WSSSV M N I.D. 2" / 4-1/2" 12.6 LB/FT 13 CR 80 VAM ACE TUBING 4-1/2"X1-112" MMG GLM 9-5/8", 47#/ft, NT80SXOTO I8348' I~ NT95HS SECTION MILL 50' WINDOW KICK OFF CMT PLUG AT 8275'MD 4-1/2" SELECTIVE X LANDING NIPPLE 9-5/8" BAKERS-3 PACKER AT 8130' 4-1/2" SELECTIVE X LANDING NIPPLE 4-1/2" NOGO XN LANDING NIPPLE 9-5/8"x7" BAKER FLEXLOCK LINER HGR +LTP AT 8150' 8-1/2" HOLE X 4-1/2" LINER 13 CR HYDRIL 563 LINER TD 10984'MD, 10295'TVD TOP OF 7" LINER I 9383'I 9-5/8", 47#/ff, NT95HS, I 9644'I CAMCO SLIDING SLEEVEI 9265 BAKER "SBR" (12" long) I 9324' (3.72" ID) Cement plug ~ Top ofwindow 9340 - 9680'I I9665' Abandoned TTRD sidetrack 7"- 29#/ft, SM-110,BTRS-TKC PBTD I 10,448' I lO, 327' I DATE 5/95 5/1/95 6 / 7/97 8/20/01 REV. BY JLH 3-112" tailpipe & BOWSPRING LEAFS COMMENTS SQUEEZE & RE-PERF JTP ADD PERFS GAM PCST SCE REPEF~= FJ Proposed Sidetrack EI~I COrT YELL 2-28B/O- 19 APl NO; 50- 029- 21847 CCK'PLETI (~N DI ~ BP EXPLORATION, INC. WELL LOG TRANSMITTAL To: State of Alaska August 30, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs: 2-28A/O-19, AK-MM-10052 2-28A/O-19: Digital Log Images 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petroltechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 REP. . IVED SEP 1 8 Alaska Oil & Gas Cons. Commhmion Anchorage WELL LOG TRANSMITTAL To: State of Alaska August 29, 2001 Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs - 2-28A/O-19, AK-MM-10052 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-21847-01 RECEIVED $£P 0 ? DO! ~" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas llil Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-018 301-061 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-02921847-01 4. Location of well at surface .. 5~/''~'~. '~,A~ 9. Unit or kease Name 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E, UM ~ I~ At top of productive interval i.. $. i'~.: ~..I .... , ¥ Duck Island Unit/Endicott N/A i:. '"' i."...'.,J '-";~ ': S~~ r At total depth .:. '..~.'~_ ..-! ~'L ~-t~~ 10. Well Number 2350' SNL, 1683' WEL, SEC. 36, T12N, R16E, UM ........ .; "-- ~ ............. '-'~"~'~' 2-28A/O-19 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Endicott Field / Endicott Pool KBE = 55.00' ADL 034633 12. Date Spudded2/27/2001 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'3/7/2001 3/14/2001 115' Water depth' if °"sh°reo' - 12' MSL 116' N°' °f c°mpleti°nsZero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 10223 10086 FTI 9342 9297 FTI [] Yes [] NoI (Nipple) 1555' MDI 1465' (Approx.) 22. Type Electric or Other Logs Run MWD / LWD, PWD, GR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Surface 131' Drive 13-3/8" 68# NT-80 Surface 2504' 17-1/2" 3687 cuft Permafrost 9-5/8" 47# NT-80S/NT95H Surface 8348' 12-1/4" 575 cu ft Class 'G' 7" 29# SM-110 9382' 9675' 8-1/2" 517 cuft Class 'G' 24. perfOrations pp. en to. Producti.On (M.D+.TVD of Top and 25. TUBING RECORD Bottom and ~nterva~, s~ze an(3 number) SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2% 12.6#, L-80 9352' 9339' MD TVD MD TVD 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9342' P&A Section w/17 Bbls Class 'G' (Temporary Abandonment) Freeze Protect with 28 Bbls of Diesel 27. 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 I Flow Tubing 3BEing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED , MAY 0 8 Z001 Alaska Oil & Gas Cons. Commission Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. K3B 9823' 9772' FI 9935' 9870' K3A / S3A4 9990' 9914' S3A2 10090' 9985' KSB 10163' 10042' RECE# /ED 0"8 20Ol Alaska O~t & Gas co~, Anchora~ Commission 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble .~~_ ~.'~ Title Technical^ssistant Date O~"'"'i~?"~/. 2-28A/O-19 201-018 301-061 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. ,,., INSTRUCTIONS GENERAL-' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, 'water supply for injection, observation, injection for in-situ combustion. ITEM 5-' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 O, IGINAL BP EXPLORATION Page 1 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/19/2001 00:00 - 00:00 24.00 RIGU P PRE PJSM (Rig move) - prepare for rig move - move rig to well 2-28a. 2/20/2001 00:00 - 03:00 3.00 RIGU P PRE Finishing moving rig on to 2-28A/O-19 and rigged up. 03:00 - 06:00 3.00 WHSUR P PROD1 ACCEPTED RIG AT 0300 HRS 02-20-2001. Took mud into pits and continued preping rig for spud. 06:00 - 06:30 0.50 WHSUR P PROD1 PJSM-on rigging up choke line, kill line and pulling BP¥. 06:30 - 09:30 3.00. WHSUR P PROD1 Made up choke line and kill line to rig mud line system. 09:30 - 12:00 2.50: WHSUR P PROD1 Rigged up lubricator from Drill Site Maintenance. Pulled BPV and installed TWC. Pressure test TWC to 5000 psi for 5 minutes. 12:00 - 16:00 4.00 WHSUR P PROD1 Nipple down tree in three pieces and laid out beaver slide. 16:00 - 00:00 8.00 BOPSUF P PROD1 Nipple up (7 1/16 x 4 1/16 xo spool - 7 1/16 5M BOPS - test spool.- riser- pipe rams - mud cross - blind ram - pipe ram - annular). Attempt to hook up 4" flex steel choke hose. Will not make up, hose against cross beam on sub. 2/21/2001 00:00 - 03:00 3.00 BOPSUF,P PROD1 Change out choke hose's from 4" steel flex to 4" rubber. 03:00 - 06:00 3.00 BOPSUF',P PROD1 Install bell nipple / flow line. Hook up hydralic lines to stack. Change boot in air union. Install turnbuckles on stack. 06:00 - 18:00 12.00 BOPSUF',P PROD1 PJSM Testing BOPS - test blind rams, riser, test spool, XO, HCR valves - blind rams would not hold pressure - recylce rams - retest ok - Inside 2 1/16 side valve on test spool grease tiffing on stem packing leaking - take off, repair, retest 300 - 5000 against TWC ok. Test Annular 300 - 3500 ok. - test upper rams, HCR valves 300 - 5000 ok. 18:00 - 22:00 4.00 BOPSUFiP PROD1 PJSM Testing. BOPS - Test lower ram 300 - 5000 ok - test upper ram, choke valves 12, 13, 14, 15, 300 - 5000 ok - test upper rams, choke valves 5, 6, 10, 11,300 - 5000 ok - test upper rams, choke valves 1,4, 7, 300 - 5000 ok - test upper rams, choke valves 2, 3, 8, 9, 300 - 5000 ok - Function test hyd choke, manual chokes. - Accumulator test - Accumulator pressure 3000 - shut pipe rams, hcr valves, annular - accumulator pressure 1900 - accumulator pumps on 200 psi 19 seconds, full pressure 3000, 104 seconds. Nitrogen back up pressure's 1- 2500, 2 - 2600, 3 - 2600, 4 - 2400. avg 2525. 22:00 - 00:00 2.00 BOPSUI;.N SFAL PROD1 PJSM - Nipple down bell nipple to pull TWC - Pull test plug - 'Rig up lubicator to pull TWC. Attempt to pull TWC can not get on check. Both o-rings off test plug. Attempt fish o-rings out no success. 2/2212001 00:00 - 02:00 2.00 BOPSUI;,N SFAL PROD1 Attempted to fish O-rings from test plug without success. Flushed TWC with water in attempted to clear debris from top of TWC. Attempt to pull TWC with no success. 02:00 - 03:00 1.00 BOPSUI;,N SFAL PROD1 Nipple down stack above adapter flange. Cleaned rubber and fine solid from top of TWC. Found ice plug above top of TWC. Thawed ice plug. Set stack back down and nippled up. 03:00 - 03:30 0.50 BOPSUI; N SFAL PROD1 Test stack against blind rams. 250 psi Iow for 5 minutes and Printed: 5/7/2001 3:08:33 PM BP EXPLORATION Page 2 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: Date From - To Hours ActivityCode NPT Phase Description of Operations 2/22/2001 03:00- 03:30 0.50 BOPSUFIN SFAL PROD1 5000 psi high for 10 minutes. 03:30 - 04:00 0.50 BOPSUF',P PROD1 Pulled TWC with lubricator. Laid down TWC and lubricator. ,04:00 - 08:00 4.00 BOPSUF~P PROD1 Finished testing IBOP, upper IBOP, and floor valves 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Nippled up bell nipple and flow line. 08:00 - 00:00 16.00 STWHIP P PROD1 PJSM - Picking up dp - m/u milling assembly - pick up 2 3/8 dp rih - tag top whipstock at 9675' set 5k down twice to confirm tag up. 305 joints plus 15' in on joint # 306. 2/23/2001 00:00 - 01:00 1.00 STWHIP P PROD1 Displaced hole with 9.3 # QuikdrilI-N mud @ 60 spm @ 2400 psi. Had lots of air from fill on trip in hole. 01:00 - 01:30 0.50 STWHIP P PROD1 Continued circulating until the air was circulated out of the system. 01:30 - 02:00 0.50 STWHIP P PROD1 Dropped steel ball to close PBL sub. Did not see shear out when ball hit. Ran in hole and tagged up on whipstock. Pump pressure increased 100 psi indicating sleeve on PBL closed. 02:00 - 03:30 1.50 STWHIP P PROD1 Worked on #1 pump -Lost prime. Recorded SPRs on both pumps. 03:30 - 10:30 7.00 STWHIP P PROD1 Milled from 9675'-9687'. Top of window 9675' Bottom of window at 9682'. Milled 5' of open hole below bottom of window. Shut down and picked up a single. Milled formation from 9687'-9689' and gas began breaking out at surface. Shut down pump and shut in well. Recorded 8 bbl pit gain. Recorded 375 psi drill pipe pressure and 400 psi casing pressure. 10:30 - 14:30 4.00 STWHIP N DPRB PROD1 Start circulating with drillers method holding 1700 psi on drill pipe (1200 spr @30 spm plus 375 psi shut in drill pipe pressure plus 125 psi safety margin). Casing pressure approximately 500 psi. Circulated 288 strokes (13 bbls) with no returns. Shut down pump and shut in well to confirm pressures. Opened choke bleed pressure to confirm and insure correct drill pipe and casing pressure. SIDPP 325 psi SICP 250 psi. Restarted circulation using driller method holding 1700 psi drill pressue. Pumped and additional 219 stroke for a total of 507 strokes (22.8 bbls) before gaining returns. Pumped a total of 2600 strokes (117 bbls-annular volume 101 bbls). Final circulating pressure 1700 psi on drill pipe and 225 psi on casing. Shut well in. Bled off excess pressure on drill pipe through fill up line. Opened float with float to confirm drill pipe pressure. Shut in drill pipe pressure 340 psi. 14:30 - 00:00 9.501 STWHIP N DPRB PROD1 Circulating drillers method while waiting on kill mud to maintain bottom hole pressure and prevent freeze up of mud. 2/24/2001 00:00 - 00:30 0.50 STWHIP N DPRB PROD1 Continued circulating drilers method while waiting on kill mud to maintain bottom hole pressure and prevent freeze up of mud. 00:30 - 01:00 0.50 STWHIP N DPRB PROD1 Held PJSM on well kill operation. Discussed job assignments Printed: 5/7/2001 3:08:33 PM .. BP EXPLORATION Page 3 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: Date From - To Hours Activity Code NPT. Phase Description of Operations 2/24/2001 00:30- 01:00 0.50 STWHIP N DPRB PROD1 and pressure schedules. 01:00 - 03:30 2.50 STWHIP N DPRB PROD1 Circulated 10.3 ppg kill weight mud in well using drill pipe pressure schedule. Initial drill pipe pressure 1540 psi and final drill pipe pressure 1330 psi with kill mud at mill. Held 1450 psi drill pipe pressure until 10.3 ppg mud at surface. Final circulating pressure 1450 psi with choke full open. 03:30 - 04:00 0.50 STWHIP N ' DPRB PROD1 Shut down pump and shut in well on choke. Monitoring for pressure on drill pipe and casing. No pressure increase. Open choke and checked for flow. No flow. Opened rams and check for flow. No flow. 04:00 - 05:00 1.00 STWHIP N DPRB PROD1 Picked up on string with no overpull. Pick up weight 115K. Pulled up above whipstock. Blow down choke manifold and all choke lines. Circulated bottoms up. Leveled out mud making sure no Iow spots. Moved drill string slow in 7" casing while circulating. Circulated 51 spin (2.3 bpm) at 2300 psi. Pumped a total of 2600 strokes. Shut down and check flow. No flow. 05:00 - 05:30 0.50 STWHIP N DPRB PROD1 Take SPRs #1 pump (4" liners) 30 spm 1300 psi and 40 spm at 1790 psi. #2 pump (5" liners) 20 spin 1310 psi and 30 spin at 2100 psi. 05:30 - 06:30 1.00 STWHIP P PROD1 Milled formation from 9689'-9693'. Milling with 55 spin (2.5 bpm) at 2500 psi. PU weight 115K SO weight 110K. Worked through window several times to assure window was clean. 06:30 - 07:30 1.00 STWHIP P PROD1 Pulled above whipstock and circulated bottoms up. 60 spm (2.7 bpm) at 2200 psi. Monitor well for 30 minutes. No flow. 07:30 - 08:30 1.00 STWHIP P PROD1 Pulled 3 stands of drill pipe without pumps to bottom of cut-off tubing tail at 9327'. 08:30 - 09:00 0.50 STWHIP N RREP PROD1 Working on topdrive hydraulic breakout. 09:00 - 10:00 1.00 STWHIP P PROD1 Back reamed through bottom of cut-off tubing tail at 9327'. Ran back in hole to bottom. Tag bottom with pump on 10:00 - 12:30 2.50 STWHIP; P PROD1 Drop vinyl ball and opened PBL sub. Circulated bottoms up. Gas cut mud to surface. Breaking out in bell nipple. No pit gain. Circulated 2 bottoms up and gas dropped out of mud. Checked flow-negative. 12:30- 13:00 0.50 STWHIP N RREP PROD1 working on top drive hydraulic breakout. 13:00 - 15:00 2.00 STWHIP P PROD1 Pump out of the hole with 5 stands of 2 3/8" dp at 20spm @ 800 psi - clear floor - lay down mud buckets - r/u power tongs - observe well after 45 mins well stopped flowing. 15:00 - 16:00 1.00 STWHIP P PROD1 RIH to 9655' break circ and take SPR's #1 30spm 1300, 40spm 1600 #2 20spm 1400, 30spm 1750 16:00 - 19:30 3.50 STWHIP P PROD1 circ bottoms up - gas cut mud to surface - cut mud weight to Printed: 5/7/2001 3:08:33 PM BP EXPLORATION Page 4 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28AJO-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYEN Rig Release: Rig Name: DOYEN 15 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations, 2/24/2001 16:00 - 19:30 3.50 STWHIP P PROD1 9.4 by mud check with regular mud scales. No pit gain circ and cond mud. 19:30 - 23:00 3.50 STWHIP P PROD1 PJSM on mixing sodium bromide -circ raise mud weight to 10.5 for trip. Volume to be raised 150 bbls on surface and hole volume 135 total 285 bbls. 23:00 - 23:30 0.50 STWHIP P PROD1 Flow check well, no flow 23:30 - 00:00 0.50 STWHIP P PROD1 PJSM - tripping -Re establish circ- pump out - 50 stks 1900 psi - 3 rains per stand - pull 5 stds 2/25/2001 00:00 - 00:00 24.00 STWHIP P PROD1 Pumping out of hole at 50 spm for the first 5 stands at 3 minutes per stand. Decreased pump rate to 30 spm at 1000 psi while pulling out of the hole at 3 minutes per stand, checking fill every 5 stands. 2/26/2001 00:00 - 00:30 0.50 STWHIP P PROD1 Finished pumping out of hole at 30 spm and 3 minutes per stand. Checking fill volumes every 5 stands. 00:30 - 01:00 0.50 STWHIP P PROD1 Flow check well and blow down top drive and stand pipe. 01:00 - 01:30 0.50 STWHIP P PROD1 Break and lay down milling assembly. String reamer guaged 3.72" OD and 3.71" OD on guage of mill. Overall mill and reamer in very good shape. 01:30 - 04:00 2.50 DRILL P PROD1 Picked up 69 joints of 2-3/8" drill pipe from pipe rack and ran in hole open ended. Rabbited each joint. 04:00 - 04:30 0.50 DRILL P PROD1 Circulated through 2-3/8" drill pipe to clear debris. 04:30 - 05:00 0.50 DRILL P PROD1 Flow check well and blow down top drive and stand pipe. 05:00 - 06:00 1.00 DRILL P PROD1 Pulled out of hole at 2 minutes per joint and racking drill pipe in derrick. 06:00 - 08:00 2.00 DRILL N RREP PROD1 Discovered leak in rubber boot on flowline. Replaced boot and checked remaining boots. 08:00 - 10:00 2.00 DRILL P PROD1 Finished pulling out of hole with 2-3/8" drill pipe and racked in derrick. Pulled drill pipe at 2 minutes per stand. 10:00 - 11:00 1.00 DRILL P PROD1 Cleared floor and calibrate Totco and MWD computers. 11:00 - 16:00 5.00 DRILL P PROD1 ;Picked up drilling BHA #1: 3.70" PDC STR 335 bit, 3-1/8" motor, FS, NM Pony collar, NMXO sub, MWD, NMDC, PWD, NMXOs, NM flex collar, and crossover to drill pipe. 16:00 - 00:00 8.00 DRILL P PROD1 PJSM tripping - RIH with 2 3/8" dp - test MWD at 1630' - con't RIH to 7289' test MWD, filling pipe every 25 stands - Con't RIH to 9640' Filling every 25 stands. 212712001 00:00 - 01:30 1.50 DRILL P PROD1 PJSM-circulating out gas on bottoms up. Break circulation. Circulate bottoms up/Gas cut mud from 10.5 ppg to 9.4 ppg. Maxiumum gas units with bottoms up 3640 units (normal Printed: 51712001 3:08:33 PM BP EXPLORATION Page 5 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: Date From - To Hours Activity Code NPT Phase, Description of Operations 2/27/2001 00:00 - 01:30 1.50 DRILL P PROD1 background gas 24 units). Working pipe slowly while circulating at 50 spm at 2700 psi. Took SPR #1 30 spin 1350 psi 40 spin 1900 psi #2 pump 20 spin 1300 psi 30 spin 2200 psi. 01:30 - 03:00 1.50 DRILL P PROD1 Attempting to establish MWD detection. Weak signal. Added de-foamer and increased pump strokes from 55 spm to 64 spin and finally signal came on good and strong. Orient tool face. 03:00 - 04:00 1.00 DRILL P PROD1 Directional drill from 9693'-9702 oriented 10 degrees to the left. WOB 4K, PU 125K, SO 120K, Torque undeterminable. 3500 psi drilling 3300 psi off bottom. 1 hour sliding at 10 degrees to the left. Total drilling hours 1.. 04:00 - 04:30 0.50 DRILL N RREP PROD1 Noticed boot on flowline with slow drip. Worked on stopping leak. Will change out with 36" dresser sleeve presently ordered. Monitoring for leaks frequently. 04:30 - 08:00 3.50 DRILL P PROD1 Directional drill 9702'-9727' oriented 10 degres to the left. WOB 4K, PU 125K, SO 120K, Torque undeterminable. 3500 psi drilling 3300 psi off bottom.2.5 hour sliding. Total drilling hours 3.5 sliding. 08:00 - 09:00 1.00 DRILL N DFAL PROD1 MWD pulsing problems. Attempt to reestablish pusling. No success. MWD failed. 09:00 - 10:00 1.00 DRILL N DFAL PROD1 Circulated hole clean and flow checked well-negative. 10:00- 13:30 3.50 DRILL N DFAL PROD1 Pumped out of hole at 3 minutes per stand pumping 30 spm. Monitor fill every 5 stands. Pulled 19 stands and began losing mud over shakers. 13:30 - 14:30 1.00 DRILL N DFAL PROD1 Flow check well while install 180 mesh screens on shakers. 14:30 - 00:00 9.50 DRILL N DFAL PROD1 Continued pumping out of hole to 2167' (80 stds out) at 3 minutes per stand and pumping 30 spin. Checking hole fill every 5 stands. 2/28/2001 00:00 - 03:00 3.00 DRILL N DFAL PROD1 Finished pumping out of hole at 30 strokes per minutes. Did not pump out of hole from 1600' to 1400' due to bad spot in tubing. Checked fill every 5 stands. 03:00 - 05:00 2.00 DRILL N DFAL PROD1 Laid down BHA and downloading MWD. 05:00 - 06:00 1.00 DRILL P PROD1 Pulled wear ring and installed test plug. 06:00- 18:00 12.00 DRILL P PROD1 Pressure test BOPE. Witnessed by John Crisp of AOGCC. Test to 250/5000 rams, valves, choke manifold and sting tools. Test annular to 250/3500. No failures. 18:00 - 18:30 0.50 DRILL P PROD1 Pull test plug and install wear ring. 18:30 - 22:30 4.00 DRILL . N DFAL PROD1 Pick up BHA #3. RR bit #1. Install and test MWD and LWD and PWD. PU PBL sub. Surface test ok. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 Trip in hole filling every 25 stands. Run 1 min per stand per surge program. Shallow test MWD at 2551'. 3/1/2001 00:00 - 04:30 4.50 DRILL N DFAL PROD1 Finished running in hole at 1 rain/stand to 9645'. Continued filling the drill pipe every 25 stands. Printed: 517/2001 3:08:33 PM BP EXPLORATION Page 6 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 3/1/2001 04:30 - 05:30 1.001 DRILL N DFAL PROD1 Circulated bottoms up. Worked pipe with circulating bottoms up. 5640 units of gas with bottoms up and mud cut to 9.8 ppg. Circulated gas out of hole. 05:30 - 06:30 1.00 DRILL N DFAL PROD1 Oriented toolface 40 left and ran in hole to bottom. 06:30 - 00:00 17.50 DRILL P PROD1 Directional drill 9727' to 9844'. Oriented for build and left hand turn. 15' surveys as required by program. Assembly appears to be operating adequately. We are still too close to the old hole for accurate azimuth. Last survey= 18.58 degrees at 9808'. ART=0 hrs, AST=I 1.2 hrs, TDT=I 1.2 hrs, PU=125K, SO=120K, GPM=95 gpm, rpm=0, motor rpm=168, PSI off bottom= 2830, on bottom= 2930. 3/2/2001 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill 9844 to 9971'. ART= 0.5 hrs, AST= 11.5, ADT= 12 hrs. Torque Off bottom= 1500, On bottom= 1600, PU= 125K, SO= 120K, RW= 123K. 95 gpm, 144 rpm, Standpipe= 3150 psi, On bottom= 3300 psi. DLS-- 19 deg/100'. Average ROP= 10.58 3/3/2001 00:00 - 11:00 11.00 DRILL P PROD1 Directional drill from 9971'-10040'. Sliding to build angle and turn according to directional well plan. PU 125K SO 120K. MW in 10.4+ MW out 10.3. Adding bromide to increase MW to 10.5 ppg. Lost prime on mud pump. Picked up 20' with pump off to switch pumps. Attempted to drill with pump #2. Unable to drill ahead due to poor MWD signals. Clean suction screen on pump and switched back to pump #1. Started to drill ahead and gas began breaking out at surface. 11:00 - 14:00 3.00 DRILL N DPRB PROD1 Shut well in at 11:04. SIDP 120 psi SlCP 300 psi. Circulated out using Drillers method. Held 2000 psi (1800 psi SPR plus 200 psi safety factor) on drill pipe and circulated out at 30 spm. Circulated complete hole volume plus 600 strokes. MW 10.5 ppg in and 10.3+ out. Shut down pumps and shut in well. DP pressure 0 Casing pressure 0. Open choke to check for flow-no flow. Opened well and check for flow no flow. Picked up 5' and pipe free. 14:00 - 15:30 1.50 DRILL N DPRB PROD1 Circulated bottoms up. Bottoms up gas 3450 units of gas. MW 10.5 ppg in and 10.4+ out. Started weighting up to 10.7 ppg. 15:30 - 18:00 2.50 DRILL P PROD1 Directional drill 10,040' to 10,068'. 