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204-043
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG (RECEIVED "Ar) 4 n 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned RI Suspended ❑ 20MC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 1b. Well Class: na Devel�p�SF,x®loyatpry ❑ Be a est ❑ 2. Operator Name: BP Exploration (Alaska), Inc 6. Date Comp., Susp., or Abend.: 2/15/2020 14. Permit to Drill Number/Sundry 204-043 319546 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 3/22/2004 15. API Number: 50-029-20220-01-00 4a. Location of Well (Governmental Section): Surface: 1316' FSL, 812' FWL, Sec. 11, T10N, R15E, UM - Top of Productive Interval: 7612' FNL, 2190' FEL, Sec. 15, T10N, R15E, UM . Total Depth: 1500' FNL, 5263' FEL, Sec. 15, T10N, R15E, UM 8. Date TO Reached: 4/2/2004 16. Well Name and Number: PBU 03-07A 9 Ref Elevations KB 55.50 ' GL 28.00 . BE 27.62 17. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MD/TVD): 10365'18782' 18. Property Designation: ' ADL 028327, 028328 & 028331 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 714073 y- ' 5937379 ' Zone - ASP 4 TPI: x- 711159 y- ' 5934368 ' Zone - ASP 4 Total Depth: x- 708084 y- 5934393 ' Zone - ASP 4 11, Total Depth (MD/TVD): 13841'/ 9052' ' 19. DNR Approval Number: 74-017 12. SSSV Depth (MD/TVD): None 20 Thickness of Permafrost MD/rVD: 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ff MSL) 21. Re-drill/Lateral Top VMndaw MD/rVD: 7968' / 6752' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD / GR / PWD, Cement Evaluation, MWD / GR / RES / ABI, OR / CCL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 30' 110' 30' 110' 32" 300 ax PF II 13-3/8" 72# MN -80 30' 2693' 30' 2693' 17-1/2" 5800 ax PF 11 9-5/8" 47# RS-95/MN-80 28' 7968' 28' 6752' 12-1/4" 1075 sx Class'G' 7" 26# L-80 7798' 10279' 6636' 8708' 8-1/2" 276 sx Class'G' 4-1/2" 12.6# L-80 10727' 13840' 8573' 9052' 6-1/8" 444 ax Class'G' 24. Open to production or injection? Yes ❑ No Rl If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): A1_,QM ft��IlU yU ctww��, CI,�•�/�� i\T - 2 'J �Z� UERII-'F r; -u- 25. TUBING RECORD GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 12.6# L-80 10130' 10073'/ 8524' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No El Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTHINTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10365' Set Whipstock 27. PRODUCTION TEST Data First Production: Not an Injection Method of Operation (Flawing, gas lift, etc.): N/A Date of Test Hours Tested: Production for Test Period -► Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Elm Tubing Press Casino Press: Calculated 24 Hour Rate --► Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API loom: Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only h&R16ft4kZ'6z6 4BUMSAr?-/ MAR 13 2020 aZU5*0 v6' 28. CORE DATA Conventional Cares) Yes ❑ No lZ Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071, 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No D Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10393' 8805' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Colville Mudstone 8142' 6875' HRZ 9979' 8442' Base of HRZ 10205' 8642' Sag River 10270' 8700' Shublik A 10303' 8729' r Shublik B 10325' 8748' r Shublik C 10346' 8766' Sadlerochit - Zone 4B 10393' 8805' 42SB - Zone 4A 10560' 8928' CGL - Zone 3 10706' 9002' r Formation at total depth: Zone 3 10706' 9002' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastulka, Joseph N Contact Name: Hyatt, Trevor Authorized Title: SI S list Contact Email: Trevor.Hyatt@bp.com Authorized Signature: Date: 3�10�2o Contact Phone: +1 907 564 4627 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. Submit a well schematic diagram with each 10407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are Conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated is pool a completion. Item lb. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071, Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Forth 10-407 Revised 512017 Submit ORIGINAL Only ***WELL INJECTING UPON ARRIVAL*** (ctd) DRIFTED W/ 3.80" CENT TO TOP OF MCX @ PULLED 4 1/2" MCX (M-636) FROM SSSV NIPPLE @ 2,190' MD 12/23/2019 ***CONT WSR ON 12/24/19*** ***CONT WSR FROM 12/23/19*** (ctd) DRIFTED W/ 20'x 3.70" DUMMY WHIPSTOCK, SD @ 10,428' SLM (no sticky) 12/24/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** T/1/0=1700/20Nac Temp=Sl Assist Eline (CTD) Load Tbg for ELine. Pumped 3 bbls 60/40 meth, 287 bbls 100* 1% KCL and 38 bbls DSL down Tbg for load. Eline in control of 1/2/2020 1well per LRS departure. FWHP's=300/26/vac IA,OA=OTG ***WELL S/I ON ARRIVAL*** (SLB ELINE: SET WHIPSTOCK) INITIAL T/1/0 = 1850/0/0. LRS L&K TBG W/ 290 BBL'S OF 1 % KCL & 38 BBL'S OF DSL. SET 4-1/2" BAKER PACKER WHIPSTOCK AT 10,359' TOWS, 150 DEG ROHS. LOG CORRELATED TO SLB JEWELRY / PDC LOG / MEMORY GR/CCL DATED 26- APRIL-2004. FINAL T/l/O = VAC/0/0. 1/2/2020 ***WELL SHUT IN ON DEPARTURE, DSO NOTIFIED*** T/I/O = 40/30NAC. Temp = SI. TBG & IA FL (pre-MIT). TBG FL @ 605'(9 bbls). IA FL @ near surface. 1/10/2020 SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:40 Target Pressure = 2500 psi (Pre CTD). Tbg FL @ 605'(9 bbls). Starting flow line pressure = 0 psi, SI @ WV & Grove. Used 10.2 bbls of DSL to pressure up Tbg from 80 psi to 2750 psi. TP lost 30 psi in the 1st 15 minutes & 9 psi in the 2nd 15 minutes for a total loss of 39 psi. Bled TP to 5 psi (2.4 bbls). During monitor TP increased 2 psi. MIT- IA PASSED to 2726 psi, Max Pressure = 2750 psi, Target Pressure = 2500 psi (Pre CTD). IA FL @ 130'( 7 bbls). Used 12.6 bbls of DSL to pressure up IAP from 24 psi to 2750 psi. IAP lost 19 psi in the 1st 15 minutes & 5 psi in the 2nd 15 minutes for a total loss of 24 psi in 30 minutes. Bled IAP to 200 psi (5 bbls). Hung tags. Final WHPs = 10/200Nac. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 1/1212020 CTU #9 - 1.75" Coil, 0.156" wt. Job Objective: Pre-CTD Mill XN Nipple, Mill Window MIRU CTU. Begin BOP Test. Failing test #6. Call out grease crew to service. 1/15/2020 ...Job in Progress.... CTU #9 - 1.75" CT. Job Scope: Mill XN-Nip, Mill Window - Pre CTD Perform BOP Test (AOGCC Witness Waived by Adam Earl). MU & RIH w/ Baker 3.80" LH Milling BHA. Displace Coil to KCL while Rih. Dry Tag XN-Nip at 10123' down/ 10119' up. Mill through XN-Nipple. Reciprocate across XN-Nip. 1/16/2020 ***In Progress*** CTU#9 - 1.75" CT. Job Scope: Mill XN-Nip, Mill Window - Pre CTD Reciprocate across XN-Nip. Perform clean dry drift. Pooh. Make up window milling BHA and RIH. Begin Milling window at 10365.5'. Exit window at - 10374.4'. Once string reamer out of window mill additional 10' of formation to a final depth of 10386.3'(10380' MD). Reciprocate across window. Did not have any motor stalls during window milling. Perform clean dry drift through window and tag TD at 10386'. Chase ooh at 80%. 1/17/2020 ***In Progress*** Daily Report of Well Operations PBU 03-07A CTU#9 1.75" CT. Job Scope: Mill XN-Nip, Mill Window - Pre CTD Chase ooh at 80%. Launch 3/4" ball & open circ -sub. Lay in 60/40 Freeze Protect from 2650' TVD. Mill gauged 3.80" Go, 3.79" Nogo. String Reamer gauged to 3.79" Go, 3.78" Nogo. Rig Down CTU. 1/18/2020 ***Job Complete*** T/1/0=0/0/0. Pre CDR2. Set 6" CIW "J" TWC #408 @ 135".TWC LTT (PASSED). RD upper tree. RU CDR tree #1, test spool #1, and kill line #2. PT'd 300 pi low and 5000 psi high 1/21/2020 (PASSED) ***JOB IN PROGRESS***. See log for details. Final WHP's=TWC/0/0 T/I/O=TWC/0/0. Pre CDR2. Change out with day crew. Pulled 6" J TWC #408 @135". Job 1/22/2020 Complete. See log. Final WHP's 0/0/0. T/1/0=0/0/0 Removed tree cap bonnet, installed tapped blind flange. PT'd through kill line against Top of Master x Bottom of Swab, 300/low..3500/high..pass. Top of second Master x Blind flange 300/low..3500/high.. pass. Through tree cap blind flange x Top of Swab, 300/low..3500/high.. pass. see "Field Charted Tests" FWP's 0/0/0 see log for details. 1/22/2020 jMV,SMV = O, SV=C, kill line valves=C. IA & OA OTG. T/l/O = 0/10/VAC. Temp = Sl. Bleed WHPs to 0 psi (pre CTD). Wellhouse, scaffold, and flowline disconnected. CDR tree installed w/ second MV. IA FL @ near surface. Bled IAP to BT from 10 psi to 0 psi in <1 min. Held open bleed for 1 hr. Monitored for 30 min. IAP increased to 0+ psi. Final WHP = 0/0+NAC. 1/22/2020 MV, MV = O. IA, OA = OTG. 23:00 North America - ALASKA - BP Page t 4A& Operation Summary Report Common Well Name: 03-07 - — - -- -- -- - --- _ - Event Type: RE-ENTER- ONSHORE (RON) Start Date. 2/11/2020 End Date: 2/2112020 Project: PBUSite: 03 Rig Name/No.: CDR -2 Spud Date/Time: 9/17/1976 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001383 Active datum: KB @55.50usft (above Mean Sea Level) Date From - To 106:30 Him Task Code NPT Total Depth Phase Description of Operations _ 2/11/2020 - 12:00 (hr) 5.50 MOB P (usft) _ PRE ! RELEASE RIG FROM L -119A. PJSM WITH PEAK CREW AND NABORS FOR PULLING OFF WELL. USE WALKING FOOT + SOW +DB TO PULL SUB OFF WELL. _ MOVE RIG TO SPINE ROAD AT 12: 00. 12:00 - 22:30 10.50 MOB P PRE MOVE RIG FROM L -PAD TOWARD DS3 2230 - 0000 1.50 MOB i N PRE STAGEDAT DS07 WAITING ON RIG MATS TO BE LAID. 2/12/2020 00:00 - 04:00 4.00 MOB P PRE I RESUME WITH RIG MOVE TO DS3 ,AT ENTRANCE TO ICE ROAD PRE MOVE ACROSS ICE ROAD AND DS -17 TO 04:00 - 11:00 7.00 MOB P DS -03. (REMOVE JEEPS. PJSM WITH PEAK CREW. MOVE SUB OVER WELLAND SET DOWN. 11:00 - 13:00 2.00 RIGU P SPOT PIT MODULE. _ ACCEPT RIG 06:00. PRE RIG UP CHECKLISTS. HOOK UP STEAM LINES. HOOK UP INTERCONNECT LINES. SPOT AUXILIARRY EQUIPMENT. PUT HEAT IN CELLAR, CYCLE TREE VALVES. 13:00 - 00:00 11.00 BB USPOR P PRE GET GOOD LEAK TIGHT TEST ON TREE VALVES. HOOK UP MPD LINE. - REMOVE TREE CAP, INSTALL BOPS. CHANGE OUTANNULAR ELEMENT CHANGE OFFAND ENERGIZER STAB ON WELL WITH INJECTOR GREASE TREE VALVES, T1 & T2 VALVES CHECK TORQUE ON TREE FLANGES COMPLETE VALVE CHECK LIST BLOWAIR THROUGH TIGER TANK LINE FLUSH COIIL WITH 5 BBLS MEOH AND FRESH WATER -HAD TO PUMP SLOWLY 0.5-1 BPM AND STOP SEVERAL TIMES AS PRESSURES WERE ERRATIC SUSPECT ICE PLUG MOVING IN REEL. SEE PRESSURE DROP AS ICE PLUG CLEARED COIL, SEND RETURNS TO TIGER TANK. TIGER TANK LINE GOING THROUGH EXITING WHEEL ROOM IS FROZE UP. THAW OUTAND BLOW DOWN LINE PRE FLUSH COIL WITH FRESH WATER TAKING 2/13/2020 0000 - 0330 3.50 BOPSUR P RETURNS TO CUTTINGS TANK FLUSH SURFACE LINES WITH FRESH WATER SHELL TEST TO 3500 PSI Printed 2/26/2020 3:34:40PM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 2 VII Operation Summary Report Common Well Name: 03-07 Event Type: RE-ENTER- ONSHORE (RON) 1 Start Date: 2/11/2020 Eno Date: 2/21/2020 Project: PBU Site: 03 Rig Name/No.: CDR -2 Spud Date/Time: 9/17/1976 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA000013B3 Active datum: KB @55.50usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations hr (usft) 03:30 - 08:00 1 4.50 1 BOPSUR P ! PRE TEST BOPEAS PER BPANDAOGCC !. STANDARD. WITNESS WAIVED BYAOGCC BY GUYCOOK - 7-1/16" ANNULAR, BLIND/ SHEAR, 2-5/8" PIPE I /SLIP, MUD X, 2-3/8" x 3-1/2" VARIABLE, 2-5/8" iPIPE/SUP -ALL TESTS 250 PSI LOW/ 3500 PSI HIGH - FOR 5 MIN EACH -TEST I: IRV, RACKOFF, C98 C10 BACKWARD -PASS -TEST 2:BLIND / SHEAR, RI,BLIA,B1,B4- (PASS -TEST 3: ANNULAR (2-5/8"), TIW#2, B3, B2, I BL1 - PASS' -TEST4: UPPER 2-5/8"PIPE/ SLIPS, TIW#2, I I I BL2, R2, T2, C75 -PASS -TEST 5: C16, TI, C11 -PASS 1 TEST 6: VERS (2-5/8"), C7, C9, C10, TV2 - PASS I-TESTI: LOWER 2-5/8" PIPE/ SLIPS, C5, C6, 'CB, TVI - PASS "- TEST 8: CHOKE A, CHOKE C - PASS REMOVE TEST JOINT, INSTALL SAVER SUB TO MOVE 3-1/2" SECTION ACROSS RAMS — -TEST 9: ANNULAR "), C1, C4 -PASS TEST10 - VBR (3-1 /2"), /2"), C2, C33 1.08:00 - 09:00 j 1.00 RIGU P — PRERIG DOWN TEST EQUIPMENT. - CLEAN AND CLEAR RIG FLOOR. INSTALL DRILLING RISERS. GET RKBS. 09:00 - 11:00 2.00 RIGU IN PRE PRESSURE TEST MUD PUMPS. LINE UP TO REVERSE CIRCULATE. CUTOFF 1 FT OF CT TO GET A NICE CUT ON THE END OF CT. MOVE INJECTOR OVER, Mi TO WELL. PJSM FOR PUMPING SLACK BACKWARDS. _ ___ ;11:00 13:00 2.00 RIGU N PRE PUMP 5.5 BPM BACKWARDS WITH 160 DEG j FRESH WATER AT 4800 PSI, NO MOVEMENT. PUMP 170 BBLS THROUGH CT. SURGE PUMP SEVERALTIMES, GO UP AND DOWN ON THE RATE. NO MOVEMENT HEARD, SHUT DOWN AND TRANSFER FLUID TO BUILD AN EP LUBE PILL. POP OFF AND CHECK CABLE WHILE MIXING 1 EP LUBE, STILL IN SAME SPOTABOUT 1 FT - 13:00 - 15:00 2.00 RIGU _ N PRE HANGING OUT. PUMP 30 BEDS EP MUD LUBE PILL FOLLOWED BY FRESH WATER AT 5.6 BPM 4700 PSI, PUMP FOR 20 MIN, NOTHING HEARD. SURGE PRESSURE UP TO 3000 PSI AT SR8 (BALL DROP VALVE) NO MOVEMENT. 1 MOVE FLUID AROUND PITS TO MAKE ROOM FOR 10.4# MUD, _ I WHILE MOVING FLUID AROUND POP OFF AND CHECK WIRE, STILL IN SAME SPOT. 15:00 - 16:15 1.25 RIGU N PRE PUMP 10.4# BRINE. WITH 10.4# BRINE ALL THE WAY AROUND PUMP 4.6 BPM AT 4800 PSI. NO MOVEMENT. CYCLE PUMP UPAND DOWN. PUMP FOR 10 MIN, NO MOVEMENT. Printed 2/26/2020 3:34:40PM **All depths reported in Drillers Depths** .. North America - ALASKA - BP Page 3 oflTf Operation Summary Report Common Well Name: 03-07 Event Type: RE-ENTER- ONSHORE (RON) Start Date. 2/11/2020 End Date. 2/21/2020 Project: PBU Site: 03 Rig Name/No.: CDR -2 Spud DateRime: 9/77/1976 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. IBPUOI: USA00001383 Active datum: KB @55.50usR (above Mean Sea Level) Date From- To H"Task hr) Code NPT Total Depth usfl Phase Description of Operations 16:15 - 19:30 3.25 RIGU P PRE PUMP 8.6# MUD AROUND. WITH MUD ALL THE WAY AROUND PUMP 5.7 BPM AT 4000 PSI. NO MOVEMENT. LIFT INJECTOR UP, INSTALL EXTERNAL CT CONNECTOR. PULL TEST AND PRESSURE TEST. INSTALL UPSIDE DOWN AGITATOR WITH A DPS AND MILL WITH 1" PORT. PUMP 8.6# MUD AT 4.7 BPM AT 3400 PSI FOR 5 MINUTES FOR TWO CYCLES, CHECK WIRE AND WIRE HAD MOVED 3' PUMP 8.6# AT 5.5 BPM AT 4150 PSI VARYING THE PUMP. RATE BETWEEN 3.7 BPMAND 5.5 BPM AND STOPPING COMPLETLY TWICE AND RAMPING UP FOR A DURATION OF 25 _ MINUTES. 19:30 - 21:00 1.50 RIGU P PRE .PERFORM SURFACE INSPECTION OF INJECTOR, GOOSE NECK, HORSEHEAD AND REELAFTER RUNNING AGITATOR. CUT 144' DITION OTHE 81' .. PREVIOUSLY CUT) DOR OTAL OF 225' CUT WITH NO ELINE OBSERVED. RIGU P PRE INSTALL COILTUBING CONNECTOR i21�i 3.00 - - BEVELAND REAM COIL j - INSTALL CTC AND DIMPLE COIL - PULL TEST CTC TO 65K NOTE: HOLD PRE SPUD AND TABLE TOP H2S I EVACUATION DRIILL WITH RICK ROYS CREW. 2/14/2020 120.45 - 00:00 3.25 _+ _ DRILL N 1 PROD1 TROUBLE SHOOT E LINE -TEST WIRE FROM MWD OFFICE TO BULKHEAD -GOOD j -OPEN UQC AND FIND WIRE PULLED OUT OF I HEAD -REMOVE UQC AND FIND E LINE IN FLOATS -TEST E LINE AND FAILED MEG -CUT 1' OFF ELINE AND STILL FAILING MEG -DISCUSS WITH ODE AND AGREE TO CUT BACK COIL IN 20'SECTIONS AND LOOK FORA GOOD TEST ON WIRE. —LOCK OUT ELINE -HOLD PJSM FOR CUTTING COILAND RIG UP CUTTER. I I -CUT COILAND CHECK ELINE EVERY20' CUT. -STOP CUTTING COILAT 100' '.-LOCKOUT REELAND CHECK COLLECTOR COLLECTOR TES WIRES CONNECTED AND COLLECTOR TESTED GOOD. Printed 2/26/2020 3:34:40PM **All depths reported in Drillers Depths" North America - ALASKA - BP Page a y* Operation Summary Report - _ Common Well Name: 03-07 Event Type: RE-ENTER- ONSHORE (RON) Start Date. 2/11/2020 End Date: 2/21/2020 Project: PBU Site: 03 Rig Name/No.: GDR -2 Spud Date/Time: 9/17/1976 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001383 Active datum: KB @55.50usft (above Mean Sea Level) Date From - To i Hrs Task Code NET Total Depth 1 Phase Description of Opemlions (hl) (usft) I 00:00 - 05:30 5.50 RIGU P PRE INSTALL COIL TUBING CONNECTOR - INSTALL STINGER -MAKE UP INJECTOR AND PUMP SLACK FORWARD -BRING PUMP RATE UP TO 5.5 BPM AND CYCLE TWICE IN 20 MINUTES, REMOVE INJECTOR AND NO WIRE FOUND. -MAKE UP INJECTORAND BRING PUMPS j —BACK UP TO 5.3 BPM AND DUMP PRESSURE SEVERAL TIMES HEARING WIRE MOVEMENT EACH TIME FOR A SHORT TIME.. REMOVE INJECTOR AND NO WIRE FOUND IMAKE UP INJECTOR AND BRING PUMPS BACK UP TO 5.3 BPM AND DUMP PRESSURE SEVERAL TIMES HEARING WIRE MOVEMENT j EACH TIME FOR A SHORT TIME. CLOSE IN SR8 AND BUILD PRESSURE 703000 PSI AND DUMP PRESSURE HEARING WIRE MOVE WHEN PRESSURE GOES DOWN PAST 1500 PSI WIRE SOUNDS LIKE IT IS AT INJECTOR. j I REMOVE INJECTOR AND NO WIRE FOUND i -MAKE UP INJECTOR AND. CLOSE IN SR8 - AND BUILD PRESSURE TO 3000 - 4000 PSI IAND DUMP PRESSURE HEARING WIRE MOVE WHEN PRESSURE GOES DOWN PAST 1500 PSI FOR ABOUT 2 SECONDS. BRINGING PUMPS UPAS WE SEE PRESSURE DROPPING WIRE SOUNDS LIKE IT IS AT INJECTOR. REMOVE INJECTOR AND NO WIRE FOUND -ORDER 200 BBLS OF HEATED FRESH WATER -MAKE UP INJECTOR AND. CLOSE IN SR8 AND BUILD PRESSURE TO 3000 - 4000 PSI AND DUMP PRESSURE HEARING WIRE MOVE j WHEN PRESSURE GOES DOWN PAST 1500 PSI FOR ABOUT 2 SECONDS. BRINGING PUMPS UPAS WE SEE PRESSURE DROPPING WIRE SOUNDS LIKE IT ISAT INJECTOR. REMOVE INJECTOR AND NO WIRE FOUND. -MAKE UP INJECTOR AND. CLOSE IN SR8 'AND BUILD PRESSURE TO 3000 - 4000 PSI AND DUMP PRESSURE HEARING WIRE MOVE WHEN PRESSURE GOES DOWN PAST 1500 PSI FORABOUT 2 SECONDS. BRINGING PUMPS UPAS WE SEE PRESSURE ''. DROPPING. -CLOSE IN CHOKE BAND PRESSURE UP TO 3000 PSI AND THEN OPEN UP CHOKE WHILE STILL PUMPING, HEAR NO MOVEMENT OF WIRE. CLOSE IN SR8 AND BUILD PRESSURE TO 3000- 4000 PSI AND DUMP PRESSURE DID ! NOT HEAR WIRE MOVE WHEN PRESSURE SII GOES DOWN REMOVE INJECTOR AND NO WIRE FOUND. --START BUILDING HI VIS PILL - MAKE UP INJECTOR AND PUMP SLACK FORWARD -BRING PUMP RATE UP TO 5.3 BPM j AND CYCLE TWICE IN 20 MINUTES, WTIH HI VIS PILL READY PUMP IN 25 BBLS OF 90K _SRV HI VIS PILL INTO COILAND ATTEMPT TO I SURGE AGAIN WITH SRS AGAIN HEARING I Printed 2/26/2020 3:34:40PM '"All depths reported in Drillers Depths" North America - ALASKA- BP rage 5os Operation Summary Report Common Well Name: 03-07 Event Type: RE -ENTER -ONSHORE (RON) Start Date: 2/11/2020 End Date: 2/21/2020 Project PBU -- Site: 03 Rig Name/No.: CDR -2 Spud Date/Time: 9/17/1976 12:00 OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOi: USA00001383 _ Active datum: KB @55.50usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth I Phase Description of Operations (hr) (usf ) ELINE MOVING BUT COMING TO AN ABRUPT STOPAFTER A COUPLE OF SECONDS. PUMP TEN BBLS OF HI VIS PILLAND SURGE COUPLE OF TIMES WITH THE SAME RESULTS. REPEAT UNTIL 50 BBLS OF HI VIS PILL IS LOADED INTO REELREMOVE ! INJECTOR AND NO WIRE FOUND. LINE UP PITS TO PUMP HEATED FRESH WATER. 10530 - 0730 2.00 RIGU P I PRE PUMP HEATED SEAWATER AT 5.5 BPM FOR 35 ! BBLS WITH NO WIRE MOVEMENT I POP OFF WELLAND INSTALL AGITATOR. INSTALL BHI FLOAT SUB WITH FLOATS TO PREVENT CABLE FROM GOING INTO (AGITATOR. PUMP 4.4 BPM / 4600 PSI WITH HEATED SEAWATER. - 'SWAP TO MUD, PUMP 5.2 BPM AT 4400 PSI. POP OFF WELL, WIRE IS THERE, CHECK WIRE, GOOD. ! INSTALL BHI CABLE HEAD. WHILE INSTALLING CHECK REEL SHIMS, CHECK BOP BOLTS AND COMPONENTS. VALVE CREW CHECKS TREE BOLTS. 107:30 - 08:30 1.00- KILLWP PRE TEST CHECK VALVES, GOOD. j TEST CT CONNECTOR AND UQC BODY, GOOD. 08:30 - 09:30 1.00 KILLW P PRE M/U BHA#1, NOZZLE BHA. INSPECT INJECTOR CARTAND INJECTOR. WAIT FOR VALVE SHOP TO FINISH CHECKING TREE BOLTS. PRE PRESSURE TEST RISER CONNECTION 3500 09:30 - 11:00 1.50 KILLW P PSI, GOOD. PUMP 10 BBLS SLICK WATER SPACER THEN 1 10 BBLS MEOH FOLLOWED BY 48 BBLS H2S SCAVENGER PILL. OPEN UP WELL, PUMP OUTTO TIGER TANK. ZERO WHP. _ 11:00 - 16:30 5.50 KILLW P PRE RIH, TAKE RETURNS TO TIGER TANK AT 10350' WT CHECK IS 73K. �— GO TO 3.6 BPM/2800 PSI. PUMP REMAINING SLICK KCL THEN SWAP TO MUD. WITH KCLAROUND PURGE CT RISER. PRE WITH GOOD MUDALLTHE WAYAROUND 16:30 - 19:15 2.75 KILLW P SHUT DOWN FOR FLOW CHECK -STATIC POOH 1.65 BPM IN /1.10 BPM OUT FLOW CHECK FOR TEN MINUTES ..__..jr— ._--F_--__..._—_ STATIC -HOLD PJSM WHILE FLOW CHECKING 18:15 - 20:45 1.50 DRILL P PROD1 BHA HANDLE ! I INJECTOR OFF AT 1915 HRS LAY DOWN NOZZLE BHA - MAKE UP BUILD BHA INJECTOR ON AT 2030 HRS TEST QTS TO 3500 P51 TEST MWD -FAILED MEG INJECTOR OFF AT 2045 HRS STAND BACK BUILD BHAAND MONITOR WELL Printed 2/26/2020 3:34:40PM "All depths reported in Drillers Depths" Printed 2/26/2020 3:34:40PM **All depths reported in Drillers Depths'" North America - ALASKA - BP Page 6 em Operation Summary Report Common Well Name: 03-07 Event Type. RE-ENTER- ONSHORE (RON) Start Date: 2/11/2020 End Date: 2/21/2020 Project: PBU Site: 03 Rig Name/No.: CDR-2 Sputl Date/Time: 9/17/1976 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUO1: USA00001383 Active datum: KB @55.50usft (above Mean Sea Level) Date From -To His Task Code NPT I Total Depth Phase Description of Operations (hr) (usft) 2/15/2020 00:0 - 05:00 5.00 DRILL N PROD1 CUTCOIL/REREAD j-CUT i COILAND CHECK ELINE EVERY 20' CUT. - - GET A GOOD TEST ON ELINE AFTER CUTTING 80' OF COIL FOR A TOTAL OF 180' CUT -RIG DOWN HYDRUALIC CUTTER. -BEVELAND REAM COIL - INSTALL CTC AND DIMPLE COIL 105:00 - 07:30 2.50 DRILL N _PULLTESTCTCT065K PROD? IN,BHI CABLE HEAD AND TEST, GOOD. I TEST CHECKS, GOOD. CT CONNECTOR, GOOD. 1 (TEST TEST RISER CONNECTION, GOOD. _ 07:30 - 09:00 1.50 DRILL N PROD1 INSTALL AGITATOR, M/U INJECTOR TO WELL. PUMPFORWARDAT4.9-5 BPM/4500 PSI FOR 30 MIN. POP OFF WELL, REMOVE AGITATOR. CHECK BHI CABLE HEAD, GOOD. M/U BHA #2. INJECTOR ON AT 08:40. VALVE SHOP I NSPECT TREE BOLTS. INSPECT INJECTOR, CART AND REEL. P TPROD-1 RIH BHA#2. 0900 - 11'.30 2.50 DRILL PUMP 4.5 BPM THROUGH OPEN EDC. REDUCE AS NEEDED TO KEEP WINDOW ECD <10.5 PPG. 11:30 - 17:45 6.25 DRILL I P 10,545.00 PROD? TIE-IN DEPTH FROM 10290'. CORRECT-7'. _ .CLOSE EDC. V RIH THROUGH WINDOWAT 0 PUMP, 150Rs 20 FT/MlN. ' LIGHT TAG AT 10387'. LIGHT PICK UP 2' AND START DRILLING. KEEP 102# ECD AT WINDOW. I DRILL FROM 10388' TO 10,540' (MUD WEIGHT IN/OUT IS 8.75/8.78 PPG. ROP IS 10 - 20 FT/HR RATE 2.74 / 2.82 BPM AT 2800 - 3000 PSI. AT 10525' PUMP 5 BBLS LO / HI VIS SWEEPS. _�' DRILL 7O 10545' '.1745 - 18A 1.00 DRILL P 10,545.00 PROD1 'WIPER/TIEINTRIP - POOH JOGGING 50' BELOW WINDOW j - PULLTHROUGH WINDOWAND OPEN EDC - TIE IN AT 10300' 0.0' CORRECTION - PERFORM CCL FROM 10100'- 10280' -CLOSE EDC - TIE IN TO RA 10373' -RIH _ 18:45 - 00:00 5.25 1 DRILL P 10,790.00 PROD1 DRILL 4-1/4' BUILD 10545'-10790' (BUILD SECTION TD) SPIN: 2750 PSI, 2.89 BPM j (PRESSURE:: - RATE: 2.89 BPM IN, 2.86 BPM OUT. CIRC PRESSURE: 3500-3670 PSI '- MUD WEIGHT: 8.80 PPG IN, 8.86 PPG OUT, WINDOW ECD: 10.16 PPG -ROP: 30-60FT/HR, WOB:2.5-4.0 KLBS Printed 2/26/2020 3:34:40PM **All depths reported in Drillers Depths'" TREE= 6-3/8' CALICO WELLHEAD= FMC GEJ 1 ACTUATOR. BAKER OKB. ELEV = 61.0' RIF E -EV = 55.5 BF. EF/ = 27.62' KOP= 7968' Max Angle = 93' @ 11811' Datum AO= 10456' Datum TVD= 8800'SS 20' COND, I—i 107 9411, H40 D = 19.124' 13-3/8' CSG, 72#, MN -80 B UTf, D = 12.347' 2699' TOPOF7"LNR 7798 9-58" CSG, 478, MN -8D BTC, D = 8.681' 7968' Minimum ID = 3.80" @ 10117 41/2" HES XN NIPPLE MILLED TBG, 12.69, 7' LW 2611, L-80 BTC -M-0383 bpf, D =6276" 10279' 45 KB BKR PKR WS ad RA TAG ® 10367'(01)02 10365' PERFORATION SUMMARY REFLOG: ANGLE AT TOP PERF: 34' r@ 103W NOW Refer to Production DB for Natodcal perfdata SIZE SPF I INTERVAL op F SHOT SOZ 2-71W 6 10396 -10426 C 07/13/19 1991 2-718" 6 10436-10466 c 07/13/19 0410604 2-71W 6 ID476-10506 C 07/12/19 10/15/14 2-7/8' 6 10528 -10558 C 07/12/19 11/17/14 2-718' 6 10890-11018 C 07/08/18 03/17/16 JMM/JMD 2-71W 6 11400-11500 C 10/15/14 2-7/8' 6 12100-12130 C 0623113 2-7/8' 6 12130-12155 C 0522/13 2-71W 6 12150-12175 C 0621113 2-718' 6 12157-12162 C 0603113 2-7/8" 6 12175-12200 C 0621/13 3-W 6 12750-12770 C 02/16/10 3nW 6 12770-12830 C 02/13/10 2-7/8' 6 13200-13300 c 09102106 2-718' 6 13650 -13750 c 0427104 3.958' 13840' 03— 0 7 A SAFETY NOTES: H2S READINGS AVERS 125 ppm W HEN ON MI -- WELL REQT702ES A SSSV =*** WELL ANGLE> 70' @ 10766' CHROME NPPL W*** F6S X FOC FOC - 7798' 9-518' X 7" BKR ZXP EPw /TACK SLV & HGR, D = 6290' MLLOUT WINDOW (03-07A) 7%8' - 7984' 10052'--j4-1/2" HES X NP ID = 3.813" 10073' 7' X 4-12" BKR S-3 PERMPKR, D = 3.875" 10097' 4-12" HES X NIP, D = 3.813" -, I 10136' 1 1 10148' 1 1126W 14-12" HES XN NP MLLED TO 3.80' (01/16)201 I WLEG, D = 17- X 5" BKR LNR HGR, 1)=4A 10" 1 3-80" EXB WINDOW AND = 12' OF I PBTD I DATE REV BY COMMENTS DATE REV BY COMMENTS 1020176 ORIGNALCOMPLEfION 04/19M6 JTGIJMD PULLED XN LOCK VdGAUGES(4118/16) 1991 R990 07/10/18 JTM/JMD MLLED PLUG/SEr PLUG/ADPERFS 0410604 KAK RIO SDERRACK (03-07A) 03/12112 DD/JMD ADD ED OKB, RE F. & BF ELEV 10/15/14 SRDIPJC SETCBP/ADPERF 07115/19 TJS/JMD SEr PLUG& ADPERFS 11/17/14 JMD CLEANED UP WBS PER TALLIES 01,0620 NXWiiE-rVMIPSTOCK%WRATAG(OlM2r2o) 03/17/16 JMM/JMD SET FLO THRU SUB w/GAUGES (3 012020 TA/JIAD MLLED XN NP & WINDOW PRE -CTD MILLED & RUSH® PRUDHOE BAY UNfr WELL: 03-07A PERMIT No: 1040430 API No: 501029-20220-01 Tl ON, R15E, 1316' FSL & 812 BP Exploration (Alaska) THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-07A Permit to Drill Number: 204-043 Sundry Number: 319-546 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage; Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 wv .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Je rice Chair DATED this \O day of December, 2019, 3BDMSN% DEC 1 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Mr 9 - nnen 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ r� Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑CYIAnKe�9,yytl•gro�ram ❑ Plug for Retlrill 0 ' Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other `// VV ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 204-043 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service Z. 6. API Number: 50-029-20220-01-00 , 7. If perforating: - What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 03-07A 9. Property Designation (Lease Number): 10. Field/Pools: ADL 02832 7. 028328 8 028331 PRUDHOE BAY, PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 10749, Junk (MD): 13841 9052 10749 9019 2554 11250,12650 13025,13490 12650 Casing MD TVD LengthWS'zeTubing Burst Collapse Structural Conductor 80 30-110 31 - 111 1530 520 Surface 2663 30-2693 30-2693 5380 2670 Intermediate 7940 28-7868 28-6752 8150 / 6870 5080/4760 Liner 2481 7798-10279 6636-8708 7240 5410 Liner 3713 10127-13840 8573-9052 8430 7500 Perforation Depth MD (ft): Perforation ing Size: Tubing Grade: Tubing MD (ft): 10396 - 13750 884-1/2" 12.6lf L-80 26-10130 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft) and TVD (ft): 10073/8526 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ P ry Stratigraphic ❑ Development ❑ Service H 14. Estimated Date for Commencing Operations: December 10, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 15. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hyatt, Trevor be deviated from without prior written approval. Contact Email: Trevor.Hyatt@bp.com Authorized Name: Mclaughlin, Sean M Contact Phone: +1 907 564 4627 Authorized Title: E2ffneenng Tea ead - CTD Authorized Signature:12-120 Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry' Number: Plug Integrity ❑ BOP Test fa/ Mechanical Integrity Test ❑ Location Clearance ❑ 3k` Jc. rto, _ee+0 ZOJi%iC-Z$ /����, G1�c rn0.7e �/JC y�4Ceih Lin �0./v TOGIC� Past Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Yes ❑ No Ef Subsequent Form Required: �y p APPROVED BYTHE Approved by: V COMMISSIONER COMMISSION Date: W C Form 10-003 Revise7O4/2017 IBDMSL-OJ DEC 1 12019 iAk0 UNMINA p tY1,8•�.@�D��-(9 r Submit Form and Approved application is valid For 12 months from the date of approval IX Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz - CTD Engineer Date: November 26, 2019 Re: 03-07A Sundry Approval Request Obp Sundry approval is requested to plug off the 03-07A production as part of the drilling and completing the proposed 03-078 coiled tubing sidetrack. History of 03-07A 03-07A was originally sidetracked in 2004. 