18:00 - 21:00 3.00 DRILL P PROD1 Work pipe to clean hole. Finally rotate and discover pressure problems was coal packing off. 21:00 - 00:00 3.00 DRILL ~P PROD1 Directional drill 10,068 to 10,095'. Some problems getting MWD information because of coal packoff. (Total today)AST= 8.8 hrs, ART= 0 hrs, ADT= 8.2 hrs. Torque on bottom= 1700, off bottom= 1600, PU= 130K, SO= 124K, RW-- 126K, GPM= 95, WOB=3-6K, Motor rpm= 144, Off bottom 3450 psi, on bottom 2550 psi. 3/4/2001 00:00 - 06:30 6.50 DRILL P PROD1 Directional drill 10,095 to 10126'. Torque on bottom= 1700, off bottom= 1600, PU= 130K, SO= 124K, RW= 126K, GPM= 95, WOB=3-6K, Motor rpm= 144, Off bottom 3450 psi, on bottom 13550 psi. MWD failed. Changed flow rates attempting to start 'MWD without success. Printed: 5/7/2001 3:08:3:3 PM BP EXPLORATION Page 7 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: . Date From - To Hours ActivityCode NPT Phase Description of Operations 3/4/2001 00:00 - 06:30 6.50 DRILL P PROD1 06:30 - 09:00 2.50 DRILL N DFAL PROD1 Circulated high vis weighted sweep around. Circulated out very fine coal across shaker. 09:00 - 10:30 1.50 DRILL N DFAL PROD1 Checked flow-negative. Pumped out of hole with 30 spin and pulling 3 minutes per stand to 9722'. Dropped vinyl ball and circulated down and opened PBL sub. Pumped out above whipstock at 9675'. 10:30 - 12:30 2.00 DRILL N DFAL PROD1 Pumped around a high vis weighted sweep and began getting gas with bottoms up. Maximum gas 3450 units. 12:30 - 14:00 1.50 DRILL N DFAL PROD1 Pumped out of hole to 8800'. 30 spin and 3 minutes per stand. 14:00 - 17:00 3.00 DRILL P PROD1 Changed saver sub. 17:00 - 00:00 7.00 DRILL N DFAL PROD1 Checked flow-negative. Pumped out of hole with 30 spm and pulling 3 minutes per stand 9722' to 6250'. Circulated through PBL sub. Observing well for flow. Negative. Fill volumes Okay. Concurrently tested choke manifold to 250 Iow and 5000 high. 3/512001 00:00 - 09:00 9.00 DRILL N DFAL PROD1 Finished pumping out of hole with 2-3~8" drill pipe. Pulling out at 3 minutes I stand and pumping 30 spm through the PBL sub. 09:00 - 12:00 3.00= DRILL N DFAL PROD1 Pulled out of hole and laid down MWD. Found MWD shroud above turbine plugged with nutplug, coal and crystalized polymer. 12:00 - 13:00 1.00 DRILL P PROD1 Rigged floor to test. Pulled wear bushing and set test plug. Filled stack with water. 13:00 - 18:00 5.00 DRILL P PROD1 Tested all rams and valves to 250 psi Iow for 5 minutes and 15000 psi high for 10 minutes. Tested annular preventor 250 psi Iow for 5 minutes and 3500 psi high for 10 minutes. All test were pressure tested with water and recorded. Accumulator test was conducted and passed. Right to witness test was waived by AOGCC Inspector, John Crisp. 18:00 - 23:30 5.50 DRILL N DFAL PROD1 Pick up BHA ~4. Adjust motor and bit, PU and load MWDILWD. Test same. 23:30 - 00:00 0.50 DRILL N DFAL PROD1 Run in hole at 1 minute per stand to avoid surge. Fill every 25 stands. 3/6/2001 00:00 - 05:30 5.50 DRILL N DFAL PROD1 Continued to run in hole to 9,675'. Filled drill pipe every 25 stands. 05:30 - 07:00 1.50 DRILL N DFAL PROD1 Circulated bottoms up above whipstock, Oriented tool face to 40L. 07:00 - 10:00 3.00 DRILL N DFAL PROD1 Ran in hole from 9,675' to 10,035'. Worked through tight spots at 9,925' and 10,076'. Hole packed off at 10,035'. 10:00 - 13:00 3.00 DRILL N DFAL PROD1 Pumped and circulated around sweep. Worked pipe from 10,004' to 10,035'. Rotated and worked pipe while pumping sweep. Printed: 5/712001 3:08:33 PM BP EXPLORATION Page 8 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 3/8/2001 13:00 - 14:00 1.00 DRILL N DFAL PROD1 Washed down through tight spot at 10,076'. Tagged bottom at 10,124'. 14:00 - 00:00 10.00 DRILL P PROD1 Oriented and directionally drilled by sliding from 10,124' to 10,215'. WOB 1,500~. Torque on bottom= 1500, off bottom= 1400, P/U W= 130K, S/O W= 124K, RT W= 126K, Motor rpm= 144, Pump rate 85 gpm, SPP 3,000 psi,Off bottom 2,900 psi, on bottom 3,000 psi. 3/7/2001 00:00 - 01:00 1.00 DRILL P PROD1 Directionally drilled by sliding from 10,215' to 10,223'. WOB 1,500#. Torque on bottom= 1500, off bottom= 1400, P/U W= 130K, S/O W= 124K, RTW-- 126K, Motor rpm= 144, Pump rate 85 gpm, SPP 3,000 psi.,Off bottom 2,900 psi, on bottom 3,000 psi. Angle dropped from 45.2 deg @ 10,123' to 42.0 deg @ 10,187'. Suspected tool face knocked out of alignment with scribe line by 50 deg Left. Attempted to build angle compensating for 50 deg. Left error. Maximum achieved doglegs 10 deg / 100'. Doglegs needed 25 deg - 29 deg / 100' to land as per program. Decision made to POOH and change bend in motor. 01:00 - 01:30 0.50 DRILL P PROD1 Pumped up survey to verify directional problems. 01:30 - 03:00 1.50 DRILL N DFAL PROD1 Pumped and circulated around weighted Barafiber sweep. Minimal cuttings recovered. Pump rate 85 gpm, SPP 3,000 psi. 03:00 - 04:00 1.00 DRILL N DFAL PROD1 Back reamed and pumped out of open hole to 9690' at 40 spin, 1 rain / stand. No hole problems. Maximum Torque 1,200 fi/lbs 04:00 - 05:00 1.00 DRILL N DFAL PROD1 Flow checked well. Well static. 05:00 - 06:30 1.50 DRILL N DFAL PROD1 RIH without pumps to 9,907'. Worked through bridge from 9,907' to 9,950'. Washed down without rotating through coal at 10,050' to 10,070'. Washed to bottom, no problems. 06:30 - 09:00 2.50, DRILL N DFAL PROD1 Pumped and circulate around weighted barafiber sweep. Pump rate 85 gpm, SPP 3,000. Circulated until returns over shaker were clean. Maximum trip gas 1800 units. 09:00 - 11:30 2.50 DRILL N DFAL :PROD1 Pumped out of the hole from 10,223' to above whipstock at 9,675'. Checked hole fill and flow checked every stand. Well static. Maximum drag 10,000~. Pump rate 56 gpm, SPP 1,200 psi. Trip rate 3 min / stand. 11:30- 13:00 1.50 DRILL N DFAL PROD1 Circulated bottoms up. Pump rate 85 gpm, SPP 2,400 psi. 13:00- 13:30 0.50 DRILL N DFAL PROD1 Serviced rig. 13:30 - 14:30 1.00 DRILL N DFAL PROD1 Pumped out of the hole from 9,675' to above whipstock at 9,311'. Pump rate 56 gpm, SPP 1,200 psi. Trip rate 3 min / stand. Top Drive out of alignment, trouble making up saversub to drill pipe connections. 14:30- 18:00 3.50 DRILL N RREP PROD1 Worked on Top Drive alignment cylinders. 18:00 - 23:30 5.50 DRILL N DFAL PROD1 Pumped out of the hole from 9,311' to above whipstock at 7,545'. Pump rate 58 gpm, SPP 1,200 psi. Trip rate 3 rain / stand. 23:30- 00:00 0.50 DRILL N DFAL PROD1 Changed out saver sub. 3/8/2001 00:00 - 01:30 1.50 DRILL P PROD1 :Finished changing out the Saver sub on the top drive. Executed a different method and saved 1 hour. 01:30 - 10:00 8.50 DRILL N DFAL PROD1 Pumped out of the hole from 7,545' to 4,033'. Pump rate 56 gpm, SPP 1,200 psi. Trip rate 3 min / stand. Flow checked well every 5 stands. Well static. Top drive not working properly. Printed: 5/7/2001 3:08:33 PM BP EXPLORATION Page 9 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 3/8/2001 01:30 - 10:00 8.50 DRILL N DFAL PROD1 Shut down to repair at 4033'. 10:00- 17:00 7.00 DRILL N RREP PROD1 Repaired top drive. 17:00 - 23:00 6.00 DRILL N DFAL PROD1 Pumped out of the hole from 4,033' to Surface. Pump rate 56 gpm, SPP 1,000 psi. Trip rate 3 min / stand. Dropped ball and opened PBL sub at 1,750'. Flow checked well every 5 stands. Well static. 23:00 - 23:30 0.50 DRILL N DFAL PROD1 Broke out and land down BHA and Bit. Note: Found tool face to be 65 degrees left of previous alignment. 23:30 - 00:00 0.50 DRILL N DFAL PROD1 Sperry-Sun Down loaded data from MWD. Blind rams closed, monitoring well through choke. Well static. Note: Held D1 drill - 1 rain 30 sec Held H2S drill - 2 min 30 sec 3/9/2001 00:00 - 02:00 2.00 DRILL N DFAL PROD1 'Finished down loading LWD data and laid down remaining BHA. 02:00- 06:00 4.00 DRILL N RREP PROD1 Worked on top drive. 06:00 - 10:00 4.00 DRILL N DFAL PROD1 M / U HTC STR335 bit wi 4 x 12 jets onto motor. Adjusted bent housing on motor to 2.83 degree and oriented to MWD. 20.63 degree offset. M / U PBL sub on one stand and RIH. MWD at 210'. 10:00 - 10:30 0.50 DRILL N DFAL PROD1 Tested MWD with 45 spm, good pulse. MWD OK. 10:30 - 11:00 0.50 DRILL N DFAL PROD1 Serviced rig. 11:00 - 19:30 8.50 DRILL N DFAL PROD1 RIH to 9,599', rate 1 minute per stand. Filled the string every 25 stands. Laid down 10 joints with face damage on box. 19:30 - 20:00 0.50 DRILL N DPRB PROD1 Circulated Bottoms up at 9,599', pump rate 75 gpm, SPP 1875 psi. Flow rate increased from 10% to 30%. Shut down pumps, well flowing, shut in well. SICP - 300 psi, SIDDP 75 psi. 20:00 - 20:30 0.50 DRILL N DPRB PROD1 Monitored shut in pressures, held PJSM prior to circulating well. 20:30 - 22:00 1.50 DRILL N DPRB PROD1 Circulated out using Drillers method. Held 1,500 psi (1275 psi SPR plus 225 psi safety factor) on drill pipe and circulated out at 30 spin. Circulated complete hole volume plus 500 strokes. Maximum gas 2,200 units, Average gas 1,300 units. MW 10.7 ppg in and 10.7 out. Shut down pumps and shut in well. DP pressure 0 Casing pressure 0. Open choke to check for flow-no flow. Opened well and check for flow. Well static. 22:00 - 22:30 0.50 DRILL N DPRB PROD1 Opened Rams and observed well. Well static. Circulated well at 75 gpm, SPP 1,875 psi. Flow increased from 10% to 25%, Gas increased from 1,500 units to 4,700 units. Shut down pumps and shut in well. SICP - 0, SIDDP - 0. 22:30 - 23:30 1.00 DRILL N DPRB PROD1 Circulated out using Drillers method. Held 1,875 psi, SPR, on drill pipe and circulated out at 40 spm. Circulated complete hole volume plus 700 strokes. Maximum gas 3,200 units, Average gas 1,200 units. MW 10.7 ppg in and 10.7 out. Shut down pumps and shut in well. DP pressure 0 Casing pressure 0. Open choke to check for flow-no flow. Opened well and check for flow. Well static. 23:30 - 00:00 0.50 DRILL N DFAL PROD1 RIH to 9,722'. Washed down from 9,722' to 9,922°. Hit bridge at 9,922' Note: Held D2 drill, 1 min. Printed: 5/7/2001 3:08:33 PM BP EXPLORATION Page .10 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: · . Date From - To Hours Activity COde NPT Phase Description of Operations .. 3/10/2001 00:00 - 02:00 2.00 DRILL N DFAL PROD1 Attempted to wash through bridge at 9,922'. Varied pump rate parameters from 30 spm up to 50 spin, Varied wash down rates from 15 sec / ft to 1 rain / ft. No progress. 02:00 - 02:30 0.50 DRILL N STUC PROD1 Well packed off and stuck drill string at 9,930'. No circulation. Worked pipe with 30,000 lbs over pull and 1,000 ft / lbs of torque. Worked pipe free and regained circulation. 02:30 - 03:30 1.00 DRILL N STUC PROD1 Circulated bottoms up. Maximum gas 4,700 units, average gas 2,000 units. 03:30 - 05:00 1.50 DRILL N STUC PROD1 Washed back down to 9,922'. Attempted to wash through bridge at 9,922'. Varied pump rate parameters from 30 spin up to 50 spin, Varied wash down rates from 15 sec / ff to 1 rain / ff. No progress. 05:00 - 05:30 0.50 DRILL N STUC PROD1 Well packed off and stuck drill string at 9,930'. No circulation. Worked pipe with 30,000 lbs over pull and 1,000 ft / lbs of torque. Worked pipe up to 9,912' with 30,000 lbs drag. No pipe movement above 9,912'. 05:30 - 10:00 4.50 DRILL N STUC PROD1 Worked stuck pipe. Pulled 50,000 lbs over and slacked off to !10,000 lbs under, put 2,500 ft / lbs torque in string while working pipe. No progress. 10:00 - 12:00 2.00 DRILL N STUC PROD1 Worked stuck pipe. Pulled 50,000 lbs over and slacked off to 10,000 lbs under. Worked all torque out of drill string. Stacked all available weight on bottom on drill string. Top Drive weight 78,000 lbs. Worked pipe to neutral weight every 15 minutes. 12:00 - 14:00 2.00 DRILL N STUC PROD1 Worked stuck pipe. Worked string from 125,000 lbs to 225,000 lbs. No movement. 14:00 - 16:00 2.00 DRILL N STUC PROD1 Worked string with 4,000 ft / lbs torque. A total 15 rounds. Worked string from 95,000 lbs to 190,000 lbs. No progress. 16:00 - 17:00 1.00 DRILL N STUC 'PROD1 Dropped Red Steel Ball to open PBL sub. Waited one hour for ball to reach PBL sub. 17:00 - 20:00 3.00 DRILL N STUC PROD1 Attempted to open PBL sub. Pressured up and bleed off ~mssure in attempt to seat ball and open the sub. Worked the drill string from 100,000 lbs to 200,000 lbs in attempt to help seat the ball and loosen the packoff. Unable to regain circulation through PBL sub. 20:00- 20:30 0.50 DRILL N STUC PROD1 Held pro-job safety meeting concerning rigging up Schlumberger and running free point tool. · 20:30 - 23:30 3.00 DRILL N STUC PROD1 Rigged up Schlumberger sheave, side entry sub and cross overs. Made up Schlumberger free point tool and rigged to run down hole. 23:30 - 00:00 0.50 DRILL N STUC PROD1 Ran in hole with Schlumberger free point tool. Note: Held Fire Drill - 1 rain 55 sec. 3/11/2001 00:00 - 01:00 1.00 FISH N STUC PROD1 Ran in hole with free point tool on Schlumberger wire line. Counted collars on trip in to correlate on depth. Free Point tool TD 9,787', Top of PBL 9,790' 01:00 - 02:30 1.50 FISH N 'STUC PROD1 Ran free point measurements and the following depths with 20,000# stretch: Depth Free 9,780' 0.0% 9,750' 2.0% 9,726' 1.5% 9,721' 0.5% 9,700' 65% Printed: 5/7/2001 3:08:33 PM · BP EXPLORATION Page 11 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYEN Rig Release: Rig Name: DOYEN 15 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations' 3/11/2001 01:00 - 02:30 1.50 FISH N STUC PROD1 9,690' 75% Tool joint at 9,694' indicated free point to back off. 02:30 - 03:30 1.00 FISH N STUC PROD1 Pulled out of the hole with free point tool. Broke out and laid down same. 03:30 - 04:00 0.50 FISH N STUC PROD1 Held Safety meeting concerning the use of and running explosives for backing off. 04:00 - 05:00 1.00 FISH N STUC PROD1 Made up string shot and tool for back off. Radio silence and Job Hazard analysis. 05:00 - 05:30 0.50 FISH N STUC PROD1 RIH with string shot on wireline and got on depth. 05:30 - 06:30 1.00 FISH N STUC PROD1 Worked 2 left hand turns at a time into string for a total of 9 left hand turns. Positioned string shot on depth at 9,694'. Fired string shot and backed out at 9,694'. 06:30 - 09:00 2.50 FISH N STUC PROD1 Pulled out of the hole with string shot and wire line and R / D Schlumberger. 09:00 - 17:00 8.00 FISH N STUC PROD1 Circulated to clean and condition hole. Maximum gas 1,800 units. Pump rate 75 gallons / minute, SPP 1,600 psi. 17:00 - 20:00 3.00 TA N STUC ABAN Continued to circulate while rigging up Dowell to set Temporary ,Abandonment plug. Held Pre-Job Safety meeting. 20:00 - 21:00 1.00 TA N STUC ABAN Pumped 3.5 bbl lead water at 1.0 BPM at 850 psi. Mixed and pumped 17 bb115.8 ppg Class "G" cement with, .200 gal/sk antifoam, 0.450% bwoc dispersant, 0.190% bwoc retarder, 0.150% gal/sk gasblok stab, 2.00 gal/sk gasblok, 0.300 °,4 bwoc salt. Pumped cement at 1.5 BPM at 900 psi, finished pumping cement at 1.5 BPM at 600 psi. Pumped 1 bbl of tail water at 1.5 BPM at 550 psi. Displaced cement with 27 bbl of mud at the following rates: Pumped Rate Pressure 9.0 bbls 2.25 BPM 1,490 3si 18.0 bbls 2.25 BPM 1,525 psi 22.5 bbls 1.35 BPM 925 )si 27.0 bbls 1.35 BPM 1.050 psi Shut down pumps, plug balanced. Cement in place at 2045 hrs. 21:00 - 21:30 0.50 TA N STUC ABAN Rigged down lines and pulled out of the hole from 9,894' to 9,339'. A total of 4 stands. Rate - 7 rain / stand. Well static. 21:30 - 22:00 0.50 TA N STUC ABAN Circulated to clean hole. Pump rate 94 gpm, SPP 1,300 psi. Circulated out 14 bbl of cement contaminated mud. 22:00 - 00:00 2.00: TA N STUC ABAN Circulated hole while waiting on cement. 3/12/2001 00:00 - 07:00 7.00 TA N STUC ABAN Circulated and waited on cement at 9340'. Fish left in hole: Total length - 218'/from 9912 to 9694'. Components of fish: HTC STR335 PDC 3.70" BIT Sperry Sun 3-1/8" Sperry Drill Lobe 7/8 - 3.0 stg Non Mag Float Sub Non Mag XO Sub Sperry Sun DGWD SuperSlim MWD 2 - Flex Drill Collars ~XO Printed: 5/712001 3:08:33 PM BP EXPLORATION Page'.12 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: Date From - To 'Hours Activity Code NPT Phase Description of Operations 3/12/2001 00:00 - 07:00 7.00 TA N STUC ABAN PBL SUB 3 jts Nabors 2 3/8" Drill Pipe. 07:00 - 09:00 2.00 CEMT N STUC PROD1 Tagged cement plug at 9,342' with 30,000~, OK. R / U and tested cement plug to 2,000 psi for 30 minutes. Plug tested - OK. Blew down lines and rigged up to displace the well to Brine. Chuck Scheve of the AOGCC waived to witness tagging of the temporary abandonment plug. 09:00 - 10:30 1.50 TA N STUC ABAN Waited on Brine trucks to arrive and vacuum trucks to haul off mud. 10:30 - 13:30 3.00 TA N STUC ABAN Displaced well to 11.0 ppg Brine. Pump rate 95 gpm, SPP 1,300 psi. 13:30 - 21:00 7.50 TA N STUC ABAN POOH from 9,340' to surface. L / D 306 jts of 2-3/8" drill pipe. Note:Held Pre-Job Safety Meeting 21:00 - 22:30 1.50 TA N STUC ABAN RIH with 23 stands of drill pipe from derrick. 22:30 - 00:00 1.50 TA N I STUC ABAN POOH to 1,500', L / D 21 jts of 2-3/8" drill pipe. Prepared to Pump diesel for freeze protection. Note: Held D1 Drill - 1 min, 48 sec 3/13/2001 00:00 - 18:00 18.00 TA N STUC ABAN Waited on HB&R to pump diesel to freeze protect well. Drill Pipe in hole at 1500'. HB&R on SDI pad preparing wells for rig move to SDI 3-15 work over. 18:00 - 19:00 1.00 TA N STUC ABAN Pumped 18 bbls of diesel from HB&R truck down 2-3/8" x 4-1/2" annulus and allowed diesel to U-tube into drill pipe. 19:00 - 19:30 0.50 TA N STUC ABAN POOH from 1,500' to surface. L / D 48 jts of 2-3/8" drill pipe. Note: Held Pre-job Safety Meeting. 19:30 - 20:00 0.50 TA N STUC ABAN Pumped 10 bbls of diesel from HB&R truck down 4-1/2" tubing to top off after pulling drill pipe. Note: Total Diesel pumped down hole 28 bbls. 20:00 - 21:00 1.00 TA N STUC ABAN Wellsite maintenance ran and installed two way check valve. 21:00 - 22:00 1.00 TA N STUC ABAN N / D Bell Nipple and Flow line and prepped BOP stack for lifting. 22:00 - 00:00 2.00 TA N STUC ABAN Waited on wells to be shut - in prior to BOP heavy lift. 3/14/2001 00:00 - 16:00 16.00 TA N WAIT ABAN Waiting on Production Wells group to prepare wells for shut in on 2-26 and 2-30 for heavy lift of BOP's. 16:00 - 17:00 1.00 TA P ABAN Wells 2-26 and 2-30 shut - in. N / D BOP's, riser spool, 2-1/16" double valve, and test spool. Set back BOP°s on stump. Note: Held Pre-Job Safety Meeting - N / D BOP's and Riser 17:00 - 18:00 1.00 TA P ABAN N / D Riser from well. 18:00 - 20:30 2.50 TA P ABAN !N / U Dry Hole tree Note: Held Pre-Job Safety Meeting - N / U Tree 20:30 - 21:00 0.50 TA = ABAN Pressure tested Tree with glycol to 2,000 psi. OK. Note: Held Pre-Job Safety Meeting - Pressure Testing 21:00 - 00:00 3.00 TA = ABAN Well Secure - Housekeeping on Well house. Released Doyon Rig #15 @ 00:00 hrs - 3 / 14 / 01 = Printed: 51712001 3:08:33 PM BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Rig Name: DOYON 15 Rig Number: Date From - To Hours ActiVity Code NPT Phase Description of Operations 3/14/2001 21:00- 00:00 3.00 TA P ABAN Note: Held Spill Drill - 1 rnin, 22 sec. Printed: 5/7/2001 3:08:33 PM Endicott 2-28a/O-19 Sundry notice ~.. ;' ' ~ ('f" ~" Subject: Endicott 2-28alO-19 Sundry notice Date: Mon, 23 Apr 2001 20:46:22 -0500 From: "Hupp, Jeffrey L" <HuppJL@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Hubble, Terrie L" <HubbleTL@BP.com> Tom, Based on the present Endicott drilling plan, the 2-28A/O-19 well will not be drilled this May as original planned. Please cancel the outstanding sundry notice. The rig is presently moving to the Endicott 3-15/K-33 rig workover (11 days) followed by the 2-061J-22 rig workover (16 days). The rig will be shut down after the 2-06 Rig Workover. Jeff Hupp MB 447 Phone: (907) 564-5344 Cell: (907) 240-8057 Fax: (907) 564-5441 e-mail: huppjl@bp.com I of I 5/7102 4:34 PM A( STATE OF ALASKA ALASK _ .L AND GAS CONSERVATION COM 51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ~,~,OperatJo~ Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 10-404 Next required form 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 55.00' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Duck Island Unit/Endicott P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E, UM 2-28A/O-19 At top of productive interval 9. Permit Number / Approval No. 201-018 301-061 2310' SNL, 1931' WEL, SEC. 36, T12N, R16E, UM (Planned) 10. APl Number At effective depth 50- 02921847-01 11. Field and Pool At total depth Endicott Field / Endicott Pool 688' SNL, 1246' WEL, SEC. 36, T12N, R16E, UM 12. Present well condition summary Total depth: measured 10223 feet Plugs (measured) Whipstock at 9675'; Perf Abandonment Cement below true vertical 10087 feet Whipstock (03/01) Effective depth: measured 9675 feet Junk (measured) 3 Bowspring Leafs at 10448' true vertical 9627 feet 3-1/2" tailpipe cut and dropped to bottom (03/01) Casing Length Size Cemented MD TVD Structural Conductor 92' 30" Driven 131' 131' Surface 2465' 13-3/8" 3687 cu. ft. Permafrost 2504' 2503' Intermediate Production 9605' 9-5/8" 575 cu. ft. Class 'G' 9644' 9597' Liner 1144' 7" 517 cu. ft. Class 'G' 9383' - 9675' 9338' -9627' Perforation depth: measured None- Abandoned Perf's for Sidetrack Operation. R E C E IV E D true vertical None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 9339' Alaska 0il & Gas Cons. Conlmissior~ Anchorage Packers and SSSV (type and measured depth) 9-5/8" Baker 'SAB' packer at 9339'; 4-1/2" SSSV Landing Nipple at 1555' : 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run ~[,Oil [] Gas ~,~[,~r~-~'~ded Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the bi, st of my knowledge ~ , , Signed Son~~.,~.~ Title Technical Assistant Date Prepared By Name/Number: $ondra $tewman, 564-4750 ~orm 10-404 Rev. 06/15/88 ORIGINAL, Submit In Duplicate Bp.EXpLORATION Page 2 of 13 Operations Summa Report . . Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: . Date "=From - To.. 'Hours Task Sub ' Phase ' ':" .. ... 'DesCriptioni:'of Operations. . ' ' ..... ' Code · " . :'. ' '. '".:." 2/2012001 00:00 - 03:00 3.00 RIGU PRE Finishing moving rig on to 2-28A/O-19 and rigged up. 03:00 - 06:00 3.00 WHSUR PROD1 ACCEPTED RIG AT 0300 HRS 02-20-2001. Took mud into pits and continued preping rig for spud. 06:00 - 06:30 0.50 WHSUR PROD1 PJSM-on rigging up choke line, kill line and pulling BPV. 06:30 - 09:30 3.00 WHSUR PROD1 Made up choke line and kill line to rig mud line system. 09:30 - 12:00 2.50 WHSUR PROD1 Rigged up lubricator from Drill Site Maintenance. Pulled BPV and installed TWC. Pressure test TWC to 5000 psi for 5 minutes. 12:00 - 16:00 4.00 WHSUR PROD1 Nipple down tree in three pieces and laid out beaver slide. 16:00 - 00:00 8.00 BOPSUI~ PROD1 Nipple up (7 1/16 x 4 1116 xo spool - 7 1/16 5M BOPS - test spool - riser - pipe roms- mud cross- blind ram- pipe mm- annular). Attempt to hook up 4" flex steel choke hose. Will not make up, hose against cross beam on sub. 2/2112001 00:00 - 03:00 3.00 BOPSUI~ PROD1 Change out choke hose's from 4" steel flex to 4" rubber. 03:00 - 06:00 3.00 BOPSUF PROD1 Install bell nipple / flow line. Hook up hydmlic lines to stack. Change boot in air union. Install turnbuckles on stack. 06:00 - 18:00 12.00 BOPSUF PROD1 PJSM Testing BOPS - test blind roms, riser, test spool, XO, HCR valves - blind roms would not hold pressure - recylce roms - retest ok - Inside 2 1116 side valve on test spool grease tiffing on stem packing leaking - take off, repair, retest 300 - 5000 against TWC ok. Test Annular 300 - 3500 ok. - test upper roms, HCR valves 300 - 5000 ok. 18:00 - 22:00 4.00 BOPSUF PROD1 PJSM Testing BOPS - Test lower mm 300 - 5000 ok - test upper mm, choke valves 12, 13, 14, 15, 300 - 5000 ok -test upper roms, choke valves 5, 6, 10, 11,300 - 5000 ok - test upper rams, choke valves 1, 4, 7, 300 - 5000 ok - test upper rams, choke valves 2, 3, 8, 9, 300 - 5000 ok - Function test hyd choke, manual chokes. - Accumulator test - Accumulator pressure 3000 - shut pipe rams, hcr valves, annular - accumulator pressure 1900 - accumulator pumps on 200 psi 19 seconds, full pressure 3000, 104 seconds. Nitrogen back up pressure's 1- 2500, 2 - 2600, 3 - 2600, 4 - 2400. avg 2525. 22:00 - 00:00 2.00 BOPSUI: BARR PROD1 PJSM - Nipple down bell nipple to pull TWC - Pull test plug - Rig up lubicator to pull TWC. Attempt to pull TWC can not get on check. Both o-rings off test plug. Attempt fish o-rings out no success. 2/22/2001 00:00 - 02:00 2.00 BOPSUF BARR PROD1 Attempted to fish O-rings from test plug without success. Flushed TWC with water in attempted to clear debris from top of TWC. Attempt to pull TWC with no success. 02:00 - 03:00 1.00 BOPSUF',B^RR PROD1 Nipple down stack above adapter flange. Cleaned rubber and fine solid from top of TWC. Found ice plug above top of TWC. Thawed ice plug. Set stack back down and nippled up. 03:00 - 03:30 0.50 BOPSUFiBARR PROD1 Test stack against blind roms. 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. 03:30 - 04:00 0.50 BOPSUF PROD1 Pulled TWC with lubricator. Laid down TWC and lubricator. 04:00 - 08:00 4.00 BOPSUF PROD1 Finished testing IBOP, upper IBOP, and floor valves 250 psi Iow for 5 Printed: 4112/2001 4:12:40 PM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: Date · FrOm- To ,HoUrs Task Sub:' Phase' ' " ' DescriptiOn of operations . ,. Code. .. .. . ..... .' .. 2/22/2001 04:00 - 08:00 4,00 BOPSUF PROD1 minutes and 5000 psi high for 10 minutes. Nippled up bell nipple and flow line. 08:00 - 00:00 16.00 STWHIP PROD1 PJSM - Picking up dp - m/u milling assembly - pick up 2 3/8 dp rih - tag top whipstock at 9675' set 5k down twice to confirm tag up, 305 joints plus 15' in on joint # 306, 212312001 00:00 - 01:00 1.00 STWHIP PROD1 Displaced hole with 9.3 # QuikdrilI-N mud @ 60 spin @ 2400 psi, Had lots of air from fill on trip in hole, 01:00 - 01:30 0,50 STWHIP PROD1 Continued circulating until the air was circulated out of the system, 01:30 - 02:00 0.50 STWHIP PROD1 Dropped steel ball to close PBL sub, Did not see shear out when ball hit. Ran in hole and tagged up on whipstock, Pump pressure increased 100 psi indicating sleeve on PBL closed. 02:00 - 03:30 1.50 STWHIP PROD1 Worked on #1 pump -Lost prime. Recorded SPRs on both pumps. 03:30 - 10:30 7,00 STWHIP PROD1 Milled from 9675'-9687'. Top of window 9675' Bottom of window at 9682', Milled 5' of open hole below bottom of window, Shut down and picked up a single. Milled formation from 9687'-9689' and gas began breaking out at surface. Shut down pump and shut in well, Recorded 8 bbl pit gain, Recorded 375 psi drill pipe pressure and 400 psi casing pressure. 10:30 - 14:30 4,00 STWHIP WCON PROD1 Start circulating with drillers method holding 1700 psi on drill pipe (1200 spr @30 spin plus 375 psi shut in drill pipe pressure plus 125 psi safety margin), Casing pressure approximately 500 psi. Circulated 288 strokes (13 bbls) with no returns, Shut down pump and shut in well to confirm pressures, Opened choke bleed pressure to confirm and insure correct drill pipe and casing pressure, SIDPP 325 psi SICP 250 psi. Restarted circulation using driller method holding 1700 psi drill pressue. Pumped and additional 219 stroke for a total of 507 strokes (22,8 bbls) before gaining returns, Pumped a total of 2600 strokes (117 bbls-annular volume 101 bbls), Final circulating pressure 1700 psi on drill pipe and 225 psi on casing, Shut well in, Bled off excess pressure on drill pipe through fill up line, Opened float with float to confirm drill pipe pressure, Shut in drill pipe pressure 340 psi, 14:30 - 00:00 9.50 STWHIP WCON PROD1 Circulating drillers, method while waiting on kill mud to maintain bottom hole pressure and prevent freeze up of mud, 2/24/2001 00:00 - 00:30 0,50 STWHIP WCON PROD1 Continued circulating drilers method while waiting on kill mud to maintain bottom hole pressure and prevent freeze up of mud, 00:30 - 01:00 0.50 STWHIP WCON PROD1 Held PJSM on well kill operation. Discussed job assignments and i pressure schedules. 01:00 - 03:30 2.50 STWHIP WCON PROD1 Circulated 10,3 ppg kill weight mud in well using drill pipe pressure schedule. Initial drill pipe pressure 1540 psi and 'final drill pipe pressure 1330 psi with kill mud at mill, Held 1450 psi drill pipe pressure until 10,3 ppg mud at surface, Final circulating pressure 1450 psi with choke full open, 03:30 - 04:00 0,50 STWHIP WCON PROD1 Shut down pump and shut in well on choke. Monitoring for pressure on Printed: 4112/2001 4:12:,40 PM : Bp EXPLORATION, Page 4 of 13 Operations Summa Report . :. ... Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYEN Rig Release: Group: RIG Rig Name: DOYEN 15 Rig Number: ............. SUb' Phase' ':"=:' . . . . ' ". DeScriptiOn of Operations "" "":'" "' ...... Date' .. Frorn..~..To- Hours,' Task Code.. . . . . , .., . .. . .. . , 2124/2001 03:30 - 04:00 0.50~ STWHIP WCON PROD1 drill pipe and casing. No pressure increase. Open choke and checked for flow. No flow. Opened rams and check for flow. No flow. 04:00 - 05:00 1.00 STWHIP WCON PROD1 Picked up on string with no overpull. Pick up weight 115K. Pulled up above whipstock. Blow down choke manifold and all choke lines. Circulated bottoms up. Leveled out mud making sure no Iow spots. Moved drill string slow in 7" casing while circulating. Circulated 51 spm (2.3 bpm) at 2300 psi. Pumped a total of 2600 strokes. Shut down and check flow. No flow. 05:00 - 05:30 0.50 STWHIP WCON PROD1 Take SPRs #1 pump (4" liners) 30 spin 1300 psi and 40 spin at 1790 psi. #2 pump (5" liners) 20 spm 1310 psi and 30 spin at 2100 psi. 05:30 - 06:30 1.00 STWHIP PROD1 Milled formation from 9689'-9693'. Milling with 55 spm (2.5 bpm) at 2500 psi. PU weight 115K SO weight 110K. Worked through window several times to assure window was clean. 06:30 - 07:30 1.00 STWHIP PROD1 Pulled above whipstock and circulated bottoms up. 60 spm (2.7 bpm) at 2200 psi. Monitor well for 30 minutes. No flow. 07:30 - 08:30 1.00 STWHIP PROD1 Pulled 3 stands of drill pipe without pumps to bottom of cut-off tubing tail at 9327'. 08:30 - 09:00 0.50. STWHIP TDRV PROD1 Working on topdrive hydraulic breakout. 09:00 - 10:00 1.00 STWHIP PROD1 Back reamed through bottom of cut-off tubing tail at 9327'. Ran back in hole to bottom. Tag bottom with pump on 10:00 - 12:30 2.50 STWHIP PROD1 Drop vinyl ball and opened PBL sub. Circulated bottoms up. Gas cut mud to surface. Breaking out in bell nipple. No pit gain. Circulated 2 bottoms up and gas dropped out of mud. Checked flow-negative. 12:30 - 13:00 0.50 STWHIP TDRV PROD1 working on top drive hydraulic breakout. 13:00 - 15:00 2.00 STWHIP PROD1 Pump out of the hole with 5 stands of 2 3/8" dp at 20spm @ 800 psi - clear floor - lay down mud buckets - r/u power tongs - observe well after 45 mins well stopped flowing. 15:00 - 16:00 1.00 STWHIP PROD1 RIH to 9655' break circ and take SPR's #1 30spm 1300, 40spm 1600 #2 20spm 1400, 30spm 1750 16:00 - 19:30 3.50 STWHIP PROD1 circ bottoms up - gas cut mud to surface - cut mud weight to 9.4 by mud check with regular mud scales. No pit gain circ and cond mud. 19:30 - 23:00 3.50 STWHIP PROD1 PJSM on mixing sodium bromide - circ raise mud weight to 10.5 for trip. Volume to be raised 150 bbls on surface and hole volume 135 total 285 bbls. 23:00 - 23:30 0.50 STWHIP PROD1 Flow check well, no flow 23:30 - 00:00 0.50 STWHIP PROD1 PJSM - tripping -Re establish circ - pump out - 50 stks.1900 psi - 3 mins per stand - pull 5 stds 2/25/2001 00:00 - 00:00 24.00 STWHIP PROD1 Pumping out of hole at 50 spm for the first 5 stands at 3 minutes per stand. Decreased pump rate to 30 spm at 1000 psi while pulling out of Printed: 4112/2001 4:12:40 PM Bp. EXPLORATION Page '5 of 13 operations Summa Report : , . ~Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: . . .. . . '. , . 'Date,'." From'-T0" Hours Task Sub.' ,.Phase.. .~. . DescriPtion.of OperationS, .. ..... .. .,. .. Code ..,..., '....... .. . . ... '..: .. ~. 2125/2001 00:00 - 00:00 24.00 STWHIP PROD1 the hole at 3 minutes per stand, checking fill every 5 stands. 2/2612001 00:00 - 00:30 0.50 STWHIP PROD1 Finished pumping out of hole at 30 spin and 3 minutes per stand. Checking fill volumes every 5 stands. 00:30 - 01:00 0.50 STWHIP PROD1 Flow check well and blow down top drive and stand pipe. 01:00 - 01:30 0.50 STWHIP PROD1 Break and lay down milling assembly. String reamer guaged 3.72" OD and 3.71" OD on guage of mill. Overall mill and reamer in very good shape. 01:30 - 04:00 2.50 DRILL PROD1 Picked up 69 joints of 2-3/8" drill pipe from pipe rack and ran in hole open ended. Rabbited each joint. 04:00 - 04:30 0.50 DRILL PROD1 Circulated through 2-3/8" drill pipe to clear debris. 04:30 - 05:00 0.50 DRILL PROD1 Flow check well and blow down top drive and stand pipe. 05:00 - 06:00 1.00 DRILL PROD1 'Pulled out of hole at 2 minutes per joint and racking drill pipe in derrick. 06:00 - 08:00 2.00 DRILL CIRC PROD1 Discovered leak in rubber boot on flowline. Replaced boot and checked remaining boots. 08:00 - 10:00 2.00 DRILL PROD1 Finished pulling out of hole with 2-3/8" drill pipe and racked in derrick. Pulled drill pipe at 2 minutes per stand. 10:00 - 11:00 1.00 DRILL PROD1 Cleared floor and calibrate Totco and MWD computers. 11:00 - 16:00 5.00 DRILL PROD1 Picked up drilling BHA #1' 3.70" PDC STR 335 bit, 3-1/8" motor, FS, NM Pony collar, NMXO sub, MWD, NMDC, PWD, NMXOs, NM flex collar, and crossover to drill pipe. 16:00 - 00:00 8.00 DRILL PROD1 PJSM tripping - RIH with 2 318" dp - test MWD at 1630' - con't RIH to 7289' test MWD, filling pipe every 25 stands - Con't RIH to 9640' Filling every 25 stands. 2/27/2001 00:00 - 01:30 1.50 DRILL PROD1 PJSM-circulating out gas on bottoms up. Break circulation. Circulate bottoms up/Gas cut mud from 10.5 ppg to 9.4 ppg. Maxiumum gas units with bottoms up 3640 units (normal background gas 24 units). Working pipe slowly while circulating at 50 spm at 2700 psi. Took SPR #1 30 spm 1350 psi 40 spm 1900 psi #2 pump 20 spm 1300 psi 30 spin 2200 psi. 01:30 - 03:00 1.50 DRILL PROD1 Attempting to establish MWD detection. Weak signal. Added de-foamer and increased pump strokes from 55 spm to 64 spm and finally signal came on good and strong. Orient tool face. 03:00 - 04:00 1.00 DRILL PROD1 Directional drill from 9693'-9702 oriented 10 degrees to the left. WOB 4K, PU 125K, SO 120K, Torque undeterminable. 3500 psi drilling 3300 psi off bottom. I hour sliding at 10 degrees to the left. Total drilling hours 1. 04:00 - 04:30 0.501 DRILL ClRC PROD1 Noticed boot on flowline with slow drip. Worked on stopping leak. Will change out with 36" dresser sleeve presently ordered. Monitoring for Printed: 4112/2001 4:12:40PM , ( ( BP EXPLORATION Page'6 of 13 Operations. Summary Report '..' Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: ' '. ' ....... . ......... . ~' Date... 'From 'To .'Hours ..Task Sub Phase DeScriPtiOn ofOperations .. .... .' .. .... ...... · COde . .' . . .. .: . 2/27/2001 04:00 - 04:30 0.50 DRILL CIRC PROD1 leaks frequently. 04:30 - 08:00 3.50 DRILL PROD1 Directional drill 9702'-9727' oriented 10 degres to the left. WOB 4K, PU 125K, SO 120K, Torque undeterminable. 3500 psi drilling 3300 psi off bottom.2.5 hour sliding. Total drilling hours 3.5 sliding. 08:00 - 09:00 1.00 DRILL LMWD PROD1 MWD pulsing problems. Attempt to reestablish pusling. No success. MWD failed. 09:00 - 10:00 1.00 DRILL LMWD PROD1 Circulated hole clean and flow checked well-negative. 10:00 - 13:30 3.50 DRILL LMWD PROD1 Pumped out of hole at 3 minutes per stand pumping 30 spm. Monitor fill every 5 stands. Pulled 19 stands and began losing mud over shakers. 13:30 - 14:30 1.00 DRILL LMWD PROD1 Flow check well while install 180 mesh screens on shakers. 14:30 - 00:00 9.50 DRILL LMWD PROD1 iContinued pumping out of hole to 2167' (80 stds out) at 3 minutes per 'stand and pumping 30 spin. Checking hole fill every 5 stands. 2/28/2001 00:00 - 03:00 3.00 DRILL LMWD PROD1 Finished pumping out of hole at 30 strokes per minutes. Did not pump out of hole from 1600' to 1400' due to bad spot in tubing. Checked fill every 5 stands. 03:00 - 05:00 2.00 DRILL LMWD i PROD1 Laid down BHA and downloading MWD. 05:00 - 06:00 1.00 DRILL PROD1 Pulled wear ring and installed test plug. 06:00 - 18:00 12.00 DRILL PROD1 Pressure test BOPE. Witnessed by John Crisp of AOGCC. Test to 250/5000 rams, valves, choke manifold and sting tools. Test annular to 250/3500. No failures. 18:00 - 18:30 0.50 DRILL PROD1 Pull test plug and install wear ring. 18:30 - 22:30 4.00 DRILL LMWD PROD1 Pick up BHA #3. RR bit #1. Install and test MWD and LWD and PWD. PU PBL sub. Surface test ok. 22:30 - 00:00 1.50 DRILL LMWD PROD1 Trip in hole filling every 25 stands. Run 1 rain per stand per surge program. Shallow test MWD at 2551'. 3/1/2001 00:00 - 04:30 4.50 DRILL LMWD PROD1 Finished running in hole at 1 min/stand to 9645'. Continued filling the drill pipe every 25 stands. 04:30 - 05:30 1.00 DRILL LMWD PROD1 Circulated bottoms up. Worked pipe with circulating bottoms up. 5640 units of gas with bottoms up and mud cut to 9.8 ppg. Circulated gas out of hole. 05:30 - 06:30 1.00 DRILL LMWD PROD1 Oriented toolface 40 left and ran in hole to bottom. 06:30 - 00:00 17.50' DRILL PROD1 Directional drill 9727' to 9844'. Oriented for build and left hand turn. 15' surveys as required by program. Assembly appears to be operating adequately. We are still too close to the old hole for accurate azimuth. Last survey= 18.58 degrees at 9808'. ART=0 hrs, AST=11.2 hrs, TDT=11.2 hrs, PU=125K, SO=120K, GPM=95 gpm, rpm=0, motor rpm=168, PSI off bottom= 2830, on bottom= 2930. 3/2/2001 00:00 - 00:00 24.00 DRILL PROD1 Directional drill 9844 to 9971'. ART= 0.5 hrs, AST= 11.5, ADT= 12 hrs. Torque Off bottom= 1500, On bottom= 1600, PU= 125K, SO= 120K, RW= 123K. 95 gpm, 144 rpm, Standpipe= 3150 psi, On bottom= 3300 3si. DLS= 19 deg/100'. Average ROP= 10.58 3/3/2001 00:00 - 11:00 11.00 DRILL PROD1 Directional drill from 9971'-10040'. Sliding to build angle and turn according to directional well plan. PU 125K SO 120K. MW in 10.4+ MW Printed: 4/12/2001 4:12:40 PM ..', BP EXPLORATION Page,7 of'13 Operations sUmma . Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: . . ... . . ,Sub'. ~ Phase · 'DescriPtiOn of.Operations " . · Date. ' From,-'To. Hours .'.Task'. Code' . ' '... ... ' ., ,, , 3/3/2001 00:00 - 11:00 11.00 DRILL PROD1 out 10.3. Adding bromide to increase MW to 10.5 ppg. Lost prime on mud pump. Picked up 20' with pump off to switch pumps. Attempted to drill with pump #2. Unable to drill ahead due to poor MWD signals. Clean suction screen on pump and switched back to pump #1. Started to drill ahead and gas began breaking out at surface. 11:00 - 14:00 3.00 DRILL WCON PROD1 Shut well in at 11:04. SIDP 120 psi SICP 300 psi. Circulated out using Drillers method. Held 2000 psi (1800 psi SPR plus 200 psi safety factor) on drill pipe and circulated out at 30 spm. Circulated complete hole volume plus 600 strokes. MW 10.5 ppg in and 10.3+ out. Shut down pumps and shut in well. DP pressure 0 Casing pressure 0. Open choke to check for flow-no flow. Opened well and check for flow no flow. Picked up 5' and pipe free. 14:00 - 15:30 1.50 DRILL WCON PROD1 Circulated bottoms up. Bottoms up gas 3450 units of gas. MW 10.5 ppg in and 10.4+ out. Started weighting up to 10.7 ppg. 15:30 - 18:00 2.50 DRILL PROD1 Directional drill 10,040' to 10,068'. 18:00 - 21:00 3.00 DRILL PROD1 Work pipe to clean hole. Finally rotate and discover pressure problems was coal packing off. 21:00 - 00:00 3.00 DRILL PROD1 Directional drill 10,068 to 10,095'. Some problems getting MWD information because of coal packoff. (Total today)AST= 8.8 hrs, ART= 0 hrs, ADT= 8.2 hrs. Torque on bottom= 1700, off bottom= 1600, PU= 130K, SO-' 124K, RW= 126K, GPM= 95, WOB=3-6K, Motor rpm-- 144, Off bottom 3450 psi, on bottom 2550 psi. 3/4/2001 00:00 - 06:30 6.50 DRILL PROD1 Directional drill 10,095 to 10126'. Torque on bottom= 1700, off bottom= 1600, PU-- 130K, SO= 124K, RW-- 126K, GPM= 95, WOB=3-6K, Motor rpm-- 144, Off bottom 3450 psi, on bottom 3550 psi. MWD failed. Changed flow rates attempting to start MWD without success. 06:30 - 09:00 2.50 DRILL LMWD PROD1 Circulated high vis weighted sweep around. Circulated out very fine coal across shaker. 09:00 - 10:30 1.50 DRILL LMWD PROD1 Checked flow-negative. Pumped out of hole with 30 spin and pulling 3 minutes per stand to 9722°. Dropped vinyl ball and circulated down and opened PBL sub. Pumped out above whipstock at 9675'. 10:30 - 12:30 2.00 DRILL LMWD PROD1 Pumped around a high vis weighted sweep and began getting gas with bottoms up. Maximum gas 3450 units. 12:30 - 14:00 1.50 DRILL LMWD PROD1 Pumped out of hole to 8800'. 30 spm and 3 minutes per stand. 14:00 - 17:00 3.00 DRILL PROD1 . Changed saver sub. 17:00 - 00:00 7.00 DRILL LMWD PROD1 Checked flow-negative. Pumped out of hole with 30 spm and pulling 3 minutes per stand 9722' to 6250'. Circulated through PBL sub. Observing well for flow. Negative. Fill volumes Okay. Concurrently tested choke manifold to 250 Iow and 5000 high. 315/2001 00:00 - 09:00 9.00 DRILL LMWD PROD1 Finished pumping out of hole with 2-3~8" drill pipe. Pulling out at 3 minutes / stand and pumping 30 spm through the PBL sub. 09:00 - 12:00 3.00 DRILL LMWD PROD1 Pulled out of hole and laid down MWD. Found MWD shroud above Printed: 4112/2001 4:12:40 PM BP EXPLORATION Page 8 of 13 .. 'Operations Summary Report " Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: . Date From.~ T° HoUrs .Task .SUb. Phase = · Description of OperatiOns. ' ' ' Code. · .... . ... , . . : 31512001 09:00 - 12:00 3.00 DRILL LMWD PROD1 turbine plugged with nutplug, coal and crystalized polymer. 12:00 - 13:00 1.00 DRILL PROD1 Rigged floor to test. Pulled wear bushing and set test plug. Filled stack with water. 13:00 - 18:00 5.00 DRILL PROD1 Tested all rams and valves to 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Tested annular preventor 250 psi Iow for 5 minutes and 3500 psi high for 10 minutes. All test were pressure tested with water and recorded. Accumulator test was conducted and passed. Right to witness test was waived by AOGCC Inspector, John Crisp. 