03-07A is currently being used to inject when there is excess MIT supply. No remaining parentvalue. -- — Proposed plan for 03-078 The sidetrack will be a ^3653' horizontal CST that will kicks -out from the 03-07A parent. The CST will be a MIST injector at the base of the victor interval supporting 5 offset producers. During pre -rig work it is proposed to set a 4-1/2" whipstock at a kickoff depth of -10367' MD and mill a 3.80" window. The rig will move in, test BOPE and kill the well, and drill into Zone 2. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" L-80 solid liner and cemented in place. This Sundry covers plugging the existing 03-07A production via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin December 2019) 1. S Drift for whipstock. 2. EL Set CIBP. Set Whipstock 3. F A/EL: Displace well to brine. MIT -T MIT -IA 4. C Mill XN Nipple. Mill Window Z y m e !i tM OCG T 5. V Pre -CTD Tree work. Rig work (scheduled to begin February 2020) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2554 p`- 2. Drill production section: 4.25" OH 3. Run 3-1/4" x 2-7/8" liner to TD. 4. Pump primary cement job: 41.5 bbls, 15.3 ppg Class G, TOC at TOL 5. Freeze protect well to a min 2,200' TVDss. 7. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. V: Valve & tree work 2. SL/FB: Set LTP if needed. PT LTP. Set KO GLD. 3. CT: Perforate -120'. Acid stim if injectivity low Ryan Ciolkosz CC: Well File CTD Engineer Joe Lastufka 564-5977 mss �0�E-%57 3�Qps % The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EMW of 8.4 ppg KCL ("'488 psi over -balance). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "openhole" a BHA. Disposal: • All Class 1& II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. • Fluids >1% hydrocarbons orflammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24 hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and 4,000 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "a firewall to shield accumulators and primary controls". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: • DS 03 is an H25 pad. Estimated H2S levels based on approx. concentration of MI gas in 03-07A: 100 ppm. Max H2S recorded on the pad: 650 ppm. — Reservoir Pressure: • The reservoir pressure on 03-07B is expected to be 3457 psi at 9035' TVDSS (7.36 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2554 psi. • A min EMW of 8.4 ppg for this well will provide 488 psi over -balance to the reservoir. Ryan Ciolkosz CC: Well File CTD Engineer Joe Lastufka 564-5977 TREE= 6-3/8'CALDO WELLHEAD= FMC GEN 1 ACTUATOR= BAKER OKB. EEE/ = 61.0' REF ELE1/= 55.5' BF. ELEV = 27.62' KOP= 7968' Max Angle = 93° W 11811' f)afixn ND= 10456' Dakm NIA B800'SS 9, W40 = 19.124' 13-3/8' CSG, 729, W80 BUTT, D=12.34T 26w TOP OF 7- LNR 7798' Minimum ID = 3.725" @ 10117' 4-1/2" HES XN NIPPLE 9-58' CSG, 479, MN -80 BTC, D = 8.681'796 12.69, 17' LNR 269, L-80 BTGM..0383 bpf, D = 6.276' I PEWORATION SUMMARY FEF LOG ANGLEAT TOP FERF: 34° @ 10396' Note: Refer M F rodwtion US for historical perf data SRE SPF INTERVAL OpNSgz SHOT SQZ 2-7/8" 6 103%- 10426 O 07/13/19 10/15/14 SRD/ PJC 2-7/8" 6 10436- 10466 O 07/13/19 03/17/16 JWMJMD 2-7/8" 6 10476- 10506 O 07/12119 2-7/8" 6 10528 - 10558 O 07/12!19 2-7/8" 6 10890-11018 C 07/08/18 2-7/8" 6 11400 - 11500 C 10/15114 2-7/8" 6 12100 -12130 C 06/23/13 2-7/8" 6 12130 -12155 C 0622113 2-7/8" 6 12150 -12175 C 0621/13 2-7/8" 6 12157 - 12162 C 0623/13 2-7/8" 6 12175 - 12200 C 06/21/13 3-318" 6 12750 - 12770 C 02/16/10 3-3/8" 6 12770- 12830 C 02/13/10 2-718" 6 13200 - 13300 C 09/02106 2-7/8" 6 13650 -13750 C 04/27/04 SAFETY NOTES: H2SREADINGS AVERAGE 125 03-07A ppm WHEN ON MI --WELL REQUIRES A SSS V WHEN ON Ml— WELL ANGLE> 70'@ 10766' TFL ...4-1/2' CHROME NIPPLES•'•* 2190'4-1/THESXNP,D=3.813' 21 325 I -J 9-5/s' FOc 2446' 9-518" FOC 7798' 9-5/8' X 7" BKR ZXP LTPwRT SLV & HGP, D = 6.290" MLLOUT WWDOW (03-07A) 7%8' - 7984' 10052' --14-1/2' FEE X NP, D= 3913' 10073' 7'X4-1/2' BKR S-3 PB7M RCR 1 10097' 4-12' HES X NP, D = 3.813' 10117' 4-12'FESXNNP,D=3.725' 10127' 9-5/8' X 7' BKR T®AqC BLV, D 10130' 4-12' WLEG, D=3.956" 10135' 7'XS'BKR ZXP LTP,D=4.420° 10141' 7'X5°BKR LNR HGR D=4.410' 101 7" X 4-1/2' XO_ D = 3 980' 10749' 1-14-1/2' 13752' i4-12' LNR 12.6#, L-80 BT -M..0152 bpf, D= 3.958' 13840' DATE REV BY COMVEJIB DATE RE/ BY OOKfABm 10120!76 ORIGINAL COMPLETION04/19/16 JTG/JMD PULLED XN LOCKw/GAUGPS(4/18/16) 1991 RWO 07/10/18 JTWJMD MLLED PLUGJSET PLUG'ADPERFS 04/06/04 KAK RIG SIDETRACK (03-07A) 03/12/12 OD'JIW ADO®OKB, IiEE, & BF LLEV 10/15/14 SRD/ PJC SET CIBP/ADPERF 07/15/19 TJS/JMD SET PLUG &ADPHKS 11/17/14 XVD CLEANED UP WBS P92 TALLIES 03/17/16 JWMJMD SET FLO THRU SUB W /GAUGES (3/15/16) FISH - 14 -1 /2' ISH: 14-1/2' CBP(02/1211011 PRUDHOE BAY UNB WELL: 03-07A PERMFr No: P2040430 APIND: 50-029-20220-01 T10N, R15F-1316' FSL & 812' FWL BP Exploration (Alaska) LHEAD= FMC GEN 1 PROPOSEDO Note: Refer to Production DB for historical erfdato SIZE SPF INTERVAL I OpF0Sqz I SHOT SAFETY NOTES: H2S READINGS AVERAGE 125 JATOR= KAK REV 1 _O Ppm WHEN ON MI— WELL REQUIRES A SSSV . ELEV= 61.0' BULTPROPOSED 08/07/19 RC/.NAD BULT PROPOSED REV 1 WHEN ON MI -- WELL ANGLE >70'@_'•"'4- ELEV = 55.5' 112" CHROME NIPPLES' :LEV = 27.62' = 7968' 20" ()OND,107" 2190' 4-12• FES X NP, D = 3.813" 4ngle = 944, H-00 n MD= nM ' n D= 8800' SS D=19 124" 2325' 9sr13• FOC 2446' 9-5/8" FOC 13-3/8" CSG, 7211, MN -80 BUTT, D = 12.347'2699' 9-5/8' CSG, 47#, MN -80 BTC, D = 8.681" 7966' Minimum ID = " OP OF 4-1/2" LNR bpf, D = 3.958" 10130' TOP OF _LNR 10200' 7• LNR, 26#, L-80 BTC -M..0383 bpf, ID = 6.276• 10279' 4-12•BKRPKRVWWSTOCK (—/_/� 103 TT LNR, 12.6#, L-80 IST -M..01 52 bp( ID = 3.958• —10367' • 3-1/4" LNR, 6.6#, L-00 TC 11, .0079 bpf, D = 2.85' PERFORATION SUMMARY REF LOG: ANGLE ATTOP PERF: Note: Refer to Production DB for historical erfdato SIZE SPF INTERVAL I OpF0Sqz I SHOT I SQZ 04106104 KAK RIG SIDETRACK 103-07A) _I_I_ PBTD D 2-7/8' LNR, 8.5#, L-80 STL, .0058 bpf, D = 2.441' 14020' 7798' �9-5/8' X 7' BKR ZXP LTP w/TEBACK SLV 8 HGR, D = 6290' MILLOUT WNDOW (03-07A) 7968' - 7984' 10052' --�4-1/2" HES X NP. D =3.813" 10073' 7" X 4-1/2" BKR S-3 PERM PKR D = 3.875" 10097' 4-112" HES X NP, ID = 3.813" 10117' ---�4-12' HES XN NIP. ID =3-725" 1 UT�-17• X 5• BKR ZXP LTP W/TEBACK MLLOUT WNDOW (03-0713)_'-_' 1066W —� 3-1/4' X 2-7A9' XO. D = 2.377' DATE ILV 8 HGR, D = 4.410" 10130' 4-12" WLEG, D=3.958" 10148' 7" X 4-12" XO, D = 3.980" 10200' 3.70" DEPLOYSLV, D = 3.00' 3-12' XNV D=2.813" MLLOUT WNDOW (03-0713)_'-_' 1066W —� 3-1/4' X 2-7A9' XO. D = 2.377' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/20(76 ORIGINAL COMPLETION 1991 RWO 04106104 KAK RIG SIDETRACK 103-07A) _I_I_ CTG ST (03-97B) 08/06/19 JMD BULTPROPOSED 08/07/19 RC/.NAD BULT PROPOSED REV 1 PRUDHOE BAY UNIT WELL: 03-07B PERMIT No: API No: 50-029-20220-02 T10N, R15E,1316' FSL 8 812' FWL BP Exploration (Alaska) Choke Manifold L ----j .......... CFarm ----------------- � I I sours I I I � I 1 I � i,_, Coiled Tubing Unit -------------- Barrels of Water per Month y;uow aad („jaw„) seg ;o zaaj :)Iqn:) puesnogl N 0 N .j O O O 0 0 N O O O O O p O e'I O e♦ p'I y;uow aad („jaw„) seg ;o zaaj :)Iqn:) puesnogl N 0 N .j O 0 0 N O 0 0 a 0 0 0 o s r o tie � c I y ♦ — is ♦ 4 1 y.c_�sti jI' ys s m c� y;uow aad („jaw„) seg ;o zaaj :)Iqn:) puesnogl N 0 N .j O 0 0 0 0 0 0 0 0 o s O o o y;uow aad („jaw„) seg ;o zaaj :)Iqn:) puesnogl N 0 N .j O Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of"Suspended." Ste Task Res onsib 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed initial Geologist work) the reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling The drilling engin6ers will serve as quality control for steps 1 and 2. Engineer (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 10-407 for the redrill is received, the Stat Tech will Stat Tech e original well's status from SUSPENDED to ABANDONED. EForm eek of every January and July, the Stat Tech and one of the Stat Tech s will check the "Well by Type Work Outstanding" user query Geologist S to ensure that all of the Plug for Redrill wells have been roperly. At this same time, they will also review the list of wells for accuracy. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG O REPORT OF SUNDRY WELL OPERATIONS A 1 2019 1. Operations Performed Abandon [I Plug Perforations D Fracture Stimulate ❑ Pull Tubing ❑ Operations 1..� C �p Suspend ❑ Perforate 0 Other Stimulate m Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set CIBP, Mud Acid Stimulation 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Pernit to Onll Number 204-043 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ® 1 6. API Number: 50-029-20220-01-00 7. Property Designation (Lease Number): ADL 028327, ADL 028328 & ADL 028331 8. Well Name and Number: PBU 03-07A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11, Present Well Condition Summary: Total Depth: measured 13841 feet Plugsmeasured 126504930255103490 feet true vertical 9052 feet Junk measured 12650 feet Effective Depth: measured 10749 feet Packer measured 10073 feet true vertical 9019 feet Packer true vertical 8524 feet Casing: Length. Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30-110 30-110 1530 520 Surface 2664 13-3/8" 30-2694 30-2694 5380 2670 Intermediate 7940 9-5/8" 28-7968 28-6752 8150 / 6870 5080 / 4760 Liner 2481 7" 7798-10279 6636-8708 7240 5410 Liner 3713 4-1/2" 10127 - 13840 8573-9052 8430 7500 Perforation Depth: Measured depth: 10396 -13750 feet True vertical depth : 8807-9049 feet Tubing (size, grace, measured and true vertical depth) 4-1/2" 12.6# L-80 26-10130 26-8575 Packers and SSSV (type, measured and 4-1/7' Baker S-3 Perm Packer 10073 8524 true vertical depth) 4-1/2" MCX SSSV 2190 2190 12. Stimulation or cement squeeze summary: Pumped the following fluids down TBG into formation: 5 BBLS 50/50, 200 BBLS 3% NH4CI to fluid pack well, 25 BBLS 12% HCI, 25 BBLS 9/1 Mud Acid, 10 BBLS Oil Seeker Diversion, 50 BBLS 3% NH4CI spacer, 25 BBLS 12% HCI, 27 BELS 9/1 Mud Acid, 210 BBLS 3% NH4CI displacement. Injectivity: 3.1 BPM at 1382 PSI, 2.1 BPM at 688 PSI, 1.2 BPM at 50 PSI Intervals treated (measured): 120' of perforated interval between 10,396' and 10,558' MD Treatment descriptions including volumes used and final pressure: 52 BBLS 9/1 Mud Acid Final Pressures: OA = 0 psi, IA = 24 psi, TBG = 0 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 38449 49 2430 Subsequent to operation: 19045 24 0 14. Attachments: freeul,ed per 20 nnc 2e07025ID1, a 25.283) 15. Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development ❑ Service ® Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ® GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-148 Authorized Name: Summers, Matthew Contact Name: Summers, Matthew Authorized Title. Production Engineer Contact Email: Matthew.SummersAbp.com _ Authonzed Signature: `�'� Date: 7 3/ �� Contact Phone: a1 9075645066 Form 10-404 Revised 04/2017 IIIMFO� RBDMSET✓ AN 0 12019 M'a'RiO'}A")i Submit Original Only Daily Report of Well Operations PBU 03-07A ACTIVITYnATF ci u,nnneoV 'WELL S/I ON ARRIVAL'**(profile mod) PULLED 4 1/2" MCX (ser# BPX480) FROM X NIP @ 2,190' MD DRIFTED TO DEVIATION @ 10,850' SLM W/ 3.625" CENTRALIZER DRIFTED TO DEVIATION @ 10,800' SLM W/ 30'x 2 7/8" DUMMY GUNS (3.16" rings) 7/10/2019 'WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** ***WELL SHUT IN ON ARRIVAL' LRS LOAD AND KILL WELL W/ 230 BBLS DIESEL SET BAKER 4-1/2" CIBP AT 10750'. TOP OF PLUG 10,749'. 10528'- 1 -7/8" X 6 SPF 60 DEG PHASING PERFORATE 10476'- 10506' WITH 2-7/8" MAXFORCE HMX 6 SPF. 60 DEG PHASINQ LOGS CORRELATED TO SLB JEWELRY LOG 4-26-04 7/12/2019 ***JOB CONTINUES ON 13-JUL-19 WSR*** ***CONT. FROM 7/12/19 WRS*** PERFORATE 10436'- 10466' WITH 2-7/8" MAXFORCEHMX, SPF, 60 DEG PHASING ' PERFORATE 10396- " AXFAR66 HMX, 6 SPF, 60 DEG PHASING LOGS CORRELATED TO SLB JEWELRY LOG 4-26-04 7/13/2019 ***JOB COMPLETE/DSO NOTIFIED' Initial T/I/0 = 165/3/0 (SLB Cementing Unit 28803 - Mud Acid Treatment) 7/16/2019 Pump 5 bbis 50/50, 200 bbls 3% NH4CI down TBG into formation. ***Job continued on 07/17/19*** Initial T/I/O = 165/3/0 (SLB Cementing Unit 28803 - Mud Acid Treatment) ***Continued from AWGRS 07/16/19*** Pumped the following fluids down TBG into formation: 5 BBLS 50/50, 200 BBLS 3% NH4CI to fluid pack well, 25 BBLS 12% HCI, 25 BBLS 9/1 Mud Acid, 10 BBLS Oil Seeker Diversion, 50 BBLS 3% NH4CI spacer, 25 BBLS 12% HCI, 27 BBLS 9/1 Mud Acid, 210 BBLS 3% NH4CI displacement. Injectivity: 3.1 BPM at 1382 PSI, 2.1 BPM at 688 PSI, 1.2 BPM at 50 PSI. Lat Valve, MV = 0, QTR Turns, SV, SSV, WV = C, IA/OA CSG = OTG. FWHPS = 0/15/0 **'Job 7/17/2019 Complete. LRS on location to FP TBG*** ***WELL S/I ON ARRIVAL*** (Profile modiication). SET 4-1/2" MCX (S/N= M -63B, 1.30" bean) IN 4-1/2" X -NIPPLE AT 2,176' SLM / 2,190' MD RAN 4-1/2" CHECK SET TO 4-1/2" X-LOCKAT 2,176' SLM / 2,190' MD (Sheared) 7/21/2019 *'*WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** TRm= 6-318'CALIDD WELLHEAD= FMC GERI ACTUATOR= BAKER OKB. R = 61.0' REFaEV= 55.5' BF. R = 27.62' KOP= 7968' Max Angle = 93' @ 11811' Datum MD= 10456' Datun TVD= 8800'SS #, W40 = 19.124' ITOPOF 7'LNR �--� 7741 Minimum ID = 3.725" @ 10117' 4-112" HES XN NIPPLE 9-5/8' CSG. 47#. MN -80 BTC. D = 8 681' 7 ITOP OF 4-12' LNR I D= 6.276' O3-07A S �O 7 e SAFETY RTES: H2S READINGS AVERAGE 125 V / A ppm WHEN ON MI -- WELL REQUIRES A SSS V WHEN ON Ni— WELL ANGLE> 70' @ 10766' �� •"`4-112"CHROME NIPPLES"" I 10127' I PERFORATION SUMMARY RIF LOO ANGLEAT TOP PERF: 34' @ 10396' Note: Refer to Rodwbon DB for histomal perf data SIZE SPF MTERVAL OWSgz SHOT SOZ 2-7/8' 6 10396 - 10426 O 07/13/19 RIG SIDETRACK (03.07A) 2-7/8' 6 10436 - 10466 O 07/13/19 11/17/14 JM) 2-7/8' 6 10476 -10506 O 07/12/19 2-78" 6 10528 -10558 O 07/12/19 2-71W 6 10890-11018 C 07/08/18 2-7/8" 6 11400 - 11500 C 10115/14 2-78' 6 12100 - 12130 C 06123/13 2-7/8" 6 12130 - 12155 C 0622/13 2-78" 6 12150 -12175 C 06121113 2-7/8" 6 12157 - 12162 C 06/23113 2-7/8- 6 12175- 12200 C 06/21/13 3-38- 6 12750 - 12770 C 02JI6110 3-3/8" 6 12770-12830 C 02/13/10 2-7/8" 6 13200- 13300 C 09/021M 2-78" 6 13650 -13750 C 04/27104 23�-19-5/8" FOC 2446' 9-58' FOC SLV & HGR, D = 6.290' MLLOUT"DOW (03.07A) 7968'- 7984' 10097' I---♦4-12'HESXNlP D=3.813' 12-1 FISH: 4-12' CBP MLLED & PUSHE)(07/08/18) 12650' 4-1/2-CBP(0621/13) DATE REV BY COMb84rS DATE REV BY OOM ENTS 10120!/8 ORIGINAL COMPLETION 04/19/16 JTG/JM) PULLED XN LOCK w/GAUGES(4/18/16) 1991 RWO 07/10/18 JTMJM) MILLED PLRIG/SEr PLUGZADPERFS 0410684 KAK RIG SIDETRACK (03.07A) 03/12/12 DD/JM) ADDED OTB, REF, & BE ELEV 10/15/14 SRDfPJC SEr CBP/ADPERF 07/15/19 TJS/JMD SEr PLUG&ADPERFS 11/17/14 JM) CLEANED UP WBS PER TALLIES 03/17/16 J?ANJkU SEr FLOTHRUSUBw/GAUGEi(3/15/16) CBP PRUDHOE BAY UNR WELL: 03-07A PERmrr No:11040430 API No: 50-029-20220-01 SFC11.T10N. R15E 1316' FSL & 812' FWL BPEploratlon (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Matthew Summers Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-07A Permit to Drill Number: 204-043 Sundry Number: 319-148 Dear Mr. Summers: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276 7542 w W.00gcc.alosko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. 0;, Daniel T. Seamount, Jr. Commissioner d rti DATED this Z day of April, 2019. RBDMS�APR 0 2 2919 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 "L—%.iL1 V L— Lop MAR 2 6 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ O ratir�Qii q eq Repair Well ❑ � �'IFJro ivS Suspend ❑ Perforate ® ' Other Stimulate ® Pull Tubing ❑ Change App g ih Other. Set CIBP, Mud Acid 0 Plug for Retlrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Stimulation 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 204-043 3. Address: P.O. Box 198612 Anchorage, AK 99519-6612Stratigraphic ❑ Service ®' e. API Number 60-029.20220-01-00 7. If perforating:Co ^ e. Well Name and Number. What Regulation or Conservation Order governs well spacing in this 17 Will planned perforations require a spacing exception?Y s ❑ No ® PBU 03-07A Z7 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028327, ADL 028328'& ADL 028331 PRUDHOE BAY. PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 11735, Junk (MD): 13841 r 9052 11735 9054 12650,13025,13490 None Casing Length Sin MD TVD Buret Collapse Structural Conductor 80 20" 30-110 30-110 1530 520 Surface 2664 13-3/8" 30-2694 30-2694 5380 2670 Intermediate 7940 9-5/8" 28-7968 28-6752 8150 / 6870 5080/4780 Liner 2481 7" 7795-10275 6633-8706 1 7240 5410 Liner 3712 4-1/2" 10128 - 13840 8573-9052 1 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade. Tubing MD (ft): 10890- 13750 9052 - 9049 4-1/2" 12.6# L-80 26-10130 Packers and SSSV Type: 4-1/2" Baker S-3 Pen Packer Packers and SSSV MD (ft) and TVD (ft): 10073, 8524 4.1/2' MCX SSSV 2190, 2190 12. Attachments: Proposal Summary Ef Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratlgraphic 11 Development ❑ Service ®' 14. Estimated Date for Commencing Operations: 5/15/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ®GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Summers, Matthew be deviated from without prior written approval. Contact Email: Matthew.Summentgop.com Authorized Name: Summers, Matthew Contact Phone: +1 9075645066 Authorized Title: Production Engineer Authorized Signature: Date: S1a 55/9 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �A V I Plug IntegrityI ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing �BDMS1 Exception Required? Yes ❑ No Q Subsequent Form Required: 10-1100 t/gpR 0 2 Y019 APPROVED BYTHE ¢I Approved b COMMISSIONER COMMISSION Date: ` ORIGINAL Forth 10-003 Revised 04/2017 Approved application is valid for 12 months from the date of approval. t I/ � Submit Form and Attachments in Duplicate 30-403 Sundry Application for Well PBU 07-03A PTD #204-043 Expected Start Date: May 15, 2019 Current condition of well: WAG Injection Well, Operable, Offline: Gas Injection Rate: 27276 Mscf/Da Tubing Injection Pressure: 2060 psi Shut-in Wellhead Pressure: 2203 psi Reservoir Pressure: 3259 psi Well History and Objective(s): The objective of this program is to move to the final MI injection location in 03-07A through setting a plug & perforating Zone 4 to mobilize unswept oil. The purpose of this procedure is to pump a bullhead mud acid stimulation to improve the deliverability of the perforations. Target Intervals We are targeting 120' of perforated interval between 10,396' and 10,558' MD. Proposed program: 1. Pull MCX. Drift to deviation pre CT (-3.56' CIBP drift with DMY Guns) 2. Tie into SLB Jewelry log 4/26/04. 3. Set CIBP at 10,750' MD. 4. Add Perfs per Perforation Form. 5. Injectivity Test of New Perforations 6. Contingent Mud Acid Stimulations: a. If below 2 bpm @ 2,000 psi. Execute stimulation per Stimulation program. 7. Set MCX (sized for 20 MM/d). BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Au -4u3 3unory rappncanon ror vveu rou u/-u3ra r i u wzuv-u,43 Wellbore Volume 159 bbls to mid pert— 10,477' MD Volume Across Perfs 77 gallons —120' in 4-1/2" liner Acid Design 12% HCI Acid @ 17.5 gpf — 50 bbls 9:1 Mud Acid @ 17.5 gpf-50 bbls Diversion Design 10 bbls OilSEEKER Tres 173 °F @ 8800' Datum SS Fluids: Stage Fluid Type Vol (bbls) Vol (gals) Fluid Pack / Flush 3% NH4CI + F103 410 17,220 Diversion 3% NH4CI + 7.5% OilSeeker 10 420 Acid 12% HCl 50 2100 Mud Acid 9:1 Mud Acid 50 2100 Freeze Protect Dead Crude 40 1680 Recipes: Loading for: 12% HCI Concentration Total volume Product Code: Function: (gal/Mgal) Gallons A264 Corrosion Inhibitor 4 8.4 A201 Inhibitor Aid 0 0 A153 Intensifier 0 0 F103 Surfactant 2 4.2 L058 Iron Control 20 42.0 W054 Anti -Emulsion 5 10.5 U067 Mutual Solvent 0 0 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 07-03A PTD #204-043 Loading for: 9/1 Mud Acid Concentration Total volume Product Code: Function: (gal/Mgal) Gallons A264 Corrosion Inhibitor 4 8.4 A201 Inhibitor Aid 0 0 A153 Intensifier 0 0 F103 Surfactant 2 4.2 L058 Iron Control 20 42.0 W054 Anti -Emulsion 5 10.5 U067 Mutual Solvent 50 105.0 Loading for: NH4CI Concentration Total Volume Product Code: Function: (gal/Mgal) Gallons F103 Surfactant 2 34.4 Loading for: OilSeeker Concentration Total Volume Product Code: Function: (gal/Mgal) Gallons J570 OilSeeker 75 31.5 Neat McOH pH 10 4.2 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 07-03A PTD #204-043 Fullbore - Acid Stimulation • MIT -IA passed 3/17/18. • Once tubing is fluid packed do not exceed 1800 PSI injection pressure. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid stages hit the perfs and the response. • Send an electronic copy of the treatment report to Matthew Summers: matthew.summers@bp.com. 1. Pump acid stimulation fluids per attached Pump Schedule. 2. During final overflush stage perform injectivity test with 5 minute intervals at 0.5, 1, 2 and 3 BPM (max WHP 1800 psi), record pressures in AWGRS. Pump Schedule: Stage Fluid Cum. Fluid Stage Description Fluid Type Vol (BBLs) Vol (BBLs) Comment 1 Spear Neat Meth 5 5 2 Fluid Pack 3% NH4CI 200 205 3 HCI 12% HCl 25 230 4 Mud Acid 9:1 Mud Acid 25 255 5 Diversion OilSeeker 10 265 Shut down for 10 minutes once OilSeeker enters formation 6 Spacer 3% NH4CI 50 315 7 HCI 12% HCI 25 340 8 Mud Acid 9:1 Mud Acid 25 365 9 Overflush 3% NH4CI 160 525 10 Freeze Protect Dead Crude 40 565 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 07-03A PTD #204-043 Perforation Form: xwu WPENDING PERFORATING PROCEDURE tome tK.m logmee a, global Acclls aryanue non wx.z9o:_.__. eepm 9nm me re+ereMetog. WBit OWK AN :50-0ffiM2Z 1 Rafe: NtXR019 prop Enpr Ll9n <cttFxn lmce Po: 19971561-WS6 NZS Levec De M- Ifg ) fees SPF pY.p, PN91ng Home pN: Ippm 10395 10 426 CeNPaper: (9971962-16X2 4afi 10 466 GC or REF. pp&MJEC 10 Ranpprt: 60 21 7fi 10506 WXS fntriea 506P6 100061 . 6002.. 4p 'y4e san Lt93T�.tmr 10 `1a PerytealeX Gun Sue: :'T CNw: 1 :. CS' c9. Na2Eou,• 9W SreX In G9> RRiM m Tien bgw hPop9tad ceps atwot W xwu Jewe(y, tome tK.m logmee a, v�a�ocA wx.z9o:_.__. eepm 9nm me re+ereMetog. flpma(Vd M) De M- Ifg ) fees SPF pY.p, PN91ng Zone PEN TTK 396 10426 10395 10 426 30 a Ranp9n_..:.- 4afi 10 466 70 435' 10 Ranpprt: 60 21 7fi 10506 10476 506P6 100061 . 6002.. 10 s5o 10 `1a PerytealeX Gun Sue: :'T CNw: wukrc Alin Xtegpnrt Xk E._ 4459repm9qurt :. CS' 9W SreX In G9> M. _7&v,a_faa Ye9. PAeaA X&HI7 MX BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Tie in Log: 10-403 Sundry Application for Well PBU 07-03A PTD #204-043 1020456060 NLN9INIINdNd�# BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 J V-n�Y s Schlumberger n MOR; GR/CCL : 26 APRIL 2004 FINAL 4�8 S Conpany BP Exploration (Alaska), Inc. r ffi Well DS 3-07A Field PrWhoe Bay " Bo h North Slope State Alaska S L.t'. MCI r,vP la«. nsE e;E rxMMWer. m1w s«wrcw _ pn a 9 n^ API 505029 20]20 006FYt $ Per mIM. MSL ENvatl9 0 Elw.KB. 655 Fi L" M "Irm 0< 55S Ft ADM* MIMID.F Drill Mus. lr DF 245 GL 2)O m (kC5 fi < 9w. a.m6 aw ar r w ra. la as of ars F.an r. 7 Tplan wcn<� m'�,�i B r a �'gVg' c a g un l000srt .a. o-..uM m.b oae. acre n M.[ew ms9 n Rag Vf m mr ae air u5u4 aLcoao Na-Irctrs Roa ra < gg y_ 3 _ $ g V F g Z S � � y_� yry �<�<�7 FM ivr a✓.1 ) M tlRl !M! n 4IA n rMrr irkrnn . n c Pnel aavra 5I v I.. i chid P111!11, ■_z evN. ■ ,. �`lg 3s a �: „ �' J 2< a� 5 y <<-. <. r+n rllm, om rt S•l� MVp.- BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 07-03A PTD #204-043 Wellbore Schematic: IR LL V&LL1FEAD= & CALCI FMC AEN I SIF -BAFETT' ND7E8: X28 READINGS AVERAGE 125 03074 ACTUATOR= BAKER SW ppm WHEN ON W -- WEll REQUIRES A SSSV OKB ELEV - E1.0 O WHEN ON MI — Wal A0G E 170'@ 10766' REF ELEV. alis 8 "••4-112 CHROME NIPPLES'••' fir. ELEV- 27.62 0712713 DSWJMSETCBPIAOPERF(M1-23713) 2-7AT• �' W%AIr�= 7988 67 $1161Y 70 COIQ 107' 21W 4-1/1' FES % NP. D•JAU' Dalin MD = 10458 1U. KAC 7676• 1I -SA• % r BKR UV Hit D -$A7 Da TVD- aaw 53 D=16124• 2526• 6.518'POC (;Dpiri;«l-4-f " Mln'" D = 3.726' a 10117' 4-112' HES XN NPPLE i 6�SA� f1KL 4L. MNaO e7i; D—ee ver- —{ _ 7BY' - 4.1? 1aC., 1761, L�e01C11, 01c ire, o- aau•"-I FE FORAT63N SUMPORY FS LOG ANCLEATTOPFEF W010890 I/ole. FMar b Aa0uc4w1®fn IrblialpM Gab SEE SIF 61F9NAL Op^ISW SOT SW 2-716• 8 IONS- 11016 O 0741.6116 ODtIM_Il_ibJ�D ADDED SSSV SAFETY 7IDTE 2-7M' 8 114M -11500 C 101514 0712713 DSWJMSETCBPIAOPERF(M1-23713) 2-7AT• 6 12100 -12130 C COMM P.O. 2 7Ar 6 12120 - 12155 C 06ran3 2-7AT• 6 12150-12175 C OMM3 2 Mr 6 12157 - 12162 C 06=3 2 7A' 6 12175 - 12100 C OSW3 3-3V 6 12750-12770 C 0271410 378' 6 t2770 IMM C 0211310 2-7A'6 13200-13300 C W12M 2-716' 8 13650-13750 C 04!0104 41? IMA 12 ef, L-00 H i�M. 9-W X 7• BKRZXP LTP W R®ACK SIV. D = 7Sto• 1llQ7F WO0.V 1a107A1 7668 1b4 41?wa X W. 0•3-A1r � x a iT sia as DATE WVBY CCM,EMS PATE FEVs, COMENTS PRlO10E BAYUVI 1720176 CRIMINAL COIILETION 1M514 SISI PJC SE 7 CRPI ADPEIF HELL. 63-C7A 7M7 RmD 1417X4 J80 CLFiNEDL.PNBSPERTALLES PBHMTM''loMD 040M KAI MQSME7RACK(01GTA) OM716 AM6LD SET FLOTHRF SUMa67AUfE5(M5116) AAM 50O262Dt2M1 ODtIM_Il_ibJ�D ADDED SSSV SAFETY 7IDTE OViM61fOULO PIALED %N LOCKnAAlAE5. 4�IINI6j_ SEC11,ilON. R15E, 7376fSliM7fYt O1H011214MAID AIx3EDWSSAFMNOTE 07RM83WWMD M-IEDPLL0SFTPLIIGADPFIES 0712713 DSWJMSETCBPIAOPERF(M1-23713) Mn2M2 DDAM ADOm0103W,6BFELEV BP EviNo on INS" BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • . Loepp, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Monday, April 09, 2018 9:12 AM To: Loepp,Victoria T(DOA) Subject: Please withdraw sundry#318-126 for 03-07A (PTD#204-043) Follow Up Flag: Follow up Flag Status: Flagged spNNED MAY 1 7 2018 Victoria, Looks like we submitted a duplicate request for 03-07A(PTD#204-043). Please withdraw sundry#318-0126. If you have any questions or need any additional information, please let me know. Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 I Office: (907) 564-4091 -1(.41H S M Subsurface&Wells I-fo,malirr BP Exploration Alaska 1900 E. Benson Blvd. I Room: 778C Anchorage, AK RBDMg 14,1 17 201 IP 111 VOF sA THE STATE Alaska Oil and Gas 4.? — • � 0fATA [(A Conservation Commission 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O4'ALAi‘t.' Fax: 907.276.7542 www.aogcc.alaska.gov Matthew Summers Production Engineer BP Exploration(Alaska), Inc. P.O Box 196612 sCON 0 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-07A Permit to Drill Number: 204-043 Sundry Number: 318-151 Dear Mr. Summers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 5 day of April, 2018. RBDMS," APR 0 6 2018 STATE OF ALASKA E E , ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS APD f1 & )fl 20 MC 25.280 18 1. Type of Request: Abandon 0 Plug Perforations RI ` Fracture Stimulate 0 Repair Well 0 Opeqr iedtei g Suspend 0 Perforate 0 Other Stimulate Q• Pull Tubing 0 Change App Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Set CIBP-Acid Stimul m• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-043 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service 0- 6. API Number: 50-029-20220-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I! PBU 03-07A 9. Property, esignation(Lease Number): 10. Field/Pools: ., Z a 5</, ADL,9203328331 • ,r�.t-- C."