18:00 - 23:30 5.50 DRILL LMWD PROD1 Pick up BHA #4. Adjust motor and bit, PU and load MWD/LWD. Test same. 23:30 - 00:00 0.50 DRILL LMWD PROD1 Run in hole at I minute per stand to avoid surge. Fill every 25 stands. 3/6/2001 00:00 - 05:30 5.50 DRILL LMWD PROD1 Continued to run in hole to 9,675'. Filled drill pipe every 25 stands. 05:30 - 07:00 1.50 DRILL LMWD PROD1 Circulated bottoms up above whipstock, Oriented tool face to 40L. 07:00 - 10:00 3.00 DRILL LMWD PROD1 Ran in hole from 9,675' to 10,035'. Worked through tight spots at 9,925' and 10,076'. Hole packed off at 10,035'. 10:00 - 13:00 3.00 DRILL LMWD PROD1 Pumped and circulated around sweep. Worked pipe from 10,004' to 10,035'. Rotated and worked pipe while pumping sweep. 113:00 - 14:00 1.00 DRILL LMWD PROD1 Washed down through tight spot at 10,076'. Tagged bottom at 10,124'. 14:00 - 00:00 10.00 DRILL PROD1 Oriented and directionally drilled by sliding from 10,124' to 10,215'. WOB 1,500~. Torque on bottom= 1500, off.bottom= 1400, P/U W= 130K, S/O W-- 124K, RT W-- 126K, Motor rpm= 144, Pump rate 85 gpm, SPP 3,000 psi.,Off bottom 2,900 psi, on bottom 3,000 psi. 317/2001 00:00 - 01:00 1.00 DRILL PROD1 Directionally drilled by sliding from 10,215' to 10,223'. WOB 1,500#. Torque on bottom= 1500, off bottom= 1400, P/U W-- 130K, S/O W= 124K, RT W= 126K, Motor rpm-- 144, Pump rate 85 gpm, SPP 3,000 'psi.,Off bottom 2,900 psi, on bottom 3,000 psi. Angle dropped from 45.2 deg @ 10,123' to 42.0 deg @ 10,187'. Suspected tool face knocked out of alignment with scribe line by 50 deg Left. Attempted to build angle compensating for 50 deg. Left error. Maximum achieved doglegs 10 deg / 100'. Doglegs needed 25 deg - 29 deg / 100' to land as per program. Decision made to POOH and change bend in motor. 01:00 - 01:30 0.50 DRILL PROD1 Pumped up survey to verify directional problems. 01:30 - 03:00 1.50 DRILL BHA PROD1 Pumped and circulated around weighted Barafiber sweep. Minimal cuttings recovered. Pump rate 85 gpm, SPP 3,000 psi. 03:00 - 04:00 1.00~ DRILL BHA PROD1 Back reamed and pumped out of open hole to 9690' at 40 spm, 1 min I stand. No hole problems. Maximum Torque 1,200 ft/Ibs 04:00 - 05:00 1.00 DRILL BHA PROD1 Flow checked well. Well static. 05:00 - 06:30 1.50 DRILL BHA PROD1 RIH without pumps to 9,907'. Worked through bridge from 9,907' to 9,950'. Washed down without rotating through coal at 10,050' to 10,070'. Washed to bottom, no problems. 06:30 - 09:00 2.50 DRILL BHA PROD1 Pumped and circulate around weighted barafiber sweep. Pump rate 85 gpm, SPP 3,000. Circulated until returns over shaker were clean. Maximum trip gas 1800 units. 09:00 - 11:30 2.50 DRILL BHA PROD1 Pumped out of the hole from 10,223' to above whipstock at 9,675'. Checked hole fill and flow checked every stand. Well static. Maximum Printed: 4/1212001 4:12:40 PM BP EXPLORATION Page 9 of 13 Operations .Summary Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: · . .. ..... .., . .. . . ....., Date' From' To HoUrs ,'Task SUb, Phase Description of Operations ' ' COde . ..' ..... .... .. 3/712001 09:00 - 11:30 2.50 DRILL BHA PROD1 drag 10,000~. Pump rate 56 gpm, SPP 1,200 psi. Trip rate 3 rain I stand. 11:30 - 13:00 1.50 DRILL BHA PROD1 Circulated bottoms up. Pump rate 85 gpm, SPP 2,400 psi. 13:00 - 13:30 0.50 DRILL BHA PROD1 Serviced rig. 13:30 - 14:30 1.00 DRILL BHA PROD1 Pumped out of the hole from 9,675' to above whipstock at 9,311 '. Pump rate 56 gpm, SPP 1,200 psi. Trip rate 3 min / stand. Top Drive out of alignment, trouble making up saversub to drill pipe connections. 14:30 - 18:00 3.50 DRILL TDRV PROD1 Worked on Top Drive alignment cylinders. .18:00 - 23:30 5.50 DRILL BHA PROD1 Pumped out of the hole from 9,311' to above whipstock at 7,545'. Pump rate 56 gpm, SPP 1,200 psi. Trip rate 3 min / stand. 23:30 - 00:00 0.50 DRILL BHA PROD1 Changed out saver sub. 3/8/2001 00:00 - 01:30 1.50 DRILL PROD1 Finished changing out the Saver sub on the top drive. Executed a different method and saved I hour. 01:30 - 10:00 8.50 DRILL BHA PROD1 Pumped out of the hole from 7,545' to 4,033'. Pump rate 56 gpm, SPP 1,200 psi. Trip rate 3 min / stand. Flow checked well every 5 stands. Well static. Top drive not working properly. Shut down to repair at 4033'. 10:00 - 17:00 7.00 DRILL TDRV PROD1 Repaired top drive. 17:00 - 23:00 6.00 DRILL BHA PROD1 Pumped out of the hole from 4,033' to Surface. Pump rate 56 gpm, SPP 1,000 psi. Trip rate 3 min I stand. Dropped ball and opened PBL sub at 1,750'. Flow checked well every 5 stands. Well static. 23:00 - 23:30 0.50 DRILL BHA PROD1 Broke out and land down BHA and Bit. Note: Found tool face to be 65 degrees left of previous alignment. 23:30 - 00:00 0.50 DRILL BHA PROD1 Sperry-Sun Down loaded data from MWD. Blind rams closed, monitoring well through choke. Well static. Note: Held D1 drill- 1 min 30 sec Held H2S drill - 2 min 30 sec 3/9/2001 00:00 - 02:00 2.00 DRILL BHA PROD1 :Finished down loading LWD data and laid down remaining BHA. 02:00- 06:00 4.00 DRILL. TDRV I PROD1 Worked on top drive. 06:00 - 10:00 4.00 DRILL BHA PROD1 M / U HTC STR335 bit w/4 x 12 jets onto motor. Adjusted bent housing on motor to 2.83 degree and oriented to MWD. 20.63 degree offset. M / U PBL sub on one stand and RIH. MWD at 210'. 10:00 - 10:30 0.50 DRILL BHA PROD1 Tested MWD with 45 spm, good pulse. MWD OK. 10:30 - 11.:00 0.50 DRILL BHA PROD1 Serviced rig. 11:00 - 19:30 8.50 DRILL BHA PROD1 RIH to 9,599', rate 1 minute per stand. Filled the string every 25 stands. Laid down 10 joints with face damage on box. 19:30 - 20:00 0.50 DRILL WCON PROD1 Circulated Bottoms up at 9,599', pump rate 75 gpm, SPP 1875 psi. Flow rate increased from 10% to 30%. Shut down pumps, well flowing, shut in well. SlCP - 300 psi, SIDDP 75 psi. 20:00 - 20:30 0.50 DRILL WCON PROD1 Monitored shut in pressures, held PJSM prior to circulating well. 20:30 - 22:00 1.50 DRILL WCON PROD1 Circulated out using Drillers method. Held 1,500 psi (1275 psi SPR plus 225 psi safety factor) on drill pipe and circulated out at 30 spm. Circulated complete hole volume plus 500 strokes. Maximum gas 2,200 units, Average gas 1,300 units. MW 10.7 ppg in and 10.7 out. Shut down pumps and shut in well. DP pressure 0 Casing pressure 0. Open choke to check for flow-no flow. Opened well and check for flow. Well static. 22:00 - 22:30 0.50 DRILL WCON PROD1 Opened Rams and observed well. Well static. Circulated well at 75 gpm, SPP 1,875 psi. Flow increased from 10% to 25%, Gas increased from 1,500 units to 4,700 units. Shut down pumps and shut in well. SICP - 0, SIDDP - 0. Printed: 4112/2001 4:12:40 PM · BP EXPLORATION Page.10 of 13 · Operations Summa~ Report !Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: · ·Date ·re Hours Task Sub.. phase ..',' DescriPtiOn of Operations . ...... F._m-.To. Code · "'" . .... . ....... 3/912001 22:30 - 23:30 1.00 DRILL WCON PROD1 Circulated out using Drillers method. Held 1,875 psi, SPR, on drill pipe and circulated out at 40 spm. Circulated complete hole volume plus 700 strokes. Maximum gas 3,200 units, Average gas 1,200 units. MW 10.7 ppg in and 10.7 out. Shut down pumps and shut in well. DP pressure 0 Casing pressure 0. Open choke to check for flow-no flow. Opened well and check for flow. Well static. 23:30 - 00:00 0.50 DRILL BH^ PROD1 RIH to 9,722'. Washed down from 9,722' to 9,922'. Hit bridge at 9,922' Note: Held D2 drill, 1 min. 3/10/2001 00:00 - 02:00 2.00 DRILL BHA PROD1 Attempted to wash through bridge at 9,922'. Varied pump rate parameters from 30 spin up to 50 spm, Varied wash down rates from 15 sec / ff to 1 rain / f. No progress. 02:00 - 02:30 0.50 DRILL RE^C PROD1 Well packed off and stuck drill string at 9,930'. No circulation. Worked pipe with 30,000 lbs over pull and 1,000 ft / lbs of torque. Worked pipe free and regained circulation. 02:30 - 03:30 1.00 DRILL REAC PROD1 Circulated bottoms up. Maximum gas 4,700 units, average gas 2,000 units. 03:30 - 05:00 1.50 DRILL REAC PROD1 Washed back down to 9,922'. Attempted to wash through bridge at 9,922'. Varied pump rate parameters from 30 spm up to 50 spin, Varied wash down rates from 15 sec Iff to 1 min / f. No progress. 05:00 - 05:30 0.50 DRILL REAC PROD1 Well packed off and stuck drill string at 9,930'. No circulation. Worked pipe with 30,000 lbs over pull and 1,000 ff / lbs of torque. Worked pipe up to 9,912' with 30,000 lbs drag. No pipe movement above 9,912'. 10:00 - 12:00 2.00 DRILL RE^C PROD1 Worked stuck pipe. Pulled 50,000 lbs over and slacked off to 10,000 lbs under. Worked all torque out of drill string. Stacked all available weight on bottom on drill string. Top Drive weight 78,000 lbs. Worked pipe to neutral weight every 15 minutes. 12:00 - 14:00 2.00 DRILL REAC PROD1 Worked stuck pipe. Worked string from 125,000 lbs to 225,000 lbs. No movement. 14:00 - 16:00 2.00 DRILL REAC PROD1 Worked string with 4,000 ft ! lbs torque. ^ total 15 rounds. Worked string from 95,000 lbs to 190,000 lbs. No progress. 16:00 - 17:00 1.00 DRILL REAC PROD1 Dropped Red Steel Ball to open PBL sub. Waited one hour for ball to reach PBL sub. 17:00 - 20:00 3.00 DRILL REAC PROD1 Attempted to open PBL sub. Pressured up and bleed off pressure in attempt to seat ball and open the sub. Worked the drill string from 100,000 lbs to 200,000 lbs in attempt to help seat the ball and loosen the packoff. Unable to regain circulation through PBL sub. 20:00 - 20:30 0.50 DRILL REAC PROD1 Held pre-job safety meeting concerning rigging up Schlumberger and running free point tool. '20:30 - 23:30 3.00 DRILL RE^C PROD1 Rigged up Schlumberger sheave, side entry sub and cross overs. Made up Schlumberger free point tool and rigged to run down hole. 23:30 - 00:00 0.50 DRILL RE^C PROD1 Ran in hole with Schlumberger free point tool. Note: Held Fire Drill - 1 min 55 sec. I 3/11/2001 ~00:00 - 01:00 1.00 FISH REAC PROD1 Ran in hole with free point tool on Schlumberger wire line. Counted collars on trip in to correlate on depth. Free Point tool TD 9,787', Top of PBL 9,790' 01:00 - 02:30 1.50 FISH REAC PROD1 Ran free point measurements and the following depths with 20,000~ stretch: Depth Free 9,780' 0.0% 9,750' 2.0% 9,726' 1.5% Printed: 4/12/2001 4:12:40 PM BP EXPLORATION Page 11 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: " " 'Sub'. .' ' ' ' .' ' "' ' .Date. FrOm ..To HOurs. Task Code Phase '... ... Description ofOperationS...' ,.. .' . . 3111/2001 01:00-02:30 1.50 FISH REAC PROD1 9,721' 0.5% 9,700' 65% 9,690' 75% Tool joint at 9,694' indicated free point to back off. 02:30 - 03:30 1.00 FISH RE^C PROD1 Pulled out of the hole with free point tool. Broke out and laid down same. 03:30 - 04:00 0.50 FISH REAC PROD1 Held Safety meeting concerning the use of and running explosives for backing off. 04:00 - 05:00 1.00 FISH REAC PROD1 Made up string shot and tool for back off. Radio silence and Job Hazard analysis. 05:00 - 05:30 0.50 FISH REAC PROD1 RIH with string shot on wireline and got on depth. 05:30 - 06:30 1.00 FISH REAC PROD1 Worked 2 left hand turns at a time into string for a total of 9 left hand turns. Positioned string shot on depth at 9,694'. Fired string shot and backed out at 9,694'. 06:30 - 09:00 2.50 FISH REAC PROD1 Pulled out of the hole with string shot and wire line and R / D Schlumberger. 09:00 - 17:00 8.00 FISH REAC PROD1 Circulated to clean and condition hole. Maximum gas 1,800 units. Pump rate 75 gallons I minute, SPP 1,600 psi. 17:00 - 20:00 3.00 TA REAC ^BAN Continued to circulate while rigging up Dowell to set Temporary Abandonment plug. Held Pre-Job Safety meeting. 20:00 - 21:00 1.00i TA REAC ABAN Pumped 3.5 bbl lead water at 1.0 BPM at 850 psi. Mixed and pumped 17 bbl 15.8 ppg Class "G" cement with, .200 gal/sk antifoam, 0.450% bwoc dispersant, 0.190% bwoc retarder, 0.150% gal/sk gasblok stab, 2.00 gal/sk gasblok, 0.300 % bwoc salt. Pumped cement at 1.5 BPM at 900 psi, finished pumping cement at 1.5 BPM at 600 psi. Pumped 1 bbl of tail water at 1.5 BPM at 550 psi. Displaced cement with 27 bbl of mud at the following rates: Pumped Rate Pressure 9.0 bbls 2.25 BPM 1,490 psi 18.0 bbls 2.25 BPM 1,525 psi 22.5 bbls 1.35 BPM 925 psi 27.0 bbls 1.35 BPM 1.050 psi Shut down pumps, plug balanced. Cement in place at 2045 hrs. 21:00 - 21:30 0.50 TA REAC ^BAN Rigged down lines and pulled out of the hole from 9,694' to 9,339'. ^ total of 4 stands. Rate - 7 min I stand. Well static. 21:30 - 22:00 0.50 TA REAC ^BAN Circulated to clean hole. Pump rate 94 gpm, SPP 1,300 psi. Circulated out 14 bbl of cement contaminated mud. 22:00 - 00:00 2.00 T^ REAC AB^N Circulated hole while waiting on cement. 3112/2001 00:00 - 07:00 7.00 TA RE. AC AB^N Circulated and waited on cement at 9340'. Fish left in hole: Total length - 218'/from 9912 to 9694'. Components of fish: HTC STR335 PDC 3.70" BIT Sperry Sun 3-1/8" Sperry Drill Lobe 7/8 - 3.0 stg Non Mag Float Sub Non Mag XO Sub Sperry Sun DGWD SuperSlim MWD .2 - Flex Drill Collars 'XO PBL SUB 3 its Nabors 2 3/8" Drill Pipe. Printed: 4112/2001 4:12:40 PM BP ExPLoRATION. Page 12 of 13 Operations Summa Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 15 Rig Number: Sub 'Phase "' ." Description of Operati°ns .Date From-To Hours.'.Task Code .., ' ' . · . .' '," 3112/2001 07:00 - 09:00 2.00 CEMT REAC PROD1 Tagged cement plug at 9,342' with 30,000~, OK. R / U and tested cement plug to 2,000 psi for 30 minutes. Plug tested - OK. Blew down lines and rigged up to displace the well to Brine. Chuck Scheve of the AOGCC waived to witness tagging of the temporary abandonment plug. 09:00 - 10:30 1.50 TA REAC ^BAN Waited on Brine trucks to arrive and vacuum trucks to haul off mud. 10:30 - 13:30 3.00 TA REAC ABAN Displaced well to 11.0 ppg Brine. Pump rate 95 gpm, SPP 1,300 psi. 13:30 - 21:00 7.50 TA REAC ABAN POOH from 9,340' to surface. L / D 306 its of 2-3/8" drill pipe. Note:Held Pre-Job Safety Meeting 21:00 - 22:30 1.50 TA REAC AB^N RIH with 23 stands of drill pipe from derrick. 22:30 - 00:00 1.50 TA REAC ABAN POOH to 1,500', L / D 21 jts of 2-318" drill pipe. Prepared to Pump diesel for freeze protection. Note: Held D1 Drill - 1 min, 48 sec 311312001 00:00 - 18:00 18.00 TA REAC ABAN Waited on HB&R to pump diesel to freeze protect well. Drill Pipe in hole at 1500'. HB&R on SDI pad preparing wells for rig move to SDI 3-15 work over. 18:00-19:00 1.00 TA REAC ABAN Pumped18 bbls of diesel from HB&R truck down 2-3/8" x 4-1/2" annulus and allowed diesel to U-tube into drill pipe. 19:00 - 19:30 0.50 TA REAC AB^N POOH from 1,500' to surface. L / D 48 jts of 2-3~8" drill pipe. Note: Held Pre-job Safety Meeting. 19:30 - 20:00 0.50 TA REAC ^BAN Pumped 10 bbls of diesel from HB&R truck down 4-1/2" tubing to top off after pulling drill pipe. Note: Total Diesel pumped down hole 28 bbls. 20:00 - 21:00 1.00 TA REAC AB^N Wellsite maintenance ten and installed two way check valve. 21:00 - 22:00 1.00 TA REAC ABAN N / D Bell Nipple and Flow line and prepped BOP stack for lifting. 22:00 - 00:00 2.00 TA REAC ABAN Waited on wells to be shut - in prior to BOP heavy lift. 3/14/2001 00:00 - 16:00 16.00 TA OTHR ABAN Waiting on Production Wells group to prepare wells for shut in on 2-26 and 2-30 for heavy lift of BOP's. 16:00 - 17:00 1.00 TA ABAN Wells 2-26 and 2-30 shut - in. N / D BOP's, riser spool, 2-1116" double valve, and test spool. Set back BOP's on stump. Note: Held Pro-Job Safety Meeting - N I D BOP's and Riser 17:00 - 18:00 1.00i TA AB^N N / D Riser from well. 18:00 - 20:30 2.501 TA ABAN N / U Dry Hole tree Note: Held Pro-Job Safety Meeting - N I U Tree 20:30 - 21:00 0.50 TA ABAN Pressure tested Tree with glycol to 2,000 psi. OK. Note: Held Pro-Job Safety Meeting - Pressure Testing 21:00 - 00:00 3.00 T^ ^BAN Well Secure - Housekeeping on Well house. Released Doyon Rig #15 @ 00:00 hrs - 3 / 14 / 01 Note: Held Spill Drill - 1 min, 22 sec. Printed: 4112/2001 4:12:40 PM BP" EXPLORATION Page '13 of, 13 Operations Summary Report Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYON Rig Release: Group: Rig Name: DOYON 15 Rig Number: , . . .. SUb. .phase.. . . ' ...DescriptiOn. of OPerations . . .' =.~ Date '.From-To HOUrs. .'Task Code' · ., · .. 211912001 00:00 - 00:00 24.00 RIGU PRE PJSM (Rig move) - prepare for rig move - move rig to well 2-28a. Printed: 4112/2001 4:12:40 PM (. 28-Mar-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 2-28APB1/0-19 . . Dear Dear Sir/Madam: "' ".c~o'.~'O' ~ ~ Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,650.60' MD 9,675.00' MD 10,224.00' MD (if applicable Please call me at 273-3545 if you h'ave any questions or conCerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 17. ?_001. Aimka Oil & ~ Cons. Commismor Anchorage DEFINITIVE Alaska State Plane 3 Alaska Drilling & Wells Endicott DI-MPi, Slot 2-28/P. ~9 2-28/P- ~ 9 - 2-28APB f /O- f 9 .Job No. AKMW10052, Surveyed: 7 March, 2001 SURVEY REPORT 28 March, 2001 Your Ref: AP1500292184770 Surface Coordinates: 5982473.39 N, 258966.93 E (70' 2f' 09.7933" N, Kelly Bushing: 55.0Oft above Mean Sea Level 147° 57' 26.7078" W) DRI'L, LINB S~ERVICE=; Survey Ref: svyg?3 A H~,lllburton Contpany Sperry-Sun Drilling Services Survey Report for 2.28/P. t9 - 2.28APB1/O- ~ 9 Your Ref: AP1500292184770 Job No. AKMW~O0$2, 9urveyed: 7 March, 2001 Alaska State Plane 3 Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastinga Northings Eastinge (ft) (ft) (ft) (ft) 9650.60 6.830 159.540 9548.23 9603.23 362.72 S 307.76 E 5982100.96 N 259262.87 E 9675.00 6.740 159.540 9572.46 9627.46 365.42 S 308.77 E 5982098.23 N 259263.79 E 9715.85 10.320 153.250 9612.85 9667.85 370.94 S 311.26 E 5982092.63 N 259266.09 E 9744.19 11.190 150.730 9640.69 9695.69 375.60 S 313.75 E 5982087.89 N 259268.43 E 9777.73 12.750 148.600 9673.50 9728.50 381.60 S 317.26 E 5982081.78 N 259271.75 E 9807.97 18.580 143.180 9702.61 9757.61 388.31 S 321.89 E 5982074.92 N 259276.17 E 9839.76 23.390 134.260 9732.29 9787.29 396.78 $ 329.46 E 5982066.22 N 259283.45 E 9873.13 28.560 120.850 9762.30 9817.30 405.50 S 341.07 E 5982057.12 N 259294.77 E 9901.63 30.890 111.150 9787.07 9842.07 411.64 S 353.75 E 5982050.58 N 259307.25 E 9938.27 35.590 105.290 9817.71 9872.71 417.85 S 372.82 E 5982043.76 N 259326.11 E 9965.08 36.690 104.380 9839.36 9894.36 421.90 S 388.10 E 5982039.23 N 259341.26 E 9997.11 38.370 94.450 9864.79 9919.79 425.05 S 407.30 E 5982035.46 N 259360.35 E 10031.55 38.740 93.760 9891.72 9946.72 426.58 S 428.71 E 5982033.24 N 259381.70 E 10059.30 42.480 91.770 9912.78 9967.78 427.44 S 446.75 E 5982031.80 N 259399.70 E 10090.83 44.830 86.010 9935.60 9990.60 427.00 S 468.49 E 5982031.54 N 259421.44 E 10123.13 45.200 80.230 9958.45 10013.45 424.26 S 491.15 E 5982033.55 N 259444.18 E 10156.38 43.510 75.420 9982.23 10037.23 419.38 S 513.86E 5982037.70 N 259467.03E 10187.66 41.960 72.720 10005.20 10060.20 413.56 S 534.27 E 5982042.86 N 259487.62E 10224.00 41.960 72.720 10032.22 10087.22 406.34S 557.47 E 5982049.33 N 259511.04E All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.191° (13-Feb-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 38.240° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10224.00ft., The Bottom Hole Displacement is 689.85ft., in the Direction of 126.088° (True). DEFINITIV£ Alaska Drilling & Wells Endicott DI-MPI Dogleg Vertical Rate Section ('/100ft) -94.40 0.37 -95.89 9.04 -98.69 3.49 -100.81 4.83 -103.34 Comment Tie on Point MWD Magnetic Window Point 19.86 -105.75 18.12 -107.72 23.36 -107.39 18.73 -104.36 15.52 -97.43 4.57 -91.15 19.58 -81.74 1.65 -69.70 14.26 -59.21 14.64 -45.40 12.71 -29.22 11.32 -11.33 7.67 5.87 0.00 25.90 Projected Survey DrillQuest 2.00.08.002 28 March, 2001 - 16:38 Page 2 of 3 Sperry-Sun Drilling Services Survey Report for 2-28/P.19.2-28APB1~0.19 Your Ref: AP1500292184770 Job No. AKMWlO052, Surveyed: 7 March, 200f Alaska State Plane 3 Alaska Drilling & Wells Endicott DI-MPI Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (it) (ft) (ft) 9650.60 9603.23 362.72 S 307.76 E 9675.00 9627.46 365.42 S 308.77 E 10224.00 10087.22 406.34 S 557.47 E Comment Tie on Point Window Point Projected Survey Survey tool program for 2-28/P-19 - 2-28APB1/O-t9 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (It) (It) (It) (ft) Survey Tool Description 0.00 9650.60 0.00 9650.60 9603.23 AK-1 BP_HG - BP High Accuracy Gyro (2-281P-1g) 9603.23 10224.00 10087.22 MWD Magnetic (2-28APBllO-'I9) 28 March, 200f - 16:38 Page 3 of 3 DrillQuest 2.00.08.002 '. STATE OF ALASKA ~'.. ALASK ~IL AND GAS CONSERVATION COM ..,SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other Ba Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 2310' SNL, 1931' WEL, SEC. 36, T12N, R16E, UM At effective depth At total depth 688' SNL, 1246' WEL, SEC. 36, T12N, R16E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10223 feet 10087 feet 9675 feet 9627 feet Length 92' 2465' 9605' 1144' Size 13-3/8" 7\ (Planned) 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 8. Datum El~)~'ation (DF or KB) //KBE = 55.00' 7. Unit 9¢Property Name K Island Unit/Endioott 8./4/Veil Number ~ L// 2-28A/O- 19 9. Permit Nu.n)ber 201-018" 10. APl Number 50- 02921847-01 11. Field and Pool Endicott Field / Endicott Pool Plugs (measured) Jun at 9675'; Perf Abandonment Cement below (03/01) 3 Bowspdng Leafs at 10448' 3-1/2" tailpipe cut and dropped to bottom (03/01) Cemented MD TVD 131' 131' cu. ft. Permafrost 2504' 2503' 575 cu. ft. Class 'G' 9644' 9597' 517 cu. ft. Class 'G' 9383' - 9675' 9338' -9627' Perforation depth: measured None - true vertical None Perf's for Sidetrack Operation. RECEIVED APR 05 2001 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 9339' Alaska 0ii & (~a.s Cons. Commission Anchorage Packers and SSSV (type and 9-5/8" Baker 'SAB' packer at 9339'; 4-1/2" SSSV Landing Nipple at 1555' 13. Attachments [] Descriptior 14. Estimated date for commencing April 20, 16. If proposal was verbally of Proposal [] Detailed Operations Program 115. Status of well classifications as: [] Oil [] Gas [] Suspended Service Date Approved Name of approver contact Engineer Name/Number'. Hupp, 564-5344 [] BOP Sketch Prepared By Name/Number: Sondra Stewman, 564-4750 17. I hereby certify that Signed Jeff Hupp ~g is true and correct to the best of my knowledge Title Senior Ddlling Engineer Date Conditions of App ~lotify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance lA Mechanical Integrity Test Subsequent form required 10- pproved by order of the Commission Approval No. Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate Stewman, Sondra D From: Sent: To: Cc: Subject: Hupp, Jeffrey L Monday, April 02, 2001 5:13 PM Tom Maunder (E-mail) Hubble, Terrie L; Stewman, Sondra D Endicott 2-28A/O-19 pre-Rig Operations Tom, The Endicott 2-28A/O-19 well was suspended on 3/14/01 after the 3.70" BHA became stuck in the open hole just outside the 3.72" window. The Sundry Notice was approved to set a cement plug above the BI-IA and back into the 7" and 9-5/8" casing. The well was freeze protected and the rig (Doyon 15) was moved off the well. See the attached diagram for well specifics. The proposed pre-rig program for the 2-28A/O-19 well is as follows: 2-28A/O-19 Detailed Rig Prep Procedure 1. RU SL- Pull btm GLV. 2. Circulate well to 10.7 ppg KW brine. $. Freeze Protect top 1500' of tbg and annulus. 4. RU e-line. Chemically cut 4-1/2" L80 tbg at 9223' MD (middle of 1st full jt above sliding sleeve (3.75" ID). $. Set BPV 2-3 days prior to rig moving over well. A new Permit to Drill package will be forthcoming to cover the proposed conventional sidetrack plan for the 2-28A O-19 well 2-28A 0-19 Pm-rig drawing.ZIP... Call me if you have any questions. Jeff Hupp MB 447 Phone: (907) 564-5344 Cell: (907) 240-8057 Fax: (907) 564-5441 e-maih huppjl @ bp.corn ]Well Name: 12-28A/N-24 Well Plan Summary Type of Well (Producer or injector): ] Producer Well Design (Conventional, slimhole, etc.):I Conventional Sidetrack FNL FEL SEC TWP RNG Surface Location: 1944 2240 36 12N 16E Top of Kekiktuk is above KOP: 2310 1931 36 12N 16E Target 2 - Bottom Hole Location: 688 1246 36 12N 16E AFE Number: I 727033 I I Rig: I DOYEN 15 Estimated Start Date: I April 20, 2001 I I Operating days to D&C 122+4 Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE TOP HRZ 9387 9287 Above KOP BASE HRZ 9643 9541 Above KOP LCU 9643 9541 Above KOP KEKIKTUK - Top 9643 9541 Above KOP K3C 9643 9541 Above KOP FV 9643 9541 10.2 ppg 5090 psi KOP 9650 9547 FIV 9654 9552 10.2 ppg 5096 psi FIII 9757 9653 10.2 ppg 5149 psi FII/K3B 9823 9714 10.2 ppg 5182 psi F1 9935 9812 10.2 ppg 5233 psi K3A/S3A4 9990 9854 9.1 ppg 4689 psi S3A4 Coal 10006 9867 9.1 ppg 4695 psi S3A3 Coal 10058 9902 9.1 ppg 4711 psi S3A2 Coal 10076 9913 9.1 ppg 4716 psi S3AI 10163 9970 9.1 ppg 4742 psi Target Interval (In build) 10192 9983 8.7 ppg 4550 psi (Upper sand) K2B K2B shale 10220 10050 Middle Shale Target Interval (In Build) 10431 10075 8.6 ppg 4550 psi (lower Sand) K2B K2B Geological Target 10685 10113 8.6 ppg 4550 psi TD 12076 10031 K2M Shale Below Planned wellbore Expected GOC 9991' Above horz section Mud Program: Production Interval Mud Pro )erties: LSND 6" hole · Density(pp Plastic Yield Point tau0 LSRV FluidLos g) ~/is(cp) (Ib/100ftz) (ib/~-~'(~ft2) oH C_.ga cc's/30mi Milling 10.7 5 - 8 25 - 35 5 - 8 < 20 K 8.5 - 9.0 <100 <10 Production 10.7-10.8 5 - 8 20 - 28 5 - 8 < 20 K 8.5 - 9.0 <100 <10 Directional: KOP: 19650' MD Maximum Hole Angle: Close Approach Wells: Logging Program: Production Hole 93.5 at 10800' MD There are no close approach wells other than the abandoned 2-2.8 wellbore and BHA fish from the 2-28A/O-19 TTRD attempt, The 2-28A planned well path will deviate to the left from the original wellbore. Drilling: Open Hole: Cased Hole: MWD / GR / Res / CNL / PWD / ABI None None C ram' Hole S~ze ~sg/ " Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD bkb Existing 20" 91.5# H-40 WLD 131' GL 131/131 Existing 13-3/8" 72# L-80 BTRS 2465' GL 2504'/ Existing 9-5/8" 47# L-80 BTRS 8309' GL 8348'/ Existing 9-5/8" 47# S-95 BTRS 1300' 8348'/8322' 96~,~,'/9596' Existing 7" 29# P-110 ~ ~'C 1144 9383/9337' 10527'/' 6" 4-1/2" 12,6# L-80 NSCT 2746' 9330'/9284' 12076'/10086' Prop.Tubing 4-1/2" 12,6# CR-13 NSCT 12095' GL 13170'/9580' Cement Calculations: Casing Size 1 4-1/2" CR-13 Production Liner I BOD: I Based on 2426' open hole volume + 40% excess + 80' shoe track volume + 150' liner lap + 100' I · Tail TOC: At -13415' MD (9821' TVD bkb) Liner Top above liner top inside the 9-5/8" casi,n..;g. Total Cement Volume: 1 63 bbl / 355 ft' / 310 sks of Dowell Class G at 15.8 ppg and 1.1 5 cf/sk. Cuttings and Fluid Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Endicott 2-28A/O-19 Drilling Hazards (Post on Rig Floor) H2S Levels: · Production from MPI 2-28 has been measured 56 ppm H2S. · Surface Offset well H2S readings o MPI 2-26:99 ppm (11/22/00) o MPI 2-30:2 ppm (12/4/00) o MPI 2-24 Water injector o MPI 2-32:89 ppm (12/11/00) Gas Injection: · The planned kickoff point (KOP) is in the 10.2 ppg Kekiktuk F-IV sand interval. In the initial 2-28A TTRD sidetrack attempt a gas influx was taken in this interval. The well was killed with a 10.5 ppg mud. The mud was weighted up to 10.7 ppg for trip margin. By drilling a larger hole (6" vs. 3.70"), the swab pressures will be significantly less. Lost Circulation: · Lost circulation is a risk due to the over pressured Upper Sub zone Intervals (10.2 ppg EMW) and lower pressured target sands (8.8 ppg). Fluid properties will be monitored closely to minimize the ECD, swab and surge pressures. Reservoir Pressure Maximum reservoir pressure is estimated to be 5233 psi at 9867 TVD RKB (10.2 ppg EMW). Max. Surface pressure with gas (0.10 psi/ft) to surface is 4247 psi. Well Control: · Pipe rams, blind rams tested to 300 psi and to 5000 psi. · The annular preventer will be tested to 300 psi and 3500 psi. Endicott 2-28A/O-19 Conventional Sidetrack Scope of Work: The 2-28A/O-19 conventional sidetrack will replace the original 2-28A/O-19 TTRD sidetrack. Pre-Rig Operations . . . Pull BPV. RU Slickline. Pull btm GLV. Circulate well to 10.7 ppg brine. Freeze protect to 500' w/diesel. Freeze point of 10.7 ppg brine: RU e-line. RIH & chemically cut tbg at 9223' MD (middle of 1st full jt of 4-1/2" tbg). Sliding sleeve @ 9265' (ID:3.75") Set TWC 2-3 days prior to rig moving over the well. Ri; Operations . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. Move Doyon 15 from SDI to the Endicott 2-28A/O-19 well. ND dry hole tree and tbg head adapter. NU & test BOPE. Circulate out freeze protection fluid. Pull and LD 4-1/2" L80 completion to chemical cut. RIH w/overshot assembly. Release SBR overshot seal assy. POH. RIH and release K-anchor from packer. RIH w/packer milling assy. Displace well to 10.7 ppg milling/drilling fluid. Mill packer, millout extension and cement to the liner top at 9383' MD. POH. RIH w/6" cement mill. Mill cement to TTRD whipstock at 9675'. MD. POH. RIH w/7" whipstock assy. Set whipstock and mill 6" window f/9656-9668'. POH. Drill 6" hole from 9668-12075' MD (2500'+/-) as per the Sperry Sun Directional plan #14. Run and cement 4-1/2" CR-13 liner. DPC perforate a 500' (+/-) interval with 2-1/2" guns. Run 4-1/2" CR-13 completion. Freeze protect well. ND BOPE & NU tree. Post Rig Procedure 1. Install flow line. 2. RU slickline and run live gaslift design. Jeff Hupp Sr. Drilling Engineer CC: 2-28/O-19 Well File Rt. ELEV = 55.0' BF. ELEV = 15.8' MAX. DEV. = 13:33 8000' MD 13-3/8", 68#/ft, Nm-so CYHE, BT RS. CSG. NT9 5HS TREE: .zL1/16" / 5000 psi / McEVOY WELLHE/~ 13-5/8" / 5000 psi / McEVOY SSSV LANDING NIPPLEI 1500' I OTIS (3.8 13" MIN. ID) W/SSSV M I N I.D. 2" 4-1/2" 12.6 ppf Cr-13 TBG GAS LIFT MANDREL SPACING NO. m VDSS U D-B RT I #~ 3750' 3805' #4 6000' 6055' #3 7300' 7356' #2 8150' 8230' #1 9000' 9090' Conventional 4-1/2" CR-13 Tail pipe assy TOP OF I 7mm LINER Est 9-5/8" x 4-1/2" liner top @ 9340' MD 93 83' I ~~' 9-5/8", 4 7#/ft, I NT9 5HS, 96 44' IBaker Conv WS set w/top @ 9656' 'X' Nipple Baker 9-5/8" x 4-1/2" S-3 pkr 4-1/2" 'X' Nipple 4-1/2" 'XN' Nipple WL Guide 9285' 9295' 9315' 9335' 9345' 6" hole drilled to 12076' MD 4-1/2" 12.6 ppf CR-13 liner IBaker -rhru--rbg whipstock I set @ 9675' Ex is lin g perfo ration s plugged with 22 bbls of crnt I lo,44s' J PET D 7" - 29 #/ft, SM-11 0'11 10,5 27' ! ~ BTRS -TKO DAm E 4/2/01 REV. BY JLH CO M M ENTS )rop 4-1/2" CR-13 Completion Original well Drilled 3.70" hole to 10223' MD Stuck BHA on trip @ 9912'. Attempted unsuccessfully to free BHA. Backed off & BHA. BHA f/9691-9912' Cemented back to orig. packer @ 9335' MD. ENDICO'R' WELL 2-28'A/O-19 APl NO' 50-029-21847-01 Proposed Conventional Sidetrack BP EXPLORATION, INC. TRE E: 4-1116' 15000 psi I McEVOY RT. ELEV=55.0' WELLHEAD: 13-518' 15000 psilMcEVOY BF ELEV = 15.8' ~"" ~~~--"~ · ~ ":' ~.~.~:.? '.':~H ,.,~'~, ,~::, MAX. DEV. = 13:3-~ ~ ~ 4 Diesel f/1500' to surface B0O0' M D ,~,-. o8#,~,, r~ sssv LA,D,,O N,PPLE ,T-80 C¥,E. BTRS. CSG. I 'm---- O~,~ ~.~,~' ~,,. 'm i ~ 4-112'. 1 2.6~1ff, L~0. { ~~ BTRS A~ Mod. TUBING GAS LIFT MANDRELS (MEELA) 10.7 ppg brine to 500' MD ~, .o. TVDSS '~l '~ ,e 4148' 4204' ." ~5 6337' 6393' 9-5~', 4 7~lft, ,, ~4 77 76' 7845' I I NTBOS ZO TO 8348' ~ __ . ' ~3 8688' 8780' NT95HS ',' ' ~2 8911 ' 9Q07' chemi~l cut ~ 9223' ~~ ~ 3.75" ID c0nfi~ed by PDS suwey ~ 9265 ';" '" ..7,.~. ,.~ '.';:'~.,.~' ,.':'L ? .:~..' ",". 9-518' PACKER XXX~ ~. 0aaa' ~ I~ ' X X X ~ cut and dropped to PBTD LINER ' x x x > Set 15.8 ppg cement plug ' x x x > f/9912-9335. Wfd te~ed w/30~ Nm9 5HS, 9644' ~ : ~ ressure te~ed w/2000 ~i. Ba ~r ~ru- ~g w hip stock set ~ 9675' plugg~ w Ith 22 bb~ of cmtI REF: LO~: DLL-GR SIZ~ SPF I~AL S 'AT~ 2-1/8 4 10114' - 1016 0' S~Z D 2-1/~ ~ lO 145'- ~ o157' o~ i ~, " Ddlled 3.70" hole to 10223' MD 2-118 4 10180' - 10~ 0' S~Z D ~1/8 4 10188'- 10213' OPEN I I ~uck BHA on trip ~ gg12'. ~ '118 4 10216' - 10246' , O~N A~empted unsuc~ssfully to free BHA. I I Backed off & BHA. Cemented back to packer ~ 9335' MD. ~ 3 BOWS PRING PBTD ~ 1014 48, I ~ . ~ LEAFS 7"- 2o~m, SM-I~0t ~0,S27' I ~ gTRS TKC DATE REV. BY COMMENTS ENDICOTT WELL 2-28AIO-19 4/~01 JLH Prop Pre-rig Schematic APl NO: 5 0-029-2t 847-0t Proposed Pre-Rig Schematic BP EXPLORATION,INC. SIZE SPF INTERVAL S' 'ATUS 2-118 4 10114' - 1016 0' SQZ D 2-118 6 10145' - 1 O157' OPEN 2-118 4 10180' - 1 0200' SQZ D 2-118 4 10188'- 102'13' OPEN 2- '118 4 10216' - 10246' OPEN Alaska State Alaska Drilling Erl~ 2-28a/0-19 Coal Section) L REPORT ~~~ 1 April, 2001 Your Reh 'Wellplan 13' w/Revised Formation Tops (3-30-01) Surface Coordinates: 5982473.39 N, 258966.93 E (70° 21' 09.7933" N, 147° 57'26.7078" W) Kelly Bushing: 55.0Oft above Mean Sea Level A Halliburton Company Proposal Reft pro974 Alaska State Plane 3 Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9650.00 6.833 159.535 9547.63 9602.63 9654.40 7.198 157.521 9552.00 9700.00 11.297 144.750 9597.00 9750.00 16.077 138.456 9645.57 9757.74 16.742 135.778 9693J 9812.00 9855.00 9862.50 9902.00 9800.00 20.843 124.350 9822.65 23.270 119.903 9850.00 26.335 115.598 at .oo.oo*** 9989.82 41.897 ~1~21 10000.00 43.238 '~84.654 10058.15 51.153 77.969 Sperry-Sun Drilling Services Proposal Report for 2-28A/0-19 Rig 2-28a/0-19 Wp 14 (Considering Coal Section) Your Ref: 'Wellplan 13' w/ Revised Formation Tops (3-30-01) I~~ !~ .~,' "'L~ , . Local Coordinates . GI~J ~,~0~~ Dogleg NoAhings Eastings ~o,~ i~ '~ings Rate 9607.00 5982100.51N 259262.96 E 10.00 9652.00 E 5982094.11 N 259266.43 E 10.00 .318.97 E 5982084.68 N 259273.55 E 10.00 9793.83 9837.72 9867.00 9910.00 9917.50 9957.00 10075.68 51.153 77.969 9913.00 9968.00 10100.00 51.153 77.969 9928.25 9983.25 10134.67 51.153 77.969 9950.00 10005.00 ).24 S 320.45 E 5982083.04 N 259274.99 E 13.00 10168.20 55.599 81.711 9970.00 10025.00 10192.21 58.848 84.150 9983.00 10038.00 10200.00 59.912 84.905 9986.97 10041.97 10236.34 64.925 88.230 10003.79 10058.79 388.85 S 330.91 E 5982074.09 N 259285.16 E 13.00 393.36 S 338.12 E 5982069.36 N 259292.22 E 13.00 398.67 S 348.28 E 5982063.72 N 259302.20 E 13.00 406.18 S 370.93 E 5982055.49 N 259324.60 E 16.00 408.91S 389.73 E 5982052.15 N 259343.31E 16.00 408.96 $ 423.78 E 5982051.00 N 259377.34 E 16.00 408.40 $ 430.64 E 5982051.34 N 259384.21 E 16.00 401.81S 472.71E 5982056.58 N 259426.47 E 16.00 398.97S 486.07 E 5982058.99 N 259439.91 E 0.00 395.02 S 504.59 E 5982062.34 N 259458.55 E 0.00 389.39 $ 531.00 E 5982067.12 N 259485.13 E 0.00 384.67 S 557.48 E 5982070.98 N 259511.75 E 16.00 382.19 $ 577.51E 5982072.81N 259531.85 E 16.00 381.56 S 584.18 E 5982073.24 N 259538.53 E 16.00 379.65 S 616.32 E 5982074.11N 259570.72 E 16.00 Alaska Drilling & Wells Endicott DI-MPI Vertical Section -213.89 -214.27 -218.63 -224.20 -225.o9 -228.94 -230.27 -231.21 -229.28 -224.46 -211.22 -208.03 -185.55 -177.72 -166.86 -151.37 -136.7o -126.60 -i23.41 -lO9.12 Comment S.T. off Whip w/TF ~ 35L (6" Hole\'/'~ 7" Csg) @ 10.0°/100ft: 9650.00 ft MD, 9602.63 ft TVD 7" Liner FIV Increase DLS to13.0°/100 ft: 9750.00 ft MD, 9700.57 ftTVD Fill K3B / FII Increase DLS to 16.0°/1 O0 ft: 9850.00 f MD, 9793.83 ft TVD K3A / S3A4 End Dir, Start Sail @ 51.15°: 10058.15 . ft MD, 9957.00 ft TVD jr S3A3 Coal S3A2 Coal Begin Dir @ 16.00°/100ft: 10134.67 ft MD, 10005.00 ft TVD S3^1 K2B (upper sand) Continue Dir @ 15.68°/100 ft: 10236.34 ft MD, 10058.79ftTVD 1 April, 2001 - 13:55 Page 2 of 8 DrillQuest 2.00.08.004 Alaska State Plane 3 Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 10300.00 66.971 77.530 10029.80 10400.00 71.544 61.484 10065.41 10431.73 73.282 56.595 10075.00 10500.00 77.384 46.373 10092.33 10503.11 77.581 45.917 10093.00 10550.81 80.689 38.991 10102.00 10600.00 84.031 31.977 10108.55 10685.24 90.000 20.000 10113 10700.00 10800.00 1O802.79 10900.00 11000.00 11100.00 11200.00 11300.00 11400.00 11500.00 11600.00 11700.00 11800.00 11900.00 12000.00 12076.24 90.450 17.682 93.447 1.95d~ 93.527~ 1~~ '"10103.37 93.527 1.515 10084.91 93.527 1.515 10078.76 93.527 1.515 10072.61 93.527 1.515 10066.45 93.527 1.515 10060.30 93.527 1.515 10054.15 93.527 1.515 10048.00 93.527 1.515 10041.84 93.527 1.515 10035.69 93.527 1.515 10031.00 Sperry-Sun Drilling Services Proposal Report for 2-28A/0-19 Rig 2-28a/0-19 Wp 14 (Considering Coal Section) Your Ref: 'Wellplan 13' w/ Revised Formation Tops (3-30-01) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 10084.80 372.42 S 10120.41 339.63 S 10130.00 324.07 S 10147.33 10148.00 ~79.49. 209020.48 E S98~'~,4S N 259716.64 E 5982124.17 N 259743.05 E 5982163.59 N 259795.90 E 5982165.62 N 259798.16 E 30.29 S ~872.28 E 5982199.13 N 259830.83 E ' 900.55 E 5982237.88 N 259860.37 E 937.75 E 5982313.00 N 259900.00 E 116.33 S 18.17 S Dogleg Rate (°/lOOft) 15.68 15.68 15.68 15.68 15.68 15.68 15.68 15.68 Alaska Drilling & Wells Endicott DI-MPI Vertical Section -80.00 -15.81 8.62 66.59 69.38 113.50 161.o7 245.88 942.51E 5982326.80 N 259905.21E 16.00 260.60 959.51E 5982424.36 N 259925.36 E 16.00 357.61 10164.35 15.39 S 959.60 E 10158.37 81.61N 962.16 E 10152.22 181.38 N 964.80 E 10146.06 281.16 N 967.44 E 10139.91 380.93 N 970.08 E 10133.76 480.71 N 972.72 E 10127.61 580.48 N 975.36 E 10121.45 680.26 N 978.00 E 10115.30 780.03 N 980.63 E 10109.15 879.81N 983.27 E 10103.00 979.59 N 985.91E 10096.84 1079.36 N 988.55 E 10090.69 1179.14 N 991.19 E 10086.00 1255.21N 993.20 E 5982427.14 N 259925.53 E 16.00 360.20 5982524.00 N 259931.22 E 0.00 450.51 5982623.64 N 259937.07 E 0.00 543.41 5982723.28 N 259942.91 E 0.00 636.31 5982822.92 N 259948.76 E 0.00 729.21 5982922.56 N 259954.61E 0.00 5983022.20 N 259960.46 E 0.00 5983121.83 N 259966.30 E 0.00 5983221.47 N 259972.15 E 0.00 5983321.11N 259978.00 E 0.00 5983420.75 N 259983.85 E 0.00 5983520.39 N 259989.69 E 0.00 5983620.03 N 259995.54 E 0.00 5983696.00 N 260000.00 E 0.00 822.11 915.01 1007.91 1100.80 1193.70 1286.60 1379.50 1472.40 1543.23 Comment K2B (lower sand) COWC (1 st Penetration) COWC (2nd Penetration) Continue Dir @ 16.0°/100ft: 10685.24 f MD, 10168.00 ftTVD Target - 2-28/O19 MOD 1, Geological End Dir, Start Sail @ 93.527°: 10802.79 ft MD, 10164.35 ft TVD Total Depth: 12076.24 ft MD, 10086.00 ft TVD 4-1/2" Liner Target - PBHL (wp10), Geological 1 April, 2001 - 13:55 Page 3 of 8 DrillQuest 2.00.08. 004 Sperry-Sun Drilling Services Proposal Report for 2-28A/0-19 Rig 2-28a/0-19 Wp 14 (Considering Coal Section) Your Ref: 'Wellplan 13' w/ Revised Formation Tops (3-30-01) Alaska State Plane 3 AIl data is in Feet unless o~e~ise stated. Directions and coordinates are relative to Tru~No~~~~ ~ Ve~ical depths are relative to Wall. No~hings and Eastings are relative to Well. The Dogleg Severi~ is in Degrees per 100 feet. ~ Ve~ical Section is from Well and calculated along an Azimuth of 22.9~~~ '~> Based upon Minimum Cu~ature ~pe calculations, at a~ ~sur~~~~76.~t., The BoEom Hole Displacement is 1600.63ft., in the ~ ~ o~~~e). Alaska Drilling & Wells Endicott DI-MPI Measured S t a t i o n s Depth TVD Fastings (ft) (ft) Comment 9650.00 362.66 S 307.67 i= 9750.00 378.64 S 318.97 E 9850.00 398.67 S 348.28 E 10058.15 9957.00 401.81 $ 472.71 E 10134.67 10005.00 389.39 S 531.00 E 10236.34 10058.79 379.65 S 616.32 E 10685.24 10168.00 130.29 $ 937.75 E 10802.79 10164.35 15.39 S 959.60 E 12076.24 10086.00 1255.21 N 993.20 E S.T. off Whip w/TF ~ 35L (6" Hole Thru 7" Csg) @ 10.0°/100ft: 9650.00 ft MD, 9602.63 ft TVD Increase DLS to13.0°/100 ft: 9750.00 ft MD, 9700.57 ft TVD Increase DLS to 16.0°/100 ft: 9850.00 ft MD, 9793.83 ft TVD End Dir, Start Sail @ 51.15°: 10058.15 ft MD, 9957.00 ftTVD Begin Dir @ 16.00°/100ft: 10134.67 ft MD, 10005.00 ft TVD Continue Dir @ 15.68°/100 ft: 10236.34 ft MD, 10058.79 ft TVD Continue Dir @ 16.0°/100ff: 10685.24 ft MD, 10168.00 ffTVD End Dir, Start Sail @ 93.527°: 10802.79 ft MD, 10164.35 ft TVD Total Depth: 12076.24 ft MD, 10086.00 ft TVD 1 April, 2001 - 13:55 Page 4 of 8 DrillQuest 2.00.08. 004 Alaska State Plane 3 Formation Tops Measured Depth (ft) Vertical Depth (ft) 9643.32 9654.40 9757.74 9822.65 9934.92 9989.82 10058.15 1O075.68 10168.20 10192.21 10431.73 10503.11 10550.81 9596.00 9607.00 9708.00 9769.00 9867.00 9910.00 9957.O0 9968.00 10025.OO 10148. Sub-Sea Depth (ft) 9541.00 9552.00 9653.00 9714.00 9812.00 9855.00 9902.00 9913., 102.00 Northings (ft) 361.92 363.16 380.24 393.36 S 9S 324.07 S 280.87 S 246.32 S Sperry-Sun Drilling Services Proposal Report for 2-28A/0-19 Rig 2-28a/0-19 Wp 14 (Considering Coal Section) Your Ref: 'Wellplan 13' w/ Revised Formation Tops (3-30-01) Eastings Dip (ft) E 0.000 423.78 E 472.71E 486.07 E 557.48 E 577.51E 786.95 E 840.70 E 872.28 E 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 358.156 358.156 358.156 358.156 358.156 358.156 358.156 358.156 358.156 358.156 358.156 K3C / FV / TKEK FIV Fill K3B / FII FI K3A / S3A4 S3A3 Coal S3A2 Coal S3A1 K2B (upper sand) K2B (lower sand) COWC (1st Penetration) COWC (2nd Penetration) Alaska Drilling & Wells Endicott DI-MPI 1 April, 2001 - 13:55 Page $ of 8 DrillQuest 2.00.08.004 Sperry-Sun Drilling Services Proposal Report for 2-28A/0-19 Rig 2-28a/0-19 Wp 14 (Considering Coal Section) Your Ref: 'Wellplan 13' w/ Revised Formation Tops (3-30-01) Alaska State Plane 3 Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> 9650.00 9602.63 9650.00 9602.63 12076.24 10086.00 associated with this wellpath~~k TargetName D~ 2-28/O19 MO Drillers Target (95%) Casing Detail Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 10168.00 130.29 S 937.75 E 10113.00 5982313.00 N 259900.00 E 70° 21' 08.5113" N 147° 56' 59.2989" W 10086.00 1255.21 N 993.20 E 10031.00 5983696.00 N 260000.00 E 70° 21' 22.1379" N 147° 56' 57.6726" W Target Boundary Point #1 10086.00 293.24 $ 941.99 E #2 10086.00 110,28 N 1200,14 E #3 10086.00 801.63 N 1106.85 E #4 10086.00 1266.04 N 1080.90 E #5 10086.00 1261.38 N 904.96 E ~ 10086.00 818.00 N 745.14 E #7 10086.00 90.59 N 526.43 E #8 10086.00 77.76 N 500.83 E Alaska Drilling & Wells Endicott DI-MPI Target Target Shape Type Point Geological Polygon Ddllers 1 April, 2001 - 13:55 Page 6 of 8 DrillQuest 2,00.08,004 Sperry-Sun Drilling Services Proposal Report for 2-28A/0-19 Rig 2-28a/0-19 Wp 14 (Considering Coal Section) Your Ref: 'Wellplan 13' w~ Revised Formation Tops (3-30-01) Alaska State Plane 3 Target Name Targets associated with this wellpath (Continued) .,#,,~ ~}ill~ Mean Sea LeveVOl~rC~na~[~l ~ O~gmphical Cm~inates $1 ~~1~1 "l~l~' ~5 ~4~6 ~7 ~8 ~'~.