-Zv7v / .' PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13841 • 9052 , 11735 9054 11735.12650.1302 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 30-110 30-110 1530 520 Surface 2668 13-3/8" 30-2694 30-2694 5380 2670 Intermediate 7944 9-5/8" 28-7968 28-6752 8150/6870 5080/4760 Liner 2841 7" 7795-10276 6633-8705 7240 5410 Liner 3712 4-1/2" 10128-13840 ( 8573-9052 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11400-13750 9051-9049 4-1/2"12.6# L-80 26-10130 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 10073, 8524 4-1/2"MCX l-SSV 2190, 2190 12.Attachments: Proposal Summary 0 Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service I 1 14.Estimated Date for Commencing Operations: 5/1/2018 15. Well Status after proposed work: � Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG Iv7 ' GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Summers,Matthew be deviated from without prior written approval. Contact Email: Matthew.Summers@bp.com Authorized Name: Summers,Matthew Contact Phone: +1 9075645066 Authorized Title: Production Engineer Authorized Signature: '"6 Date: V13// COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: y8- 151 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No ted Subsequent Form Required: `19 r'O 4 APPROVED BYTHE Approved by: flaiLY:C". COMMISSIONER COMMISSION Date: '5 lit Vri--4-6571(e Sc,J\.40 x. ORI G�NA APR It 6 2018 Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Approvals (10-403) April 3, 2018 To Whom it May Concern: Attached please find the Sundry Application for Plug Perforations and Acid Stimulation (contingent) for well PBU 03-07A (PTD #204-043) Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 Application Proposal Summary Well Bore Schematic BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 S S 10-403 Sundry Application for Well PBU 03-07A CTD#204-043 Expected Start Date: May 1, 2018 Current condition of well: WAG Injection Well, Operable, Injecting: Gas Injection Rate: 17133 Mscf/Day Injection Pressure: 3086 psi Shut-in Wellhead Pressure: 2700 psi Reservoir pressure: 3259 psi Well objective(s): To move to next MI bulb location in 03-07Ai through plug and perf and a contingent acid treatment. In order to develop opportunities to go back to previous MI locations mill current CIBP and ones below if possible. Proposed program: 1. Pull MCX. 2. D&T to deviation with drift for 3.56" CIBP. 3. With choke closed, attempt to mill top 3 CIBPs using junk mill. Push to plug at 13,400' MD. 4. RIH to 11,300' with BHA including drift for 3.56" CIBP and GR/CCL. Flag pipe near 11,250' MD. 5. Set CIBP at 11,250' MD correlated to SLB jewelry log dated 4/26/04. 6. Adperf per perforating form using CIBP for depth control. 7. Injectivity test with non-freezable fluid. If injectivity is less than 2 BPM at 2000 psi contingent acid stim per attached program. 8. Set MCX (sized 20 MM/d) BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 0 • 10-403 Sundry Application for Well PBU 03-07A CTD#204-043 Annotated Reference Log (CIBP): JEWELRYlPDC I_'7<i Ida Schlumberger 26 , ; ttNgg g2 roKE FINAL i O 8 r I_ompOt4 BPExp4>r at lon<Alaska),Inc, 1/!1! x Well DS 3-07A � A L eto Prudhoe tray .v 0 Horougn North Slope State Alaska j ;7414 4 `z •r 14,0,43 SCC 0.IVO 100 110f Me otnw 3snoces p s ea-4xe OK.Of C.It Or,OR C01 +n4 API 030433 SO 024232A-01 i 574<i P4rmsa0.M Oatew Mt EMVYbn R Ft. e 8 AES C1 y °e 0.es°reo/rnn or 555 rt 13Mw Days O.r ZOO f1 Vv )rillry Mna.(ran Or O.L T4 rt3 O 9.13 ( 4r� Ie :i R is h < °4 .--- — — 1 R '� � a Z ..f. ll _ IIS a, me.. s .., .. &ijIx g < iill • 2 i ; 1!.1t ff... 7 _ e.r I .y. 1.• I n.M < riLf I glz ,,, _ gids r ;1 ; 15 —__ I E l i a 1 :q =3.. �.:*,� 1.......- — ; i 11 rI1# h w._•y_ 3 es– t H L L_ i + I # { i - i — s t F — 030 t- itjj t I . atst nrn set CIDP.11 250 At } _I.- I $� t _—__ . f Y + RI naa. ow MI -1 is 4._ BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 S • 10-403 Sundry Application for Well PBU 03-07A CTD#204-043 CTU Acidize — Contingent Design Details Wellbore Volume 171 bbls to PBTD of 11,250' MD, 4.5" Monobore Volume Across Perfs 77 gallons — 120' in 4.5" liner Acid Design 12% HCI Acid @ 25 gpf— 72 bbls 9:1 Mud Acid @ 25 gpf— 72 bbls Pres Tres 3259 psi & 173°F @ 8800' Datum SS Target Treatment Intervals We are targeting 120' of perforated interval. 10,890'-11,010' MD CTU Acidize — Contingent 1. MU BHA including JSN for acid job. 2. RIH while loading well down backside then CT with 210 bbls of 3% NH4CI. 3. Injectivity should be low enough (pre-acid) where keeping positive WHP is easily achievable. 4. Pump the following fluids per schedule below. o Reciprocate nozzle across perforated interval during treatment. Try to maintain WHP of 2000 psi during acidizing by increasing rate as injectivity increases. Can go up to 3000 psi if diversion locks up formation. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 _AlTREE= 6-318"CALICO e WELLHEAD= FMC GEN 1 03-07A SAFETY Spm WHEN ON: H2S S READ NGS REQUIRES ERAGE 1 25 G SSSV ACTUATOR= BAKER N 11AL KB Q 61' I WHEN ON MI-- WELL ANGLE>70°@ 10766' BF E EV_ "'"`4-1/2"CHROME NIPPLES"" KOP= 7968' 9 Max Angle= 93'@ 11811' 20"GOND, 107' , 21 90' 4-1/2" HES X NIP, ID= 3.813" Datum MD= 10456' 94#,H-40 Datum TVD 8800'SS D=19.124" - - 2325' L9-518"FOC —\ 2446' 9-5/8"FOC 13-3/8"CSG,72#,MN-80 BUTT,D=12.347" — 2699' -A , -----k 7798' 9-5/8"X 7"BKR ZXP LW w/TEBACK TOP OF 7"LNR — 7798' SLV,ID=7.510" 7816' 9-5/8"X 7"BKR LNR HGR,D=9.625" Minimum ID = 3.725" @ 10117' 4-1/2" HES XN NIPPLE 9-5/8"CSG,47#,MN-80 BTC,D=8.681" 7968' MLLOUT WINDOW(03-07A)7968'-7984' ' 10052' 4-1/2" HES X NIP, ID= 3.813" 10073' 7"X 4-1/2"BKR S-3 P52M PKR,ID=3.875" 10097' 4-1/2'HES X NIP, ID= 3.813" 10117' 4-1/2" HES XN NIP, ID= 3.725" TOP OF 4-1/2"LNR 10127' 4-1/2"TBG, 12.6#,L-80 TC11,.0152 bpf,D=3.958" 10130' --.......\\ 10127' 19-5/8"X 7'BKR TEBACK SLV,D=5.25" LI 7"LNR 26#,L-80 BTC-M,.0383 bpf,ID=6.276" 10279' I g, 10130' 4-112"WLEG,D=3.958 I 10136' 7"X 5'BKR ZXP LIP,D=4.420" \A , 10141' 7"X5"BKR LNR HGR,D=4.410" FERFORAT1ON SUMMARY I 10148' 7"X 4-1l2"XO,D=3.980" REF LOG: ANGLE AT TOP PEW: 89"@ 11400' Note;Refer to Production DB for historical perf data 11735' 4-1/2"WFD CEP(10/14/14) SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 11400-11500 0 10/15/14I 2-7/8" 6 12100-12130 C 06/23/13 12650' 4-1/2"CIBP(06/21/13) 2-7/8" 6 12130-12155 C 06/22/13 ' 2-7/8" 6 12150-12175 C 06/21/13 2-7/8" 6 12157-12162 C 06/23/13 j 13025' 4-1/2'OBP(02/12/10) 2-7/8" 6 12175-12200 C 06/21/13 ' 3-3/8" 6 12750-12770 C 02/16/10 3-3/8" 6 12770-12830 C 02/13/10 13490' 4 1/2"CBP(00/02/06) 2-7/8" 6 13200-13300 C 09/02/06 ' 2-7/8" 6 13650-13750 C 04/27/04 .....f. 13752' FBTD 4-1/2"LNR,12.6#,L-80 13T-M,.0152 bpf,D=3.958" 13840' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/20/76 ORIGINAL COMPLETION 10/15/14 SRCY PJC SET CEP/ADFERF WELL: 03-07A 1991 RWO 11/17/14 AND CLEANED UPWBSPERTALLIES PERMIT No:42040430 04/06/04 KAK RIG SIDETRACK(03-07A) 03/17/16 JMf+NJMD SET FLO THRU SUB w/GAUGES(3/15/16) API No: 50-029-20220-01 02/09/11 ME/JM) ADDED SSSV SAFETY NOTE 04/19/16 JTG/JMD PULLED XN LOCK w/GAUGES(4/18/16) SEC11,T10N,R15E, 1316'FSL&812'FWL 01/10/12 TM14J1VD ADDED EQS SAFETY NOTE 07/12/13 DBMYJMD SET CIBP/ADFERF(06/21-23/13) BP Exploration(Alaska) • • OF 74, 0+\���I//y� s� THE STATE Alaska Oil and Gas f Conservation Commission o ALASKA 333 West Seventh Avenue i GOVT Anchorage, Alaska 99501-3572 *M� GOVERNOR BILL WALKER g -' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Matthew Summers Production Engineer BP Exploration(Alaska), Inc. P.O Box 196612 SCAMMEC Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Oil Pool, PBU 03-07A Permit to Drill Number: 204-043 Sundry Number: 318-126 Dear Mr. Summers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (CO2-9r1 Hollis S. French Chair DATED this 5 day of April, 2018. RBDMS-3u APR 0 6 2018 S E F SSKA OIL AND GAS CONS RATION COMMISSI• RECEIVED APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 fq� �(y- tA� 1. Type of Request: Abandon 0 Plug Perforations p• Fracture Stimulate 0 Repair Well 0 M°''pe7al r?s'.5162I l do ❑ Suspend 0 Perforate ii r Other Stimulate 0 Pull Tubing 0 C , Ellif • Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Othe 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-043 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service El• 6. API Number: 50-029-20220-01-00 • 7. If perforating: 341E . 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No El PBU 03-07A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028331• PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13841 • 9052 • 11735 9054 111None 13025,112650,3490 Casing Length Size MD TVD Burst Collapse Structural Conductor 82 20" 27-109 27-109 1530 520 Surface 2668 13-3/8" 26-2694 26-2694 5380 2670 Intermediate 7944 9-5/8" 24-7968 24-6752 8150/6870 5080/4760 Liner 2481 7" 7798-10279 8635-8708 7240 5410 Liner 3713 4-1/2" 10127-13840 8572-9052 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11400-13750 8811-9049 4-1/2"12.6# L-80 21-10130 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 10073/8524 4-1/2"HESMCXM-12 2190/2190 12.Attachments: Proposal Summary 0 Wellbore Schematic 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service B • 14.Estimated Date for Commencing Operations: April 15,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG Il • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Summers,Matthew be deviated from without prior written approval. Contact Email: Matthew.Summers@bp.com Authorized Name: Summers,Matthew Contact Phone: +1 9075645066 Authorized Title: Production Engineer Authorized Signature: A___..,..„... .-----------____ Date: Vas.3//46 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: I ,�(/1 to Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance,❑ 3 ti• l (/ Other: Post Initial Injection MIT Req'd? Yes 0 No 1< Spacing Exception Required? Yes 0 NoI SSubsequent Form Required: /0 — 4 0 4- \ APPROVED BYTHE 'LI1� )t Approved by: LJ COMMISSIONER COMMISSION Date: t ) V•7`L 4/5/18 `1 J ,gy p � �� ORIGINAL �.29,g 7RBDMS APR 0 6 2018 Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: 03-07A Well Type: WAG Injection Well API Number: 50-029-20220-01 Well Activity Conventional 4 Classification: Activity Description: Plug&Perf Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, 100 bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory N/A requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Matt Summers Contact numbers: (907)564-5066 (907)952-1682 Well Intervention Engineer: Todd Sidoti Contact numbers: (907)564-5113 (907)632-4113 Lead Engineer: Bernhard Stechauner Contact numbers: (907)564-4594 (907)360-7485 Date Created: February 21,2018 Revisions(date,who,what changed): Current Well Status Information Gas Injection FTP or Injection Oil Rate Water Inj GOR Gas Lift Rate Date Pressure (bopd) Rate(bwpd) Rate (scf/stbo) Choke Setting (Mscf/Day) (Mscf/Day) (psi) 2/10/2018 17,133 3,086 Current Status: Operable Flowing Inclination>70°at Depth(ft) 10,779' MD Recent H2S (date, ppm) est Maximum Deviation(Angle and 11,813'MD Depth) Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 20° 10,904'MD Reservoir pressure(date, 10/23/2014 3,259 psi Minimum ID and Depth 3.725" 10,117'MD psig) Reservoir Temp, F 173° F Shut-in Wellhead Pressure 2,700 psi Known mech. integrity None problems(specifics) Last downhole operation(date,operation) 5/27/2017 Set MCX Most recent TD tag(date,depth, 5/27/2017 2,190'MD 3.805"Gauge ring toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? N/A Comments,well history, Job Purpose: background information, To move to next MI bulb location in 03-07Ai through plug and perf. In order to develop opportunities to go etc: back to previous MI locations mill current CIBP and ones below if possible. History: Well 3-07A is a MIST injector sidetracked in 2004 accessing the 31 P.The 5th MI bulb was added in May 2014 with the well most recently injecting MI since July 2017.A caliper run on May 27,2017 prior to setting the MCX indicated the tubing is in very good condition. There have been historic issues with injectivity of the MI bulbs for almost all stages in 03-07Ai, most recently 4&5. Stage 4 in 2013(12,100'-12,162' MD)took very little PWI following its MI bulb and Stage 5 in 2014(11,400-500'MD)was shot with NOVA guns with SBG treatments and High Pressure Breakdowns being performed to increase PWI injectivity in 2015. Stages 2, 3,&4 were acidized to increase injectivity following perforating(2006&10 respectively). Due to historic views on MI Injection CIBPs have been"stacked"in this well. Recent review has indicated it may be worthwhile to go back to original stages if possible or inject MI into multiple bulbs at once. Due to this the SOR requests that the first CIBP(11,735' MD)be milled and an attempt be made to mill the 2nd& 3rd to reopen previous bulb locations for possible future use. i Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. 3.Does the planned equipment to be installed in the well meet the requirements of the GWO Well Equipment Group Practice,GP 100220(AKA 10-50),by either being documented as Legacy Equipment or having the required design assurance work completed?https://gwo.bpglobal.com/sites/gwo2/GlobalLibrary/100220.pdf Suspected Well Problem: Move to next MI bulb Specific Intervention or Well Objectives: 1 Set CIBP&add perfs uphole 2 Mill as many current CIBPs as possible 3 Key risks,critical issues: Mitigation plan: Attempt to mill with clear stop flag(36 hrs max). If WSL has evidence that no progress is being made before 1 Milling multiple stacked CIBPs this contact PE. It is recognized that this will be difficult&its likely we may only mill the 1st CIBP& possibly the 2nd. 2 High Pressure Gas Exercise due caution and follow proper safety procedures 3 Summary Service Line Activity Step# 1 SL Pull MCX. D&T for CT 2 CT Mill CIBPs(36 hrs max). D&T with GR/CCL. Set CIBP @ 11,250'MD. Add perfs per form. Injectivity Test. Contingtent Acid Stim. 3 SL Set MCX(sized 20 MM/d) Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 SL 1. Pull MCX. 2. D&T to deviation with drift for 3.56"CIBP. 1.With choke closed, attempt to mill top 3 CIBPs using junk mill. Push to plug at 13,400'MD. 2. RIH to 11,300'with BHA incluing drift for 3.56"CIBP and GR/CCL. Flag pipe near 11,250'MD. 2 CT 3. Set CIBP at 11,250'MD correlated to SLB jewelry log dated 4/26/04. 4.Adperf per perforating form using CIBP for depth control. 5. Injectivity test with non-freezable fluid. If injectivity is less than 2 BPM at 2000 psi contingent acid stim per attached program. 3 SL Set MCX(sized 20 MM/d) Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: 20 BWPD: Expected Production Rates: FTP(psi): 3300 Choke setting: PI(bfpd/psi dp) Post job POP instructions: Return to DSO. POI when appropriate Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc . i • C H2O Injector Mini►og 1111 Techlog `'- „, DS-03 Minlios Update 2017 Well: 03-07AI Author ILa,u,.Larson f-.J« 1:4000 Dat.:2/7(2017 _`�.. 040_110.0 D. ,ver Prudhoe Bey t ,, .,,,% Oramier covvoo.earn SESTA* ®ESTASiriAL it 0i o AN 14+42 PE Info _._ tvass tela ++FSt.ROO OUT) mail a IaIaI.TVO�Sf �iE4'P.ROtE� 17646 soo 1.400o 1441:X)f ]C 1050 it N50 0.2 OfitillNit 200- '4 - 815 = MO)t _ ...., 11944 - u600- 1:1111,A - tom/ T 8963 ayes i t eyes * ,r/=) Add Peas ` ,.- -11o00.s _ .._ _..._ _ ., ' IIII. Set CIBP 11,250'MD r 11994 C • a. .. 1199S , susoa x a99S 11400 t j4 I r y, +.+ -1 JS00- - 6 T 4`, :6994 r ► } � . 4% 8995 S, xr e,"` � ., -11600- fC 114 x, tr _- A m p ams MIA 8"CALICO III 1a1+ELLFEAt �31FMC GEN 1 03-07A 3_0 7A SAFEOITES: H2S READINGS AVERAGE 125 ACTUATOR BAKER / ppm WHEN ON MI--WELL REQUIRES A SSSV INITIAL KB.El 61' WHEN ON MI-- WELL ANGLE>70°@ 10766' I BF.BEV= J ****4-1/2"CHROME HIPPIES**** KOP= 7968' L/ Max Angle= 93°@ 11811' 20"COND, 107' I 2190' 4-1/2" HES X NIP, ID= 3.813" Datum kV= 10456' 94#,H-40 DatumTVG= 8800'SS D=19.124" it...1 2325' 9-5/8"FOC MINIM 2446' I 9-5/8"FOC 13-318"CSG,72#,MN-80 BUTT,D=12.347" H 2699' -, 7798' 9-5/8"X 7"BKR ZXP LTP w/TEBACK TOP OF 7"LNR 7798' SLV,D=7.510" 7816' 9-5/8"X 7"BKR LNR HGR,ID=9.625" Minimum ID = 3.725" @ 10117' 4-1/2" HES XN NIPPLE 9-5/8"CSG,47#,MIN-80 BTC,ID=8.681" H 7968' F-- MLLOUT WINDOW(03-07A)7968'-7984' ' 10052' 4-1/2'HES X NIP, ID=3.813" 11 10073' 7"X 4-1/2"BKR S-3 PERM PKR,ID=3.875" 10097' 4-1/2"HES X NIP, ID= 3.813" ' 10117' 4-1/2" HES XN NIP, ID= 3.725" TOP OF 4-1/2"LNR 10127' 4-1/2"TBG,12.6#,L-80 TC11,.0152 bpf,D=3.958" 10130' 10127' _1 {9-5/8"X 7"BKR TIEBACK SLV,D=525" 1 7"LNR,26#,L-80 BTC-M,.0383 bpf,ID=6.276" 10279' j 10130' 4-112"WLEG,D=3.958" 10136' 7"X 5"BKR ZXP LTP,ID=4.420" 1 10141' 7"X 5"BKR LNR HGR,ID=4.410" F7 2FORATION SIJMAARY NA ' 10148' 7"X 4-1/2"XO,D=3.980" REF LOG: ANGLE AT TOP PERF: 890 @ 11400' -~.a a Note:Refer to A'oduction DB for historical perf data 11735' 4-1/2"WFD CUP(10/14/14) SIZE SFF INTERVAL Opn/Sqz SHOT SOZ 2-7/8" 6 11400-11500 0 10/15/14 I 2-7/8" 6 12100-12130 C 06/23/13 12650' 4-1/2"CIBP(06/21/13) 2-7/8" 6 12130-12155 C 06/22/13 ' 2-7/8" 6 12150-12175 C 06/21/13 2-7/8" 6 12157-12162 C 06/23/13 13025' 4-1/2"CIBP(02/12/10) 2-7/8" 6 12175-12200 C 06/21/13 ' 3-3/8" 6 12750-12770 C 02/16/10 3-3/8" 6 12770-12830 C 02/13/10 13490' 4-1/2"GBP(09/02106) 2-7/8" 6 13200-13300 C 09/02/06 ' 2-7/8" 6 13650-13750 C 04/27/04 ;7� 13752' PBTD 4-1/2"LNR,12.6#,L-80 BT-M,.0152 bpf,D=3.958" 13840' DATE REV BY COMMENTS DATE REV BY COMVENTS PRLDHOE BAY UNIT 10/20/76 ORIGINAL COMPLETION 10/15/14 SRLY PJC SET CEP ADPERF WELL 03-07A 1991 RWO 11/17/14 MUD CLEANED UP WBS PER TALLIES PE MT No:"`2040430 04/06/04 KAK RIG SIDETRACK(03-07A) 03/17/16 JMWJM)SET FLO TI-IRU SUB w/GAUGES(3/15/16) AR No: 50-029-20220-01 02/09/11 M3/JM) ADDED SSSV SAFETY NOTE 04/19/16 JTG/JMY PULLED XN LOCK w/GAUGES(4/18/16) SEC11,T1 ON,R15E,1316'FSL&812'FWL 01/10/12 TWWJM)ADDED IQS SAFETY NOTE 07/12/13 DBMJMD SET CIBP/ADPERF(06/21-23/13) BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: Friday,June 03,2016 P.I.Supervisor (.1-- -e4 '(3/l 4a SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 03-07A FROM: Jeff Jones PRUDHOE BAY UNIT 03-07A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry leg-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03-07A API Well Number 50-029-20220-01-00 Inspector Name: Jeff Jones Permit Number: 204-043-0 Inspection Date: 4/23/2016 Insp Num: mitJJ160526094535 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03-07A Type Inj W TVD 8524 ' Tubing 1288 ' 1282 - 1298 1284 PTD 2040430 Type Test SPT Test psi 2131 IA 602 2502 ' 2479 2470 Interval 4YRTST P/F P '' OA 7 5 - 6 - 4 - Notes: 1 well inspected,no exceptions noted. salgQED DEC 2 9 NIS Friday,June 03,2016 Page 1 of 1 XHVZE Image Project Well History File Cover Page 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 1+- 0 ~3 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: -!/-D- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: & I~/o(p Organizing (done) D Two-sided '" II 111111" 111111 RESCAN DIGITAL DATA ~skettes, No. I D Other, NolType: D Color Items: D Greyscale Items: D Poor Quality Originals: D Other: NOTES: BY: ~ Date(4~ /00 Date to! ~ /0(, cÀ Project Proofing BY: ~ Scanning Preparation BY: Date: Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Maria Date: Scanning is complete at this point unless rescanning is required. D Rescan Needed 11111111111 II 111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: o Other:: ·ffiP III 1111111111111111 m£ 151 151 11/1111111111111111 NO YES 151 VV\ P NO 151 11111111111I11 1/11I ReScanned BY: Maria Date: 151 Comments about this file: 11/ 11111111 1111111I Quality Checked '" 11111111I 111111I 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA • RECEIVED SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL. 19 2013 1.Operations Abandon Lf Repair Well U Plug Perforations U Perforate U Other U AOGCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other SI Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Developments Exploratory O. 204-043-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service 111 6.API Number: • Anchorage,AK 99519-6612 50-029-20220-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028331 PBU 03-07A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 13841 feet • Plugs measured See Attachment feet true vertical 9051.62 feet Junk measured None feet Effective Depth measured 9521 feet Packer measured See Attachment feet true vertical 8055.75 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20"101.1#H-40 28-110 28-110 1650 650 Surface 2667 13-3/8"72#MN-80 27-2694 27-2693.96 5380 2670 Intermediate None None None None None None Production 7943 9-5/8"47#MN-80 25-7968 25-6751.75 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet r pHHEf NOV 0 6 UI Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"MCX I-SSV 2190 2189.97 SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12100'-12200' Treatment descriptions including volumes used and final pressure: 78 BBL 12%HCL,73 BBL MUD ACID,430 BBL NH4CL W/0.2%F103,696 GAL N2 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratori❑ Development❑ Service 0• Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas U WDSPIU GSTOR ❑ WINJ ❑ WAG 0 • GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-292 Contact Nita Summerhays Email Nita.Summerhays(CDBP.com Printed Name Nita Summerhay. Title Petrotechnical Data Technician - •Sign- _ .,. Alloo.-_ Phone 564-4035 Date 7/19/2013 i \IIF RBDMS JUL 2 3 2O "(66 I Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028331 -***WELL INJEC I ING ON ARRIVAL***(profile mod) DRIFT TO MCX W/3.805" G-RING @ 2,172' SLM PULLED 4 1/2" MCX(ser# NM-08) FROM 2,172' SLM/2,190' MD --CURRENTLY RIH W/4 1/2"XN LOCATOR, 2.50" S.BAILER 6/15/2013 ***CONT WSR ON 6/16/13*** ***CONT WSR FROM 6/15/13***(profile modification) TAGGED XN NIPPLE W/XN LOCATOR @ 10,101' SLM/ 10,117' MD (16' CORRECTION). STOP DUE TO DEVIATION @ 10,680' SLM / 10,876' MD (no issues) DRIFTED TO DEVIATION W/20' x 2 7/8" DUMMY GUNS, 3.62" SWAGE @ 10,868' SLM/ 10,884' MD (no issues) ***WELL S/I UPON DEPARTURE, DSO WALK THROUGH UPON 6/16/2013 DEPARTURE*** CTU #3 - 1.75" Coil Job Objective: set CIBP, add perfs and con. acid Move in, RU, and performed weekly BoP test, MU/RIH w/2 7/8" PDS carrier w/3.66" drift nozzle. Tag shallow @ 12787' (ctm up). Jet on tag, solid. Log from 12787' to 9950' w/coil flag @ 12600' @ 40 fpm. POOH in progress. 6/20/2013 Continued on 06/21/13 WSR. CTU #3- 1.75" Coil Job Objective: set CIBP, add perfs and con. acid POOH from logging/drift pass. Make depth shift of+10'. Corrected PBTD is 12792'. MU/RIH w/4.5"WOT CIBP. Correct depth at flag. Set 4.5" CIBP @ 12650' (top of plug). POOH. MU/RIH w/gun#1: 25' of 6 spf. Correct at flag, check depth at plug. Shoot interval 12175'- 12200'. POOH. MU/RIH w/gun#2: 25' of 6 spf. Correct at flag. Tag plug 12.4' shallow, use flag to shoot interval 12150'-12175'. POOH. In 6/21/2013 progress. Continued on 06/22/13 WSR. CTU #3 - 1.75" Coil Job Objective: set CIBP, add perfs and con. acid POOH w/gun#2. Rehead. MU/RIH w/ PDS 2 7/8" carrier and 3.5" drift nozzle for 2nd coil flag. Log data was good, had -5.5 ft depth correction. found the plu on depth 12650 ft and the perf interval (12162-12208). MU/RIH w/third perf run. perforated interval (12130-12155). POOH. MU/RIH w/Gun#4: 30' of 2 7/8" at 6 spf. Continued on 06/23/13 WSR. 6/22/2013 CTU#3 - 1.75" Coil Job Objective: set CIBP, add perfs and con. acid RIH w/gun#4, 30' of 2 7/8"6 spf. Tag plug and correct depth. Shoot interval 12100'-12130'. Pull up to 12000', perform injectivity test down backside w/ KCL. Final injectivity was 0.7 bpm/1290 psi WHP. POOH PU gun#5, 5' of 2 7/8" 6 spf, RIH, Tag plug and correct depth. Shoot interval 12157'-12162'. POOH, cut 20 ft of coil, changed the pack-offs and inspected the injector chains, PU 2.65" nozzle w/two 2" stingers and RIH. Re-check injectivity, same 0.7 bpm/1290 psi WHP. RIH, tag CIBP @ 12650', correct depth to plug. Pull up to 11600' and circ wellbore to 6/23/2013 diesel. Circ in progress. Continued on 06/24/13 WSR • • Daily Report of Well Operations ADL0028331 CTU#3- 1.75" Coil Job Objective: set CIBP, add perfs and con. acid Circ wellbore to diesel from 11600'. Prep for acid job. performed a 15 stage HCI/Mud acid job with total 78 bbl of 12% HCI + 73 bbl of mud acid &two stages of nitrified diverters (4 bbls each). RIH and tagged the plug @ 12650 and displaced the rat hole w/NH4CI. POOH while displacing the hole w/ 1% KCI. At surface perform SRT: 0.7 bpm @ 958 WHP. 1.0 @ 1290 WHP. FP wellbore to 2500'w/water/meth. Job complete. 6/24/2013 RDMO. Progress********** FLUIDS PUMPED BBLS 143 DIESEL 708 1%KCL 290 FRESH WATER 78 12%HCL 73 MUD ACID 430 NH4CL W/0.2%F103 31 60/40 METH 1753 TOTAL FLUIDS PUMPED GAL 696 N2 696 TOTAL • Perforation Attachment ADL0028331 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 03-07A 6/23/2013 APF 12100 12130 9048.24 9048.63 03-07A 6/22/2013 APF 12130 12150 9048.63 9049.04 03-07A 6/22/2013 APF 12150 12155 9049.04 9049.14 03-07A 6/23/2013 APF 12155 12157 9049.14 9049.18 03-07A 6/23/2013 APF 12157 12162 9049.18 9049.27 03-07A 6/23/2013 APF 12162 12175 9049.27 9049.46 03-07A 6/21/2013 APF 12175 12200 9049.46 9049.68 • 03-07A 6/21/2013 BPS 12750 12770 9052.32 9051.68 03-07A 6/21/2013 BPS _ 12770 12830 9051.68 9049.05 03-07A 6/21/2013 BPS 12830 12850 9049.05 9048.24 03-07A 6/21/2013 BPS 13200 13250 9046.36 9047 03-07A 6/21/2013 BPS 13250 13300 9047 9047.29 03-07A 6/21/2013 BPS 13650 13725 9047.86 9048.34 03-07A 6/21/2013 BPS 13725 13750 9048.34 9048.85 BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Casing / Tubing Attachment ADL0028331 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20" 101.1# H-40 28 - 110 28 110 1650 650 LINER 2481 7"26# L-80 7798 - 10279 6635.32 - 8707.7 7240 5410 LINER 21 7"26# L-80 10127 - 10148 8572.31 - 8591 7240 5410 LINER 3692 4-1/2" 12.6# L-80 10148 - 13840 8591 - 9051.6 8430 7500 PRODUCTION 7943 9-5/8"47#MN-80 25 - 7968 25 - 6751.75 6870 4760 SURFACE 2667 13-3/8" 72# MN-80 27 - 2694 27 - 2693.96 5380 2670 TUBING 4 7"26# L-80 24 - 28 24 - 28 7240 5410 • TUBING 10102 4-1/2" 12.6# L-80 28 - 10130 28 - 8574.98 8430 7500 • 0 • Packers and SSV's Attachment ADL0028331 SW Name Type MD TVD Depscription 03-07A SSSV 2190 _ 2134.47 4-1/2" MCX I-SSV 03-07A PACKER 7810 _ 6588.08 7" Baker ZXP Top Packer 03-07A PACKER 10073 8468.9 4-1/2" Baker S-3 Perm Packer 03-07A PACKER 10135 8523.93 5" Baker ZXP Top Packer • • 03-07A 204-043-0 Plugs Attachement SW Name Date MD Description 03-07A 6/21/2013 12650 03-07A 2/12/2010 13025 03-07A 9/2/2006 13490 -T •= 6-3/8" GR'l 1 _ S14P�'TY NOTES: H2S READINGS AVERAGE 125 VWI3LHEAD= FMC GEN 1 ACTUATOR= BAKER 03-07A WHEN ON MI.WELL ANGLE 70° 0766'. URAL KB.El 61' BF.BEV= - KOP= 7968' Max Ancje= 93°@ 11811' Datum NO= 10456' I 1 1 2190' -- 4-112"HES X NP,D=3.813' I DatumTVD= 8800'SS um mm! 2325' 9-5/8"FOC MI 2446' —I 9-518"FOC 13-3/8"CSG,72#,M44-80,D=12.347' f 2699' f A ■ Minimum ID =3.725" @ 10117' 4-1/2" HES XN NIPPLE Z 2i 7810' I 9-5/8"X 7"BKR ZXP LNR TOP PKR PULLOUT WIDOW 7968'-7984' 10052' 4-1/2"HES X NP,D=3.813" 9-5/8'CSG,47#,AW-80,D=8.681" 7968' 10073' I-1 7'X 4-1/2'BKR S-3 PERM PKR ' 10097' 4-112"HES X NP,D=3.813' I , 1011T I 4-112"HESXNNP,D=3.725" 10130' I 4-1/2"WLEG,D=3.958" :; 4-112"TBG, 126#,L-80,.0152 bpi,D=3.958' H >, 10135' I-7'X5"BKR ZXP LNR TOP PKR 7"LNR 26#,L-80, 0383 bpf,D=6276" I—{ 10279' V: 101481J-J 7"X 5'XO ` D=3.980' PERFORATION SUMMARY REF LOG: 4a, ANGLE AT TOP PBZF: 90°@ 12100' Note:Refer to Production DB for historical perf data 14 112 CBP(06111113) H 12650' �/ SIZE SPF INTERVAL Opn/.5q7 SHOT SOZ 2-7/8* 6 12100 12130 0 06/23/13 $i ` 2-7/8" 6 12130-12155 0 06/22/13 4-1/2'CBP(02/12/10) 13025' A, ■2-7/8' 6 12150-12175 0 06/21/13 r 2-7/8" 6 12157-12162 0 06/23/13 COP(09/02/06)I I 13490, I 3�rs�► 2-7/8" 6 12175-12200 0 06/21/13 3-3/8" 6 12750-12770 C 02/16/10 PBTD 13751' 3-3/8' 6 12770-12830 C 02/13/10 2-7/8" 6 13200-13300 C 09/02/06 I 4-1/2'LNR, 12.6#,L-80,1)152 bpf,D=3.958' I 13840' 2-7/8" 6 13650-13750 C 04/27/04 DATE REV BY CONSENTS DATE REV BY COMBOS PRUDHOE BAY MT 10/20/76 ORIGINAL COMPLETION 03/18/10 JKD/SV SET(MP/ADFBZF(02/13/10) WELL: 03-07A 04/06/04 KAK RIG SIDETRACK(03-07A) 02/09/11 M3/JIVE) ADDED SSSV SAFETY NOTE PEEWIT No:"2040430 04/27/04 McN/KAK PERES 01/10/12 T NUJ D ADDED H2S SAFETY NOTE AR No: 50-029-20220-01 09/02/06 GLMPAG SET CBP @ 13490;ADPERF 07/12/13 DBMJMD SET CIBP/ADFERF(06/21-23/13) SE-C11,T10N,R15E,1316'FSL&812'FWL 11/10/06 ATDVTLH PERF BOX CORRECTION 07/21/08 RIWSV TREE GO(07/03/08) BP Exploration(Alaska) • • o[F atia[KKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Higino Dos Santos Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 c).4,73 Anchorage, AK 99519 -6612 a Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03 -07A Sundry Number: 312 -292 Dear Mr. Santos: 51<,A414WFA, Ai; ? ` ZU?j Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy r. Foerster Chair DATED this j! day of August, 2012. Encl. R S STATE OF ALASKA • ttiv I� ALASKA OIL AND GAS CONSERVATION COMMISSION 1 APPLICATION FOR SUNDRY APPROVALS )) 7 / z)) Z 20 MC 25.280 rs?.1•I AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ri Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate a - Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to bill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 204 -043 -0 ` 3. Address: Stratigraphic ❑ Service in 6. API Number: P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 20220 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 PBU 03 -07A ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0028331 ' PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13841 9052 - 9521 8056 See Attachment None Casing Length Size MD TVD Burst Collapse Structural Conductor 82 20" 101.1# H -40 28 - 110 28 - 110 Surface 2667 13 -3/8" 72# MN -80 27 - 2694 27 - 2693.96 5380 2670 Intermediate None None None None None None Production 7943 9 -5/8" 47# MN -80 25 - 7968 25 - 6751.75 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths 4 -1/2" MCX I -SSV 2190', 2189.97' 12. Attachments: Description Summary of Proposal © 13. Well Class after proposed work: Detailed Operations Program (l BOP Sketch n Exploratory n Development ❑ Service n 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ED Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ L Igi iv WAG [ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Prepared by Garry Catron 564 -4424 Printed Name Higino Dos San k 564 -4342 Title Production Engineer Signature �i/' Phone Date fi r• si 07- Z-6-12_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 12. ' 20 2... Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: l 01 APPROVED BY Approved by: / , �� ' - ✓ /--t.------ COMMISSIONER THE COMMISSION Date: U Q 2- / Z Form 1040 '' 7 ∎ M, 0 AUG 0 3 2012 f'1.1 L ORIGINAL .,Sybglit ( in Duplicate iv w : • • Perforation Attachment ADL0028331 Well Date Perf Code MD Top MD Base TVD Top TVD Base 03 -07A 2/16/10 APF 12750 12770 9052 9052 03 -07A 2/13/10 APF 12770 12830 9052 9049 03 -07A 2/12/10 APF 12830 12850 9049 9048 03 -07A 2/12/10 BPS 13200 13250 9046 9047 03 -07A 2/12/10 BPS 13250 13300 9047 9047 03 -07A 2/12/10 BPS 13650 13725 9048 9048 03 -07A 2/12/10 BPS 13725 13750 9048 9049 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0028331 Well Facility Type MD Top Description TVD Top 03 -07A SSSV 2190 4 -1/2" MCX I -SSV 2190 03 -07A PACKER 7810 7" Baker ZXP Top Packer 6644 03 -07A PACKER 10073 4 -1/2" Baker S -3 Perm Packer 8524 03 -07A PACKER 10135 5" Baker ZXP Top Packer 8579 I II • • Casing Summary ADL0028331 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse CONDUCTOR 82 20" 101.1# H -40 28 110 28 110 1650 650 LINER 21 7" 26# L -80 10127 10148 8572 8591 7240 5410 LINER 3692 4 -1/2" 12.6# L -80 10148 13840 8591 9052 8430 7500 LINER 2481 7" 26# L -80 7798 10279 6635 8708 7240 5410 PRODUCTION 7943 9 -5/8" 47# MN -80 25 7968 25 6752 6870 4760 SURFACE 2667 13 -3/8" 72# MN -80 27 2694 27 2694 5380 2670 TUBING 4 7" 26# L -80 24 28 24 28 7240 5410 TUBING 10102 4 -1/2" 12.6# L -80 28 10130 28 8575 8430 7500 1 • • bp ii�� *. Memorandum To: Clark Olsen & Tyler Norene Date: June 18 2012 ADW Well Service Team Leaders From: Bernhard Stechauner AFE: APBINJEC DS- 03Production Engineer Reviewed: Josh Allely, 6/28/2012 Est. Cost: Subject: 03 -07A CIBP, Add Perf, Acid IOR: 200 Type Desc. Comment S Retrieve 4 -1/2" MCX and drift to deviation F SBG treatment C Drift/Flag /Log, Set CIBP, Add 100' perforations, Acidize (pending injectivity test) S SBHPS, set 4 -1/2" MCX Current Status: WAG injector, online, injecting MI Last Injection Rate: 25,557 Mscf /d MI @ 3,089 psi on 6/17/2012 Max Deviation: 93° @ 11,811' MD Min. ID: 3.725" @ 10,117' MD (4 -1/2" HES XN Nipple) Last Downhole Ops: 5/3/2012 — Set 4 -1/2" MCX @ 2,190' MD Last SBHP: 08/16/2006: 3,263 psi @ 8,800' TVDSS;177F Latest H2S level: N/A - Injector Job Objective: The objective of this procedure is to set a CIBP to isolate all current perforations, to add 100' of new perforations for the fourth MI bulb in the well, and to stimulate the new perforations with acid. Also, an opportunistic static bottom hole pressure will be obtained when slickline returns to re -set the MCX safety valve. Well History: Well 3 -07A is a MIST injector in Zone 3. The overall plan for this well is to have 7 sets of 100' perforated interval, with each set separated by a CIBP. MI will be injected into each set with each "plug - pert -MI injection" cycle lasting 1 -2 years. Initial perforations were shot from 13650'- 13750' on 4/27/04 and three MI bulbs were injected from 7/2004 to 5/2006. On 09/04/06 a CIBP was set and tagged at 13489' CTM and a second set of 100' of perforations were added from 13200' — 13300'. An acid stimulation was needed for the second set of perforation to increase injectivity. The third set of 100' perforations were added in 2010. Anticipating poor injectivity, with coil still on location, the well failed an injectivity test and coil performed an acid stimulation. Discussion and Justification 03 -07A has a history of add perfs followed by acid stimulations. Therefore the acid was included in the procedure to be performed on coil. The acid schedule is the same as used for the last stimulation in 2010 where we saw an increase in injectivity from 0.7 bpm @ 2000 psi pre acid stim to 2 bpm @ 350 psi post acid stim. The last CIBP and perforations were added without tie -in logs due to large uniform sands. This set of perforations will be located closer to a shale barrier and depth control is more critical. 0 • The well is currently on MI injection, but will be swapped to water during the CCP shut -down (7/28- 8/31 2012). Please allow for a minimum of one month of water injection before carrying out this procedure to ensure that all the gas has been displaced away from the well. Once the well has been swapped to diesel, please pump only diesel to maintain diesel fluid column. For questions or comments please call Bernhard Stechauner 564 -4594 (work) or 360 -7485 (mobile). Cc: Well File Note: This program was designed with the intention that it would require 7 coil runs: 1. Drift/Log /Flag 2. Set CIBP 3. Add 25' perforations 4. Add 25' perforations 5. Add 25' perforations 6. Add 25' perforations 7. Acidize perforations to increase injectivity (pending injectivity test) 03 -07A SL Procedure 1. MIRU Slickline. PJSM. 2. Pull MCX from 4 -1/2" HES X Nipple @ 2,190' MD. ' 3. Drift to max deviation with drift large enough for 4 -1/2" CIBP and 25' 2 -7/8" dummy gun. , OD CIBP: 3.562 ". Drifted to deviation 10,801' MD 2/10/2012 with 3.375" dummy gun. 4. RDMO. 03 -07A SBG Treatment 1. MIRU. PJSM. 2. Pressure test. 3. Pump 5 bbl of methanol spear and 250 bbl of SBG mix. (17% concentration, 44 bbl of concentrate in 216 bbl of hot water) followed by 5 bbl of methanol. 4. Wait three hours. 5. Pump 200 bbl of 1% KCI displacement flush followed by 5 bbl of methanol. 6. Wait three hours. 7. Hand well back to operations to put well back on injection. 03 -07A Coil Add Perf Procedure 1. MIRU CTU. PJSM 2. Displace wellbore with -1.2 tubing volumes of diesel at ambient temperature. Bullhead -240 bbl diesel down tubing. 3. MU drift assembly with nozzle and GR /CCL. Drift to -12,700' MD, log to 10,000', paint flag and POOH. Tie in log: SLB Jewellry Log 26 April 2004 OD of Weatherford CIBP to be run: 3.562" 2 • • U AOP 4. Pick up CIBP, RIH, tie into flag and set CIBP (7a, 12,650 MD.•OH. Ensure good depth control so we can use the CIBP to tag for future tie in if needed. When pumping balls to seat use diesel to maintain diesel fluid column. 5. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 6. RIH, tag CIBP for depth control and perforate 12,175 - 12,200' MD. POOH. Note any tubing pressure changes in AWGRS summary. 7. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. D pie ti p 8. RIH, tag CIBP for depth control and perforate 12,150 - 12,175' MD. POOH. 1 9. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 10. RIH, tag CIBP for depth control and perforate 12,125 - 12,150'MD. POOH. �Z 11. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 12. RIH, tag CIBP for depth control and perforate 12,100 - 12,125' MD. 13. Pick up -200' and perform injectivity test with diesel down backside. Pump down tubing @ 2,000psi max pressure. If injectivity is less than 2bpm an acid stimulation is needed. Otherwise, RDMO. Please record injectivity results in AWGRS report. Pending 03 -07A Coil Acid Stim Procedure • Wellbore volume to CIBP @ 12,650' MD: -192 bbl • CT /Tbg annular volume: -155 bbl • Monitor the IA pressure throughout the job to prevent damage to the packer. • Current MSDS for this job is onsite and acid safe handling procedures are followed. • Ensure that the acid shower trailer is on site and functional. • Keep out all personnel not associated with this job. • Ensure Sundry for performing acid stimulation is on location. • Well has L -80 liner. Ensure correct additives are used. Inhibitor Package needs to be checked for 24 hours minimum protection time. Acceptable acid concentrations +/ -1 % for HCI. Fluids should be 90 -110 F • Mix/Circulate acid to ensure homogeneous solution at pump time. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Attempt to not exceed 2000 psi while acid is entering the perforations if possible. It is ok to go up to 3000 psi surface pressure in the following cases: o If the diversion is very effective at plugging slots. Increase pressure as needed to allow job to be completed. • Send an electronic copy of the treatment report including digital, ASCII, or an excel copy of pumping rates and pressures to Bernhard Stechauner at: Bernhard.stechaunerabp.com 3 • i Perforation Details Zone MDT MDB H Status Z3 12100 12200 100 Open Design Details: Wellbore Volume 185 bbls to top of pert at 13750' MD, 192 bbls to CIBP at 12,650' MD Acid Design 30 gpf of 12% HCL and 30 gpf of 9:1 Mud Acid Foam Design 15bbI per diversion 70Q Foam (2 diversions) Pres 08/16/2006: SBHP 3,263 psi at 8800 tvd, SBHT is 177 F 14. RIH with jet swirl nozzle (minimum ID is 3.725" @ 10,117' MD) to top of perforations (diesel should be in the coil at this stage) and displace coil with Ammonium Chloride while taking returns through backside. Displace diesel -500ft away from top of perforations to prevent diesel and acid getting into contact with each other (500 ft - 6.5 bbl). Close in backside and keep on injecting ammonium chloride until steady injection is achieved. If needed to establish injection, go to 3000 psi, but drop back to 2000 psi WHP immediately as not to frac the well during the acid wash. 15. Pump fluids per attached pump schedule (see acid recipe below) while reciprocating slowly across perforations (12,100 - 12,200' MD). When acid is at the perforations, max WHP should be 2000psi. Before POOH, complete the over flush to ensure that the acid has been pushed away. The acid stim should take -9.5 hours to pump. Please record N2 rates and total volumes pumped in AWGRS report. 16. Perform another injectivity test with diesel down the backside post acid stimulation. Establish a stabilized rate and pressure to ensure we have good injection. 17. RDMO Coil. 03 -07A SL Procedure 1. MIRU Slickline. PJSM. 2. SBHPS as per attached form. 3. Run MCX and set in 4 - 1/2" HES X Nipple @ 2,190' MD. 4. Run check set to ensure MCX is set. 5. RDMO SL. 6. Hand well back to operation to POI. 4 Fluid Type Vol (bbl) Vol (gal) o aa) 3% NH4CI + F103 418 17,562 Td = 12% HCI 71 3,000 0 j 9:1 Mud Acid 71 3,000 Foam (3% NH4CI +F103 +N2) 8 336 Temperature: I Medium (175 °F to 225 °F) Foam Mixing Rates Completion metallurgy: L80 total chem total chem Liquid Rate N2 Rate Loading for: 12% HCI 9:1 mud acid 12% HCI 9:1 mud acid bbl /min scf /min Product Code: Function: Units: 0.25 314 • A264 ACI gal /Mgal 6 6 18 18 A201 Inhibitor Aid gal /Mgal 15 15 45 45 0.5 629 A153 Intensifier Ib /Mgal 0 0 0 0 0.75 943 F103 Flowback aid gal /Mgal 2 2 6 6 1 1257 L058 Iron Control Ib /Mgal 20 20 60 60 1.25 1571 W054 Antiemulsifier gal /Mgal 5 5 15 15 1.5 1886 U067 Mutual Solvent gal /Mgal 0 50 0 150 ,s Stage Cum Foam vol, I N2 vol, Stage Step Description Fluid Fluid Fluid bbl I scf /bbl Pre -Flush 1 Pre - Displacement 3% NH4CI + F103 60 60 2 Acid 12% HCI 24 84 3 Mud Acid 9:1 Mud Acid 24 108 m 1 4 Overflush 3% NH4CI + F103 36 143 m 5 Diverter Foam (3% NH4CI + F103 + N2) 4 147 15 1254 s 6 Spacer 3% NH4CI + F103 20 167 CA 7 Acid 12% HCI 24 191 c 8 Mud Acid 9:1 Mud Acid 24 215 E 2 9 Overflush 3% NH4CI + F103 36 251 o. 10 Diverter Foam (3% NH4CI + F103 + N2) 4 255 15 12571 11 Spacer 3% NH4CI + F103 20 275 12 Acid 12% HCI 24 298 3 13 Mud Acid 9:1 Mud Acid 24 322 14 Overflush 3% NH4CI + F103 36 358 Overflush 15 Displacement 3% NH4CI + F103 211 569 • • TRE£ z 6-318" CALIOn ' YrfLLHEAG FMG OEN 1 SAFETY NOTES: H2S READING R AVE 125 ACTUATOR= BAKER 03-07A WHEN ON 644 WELL ANGLE tr 70' 6 10766', KS. ELEV F 61' OF ELEV KOP o 7968 Max Angle = 93` 0 11811 Datum MD = 10456 1 - —1 1 2160 I°-1 4.147 BES X N6' On 3 d13" 1 DIVA TV Cm 8100' SS m MI ' `. 225' — e•rra` FOCI i 2443' Hk' FOCI 113.316" 0.10 724 MN 0, 0 .12 347" H 3549° I • ` Minimum ID = 3128" @ 10117' 41112" TIES XN NIPPLE ' k 7810 1—^I 8-50' X 7" tiKR ZXP t 4A TOP S KR 1 L ALLOVT WXVOW 7086 MB:Li 1 10082' 4- 11T HFSX NIP, ID *3813` I 9-5IF C50, 478,MNIIXO =8. 71188' 10073' 7' X 4.113' 5KR S 3 1 1 T 1 41J2' HESXMP,Dz 3513" ; I 10117' 3 E +1°1+1' HE$ AN MP, lO = 3 725' 10130' 4 - 1a2 "%LEO ID -9966" .‘4 111114 t 10135' H 7 "X 5` BKRZ cP * 5 . LNR TORPOR I T X5° XO i 1 410 0. 4-4;2" T80,12 611 L -80, .0152 8pt, C=3 GM' 10130 No / 3 3a7' i t 7' LNR 264 L160, 0363 614, :0. 6. 276" 102791 iff 14 1411, PERFl7RATK3N StrMMARY 4-1, CSP 402/12410) 13025' REF LOG I08P'(0 62A00 13d40' dos. . ANCLEAT TOP PERE Sr fa 12750 ,,�► Note for to P- oduclion CS for 1icgoricaI pert data SIZE SPF INTERVAL OprlSgz [ATE 3 318" 6 12750. 12770 0 0118110 I 1 P810 13751' 3-38` 6 12770 - 12830 0 02113ttO I' 2 -718" 6 13200 - 13300! C I 4.112' LNR, 12 8M. L• 019? test I 3 5 ' t----I 30140' J 133432A36 -- 2 -710' 6 13650 - 13750 C 0017104 DATE REV BY coimens FITLO10E BAY WI 1 1 w 2017 V 8Y ORIGINAL COMPLETION 1 03/I8/10 ..IKOSV MD SET C P t A F FET1 NOTE W N3: 03-07A KAK FRO SIDETRACK (83 07A) 02109! 04427/04 NE WAK FMS 01110112 TNWJM) ADDED H2S SAFETY NOTE API Na: 50-029-Al220-01 ITSMO5 GLMPPAG 6ET C1$P it 13490 ADPCRF I 6E011 0 & R . T11 91!.'+ .4171.' S 1461 57' FNL 11 {101x3 ATO FLH PELF BOX CORRECTON ,07/21/1X1 BMW TREE CIO 4O7N _ 1P Esploratioo(Alaska) 6 y Mini -Log 1 I og Minilog for Well T � Project 03 -07" Author LAURA J. LARSON Scale. 1.3600 Dat .4/10,2012 Injector Well: 03 -07A OW l: 500292022001 Elevation: 55.5 + 708084.32 SPUD date: 2004 -03 -22 00:00:00 County; . USA Short name: 03 -07A Elevation datum: KB ti: 5934393.52 Completion date: 2004 -04- 2600:00:00 Field: PRUDHOE Long name: DRILISITE 03 NO 07A Total depth: 13841 Longitude: - 148.2717865 Status: State: Alaska Coi ;:dlnate system: NAD27 AFT Latitude: 70.2318391 Operator: BPXA Company: BPXA Z' GRMM_MWD 0 MWD.RE MWD FTHR PE Info 3 u n cnn TVDSS MD m a GR (FEET) (ft) 'n TVDSS O O hi . I w 11 Ii hi ■ r w 1 01 ,nn � a. 1:3600 1:3600 etler 55 M W D E W R M W D - ii ®iF� °°'° aacn on f)HMM non VI _. - 8735 L _ Fill 8830 10500 - N. lim a. 4 258LY4.'E - 8910 - `..:_.. - 8965 • • • ti 11000 - - 8995 - . - 8995 f • - 11500 - - 8095 - I. - 12000 - Add Perf @ . t 12,100' - 12,200' and TCGL p -'- y. - 12500 - _ - 8095 • CIBP ti 12,650' and • - 8995 PERF 00F 1 . r - 13000 - 1 SQP E / F L i - - SUP Sts is • ` - 13500 - Ji . • - SOP BPS 8995 7 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April 26, 2012 TO: Jim Regg c � J ,7111 /v P.I. Supervisor I \ �/ SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION (ALASKA) INC 03 -07A FROM: Lou Grimaldi PRUDHOE BAY UNIT 03 -07A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 7 NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03 - 07A API Well Number 50 029 - 20220 - 01 - 00 Inspector Name: Lou Grimaldi Permit Number: 204 - 043 - Inspection Date: 4/24/2012 Insp Num: mitLG120424152406 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03 -07A Type Inj G 'TVD 8524 - IA 15 2415 - 2390 2390 - PTD 2040430 - Type Test SPT Test psi 2131 - OA 5 0 0 0 Interval 4YRTST P/F P ' Tubing 2960 2960 2970 2970 Notes: Good solid test. - Thursday, April 26, 2012 Page 1 of 1 STATE OF ALASKA L _ ALASKA LAND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate0 Other Pertormed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ CIBP Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re- ter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 204-0430 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029-20220-01-00 8. Property Designation (Lease Number) : 9. Well Name and Numb(: \\ ADLO-028331 \ PBU 03-07A 10. Field/Pool(s): „ /„ ~!~' ~ PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Cormu Alaska 0"sf 8 6a: Cen- . Total Depth measured ~ 13841 feet Plugs (measured) 13490' 13025' feet ~ncher~ge true vertica~ 9051.62 feet Junk (measured) None feet Effective Depth measured 13752 feet Packer (measured) 7810 10073 10135 true vertical 9048.9 feet (true vertical) 6644 8524 8579 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 101.1# H-40 28 - 108 28 - 108 1650 650 Surtace 2672 13-3/8"72# MN-80 27 - 2699 27 - 2699 5380 2670 Intermediate Production 7942 9-5/8" 47# MN-80 26 - 7968 26 - 6752 6870 4760 Liner 2469 7" 26# L-80 7810 - 10279 6644 - 8708 7240 5410 Liner 3705 4-1/2" 12.6# L-80 10135 - 13840 8579 - 9052 8440 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 24 - 10130 24 - 8579 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Too Packer 7810 to P 6644 4-1/2" Baker S-3 Perm Packer 10073 f',tlC 8524 5" Baker ZXP Toa Packer 10135 8579 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~ ry Treatment descriptions including volumes used and final pressure: '~~+?~:.~ ~~C~ L' ~/- L.o~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 9649 3149 Subsequent to operation: SI 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG Q GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-429 Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 2/26/2010 sion Form 10-404 Revised 7/2009 RBD~pIS MAR O 120 ~ '?~L~- 3•~~D Submit Original Only l////a 03-07A 204-043 PERF oTTOCHFr) • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-07A 4/26/04 PER 13,725. 13,750. 9,048.34 9,048.85 03-07A 4/27/04 PER 13,650. 13,725. 9,047.86 9,048.34 03-07A 9/2/06 APF 13,250. 13,300. 9,047. 9,047.29 03-07A 9/2/06 BPS 13,486. 13,486. 9,047.35 9,047.35 03-07A 9/3/06 APF 13,200. 13,300. 9,046.36 9,047.29 03-07A 6/30/08 BPS 2,174. 13,650. 2,173.97 9,047.86 03-07A 7/7/08 BPP 2,174. 13,650. 2,173.97 9,047.86 03-07A 2/12/10 APF 12,830. 12,850. 9,049.05 9,048.24 03-07A 2/12/10 BPS G Amp 13,025. 13,750. 9,046.79 9,048.85 03-07A 2/13/10 APF 12,770. 12,830. 9,051.68 9,049.05 03-07A 2/16/10 APF ~ 12,750. 12,770. 9,052.32 9,051.68 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • C~ • 03-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/11/2010~CTU #8 1.75" CT Job Scope: Drift, Set CIBP and Perf. «<InterACT is i ~ Publishing»> SIMOPS with 9ES & MIRU CTU. Drift to 13125' ctmd with X3.68" JSN BHA and POOH. MU CIBP BHA and RIH. **'`Job continued on WSR 2/12/10**" 2/12/2010~CTU #8 1.75" CT Job Scope: Drift, Set CIBP and Perf. «<InterACT is Publishing»> Continue from WSR 2/11/10. Continue RIH WFD 10k psi Diff Pressure CIBP and set top of CIBP at 13,025'. PUH and paint EOP flag at ~ 12,950' and POOH. OOH tool shifted normal and recovered ball. MU and RIH ;with Gun Run #1: 3 3/8" x 20' gun loaded 6 spf w/ PJ3406 HMX charges. ;Perforate interval 12830' - 12850'. MU and RIH with Gun Run #2: 3 3/8" x 20' gun loaded 6 spf w/ PJ3406 HMX charges. ***Job continued on WSR 12/13/10*** 2/13/2010=CTU #8 1.75" CT Job Scope: Drift, Set CIBP and Perf. «<InterACT is 'Publishing»> Continue from WSR 2/12/10. Perforate intervals 12810' - ~ 12830', 12790' - 12810', and 12770' - 12790' ctmd in three runs with 3 3/8" x 20' gun loaded 6 spf w/ PJ3406 HMX charges. Correct depth at flag and tagged CIBP on depth for each run. Pinhole leak found in CT at 9015' while pulling out of hole after Run #3. Freeze protect tubing with 38 bbls 60/40 McOH. OOH with spent gun. Blow down reel and RDMO to shop to swap pipe. ***Job continued on WSR 2/14/10*** 2/14/2010 ~ CTU #8 Maintenance to swap Pipe 2/15/2010CTU #8 Maintenance to Spool new pipe 2/16/2010~CTU #8 w/ 1.75" CT: CIBP /Perforate: Job Continued from 13 Feb 10: EMIRU CT unit after pipe swap. Pump and recover 1.25" coil drift ball. Perform ;weekly BOP test. Perform infectivity test. Infectivity is 0.7 bpm at 2000 psi. MU and RIH with perforating run #5. Load 1/2" aluminum ball to fire gun and POOH. OOH and all shots fired, 12750'-12770' 6 SPF LD TCP, MU JSN =BHA to pump acid and RIH "**Job continued on WSR 2/17/10*"* • • ,_ _._ ~ . ~ .__ __... ~ _ ___.,_.....____ ~...~ ___ ~ _._~ _~_.__o..._ __. _ ..__ _._ ! 2/17/2010 CTU #8 1.75" CT Job Scope. Drift, Set CIBP and Perf. «<InterACT is Publishing»> Continue from WSR 2/16/10. Continue RIH, tag CIBP & correct E [ depth to 13,025'. Pump Acid Stim. POOH *"*Job complete"**'' FLUIDS PUMPED BBLS 359 1 % KCL 1 DIESEL 387 60/40 METH 73 3% NH4C1 + 0.2% F103 17 3% NH4C1 + 0.2% F103 W/U067 58 12% HCLTlTRATION=12.6% AND IRON <50 PPM 60 9:1 MUD ACID TITRATION 6 3% NH4C1 + 0.2% F103 W/L066 961 Total TREE - 6-S/8" CALICO WELLHEAD= FMC GEN 1 ACTUATOR= BAKER KB. ELEV = 61' BF. ELEV = KOP = 7968' Max Angle = 93 @ 11811' Datum MD = 10456' Datum TV D= 8800' SS ~ 03-07A 2190' ~-{ 4-1/2" HES X NIP, ID = 3.813" 2325, ~- j 9-5/8" FOC 2446' 9-5/8" FOC 13-3/8" CSG, 72#, MN-80, ID = 12.347" Minimum ID = 3.725" @ 10117' 4-1 /2" HES XN NIPPLE 7s1o' 9-5/8"X7"BKRZXP LNR TOPPKR MILLOUT WINDOW 7968' - 7984' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 90 @ 13200' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 13200 - 13300 O 09/02/06 2-7/8" 6 13650 - 13750 C 04/27/04 I 10052' -~ 4-1/2" HES X NIP, ID = 3.813" 10073' 7" X 4-1/2" BKR S-3 PERM PKR 10097' 4-1/2" HES X NIP, ID = 3.813" 10117' 4-1/2" HES XN NIP, ID = 3.725" 10130' 4-112" WLEG, ID = 3.958" 10135' 7" X 5" BKR ZXP LNR TOP PKR 10148 7° x 5° x0 ID = 3.980" -e 9-518" CSG, 47#, MN-80, ID = 8.681" 11669' ~ ~30~ 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10130' CIBP 13490_ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~~ 10279' ( PBTD 13751' 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/20!76 ORIGINAL COMPLETION 04(06/04 KAK RIG SIDETRACK (03-OlA) 04/27!04 McN/KA IPERFS 09/02/06 GLMiPA SET' CIBP @ 13490; ADPERF 11110/06 ATD/TLH PERF BOX CORRECTION 07/21(08 RM/SV TREECiO(07/03/08) PRUDHOE BAY UNIT WELL: 03-07A PERMIT No: "2040430 API No: 50-029-20220-01 SEC11, T10N, R15E, 4171.95' FEL & 1461.57' FNL BP Fxplaration (Alaska) ,_ ~. ~ =~ ~ 4 _ ~~ ~ ~~ 4~ ~ ~, ~ ~, ~ ~, ~ ~ to ~ ~ ALA5SA OIL A11iD GA.S CO1~T5ERQATIOI~T COMl-II55IO1~T Mr. Al Schmoyer Senior Pad Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 a ~g SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 3 ~o,~ - o ~ Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 03-07A Sundry Number: 309-429 Dear Mr. Schmoyer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount ~~ Chair DATED this2- day of December, 2009 Encl. wQio~' ~~"1r" STATE OF ALASKA ~~'1~Z ti~ -~`~I ALAS IL AND GAS CONSERVATION COMMIS APPLI ATION FOR SUNDRY APPRO~S 20 AAC 25.280 -A~ 7 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^~ - ~~ _~~, ~$~0(111IT115S1 ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate Q - dt er ~ CIBP Spp~,~~i Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension ^ r~ H 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), .Inc. Development ^ Exploratory ^ 204-0430 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ - 6. API Number: Anchorage, AK 99519-6612 50-029-20220-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ PBU 03-07A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028331. PRUDHOE BAY Field / PRU DHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13841 - 9051.62 - 13752 ~ 9048.9 ~ NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 101.1# H-40 28 108 28 108 1650 650 Surtace 2672 13-3/8" 72# MN-80 27 2699 27 2699 5380 2670 Production 7942 9-5/8" 47# MN-80 26 7968 26 6752 6870 4760 Liner 2469 7"26# L-80 7810 10279 6644 8708 7240 5410 Liner 3705 4-1/2" 12.6# L-80 10135 13840 8579 9052 8440 7500 Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached - - 4-1/2" 12.6# L-80 24 - 10130 Packers and SSSV Tvoe: 7" Baker ZXP Toa Packer Packers and SSSV MD and TVD (ft): 7810 6644 4-1/2" Baker S-3 Perm Packer 10073 8524 5" Baker ZXP Top Packer 10135 8579 12. Attachments: Description Summary of Proposal ^ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/2/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WIND ^ GINJ ^ WAG Q- Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact AI Schmo er Printed Name AI Sch oyer Title Senior Pad Engineer Signature ~ Phone Date B 564-5865 12/21/2009 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: • Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: / `- . y Q T ` CJ APPROVED BY Approved b COMMISSIONER THE COMMISSION Date: RBDf~ Form 10-403 Revised 07/2009 l~(~`Il~ ~`- ~)RIG(~!Al.. ~I,~- ~Z • 2/3•d s `~ / ° ~~(~ Submit in Duplicate 03-07A 204-043 DFRF ATTArHMFNT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-07A 4/26/04 PER 13,725. 13,750. 9,048.34 9,048.85 03-07A 4/27/04 PER 13,650. 13,725. 9,047.86 9,048.34 03-07A 9/2/06 APF 13,250. 13,300. 9,047. 9,047.29 03-07A 9/2/06 BPS 13,486. 13,486. 9,047.35 9,047.35 03-07A 9/3/06 APF 13,200. 13,300. 9,046.36 9,047.29 03-07A 6/30/08 BPS 2,174. 13,650. 2,173.97 9,047.86 03-07A 7/7/08 BPP 2,174. 13,650. 2,173.97 9,047.86 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE i by ~~~~. To: J. Bixby/C Olsen GPB Well Ops Team Leaders From: Whitney King, DS 03 Pad Engineer Rev by: Brad Gathman, Wells Group Engineer Subject: 03-07A CT set CIBP and Adperfs • Memorandum Date: December 17, 2009 Est. Cost: $120,000 AFE: PBD03WL07-C IOR: 500 1. S Drift with 3-3/8" dumm tan to deviation. 2. C Set 4-1/2" CIBP and ad erfs. Perform in'ectivit test. 3. CP Acidize erfs to increase in'ectivit Current Status: Horizontal MIST Injector Last Test: 12/06/09: 18,221 bwpd, 1264 WHP Last SBHP: 08/16/06: 3263 psi, 177E Max Deviation: 93 degrees C~ 11811' MD Min. ID: 3.725" C~ 10117' MD, 4-1/2" HES XN nipple Last TD tag: 09/03/06: Tag Composite C«3 13489' CTM Last Downhole Ops: 07/07/08: Set MCX Latest H2S level: n/a, injector Ref Log: SLB Jewelry Log/Mem GR/CCL 26 April 2004 Job Objective The purpose of this procedure is to prepare for the next cycle of this MIST horizontal. A CIBP will be set to isolate the old perforations and a new set of perforations will be shot. An acid stim to increase injectivity has been included because it was needed to increase injectivity on the last set of perfs. Well History Well 3-07A is a MIST injector in Zone 3. The overall plan for this well is to have 7 sets of 100' perforated interval, with each set separated by a CIBP. MI will be injected into each set with each "plug-perf-MI injection" cycle lasting 1-2 years. Initial perforations were shot from 13650'-13750' on 4/27/04 and three MI bulbs were injected from 7/2004 to 5/2006. On 09/04/06 a CIBP was set and tagged at 13489' CTM and a second set of 100' of perforations were added from 13200' - 13300'. An acid stimulation was needed for the second set of perforation to increase injectivity. For questions or comments please contact Whitney King at (work) 564-4840 or (cell) 310-989-7674. cc: w/a: Well File • • SL Pre-CIBP and Adperf: 1. RU SL. RIH and pull 4-1/2" MCX from 4-1/2" X nipple C 2190' MD (2174' SLM 07/07/08). POOH. Drift as deep as possible fora 3-3/8" pert gun. Deviation surpasses 70° 10780' MD. Note: if 3.7" drift is unable to clear minimum restriction of 3.725" ~ 10117' MD, will have to run 2-7/8" pert guns. 3. POOH. RDMO. CT CIBP and Adperf: 4. SI well and RU CT. Liquid pack as needed. Volume to freeze protect is ~40 bbls. 5. Make up drift MHA with JSN (minimum ID is 3.725" 10117' MD). Drift 100' past CIBP setting depth (13025' CTMD). Clean out if necessary. POOH. Note: Depth control is not critical. No memory logs are necessary for setting plug or adperf. 