~; .': ~i.. ,. ,~. ?,.I?.~:.."'..~'::;~:~. "'~ ,~,,i ",!,"~,,h ,,~,- ,'.!',~': ;,.':'~,~'~ ,?:,.,, i,~,~' ,~ F-~ [,l:, ';, .~,;,'.;., ,.,.,m.c.,. '~,,,: /'~ ',,~,. i,?~ ',;. '?. .~a ,,~,.. .~.7,~,, b ' .., ,1~ ~ ~ ,,, · . T ~.'~I ,(~i~"¢L',,.~'~; ~r~mngu Eastings . ;~ ~.~ .... :~,: ..~ ~:..,~,~ ..., ,.,..'~ ".5'~ "~? ~:,. "%. } '~,,;,,~ 10031.00 5982150.00 N 259899.00 E 10031.00 5982545.00 N 260170.00 E 10031.00 5983239.00 N 260099.00 E 10031.00 5983704.00 N 260088.00 E 10031.00 5983705.00 N 259912.00 E 10031.00 5983267.00 N 259738.00 E 10031.00 5982547.00 N 259496.00 E 10031.00 5982535.00 N 259470.00 E 70° 21' 06.9086" N 147° 56' 59.1754" W 70° 21' 10.8769" N 147° 56' 51.6283" W 70° 21' 17.6767" N 147° 56' 54.3521" W 70° 21' 22.2443" N 147° 56' 55.1088" W 70° 21' 22.1986" N 147° 57' 00.2523" W 70° 21' 17.8382" N 147° 57' 04.9257" W 70° 21' 10.6841" N 147° 57' 11.3207" W 70° 21' 10.5579" N 147° 57' 12.0690" W HARDLINES Mean Sea Level/Global Coordinates: Geographical Coordinates: 10130.00 20.43 S 714.10 E 10075.00 5982430.00 N 259680.00 E 70o21'09.5920"N 147057'05.8355"W Target Boundary Point #1 #2 #3 #4 #5 #6 #7 #8 #9 #10 10130.00 976.47 N 1161.26 E 10130.00 328.81N 1182.10 E 10130.00 9.61N 1274.42 E 10130.00 303.04 $ 948.31E 10130.00 427.45 S 813.24 E 10130.00 123.03 $ 448.26 E 10130.00 1156.02 N 771.28 E 10130.00 1418.09 N 1017.98 E 10130.00 1235.72 N 1195.94 E 10130.00 976.47 N 1161.26 E Alaska Drilling & Wells Endicott DI-MPI Target Target Shape Type Polygon 1 April, 2001 - 13:55 Page 7 of 8 DrillQuest 2,00.08.004 Sperry-Sun Drilling Services Proposal Report for 2-28A/0-19 Rig 2-28a/0-19 Wp 14 (Considering Coal Section) Your Ref: 'Wellplan 13' w/Revised Formation Tops (3-30-01) ..~i , '~ .,~1~ ; L,~,,.~,', ',,~. ~,~. "~.~.'~?'~' .,~-1~,,I ,- ~ ?,- . Alaska State Plane 3 .~.~ ~,~, , . T a r4t~e'~'.,,~ E.. ~oordinate~ Target ~ ~{~ 'N,~things Eastings Targets associated with this wellpath (Continued) ~~.~.,~ ~ Mean Sea LeveVGI~J~n----~=~' 10075.00 5983412.00N 260159.00 ,~l~ll~ ~'~~J ~3#4 10075.00 5982764.00 N 260159.00 10075.00 5982442.00 N 260241.00 10075.00 5982020.00 N 259766.00 10075.00 5982336.00 N 259411.00 10075.00 5983604.00 N 259775.00 I¢ #8 10075.00 5983858.00 N 260030.00 #9 10075.00 5983670.00 N 260202.00 #10 10075.00 5983412.00 N 260159.00 Geographical Coordinates #1 70° 21' 19.3962" N 147° 56' 52.7610" W #2 70° 21' 13.0263" N 147° 56' 52.1546" W #3 70° 21' 09.8868" N 147° 56' 49.4577" W #4 70° 21' 06.8122" N 147° 56' 58.9908" W #5 70° 21' 05.5888" N 147° 57' 02.9389" W #6 70° 21'08.5831" N 147° 57' 13.6058" W #7 70° 21' 21.1626" N 147° 57' 04.1606" W #8 70° 21' 23.7398" N 147° 56' 56.9478" W #9 70° 21'21.9459" N 147° 56' 51.7461" W #10 70° 21' 19.3962" N 147° 56' 52.7610" W PBHL (wplO) Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: 10086.00 1255.21 N 993.20 E 10031.00 5983696.00 N 260000.00 E 70° 21' 22.1379" N 147° 56' 57.6726" W Alaska Drilling & Wells Endicott DI-MP! Target Target Shape Type E E E E E E E E E E Point Geological 1 April, 2001 - 13:55 Page 8 of 8 DrillQuest 2.00.08.004 Sperry-Sun Drilling Services Proposal Data - 2-28A/0-19 Rig - 2-28a/0-19 Wp14 (Considering Coal Section) ' MD Delta ;.'.nc].in. Azimuth TVD Delta Northings ! Eastings Dogleg A. iA. Tarn T°olface VS (25°) (fi) M~) i (o) : (ft) i TVD ' (ft) i (ft) ,°/100fti Build i °/100ft (ft) [ [ ........ (.ft..) ......... :-1 , o,-~.". 0""! 6 8'~3 161 379/ 9547 63l 1598:101.02 ~B59262.'78 ~,', ] , ! .... 213.89 .... "~' '~ ~ ' ~ ~ ' ' ~ ~ ' 4 '~__~ ................... ~ ..... ! ............ L .................................. 2 , 9750.00 :.CC, ',,',' ]6.077 140.300! 9645.571 97 . 94 5982084. 68 N~59273.SD E: =~..u'~'c. 9.244 .... 21.079 .~/.:~.:~,u':,3 -224.20 ................................ ~ ..... ~.------ .......... .-!-- ........ ' ............. ~ 3 ~ 9850.00! ~:~,0.£,3126.335[ 117.442J 9738.83 93.26j5982063.72 N~59302.20 E~, ~3.000 10.257i .... 22.858= 3~0.,~.0~ .... 231.21 ...................4' i-j10058.151 ..................................................... 208.15~51.153!~ ............................. 79.812:~' ........................................ 9!)C2.C:C,,i 163'.175982056.58: ............. ~ ............................................... N,259426.47~ ........................................ E'~¢ ................................................................................. '_6.00C 11.923! .... 18.078.! 300.800 .......................... -185.55: ............ ~. ~ ' J~ ; .... .1. ................... .~-. ~ ........ --4-' .......... ' ......................................... 5' '1013~ 67 76 52!51 153~ 79 812 e,~?: :~,r.~ ~8 005982067 12 N~59485 13 E' ~, nr, c, 0 000 0 0001 0 000 .... 151 37' , " ; ..... i ' : ~ ~ '" .... . ........ ~.' '~_.__J.. ' ' .L .............. "- ........ 6' 10236.34 101.6'7 64.925 90.0'73 10003.79 53.795982074.11 N259570.72 E ~..0~,C' 13.546 10.093 35.169 ...109.12 7T' 10685.24 448.90 90.0~0 22.B44 10113.80 109.2159~2313.00 N259905.00 E 15.676 5.586 -15.199 279.606 245.88. ~ ~ 10802.7.~117.5~ 93.5~7 3.359 1010~.35 -3'~./-.~f'~';'~'T:,-~"-~"~¢-¢'~/5':~-~-~'j'~;?.,'i~. ............. :J6'~-i-"'-"~.'~-7~-~ ..... '~--~'~i~"~-~ ............. J~'~" 9T 12076.24 1273.46 93.527 3.359 '$031.C.C -78.355983696.00 ~26,5000.03 E 0.000 0.000 0.000 0.000 1543.23 30 March, 2001 - 14:45 - I - DrillQuest Sperry Sun Drilling S rvices Proposal Data- 2-28A/0-19 Rig- 2-28a/0-19 Wp14 (Considering Coal Section) Cnclin-i}.Azimuth{' ' .TVD '..De'lta · .:. (o). I (ft) 'TVD ."loi ' .I ". "i"F~-'% .' 6.833 159'.'~35{.' 9602".631 .':'"" '51 ..~:5.3 i:~ ...,~ ~,.. ~ 6 ~,,I '-' F~"~ :;': 3'3[' ~ .i~3. z -~.: ~ -. 77. .., ~! i o ~'~"E"o o l-~72-d ~-3~ 88'.230 10058'.~79 · 53.'79:3.79.65.'S 616.32 20.000 10168.00 ':.. "10~ :,'21' 130.29 S 937.75 ~0rthingsiEastings Dogleg..l .. A,' ' ' °/100fi i' ·Build · re.,,- ,, . { ' ~..¢~ ~: ' { o/~_O.fl~F~ 3'~2':~'~1~o7.~7::~1 '" - .'. · .3~.8. ~4. &l 3~ a, ~ ':~l '-~%-01 · '~ .'~ ~4 :..~,:8.:.~7 sizzle=8 ~j ..... ;;-':'o~'~:~',7 ,.~'~.~, sl~n..oo ~i ' o.~'~'o"i~E~% 26.000 Zi.~7~',: 8 1'0802 ;'79 :";117 .'54 93,527' · .. 9T ' 12076,.'24' 1273.46 9'3.527.< '1'.515 !01'64,.35 '::3.65 15,39 S 959.60-'~. 16.000 ·3.001 ··115,726 281,0'02 " ..... . .... 1.. 515 1008 ~. 00..-_ 'il_.~j_%s... :L 255.2 %.. ~J. 993.2.0 ~. ...... .0_..._0..0__0 ..... '0__._9_97. ........ _?__O_O_O______O_:.9.0_o_o_.._.'L~I~.43_.?_3_: 30 March, 2001 - 14:45 - I - DrillC}uest slaer' ,-sun. DFIIFI~I-IN E SI~RVICeS A Halffbmton Company Alaska State Plane 3 Alaska Drilling & Wells Endicott DI-MPI 2-28AJO-19 wp14 I DrillQuest' 9400 Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: North Reference: Units: 2-28AJO-19 wp14 5982473.39 N, 258966.93 E 3207.81 N, 2183.73 E 70° 21' 09.7933" N, 147° 57' 26.7078' W 55.00ft above Mean Sea Level 55.00ft above Structure Reference True North Feet Proposal Data for 2-28a/O-19 wp14 Vertical Origin: Well Horizontal Origin: Well Measurement Units: ff North Reference: True North Dogleg severity: Degrees per 100 feet Vertical Section Azimuth: 22.963° Vertical Section Description: Well Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 9650.00 6.833 159.535 9602.63 362.66 $ 307.67 E -213.89 9750.00 16.077 138.456 9700.57 378.64 S 318.97 E -224.20 10.00 9850.00 26.335 115.598 9793.83 398.67 S 348.28 E -231.21 13.00 10058.15 51.153 77.969 9957.00 401.81S 472.71E -185.55 16.00 10134.67 51.153 77.969 10005.00 389.39 S 531.00 E -151.37 0.00 10236.34 64.925 88.230 10058.79 379.65 S 616.32 E -109.12 16.00 10685.24 90.000 20.000 10168.00 130.29 S 937.75 E 245.88 15.68 10802.79 93.527 1.515 10164.35 15.39 S 959.60 E 360.20 16.00 12076.24 93.527 1.515 10086.00 1255.21N 993.20E 1543.23 0.00 9600 7' casing 965o.oo' MD 9602.63' TVD S.T. off Whip w/TF - 35L (6" Hole Thru 7" Csg) @ 10.0°/100ft: 9650.00 ft MD, 9602.63 ff 'I'VD 9800 10000 10200 Increase DLS to13..0°/100 ft: 9750.00 ff MD, 9700.57 fl TVD .... Increase DLS to 16.0°1100 fl: 9850.00 fl MD, 9793.83 ff TVD Dir, Start S~il @ 51.15°: 10058.15 ff MD, 9957.00 fl TVD _..- I Begin Dir ~ 16.00°/100ft: 10134.67 fl MD, 10005.00 ft TVD · ~ ..... ' .... . . . :,T.-:i:~ .?,.-.~-~-.:.;;:~ ,~;:~.: ~.-(:: - ~ ~?'.::~3;.:¥)' ~:'~-] ~ .... ":~'* ~ Continjue Dir @ 15.68°/100 ft: 10236.34 ft MD, 10058.79 ff TVD -. .~ ~'~ .......................................... .~ - .. ~ 2-28X019 MOD 1 d Dir, Start Sail @ 93.527°: 10802.79 ft MD, 10164.35 ft TVD ~ 101#8.00 TVD, 130.29S, 937.75E i Continue Dir @ 16.0°/100ft: 10685.24 ft MD, 10168.00 ftTVD -200 n 200 400 600 800 1000 Scale: linch = 200ft Total Depth: 12076.24 fl MD, 10086.00 ftTVD · . · ! ! PBH£ (wplO) / ~OOB~.O0 TVD, 1~$~.21 gl, ~$.20 ~ ~ol¥§on 'l'argot, Th~ckno$s: $O. OOfl I I I 1200 1400 1600 JPrepared by: JOate/Time: Dave Egedahl J 1 April, 2001 - 13:32 sP~'~r~-sun.I ORII-I-ING SERVIC~:S A HIIIIburlon Alaska State Plane 3 Alaska Drilling & Wells Endicott DI-MPI 2-28A/O-19 wp14 I DrillQuestTM 1500 - 1250 - 1000 - 750 - 500 - 250 - 0 -250 7' Casing 9650.00' MD 9602.65' TVD N Reference is True North PBHL (wplO) Point Target 10086.00 TVD, 1255.21 N, 993.20 E / I / I Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: North Reference: Units: 2-28A/O-19 wp14 5982473.39 N, 258966.93 E 3207.81 N, 2183.73 E 70* 21' 09.7933" N, 147' 57' 26.7078" W 55.00ft above Mean Sea Level 55.00ft above Structure Reference True North Feet Total Depth: 12076.24 ft MD, 10086.00 ft TVD Drillers Target (95%) Polygon Target 10086.00 TVD, 1255.21 N, 993.20 E 6.0'/100ft: 10685.24 ft MD, 10168.00 ff TVD 2-28/019 MOD 1 ~ oo Point Target ~ TVD, S, 937.75 E 10168.00 130.29 ~%~.~o oo ~1 Conti~ D/ir 5.68°/100 ft: 10236.34 ft MD, 10058.79 ft TVD in Dir @ 16.00°/100f1:10134.67 ft MD, 10005.00 ft TVD Dir, Start Sail @ 51.15°: 10058.15 ft MD, 9957.00 ft TVD DLS to 16.0°/100 ft: 9850.00 ft MD, 9793.83 ft TVD o13.0°/100 ft: 9750.00 ft MD, 9700.57 ft TVD S,T. off Whip w/TF ~ 35L (6" Hole Thru 7" Csg) @ 10.0°/100ft: 9650.00 ff MD, 9602.63 ft TVD I I I I I 375 625 875 1125 1375 I 1625 Scale: linch = 250ft Eastings Prepared by: ~)ate/Tlme: Dave ~.,='l~hl ! 30 Mamh, 2001 - 16:35 DrillQuest 2.00.08.004 sP= -sun.I O,Fll L.I-I NG S~:FlVlCGS .. Alaska State Plane 3 Alaska Drilling & Wells Endicott DI-MPI 2-28A/O-19 wp14 I DrillQuest N Reference is True North Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ret Structure Reference: Ref. Geographical Coordinates: RKB Elevation: North Reference: Units: 2-28A/O-19 wp14 5982473,39 N, 258966.93 E 3207.81 N, 2183.73 E 70° 21' 09.7933" N, 147° 57' 26.7078" W 55.00ft above Mean Sea Level 55.00ft above Structure Reference True North Feet Proposal Data for 2-28a/O-19 wp14 Vertical Origin: Well Horizontal Origin: Well Measurement Units: ft North Reference: True North Dogleg severity: Degrees per 100 feet Vertical Section Azimuth: 22,963° Vertical Section Description: Well Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 9650.00 6.833 159.535 9602.63 362.66 $ 307.67 E -213.89 9750.00 16.077 138.456 9700.57 378.64 S 318.97 E -224.20 10.00 9850.00 26.335 115.598 9793.83 398.67 S 348.28 E -231.21 13.00 10058.15 51.153 77.969 9957.00 401.81 $ 472.71E -185.55 16.00 10134.67 51.153 77.969 10005.00 389.39 $ 531.00 E -151.37 0.00 10236.34 64.925 88.230 10058.79 379.65 S 616.32 E -109.12 16.00 10685.24 90.000 20.000 10168.00 130.29 S 937.75 E 245.88 15.68 10802.79 93.527 1.515 10164.35 15.39 S 959.60 E 360.20 16.00 12076.24 93.527 1.515 10086.00 1255.21N 993.20 E 1543.23 0.00 Single Well Target Data for 2-28AJO-19 wp14 Measurement Units: ff Coordinate Target Point TVD Northings Eastings (SS) ASP (3) ASP (3) Target Name Type TVD Northings Eastings Shape 2-28/O19 MOD 1 Entry Point 10168.00 130.29 S 937.75 E 10113.00 5982313.00 N 259900.00 E Point Drillers Target (95%) Entry Point 10086.00 1255.21 N 993.20 E 10031.00 5983696,00 N 260000,00 E Polygo'n :Botmdary Point A 10086.00 293.24 S 941.99 E 101)31,00 5982150.00 N 259899.00 F 'B 112)086.0() 110,28 N 1201.). 14. E 11)('.)31,00 5982545,00 N 260170,00 'E C 10086.00 8{i)1,63 N 1101i.85 E 101.131,()0 5983239,00 N 2601.)99,00E D 1 t)086.00 1266,04 .N 1080.90 E 10031.00 5983704,00 N 260088.00 .E E 10086,00 1261.38 N' 904.96 E 101131.00 5983705,011 N 259912.(10 ',E F 1 ()086,00 818,01) N 745.14 E 10031,00 5983267,00 N 259738,00 E G 10086,00 90.59 N 526.43 E 10031 ,()0 5982547.011N 259496,00 iE H 11)086,01) 77,76 N 51',~(',).83 E 11)031 .()0 5982535,00 N 259470,()0 ',E HARDLINES Entry Poim 10130.00 20.43 S 714.10 E 10075.00 5982430.00 N 259680.00 E Polygon BoundaryPoint A 10130.00 976.47 N 1161.26 E 10075.00 5983412.00 N 260159.00'E B 10130.00 328.81 N 1182.10 E 10075.00 5982764.00 N 260159.00 E C 10130.00 9.61 N 1274.42 E 10075.00 5982442.00 N 260241.00 E D 10130.00 303.04 S 948.31 E 10075.00 5982140.00 N 259905.00 E E 10130.00 427.45 S 813.24 E 10075.00 5982020.00 N 259766.00 E F 10130.00 123.03 S 448.26 E 10075.00 5982336.00 N 259411.00 E G 10130.00 1156.02 N 771.28 E 10075.00 5983604.00 N 259775.00 E H 10130.00 1418.09 N 1017.98 E 10075.00 5983858.00 N 260030.00 E I 10130.00 1235.72 N 1195.94 E 10075.00 5983670.00 N 260202.00 E J 10130.00 976.47 N 1161.26 E 10075.00 5983412.00 N 260159.00 E PBHL (wpl0) Entry Point 10086.00 1255.21 N 993.20 E 10031.00 5983696.00 N 260000.00 E Point Prepared by: Date/rime: Dave Egedahl 30 March, 2001 - 16:35 DrillQuest 2.00.08.004 Sperry-Sun Anticollision Report Date: 03/30/2001 'time: 14:34:29 P~ge: I Co-ordinate(NE) Reference: Vertical (TVD) Reference: Compaq: BP Amoco ~eld: Endicott Reference Site: End MPI Well: 2-28/P-19, True North Reference Well: 2-28/13-19 34: 28 7/30/1988 00:00 55.0 Ret'ereace Wellpath: Plan: 2-28A/O-19 Db: Oracle GLOBAL SCAN APPLIED: All welipaths within 200'+ 100/1000 of reference - There are TBBBmmiis in this t~blh: 2-28a/O-19 wp14 & NOT PLANNED Interpolation Method: MD Interval: 100.0000 ft Error Model: ISCWSA Ellipse Depth Range: 9650.0000 to 12075.2946 ft Scan Method: Trav Cylinder North Maximum Radius:1403.5896 ff Error Surface: Ellipse + Casing Casing Points l MD · TVD Diameter Hole Size Name · ft . . ft . in in 6so.o--~0 -~o2.~ .112076.396010086.0004 7.0000 8.5000 7" 5.5000 6.0000 5 1/2" Man: 2-28a/O-19 wp14 Date Composed: 03/20/2001 Version: 1 ]~rincipal: Yes Tied-to: From: Definitive Path Summa7 ~....- ../~. ~=~ ~;~..:,.~.~'...~'~,~.~', ~ .~:,.,-~:~;.,:;~.~;. :.,..~.,:.: ~ ~,~.~,.~,;'f~ .,.,~. ~ ~ .,,f~..~ ..~..~ ~.:~,~.~.~,.~.~,~=. ~= ~'~.~,-.' ,~ .,~.~ . ~: .... ?.~ .~'~, .~ ,;~ ,, ~.~. ~?...:~.'r.~..,..?:...~ ~ ~,.~..~.,..~. · ...~,,.~.;.~,~:[, ,:.~?z.,.;~..~,,;~... . ....... ~ ........................ . ..... ~,~., ....................... ~ .................................... ~ ........... ~.~..~..,~ ................. ~..~.? ........ ..=..~ ...... . ..... ~.~....,~ End MPI 1-0~P-16 1-03~-16 Vl O~ of range End MPI 1-03/P-16 End MPI 1-05/O-20 End MPI 1-23/O-15 End MPI 1-25/N-22 End MPI 1-27/P-20 End MPI 1-39/P-17 End MPI 1-47A/M-20 End MPI 1-47NPB1 End MPI 1-47NPB2 End MPI 1-53/Q-20 End MPI 1-61/Q-20 End MPI 2-04/M-19 End MPI 2-14/O-16 End MPI 2-18/L-16 End MPI 2-28/P-19 End MPI 2-28/P-19 End MPI 2-62/Q-17 1-03/P16PH V5 1-05/O-20 V1 1-23/O-15 V1 1-25/N-22 V1 1-27/P-20 V1 10500.000010000.00001284.6860103.86961186.5803 1-39/P-17 V1 9650.0000 9900.00001213.6796187.86251131.8864 1-47A/M-20 V3 Plan: Url10625.000011100.00001200.9422155.39991066.3063 1-47A/PB1 V3 1-47A/PB2 V2 1-53/Q-20 Vl 1-61/Q-20 V1 2-04/M-19 V1 2-14/O-16 V1 2-18/L-16 V1 2-28/P- 19 V4 2-28APB1\O-19 V2 2-62/Q-17 V1 10625.000011100.00001197.8074155.62701063.0249 10625.000011100.00001200.9756154.67521066.8228 10350.0000 9739.0000 839.527~00.9679 754.6061 10350.0000 9800.0000 775.339~01.6403 689.4348 11991.733ffi0200.00001129.5338155.2793 978.8597 12046.203~0500.0000 312.601~50.8869 163.4021 9699.8711 9700.0000 2.2077 0.0010 2.2067 9699.9102 9700.0000 1.6895 64.2760 -61.0758 9650.0000 9800.00001315.6764 94.49991227.5905 Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: NOERRORS FAIL: Major Risk Pass: Major Risk ROG ~ +N/-s +~-w No~t~n~ ~ L~'~- Lon~tnd~ Slnt ~28/P-19 3208_.~90 21S2.S'/66 598~1q3.3886 258~66.9317 70~.1~9.911N 147:3~26.704W 2~ SURVEY PROGRAM l:hrpthFan Dq~To Smn~-y/Phn Tool 9650.0000 12ff/5~16 lqmmJ: 2-2b/C)- 19 'A'pl4 ¥ 1 MWD --1456 --30O --0 --300 ANTI-COLLISION SEI'TINGS Interpolation Method:MD Interval: 100.0000 Depth Range From: 9650.0000 To: 12075.2946 Maximum Range: 1403.5896 Reference: Plan: 2-28n/O-19 wpl4 From ColourTo MD 0 9S00 9S00 10000 10000 .... 10500 10S00 11000 11000 ........... 1 IS00 1 IS00 12000 12000 12500 12500 13000 13000 13500 13500 14000 14000 14500 14500 15000 15000 15500 160OO 165O0 --1456 WELLPA'fH DETAILS Pkn: 2-28AK~19 trot Welling' 2-28/P- 19 Tie on 1~ ~60.0000 Doym 15 Ref. An~ +NbS +F_J-W Fn~n TVD 38.351° O.(XlO0 0.0000 0.GO00 COMPANY DETAILS BP Ammo Enor Smface: El~l~iml + Ca,rig Wining Me~hod: Ruks Btml "=39 -30 From Colour 0 9500 10000 10500 II000 ! 1500 12000 12500 13OO0 135O0 14OOO To MD 95O0 10000 10500 I1000 11500 12000 12500 13000 13500 14000 14500 15OOO 155O0 16000 16500 19 (2-28APBI\O-19) IePk~ 2-28a/O- 19 wpl4 (2-28/P- 19/Plan: 2-28A~}- P sr, al~! By: DeWaym~ i~111 DnI~ {1~/30'"~-00. becked: Date: pprm'ed: Date: Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Sepamlion [20ft/in] Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Cenlxe Separation [600ft/in] DRAFT COPY (w..p SECI'iON DETAILS Sec MD [nc A~ 'rVD +NbS +E/-WD~e$TFac~ VS~c Target 1 9650.0000 6.830 159..n40 9602-.6341 -362.6614 307.6732 0.000 0.000-935018 9750.0000 16.074 138,457 9700.5732 -37g.6350 318.~616 IO.O00 325.000 -99.0243 3 9S50.0000 26.332 115.597 9793.g306 -39S.6649 348.2707 13.000 310.000 -96.,q465 ]005g.1337 51.1~ 77.g67 g957.0G00 -J,01.8015 472.6882 16.000 34X).000 -21.g077 101M.6521 5LI49 77.967 IG0(D.(X]00 -3893~6 530.9697 O.000 0.00024.0972 6 102~65721 64.930 8g~010058.8175 -3793328 6J6.329J J6.000 35. J$8 84.7010 710685.2470 90.000 20.000 10168.0000 -130.2g0~ 937.7450 15.677 279.605 479.6759 S108~.87.43 93_~30 I~il0 10164.3474 -153561 9.59-~947 16.(}00 281.0~ 5S33674 9I-'2075.2946 93330 1.SlO 10~6.0000 12547.589 993.0625 O.0GO 0.0001599.7932 PBHL(~pI0) 2-28A/O-19 Sidetrack Operations Subject: 2-28A/O-19 Sidetrack Operations Date: Thu, 29 Mar 2001 12:40:12 -0600 From: "Hupp, Jeffrey L" <HuppJL@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder~admin.state.ak.us> CC: "Archey, Pat" <ArcheyPJ~iBP.com>, "Hubble, Terrie L" <HubbleTL~BP.com> Based on the present Endicott rig schedule, the suspended 2-28A/O-19 well will be re-entered and drilled as a conventional sidetrack to essentially the same bottom hole location The new sidetrack operation is expected to commence on 4/20/01. This date may vary by a few days based the previous operations (3-25A/N-24 Sidetrack & 3-161K-33 rig workover). Call or e-mail me if you have any further questions. Jeff Hupp MB 447 Phone: (907) 564-5344 Cell: (907) 240-8057 Fax: (907) 564-5193 e-mail: huppji~bp.com 1 of I 3/29/01 10:24 AM STATE OF ALASKA ALASK,~ .L AND GAS CONSERVATION COMI(r'' APPLICATION FOR SUNDRY APPROVAL 31ON 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 2310' SNL, 1931' WEL, SEC. 36, T12N, R16E, UM At effective depth [] Suspend [] Repair Well [] Operation Shutdown (Planned) [] Plugging [] Time Extension [] Pull Tubing [] Vadance [] Re-Enter Suspended Well [] Stimulate 12. At total depth 684' SNL, 1247' WEL, SEC. 36, T12N, R16E, UM Size 30" 13-3/8" 9-5/8". 7" (Planned) [] Perforate [] Other 6. Datum Elevation (DF or KB) KBE = 55.00' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 2-28A/O- 19 9. Permit Number 201-018 10. APl Number 50- 02921847-01 11. Field and Pool Endicott Field / Endicott Pool Present well condition summary Total depth: measured 10223 feet true vertical 10087 feet Effective depth: measured 9675 feet true vertical 9627 feet Casing Length Structural Conductor 92' Surface 2465' Intermediate Production 9605' Liner 1144' 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Plugs (measured) Junk (measured) Cemented Driven 3687 cu. ft. Permafrost 575 cu. ff. Class 'G' 517 cu. ff. Class 'G' Whipstock at 9675'; Perf Abandonment Cement below Whipstock (03/01) 3 Bowspdng Leafs at 10448' 3-1/2" tailpipe cut and dropped to bottom (03/01) MD 'I'VD 131' 131' 2504' 2503' 9644' 9597' 9383'-9675' 9338'-9627' Perforation depth: measured None- Abandoned Perf's for Sidetrack Operation.RE C E J V E D true vertical None MAR l 9 Z0Ol Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 9339' Alaska Oil & Gas Cons. Commission " Anchorage Packers and SSSV (type and measured depth) 9-5/8" Baker 'SAB' packer at 9339'; 4-1/2" SSSV Landing Nipple at 1555' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation 115. March 11, 2001 !16. If proposal was verbally approve(~.'.