6. MU BHA for 4-1/2" CIBP. RIH to 13025' CTMD and set CIBP. POOH. 7. MU 3-3/8" perforating guns and perforate the following intervals (Zone 3). All depths are given as CTMD. If there are problems or discrepancies with the CT counter, tag the CIBP for depth control. Perfs are requested 150' above the CIBP. Window is not critical. If unable to do 30' stands, four runs of 25' stands totalling 100' of perfs (12750' - 172850') is fine. 0 12750' - 12780' (30' adperf) 0 12780' - 12810' (30' adperf) 0 12810' -12840' (30' adperf) Note: Guns must be shot in water, not gas. Max swell of 3-3/8" guns in liquid is 3.66". Minimum ID is 3.725" C~ 10117' MD. If SL or initial CT drift run encountered problems with 3.7" drift, downsize to 2-7/8" guns. 5. Perform injectivity test. Pump down tubing C 2000 psi. If injectivity < 2 bpm, acid will need to spotted across the perfs to increase injectivity. POOH. CT Pending Acid Job: o Wellbore Volume: 198 bbls to proposed CIBP depth of 13025' CTMD o CT/Tbg annular volume: 160 bbls (w/ 1.75" CT) o Note: monitor IA pressure throughout the job to protect the packer. Include an IA tie-in during RU in case there is a need to pressure up the IA. 6. RIH with a jet swirl nozzle (minimum ID is 3.725" 10117' MD) and pump the following fluid schedule while reciprocating slowly across perforations (12750' -12850' CTMD). 80 bbls 3% NH4CI + F103 15 bbls 3% NH4CI + F103 + 0067 60 bbls 12% HCI 60 bbls 9:1 Mud Acid 100 bbls 3% NH4CI + F103 + L066 If needed to establish injection, go to 3000 psi WHP, but drop immediately to 2000 psi WHP as to not frac the well during the acid wash. When acid is on the perfs, max WHP should be 2000 psi. Before POOH complete the over flush to ensure acid has been pushed away. 7. Do an injectivity test down the backside post acid stim. Establish a stabilized rate and pressure to make certain of positive injection. 8. POI and RDMO. • T + 6.318' C'ALf~E3 f`f/iC C~t1 t RCfUAT~+ 9AK~R KB H_~d a 8i` ~~_ A fC • a968' f~c + it8ii` t)aLm fail. 1415fa' ikat~an 11/tAw 88(16` 53 113.3{8' ,, 72#J, uli•8o. !l + 12:347' Minimum ID = 3.T25" 10117' 4.112" HES XN NIPF+LE 9-s.~' f~.LCA.rr tivrfw a9~1° K T9s~ ftfZl~4Tf3fiI riv IMF LOG: Ah~i=ATTt~F'E} 96 ~ 13204Y Fb+fe: Rsler 1D AO~u~#ore f3f14ar P~fa-ie~ P~1 5LrE SP>T 1!473=i2VR.L Q~irtlS~x OATS 2~7~8' 6 1326(1- 133QQ 4 [19+Y12R8 ~T18' fi i36~- i3T5it ., ff4t2T.t1A A-i.2'TBG, i i~ ~ ~ $AfETY Nd7ES~ 2190' 4.1;r X lam, ~r.3~s13• 2~~ 9•Sf8' F'OC 2448' 8 ' f, try, .0152 [!¢S, Q ~ 3 ~--~ 18730' 7'L7~ 28A, L-8(t. A383bpf. D+b`.s78' A-id2Llit, 12brlf,L-811, Ai52~t1,~a+3.~J58' Xlri f~; D ~ 3.T~ ~WLf=G, ~ + 3.958' 7'X5' E1iR ZX1' Lfii T('J# f4SR 7' X 5' XCJ 3~98E1' T t6l2gT$ UAQI~L CCIiAPLETI4#1 WlOBd04 IWS 7t~SWET7iACK{93•U7AJ 41J27d4I VISA S 11Bd~lOB L:111i'A 3>=f ~ 13+196; 11f 10!1}6 07121J09 (07JQ3708f • T2750 Adp¢~ ~ 7~ so ~ i~ e4o' 12800 A dqu~rF +~so~_ S2BH0~ 12850 • SLB Jewelry Log 26 Apri12004 f28OO Company: 6P Exploraticx~ Alaska f. J '~A'eli C^s-07 Perforating System #1 2-718" High Shot Gensiry, a~,~erJet 29C~6, HhiX, 15.0 g '_' °'^asing, d DD spf Clearance .Avg 0.51 in Total Fen Avg 1 x.32 in Formation Pen Avg 15.24 in Formation Dia.A;rg 0._8 in Casing ~H Avg D.36 in AOF ~,a 6.C0 spf, 0.5'' in'rft AEI: °en 2'.?= in. E- Dia G 38 ^. '6 tst Ed. Perforating S~stem #2 2-718" High Shot Densi:~;, Power,;e Omega 25+06, HMX, 14.0 g :_ =^asing, @ DD spf Clearance .Avg ._ m Total Pen Avg ?1.73 in Fom~ation Pen Avg ''C;'.70 in Formation Dia Avg 0.53 in Casing H Avg 0.3y in AOF i,at 6.40 spf4 D.70 in'a A.?I: °en 58.=i in. E- :;~~a t; 34 ^. a6 1st Ed. Perforating System #3 3-3~'8" High Shot C~ensir,+, o~.verJet 3406, HMX, 22.7 g __ =^asing, ~: DD spf Clearance Avg O.~a in Total Pen Avg "_'x.14 in Formation Pen .Avg 21.Oc~ in Formation Dia .Avg 0.81 in Casing~H .Avg O. ti8 in AOF rat 6.G0 spf; 0.~~7 in'ift API: Pen 3fS.5Q in. EN Dia 0 3i n. ' ~6 1st Ed. Rock -ype: Sar~s:one Rock UCS: Pr103 psi ~ E,.ne ~denical stress: BD5D psi ~ ement ?xe Pressure. 4D4} psi ~ :;amagedZone Fcnnattx Results are bases on API and c~her test data of schium6erge~ perHxatin9 systens as •Nell as computer ncdeling of perforated ccmpletc•^s. ResuBs are prsrvided m gccdfath wiCrflut warranty SPAN Version $.Ol File: C:'~.Program FilestSchlu.. t;~ergei'~.SPAN °~ O'~.UNTITLED.SP8 c~Copyright 2~9 Sehlumberger Sd>fumberper D"drield Sevicas Bdan Sinasc Pr-~ora9e. AK Clierrt : BP Exploration Alaska, krc. Engineer: Ms. Vyhiprery King Service District: Prudhoe Bay ~J Schlumberger ~~m Well Macs: 03-07A i"ield P~hoe Bey fornraticn: Fluid Systems: f 60 bbls 9:1 Regular Mud Acid 25.0 ppt A153 Irtribitor Aid 4.0 ppt x1179 Irdribitor Aid 1.0 96 A~61 Inhibitor 0.2 96 F103 Surfacmnt, EZEFLQ 2110 ppt L05B km 5tsbifiaer 0.5 16 bL'054 Non•ErnulsifyingAgent 0.5 96 44'00 Sludge and Emulsion Preventer 3 811 bbls 346 MH4GI + F103 D.2 % F103 5urfac~nt, EZEFLd 250.0 ppt J235 Ammonium chloride 5 15 bbls 346 NH,CI + F103 + U067 0.2 % FU73 Surfactant,EZEFLO 250.0 pp[ J235 Arnrrcniurn chloride 5.0 '~ llOli7 Mutual Solvent 2 60 bbls 1346 HCI 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 InhibitorAid 0.6 96 Ai61 Inhibitor D.2 96 F 103 Surfactant. E2FFL0 20.0 ppt LCGa IronStabiNaer 5.0 ~ U067 Mutual Salmrent 0.5 96 W1154 Non-Emulsif}ing Agent 0.5 96 Nt060 Sludge andErnulsmPreverr<er 100 bbls 346 MHaGI + F103 +1066 0.2 96 F103 Surfactant, Er£FLO 25A.0 ppt J2~ Ammonium chloride 3.5 Wo LO66 Acid Compatible Scale Inhibitor Nota: BHST ~ 230 °F, wellbore cmffiins 13-CR tubulars Irtribitars and non-emulsifiers to be designed accordingly Chemical Requirements: Total liquid Load: 315 bbls 126 Ib A.153 IrtiibitorAid 21 Ib A179 IrhibitorAid 41 gal 11261 Inhibitor 27 gal F103 Surfactant, EZEFLO 2049 Ib J2s35 Ammonium chloride 0 gal J529 OiISEEKER 101 Ib L05B har 5tabiliarir 147 gal 1A66 Acid Compatible Sale Inhibitor 15g gal U067 Mutual Solverd 26 gal 44'G&1 Non-EnrulsifyingAgent 26 gal 44'CGO Sludge and Emulsion Prev~ter •- Schlumberger ditltield Ser-jces Baan3inomc Arxhoraga AK CliarC BPExploratlonAlaska.lrrc. Engirwor. Ms. Whitney King Senriu Distrie! PNdhoe Bay PRICING ESTIMATE: Material Duentity Unit Qescripton $ERVIiCES: 18000718 1 ea Acd Purnp tat 6hrs 18001710 3 hr Acid Purnp,>8 hra 58041009 6 hr Transport, Md [Shop to Shopl 104432004 0.6 ea Cod Unit Operation 13(4' Total Sorvice~ MATERIALS: H036 754 gal 3696 HCI Acid H449 ?,520 gal Acd, Regular Mud A153 126 Ib InhihrtaAid A1r~3 ?t Ib InbibitcrAid A?61 41 ~I Inbib~or FiD3 27 gal Svfrxtant.E~LO J285 ?,048 Ib Ammaniurn chbxide J529 - gal OdSEEKER L058 101 Ib Ircn Stabilizer 1066 147 gal Acd Conpatible Scalel~ubmor 0087 158 gal Munml SoMent W064 26 gal Non-Ernelsifying Agent W066 26 gal Sludge and Emulsion Rewertter Total AAatorialsd Total Sri-Partx S~~mber~ 21-Feb-08 Woll Nana 03-O7A Fioltk Prudhoe Bay Parnatbrc Price Arncunt $ 6,456.73 $ 6,466.73 $ 90684 5 2,98052 $ 249.06 $ 1,494.38 S 17,896.90 $ 10,90594 S 31$17.58 $ 2.74 $ 2.06272 S 2.32 $ 5,846,83 S 16.43 S 2,069:92 $ 3.78 S 7'9.31 S 19.86 $ 814.31 S 10.64 S 28737 $ 0.60 $ 1,23583 S 7888 $ - S 3.56 S 35832 $ 5985 $ 8,198.57 S 27.52 $ 4,34794 $ 1482 $ 395zo S 26.56 $ 69060 $ ffi,976J1 $ - TOTAL SERVICES, MATERIALS & 3RD-PARTY: $ 48,794.28 MEM®RANI)UM To: Jim Regg ~v ~~Z7~~~ P.I. Supervisor 1 ~~~~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 19, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03-07A PRUDHOE BAY UNIT 03-07A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~- Comm Well Name• PRUDHOE BAY UNIT 03-07A API Well Number: s0-029-20220-01-00 Inspector Name• Jeff Jones Insp Num: mitJJ080s17121422 Permit Number: 204-043-0 i Inspection Date: 5/13/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - --_. - Well ~ 03-07A ~TYpe In]. W ~ TVD 8524 ~ IA ~ 470 ~ 4000 ~ 3940 ~ 3920 ' Yp ; ------ . - - -- - -- ~ - - - - - ' p•T• 2o4oa3o 'T eTest sPT Test psi z131 ', OA zo so ~ so so l _. _ _.. - --- _ -- - - -- - ----- ---- - - - Interval 4YRTST p~F P / TUbing' 1260 ~ 1260 1260 I 1260 Notes• 7.1 BBLS 60/40 methanol pumped. i~~h~~~ JUL ~ ~ ~~~~ Monday, May 19, 2008 Page I of 1 ~ • -,x ~- t MICROFILMED 03101/2008 DO NOT PLACE ems. -.. ~~ ,~ ;. _. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc OCT 1 0 2006 <- STATE OF ALASKA '-," ~.~ ALASKA OIL AND GAS CONSERVATION COMMI~~~~'ldi ..' . . G~ Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Ancnorage 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 Repair WellO PluQ PerforationsD Pull TubingD Perforate New PoolO Operation ShutdownD Perforate Œ] Stimulate 00 WaiverO 2. Operator Name: 3. Address: 4. Current Well Class: Development 0 ExploratoryO BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicO ServiceŒ} 9. Well Name and Number: 03-07A 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 55.50 8. Property Designation: ADL-028331 11. Present Well Condition Summary: Total Depth measured 13841 feet true vertical 9051.6 feet Effective Depth measured 13490 feet true vertical 9047.0 feet Plugs (measured) Junk (measured) Casing Length Size CONDUCTOR 80 20" 101.1 # H-40 SURFACE 2672 13-3/8" 72# MN-80 PRODUCTION 7942 9-5/8" 47# MN-80 LINER 2469 7" 26# L-80 LINER 3705 4-1/2" 12.6# L-80 MD TVD 108.0 - 2699.0 - 6752.0 - 8708.0 - 9052.0 108 - 2699 - 7968 - 10279 - 13840 28.0 27.0 26.0 6644.0 8579.0 28 27 26 7810 10135 Perforation depth: §C~NED OCT 3 1 2DOB Measured depth: 13200-13300, 13650-13750 True vertical depth: 9046-9047,9048-9049 Tubing ( size, grade, and measured depth): @ 24 10130 4-1/2" 12.6# L-80 Packers & SSSV (type & measured depth): 9-5/8" BKR ZXP LNR Top PKR @ 7810 7" Baker 5-3 PERM PKR @ 10073 7" Baker ZXP LNR Top PKR @ 10135 Otheroo CIBP Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Number: 204-0430 6. API Number 50-029-20220-01-00 CIBP set @ 13490 (09/02/2006) None Burst Collapse 1650 650 5380 2670 6870 4760 7240 5410 8440 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft 0 C1 ), 1 2006 Oil-Bbl Representative Daily Averaqe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 15589 10 51 0 Tubing Pressure 1308 660 WAG ŒI GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. SUndry Number or N/A if C.O. Exempt: 306-264 13 Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Exploratory(] 16. Well Status after proposed work: OilD GasD Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr n Ii Signature A!Y....;l~ _~.dr ~ Form 10-404 Revised 4/2004 ("I D , ~ i f\ f 11 Title Petroleum Engineer Phone 564-5174 DevelopmentD Service 00 Date 10/5/06 .~- --/ 03-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/04/2006 TestEvent --- Inj Press, psi: 661 Type: PW Vol: 09/04/2006 CTU #5. Acid Stim. Load IA with diesel and pressure to 1000 psi. Pump 5 bbls of 3% ammonium chloride water, 20 bbls of 7.5% HCI and 10 bbls of 9:1 Mud acid. reciprocating from 13195' to 13305' with 3 passes. Allowed to soak on final pass. Overdisplace with 20 bbls of 3% ammonium chloride water, 8 bbls of fresh water and 150 bbls of 1 % KC!. Good pressure breaks were noted when HCI and Mud Acid contacted the perfs. Initial injectivity was 1.0 bpm @ 1550 psi. Final injectivity was 2.0 bpm @ 479 psi. POOH. Freeze protect well with 38bbl of 50/50 methanol. Secure well and notify DSO of well status...RDMO*** JOB COMPLETE*** 7.5% HCI (Titration: 7.6% HCI, Iron < 50 ppm) 9:1 Mud Acid (Titration: 9.1 % HCI, 1 % HF, Iron <50 ppm) 09/03/2006 T/IIO=N/ANACNAC. Temp.= 51. IA FL. for CTU. IA FL @ 96'. (6 bbl). 09/03/2006 CTU #5. Adperf. MU BHA #5: 2.375" Weatherford MHA, SLB firing head, 2 7/8" Powerjets, 6spf, 30' guns. Tag CIBP @ 13489' ctm. Correct to bottom shot. PUH to firing depth. Shoot interval 13225' to 13250'. POOH. RIH with BHA #6: Weatherford MHA, SLB firing head, 2 7/8" Powerjets, 6spf, 30' guns. Tag CIBP @ 13489' ctm. Correct to bottom shot. PUH to firing depth. Shoot interval 13200' to 13225'. POOH. Performed injection test. Injection rate @ 1.2 bpm at 2000 psi. MU BHA #7: 2.5" JSN for acid stimulation. RIH and Tag CIBP at 13490' ctm. Standby on loading of fluids. 09/02/2006 CTU #5. Set CIBP/Perforate. RIH with Weatherford 4.5" CIBP. Set plug center of element at 13490' ctm. Successfully pressure tested plug to 3000 psi. POOH. RIH with BHA #3, 2.375" Weatherford MHA, SLB Firing head, 2 7/8" Powerjets, 6spf, 30' guns. Tag CIBP @ 13486' ctm. Correct to bottom shot. PUH to firing depth. Shoot interval 13275' to 13300'. POOH. RIH with BHA #4, 2.375" Weatherford MHA, SLB firing head, 2 7/8" Powerjets, 6spf, 30' guns. Tag CIBP @ 13486' ctm. Correct to bottom shot. PUH to firing depth. Shoot interval 13250' to 13275'. POOH. At surface, all shots fired. Making up next gun string. 09/01/2006 CTU #5..MIRU..Weekly BOP test..RIH with Weatherford MHA and 3.625" JSN for drift. Tag at 13715' ctm (82' discrepancy between counters). PUH and wash 13150' to 13500'. POOH. RIH with Weatherford MHA, Hyd Setting Tool, 3.57" CIBP. At 9800' discover electronic counter failed. POOH to inspect counter. At surface, counter not rolling correctly in housing, rebuild counter. 08/17/2006 (pre ctu cibp) RIG DOWN MOVE TO L4-12 *** TURN WELL OVER TO DSO *** 08/16/2006 ***WELL SHUT IN ON ARRIVAL*** (pre cibp) RAN 3.85" GAUGE TO ISSSV @ 2173' SLM. PULLED 4.5" MCX W/1.31 BEAN SERIAL# M-19. CORRECTED BACK TO X-NIP @ 2190' (2174' SLM) 16' CORRECTION MADE 15 MIN. STOP'S W/ SBHP GAUGES @ 10,334', 10,456' & 10,606' MD. *** JOB IN PROGRESS *** Page 1 ~~ ...........-' 03-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 1 Diesel --- PT Surface Equipment 20 Methanol 112 50/50 Methanol Water 260 1 % KCL Water 203 2°/Ó KCL Water 30 30/0 Ammoium Chloride plus 50/0 U067 + 0.2% F13 20 7.50/0 HCL (Titration 7.6% HCL, Iron < 50 ppm) 10 9:1 Mud Acid (Titration 9:10/0 HCL, 1% HF, Iron < 50 ppm) 656 TOTAL Page 2 TREE = WB-LHEAD= . A CTUA TOR= KB. ELEV = BF. REV = KOP= Max Angle = Datum MD = Datum ND= McEVOY FMC GEN 1 AXB-SON 61' 7968' 93 @ 11811' 10456' 8800' SS 113-3/8" CSG, 72#, MN-80, ID = 12.347" 1---1 2699' Minimum ID = 3.72511 @ 10117' 4-1/211 HES XN NIPPLE ÆRFORA TION SUMMA RY REF LOG: ANGLEAT TOP PERF: 90 @ 13200' Note: Refer to Production DB tor historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 2-7/8" 6 13200 - 13300 0 09/02/06 2-7/8" 6 13650 - 13750 0 04/27/04 03-07 A ~ SAFETY NOTES: I - 2190' 1-1 4-1/2" HES X NIP, ID = 3.813" I ~ 2325' 1---1 9-5/8" FOC 1 2446' 1---1 9-5/8" FOC 1 .. ~ ~ ~ 7810' 1---1 9-5/8" X 7" BKR ZXP LNR TOP ffiR I MILLOUT WINDOW 7968' - 7984' 10052' 1--1 4-1/2" HES X NIP, 10 = 3.813" 1 10073' l-i 7" X 4-1/2" BKR S-3 ÆRM PKR I 10097' 1---1 4-1/2" HES X NIP, 10 = 3.813" 10117' l-i 4-1/2" HES XN NIP, 10 = 3.725" I 10130' 1---1 4-1/2" WLEG, 10 = 3.958" 10135' 1- 7" X 5" BKRZXP LNR TOP PKR 10148' 1- 7" X 5" XO 10 = 3.980" 19-5/8" CSG, 47#, MN-80, ID = 8.681" 1---1 11669' 4-112" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1--1 10130' 1 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" l--f 10279' 1 1 PBTD 1--1 13751' I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10= 3.958" 1----1 13840' DA TE REV BY DA TE REV BY COMMENTS 10/20/76 ORIGINAL COM PLETION 04/06/04 KAK RIG SIDETRACK (03-07A) 04/27104 McNlKAK IÆRFS 09/02/06 GLMlPAG SETCIBP@ 13490; ADPERF COMMENTS FRUOHOE BAY UNIT WB-L: 03-07 A PERMIT No: "'2040430 API No: 50-029-20220-01 SEC11, T10N, R15E, 4171.95' FEL & 1461.57' FNL BP Exploration (Alaska) . . 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ( (907)276-7542 FRANK H. MURKOWSKI, GOVERNOR AI{ASIiA OIL AND GAS CONSERVATION COMMISSION Patti Phillips Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 03-07 A Sundry Number: 306-264 Dear Mr. Phillips: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. -, DATED this~ day of August, 2006 Encl. :-}Gtf- (:/-i3 DJ":::S ð'/eJ/6> 1ft~~O~ . STATE OF ALASKA m 8 ,,9'.ð. ~ ALA OIL AND GAS CONSERVATION COMMI N AUG 0 4 2006 APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commissìon 20 AAC 25.280 w6* Abandon Suspend Operational shutdown Perforate Waiver / Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate.-f!t Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: \!f\\;i cD \~)v (lli a\ "1ft 'i) ~14;'ð'1 ~ 1. Type of Request: er BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Development 0 Stratig raphic 0 Exploratory 0 .-/ Service eJ 204-0430 ./ 6. API Number: 50-029-20220-01-00 / 9. Well Name and Number: 55.5 KB 03-07A ./ 8. Property Designation: ADL-028331 11. Total Depth MD (ft): 13841 Total Depth TVD (ft): 9051.62 10. Field/Pools(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 13751 9048.87 Plugs (measured): None Junk (measured): None Collapse 650 2670 4760 5410 7500 Casing Length Size TVD Burst Conductor 80 20"101.1# H-40 28 108 28 108 1650 Surface 2672 13-3/8" 72# MN-80 27 2699 27 2699 5380 Production 7942 9-5/8" 47# MN-80 26 7968 26 6752 6870 Liner 2469 7" 26# L -80 7810 10279 6643.58 8708 7240 Liner 3705 4-1/2" 12.6# L-80 10135 13840 8579.43 9052 8440 Perforation Depth MD (ft): 13650 - 13750 / Perforation Depth TVD (ft): 9047.86 - 9048.85 Tubing Size: 4-1/2" 12.6# Tubing Grade: L-80 Tubing MD (ft): 24-10130 ( ¿' Packers and SSSV Type: 7" Baker ZXP Top Packer 4-1/2" Baker S-3 Perm Packer 5" Baker ZXP Top Packer Packers andSSSV MD (ft): 7810 10073 10135 / 12. Attachments: Descriptive Summary of Proposal 0 Detailed Operations Program eJ BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 13. Well Class after proposed work: Exploratory 0 Development 0 Service eJ Date: 15. Well Status after proposed work: Oil 0 / Gas 0 Plugged 0 Abandoned 0 WAG ø GINJ p WINJ 0 WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Contact Patti Phillips Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Signature En ineer Phone 564-4578 Date COMMISSION USE ONLY 8/3/2006 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Form 10-403 Revised 7/2005 RBDMS BFL AUG 0 9 20D6 Subsequent Form Required: Approved by: COMMISSIONER APPROVED BY THE COMMISSION Date: L Submit in Duplicate · TREE = WI3...LHEAD- A CTUA TOR= KB. ELEV = BF. ELEV = KOP= Max An Ie = Datum MO = OatumTVO= McEVOY FMC GEN 1 AXELSON 61' 7968' 93@11811' 10456' 8800' SS 13-3/8"CSG, 72#, MN-80.10= 12.347" I Minimum ID = 3.725" @ 10117' 4·1/2" HES XN NIPPLE ÆRFORA llON SUMMA RY REF LOG: AI\K3LEATTOPPERF: 90@ 13650' Note: Refer to Production DB for historical perf data SIZE SA" INTffiVAL Opn/Sqz DA TE 2-7/8" 6 13650-13750 0 04/27/04 03 -0 7 A 1 SAFETY NOTES: 2190' 4-1/2" HESX NIP, 10-3.813" 9-5/8" FOC I 9-5/8" FOG I 7810' ---1 9-5/8" X7"BKRZXPLNRTOPPKR I I MLLOur WINDOW 7968' - 7984' 7" X 4-1/2" BKR &-3 PERM A<:R 4-1/2" HES X NIP, 10 - 3.813" 19-518" CSG, 47#, MN-80, 10 = 8.681" 1-1 11669' 1 4-1/2" TOO, 12.6#, L-80, .0152 bpf, 10 = 3.958" 7" LNR, 26#, L-BO, .0383 bpf, 10 = 6.276" I DATE REV BY 10/20/76 04/06/04 KAK 04/27/04 I'v'cNiI<A COMMENTS ORIGINAL COMPLETION RIG SIDETRACK (03-07A) IÆRFS DATE REV BY 4-1/2" LI\R, 12.6#, L-80, .0152 bpf, 10 - 3.958" I OOMMENTS PRUDHOE BAY UNIT WELL: 03-07A ÆRMT No: 2040430 API f\b: 50-029-20220-01 SEC11, T10N, R15E, 4171.95'FEL& 1461.5T FNL 8P Exploration (Alaska) bp o . . To: Jerry Bixby / Clark Olsen GPB Well Ops Team Leaders Date: 08/01/06 From: Patti Phillips DS 3 and 17 Production Engineer Subject: DS 03-07 Ai CIBP. Perf. and Acid Stimulation PBD03WL07-C Capacity Sustainment Est. Cost: $120M lOR: 600 Please perform the following steps to set a CffiP, adperfs and acid stimulate 03-07 A MIST injector. Type lOR PR N DS-WL AFE JOB DESCRIPTION PRIORITY COMMENTS/OTHER S 600 03-07i A PBD03WL07 Drift and tag C 600 2 03-07i A PBD03WL07 Set CIBP and Adperf, Injectivity test. Possible acid job (not likely). Does not require acid flowback. Procedure: 1. S 2. C 3. CP Drift and tag as deep as possible. Set CffiP at 13490'MD. Perforate 13200' -13300'MD (see attached procedure). /' Perform acid stimulation (see attached procedure). Max Deviation: 93 deg @ 11811'MD Proposed Plug Deviation: 90 deg Proposed Adperf Deviation: 90 deg Min. ill: 3.725" @ 10117' MD, 4-1/2" HES XN Nipple Last TD tag: 13710' MD 4/27/04 Last Downhole Ops: SBG 7/24/06; c/o SSSV 7/8/05; IPERF 4/27/04 Latest H2S value: No Data Tie-in Log: Jewelry/PDC Schlumberger 4/26/04 Well 3-07A is a MIST injector in Zone 3. The overall plan for this well is to have 7 sets of 100' perfed interval, with each set separated by a CffiP. MI will be injected into each set with each "plug- /' perf-MI injection" cycle lasting 1-2 years. Initial perforations were shot from 13650'-13750' on 4/27/04 and three MI bulbs were injected from 7/2004 to 5/2006. A second set of 100' of perforations will be added (see attached procedure). An acid stimulation procedure is also attached, which will help increase injectivity, if post perf injectivity is lower than anticipated. This is not expected because the 1 st perf job did not require an acid job. Contact Patti Phillips at x4578, 346-1755 (home), or 240-3742 (cell) or Jennifer Julian at x5663, 274-0929 (home) or 240-8037 (cell) with any questions or comments. Please note that Jennifer's cell phone does not work from the CT unit and you may have to use your truck phone. cc: w/a: 03-07 A Well File . . Patti Phillips 03-07 Ai Recompletion Program Prepared By: Patti Phillips Jennifer Julian Phone#: 564-4578 (w), 240-3742 (c) 564-5663 (w), 240-8037 (c) JOB PLANNING DETAILS: Perfs: 13200 - 13300' (new perfs-see attached procedure) 13650' - 13750' (to be isolated by plug) Proposed Plug Deviation: 90 deg Proposed Perf Deviation: 90 deg TD Tag History: 13710' MD 4/27/04 Displacement bbls: 210 bbls (4-1/2" monobore to top pert) Static: -3250 psi @ -8800' SS (average from 2 recent statics in offset wells) NOTE: CIBP to be set at 13490' MD Beware of potential H2S in any returns taken at surface. / PREP WORK: 1. Drift and tag as deep as possible. CT OPERATIONS: 3. SI PW Injection. RU CT. Rig up and be able to pump down tubing. 4. RIH with 4-112" CIBP and set at 13490'MD. Pressure test the CIBP to 3000 psi. Memory log not required due to large window. 5. Perforate with 2-7/8" Powerjets, 6 SPF from 13200' - 13300'. See attached procedure. Memory log not required due to large window. 6. Pump down tubing @ 2000 psi. If injectivity < 2 bpm, plan on acid job below. Not expected because 1 st set of perfs did not require acid job. . . Contineent Acid Job: 7. Trap 1000 psi on the IA. 8. Make multiple passes across the perfs and pump the following at maximum rate with a recommended maximum WHP of 2000 psi (*). Don't POOH until the entire overflush has been pumped behind pipe in order to reduce the chance of stirring up schmoo. 5 bbls 20 bbls 10 bbls 20 bbls 3% NH4CI with 10% U-66 and 0.2% F103 7.5% HCI 9% - 1 % HCI-HF 3% NH4CI overflush with 10% U-66 and 0.2% F103 . * Go to 3000 psi if necessary to establish injection. Once acid is at the peifs, the maximum treating pressure should be 2000 psi . LJ . DO NOT bring acid to surface due to likelJ(H~$Jormation. All fluids should be filtered to 3 microns. Please note the initial andfinal injectivity in the WSR. Please note the vitals in the WSR when each stage hits the peifs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the treating report to the program author. Treatment Design: 4200 gal 7.5% HCI 0.5% A261 0.5% A201 20 ppt L58 0.2% FI03 0.5% W54 0.5% W60 2100 gal 9:1 HCI:HF 0.5% A261 0.5% A201 0.2% F103 20 ppt L58 0.5% W54 0.5% W60 -125 bbIs 3% NH4CI water with 10% U-66 and 0.2% F103 Please note the acid titrations and iron ppm on the WSR. 9. POOH. Bleed lAP. RDMO. Put on PWI injection. riP Well: Date: 03-07 Ai ......................-..-......................"........ 08101106 ..............................................--.-............................ Cost: ..........................~.~.ºº!ººº......_......_............ CC or AFE: PBD03WL07-C ................................................................................. lOR: 600 .......................................................................,......... lOR 1 ,... 2 3 ...n.................................. ....................................... . PERFORATING PROCEDURE API #: 50-029-20220-01 ...............-.............................. Prod Engr.p~~.i..':'.~.il.li.P..s....._..... . Office Ph: 564-4578 Home Ph: ....346:1755..·..·.... CelVPager: ·::::::::::::::::::::::::~~H?~~....................... WBL Entries Feet SPF 100' .........§........ m..................._......... ... ................................... ......... ....................... ...-......-............................ .m......··...................... ....,.................................. ..........................,....... Requested Gun Size: ............?:.!.!.?::........... .................,..F.'.r.i<:>.r.i~!.Çf:).I!1r.f.1.I3D!~...._.......... ..__...........................................!.::þ.:r.~~:~~:r.~:\~~ï.::QiªÞ..!2..?900 si. Notes: ressure. Well Ob'ectives and Perforatin Min 10 = 3.725" @ 10117' MO, 4-1/2" HES XN Nipple; Angle at Min 10 =27 deg Max Angle to adperfs = 90 deg @ 13350' MD; Angle at top perforations = 90 deg @ 13200' Set CIBP above lower perfs @ 13650'-13750' and perf above for next MI bulb In'ectivit test ost ad erf. Pum -25 bbls down backside at max rate @ 2000 Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Log: MWO/GR Jewelry/PDC Date: "3ï2:öï2:öo¡" .._..¡i2:6i2ÒÖ¡··.. ............................. ........................................ Company:~f.>.!;Jr.ry:~.lJ.!l. ~1::.~~.IJ_~.~~r.9.I3..r Depths (from-to) Depths (from-to) ......1.9.,;3.Q9:...... .......~.;3.,.?ºQ.:..... .........................._............ Add/Subtract .....~.~............. to the tie-in log to be on depth with the reference log. Orient. ....................'3ªf.1.g9.J.l:I. ........-....................,.......... ......................,.............. .........-.................. ..,.....,-.......................... .............................................................., Charge: .?~º?..F.'.f:).~.~r.~.~!,..'::I~.~......_...... ...."..................................... Last Prod: BOPD Is Drawdown Necessary/DesiredlUnnecessary During Perforating Preferred Amount of Drawdown/Suggestions to Achieve Drawdown BWPD .................................... Last Tag: 13710' ft MD ....".............................. Well: Date: 03-07 Ai ~~~~__~~n_n_____~ API#: General Comments: Balance O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U OIBIU O/B/U Referenced to BHCS ........m........................ .!J..!l!:'~C?~??..~.ry..... NA ........-............................ ,.........................,. GOR ............................................ m~/2.!.!.?ºº~. Est Res. Pres. @ ._....__......__.!.~.,.?ºº.:... Perforation Summary 50-029-20220-01 .................................. .....m....."'.............. Gun Dla. Orient. SPF MD is Prod Engr: ..... PBTD Phasing ..................... . Phasing .§º~ 1·......I:!.~-~Ñ'1·:'.~·I:··...i m.............··.....··......................................·· ............................. feet Zone Ad/Rellperf .........?;.9....mm ....m ..........m......Agpl3..r.t........_..... . ........................................ ...................................................... .......................... ....................................................... .......................... . .............................................. .........,.................."