~ Tom Maunder ~ I ~/f,/-u~'~"-3fl 1/2001 Name of approver Date Approved Contact Engineer Name/Number: Jeff Hupp, 564-5344 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that Signed Jeff Hupp is true and correct to the best of my knowledge Title Senior Drilling Engineer Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test . Subseauent form required 10- gRIGINA"L SIGNED order of the Oommission D Taylor Seamount Form 10-403 Rev. 06/15/88 Approval No. q;~ fi / "' · Commissioner Date Submit In Triplicate bp (' Date: March 19, 2001 Subject: MPI 2-28A/O-19 Temporary Abandonment Procedure The procedure will cover the plug and abandonment of the 3.70" open hole and suspension of the 2-28A/O-19 drilling operation. The procedure was revised to reflect pumping the cement prior to POH with the 2-3/8" drill pipe. Verbal approval was received from Tom Maunder of the AOGCC on 3/11/01. 1. After backing off the 2-3/8" drill pipe at 9691', circulate and prepare to plug and abandon the 3.70" window. 2. RU Schlumberger Dowell to set cement plug. 3. Based on the back of depth of 9691', a 17 bbls cement slurry will be spotted through the 2-3/8" drill pipe. This volume is based on 0.3 bbls in the 3.70" open hole, 10.8 bbl in the 7" liner above the whipstock and 2 bbls in the 9-5/8" csg below the production packer at 9339' MD. A 20% excess is included to increase to volume to 17.0 bbls. 4. Spot the 17 bbls 15.8 ppg cement slurry from 9691 to 9339'. 5. PU to the packer at 9339' MD. Circulate while cement develops 1500 psi compressive strength. 6. After cement develops 1500 psi compressive strength, RIH and tag cement. Wt test cement with 30K lbs. Pressure test cement to 2000 psi. 7. After testing cement, displace well to 11.0 ppg brine. 8. POH w/2-3/8" drill pipe. Freeze protect top 1500' with diesel. 9. SET BPV. ND BOPE. 10. NU dry hole tree. Test tree to 2000 psi. 11. RD & MO Doyon 15. Please contact Jeff Hupp (564- 5344 or 240-8057 cell) with any questions or concerns. Sr. Drlg Egr~ Attachments cc:Well File RECEIVED 1_. 9 Alaska Oi~ & Gas Cons. Commission Anchorage Page 1 of 1 TREE: 4-1/16" / 5000 psi / McEVOY PT. ELEV = 55.0' 13-5/8" / 5000 psi / McEVOY BF. ELEV = 15.8' . .... MAX. DEV. = 13:33 8000' MD NT-80 CYHE, BTRS. COG. '~---- OTIS (3.813" MIN. ID) ~ 2504' I "~ ,~ ' !~. W/SSSV MIN I.D. 2" I I im,---- ~ I-- 4-1/2", 1 2.6#/ft, L-80, ' BTRS A/B Mod. TUBING i GAS LIFT MANDRELS (MERLA) NO. TVDSS M D-BRT .il '~ I-- #6 41 48' 42 04' #5 63 37' 63 93' #4 77 76' 78 45' 9-5/8", 47#/ft, I I #1 90 57' 91 55' ~[T=~I"" I SLIDINGSLEEVECAMCOII 3.75" ID confirmed by PDS survey ,. 9265 9-5/8" PACKER (BAKE R "SAB ") 93 39' :~ x x x-~~ TO. o. I I ;: x x x )_~. ~ 3-1/2,,, 9.2#/ft, L-SO TAILPIPEi 7"- 9383'. ~~ E~ X X X ) ~ cut and dropped to PBTD J LINER = ~ ,' x x x ). Set 15.8 ppg cement plug ,' X x x ). f/'9912-9335. Wt'd tested w/30K# 9-5/8", 47#/ft,, '1 , i · NT95HS,. . I 9644 . ,' X X X ~ ~.~' fessure tested w/2000 psi. . ,. IBaher Thr u-'rbg w hipst°ck I I set ~ ,~?s' I Ex isfing perforations plugged with 22 bbb of crrt , PER I=ORA'n ON SUMMARY REF: LOG: DLL-GR (08-13-88) SIZE SPF INTB:IVAL S'rATUS 2-1/8 4 10114'- 10160' SQZD 2-1/8 6 10145' - 10157' OPEN 2-1/8 4 10180'- 10200' SQZD : ' ' Drilled 3.70" hole to 10223' MD 2-1/8 4 10188'- 1 021 3' OPEN I!Stuck BHA ontrip @9912'. 2-1/8 4 10216'- 10246' OPEN Attempted unsuccessfully to free BHA. I I Backed off & BHA. Cemented back to packer @ 9335' MD. I~~ 3 BOWS PRI NG PBTD I 10,448' I ~ -- ~- LEAFS 7" - 29 #/ft, SM-11 0'1! 10,5 27' I ~ BTRS-TKC I DATE REV. BY COMMENTS ENDICOTT WELL 2-28A/O-19 1/9/01 JLH Temporary Abandonment APl NO: 50-02~1-21 847-01 Tempora~ Abandonment Schematic BP EXPLORATION, INC. I SIZE SPF INTB:IVAL S'rATUS 2-1/8 4 10114' - 10160' SQZD 2-1/8 6 10145' - 1 0157' OPEN 2-1/8 4 10180' - 1 0200' SOZD 2-1/8 4 10188' - 1 021 3' OPEN 2-1/8 4 10216'- 10246' OPEN Re: 2-28 O-19 P&A procedure Subject: Re: 2-28 0-19 P&A procedure Date: Mon, 12 Mar 2001 09:16:01 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Hupp, Jeffrey L" <HuppJL@bp.com> Jeff, Thanks for the information. Bad news about the problems. Your proposal is appropriate, as we discussed over the week end. Please follow-up with the appropriate 403. Based on our discussion that it is likely that a full sized sidetrack may be the remaining option, I believe that this action should be considered a P&A of the A sidetrack. Let me know your thoughts on this. Tom Maunder "Hupp, Jeffrey L" wrote: <<End 2-26 0.19 P&A procedure Rev 1.doc>> The P&A procedure for the Endicott 2-28A/0.19 well we discussed on 3/11/01. The cement has been spotted and we are presently circulating waiting on the cement to develop compressive strength prior to wt testing the cement plug. Call me if you have any questions. Jeff Hupp MB 447 Phone: (907) 564-5344 Cell: (907) 240-6057 Fax: (907) 564,4441 e-ma#: huppjl@bp.com Name: End 2-26 O-19 P&A procedure Rev 1.doc End 2-28 0-19 P&A procedure Rev 1.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of I 3/22/01 2:43 PM Date: March 11, 2001 To: From: Doyon Rig 15 Rig Rep Mike Miller JeffHupp Work:564-5344, cell: 240-8057 Sr. Drilling Engr. Subject: MPI 2.28MO.!9 Temuorarv Ab..and, o. nment,.Procedu~. AFE #: 727,03! Sundry#: 190,!82 The procedure will cover the plug and abandonment of the 3.70" open hole and suspension of the 2-28A/O-19 drilling operation. The procedure was revised to reflect pumping the cement prior to POH with the 2-3/8" drill pipe. le , 8. 9. 10. 11. After backing off the 2-3/8" drill pipe at 9694', circulate and prepare to plug and abandon the 3.70" window. RU Schlumberger Dowell to set cement plug. Based on the back of depth of 9694', a 17 bbls cement slurry will be spotted through the 2-3/8" drill pipe. This volume is based on 0.3 bbls in the 3.70" open hole, 10.8 bbl'in the 7" liner above the whipstock and 2 bbls in the 9-5/8" csg below the production packer at 9339' MD. A 20% excess is included to increase to volume to 17.0 bbls. 4. Spet the 17 bbls 15.8 ppg cement slurry bom 9691 to 9339'. · BHST:209°F BHCT: 160°F · Fluid loss: 100 cc · Thickening time: 4 Hfs 5. PU to the packer at 9339' MD. Circulate while cement develops 1500 psi compressive strength. 6. ARer cement develops 1500 psi compressive strength, RIH and tag cement. Wt test cement with 30K lbs. Pressure test cement to 1500 psi. Al[er testing cement, displace well to 11.0 ppg brine. POH w/2-3/8" drill pipe. Freeze protect top 1500' with diesel SET BPV. ND BOPE. NU dry hole tree. Test tree to 2000 psi. RD & MO Doyon 15. Page 1 of 2 Please contact Jeff Hupp (ext. 5344 or 240-8057 cell) with any questions or concerns. JeffHupp Sr. Drlg Engr Mike Miller ACT! Drlg Supt. Mark Weggeland Endicott SS Team Leader Attachments cc Well File Dan Robertson Pat Archey Page 2 of 2 ALASKA OIL AND GAS CONSERVATION COM~SSION t / / / / / / / ! / / / TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276- 7542 ADMINISTRATIVE APPROVAL NO. 202.38 Re: Spacing Variance for Endicott 2-28/O-19 Well Mr. JeffHupp Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box' 196612 Anchorage, AK 99519-6612 · . Dear Mr. Hupp: We. have received your correspondence dated January 25, 2001 requesting a spacing variance for the Endicott 2-28/O-19 well. As proposed, the bottom hole location of 2- 28/0-19 is approximately 200 feet horizontal distance from the existing 2-14/O-16 well.. The proposed 2-28/0-19 well will be drilled as a high-angle producer in Subzone 2B. of the Kekiktuk Formation. Existing well 2-14/O-16 is a production well completed in Kekiktuk Subzone 2A. Subzone 2B is separated from the underlying Subzone' 2A by the K2M shale, which is a barrier to vertical flow. Recent static pressure measurements in this area indicate a pressure differential of approximately 280 PSIA exists between Subzones 2A and 2B. Drilling and completion of the 2-28/0-19 production well will not interfere with production from the adjacent 2-14/0-16 well. ., The Commission has determined placement of the well will not promote waste, will enhance recovery, and hereby approves the drilling of the Endicott 2-28/O-19 well as proposed pursuant to Rule 3 of Conservation Order No. 202. DONE in Anchorage, Alaska this/~.'~ day of February, 2001. Daniel T. Seamount, Jr. Commissioner aylor . Commissioner Julie Heusser Commissioner BY ORDER OF THE COMMISSION ALAS~ OIL AND GAS CONSERVATION COPlPIISSION / ! ,, ~t ! ! TONY KNOWLES, GOVERNOR 333 W. 'FTM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276- 7542 JeffHupp Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Duck Island Unit/Endicott 2-28A10-19 BP Exploration (Alaska) Inc. Permit No: 201-018 Sur Loc: 1944'SNL, 2240'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc. 684'SNL, 1247'WEL, Sec. 36, T12N, R16E, UM Dear Mr. Hupp: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this ~ .....- day of February, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. 'Department of Environmental Conservation w/o encl. bp ) January 25, 2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Mr. Steve Davies Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anch(~rage, Alaska 99501 Re: Proposed Endicott Well 2-28a/O-19 Spacing Variance Dear Steve: RECEIVED JI1N ,~ O, ZOO/ Alaska Oil & Gas Cons. Anchorage Commission Enclosed please find a map and Icg cross section showing the proposed Endicott. high angle TTRD sidetrack well 2-28a/O-19. 2'28a/O-19 is intended to drain Subzone K2B oil d0wndip of the gas. Prone K2B at 2-14/O-16, and updip of the water swept K2B at 2-28/P-19. Well 2-14/O-16, the neareSt existing well to the proposed 2-28a/O-19 BHL; is approximately 200 feet horizontal distance from the TD location of the proposed K2B 2-28a/O-19 producer. 2-14/O-16 however produces from the K2A, a deeper subzone at Endicott. Endicott Subzones K2A and K2B are separated vertically by a field-wide stratigraphic hydraulic barrier, the K2M shale, ranging from 20-40 feet TVD in the area. Recent static pressures (-10000 ft TVDss datum) indicate a reservoir pressure of 4585 psia for the K2B (2-28/P-19), and 4306 psia for the K2A (1-33b/-24), a differential of 279 psia. Well 2-14/O-16 is a former K2B producer, however the zone was completely squeezed off in December 1998.due to high gas produCtion and mechanical .. problems (combination of failed squeeze perforations behind a straddle and' corroded straddle tubing). Consequently them are no plans at this time to attempt to access K2B at 2-14/O-16 due to the risk of jeopardizing the existing K2A production in the well.' Current K2B producing wells near the planned. 2-28a/O-19 BHL include 1-03/P- 16 and 2-28/P-19. These wells are located (midpoint of producing intervals), at a horizontal distance of approximately 1500 feet to the north, and 1175 feet to the southwest, respectively, of the planned 2-28a/P-19 K2B well. BPX (Alaska) Inc. requests administrative approval to waive requirements stipulated in Title 20, AAC 25.055 (3) and allow well 2-28a/0-19 to be permitted within 1000 feet of existing well 2-14/0-16. Please contact me at 564-5345 if you wish to discuss this matter in further detail. Sincerely, bjv encl: Well location map Offset well log cross section cc: 2-28a/0-19 well file ec: . Weggeland, M. Vandergon, M. Robertson, D. Hupp, J.. Ding, E. Voorhees, B. RECEIVED JAN ,3 0 20~)? Alaska Oil & Gas Cons. Commission Anchorage ~,-,~, ~ 2-28alO-19 TTRD Dril'ling Proposal -' Target Location'Map'. 0-19 K2BL MPI Target . . . 2001 Endicott Field Drilling Program .- 2-57588' Z5850o '-z595eo Z-605oo z6t 580 z6z508 0-19 Volumetric Polygon i ,-% ~riller's ~z- ~0-19 TTRD Dr£11£ng et LocatiOn Ha . - ~ X. :'~ X~ :" .1_..- ~-'. "' ' ~-" ~:~:~:~.~'~:' ~]ue Con,ours ~e~_.~5OOF 'TVgsS,_ K2~/K2H-F-e~ C°lor CurrenE' CU]C...Thickness' . . z575~o ~s85oo zsgse~.- ZG050° ZGt500 i -22 26Z500 Attachment 2 ...,.. ~, .- .... ,: .';~ ... 2- -19 TTRD Drilling Proposal ~' ,~ ..-"....~.~.~..~. ~ ..... '"="~':'"~'""'~"':~ Offset Wells Log Cross Section N-24 K2A MPI Target 2001 Endicott Field Drilling Program South 2-2 8/P- 19 2-14/0-16 ,, -- North ~- -- 1750 ff ~ '--=~ .=..- -- K3A K2B (upper Mid Sh, K2B (Iowel~ Shal4 K2A Current OWC . -. K2B Iowor has long transisiton zono with OB/G at, or hoar top of sand K2B cemented off prior to depletion due to mechanical problems (3 mmbo cum);, RST OWC p50 -10061'ss vertical scale 00 ft Attachment 6 JAM 8G '01 10:38AM BP MILME POIMT GROUP {" BP EXPLORATION Fax cover Sheet P.1 Number of pages including cover sheet: ~ II. For your review n Reply ASAP 1~ Please comment IVED ~N g6 ?.001 JAM 2G, '01 10:39AM BP MILHE POIMT GROUP bp Janus,/25, 2001 BP Exp~oratlon (Alaska) thC, P.O. Box 1B8812 Anchorage, Alaska g9~19.6~12 (907) $61.$111 p.;:, O Mr, Steve Davies Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: P, ro=osed Endicott Well 2~28a/O-19 Spacing Variance Dear Steve: Enclosed please find a .map and log cross section showing the proposed' Endicott high angle TTRD 'sidetrack well. 2-28a/O-19. 2-28a/O-19 is intended t° drain Subzone K2B oil downdip' of the gas prone K2B at 2.14/O-16, and updip of the w, ater swept K2B at 2-28/P-19. Well 2-14/O-16,.the nearest existing well to the proposed 2-28a/O-19 BHL, is approximately 200 feet horizontal distance from the TD location of the prOposed K2B 2-28a/O-19 producer. 2-14/O-16 however produces from'the K2A, a deeper subzone at. Endicott. Endicott Subzones K2A and K2B are separated vertically by a field-wide stratigraphic hydraulic barrier, the' K2M shale, ranging frOm 20-40 feet TVD in the area,. Resent'static pressures (-10000 ff TVDss datum) indicate a reservoir pressure'of 4585 psis for the K2B (2-28/P-19), and 4306 psis for the K2A (1-33b/-24), a differential' of 279 psis. Well 2-14/O-16 is a former K2B producer, however the zone was aompletely squeezed off in December 1998 due to high gas production and mechanical problems (combination of failed squeeze perforations behind a straddle and . corroded straddle tubing). Consequently there are no plans at this time 'to. attempt to access K2B at 2-1'4/O-16 due to the risk of jeopardizing the existing K2A production in the well, ... Current K2B producing Wells near the. planned 2-28a/O-19 BHL include 1-03/P-' 16 and 2-28/P-19. These wells, are located (midpoint of producing intervals) at a horizontal distance of approximately 1500 feet to the north, and 1175 feet to the southwest, respectively, of the planned'2-28a/P-19 K2B welJ. 10:3gAM BP MILME POIMT GROUP P.3 BPX (Alaska) Inc. requests administrative approval to waive requirements stipulated in Title 20, AAC 25,055 (3) and allow well 2-28a/O-19 to be permitted within 1000 feet of existing well 2.14/0-16. Please contact me at 564-5345 if you wish to discuss this matter in further detail. S ince rely,,~..,.._~.. ~~oorhees bjv encl: Well location map Offset well log cross section cc: 2-28a/O-lg well file .' weggeland, M. Vandergon, M.' RObertson, D, Hupp, J. Ding, E, Voorhees, B. 0-~9 K2B£ MPI 'l'arge~ m ' 2-28a/0-19 TTRD Drilling Proposal Target Location Map Z5758~ Z~85E~ Z595ee Z5~5~ 2615~ 0-19 Volume&ic Polygon I Locat. lon 2001 Endicott Field Dr/lling Program :z :"-' :.-*'.-:L-. ....... :~-~:=----.?-'.'--':-.-.~-~ ~. - __~-_.~'-'~L""~ '-'_-~, ro Z67_500 Attachment 2 10:40AM BP MILHE POIHT GROUP Offset Wells Log Cross Section South 2-28/P- 19 -~- -- 1750ff K3A 'K2B (upp®r Mid S K2B ('lowe~r K~M Shale K2A' K2B lower has, r,transisiton zone ith OWC at,. or near top of sand 200f Endicott Field Dr#ling Program . . . ....... 2-14/O-16 ~ I ~1 ,~,~,.,;.,,B-., PI' t i ' ' : :" ;,,. .I, : ' ",~ . .![ ' .~ . North vertical scale 00 fl . K2B cemented off prior to depletion due to mechanical problems (3 mmbo cum); RST OWC p50 ..10081'ss Attachment 6 STATE OF ALASKA ,( · ALASK~.~ ,L AND GAS CONSERVATION COM ,,.,SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work · 1 Redrill I Exploratory I-I~Strafigraphic Test [] Development Oil _DrilIRe. Entry [] Deepen []Service _ Development Gas .~'S~,l,~eZone rl Multiple Zone lb. Type of well 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 55.00' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034633 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E, UM Duck Island Unit/Endicott At top of productive interval 8. Well Number 2310' SNL, 1931' WEL, SEC. 36, T12N, R16E, UM 2-28A/O-19 Number 2S100302630-277 At total depth 9. Approximate spud date 684' SNL, 1247' WEL, SEC. 36, T12N, R16E, UM 02/15/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 312828, 1247' MDI No Close Approach 2560 11793' MD / 10130' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9675' MD Maximum Hole Angle 88.03 ° Maximum surface 3588 psig, At total depth (TVD) 9900' / 4578 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casin.cl WeicIht Grade CouDlina Lenath MD TVD MD TVD (include sta,qe data) 3-3/4" 2-7/8" 6.16# CR-13 ST-L 2493' 9300' 9200' 11793' 10130' 112 cu. ft. Class 'G' ,: .... I/!., ""~/V .~ .q ?n,-, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Alaska Oil&- c u~!! Present well condition summary Total depth: measured 10530 feet Pl'ugs (measured) AnChorage. c°mn~ission true vertical 10479 feet Effective depth: measured 10448 feet Junk (measured) 3 Bowspring Leafs at 10448' MD true vertical 10397 feet Casing Length Size Cemented MD TVD Structural Conductor 92' 30" Driven 131' 131' Surface 2465' 13-3/8" 3687 cu. ft. Permafrost 2504' 2503' Intermediate Production 9605' 9-5/8" 575 cu. ft. Class 'G' 9644' 9597' Liner 1144' 7". 517 cu. ft. Class 'G' 9383' - 10527' 9338' -10476' Perforation depth: measured open: 10140' - 10160'; 10186' - 10212' sqzd: 10002'- 10016'; 10030'- 10034'; 10114'- 10140'; 10180'- 10186'; 10212'- 10246' true vertical open: 10090' - 10110'; 10136' - 10162' sqzd: 9923'- 9967'; 9980'- 9984'; 10064'- 10090'; 10130'- 10136'; 10162'- 10196' '20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program ' [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements "Contact Engineer Name/Number: Jeff Hupp, 564-5344 Prepared By Name/Nu~nber: $on~lra Stewman, "564-47'50 21.1 hereby certify that the for~~~;lo[r~e best of my knowledge , ~igned Jeff Hupp ~~ /'~/~/"'~' Title Senior Drilling Engineer Date zr APl Number Ap. Droval Date See cover letter Permit Nu / -' ~:)/~ 50- 02921847-01 ~ ~ / ~--(..O I for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes I~ No Hydrogen Sulfide Measures ~ Yes [] No Directional Survey Required I~'Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K ~ [] 10K [] 15K [] 3.5K psi for CTU Other: by order of Approved By ~."~:.~.."±." =.,...-_.t.,_--_.._--~ :_~_ Commissioner the commission Date ~ "~, '-" ~ / Form 10-401 Rev. 12-01-85 NEb UT J. M. Heusser 0RIGINAL Submit In Triplicate BPX ~' Endicott MPI 2-28AJO-19 Sidetrack Summary of Operations: 2-28/P-19 production has declined. The sidetrack, 2-28A/O-19, will kick off in the upper Kekiktuk and target the K2B. Planned TD will be 11793' MD, (10,130' TVD). This sidetrack will be conducted in two phases. Phase 1: Set Whipstock and down squeeze cement, Planned for 1/25 - 2/1/01. · Service coil will mill off tail pipe. · E-Line will set the whipstock at approx. 9675' MD · Service coil will down squeeze approx. 22 bbls cement to shut off existing perfs. · Sundry Notice for abandonment has been submitted. Phase 2: Drill and Complete sidetrack: Planned for 2/15/01. Doyon Rig #15 will be used to mill the window, drill and complete the directional hole as per attached plan. The sidetrack will be completed with a cemented liner. Top of 2-7/8" liner will be at approx.9300' MD (9200' TVDss) with top of liner cement approx 200 ft above the window. Approx. 2.0 bbls cement will be used for this liner cement job. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and Solids Free Drilling Fluid (9.2-9.4 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8!', 6.16#, CR-13, ST-L cemented liner will be run from TD to approx. 9300' MD (9200'ss). Top of liner cement will be 200 ft above window Well Control: · BOP diagram is attached. · Pipe rams, blind rams tested to 300 psi and to 5000 psi. · The annular preventor will be tested to 300 psi and 3500 psi. RECEIVED Directional Plan and Formation Tops J,4N .7 ~q ~20g/ · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Alaska Oil & Gas . Cons. Close approach A,~Orage Com/~ission · No close approaches. Logging · An MWD Gamma Ray Icg will be run over all of the open hole section. · A real time Resistivity or a Memory Induction Log will be run in open hole. Hazards Production from MPI 2-28 has been measured 56 ppm H2S. Surface Offset well H2S readings o MPI 2-26:99 ppm (11/22/00) o MPI 2-30:2 ppm (12/4/00) o MPI 2-24 Water injector o MPI 2-32:89 ppm (12/11/00) Lost circulation risk is Iow. Reservoir Pressure Res. press, is estimated to be 4578 psi at 9900ss (8.9 ppg EMW). Max. Surface pressure with gas (0.10 psi/ft) to surface is 3588 psi. ,TREE: 4-1/16" / 5000 psi / McEVOY RT. ELEV= 55.0' /' WELLHEAJr 13-5,8" , 5000 psi , McEVOY BP. ELEV = 15.8' MAX. DEV. = 13:33 / 8000' MD I NT-80 CYHE, BTRS. CSG. '~ ~-'-- OTIS (3.813" MIN. ID) I a o4' I ~ II~ W/SSSV MIN I.D. 2" I I -~ I~-- 4-1/2", 1 2.6#/ft, L-S0, BTRS A/B Mod. TUBING GAS LIFT MANDRELS (MERLA) i NO. T VDSS M I;)-I~ IRT ~1-I~--#6 4148' 4204' #5 63 37' 63 93' #4 77 76' 78 45' 9-5/8", 4 7#/ft, I #3 8688' 8780' ~ #2 8911' 90 07' Nm9 5HS i #1 9057' 91 55' ~(Drifted to 3.80" ID) 9265 ~ BAKER "SBR" (12' Iong) l 9324' 9-5/8" PA CKER ' I (BAKE R "SAD")I 93 39' TO.P OF I ~ 3-1/2", 9.2#/ft, L-80 TAILPIPE 7"" 9383'I --~ I~ ~ cut and dropped to" PDTD :.. · LI ~ER .'i'. :. ! .... :.. ~ .. . . ,... .