..................... ...,.....,.......".................................................. ...........................................-. ......................... ................................ .................................................-.. 3250 psi Zone ............................. .............................................................-..-.... Summa Dist Town: .m.............. Anch Prod Engr P.O. Center AdperflReperf . ............................ . . n , I f ,",'? Á~u7 , , VCfV N"7 r;" ,-/. 1 ji f I- , , m , :t j1 , ~, t .1., d_J , , IP,'(V' , I 1: d: :J , , , ¡ , , , ,1 \ IJ400 I i , I ¡ I , I \ 1 , ~ , =:~ i , , I , ¡ ¡ , ¡ t j \ I ¡ }, I ¡¡ f , , ¡ , \ fW , , ( . 13450 , , ¡ ~ ;; . , I I , , , - .Ie aI ¡ I , . ¡ 4', ..L g I I I (}¡ðf' I 13:t'#J I , -, ,- ,t J3500 \ r , " , ~m-, , , ~' I ¡ , , . - ~ ;f , 1; . . - 'ßS5() , ¡,~ ~ . H_ ...... 'c' .- ...... , .u - .-...- ---, ....- --- .--- -. . .~" '_M - .-. -c:: - -:} _. ..-1. -. -\ ----- '_H' + -; I SROP -+ -+c:"'+- -I-..:j' : ". .~- I . - _H. ~ -- ,- , ,.. I.. : --C, , -e: I - I I ~ ,<, , I -:-:r " -+--> -' I . ," , ~ -C' ;- ...... <- .j ...." I :". ,,"^- ·'H_ C ....... ¡.~ ~.~ ..~ .... ".--. .- '--- '._-- -.-- . I . .L 1)3-0711 I- - I'/Iw() 16 f( 3Þ.I>!tJ 1 ! , -T l J ¡ +-SEXP,SESP.SEMP.SEDP i : : i !:¡ .,L.,>~~....~J_+-+_+ " ~---~j-+-+-W~-L .-- -; _.~ ; +-t-+ --+--", ¡ ; _.. "T I I - -- I I -- I -- I I , I -- I .- I I I , II I , -- I I I I I 4 -- ! i; ... I I M .- .- I .... I . - ... , . 13 --- , i ~':;¡::J( I ç 0 0 1 k" 0 ~ i 0 'r-- 13 250 0 Ö ----,.. "T 0 r - 0 I .- _. '" 0 , <R6 fR7 <ENDf ~I 6/ ~EGIN RUI '> .' 0 C I ! 0 -- I 13 300 I 1 ! ,I ··t·-··· I I tr , I " , 133 50 i·· +- .J.~ -~i-' i tI , , ~. --- .--- _. "_.~ -- . :: -. ---" - .- -- - -- -- C.i· . I-M - .-- I I I II . 'Of ,...,... t .¡ å , J<c t {J . II ,ill ¡ -""I , ..... ,'1. \ ..... , ¡ . i ..... i: { ! ¡ , ¡ , I I ! , t , , . ª ~. -.1: - f ¡ ~ I .¡ i' I , Ii . . 3...", w<,( DC '3 UISO It, $ I 74 , ry ;" Ip1/ ! ¡ I 0 , , M 'J I " I } I D , I ¡ :J , I , ,.., . ;1 1,-" ¡ I I (l ð 1 (1 '5(1 ! Q , ,. :) ¡ 1° 1 I ! t) 1 ~ , - I I) \ t ¡ I I ç , ~ ¡ t , I ¡ J:: " 00 . . ;:¡~ U200 32 C1.. us . . WSR from last perf job 4/26/04: WELL SERVICE REPORT WEll JOB SCOPE UNIT 03-07 A SIDETRACK CTU #5 DATE DAilY WORK DAY SUPV 4/26/2004 JEWELRY LOGnDEPTH CONTROL; PERFORATING MCNERLlN COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P2186-D DS-HUNTINGTON MONTGOMERY MINID I DEPTH Tn SIZE 3.725 " 10117FT 4.5 " DAilY SUMMARY Continued from 04/25/04 WSR. Pump 1.25" ball through new pipe. MU Baker 2 3/8" MHA, MU/RIH wI SLB mem GR/CCL in carrier. Log GR/CCL from 10,000'-10700'. Tag TD @ 13742' (up). Log up to 10,000' for tie-in/jewelry log. Flag CT @ 13575'. POOH. MU/RIH wI 25' guns. Tie in to flag. Shoot 13725' - 13750'. POOH. PT/changeout CC/MHA. Bullhead 18 bbllow vis flopro pill wI 10% lubtex to btm. MU/RIH wI 25' qun #2. Continued on 04/27104 WSR. lOG ENTRIES Init Tbg, lA, OA I 01 01 01 TIME DEPTH TBG CTP BPM BBlS COMMENTS 00:01 0 Continued. PJSM, review muster, continaencies, sliDs/triDs/sDills, iob plan. 00:19 0 Fluid pack backside. Line up m/w down CT. Load 1.25" ball, displace wI meth/water. 00:27 0 5 Swap to 135 F water to displace ball. (Using hot water to cut external grease on new reel.) 01:03 0 76/0 Swap to meth/wtr to FP coil. 01:27 0 39 SD pumpinq. Bleed down. POD off well. 01:50 0 Come to back deck. Have PJSM wI mem loqqer and mha reD. 02:05 0 Recover ball. Cut CT. PU lubricator. MU Baker 23/8" PAC mha: 2.36" CC. Pull test to 20k#. Good. 02:22 0 Continue make up MHA: 2 7/8" cks, 27/8" disco (7/8" ball), 27/8" XO to 1.5" MT. MHA OAL - 5.25' 02:33 0 PT UD to XO to 3500 DSi. Good. Bleed down. 02:56 0 43 PJSM wI mem logger. MU Baker XO. MU SLB CCUGR in carrier. Carrier is 2.2" Xn 14.55' L. 03:12 0 Stab onto well. Fluid pack coil. PT low to 200 psi/high to 4000 psi. Good. Bleed down. 03:22 0 Swab is pressure locked aqain. Call out arease crew. 03:50 0 0 0 441 Unlock valve. Open swab. RIH. Crack choke for returns. Discuss swab valve wI valve shop supervisor. 04:40 5000 10 14 0 Svnch wI mem loaaer. Wt ck - 11.5k#. Continue RIH. 05:34 10100 15 21 0 Wt ck = 22k#. 05:39 10000 15 34 0 Park. Svnch wI mem loaaer. Loa down @ 60 fpm. 05:55 10700 14 188 0 Park. Synch wI mem loaaer. Continue RIH. 06:26 13753 15 485 0 Taq TD @ 13753' dn, 13742' up. Synch wI mem loaaer. Loa UD @ 60 fDm.. 06:31 13575 14 245 0 Park, flag CT @ 13574.7'. (Teal wI yellow hi-lites). Continue logging up @ 60 fpm. Close in returns. Freeze protect treelsurface lines. 07:33 10000 20 159 0 TOD of interval. Svnch wI mem loaaer, POOH. 08:42 0 At surface, bleedlunstab lub. 09:35 0 Break down loaaina tools, aood data. 09:45 0 MU firina head & 2-7/8" auns to MHA. OAL - 36.25'. 10:23 0 Stab lubricator. PT low to 300 psi, hiah to 2500 Dsi, aood. 10:34 0 Open swab, RIH. 11:04 950 Snubbing in and pulling heavy when PUH. Spear meth down backside, to tanks. Trv RIH aaain, no problems. 12:28 8700 Wt ck = 9.5k#. 13:15 13150 Wt ck = 17k#. Losing weight while RIH, having to snub in. Gain wt when stop RIH, PU's clean. 13:43 13450 Wt ck = 17.5k#. Havinq to snub in. 14:09 13586 At flaa, reset to 13572' corrected to top shot. 14:38 13610 31 Cvcle DumD down backside to RIH, makina slow Droaress, pipe helicallina. 14:52 13660 Try to let coil relax to work downhole, no luck. Cvcle DumDS to aet downhole. 15:30 13725 481 Tag TD @ 13737' dwn, 13725' up. Shot interval 13725' to 13750'. . . 15:45 13725 15 1160 2.4 0 Drop 5/8" AI ball. 16:06 13725 0.7 32.71 Ball on seat, shear @ 3400 psi. Clean PU = 25.5k#. 16:15 13572 0.3 1 Repaint flaa (aaua wI banana hi-lites), fill hole while POOH. 18:06 223 Crew c/o. PJSM to discuss removing spent guns from well. 18:27 0 38 At surface, swab SI, bleed unstab. 18:51 0 Break down spent guns, recover 5/8" ball. 19:21 0 Attempt to PT mha. Leak @ CC/mha. Call out Baker rep 20:06 0 7 Baker rep on location. Discuss. PJSM. Re-PT mha to 300 psi for Baker witness. 20:25 0 8 Cut off CC. Cut about 2-3" of CT. Assume flag unchanged. MU new CC. Pull test to 20k#. Continue MU new (same) MHA. 2.36" CC, 2 7/8" Cks, 2 7/8" Hyd Disco (7/8" ball), 2 718" Pac to 1.5" MT XO. PT MHA to 3500 psi. Good. Bleed down. 21:01 0 PJSM. Revew next steps to install nite cap and spot lubtex pill across high anqle interval. 21:17 0 Nite cap installed. Isolate reel. Fluid pack lines wI water/meth. PT surface lines low to 200 psi/hiqh to 3000 psi. Good. Bleed down. 21:29 0 0 10 Swab pressure locked. Open bleeder port, open valve, close bleeded port. Spear down backside wI meth/wtr. 21:30 0 0 5/5/0 5 bbl meth/wtr spear. Swap to 1 % KCL spacer. Swap to low vis flopro wI 10% lubtex down backside. Catch fluid @ 5 bbl flopro away (15 bbls total). 21:47 0 2800 16 Pumping @ 1.5- bpm @ 2800 whp. Perfs locking upl Backed pump down to 0 rate @ 16 bbl florpro away @ 2800 psi. Resume pumping @ .1-.3 bpm/2800 psi whp. 21:54 0 2800 0.1 18 Abort bull heading flopro pill. Insufficient injectivity. Swap to water down backside. 22:07 0 1908 2.5 39 ??Iniectivitv returned?? Continue displacinq flopro wI water. 22:12 0 2000 3.3 51 Current injectivity? On water. 22:24 0 1786 4.1 95 Current iniectivity. On water. 22:34 0 4 136 Coil pressuring up, one of the reel isolation valves is leaking. SO pumping, qrease valve. 22:39 0 1800 4 Coil depressured, valve qreased. Resume pumpinq. 22:46 0 164 146 bbls water pumped. SO pump, swap to meth/wtr. Continue displacing pill. 23:02 0 209 45 bbls meth/wtr pumped. SO pumpinq. Have PJSM wI mem loqqer. 23:22 0 Remove nite cap. Begin MU firina head and 25' aun. 23:44 0 Stab onto well. Line up to PT down backside only wI water/meth. 23:53 0 219 Fluid pack lines wI w/m. PT backside only, low to 200 psilhigh to 2500. Good. Bleed down. 23:59 0 0 3 0 219 Open swab. RIH wI qun #2. Continued. Final Tbq, lA, OAI 01 01 01 JOB COSTS SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL BAKER THRU TUBING $4,500 $4,500 CONAM $1,060 $4,564 DOWELL $14,880 $53,815 MI FLUIDS $3,830 $5,899 ORBIS $950 $4,750 SCHLUMBERGER $4,676 $30,538 VECO $1,642 $19,850 WAREHOUSE $4,830 $15,545 BP $0 $5 PAD THREE $0 $1,231 HOT WATER PLANT $0 $3,802 PEAK $0 $640 HALLIBURTON $0 $9,425 TOTAL FIELD ESTIMATE: $36,368 $154,564 FLUID SUMMARY 188 bbls meth/wtr 71 bbls fresh water (pump ball on CT) 18 bbls low vis flopro wI 10% lubtex 151 bbls 1% KCL SAFETY NOTES Job in proqress. . . PERFORATIONS TOP DEPTH BOTTOM DEPTH GUN DIAMETER ORIENTATION SHOT DENSITY SHOT PHASE 13,725 13,750 2.875 N 6.00 180 WSR continued from last perf job 4/27/04: WELL SERVICE REPORT WEll JOB SCOPE UNIT 03-07 A SIDETRACK CTU #5 DATE DAilY WORK DAY SUPV 4/27/2004 JEWELRY LOG--DEPTH CONTROL MCNERLlN COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P2186-D DS-HUNTINGTON MONTGOMERY MINID I DEPTH TTl SIZE 3.725 " 10117 FT 4.5 " DAilY SUMMARY Continued from 04/26/04 WSR. RIH wi 25' gun #2. Tie -in to flag. Tag TD @ 13710' (up). Circ flopro/lubtex pill ahead of ball. Shoot 13700'-13725'. MU/RIH wi 25' gun #3. Tie -in to flag. Tag TD @ 13706' (up). Circ flopro/lubetex pill ahead of ball. Shoot 13675'-13700'. MU/RIH wi 25' gun #4. Tie -in to flag. Tag TD @ 13703' (up). Shoot 13650'-13675'. FP to 2700' while POOH. BOP test @ surface. RDMO. lOG ENTRIES Init Tbq, lA, OA I 01 01 01 TIME DEPTH TBG CTP BPM BBlS COMMENTS 00:01 0 0 3 RIH wi 25' aun #2. 00:45 5000 50 3 0 219 Wt ck = 9.5k#. Continue to RIH. 00:58 6420 0 3 0 219 Get scaffoldina inspected/sian-ed off. 01:29 10000 3 3 0 219 Wt ck = 19.5k#. Continue RIH. 01:59 13000 6 2 0 219 Wt ck = 22k#. Continue RIH. 02:11 13593 8 2 0 219 Pull up to & Park @ flag. make tie-in correction to top shot depth of 13572'. Continue RIH. 02:20 13700 8 1 0 Loosing weight, stacking out. PU. RIH faster. Made it down to 13718'. Next attempt, made it to 13719'. 02:30 13676 37 2 2.5 220 Pump mlw down backside. Made it down to 13720', cycling pipe. PU. RIH to 13719'. PU @ 13710'. 02:36 13700 950 1 0 222 Park @ 13710'. Line UP water down CT. Bleed off WHP and take returns. 02:45 13700 13 2500 1.7 121 Pump 2 bbl water spacer, follow wi 18 bbl floDro Dill. 02:58 13700 15 1600 1.6 20 Pump 2 bbl water tail for pill. 03:00 13700 15 1600 1.6 22/0 SD pump. Drop 518" aluminum ball. Displace wi water/meth. Reduce rate to 1 bpm @ 28 bbls pumped. Ball on seat @ 33 bbls, shear @ 3260 DSi. POOH. 03:30 13572 0 216 0 37 Park @ flag. Repaint. White base/red stripes. POOH. FP surface lines to tanks. 05:15 100 0 0 0 PJSM wi TCP rep. Review gun handling safety, roles/responsibilities, hand safety, radio communications. 05:30 0 0 0 0 37 Tag up at surface. Close swab. Pop off well. Have holes. Begin removing gun. 05:45 0 Ball recovered. Continue removal. 05:49 0 122 Fluid pack coil. PT MHA to 3500 psi. Good. Bleed down. Continue wi make up of qun #3. 25' of 2 7/8" 6 spf. 06:29 0 Stab onto well. PT backside to 2500 psi. Good. Bleed down. 06:37 0 Open swab. Install fusable. RIH wi aun #3. Choke cracked for returns. 07:55 9000 Wt ck = 16k#. 08:12 11 000 Wt ck - 20k#. 08:35 13595 At flaq, reset depth to 13572'. PU wt = 23k#. 08:40 13706 Taq TD @ 13706 UP wt, PUH to 13675'. 08:41 13675 3600 2 0 At depth. Pump 2 bbl wtr spear down coil, 32 bbl FloPro spear, 2 bbl wtr spear. 09:09 13675 361 Drop 518" AI ball, on seat @ 33.2 bbls, shear @ 3200 DSi. PUH. 09:30 13675 33.2 Ball on seat @ 33.2 bbls, shear @ 3200 psi. PUH. , . . . 09:32 13571 361 Repaint flag (red w/yellow polka dots). SI PIS. POOH. 11 :15 0 At surface, SI swab. 11 :24 0 261 Unstab, break down auns, all shot. Ball retrieved. PT MHA to 3500 psi, aood. 12:15 0 MU BHA wI gun #4. 25' of 2 7/8" 6 spf. Stab well. PT 300 psi lowl 2500 psi hiah, aood. 12:20 0 Open swab, RIH wI aun #4. 13:53 11000 Wt ck = 20k#. 14:17 13599 At flag, reset depth to 13572'. PU wt = 22k#. 14:23 13650 Taa TD @ 13703' up wt. PU to 13650'. 14:28 13650 22 2900 1.7 0 Drop 5/8" AI ball, 14:55 13650 33 Ball on seat @ 32.6 bbls, shear at 3372 psi. POOH. 16:33 0 42 At surface, SI swab. 16:46 0 Unstab lub, guns shot, break down BHA. Recover ball. Add cc & nzl for BOP test. 17:10 0 Begin BOP test. 20:00 0 Complete BOP test 20:59 0 Ria down complete. Drive to shop for conversion to N* Final Tba, lA, OAI 01 01 01 JOB COSTS SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL BAKER THRU TUBING $5,362 $9,862 CONAM $1,060 $5,624 DOWELL $13,020 $66,835 ORBIS $950 $5,700 PAD THREE $513 $1,744 SCHLUMBERGER $24,228 $54,766 VECO $1,343 $21,193 WAREHOUSE $1,890 $17 ,435 BP $0 $5 HOT WATER PLANT $0 $3,802 PEAK $0 $640 MI FLUIDS $0 $5,899 HALLIBURTON $0 $9,425 TOTAL FIELD ESTIMATE: $48,366 $202,930 FLUID SUMMARY 201 + bbls meth/wtr 50 bbls low vis flopro wI 10% lubetex 8 bbls 1% KCL PERFORATIONS TOP DEPTH I BOTTOM DEPTH I GUN DIAMETER I ORIENTATION I SHOT DENSITY I SHOT PHASE 13,650 I 13,725 I 2.875 N I 6.00 180 ~ ~ M') -?-. ~ó ~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040430 Well Name/No. PRUDHOE BAY UNIT 03-07A Operator BP EXPLORATION (ALASKA) INC J(Jud J.)..t1~ ~ i API No. 50-029-20220-01-00 MD 13841./ TVD 9052...- Completion Date 4/26/2004 ? Completion Status WAGIN Current Status WAGIN UIC Y ~~,----,----~~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: DIR I GR / PWD, USIT, DIR I GR / RES I ABI, GR / CCL (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 4/23/2004 C Lis 13593 Induction/Resistivity 7968 13841 Open 2/22/2006 ROP DGR EWR plus Graphics Directional Survey 4/23/2004 D TIF 12990 Induction/Resistivity 7821 13791 2/5/2005 GRlEWR4/ABI/PWD/ROP 12990 LIS Verification 7821 13791 2/5/2005 GRlEWR4/ABI/PWD/ROP ---- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments . ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? ~ Daily History Received? ~/N (5)N . Formation Tops Analysis Received? ~ Comments: ...~ Date: 23 11) ÀI\)~ Compliance Reviewed By: . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 VIC- ;2040A-3 1 55q-3 RE: MWD Formation Evaluation Logs 03-07A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 03-07 A: LAS Data & Digital Log hnages: 50-029-20220-01 1 CD Rom t4~ J! 291 DG · / )-~ t2- . ./--r éJotf~ 0 'IS WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 2, 2005 RE: MWD Formation Evaluation Logs: 03-07 A, AK-MW-2978518 1 LDWG formatted Disc with verification listing. API#: 50-029-20220-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy O}' THE TRANSMITTAL LE'n'ER TO THE A1TENTlON OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-l 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: #}ç I STATE OF ALASKA I ALASKP\ LAND GAS CONSERVATION COMMISION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED MAY I 9 2004 il¡~u,L" n;¡ 0_ n .... 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Glass: '~y" '-'Uil", l.JummlSSIO~ 20AAC 25.105 20AAC 25.110 o DevelopmerWU:hrmmr.Exploratory OGINJ ~WINJ o WDSPL No. of Completions One Other o Stratigraphic Test ~ Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/26/2004 204-043 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 3/22/2004 50- 029-20220-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4/2/2004 PBU 03-07 A 1316' NSL, 812' EWL, SEC. 11, T10N, R15E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 1787' SNL, 2348' WEL, SEC. 15, nON, R15E, UM 55.5' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1500' SNL, 5263' WEL, SEC. 15, nON, R15E, UM 13752 + 9049 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 714073 y- 5937379 Zone- ASP4 13841 + 9052' Ft ADL 028331 --- -- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 711006 y- 5934188 Zone- ASP4 Total Depth: x- 708084 y- 5934394 Zone- ASP4 (Nipple) 2190' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost ~Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: DIR / GR I PWD, USIT, DIR / GR I RES I ABI, GR I CCL 122. CASING, LINER AND CEMENTING RECORD . CASING §~'I\I§ sF'Tli MD ::iETTING""",r'r '....'" HOLE ..... AMOUNT SIZE WT. PEFf~,.. GRADE. ~ IQP 6ÖTTOM ·'OP l"""y'·.....M. SIZE "''''YI'''~' 'I~", PULLED 20" 94# H-40 Surface 75' Surface 75' 32" 300 sx PF II 13-3/8" 72# MN-80 Surface 2699' Surface 2699' 17-1/2" 5800 sx PF II 9-518" 47# MN-80 I SOO-95 Surface 7968' Surface 6752' 12-1/4" 1075 sx Class 'G' 7" 26# L-80 7798' 10279' 6635' 8708' 8-1/2" 276 sx Class 'G' 4-1/2" 12.6# L-80 10127' 13840' 8572' 9052' 6-1/8" 44 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 124. TUBfNGRECORD /... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10130' 10073' MD TVD MD TVD 13650' - 13675' 9048' - 9048' 125. .··..ETC.~ 13675' - 13700' 9048' - 9048' --'. 13700' - 13725' 9048' - 9048' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13725' - 13750' 9048' - 9049' Freeze Protect with 160 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 29, 2004 Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit fõi@r,~~~ne, state "none". None ~ OR\G\NÞ\! M a5~ Uft _BfL ~V Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10270' 8700' None Shublik A 10303' 8729' Shublik B 10325' 8748' Shublik C 10345' 8766' Sadlerochit 10393' 8805' 45N 10448' 8849' Zone 4A 10525' 8905' 42SB 10560' 8928' 22TS 10627' 8967' Zone 3 10706' 9003' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date PBU 03-07 A Well Number 204-043 Permit No. / A roval 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. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Phil Smith, 564-4897 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ::;; « 0; t- O) a. N Eo c::? 0 :: ..,. C\Ï 0 0 ~ ~ '" ;¡o Ü ( ) E ð: ,j) Eo ,j) Eo 0; a. Eo - - g I- ü: '<t o o ~ to ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/18/2004 Rig Release: 4/5/2004 Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 3/17/2004 00:00 - 04:30 4.50 MOB P PRE RD floor & Top Drive. Blow Down And disconnect utilities between pit complex and sub base - move cuttings tank - Bridal up - LD derrick and pull sub base off of well - Hold PJSM w/ Security, CPS, And Rig Team 04:30 - 19:00 14.50 MOB P PRE Move sub from DS 15 - 43 to DS 03 - 07 Ai. Note: Drive motor failure on moving system - repair same. Total time 5.5 hrs 19:00 - 22:30 3.50 RIGU P PRE Tool Service complete location prep. Raise derrick - bridal down - RU Top Drive 22:30 - 00:00 1.50 MOB P PRE Lay mats & herculite around well. Move pit complex, shop & camp from DS 15 - 43 to DS 03 - 07Ai. 3/18/2004 00:00 - 01 :30 1.50 MOB P PRE Remove gauges & blind flange from tree on sub side. Spot sub over well. Fin move shop, camp & pit complex from DS 15 - 43 to DS 03 - 07Ai. 01 :30 - 05:00 3.50 RIGU P PRE Spot & RU shop, pit complex, cuttings tank & camp. Berm same. 05:00 - 07:00 2.00 RIGU P PRE Review Pre Spud check list. Complete all tasks. Accept rig @ 0400 hrs March 18, 2004. Note: Rig accept moved back 3 hrs due to location prep delays. 07:00 - 08:00 1.00 RIGU P PRE Pre Spud meeting with rig team & crews. Discuss BP expections, H2S precautions / hazards. 08:00 - 10:30 2.50 WHSUR P DECOMP Check wellhead pressures @ 0 psi. RU surface circ lines on tree. Test same. RU DSM lubricator pull BPV. RD DSM lubricator. 10:30 - 14:30 4.00 CLEAN P DECOMP Circ freeze protect from well utilizing 30 bbl 'soap' sweep. 5 BPM @ 500 psi. 14:30 - 15:00 0.50 WHSUR P DECOMP Blow down - rig down surface circ lines. 15:00 - 15:30 0.50 WHSUR P DECOMP Dry rod TWC in place. Test same 1000 psi - OK. 15:30 - 19:00 3.50 WHSUR P DECOMP FMC rep cap control lines. ND tree & adaptor flange. Check XO on tbg hanger - no good. MU 7" landing jt - OK. 7.75 turns total make up. LD landing jt. 19:00 - 22:00 3.00 BOPSU DECOMP NU BOPE. 22:00 - 23:30 1.50 BOPSU DECOMP Change upper pipe rams to 7". Function test same. 23:30 - 00:00 0.50 BOPSU SFAL DECOMP Remove ice plug from choke line. 3/19/2004 00:00 - 01 :00 1.00 BOPSU SFAL DECOMP Fin thaw ice plug from choke line. 01 :00 - 05:30 4.50 BOPSU DECOMP Test BOPE to BP & AOGCC regs. 250 psi low 14000 psi high. RD testing equip. John Crisp of the AOGCC waived witness of test. 05:30 - 06:30 1.00 WHSUR P DECOMP RU DSM lubricator. Pull TWC. RD lubricator. Note: Tbg @ 0 psi, Annulus @ 0 psi. 06:30 - 09:00 2.50 PULL P DECOMP MU 7" landing jt into tbg hanger. MU TDS. BOLDS. Pull hanger to rig floor wI 210k PU WT. No overpull. LD landing jt. 09:00 - 10:00 1.00 PULL P DECOMP RU 7" handling equip. RU Schl control line spooling unit. 10:00 - 13:00 3.00 PULL P DECOMP POH LD 7" 26#, LTC, L 80 tbg to SSSV spooling dual control lines. Recover 52 SS bands. 13:00 - 13:30 0.50 PULL P DECOMP RD Schl spooling unit. 13:30 - 19:00 5.50 PULL P DECOMP Fin POH LD 7" 26#, LTC, L 80 tbg. Recover 186 jts & 20.46 ft cut off jt. SSSV assy. Chemcial cut was clean. 19:00 - 20:00 1.00 PULL P DECOMP RD 7" handling equip. Clear rig floor. Printed: 4/12/2004 11:32:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 3/20/2004 00:00 - 03:30 DECOMP 03:30 - 04:00 0.50 DECOMP 04:00 - 09:00 5.00 DHB P DECOMP 09:00 - 10:00 1.00 CASE P DECOMP 10:00 - 18:30 8.50 BOPSU SFAL DECOMP 18:30 - 00:00 5.50 BOPSU SFAL DECOMP 3/21/2004 00:00 - 05:00 5.00 BOPSU SFAL DECOMP 05:00 - 07:00 2.00 BOPSU SFAL DECOMP 07:00 - 11 :30 4.50 STWHIP P WEXIT 11 :30 - 12:00 12:00 - 12:30 12:30 - 13:30 13:30 - 19:30 0.50 STWHIP P 0.50 STWHIP N 1.00 STWHIP C 6.00 STWHIP C RREP WEXIT WEXIT WEXIT WEXIT 19:30 - 20:30 1.00 STWHIP C WEXIT 20:30 - 21 :30 1.00 STWHIP C WEXIT 21 :00 - 00:00 3.00 STWHIP C WEXIT 3/22/2004 00:00 - 04:00 4.00 STWHIP P WEXIT 04:00 - 05:00 1.00 STWHIP P WEXIT 05:00 - 06:00 1.00 STWHIP P WEXIT 06:00 - 08:00 2.00 STWHIP P WEXIT 08:00 - 10:30 2.50 STWHIP P WEXIT 10:30 - 12:00 1.50 BOPSU P WEXIT Start: 3/18/2004 Rig Release: 4/5/2004 Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 Change upper pipe rams to 31/2" x 6" VBR's. Change out & test 9 5/8" pack off. 5000 psi /10 mins. Test upper & lower rams to BP & AOGCC regs. 250 psi low / 4000 psi high. Jeff Jones of the AOGCC witnessed test. Complete testing 4" equip & full body choke to BP & AOGCC regs. 250 psi low / 4000 psi high. Jeff Jones of the AOGCC witnessed test. Annular & HCR choke failed. Will change out both after wireline set 9 5/8" EZSV Blow down surface lines. Pull test plug. Install wear bushing. LD test jt. RU Schl e line unit. Run 8.5" GR/JB/CCL. Run & set 9 5/8" EZSV @ 8,003 ft RD Schl e line. Test 9 5/8" 47#, BTC, SM-95 & MN 80 casing to 4000 psi 130 mins. OK. Attempt to chg out Hydril element. Unable to back off bonnet cap. Chg out HCR choke valve. ND Hydril body. MU Hydril body w/ new element installed. Pull wear bushing. PU test jt. Test annluar & HCR choke to BP & AOGCC regs. 250 psi low / 4000 & 3500 psi high. LD test jt. Install wear bushing. Jeff Jones of the AOGCC witnessed test. PU & orient MWD.Shallow test MWD - failed. Change out MWD probe, orient & test OK. PU 9 5/8" whip stock. Con't RIH picking up BHA. Repair pipe handler. Con't RIH w/9 5/8" whipstock picking up BHA to 1,041 ft. Con't RIH w/9 5/8" whipstock on 4" DP from pipe shed to 7,918 ft. Install blower hose on TDS Est parameters. PUW 175k, SOW 150k. Orient 9 5/8" whip stock to 80 degs LHS. Wash down from 7,918 ft. Tag EZSV @ 7,992 ft (Drillers tally) Trip anchor w/20k, confirm w/10k over pull. Shear w/40k. Displace to 10 ppg LSND mud. 500 GPM @ 1800 psi Free TO 4k. Rot Wt 160k. Est SPR's Mill 8.5" window 7,968 ft - 7,973 ft. PUW 175k, SOW 150k, Rot WT 160k, TO 5-8k, 100 RPM 550 GPM @ 1800 psi. Mill 8.5" window 7,973 ft - 7,999 ft. 550 GPM @ 1800 psi. PUW 175k, SOW 150k, Rot Wt 160k, TO 5-6k, 105 RPM CBU. Make several psses thru window with rotary & without. Window slick. Pick up to 7900', Perform FIT to 12 ppg EMW. 775 psi surface pressure wI 9.8 ppg mud. POH to BHA at 1016' LD BHA, upper mill in gauge, cleared floor Held PJSM - Remove wear bushing - PU Johnny Wacker, Flush out BOP stack, flowline, possum belly and shaker beds, Printed: 4/12/2004 11:32:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/18/2004 Rig Release: 4/5/2004 Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 15:00 - 18:30 18:30 - 20:00 20:00 - 20:30 20:30 - 21 :00 21 :00 - 00:00 3/23/2004 00:00 - 18:30 18:30 - 19:00 19:00 - 20:30 20:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 3/24/2004 00:00 - 10:00 10:00 - 11 :00 11:00 -11:15 11 :15 - 12:00 12:00 - 13:30 13:30 - 15:30 3.50 STWHIP P WEXIT 1.50 STWHIP P WEXIT 0.50 STWHIP P 0.50 STWHIP P WEXIT WEXIT 3.00 DRILL P INT1 18.50 DRILL P INT1 0.50 DRILL P 1.50 DRILL P 0.50 DRILL P 1.00 DRILL P INT1 INT1 INT1 INT1 2.00 DRILL P INT1 10.00 DRILL P INT1 1.00 DRILL P INT1 0.25 DRILL P INT1 0.75 DRILL P 1.50 DRILL P INT1 INT1 2.00 DRILL P INT1 LD Flushing Tool - Total metal recovered 130 Ibs. PU, MU 8 1/2" M75 bit on 1.22 degree mtr, stab, MWD, orient, surface test, ok, PU flex collars and 5" HWDP, RIH to 841' PU 4" DP to 3360', RIH wI 4" to 7750', filled DP and test mwd at 3360' and 6065' Cut and slip 82' of drlg line, check crown saver, service top drive and grease crown RIH to 7850', orient 80 left Madd pass f/7850' to 7985', no problem passing through window fl 7968' to 7984' Wash and ream hole from 7985 to 7999', Dir drill w/1.22 motor f/7999' - 8155', surveyed with MWD- Dir-GR-PWD. Up Wt 160 k, Dn Wt 140 k, Rot Wt 150 k, spm 204, pp 2200 psi, gpm 500, Tq on btm 5-8 k, Tq off btm 4 k, ast 1.51 hrs, art - .23 hrs, ECD 10.81ppg Dir drill w/1.22 motor f/ 8155' - 9429', surveyed with MWD- Dir-GR-PWD. Up Wt 185 k, Dn Wt 146 k, Rot Wt 167 k, spm 223, pp 3000/3350 psi, gpm 547, wob 8,rpm 60-100, Tq on btm 8-11 k, T q off btm 6-7 k, art - 5.3 hours, ast - 6.16 hours Circ Hole Clean at 545 gom Short trip above 9 5/8' window to 7937', no problems service top drive Orient and pass through window, RIH to bottom at 9429, (note: washed last 93' to bottom). No Hole Problems Dir drill wI 1.22 motor f/ 9429' - 9490, surveyed with MWD- Dir-GR-PWD. Up Wt 185 k, Dn Wt 146 k, Rot Wt 167 k, spm 223, pp 3000/3350 psi, gpm 547, wob 8,rpm 60-100, Tq on btm 8-11 k, Tq off btm 6-7 k, art - .47 hours, ast - 1.58 hours Drill 8-1/2" directional hole F/9490'-10275', surveyed with MWD- Dir-GR-PWD. WOB = 8-10k RPM = 60-100 Torque On Btm 8-12k Torque Off Btm 7-8k GPM = 539 @ 3500 psi On Btm, with 350-400 psi differential pressure PIU 207k SIO 155k Rot Wt 177k AST = 2.65 Hrs ART = 4.19 Hrs Survey/Connection = 3.16 Hrs Pump sweep. Circulate hole clean F/1 0275' @ 539 gpm wI 3200 psi. Drill 8-1/2" directional hole F/10275'-10280' TD, surveyed with MWD- Dir-GR-PWD. WOB = 8-10k RPM = 60-100 Torque On Btm 8-12k Torque Off Btm 7-8k GPM = 547 @ 3500 psi On Btm, with 350-400 psi differential pressure PIU 207k S/O 155k Rot Wt 177k AST = 0 Hrs ART = 0.03 Hrs CBU F/1 0280' @ 539 gpm wI 3200 psi. Make 10 Std wiper trip to FI 10280'-9337' with no problems. Hole slick. No fill on bottom. Pump sweep. Circulate hole clean F/1 0280' @ 539 gpm w/ Printed: 4/12/2004 11 :32:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 3/18/2004 4/5/2004 3/24/2004 13:30 - 15:30 2.00 DRILL P INT1 15:30 - 16:30 1.00 DRILL P INT1 16:30 - 19:30 3.00 DRILL P INT1 19:30 - 23:00 3.50 DRILL P INT1 23:00 - 23:30 0.50 DRILL P INT1 23:30 - 00:00 0.50 DRILL P INT1 3/25/2004 00:00 - 01 :00 1.00 CASE P INT1 01 :00 - 01 :30 0.50 CASE P INT1 01 :30 - 05:00 3.50 CASE P INT1 05:00 - 06:00 1.00 CASE P INT1 06:00 - 09:00 3.00 CASE P INT1 09:00 - 10:00 1.00 CASE P INT1 10:00 - 11 :00 1.00 CASE P INT1 11 :00 - 11 :30 0.50 CASE P INT1 11 :30 - 13:00 1.50 CASE P INT1 13:00 - 13:15 0.25 CASE P INT1 13:15-15:30 2.25 CEMT P INT1 3200 psi. Monitor well-static. Drop ESS. Pump slug. POOH to 7937' (Top of 9-5/8" Window @ 7968') with no problems. Monitor well-static. Finish POOH to top of 5" HWDP UD 21x 5" HWDP, Jars, MWD, Mud-motor & Bit. Clear excess directional drilling equipment from Rig Floor. Clean Rig Floor Held PJSM. Level Rig. R/U 7" Casing equipment. SAFETY--- Held PJSM with Rig crew & Baker Service Rep regarding 7" Liner running operations. Pick Up & RIH with 7" Shoe Track - BakerLock first 3 Connections. Verify Floats Holding - RIH With 60 Joints of 7" 26# L-80 BTC-M Liner. M/U BOT "HMC" Liner Hanger w/ ZXP Liner Top Packer. Total length = 2480.51 ' Liner String wt = 54k.- Average MIU Torque 8000 ftllbs. Circulate one liner volume (93 bbl) @ 5 bpm wI 350 psi. RIH with 7" liner assembly on 4" DP to 7928'. Circulate 150 bbl mud through 7" liner @ 5 bpm wI 550 psi with full returns. Continue RIH with 7" liner assembly on 4" DP to 10260' with no problems. MIU Baker TDS Plug Dropping Head (DP Wiper Dart Loaded) & hook up circulating lines. Establish circulation. Wash down & tag bottom @ 10280'. Stage pumps to 7 bpm wI 1450 psi. Reciprocate string 15'-20'. Had full returns while circulating. P/U 215k S/O 140k. SAFETY--- Held PJSM with Rig Crew, Dowell, Baker, MI + associated personnel regarding cementing & liner setting operations. Shut down mud pumps. Turn over to Dowell - Pump 3 BBLS Water - Test surface lines & equipment To 4,000 Psi. (Test Good) - Clear Lines With Mud Push Prior To Going Down Hole - Pump 25 BBLS 11.4 PPG Mud Push, Followed With 57 BBLS (276 Sacks) 15.8 PPG Class "G" Tail Cement At 4.4 BPM- Wash Up Lines To Floor - Drop Dart And Displace With 10.4 PPG LSND Mud At 6.7 BPM With 1250 Psi. - Slow Rate And Latch Liner Wiper Plug With 77 BBLS Pumped Away - Increase Rate To 6.4 BPM Continue To Displace - Slow Rate To 4 BPM With Final Circulating Pressure At 1,140 Psi. - Bump Plug With A Total Of 171 BBLS Pumped Increase Pressure To 3,500 Psi To Set Baker Liner Hanger - Bleed Off Pressure And Check Floats (Floats Held) - Cement In Place At 15:05 Hours - Rotate 20 Turns To The Right And Release From Liner - Pressure Up Down Drill Pipe To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs As Pressure Decreases Ramp Up Pumps To 12.4 BPM With 3,300 Psi. And Circulate Cement Up Hole 30 BBLS - Reduce Pump Rate To 3 BPM With 500 Psi. Slack Off String With 50,000 Ibs To Set Baker ZXP Packer. Rotate And Repeat Process Several Times (Had Clear Surface Indication That Packer Set on initial S/O but did not see the dogs on running Printed: 4/1212004 11:32:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/18/2004 Rig Release: 4/5/2004 Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 3/25/2004 13:15 - 15:30 2.25 CEMT P INT1 tool set) - Increase Pump Rate At 12.8 BPM With 3,310 Psi. Top Of Liner At 7798', Insert Landing Collar At 10,195', Float Collar At 10,236', Float Shoe At 10,279' 15:30 - 16:00 0.50 CEMT P INT1 Increase Pump Rate to 12.8 BPM With 3,310 Psi. Circulate Out Trace of MudPush Spacer Estimated At 5 BBLS. To Surface. 16:00 - 17:00 1.00 CEMT P INT1 R/D BOT Plug Dropping Head. Clear rig floor of exces cementing equipment. 17:00 - 17:30 0.50 CEMT P INT1 Pump slug. Blow down TDS. 17:30 - 20:30 3.00 CEMT P INT1 POOH from 7798'. UD 15' Pup Jt & BOT Liner Running Tool. Inspect Running Tool. The pins had sheared with Dogs extended. UD Running Tool & Clear Rig Floor. 20:30 - 00:00 3.50 BOPSU P INT1 Hold Pre-Job Safety Meeting. Pull wear bushing. Install Test Plug - Rig Up to test BOP's with 4" DP. Test BOP & Related Equipment - Witness of BOP Test Waived by AOGCC Inspector Jeff Jones - Test Annular to 250/3500 psi, Upper & Lower Pipe Rams, Blind Rams, Manual & HCR Valves On C/K Lines, Choke Manifold, TIW & Drill String IBOP valves, Top Drive Upper & Lower IBOP Valves to 250/4000 Psi. All test were API. RID Testing Equipment. Install wear bushing. 3/26/2004 00:00 - 00:30 0.50 BOPSU P INT1 UD BOP Drill Pipe Test Jt & clear rig floor. 00:30 - 01 :30 1.00 CASE P INT1 R/U to test 9-5/8" casing x 7" liner. Pressure casing to 4000 psi (8.4 bbl). Hold for 30 minutes. Test was API. RID test equipment. Blow down surface lines. 01 :30 - 02:30 1.00 EVAL P INT1 Service TDS & Inspect Drawworks brakes. 02:30 - 05:30 3.00 EVAL N WAIT INT1 TIH picking up 4" DP to 4298' while waiting on Schlumberger E-line unit to arrive at location. 05:30 - 07:00 1.50 EVAL N WAIT INT1 POOH with 4" DP. 07:00 - 07:15 0.25 EVAL P INT1 SAFETY--- Held PJSM with Rig Crew & Schlumberger personnel regarding E-line logging operations. 07:15 - 08:00 0.75 EVAL P INT1 R/U SWS e-line & related equipment for running USIT log. 08:00 - 14:30 6.50 EVAL P INT1 SWS RIH with USIT log to 10150' WLM. Log up to 7812'. POOH with e-line. Estimated TOC @ 8330'. 14:30 - 15:00 0.50 EVAL P INT1 RID SWS e-line equipment. 15:00 - 17:00 2.00 DRILL P PROD1 PJSM. M/U 6-1/8" Steerable Drilling assembly. Test MWD-OK. 17:00 - 20:00 3.00 DRILL P PROD1 TIH with 6-1/8" Steerable Drilling assemble on 4" DP to 10101'. 20:00 - 22:00 2.00 DRILL P PROD1 Break circulation. Wash down & tag Landing Collar @ 10196'. Drill out Landing Collar, Cement & Float Collar (10236') from 10196' to 10276'. WOB = 5-14k RPM = 30 Torque off Btm = 7.5 KFtLb, Torque on Btm = 8.1 KFtLb GPM = 270 @ 2300 psi on Btm with 250 psi diff. P/U 165k S/O 140k Rot Wt 156k 22:00 - 00:00 2.00 DRILL P PROD1 Displace well with FloPro SF Mud System - Pump 50 BBLS HV Spacer + 50 BBLS Fresh Water, Followed Up With 8.4 ppg FloPro Mud. Pump Rate = 294 gpm w/ 2000 psi. Reciprocate & rotate (30 rpm) drill string while circulating. P/U 175k S/O 155k Rot Wt 165k 3/27/2004 00:00 - 01 :00 1.00 DRILL P PROD1 FloPro mud to surface. Shut down & clean shale shakers & flow line. Printed: 4/12/2004 11:32:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/18/2004 Rig Release: 4/5/2004 Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 3/27/2004 01 :00 - 02:00 1.00 DRILL P PROD1 Drill out 7" Float Shoe @ 10279', clean out 8.5" Rathole to 10280'. Drill 6-1/8" directional hole from 10280' to 10300'. Slide as required to build & maintain inclination & azimuth as per directional plan. WOB = 10-15 klbs. RPM = 40 Torque off Btm = 7.8 KFtLb, Torque on Btm = 8.5 KFtLb GPM = 275 @ 2200 psi on Btm with 150 psi Diff. P/U 175k S/O 155k Rot Wt 165k. 02:00 - 03:30 1.50 DRILL P PROD1 CBU F/1 0300' @ 325 gpm w/ 2250 psi. Reciprocate & rotate (30 rpm) while circulating. 03:30 - 04:00 0.50 DRILL P PROD1 RIU for Formation test (FIT). Pressure up on formation to 725 psi with 8.4 ppg mud to achieve a EMW of 10.0 ppg (TVD @ 8708'). Held pressure for 10 minutes. Final pressure = 700 psi. Bled-off pressure & open BOP. 04:00 - 00:00 20.00 DRILL P PROD1 Drill 6-1/8" directional hole from 10300' to 10650'. Slide as required to build & maintain inclination & azimuth as per directional plan. WOB = 10-20 klbs. RPM = 60 Torque off Btm = 5.0 KFtLb, Torque on Btm = 9.0 KFtLb GPM = 320 @ 2550 psi on Btm with 250 psi Diff. P/U 177k S/O 150k Rot Wt 170k. Drilling Time last 24 Hrs= 13.60 hrs ART = 1.96 Hrs AST = 11.64 Hrs. Survey & Connection time = 6.90 Hrs 3/28/2004 00:00 - 14:00 14.00 DRILL P PROD1 Drill 6-1/8" directional hole from 10650' to 11037'. Slide as required to build & maintain inclination & azimuth as per directional plan. WOB = 10-20 klbs. RPM = 60 Torque off Btm = 5.0 KFtLb, Torque on Btm = 9.0 KFtLb GPM = 312 @ 2400 psi on Btm with 250 psi Diff. P/U 182k S/O 151k Rot Wt 172k. Drilling Time last 24 Hrs= 7.69 hrs ART = 1.36 Hrs AST = 6.33 Hrs. Survey & Connection time = 6.31 Hrs 14:00 - 14:30 0.50 DRILL P PROD1 Pump HV sweep & circulate sweep up into 7" casing with 312 gpm @ 2150 psi. Reciprocate & rotate (60 rpm) while circulating. 14:30 - 15:00 0.50 DRILL P PROD1 Flow check. Well static. POOH from 11037' to 10270' with no problems. 15:00 - 16:00 1.00 DRILL P PROD1 Drop eirc-sub opening ball & pump on seat. Shear eire-sub. CBU from 10146' with 525 gpm @ 1600 psi. Flow check. Pump slug. 16:00 - 19:00 3.00 DRILL P PROD1 POOH to top of BHA. 19:00 - 22:00 3.00 DRILL P PROD1 Stand back Jars, HWDP & Flex Collars. Down load MWD data & Change out MWD-DM tool. Rejet Mud-motor, change out stabilizer & adjust bend on Motor to 1.15 deg. MIU Bit #3. Orient Mud-motor to MWD. Load MWD Program. Surface test I MWD-OK. I Printed: 4/12/2004 11:32:47 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 3/18/2004 Rig Release: 4/5/2004 Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 3/28/2004 22:00 - 00:00 2.00 DRILL P PROD1 TIH with BHA #4 on 4" DP to 6834'. Fill DP every 3000'. 3/29/2004 00:00 - 01 :30 1.50 DRILL P PROD1 TIH with BHA #4 on 4" DP to 10191'. 01 :30 - 03:30 2.00 DRILL P PROD1 Slip & Cut 136' of drill line. Reset C-O-M. Inspect Drawworks Brake System. Service TDS. 03:30 - 04:00 0.50 DRILL P PROD1 Continue TIH to 10943' with no problems. Hole in good shape. 04:00 - 04: 15 0.25 DRILL P PROD1 Establish circulation. Precautionary wash/ream F/1 0943' to 11037' TD with no problems. Take MWD Check shot. 04:15 - 15:00 10.75 DRILL P PROD1 Drill 6-1/8" directional hole from 11037' to 11774'. Slide as required to build inclination & maintain azimuth as per directional plan. Note: Had drastic decrease in ROP @ 11774'. WOB = 10-20 klbs. RPM = 60 Torque off Btm = 5 KFtLb, Torque on Btm = 8 KFtLb GPM = 321 @ 2650 psi on Btm with 250 psi Diff. P/U 187k S/O 141k Rot Wt 167k. Drilling Time last 24 Hrs= 7.59 hrs ART = 4.52 Hrs AST = 3.07 Hrs. Survey & Connection time = 3.16 Hrs 15:00 - 15:30 0.50 DRILL P PROD1 Pump HV sweep & circulate sweep up into 7" casing with 315 gpm @ 2300 psi. Reciprocate & rotate (60 rpm) while circulating. 15:30 - 16:00 0.50 DRILL P PROD1 Flow check. Well static. POOH from 11774' to 10270' with no problems. 16:00 - 17:00 1.00 DRILL P PROD1 Drop eire-sub opening ball & pump on seat. Shear eire-sub. CBU from 10146' with 525 gpm @ 1600 psi. Flow check. Pump slug. 17:00 - 20:00 3.00 DRILL P PROD1 POOH from 1 0270' to top of BHA. 20:00 - 21 :30 1.50 DRILL P PROD1 UD Jars. Stand back HWDP & Flex Collars. Down load MWD data & pull Pulser probe. UD stabilizer, mud-motor & bit. The Bit was totalled 21 :30 - 22:30 1.00 DRILL P PROD1 Service TDS & Drawworks. 22:30 - 23:30 1.00 DRILL N RREP PROD1 Repair Main Drum clutch on Drawworks (Replaced clutch diaphragm bladder). 23:30 - 00:00 0.50 DRILL P PROD1 MIU BHA #5. 3/30/2004 00:00 - 01 :30 1.50 DRILL P PROD1 M/U BHA #5 consisting of a 6-1/8" Bit + 4-3/4" mud-motor (1.15 deg Bend) + NMFS + 5.940" OD String Stab + MWD tool + 3 x NM Flex DC + 3 x 3.5" HWDP + Jars + Circ-Sub + XO Sub. Total length = 304.35'. Surface test MWD-OK. 01 :30 - 06:00 4.50 DRILL P PROD1 TIH with BHA #5 on 4" DP to 10196'. Fill DP every 3000'. Install blower hose. RIH from 10,196' to 11,032'. Check shot. RIH from 11,032' to 11,601' 06:00 - 07:00 1.00 DRILL P PROD1 Wash and ream from 11,601' to 11,774'. 07:00 - 18:00 11.00 DRILL P PROD1 Directional drill from 11,774' to 12,216'. AST - 2.6 hrs, ART- 5.22 hrs. PU - 185K, SO - 145K, ROT - 165K, TQ on - 8K, TQ off - 6K 18:00 - 19:30 1.50 DRILL P PROD1 Circulate sweep. POH from 12,216' to 10,200' - no tight spots, PU - 200K. 19:30 - 20:30 1.00 DRILL P PROD1 Drop ball and open up circ sub. Circulate bottoms up @ 12.5 bpm, 1400 psi. 20:30 - 23:30 . 3.00 DRILL P PROD1 POH from 10,200' to 304'. 23:30 - 00:00 0.50 DRILL P PROD1 PJSM. LD BHA #5. 3/31/2004 00:00 - 00:30 0.50 DRILL P PROD1 Download MWD Tools. LD BHA # 5. Printed: 4/12/2004 11:32:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/18/2004 Rig Release: 4/5/2004 Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 3/31/2004 00:30 - 01 :30 1.00 DRILL P PROD1 M/U BHA #6 - 6-1/8" Bit + 5" mud-motor (1.15 deg Bend) + NMFS + 5.940" OD String Stab + MWD tool (changeout Pulsar) to 83'. Orient and upload MWD tools. 01 :30 - 02:30 1.00 DRILL P PROD1 MU remaining BHA - 3 x NM Flex DC + 3 x 3.5" HWDP + Jars + Circ-Sub + XO Sub. Total length = 305.39'. Surface test MWD-OK. Blow down surface equipment. 02:30 - 04:30 2.00 DRILL P PROD1 RIH with BHA #6 on 4" DP to 8,329'. Fill DP every 3000'. 04:30 - 05:00 0.50 DRILL P PROD1 Service Top Drive. Adjust Brakes. 05:00 - 06:00 1.00 DRILL P PROD1 RIH with 4" DP from 8,329' to 10,198' filling pipe every 3000'. Install Blower Hose. 06:00 - 07:00 1.00 DRILL P PROD1 RI H from 10,198' to 11,033'. Check shot @ 11,033'. Cont RIH to 12,069'. 07:00 - 07:30 0.50 DRILL P PROD1 Precautionary wash and ream from 12,069' to 12,216'. 07:30 - 00:00 16.50 DRILL P PROD1 Directional drill from 12,216' to 13,145'. AST - 4.9 hrs, ART- 7.24 hrs. PU - 185K, SO -135K, ROT - 165K. TO on - 8K, TO off - 6K. 4/1/2004 00:00 - 03:30 3.50 DRILL P PROD1 Directional drill from 13,145' to 13,281'. AST - 0.62 hrs, ART- 1.66 hrs. BHA started to torque up from 7500 ft-Ibs to 9000 ft-Ibs and the ROP dropped off from 90 fph to 45 fph rotating. Decision made to trip for new bit. Pump sweep and circ bottoms up. Prep to POH. 03:30 - 05:00 1.50 DRILL P PROD1 Circulate sweep. POH from 13,281' to 10,198' - no tight spots, PU - 205K. Monitor well - good. 05:00 - 06:30 1.50 DRILL P PROD1 Drop dart and open circ sub. Circulate Bottoms Up @ 12 bpm, 1,480 psi. Slug pipe and blow down surface equipment 06:30 - 09:30 3.00 DRILL P PROD1 POH w/ DP from 10,198' to 305'. 09:30 - 10:30 1.00 DRILL P PROD1 Break out bit and stand back BHA #6. Clear the floor. 10:30 - 11 :00 0.50 BOPSU P PROD1 Pull wear ring and make up test joint 11 :00 - 15:30 4.50 BOPSU P PROD1 Test BOPE and all related valves to 250 psi low and 4,000 psi high. The witnessing of the test was waived by John Crisp of the AOGCC. Clean and clear the rig floor. 15:30 - 16:30 1.00 DRILL P PROD1 MU BHA #7 with new Hughes MX20DX to 305'. Shallow Pulse test - good. 16:30 - 18:30 2.00 DRILL P PROD1 RIH w/ BHA #7 on 4" DP from 305' to 10,198'. 18:30 - 20:30 2.00 DRILL P PROD1 Slip and cut drilling line. Service top drive and adjust brakes. 20:30 - 22:00 1.50 DRILL P PROD1 RIH from 10,198' to 13,188'. Precautionary wash and ream the last stand to 13,281' - no fill. 22:00 - 00:00 2.00 DRILL P PROD1 Drill directionally from 13,281' to 13,420'. AST - 0.2 hrs, ART- 1.2 hrs. PU - 185K, SO - 135K, ROT - 165K. TO on - 8.5K, TO off - 6.5K. 4/2/2004 00:00 - 06:00 6.00 DRILL P PROD1 Drill directionally from 13,420' to 13,841' - TD. AST - 0.43 hrs, ART - 3.97 hrs. PU - 185K, SO - 135K, ROT - 165K. TO on - 9K, TO off - 7K. -45-55% chert. 06:00 - 07:00 1.00 DRILL P PROD1 Pump sweep. Circulate bottoms up @ 335 gpm - 2,700 psi. 07:00 - 08:00 1.00 DRILL P PROD1 Short trip to 13,188' - no problems. 08:00 - 10:00 2.00 DRILL P PROD1 Pump sweep and circulate bottoms up @ 335 gpm - 2,700 psi. Spot liner running pill. 10:00 - 12:30 2.50 DRILL P PROD1 POH from 13,841' to 10,198' - no problems. Drop circ sub opening dart, pump slug, drop DP rabbit. 12:30 - 16:00 3.50 DRILL P PROD1 POH from 10,198' to 305'. 16:00 - 18:30 2.50 DRILL P PROD1 LD BHA from 305'. Flush MWD tools with fresh water. Download MWD tools. Clear the floor. 18:30 - 19:30 1.00 CASE P COMP RU 4-1/2" Liner handling equipment. Printed: 4/12/2004 11:32:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/18/2004 Rig Release: 4/5/2004 Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 4/2/2004 19:30 - 23:00 3.50 CASE P COMP PU float equipment and check floats. PU 4-1/2",12.6#, BTC-M Liner to 3,686' 23:00 - 23:30 0.50 CASE P COMP Change out handling equipment and MU hanger. 23:30 - 00:00 0.50 CASE P COMP Circulate one liner volume - 5 bpm@ 250 psi. 4/3/2004 00:00 - 03:30 3.50 CASE P COMP RIH w/4-1/2", 12.6#, BTC-M Liner on 4" DP from 3,686' to 10,270'. 03:30 - 04:30 1.00 CASE P COMP Circulate DP and Liner volume at the shoe - 5 bpm @ 800 psi. Blow down top drive. 04:30 - 06:30 2.00 CASE P COMP RIH wI Liner on 4" DP from 10,258' to 13,820'. MU cement head and break circ @ 1 bpm, 300 psi. RIH and Tag Bottom @ 13,841' 06:30 - 09:00 2.50 CEMT P COMP Circulate 3 open hole volumes while staging the pump up to 6 bpm - 1390 psi. Batch mix cement. 09:00 - 10:30 1.50 CEMT P COMP Pump 5 bbl water ahead. Pressure test lines to 4,500 psi. Pump cement job as follows: 15 bbls CW 100,5 bpm, 385 psi. 25 bbls 9.5 ppg Mudpush, 3 bpm, 900 psi 91 bbls 15.8 ppg Class G + adds, 6 bpm, 1157 psi initial, 269 psi final Flush lines with 5 bbls Perf Pill and displace cement 90 bbls Perf Pill, 7 bpm, 132 psi initial, caught cement 57 bbls into displacement, dropped rate to 6 bpm, 1551 psi final. 66 bbls 8.5 ppg FloPro, 4 bpm, 1102 psi initial, picked up wiper dart 98 bbls into displacement, 1954 psi prior to plug bump. Bump Plug with 3,000 psi and set hanger. Hold pressure for 5 minutes. Bleed off and check floats - holding. Cement in place @ 1000 hrs. Reciprocated pipe throughout entire cement job. Rotate 20 RH turns to release running tool. Circulate 30 bbls up hole. Rotate and set down to 75K to set ZXP packer. Top of Liner Tie-back @ 1 0,127' Top of Liner Top Packer @ 10,134' Top of Liner Hanger @ 10,141' Baker Insert Landing Collar @ 13,752' Float Collar @ 13,795' Float Shoe @ 13,838' 10:30 - 11 :30 1.00 CEMT P COMP Circulate out - 20 bbls of cement returns to surface @ 12 bpm, 2,700 psi. Repeat packer setting procedure several times to ensure set. 11 :30 - 13:30 2.00 CEMT P COMP Displace well to seawater @ 9.5 bpm, 2,000 psi. Slug pipe and blow down surface equipment. 13:30 - 14:00 0.50 CEMT P COMP LD rotary cement head, manifold and hoses. 14:00 - 18:00 4.00 CASE P COMP LDDP from 10,118' to 3,703'. 18:00 - 18:30 0.50 CASE P COMP Service top drive 18:30 - 21:00 2.50 CASE P COMP LDDP from 3,703'. LD Liner running tool and clear the floor. 21 :00 - 22:00 1.00 CASE P COMP MU mule shoe and RIH with DP from the derrick to 3,734' 22:00 - 00:00 2.00 CASE P COMP LDDP from 3,734'. RD mule shoe and clear the floor. 4/4/2004 00:00 - 00:30 0.50 CASE P COMP Pull wear ring. 00:30 - 01 :30 1.00 CASE P COMP Pressure test 9-5/8" x 7" x 4-1/2" production casing to 4,000 psi and hold for 30 minutes - good test. 01 :30 - 02:00 0.50 RUNCO COMP RU tubing handling equipment to run 4-1/2",12.6#, L-80, TCII Printed: 4/12/2004 11:32:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-07 03-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/18/2004 Rig Release: 4/5/2004 Rig Number: Spud Date: 9/17/1976 End: 4/5/2004 05:00 - 17:30 12.50 COMP 17:30 - 20:30 COMP 20:30 - 23:30 COMP 23:30 - 00:00 0.50 WHSUR P COMP 4/5/2004 00:00 - 05:00 5.00 WHSUR P COMP 05:00 - 06:00 1.00 WHSUR P COMP 06:00 - 10:30 4.50 WHSUR P COMP 10:30 - 13:00 2.50 RUNCO COMP 13:00 - 14:00 1.00 RIGD P COMP tubing. Time adjustment for Daylight Savings Time. Continue to rig up tubing handling equipment. PJSM. PU Wireline entry guide assy, XN Nipple assy, Baker S-3 Packer assy, X Nipple assy and RIH. Torque Turned TCII connections to 3,850 ft-Ibs. Bakerloc connections below the packer assy. PU 4-1/2",12.6#, L-80, TCII tubing to 10,127'. Torque Turned to 3,850 ft-Ibs average. PU 132K, SO - 110K Space out completion. MU and land hanger. RILDS. RU circulation lines and test to 3,500 psi. Reverse circulate 413 bbls of seawater w/ corrosion inhibitor @ 3 bpm and 150 psi. Set TWC and test from below to 1,000 psi. Blow down surface equipment. ND BOPE and NU tree and Adapter Flange (the tree is the same height as prior to the sidetrack). Test tree to 5,000 psi. Good test. Pull TWC with lubricator. PJSM. RU circulation lines and Little Red. Circulate 160 bbls diesel freeze protection fluid down annulus @ 3 bpm - 500 psi. Allow to u-tube. RD circulation lines, drop 1-7/8" ball and rod, RU lines for setting packer and testing tubing and annulus. Pressure up to 4,000 psi, set packer and test tubing for 30 minutes - good test. Bleed pressure back to 2,500 psi and pressure test the annulus to 4,000 psi for 30 minutes - good test. Bleed off pressure - 7.5 bbls recovered. Blow down surface lines and RD LRHOS. John Crisp with AOGCC witnessed both tubing and annulus pressure tests. **1-7/8" Ball and rod located in the RHC-M plug in the 'XN' Nipple @ 10,117' MD.** Dry rod set the BPV. Remove secondary annulus valve. Secure the tree and the cellar. Rig released @ 1400 hrs - 4/5/2004 to P1-07 A Printed: 4/12/2004 11 :32:47 AM - e 03-07 A Prudhoe Bay Unit 50-029-20220-01-00 204-043 Accept: Spud: Release: Ri: 03/18/04 03/22/04 04/05/04 Nabors 2ES POST RIG WORK 04/12/04 ASSISTED VECO WI BPV. PULLED BALL & ROD FROM RHC PLUG BODY @ 10,090' SLM. PULLED RHC PLUG BODY FROM XN NIP @ 10,094' SLM. 04/25/04 MU RIH W/3" JSN ON 2 STINGERS. TAG TD @ 13741 '. POOH. IDENTIFY THIN SPOTS IN COIL WHILE POOH, NEED TO SWAP PIPE. BLOW DOWN COIL WI N2 AT SURFACE. RDMO. 04/26/04 PUMP 1.25" BALL THROUGH NEW PIPE. MU BAKER 2 3/8" MHA, MU RIH WI SLB MEM GRICCL IN CARRIER. LOG GRICCL FROM 10,000'-10700'. TAG TD @ 13742' (UP). LOG UP TO 10,000' FOR TIE-IN/JEWELRY LOG. FLAG CT @ 13575'. POOH. MU RIH WI 25' GUNS. TIE IN TO FLAG. SHOOT 13725' - 13750'. POOH. PT CHANGEOUT CC/MHA. BULLHEAD 18 BBL LOW VIS FLOPRO PILL W/10% LUBTEX TO BTM. MU RIH WI 25' GUN #2. 04/27/04 RIH WI 25' GUN #2. TIE -IN TO FLAG. TAG TD @ 13710' (UP). CIRC FLOPRO/LUBTEX PILL AHEAD OF BALL. SHOOT 13700'-13725'. MU RIH WI 25' GUN #3. TIE -IN TO FLAG. TAG TD @ 13706' (UP). CIRC FLOPRO LUBETEX PILL AHEAD OF BALL. SHOOT 13675'-13700'. MU RIH WI 25' GUN #4. TIE -IN TO FLAG. TAG TD @ 13703' (UP). SHOOT 13650'-13675'. FP TO 2700' WHILE POOH. BOP TEST @ SURFACE. RDMO. 05/08/04 TIO= 120011400/100. TEMP= WARM. IA FL @ SURFACE. (PRE MITIA). BLED lAP FROM 1400 PSI TO 400 PSI IN 20 MIN. MONITOR FOR 15 MIN, lAP INCREASED 20 PSI. FINAL WHP'S 1200/4201100. 05/09/04 T/I/O=1200/350/50. TEMP=HOT. WELL IS ON INJECTION. MITIA TO 2500 PSI PASSED. (AOGCC WITNESS CHUCK SCHEVE). PRESSURED IA TO 2500 PSI WITH 1.5 BBLS ON METHANOL. IA LOST 40 PSI IN FIRST 15 MINUTES AND 0 PSI IN SECOND 15 MINUTES FOR A TOTAL OF 40 PSI IN 30 MINUTES. BLED IA BACK TO 300 PSI. FINAL WHP'S=1200/300/50. 05/10/04 TIO= 1200/520/50. TEMP= WARM. MONITOR WHP'S. (POST MIT-IA). lAP INCREASED 220 PSI FROM YESTERDAY. e e 17-Apr-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3-07 A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,894.50' MD 7,968.00' MD 13,841.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date J-J ~)J}f ~I 1iJ ()1/1 ¡ Signed .' · . .'.f6.V.,J Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ^ 0'1 -0'-13 Attachment(s) Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 03 03-07 - 3-07 A Job No. AKMW2978518, Surveyed: 12 April, 2004 Survey Report 16 April, 2004 Your Ref: API 50029202201 Surface Coordinates: 5937378.76 N, 714073.07 E (70013' 54.6199" N, 148016' 18.4275" W) Grid Coordinate System: NAD27 A/aska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 937378.76 N, 214073.07 E (Grid) Surface Coordinates relative to Structure Reference: 1888.90 S, 1728.68 E (True) Kelly Bushing Elevation: 55. 50ft above Mean Sea Level Kelly Bushing Elevation: 55. 50ft above Project V Reference Kelly Bushing Elevation: 55. 50ft above Structure Reference spaI"""'I"""Y-'SU:1'1 DRILLING· SERVIC:SS A Halliburton Company DEFINITIVE e e Survey Ref: svy4253 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 03 - 03-07 - 3-07A Your Ref: API 50029202201 Job No. AKMW2978518, Surveyed: 12 April, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7894.50 46.830 241.980 6646.05 6701.55 1756.00 S 2506.89 W 5935552.31 N 711617.03 E 3010.25 Tie-on Point 7968.00 47.010 241.920 6696.25 6751.75 1781.25S 2554.27 W 5935525.73 N 711570.38 E 0.252 3063.84 Window Point 8009.23 47.330 239.650 6724.29 6779.79 1796.00 S 2580.66 W 5935510.23 N 711544.43 E 4.112 3093.97 8040.46 45.790 237.900 6745.76 6801.26 1807.75 S 2600.05 W 5935497.94 N 711525.38 E 6.393 3116.49 8069.56 44.360 236.180 6766.31 6821.81 1818.96S 2617.34 W 5935486.25 N 711508.41 E 6.454 3136.88 e 8103.42 43.100 234.090 6790.78 6846.28 1832.33 S 2636.54 W 5935472.33 N 711489.60 E 5.661 3159.91 8132.39 42.170 232.220 6812.09 6867.59 1844.10 S 2652.25 W 5935460.13 N 711474.23 E 5.424 3179.08 8161.68 40.840 230.240 6834.03 6889.53 1856.25 S 2667.38 W 5935447.55 N 711459.45 E 6.378 3197.90 8194.28 39.560 224.670 6858.93 6914.43 1870.45 S 2682.88 W 5935432.91 N 711444.36 E 11.703 3217.90 8224.97 38.140 224.760 6882.83 6938.33 1884.13S 2696.42 W 5935418.86 N 711431.21 E 4.631 3235.91 8255.62 36.830 222.830 6907.16 6962.66 1897.59 S 2709.33 W 5935405.04 N 711418.69 E 5.740 3253.25 8286.68 36.120 219.090 6932.13 6987.63 1911.52 S 2721.44 W 5935390.76 N 711406.98 E 7.513 3270.05 8317.21 35.360 216.040 6956.92 7012.42 1925.65 S 2732.31 W 5935376.33 N 711396.52 E 6.343 3285.82 8348.44 34.580 214.100 6982.51 7038.01 1940.30 S 2742.59 W 5935361.40 N 711386.65 E 4.349 3301.27 8380.21 33.270 211.780 7008.87 7064.37 1955.17 S 2752.24 W 5935346.26 N 711377.43 E 5.797 3316.23 8411.23 32.120 210.200 7034.98 7090.48 1969.54 S 2760.87 W 5935331.66 N 711369.21 E 4.616 3330.05 8441.70 30.890 208.1 00 7060.96 7116.46 1983.44 S 2768.63 W 5935317.54 N 711361.85 E 5.409 3342.89 8473.33 29.340 206.510 7088.32 7143.82 1997.53 S 2775.91 W 5935303.24 N 711354.97 E 5.511 3355.38 8503.95 29.160 204.690 7115.03 7170.53 2011.03 S 2782.38 W 5935289.57 N 711348.89 E 2.963 3366.87 8534.42 29.190 203.780 7141.64 7197.14 2024.57 S 2788.47 W 5935275.86 N 711343.18 E 1 .459 3378.05 8582.07 30.210 203.040 7183.03 7238.53 2046.24 S 2797.85 W 5935253.94 N 711334.42 E 2.275 3395.59 8628.65 30.170 201.740 7223.29 7278.79 2067.89 S 2806.77 W 5935232.04 N 711326.12 E 1 .406 3412.72 e 8722.11 29.670 197.420 7304.30 7359.80 2111.78S 2822.40 W 5935187.72 N 711311.75 E 2.366 3445.19 8816.60 29.220 194.630 7386.59 7442.09 2156.41 S 2835.23 W 5935142.74 N 711300.19 E 1.527 3475.43 8909.32 28.060 194.580 7467.96 7523.46 2199.42 S 2846.43 W 5935099.44 N 711290.21 E 1.251 3503.51 9001.81 27.650 194.120 7549.74 7605.24 2241.28 S 2857.14 W 5935057.29 N 711280.69 E 0.501 3530.67 9095.74 29.580 191.080 7632.20 7687.70 2285.18 S 2866.92 W 5935013.13 N 711272.17 E 2.573 3557.83 9190.90 28.980 191.560 7715.20 7770.70 2330.81 S 2876.05 W 5934967.26 N 711264.33 E 0.677 3585.12 9283.77 30.350 191.870 7795.89 7851.39 2375.82 S 2885.39 W 5934922.00 N 711256.28 E 1 .484 3612.34 9375.58 30.210 189.850 7875.18 7930.68 2421.28 S 2894.11 W 5934876.32 N 711248.85 E 1.120 3639.18 9467.93 30.720 189.670 7954.78 8010.28 2467.42 S 2902.04 W 5934829.97 N 711242.23 E 0.561 3665.60 9561.77 31.850 188.710 8034.97 8090.47 2515.53 S 2909.82 W 5934781.66 N 711235.82 E 1.316 3692.69 9655.43 33.290 188.170 8113.90 8169.40 2565.40 S 2917.22 W 5934731.60 N 711229.84 E 1.568 3720.17 9748.97 34.470 190.150 8191.56 8247.06 2616.87 S 2925.53 W 5934679.91 N 711222.99 E 1.727 3749.15 9842.75 32.760 190.480 8269.66 8325.16 2667.95 S 2934.82 W 5934628.59 N 711215.15 E 1.834 3778.85 16 April, 2004 - 16:16 Page 2 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 03 - 03-07 - 3-07A Your Ref: API 50029202201 Job No. AKMW2978518, Surveyed: 12 April, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9934.97 30.420 189.850 8348.21 8403.71 2715.49 S 2943.36 W 5934580.82 N 711207.97 E 2.562 3806.39 10028.94 28.440 189.850 8430.05 8485.55 2760.98 S 2951.25 W 5934535.13 N 711201.37 E 2.107 3832.51 10120.39 27.190 189.970 8510.93 8566.43 2803.01 S 2958.60 W 5934492.90 N 711195.22 E 1.368 3856.67 10214.83 26.830 192.280 8595.07 8650.57 2845.09 S 2966.87 W 5934450.61 N 711188.15 E 1.174 3881.70 10226.19 27.050 193.100 8605.20 8660.70 2850.11 S 2968.00 W 5934445.56 N 711187.16 E 3.801 3884.82 e 10281.05 27.230 196.100 8654.02 8709.52 2874.32 S 2974.30 W 5934421.18 N 711181.54 E 2.516 3900.63 10310.78 30.030 197.580 8680.11 8735.61 2887.95 S 2978.44 W 5934407.44 N 711177.80 E 9.715 3910.06 10345.19 32.600 204.620 8709.52 8765.02 2904.60 S 2984.90 W 5934390.62 N 711171.81 E 12.984 3922.87 10375.43 33.710 210.260 8734.84 8790.34 2919.25 S 2992.53 W 5934375.75 N 711164.60 E 10.837 3935.90 10403.38 34.830 214.170 8757.94 8813.44 2932.56 S 3000.92 W 5934362.21 N 711156.59 E 8.836 3949.07 10435.87 37.120 216.590 8784.23 8839.73 2948.11 S 3011.98 W 5934346.35 N 711145.98 E 8.295 3965.59 10468.67 41.130 218.450 8809.67 8865.17 2964.51 S 3024.59 W 5934329.60 N 711133.84 E 12.737 3983.89 10497.40 45.430 219.850 8830.58 8886.08 2979.78 S 3037.03 W 5934313.99 N 711121.84 E 15.334 4001.55 10531.45 48.920 219.390 8853.73 8909.23 2999.01 S 3052.95 W 5934294.31 N 711106.47 E 10.297 4024.03 10562.75 50.210 221.300 8874.03 8929.53 3017.16 S 3068.38 W 5934275.72 N 711091.57E 6.209 4045.61 10591.44 53.960 223.020 8891.66 8947.16 3033.93 S 3083.57 W 5934258.53 N 