~ ~:. .. 9-5~'8", 47#",, I .91~.441'~ I~ ~ · '.;.' ' ' '~ ' ' i? ?: ,;. NTB 5NS, "I "! I PER FORA11ON SUMMARY REP' LOG: DLL-GR (08-13-88) ~ Baler -l'hru--I-bg whipstock .... set @ 9675' SIZE SPF INTI~={VA L S; I-ATUS 2-1/8 4 10114'- 10160' SOZD '. .. 2-1/8 6 10145'- 10157' OPEN '" ' '::'" 2-1/8 4 10180'- 10200' SOZD · . .. . 2-1/8 4 10188'- 10213' OPEN '"' " 4-- Existing perforations 2-1/8 4 I 10216'- 10246' OPEN ..'"..:....'"' . . .' .:i.1[ plugged with 22 bbls of crrt .... .' . RECEIVED JAN I Alaska 0il & Gas Cons. ~ I Anchorage C°rnrnission ~ 3 BOWS PRI NG PDT D I 10,4 48' I ~ - - LEAFS 7" - 29 #/ft, SM-110'11 10,527' BT RS -T K C I i DATE REV. BY COMMENTS ENDICOTT WELL 2-28/P-19 , 1/9/01 JLH Prop. FYe-dg Schematic APl NO' 50-029-21847 PROPOSED PRE-RIG DIAGRAM BP EXPLORATION, INC. SIZE SPF INTB:IVAL S I-ATUS 2-1/8 4 10114'- 10160' SQZD 2-1/8 6 10145' - 10157' OPEN 2-1/8 4 10180'- 10200' SOZD 2-1/8 4 10188'- 10213' OPEN 2-1/8 4 10216' - 1 0246' OPEN TREE: 4~1/16" / 5000 psi / McEVOY ,~. ~,~v-- ~.o. ( ._.~,.~.~_~ ~_~,~.., ~ooo ~.,~o~,~o,~ DF; ELEV = I 5.8' , ...... MAX. DEV. = 13:33 8000' MD NT-80 CYHE, BTRS. CSG. ,~ ~_ ~ SSSV LANDING NIPPLE 1555' ~ OtiS (3.813" MIN. ID) 2504' I ""- · · W/SSSV MIN I.D. 2" I ! "= I-- 4-1/2", I 2.6#/ft, L-SO, i BTRS A/B Mod. TUBING GAS LIFT MANDRELS (MERLA) NO. T VDSS M D-B RT '~ ~ #6 41 48' 42 04' #5 63 37' 63 93' 9-5/8" 4 7#/ft,, , #4 77 76' 78 45' I',,I-r8 o~ I NT9 5NS : #2 89 11' 90 07' #1 90 57' 91 55' SLEEVE 92 65 , CAMCO 2-7/8" liner top @ 9300' -----______ ~ ___._ ' 9-5/8" I i PACKER 93 39' ~ , ~ 2-718" 6.4,ppf x x x',~ / XXX IF x x x :ii, ii' 3-3/4" hole drilled to 11800' MD(+/-) /'"x x >~ :':?~ ,, /f'[~" "":i ~. 3-1,2 L-80 Tail pips assy , I -- Milled & pushed to PBTD / ~ ' RECEIVED,, ~ 3 BOWS PRI NG . ,r ", LEAFS LINER 9--.5/8", 4.7#/ft, ~HS, I '*~' Baker Whipstock set @ 9675" MD Existing perforations P&A'd during pre-rig PER FORAlt ON SUM MARY REF: LOG: DLL-GR (08-13-88) SIZE I SPF INTB=iVA L S FATUS 2-1/8 4 10114' - 10160' SQZD 2-1/8 6 10145' - 1 0157' OPEN 2-1/8 4 10180' - 1 0200' SQZD 2-1/8 4 10188' - 1 021 3' OPEN 2-1/8 4 10216' - 1 0246' OPEN SIZE SPF INTB:{VA L S FATUS 2-1/8 4 10114' - 10160' SQZD 2-1/8 6 10145' - 1 0157' OPEN 2-1/8 4 10180' - 1 0200' SQZD 2-1/8 4 10188' - 1 02 1 3' OPEN 2-1/8 4 10216' - 1 0246' OPEN PDT D I 10,4 48' I 7"- 29 #/ft, SM-110,I 10,527' I-~ JAN 1 ~ ~{]01 BTRS -TK C Alaska 0il & Gas Cons, Commission Anch0ra~e DATE REV. BY COMMENTS ENDICOTT WELL 2-28A/O-19 12/22/00 JLH Proposed TTRD ST 50-029-21 847'-01 PROPOSED COMPLETION DIAGI~AM · BP EXPLORATION, INC. I DrillQuest:' Alaska State Plane 3 Alaska Drilling & Wells Endicott DI-MPI 2-28A/O-19 WPS 9500 - 9750 -- 10000 --__ II ..~ 10250 - ,~~Begin Dir @ 16.03°/100ft : g675.00ft MD, g627.46ft TVD ontinue Dir @ 16.00°/100ft : 973g. g6ftMD,g691.25ftTVD ~ ,/../~/, -- i ........... y,( 703 v.~z.,.~t '. ,., · - ~ t'{U ~'" o. n~-~r, Start S~ --- ~ ~ ~B9~!n Dir ~ 0.~"/!00ff : 10!92.1~ MD ~l~q~ff ~/n ..... s.~.,t/ J ...... ~ ................ j~ Potygo~t ?fhrgeg Thickttess: 3~).OOfi t'<,(vgtm 't?n'geh Ttlickm'ss: 30, tt(~/~ I I I I I 0 250 500 750 1000 Scale: linch = 250ft . Vertical Section F repamd by': Admin I I I 1250 1500 1750 SectiOnDate/Time:17 january,Azimuth:2oo~ - la:s?38'243°Checked:(True North) [Approved: Alaska State Plane 3 Alaska Drilling & Wells Endicott DI-MPI 2-28A/O-19 WPS 1500 - 1200 - 900 -- 600 - 300 - __ c) c) "-300 - .c_ Scale: linch = 300ft Eastings 0 300 600 I I I 9OO I 1200 I RECEIVED JAN 1 9 ~00! Alaska Oil & Gas Cons. Commission Anchorage 10113.1( 10100 in Dir @ Sail @ Dir @ 16.00°/100f : 10192.19ft MD. 1001 : 10114.86ftMD .,9691.25ftTVD I I I 0 300 600 Scale: linch = 300ft Eastings I I 900 1200 Reference is True North 1500 )130.05ftTVD 900 600 u~ O; Z .. 300 0 10085.00ftTVD Prepared by: Date/'l'lme: Checked: Approved: Adm n 17 January, 2001 - 14:14 Sper 'j/-Sun Drilling Serwces Proposal Data - 2-28A/0-19 WPS - 2-28A O- 19 Wp05 ......... :~':~!ii~i:i~?i.~'.i~'!i!:.~":::i~.~.:.]:.:~i~'' "." ...... .':' ' 2~'.' : ' ':' i~ ~'~i!~i~i~ ....... ""' 5 'i'i~i~[~i~,[ii:~.:.8.'.:i'i;!il :~.~)i..?*i~:ii'"'~'8"i"'~':~' ............ ~.'~"]'~'8'"~'~'~"~5"i"~)'0':.i:(?~!,:,i~' ~::~ ........ ~'~"~3'0'""'~'."~'~'~.08 ~ 16.000 293.688 426.08 o ~ ['.:.~'~:.:~,~'~¥::~:~J~'~'::~:~.:~ :.~:~ ~:~ ~.~:: ~;.~ ~~ooJ RECEIVED JAN ~ 9 ZOO1 Alaska Oil & Gas Cons. Commission Arrcflorage 17 January, 2001 - 13:54 - 1 - DrillQuest Alaska State Plane 3 Alaska Drilling & Wells Endicott DI-MPI 2-28A/0-19 WPS - 2-28A O- 19 Wp05 PROPOSAL REPORT 18 January, 2001 Proposal Ref: pro954 RECEIVED JAN 1 9 2001 Alaska Oil & Gas Cons. Commission Anchorage Alaska State Plane 3 Measured Depth Incl. Azim. (ft) 9675.00 6.746 159.044 9700.00 9.493 138.034 9739.96 15.089 123.065 9756.30 15.886 113.729 9800.00 19.598 94.094 Sub-Sea Depth (ft) 9572.46 9597.21 9636.25 9652.00 9693.65 9823.93 22.287 86.449 9716.00 9900.00 32.327 71.173 9783.59 9919.73 35.136 68.573 9800.00 9975.25 43.265 62.879 9843.00 10000.00 46.963 60.876 9860.46 10038.05 52.706 58.227 9885.00 10060.39 56.102 56.856 9898.00 10100.00 62.156 54.671 9918.32 10114.86 64.436 53.916 9924.99 10186.71 64.436 53.916 9956.00 10192.19 64.436 53.916 9958.36 10200.00 64.944 52.653 9961.70 10237.96 67.555 46.661 9977.00 10300.00 72.263 37.351 9998.35 10400.00 80.667 23.331 10021.84 10482.68 88.030 12.280 10030.00 10500.00 88.030 12.280 10030.60 10600.00 88.030 12.280 10034.04 10700.00 88.030 12.280 10037.47 10800.00 88.030 12.280 10040.91 Sperry-Sun Drilling Services Proposal Report for 2-28A/0-19 WPS - 2-28A 0-19 Wp05 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9627.46 365.51S 308.68 E 5982098.03 N 259263.61E 9652.21 368.41S 310.58 E 5982095.07N 259265.42E 9691.25 373.71S 317.15 E 5982089.56 N 259271.81 E 9707.00 375.77 S 320.98 E 5982087.38 N 259275.58 E 9748.65 378.70S 333.78 E 5982084.04 N 259288.28 E 9771.00 378.71S 342.32 E 5982083.76 N 259296.81E 9838.59 371.22 S 376.09 E 5982090.15 N 259330.81E 9855.00 367.44 S ~- 386.38 E 5982093.60 N 259341.20 E 9898.00 352.90 S:? ~;~'"4~8.24 E 5982107.10 N 259373.52 E 9915.46 344.63 S 433,70 E 5982114.87 N 259389,24 E 9940.00 329.88 S 458.74 E 5982128.81N 259414.74 E 9953.00 320.1~ S''~ ~474~06 E 5982138.06 N 259430.37 E 9973.32 301.00 S 502.14 E 5982156.29 N 259459.05 E 9979.99 293.25 $ 512.92 E 5982163.68 N 259470.07 E 10011.00 255.07 S 565.30 E 5982200.16 N 259523.65 E 10013.36 252116 S 569.30 E 5982202.94 N 259527.74 E 10016.70 247.94 S 574.95 E 5982206.97N 259533.53 E 10032.00 225.45 $ 601.40 E 5982228.60 N 259560.69 E 10053.35 182.18 S 640.28 E 5982270.60 N 259600.94E 10076.84 98.47 S 689.03 E 5982352.69 N 259652.36 E 10085.00 20.30 S 714.08 E 5982430.02 N 259679.91 E 10085.60 3.38 S 717.77 E 5982446.81N 259684.14 E 10089.04 94.27 N 739.02 E 5982543.73 N 259708.52 E 10092.47 191.92 N 760.28 E 5982640.65 N 259732.91E 10095.91 289.58 N 781.53 E 5982737.57 N 259757.30 E Dogleg Rate (°/100ft) 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 16.00 0.00 0.00 16.00 16.00 16.00 16.00 16.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells Endicott DI-MPI vertical Section comment -95.99 Begin Dir @ 16.03°/100ft : 9675.00ft MD, 9627.46ft TVD -97.10 -97.19 Continue Dir @ 16.00°/100ft : 9739.96ftMD,9691.25ftTVD -96.44 Fill -90.82 -85.54 FII -58.75 -49.42 FI -18.27 K3A -2.21 24.88 42.02 74.43 87.19 149.59 154.35 161.17 195.20 253.25 349.17 426.08 441.64 531.50 621.35 711.20 S3A4 S3A2 End Dir, Start Sail @ 64.436° : 10114.86ftMD,9979.99ftTVD S3A1 Begin Dir @ 0.00°/100ft : 10192.19ft MD, 10013.36ft TVD K2B End Dir, Start Sail @ 88.030° : 10482.68ftMD,10085.00ftTV D 18 January, 2001 - 10:24 Page 2 of 3 DrillQuest 2.00.06 Sperry-Sun Drilling Services Proposal Report for 2-28A/0-19 WPS - 2-28A O- 19 Wp05 Alaska State Plane 3 Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (~t) (~t) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (it) (ft) 10900.00 88.030 12.280 10044.35 10099.35 387.23 N 802.79 E 5982834.49 N 259781.68 E 11000.00 88.030 12.280 10047.79 10102.79 484.89 N 824.05 E 5982931.41 N 259806.07 E 11100.00 88.030 12.280 10051.22 10106.22 582.54 N 845.30 E 5983028.33 N 259830.46 E 11200.00 88.030 12.280 10054.66 10109.66 680.20 N 866.56 E 5983125.25 N 259854.84 E 11300.00 88.030 12.280 10058.10 10113.10 777.85 N 887.82 E 5983222.17 N 259879.23 E 11400.00 88.030 12.280 10061.54 10116.54 875.50 N 909.07 E 5983319.09 N 259903.62 E 11500.00 88.030 12.280 10064.97 10119.97 973.16 N 930.33 E 5983416.01 N 259928.00 E 11600.00 88.030 12.280 10068.41 10123.41 1070.81 N 951.59 E 5983512.93 N 259952.39 E 11700.00 88.030 12.280 10071.85 10126.85 1168.47 N 972.84 E 5983609.85 N 259976.78 E 11704.39 88.030 12.280 10072.00 10127.00 1172.75 N 973.77 E 5983614.10 N 259977.85 E 11793.19 88.030 12.280 10075.05 10130.05 1259.47 N 992.65 E 5983700.16 N 259999.50 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 38.243° (True). _. Based upon Minimum Curvature type calculations, at a Measured Depth of 11793.19ft., The Bottom Hole Displacement is 1603.62ft., in the Direction of 38.243° (True). Dogleg Rate (°/lOOft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells Endicott DI-MPI Vertical Section Comment 801.06 89o.91 98o.77 1070.62 1160.48 1250.33 134o.18 1430.04 1519.89 1523.84 16o3.62 K2M Total Depth · 11793.19ftMD,10130.05ftTV D 18 January, 2001 - 10:24 Page 3 of 3 DrillQuest 2.00.06 3-1/8' x 2-1/16' ADA°T. 2-1/16' 3' I' 3' 19.13/4 I! '~ 1'0' O' 7-1/4' t' 1-1/4' 2' 1 7 1/16" BOP STACK ARRANGEMENT (_5M) MUO ~-1/8' 134-' - 2-1/16'U.Vit~t. /16' x~l/IG' XO $1K]C)L TEST SPOOL ADAPT. FU~ TUBING SP(X~ C.~G SPOCX. 13 5/8; 5000 FSI, HYOR~. NGIIJU~ BOP SmDOED TOP/FI..~rn FLM~ 8OWOM/P,.~G~ TOP 13 5/8', 5QQO FSI.lO' MPL OPERATORS HYORIL P~E RM, J ~ BOITO~/$TUDOED TOP i,3 5/8', 5600 FSI. 14'UI~. 3 I/8' SO(IQ PSI K~ VAI..~ 2' KIt. L MNE 3 1/8' 5000 PSI r..~,TE VN.VE t3 5/8', ~ PSt. 10' ~ OM~,AtORS, Ft.,em~/FtlN~£ ! BOP STAC! ELEVATION ! = 21 I/4' 2000 PSI, MSP IMPerIL ) s1uool~ TOP/~ BOITG~I 12' I.~ PSI HYOR. OPERATED / SURFACE DIVERTER CONFIGURATION January ~, 2001 ADMINISTRATIVE APPROVAL NO. 202.38 Re: Spacing Variance for Endicott 2-2'8/0-19 Well Mr. Jeff Hupp Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Hupp: We have received your correspondence dated Janum3r 25, 2001 requesting a spacing variance for the Endicott 2-28/O-19 well. As proposed, the bottom hole location of 2- 28/0-19 is approximately 200 feet horizontal distance from the existing 2-14/O-16 well. The proposed 2-28/O-19 well will be drilled as a high-angle producer in Subzone 2B of the Kekiktuk Formation. Existing well 2-14/O-16 is a production well completed in Kekiktuk Subzone 2A. Subzone 2B is separated from the underlying Subzone 2A by the K2M shale, which is a barrier to vertical flow. Recent static pressure measurements in this area indicate a pressure differential of approximately 280 PSIA exists between Subzones 2A and 2B. Drilling and completion of the 2-28/O-19 production well will not interfere with production from the adjacent 2-14/0-16 well. The Commission has determined placement of the well will not promote waste, will enhance recovery, and hereby approves the drilling of the Endicott 2-28/O-19 well as proposed pursuant to Rule 3 of Conservation Order No. 202. Sincerely, Daniel T. Seamount, Jr. Chair Cammy Taylor Commissioner Julie Heusserk:P~. Commissioner BY ORDER OF THE COMMISSION DATE I C.EC~NO. 1 VENDOR ALASKAO I LA DATE INVOICE / CREDIT MEMO DESCRIPTION OR088 DISCOUNT NET :1.22100 CK1;~.-~IOOD 100. O0 100. O0 PYHT 4:CII"IHENTS' PeThr~it; To DT'i11' 'ee HANDL [NO TNST- S/H - Te~-~-ie Hubi)le X4b2Ei ., .E A'nACHED CHECK m m PAYMENT ~ iTEm DESCRIBED ABOVE~ 2. WELL PERMIT CHECKLIST COMPANY--.~'~P WELL NAME 2-2---~A'A-_/~J PROGRAM: exp INIT CLASS ~ ~'~..~//.-- GEOL AREA 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..'~- ........ Y Sufficient acreage available, in drilling unit.'.~c .......... ~ If deviated, is wellbore plat included ............. ... Operator only affected party ................... Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... ~ 13. Can permit be approved before 15-day wait ........... ~)N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs.... ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol'adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons ..... ' ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate weilbore separation proposed ....... ' ....... 23. If diverter required, does it meet regulations ......... ~ . 24. Drilling fluid program schematic & equip list adequate ..... FIELD 8, POOL ADMINISTRATION DATE I- ENGINEERING . 2. 3. 4. 5. 6. 7. 8. 9. 10. 25. BOPEs, do they meet regulatiOn ................ /~~ D,~,TE 26. BOPE press rating appropriate; test to ~~,-,~ psig. '~'-/5 ~. 27.' Choke manifold complies w/APl RP-53 (May 84) ........ "- ~- 28. Work will occur without operation shutdown ...... ; ..... dev j reddl ~ sew wellbore seg ann. disposal para req UNIT# (..~/(.~C/'~'-~ ON/OFF SHORE (~,~9 . Y Y 29. Is presence of H~,S gas probable .............. .~"-~'. GEOLOGY . 30. Perm,t can be ~ssued wlo hydrogen sulfide measu ...... '31. Data presented on potential overpressure zones . .. ..... ~.~)~ .~¢~_.~, ' 32. Seismic analysis of shallow gas zones.. ............ .~6 --"~'N. ' .. . v. "- .. . · .. .., .. II ANNULAR DISPOSAL35. With proper cementing records, . this plan ; ' ' ~ ' '(A) will.contain waste in a suitable receiving zone; ........ Y N ' APPR, DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical'integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not cimumvent 20 AAC 25.252 or 20 AAC 25.412.. Y N , . ENGINEERING: . UlC/Annular -' COMMISSION: Commentsllnstrucflons: O Z O .-I .( c:~nsoffice\wordian~liana~checklist (rev. 11101//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, informati;3n of this nature is accumulated at the end of the file under APPENDIX. No.special effort has been made to chronologically organize this category of information. 2-28A_O-19. tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Aug 28 17:08:56 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/08/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Endicott MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-10052 R. FRENCH E. VAUGHN 2-28a / O-19 500292184701 BP Exploration Alaska, Inc. Sperry Sun 28-AUG-01 MWD RUN 2 MWD RUN 3 AK-MM-10052 AK-MM-10052 S. LAITILA R. FRENCH D. REID E. VAUGHN 36 12N 16E 1944 2240 .00 55.00 14.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 3.700 4.500 9675.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2, MWD RUNS 1-3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING Page 1 2-28A O-19.tapx GEIGER-MUELLER TUBE DETECTORS AN~ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). MWD RUN 4 ENCOUNTERED TIGHT HOLE DURING TRIP IN HOLE. STUCK DRILLSTRING AT 9912' MD. BACKED OFF BHA AND CEMENTED TO PLUG AND ABANDON WELLBORE. DEPTH SHIFTING IS WAIVED PER THE E-MAIL OF 8/2/2001 FROM D. SCHNOOR OF BP EXPLORATION (ALASKA) INC. MWD RUNS 1-3 REPRESENT THE MWD DATA FOR WELL 2-28A / 0-19 WITH API% 50-029-21847-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10223' MD, 10087' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9634.5 10165.0 FET 9645.5 10176.0 RPD 9645.5 10176.0 RPM 9645.5 . 10176.0 RPS 9645.5 10176.0 RPX 9645.5 10176.0 ROP 9693.0 10223.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD i 9634.5 9723.0 MWD 2 9664.5 10127.0 MWD 3 10068.0 10223.0 $ # REMARKS: MERGED MAIN PASS. Page 2 2-28A_O-19.tapx $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9634.5 10223 ROP MWD FT/H 0 68.22 GR MWD API 23.12 558.95 RPX MWD OHMM 0.1 2000 RPS MWD OHMM 0.1 1959,61 RPM MWD OHMM 0.14 2000 RPD MWD OHMM 0,11 2000 FET MWD HOUR 0,29 65.1221 First Reading For Entire File .......... 9634.5 Last Reading For Entire File ........... 10223 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0,0 Date of Generation ....... 01/08/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Mean Nsam 9928.75 1178 5.95656 1061 143,434 1062 35.6985 1062 53.9045 1062 103,768 1062 101.081 1062 17.085 1062 First Reading 9634.5 9693 9634.5 9645.5 9645.5 9645.5 9645.5 9645.5 Last Reading 10223 10223 10165 10176 10176 10176 10176 10176 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 3 GR 9634 5 RPD 9645 5 RPM 9645 5 RPS 9645 5 RPX 9645 5 FET 9645 5 ROP 9693 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 2-28A_O-19.tapx 9664.0 9675.0 9675.0 9675.0 9675.0 9675.0 9723.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 27-FEB-01 Insite 0 Memory 9723.0 6.7 10.3 TOOL NUMBER pbo1862 pbo1862 3.700 Quick Drill-N 10.40 47.0 9.5 177000 3.3 .000 .0 .000 158.9 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 Page 4 2-28A O-19.tapx RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 9634.5 9723 ROP MWD010 FT/H 0.07 18.09 GR MWD010 API 300.66 558.95 RPX MWD010 OHMM 0.1 1180.43 RPS MWD010 OHMM 0.1 1959.61 RPM MWD010 OHMM 0.14 2000 RPD MWD010 OHMM 0.11 1982.36 FET MWD010 HOUR 0.29 4,536 First Reading For Entire File .......... 9634.5 Last Reading For Entire File ........... 9723 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Mean Nsam 9678.75 178 7.14279 61 444.705 60 142.795 60 327.157 60 784.364 60 544.24 60 2,11774 60 First Reading 9634.5 9693 9634 5 9645 5 9645 5 9645 5 9645 5 9645 5 Last Reading 9723 9723 9664 9675 9675 9675 9675 9675 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name,.. Version Number ........... 1.0,0 Date of Generation ....... 01/08/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): START DEPTH STOP DEPTH 9664.5 10067.5 9675.5 10078.5 9675,5 10078.5 9675.5 10078.5 9675.5 10078.5 9675.5 10078.5 9723.5 10127.0 04-MAR-01 Insite 0 Memory 10126.5 Page 5 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG, RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD.CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ......... ' ............ 60 ,liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type,,,0 Name Service Order 2-28A_O-19.tapx 6.7 42,5 TOOL NUMBER pbo1862 pbol 862 3.700 Units Size Nsam Rep Code Offset Channel Quick Drill-N 10.70 42.0 8,7 188000 4,2 DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 .040 75,0 ,020 180.0 ,060 75,0 ,060 75,0 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9664,5 10127 ROP MWD020 FT/H 0 68,22 GR MWD020 API 23,12 504.43 RPX MWD020 OHMM 0,14 2000 RPS MWD020 OHMM 0,28 1915,91 RPM MWD020 OHMM 0.45 2000 RPD MWD020 OHMM 0,38 2000 FET MWD020 HOUR 4,7246 54,9738 Mean 9895,75 5,67032 116,138 33,7544 39,7342 63.4321 82,9964 14,0502 Nsam 926 808 807 807 807 807 807 807 First Reading 9664,5 9723,5 9664.5 9675,5 9675,5 9675.5 9675,5 9675,5 Last Reading 10127 10127 10067,5 10078,5 10078,5 10078,5 10078,5 10078,5 Page 6 2-28A_O-19.tapx First Reading For Entire File .......... 9664.5 Last Reading For Entire File ........... 10127 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files, BIT RUN NUMBER: 3 DEPTH INCREMENT: ,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10068.0 RPD 10079.0 RPM 10079.0 RPS 10079.0 RPX 10079.0 FET 10079.0 ROP 10127,5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD'DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: STOP DEPTH 10165.0 10176.0 10176.0 10176.0 10176.0 10176.0 10223.0 07-MAR-01 Insite 0 Memory 10223.0 42.0 45.2 TOOL NUMBER pbo1836 pbo1836 3.700 Quick Drill-N 10.70 40.0 9.5 Page 7 2-28A O-19.tapx MUD CHLORIDES (PPM): 172000 FLUID LOSS (C3): 3.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .050 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .020 169.6 MUD FILTRATE AT MT: .050 70.0 MUD CAKE AT MT: .060 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 ,liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Units Size Nsam Rep Code Offset Channel Name Service Order DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 10068 10223 ROP MWD030 FT/H 0 25,61 GR MWD030 API 84.77 249.68 RPX MWD030 OHMM 0,18 56.44 RPS MWD030 OHMM 0.51 1221,3 RPM MWD030 OHMM 0.87 1657.92 RPD MWD030 OHMM 1.55 1593.02 FET MWD030 HOUR 3,7554 65.1221 First Reading For Entire File .......... 10068 Last Reading For Entire File ........... 10223 File Trailer Service name ............. STSLIB.004 Service Sub Level Name,.. Version Number ........... 1.0,0 Date of Generation ....... 01/08/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Mean 10145.5 6,78427 163,702 10.791 28,4699 61.2818 39.5647 34.2499 Nsam 311 192 195 195 195 195 195 195 First Reading 10068 10127.5 10068 10079 10079 10079 10079 10079 Last Reading 10223 10223 10165 10176 10176' 10176 10176 10176 Physical EOF Tape Trailer Service name ............. LISTPE Page 8 2-28A_O-19.tapx Date ..................... 01/08/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/08/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 9