711076.85 E 13.899 4066.40 10625.71 58.580 224.630 8910.68 8966.18 3054.48 S 3103.31 W 5934237.43 N 711057.71 E 14.035 4092.90 10656.72 61.640 225.680 8926.13 8981.63 3073.43 S 3122.37 W 5934217.94 N 711039.19 E 10.295 4118.12 10685.64 66.040 228.670 8938.88 8994.38 3091.06 S 3141.41 W 5934199.78 N 711020.66 E 17.819 4142.77 10720.12 67.920 231.330 8952.37 9007.87 3111.45 S 3165.72 W 5934178.71 N 710996.94 E 8.952 4173.36 10751.20 68.640 232.210 8963.87 9019.37 3129.32 S 3188.40 W 5934160.20 N 710974.77 E 3.505 4201.42 10779.55 70.810 234.190 8973.69 9029.19 3145.25 S 3209.69 W 5934143.68 N 710953.94 E 10.075 4227.41 e 10812.73 74.760 235.290 8983.51 9039.01 3163.54 S 3235.57 W 5934124.66 N 710928.59 E 12.319 4258.55 10844.21 78.560 235.810 8990.77 9046.27 3180.86 S 3260.82 W 5934106.63 N 710903.84 E 12.178 4288.72 10872.43 83.070 236.290 8995.28 9050.78 3196.41 S 3283.93 W 5934090.43 N 710881.19 E 16.069 4316.20 10904.85 89.260 237.270 8997.44 9052.94 3214.12S 3310.97 W 5934071.96 N 710854.66 E 19.330 4348.17 10965.27 91.170 240.430 8997.22 9052.72 3245.37 S 3362.67 W 5934039.25 N 710803.86 E 6.111 4408.18 10999.47 90.310 241.330 8996.78 9052.28 3262.01 S 3392.55 W 5934021.77 N 710774.47 E 3.640 4442.27 11030.69 90.490 242.440 8996.56 9052.06 3276.73 S 3420.08 W 5934006.28 N 710747.37 E 3.602 4473.43 11058.61 90.250 244.000 8996.38 9051.88 3289.31 S 3445.01 W 5933993.00 N 710722.81 E 5.653 4501.33 11092.00 90.190 246.520 8996.25 9051.75 3303.28 S 3475.33 W 5933978.17 N 710692.90 E 7.549 4534.71 11123.40 90.680 248.210 8996.01 9051.51 3315.36 S 3504.31 W 5933965.27 N 710664.27 E 5.604 4566.09 11151.72 91.230 251.350 8995.54 9051.04 3325.15 S 3530.88 W 5933954.74 N 710637.99 E 11.255 4594.32 11185.83 90.190 254.240 8995.12 9050.62 3335.23 S 3563.45 W 5933943.73 N 710605.72 E 9.004 4628.14 11218.50 90.120 256.750 8995.03 9050.53 3343.42 S 3595.08 W 5933934.65 N 710574.33 E 7.686 4660.31 16 April, 2004 - 16:16 Page 3 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 03- 03-07 - 3-07A Your Ref: API 50029202201 Job No. AKMW2978518, Surveyed: 12 April, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 11247.03 90.550 257.390 8994.86 9050.36 3349.80 S 3622.89 W 5933927.48 N 710546.72 E 2.703 4688.25 11340.47 89.690 260.560 8994.66 9050.16 3367.67 S 3714.59 W 5933907.02 N 710455.56 E 3.515 4779.07 11433.84 87.840 267.260 8996.68 9052.18 3377.57 S 3807.35 W 5933894.49 N 710363.12 E 7.442 4867.54 11488.59 88.210 267.070 8998.57 9054.07 3380.27 S 3862.00 W 5933890.24 N 710308.56 E 0.760 4918.36 11527.95 89.630 266.860 8999.31 9054.81 3382.36 S 3901.30 W 5933887.04 N 710269.34 E 3.647 4954.96 e 11575.77 89.810 267.670 8999.54 9055.04 3384.64 S 3949.06 W 5933883.40 N 710221.66 E 1.735 4999.34 11621.84 90.430 266.810 8999.45 9054.95 3386.86 S 3995.08 W 5933879.88 N 710175.73 E 2.301 5042.11 11703.85 90.620 267.810 8998.69 9054.19 3390.70 S 4077.00 W 5933873.71 N 710093.95 E 1.241 5118.19 11718.68 90.560 268.370 8998.54 9054.04 3391.20 S 4091.82 W 5933872.79 N 710079.15 E 3.798 5131.88 11752.50 91.910 269.100 8997.81 9053.31 3391.95 S 4125.62 W 5933871.09 N 710045.39 E 4.538 5162.92 11781.47 92.530 269.200 8996.69 9052.19 3392.37 S 4154.56 W 5933869.83 N 710016.46 E 2.168 5189.42 11811.38 93.330 269.100 8995.16 9050.66 3392.82 S 4184.43 W 5933868.54 N 709986.62 E 2.695 5216.77 11859.37 90.860 270.630 8993.41 9048.91 3392.93 S 4232.38 W 5933867.07 N 709938.69 E 6.053 5260.42 11904.43 90.740 269.940 8992.78 9048.28 3392.71 S 4277.44 W 5933866.02 N 709893.65 E 1.554 5301.29 11997.79 90.250 270.370 8991.97 9047.47 3392.45 S 4370.79 W 5933863.62 N 709800.32 E 0.698 5386.08 12047.97 89.140 268.830 8992.24 9047.74 3392.80 S 4420.97 W 5933861.84 N 709750.18 E 3.783 5431.85 12090.89 89.690 268.830 8992.68 9048.18 3393.68 S 4463.88 W 5933859.75 N 709707.31 E 1.281 5471.23 12145.53 88.700 268.560 8993.44 9048.94 3394.92 S 4518.50 W 5933856.96 N 709652.75 E 1.878 5521.41 12183.37 89.440 266.400 8994.06 9049.56 3396.59 S 4556.29 W 5933854.22 N 709615.02 E 6.033 5556.47 12278.05 91.110 266.130 8993.60 9049.10 3402.76 S 4650.77 W 5933845.37 N 709520.75 E 1.787 5644.95 12370.88 91.110 269.680 8991.81 9047.31 3406.15 S 4743.50 W 5933839.35 N 709428.15 E 3.823 5730.68 12404.39 89.880 272.930 8991.52 9047.02 3405.38 S 4777.00 W 5933839.16 N 709394.65 E 10.369 5760.82 e 12435.36 88.580 275.700 8991.93 9047.43 3403.05 S 4807.88 W 5933840.62 N 709363.72 E 9.879 5787.93 12464.61 89.380 275.610 8992.45 9047.95 3400.17 S 4836.98 W 5933842.67 N 709334.55 E 2.752 5813.19 12498.64 89.630 278.860 8992.75 9048.25 3395.89 S 4870.73 W 5933846.00 N 709300.69 E 9.578 5842.10 12530.24 87.840 280.080 8993.44 9048.94 3390.69 S 4901.89 W 5933850.31 N 709269.39 E 6.855 5868.27 12558.82 87.530 280.380 8994.60 9050.10 3385.62 S 4929.99 W 5933854.58 N 709241.16 E 1.509 5891.72 12593.35 88.460 281.520 8995.81 9051.31 3379.06 S 4963.87 W 5933860.17 N 709207.10 E 4.259 5919.80 12652.08 88.580 286.520 8997.32 9052.82 3364.85 S 5020.82 W 5933872.77 N 709149.78 E 8.513 5965.66 12685.05 89.570 287.930 8997.86 9053.36 3355.08 S 5052.30 W 5933881.63 N 709118.03 E 5.225 5990.23 12715.19 91.230 289.350 8997.65 9053.15 3345.45 S 5080.86 W 5933890.45 N 709089.21 E 7.248 6012.19 12743.61 91.420 289.730 8996.99 9052.49 3335.95 S 5107.64 W 5933899.19 N 709062.18 E 1 .495 6032.58 12778.70 92.350 291.470 8995.83 9051.33 3323.61 S 5140.46 W 5933910.59 N 709029.01 E 5.620 6057.29 12809.34 92.650 291.600 8994.50 9050.00 3312.37 S 5168.94 W 5933921.01 N 709000.23 E 1.067 6078.51 12837.52 92.600 293.480 8993.21 9048.71 3301.58 S 5194.94 W 5933931.06 N 708973.94 E 6.667 6097.66 16 April, 2004 - 16:16 Page 4 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 03 - 03-07 - 3-07A Your Ref: API 50029202201 Job No. AKMW2978518, Surveyed: 12 April, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12872.16 90.060 294.080 8992.40 9047.90 3287.625 5226.62 W 5933944.12 N 708941.86 E 7.534 6120.67 12903.07 89.570 294.600 8992.50 9048.00 3274.88 5 5254.79 W 5933956.05 N 708913.35 E 2.312 6140.97 12931.49 90.060 294.490 8992.60 9048.10 3263.07 S 5280.64 W 5933967.12 N 708887.18 E 1.767 6159.57 12965.68 90.490 295.190 8992.43 9047.93 3248.71 5 5311.66 W 5933980.60 N 708855.75 E 2.403 6181.80 12996.49 91 .480 295.550 8991.90 9047.40 3235.51 S 5339.50 W 5933993.00 N 708827.56 E 3.419 6201.62 e 13024.90 90.990 296.480 8991.29 9046.79 3223.06 5 5365.02 W 5934004.73 N 708801.69 E 3.699 6219.65 13058.39 89.690 295.790 8991.09 9046.59 3208.30 S 5395.09 W 5934018.62 N 708771.22 E 4.395 6240.85 13089.52 89.880 295.340 8991.21 9046.71 3194.875 5423.17 W 5934031 .25 N 708742.76 E 1.569 6260.79 13118.58 89.810 295.760 8991.29 9046.79 3182.345 5449.39 W 5934043.04 N 708716.20 E 1 .465 6279.42 13152.35 90.310 295.840 8991.25 9046.75 3167.645 5479.79 W 5934056.87 N 708685.39 E 1 .499 6300.95 13183.19 90.860 296.740 8990.94 9046.44 3153.985 5507.44 W 5934069.73 N 708657.37 E 3.420 6320.40 13211.66 88.890 297.420 8991.00 9046.50 3141.025 5532.79 W 5934081.97 N 708631.66 E 7.320 6338.06 13244.11 89.510 296.840 8991.45 9046.95 3126.23 S 5561.66 W 5934095.94 N 708602.38 E 2.616 6358.16 13274.77 89.880 296.950 8991.61 9047.11 3112.36S 5589.01 W 5934109.03 N 708574.65 E 1.259 6377.25 13302.24 89.260 297.520 8991.82 9047.32 3099.79 S 5613.43 W 5934120.90 N 708549.88 E 3.066 6394.23 13337.29 89.010 297.990 8992.35 9047.85 3083.47 S 5644.44 W 5934136.33 N 708518.42 E 1.519 6415.64 13368.11 90.060 298.120 8992.60 9048.1 0 3068.97 S 5671.64 W 5934150.05 N 708490.82 E 3.433 6434.34 13396.29 90.620 298.770 8992.43 9047.93 3055.55 S 5696.42 W 5934162.76 N 708465.67 E 3.045 6451.28 13430.45 90.430 299.010 8992.12 9047.62 3039.05 S 5726.33 W 5934178.41 N 708435.31 E 0.896 6471.61 13461.56 90.430 300.040 8991.89 9047.39 3023.71 S 5753.39 W 5934192.97 N 708407.81 E 3.311 6489.85 13488.98 89.690 300.610 8991.86 9047.36 3009.87 S 5777.06 W 5934206.13 N 708383.76 E 3.407 6505.61 13523.62 89.810 301.010 8992.01 9047.51 2992.13 S 5806.81 W 5934223.02 N 708353.52 E 1.206 6525.28 e 13555.08 89.750 301.250 8992.13 9047.63 2975.86 S 5833.74 W 5934238.52 N 708326.14 E 0.786 6543.00 13583.05 90.120 302.350 8992.16 9047.66 2961.13 S 5857.51 W 5934252.58 N 708301.96 E 4.149 6558.48 13617.43 89.810 302.830 8992.18 9047.68 2942.61 S 5886.48 W 5934270.26 N 708272.48 E 1.662 6577.11 13647.37 89.570 303.480 8992.34 9047.84 2926.23 S 5911.55 W 5934285.92 N 708246.96 E 2.314 6593.09 13676.77 90.000 303.820 8992.45 9047.95 2909.94 S 5936.02 W 5934301.51 N 708222.03 E 1.865 6608.57 13770.33 88.210 305.660 8993.92 9049.42 2856.64 S 6012.89 W 5934352.61 N 708143.69 E 2.744 6656.28 13841.00 88.210 305.660 8996.12 9051.62 2815.46 S 6070.28 W 5934392.14 N 708085.15 E 0.000 6691.33 Prosected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska 5tate Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 245.410° (True). 16 April, 2004 - 16:16 Page 5 of6 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 03 - 03-07 - 3-07A Your Ref: API 50029202201 Job No. AKMW2978518, Surveyed: 12 April, 2004 BPXA North Slope Alaska Based upon Minimum Curvature type calculations, at a Measured Depth of 13841.00ft., The Bottom Hole Displacement is 6691.42ft., in the Direction of 245.118° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment e 7894.50 7968.00 13841.00 6701.55 6751.75 9051.62 1756.00 S 1781.25S 2815.46 S 2506.89 W 2554.27 W 6070.28 W Tie-on Point Window Point Prosected Survey Survey tool program for 03-07 - 3-07 A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 13841.00 9051.62 MWD Magnetic (3-07 A) e 16 April, 2004·16:16 Page 60f6 DrillQuest 3.03.06.002 t I J , I I I i I ¡ I I MEMORANDUM e - State of Alaska d2ölf' - () 4-.3 Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~1 611 ~}otr DATE: Wednesday, May 12,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03-07A PRUDHOE BAY UNIT 03-07 A FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv'-...J]1z. i:{¡ I z.{ûtr Comm NON-CONFIDENTIAL 'II API Well Number: 50-029-20220-01-00 Insp No: mitCS040509185336 Inspection Date: 5/9/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 03-07 A Type Inj. P TVD 8524 IA 350 2500 2460 2460 P.T. 2040430 TypeTest SPT Test psi 2131 OA 50 75 75 75 Interval Post Workover Test PIF Tubing 1200 1200 1200 1200 Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. Wednesday, May 12,2004 Page I of I 03-07A MIT-IA Form All, Please find enclosed the MIT-IA form for well 03-07A, the well was recently sidetracked. This is the initial MIT post sidetrack. Please call if you have any questions. Clark Olsen for Joe (907) 659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 «MIT PBU 03-07 05-09-04.xls» Content-Description: MIT PBU 03-07 05-09-04.xls PBU 03-07 OS-09-04.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 5111/20048:15 AM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I DS-03 05/09/04 Clark Olsen Chuck Scheve s P I P v Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form Revised: 06/19/02 2004-0509_MIT _PBU _ 03-07.xls MEMORANDUM e - State of Alaska TO: Alaska Oil and Gas Conservation Commission THRU: Jim Regg P.I. Supervisor ~11 4/Z1(cA- DATE: Thursday, April 29, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03-07 A PRUDHOE BAY UNIT 03-07 A FROM: John Crisp Petroleum Inspector 8rc: Inspector ~"+;'-~~ NON-CONFIDENTIAL API Well Numbe 50-029-20220-01-00 Insp N mitJCr040407091726 Inspection Date: 4/5/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 03-07 A Type Inj. N TVD 8525 IA 0 4000 3900 3900 P.T. 2040430 TypeTest SPT Test psi 2131.25 OA 50 50 50 50 Interval Initial Test PIF Pass Tubing 2500 3150 3150 3150 Notes: Witnessed tubing & IA pressure tests to 4000 psi. 2500 psi was left on tubing during IA pressure test. Tubing was tested to 4000 psi w/ IA open to atmosphere. Tubing was tested to 4000 psi pre IA MIT. MIT IA passed no problems witnessed. Type INJ. Fluid Codes F =FRESH WATER INJ. G=GAS INJ. S=SALT WATER INJ. N=NOT INJECTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=lntemal Radioactive Tracer Survey A= T emprature Anomaly Surve D=Differential Temprature Test Interval 1=lnitial Test 4=Four Year Cycle. V=Required by Variance W=Test during Work over O=Other (describe in notes) Thursday, April 29, 2004 Page 1 of 1 . . FRANK H. MURKOWSKI, GOVERNOR AItASKA. ORAND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 03-07 A BP Exploration (Alaska) Inc. Permit No: 204-043 Surface Location: 1316' NSL, 812' EWL, SEe. 11, TlON, R15E, UM Bottomhole Location: 1463' SNL, 5258' WEL, SEC. 15, TlON, RI5E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you fÌ'om obtaining additional permits or approvals required by law fÌ'om other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to 'tness any required test. Contact the Commission's North Slope petroleum field ins ector 9 3607 (pager). BY ORDER æUE COMMISSION DATED thiSr day of March, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25 005 VJ41\ 31 '3[2-001 o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1316' NSL, 812' EWL, SEC. 11, nON, R15E, UM Top of Productive Horizon: 1939' SNL, 2530' WEL, SEC. 15, T10N, R15E, UM Total Depth: 1463' SNL, 5258' WEL, SEC. 15, nON, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-714073 y-5937379 Zone-ASP4 16. Deviated Wells: Kickoff Depth tª.Qàsing ...Prográl'l'l SiZé Casino 7" 4-1/2" 11b. Current Well Class 0 Exploratory I 0 Stratigraphic Test B Service 5. Bond: 181 Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 12300 TVD 9057 7. Property Designation: ADL 028331 f¡J'td~ 1\ .. l n nt¡ o Development Oil 0 Multiple Zone o De,y~lopm~nt Ga~ I;JSilJ~ e f?Il~".... e :;'. 11.Wêß Name éI~d.N~rn,~er: PBÜ()3~0'1A / 12. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Date: ,/ March 25, 2004 14. Distance to Nearest Property: 20,100' 9. Acres in Property: 2560 Hole 8-1/2" 6-1/8" o 8000 ft Maximum Hole Angle 91 ~ Grade CouDlina Lenath L-80 BTC-M 2421' L-80 IBT 3870' Weiaht 26# 12.6# 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): Plan 55.5 feet N-22A is 602' away at 11250' MD 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3350 psig Surface: 2470 psig ....···CEll'l'le ii S) (jncludino staae data) 169 sx Class 'G' 261"'sx Class 'G' '"I (gç WúA- Tc 0 - . J:I^'.^_ MD TVD MD TVD 7850' 6675' 10271' 8700' 10120' 8570' 14000' 9048' 119. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): I Effective Depth TVD (ft):1 Junk (measured): 11695 9384 11076 11076 I 8926 NIA . . . . . Size ... . . . . IVlLJ. . . : 1VD ~trllr.tlJr::l1 Conductor ^ 75' 2699' 20" 13-3/8" 300 sx Permafrost II (Approx.) 5800 sx Permafrost II 75' 2699' 75' 2699' I iate Prnrlllr:tinn Liner 11669' 9-5/8" 1075 sx Class 'G' 11669' 9365' Perforation Depth MD (ft): 10765' - 11055' 20. Attachments !HI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8694' - 8910' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program a 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name BiIIlsaacson Title Senior Drilling Engineer '1 I Prepared By Name/Number: SiQnature J..-.. -lL. ^. A . Phone 564-5521 Date 3/' 0'1 Terrie Hubble, 564-4628 .:i.<::'i:...::.'.i.:.: ..........f.....:.ii::,··iii:·.·:::.i Permit To Drill API Number: Permit App~yal/ / . f I See cover letter for Number:..2c::::J'1 - o4l.~ 50-029-20220-01-00 Date: 3/Lf /0'7-- I other requirements Conditions of Approval: Samples Required 0 Yes t:&I No Mud Log Required 0 Yes ~ No HYd~~de Measures IS Yes 0 No Directional Survey Required 8Yes 0 No Othec Tt~(t ~ K_rOI7 P$ ¡. M:r:T¡ u~t ß""'-~ tz ¡D~ rei"': Vt d . \)w/'; .-.J F {"" S (IL) (I) I "-l te..- "'"""t.>. r; 0 P'" I < "Í' p.",,/f J . Annroved avo -r -1~Ut " ~ I " I . I . I ~~~~g~~g~'ON Date a/¥h ~ Form 1 0-401 ~ed ~3 ..... - - U ~ IlJ II \! I~ L I Sub.¢it In Dliplicate · . I Well Name: I 083-07 Ai Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Injector /' Surface Location: X = 714,073 Y = 5,937,379 3964' FNL 812' FWL Sec. 11, T10N, R15E Umiat / Target Location: X = 710,829 Y = 5,934,031 TVDss 9002' Ivishak Zone 2 & 3 1939' FNL 2750' FWL Sec. 15, T10N, R15E Umiat Bottom Hole Location: X = 708,088 Y = 5,934,431 TVDss 8992' 1463' FNL 22' FWL Sec. 15, T10N, R15E Umiat / 1 AFE Number: I PBD4P2186 I I Estimated Start Date: 1 03/25/2004 1 ~ 12,300' I I TVD: 19057' 1 1 Rig: 1 Nabors 2ES 1 Operating days to complete: 126.0 ../ I GL: 127.0 I KB: 128.5' I I KBE: 155.5 I Well Design (conventional, slim hole, etc.): I Two String Horizontal Sidetrack /'/ 1 Objective: ¡Ivishak Zone 2 & 3 Directional - Sperry wp07 KOP: 8000' MO Maximum Hole Angle: -470 in the 8-1/2" intermediate section (KOP; 29.80 at section TO) / _910 in the 6-1/8" horizontal section @ TO' All wells pass major risk criteria. The closest well is OS17-07A with a center-to-center distance of 321' and allowable deviation of 202' from the lanned well ath. MWO Standard 20,100' to the nearest P8U propert line N-22A is 602' awa from planned well OS3-07 A at 11,250' planned MO. Close Approach Wells: CasinQITubing Program Hole Size CsgITbg WtlFt Grade Co~ Length Top Btm O.D. ./ MDITVD MDITVD 8-1/2" 7" 26# L-80 8TC-M 2421' 7,850/6,675' 10,271 '/8,700' 6-1/8" 4 }2" 12.6# L-80 18T 3870' 10,120'/8,570' 14,000/9,048' TubinÇ. 4 }2" 12.6# L-80 18T -10,090' GL 10,120'/8,570' OS3-07 Ai Permit to Orill Page 1 . Formation Markers . Formation Tops (wp07) TVDss TVD MD Comments WS1 -6550 6606 CM3 -6810 6866 8130 CM2 -7308 7364 8730 CM1 -8028 8084 9560 THRZ -8404 8460 9993 BHRZ / JKU -8581 8637 10,197 LCU /TJA -8600 8656 10,219 TSGR -8645 8701 10,271 TSHA/TSHU -8660 8716 10,288 TSAO -8750 8806 10,395 45N -8788 8844 10,443 3350 psi @ 8800' TVDss 1. , 42N -8853 8909 10,533 TZ3 -8940 8996 10,687 Zone 2 expected to drop to -9005' ss TZ2C -9001 9057 10,947 iust after penetrating in horizontal HOT/TAR -9010 9066 Not penetrated OWC NR TZ2B NR BSAO NR TO -8992 9048 14,000 TD Criteria: Reach planned XY. If drilling problems are encountered, then a TO decision may be made if there is already >2,500' of wellbore in the horizontal section. FloPro PV 10 g.ç 8-1/2" hole section YP TauO 22-28 3-7 Lo Pro ram 8-1/2" Intermediate: Sample Catchers - None Orillin: Dir/GRlPWD Open Hole: None Cased Hole: USIT 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GRlRes/ABI Open Hole: None Cased Hole: None DS3-07 Ai Permit to Drill Page 2 . . /sack t3/sack Well Control , Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Annular test to 2,500 /' * /. Annular test to 2,500 Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at D5-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to D5-04 for injection. Haul all Class I wastes to Pad 3 for disposal. D53-07 Ai Permit to Drill Page 3 . . Pre-RiQ Work: ./ Perform MITIA. Passed 2500 psi 6/8/03. ./ Perform MITOA. Passed 2000 psi 12/24/03. ./ Test the 9 518" pack-off and tubing hanger seals to 5,000psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. LOS cycled successfully, packett and tubina hanaer failed 1/25/04. 1. Shut in the well and freeze protect as necessary. 2. Allow adequate time for pressure stabilization and shoot a tubing fluid level as per 2/26104 request from B. Carlson. 3. If fluid level is within 200' of surface, perform a static pressure survey and send results to smithpg1 @bp.com Do not return the well to iniection. 4. Pull the 7" WRDP-2 SSSV (WSR indicates last set in 1997). 5. R/U and RIH with coil tubing to plug and abandon (this well has been frac'd so aggregate cement is recommend) the well bore above the PXN plug, up into the 7" X 5 W' tubing tail. Plug and abandon, with 15.8ppg class 'G' cement. Use adequate cement volume to fill the 9 5/8" casing above the PXN plug, plus -100 feet of 5 W' X 7" tubing tail, plus squeeze the open perfs. The estimated minimum cement volume required is 45bbls. 6. R/U slick-line. Drift the 7" X 5 W' tubing to 8,300' md to confirm clear to the required cut depth of 8,100'md. 7. Fluid-pack the 7" X 5 W' tubing and 9 5/8" x 7" x 5 W' annulus to surface. 8. R/U E-line. RIH with the appropriate cutter and cut the 7" tubing at -8,100' md. 9. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 10. Combo test the tubing and IA to 3500 psi. Bleed casing and annulus pressures to zero. 11. Set a BPV. Secure the well. Level the pad as necessary. Ria Operations: 1. Mil RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPVfTWC. 3. Nipple down tree. Nipple up and test BOPE to~psi. Pull BPVfTWC. ./ 4. R/U. Pull 7" tubing from the cut at -8,100' MD anda5ove. -4000 ~ 5. Replace 9 5/8" mandrel packoff and test to 5000 psi 6. M/U 8 1/2" mill BHA. RIH wi drill pipe and tag tubing stump. 7. R/U E-line. RIH with GR/JB to BP setting depth. PU EZSV and set bridge plug as required to avoid cutting casing collar and place top of whip stock at -8,OO~ POOH. RID E-line. 8. Pressure-test the 9 5/8" casing to 4000psi for 30 minutes. Record test. 9. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. 10. Displace the well to 10.4 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. POOH. 11. Orient whip stock, as desired, and set on bridge PJY.g. Shear off of whip stock. 12. Mill window in 9 5/8" casing at ± 8,000' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 13. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg EMW. POOH. /' 14. M/U 8 Y2" Dir/GR/PWD assembly. RIH, kick off and drill the 8 1/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, s~trip to window. POOH. 15. Run and cement a 7",26.0#, L-80 intermediate drilling liner. / 16. Test the 9 5/8" casing X 7" liner to 4000psi for 30 minutes. Record the test. 17. RIU Schlumberger and RIH with appropriate USIT logging tool. Acquire ~and evaluate cement placement and quality. 18. M/U 61/8" Dir/GR/Res assembly. RIH to the landing collar. 19. Drill out the 7" liner float equipment and cement to the shoe. 20. Displace the well to 8.5ppg Flo-Pro drilling fluid. 21. Drill out the 7" shoe plus drill -20' new formation; pull up into the shoe and conduct an FIT to 10.0ppg / EMW. Drill ahead to horizontal landing point. POOH for bit I BHA change. / 22. RIH, drill ahead, according to the directional proposal, to bit end of life. Circulate well bore clean, short trip as necessary. POOH for bit I BHA change, as required. DS3-07 Ai Permit to Drill Page 4 . . 23. RIH, drill ahead, according to the directional proposal, to bit end of life or planned TO of 14,000' md. / 24. Circulate, short trip as necessary, POOH. ./ 25. Run and cement a 4 W', 12.6#, L-80 solid production liner. POOH UO all drill pipe. ./ 26. R/U and run 4 1/2", 12.6#, L-80, TCII completion tubing, including Bal-O SSSV. Circulate and freeze protect prior to setting packer. 27. Set packer and individually test the tubing to 4,OOOpsi and annulus to 4,000psi for 30 minutes. Record each test. . 28. Set a TWC. / 29. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 30. Freeze protect the well to -2,200'. Secure the well. 31. Rig down and move off. Post-RiQ Work: 1. MI / RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. 3. CTO Perforate as per request DS3-07A Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ OS3-07 is positioned in the main row of N-S wells. No wells will require well house removal or shut-in for the rig move onto OS3-07. The closest neighboring wells are OS3-06 and OS3-08, each on 120' centers. ~ DS3 IS a designated H2S site. Standard Operating Procedures for H2S precautions should be ~ followed at all times, including H2S contingency plan posted in the doghouse. Recent H2S data from the pad is as follows: ./" Well Name H2S Reading Date #1 Closest SHL 03-08 35 1/8/2004 #2 Closest SHL 03-14 51 1/9/2004 #1 Closest BHL 03-19 132 6/25/2002 #2 Closest BHL 03-21 167 12/14/2003 The maximum H2S reading on H Pad is 318 ppm on DS3-01 on 9/4/2003. ~ This well has been on injection to-date. Pre-rig operations will include a shut-in tubing fluid level or static pressure survey to ensure BHP data is accurate. Job 2: De-complete Well Hazards and Contingencies ~ OS3-07 has had no caliper logs to indicate the condition of the tubing, however corrosion is not expected since the well has been a dedicated injector since the tubing change out in 1991. The 7" tubing is IPC and should be junked after pulling. ~ The 9 5/8" Baker FB-1 packer was set on OP during the 1991 RWO after displacing the well to clean seawater. If the pre-rig cut is incomplete, the seal assembly may pull out of the packer, though the tailpipe will be cemented at that depth. ~ Pre-Rig operations will include P&A'ing the well with cement. After the cement work and tubing cut, the wellbore will be fluid packed, pressure tested & freeze protected. OS3-07 Ai Permit to Drill Page 5 . . ~ The cement and kill-weight seawater will serve as the two barriers while changing out the 9 5/8" mandrel packoff. Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. ~ The 9 5/8" casing was cemented with 1075 sacks of 15.5 ppg class G cement. The 9 5/8" x 13 3/8" annulus was cemented through the lower Fa at 2446' with 275 sacks PF "C" @ 15.6 ppg. The annulus was then freeze protected with 344 bbls Arctic Pack through the upper Fa at 2326' to surface. There is no CBL on record; assuming 1.2 ft3/sk yield, TOC should be at 500' above KOP with gauge hole or 500' below KOP with 30% washout in the 12 W' hole. The KOP in the West Sak will be more forgiving than Colville below if the annulus is not cemented. Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in the West Sak, ±130' above the Colville CM3, and drill through the Kingak shale package and TO at the top of Sag River. Since OS3-07 A will be at -300 inclination and a favorable azimuth, 10.4 ppg mud weight should provide ample overbalance fo the Kingak and HRZ shales. Follow all shale drilling practices to minimize potential problems. ~ The well plan is not expected to cross any faults in this hole section. The original well was drilled with a maximum mud weight of 10.2 ppg with no reported losses. ~ KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gradient of 12.5 ppg at the 9-5/8" casing window, and 10.4 ppg mud in the hole, the kick tolerance is Infinite./" Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ A single fault in the Zone 2 sands will be crossed in this hole section. The fault could intersect from 11,300 to 11,650 ft MD. The fault is down-thrown to the west. Approx. 2,500' MO of well bore is to the West of this fault and in the event of lost circulation this interval can still be completed and will provide a sufficient length through the target for a successful well. ~ Formation tops are given as they will be encountered during drilling, and are not intended to represent the formation tops throughout the whole length of the wellbore. ~ All polygon lines should be considered hardlines - most hardlines are to maintain adequate standoff from the nearby wells. ~ The horizontal section will be drilled -10' tvd above the HOT, and so structural tops are not as critical for steering in this well. Much of the section will be drilled within Zone 3, which may result in low Rap because of the conglomeratic nature of this interval. ~ The wellbore is designed to mitigate but not eliminate drilling hazards due to faulting and achieve sufficient a target section capable to inject 5 equally spaced MI bulbs at -500' intervals. ~ KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradient of 9.5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance is Infinite. // OS3-07 Ai Permit to Drill Page 6 . . Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Job 12: Run Completion Hazards and Contingencies ~ ~iesel will be used to freeze protect the well. The diesel flash point is 1000 F. ~iesel vapor pressure is - 0.1 psia at 1000 F. Job 13: ND/NUlRelease Ria Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move off of 083-07. 8ee Job 1 for nearby well data and use spotters for moving the rig. 083-07 Ai Permit to Drill Page 7 TREE';' McEvoy . I SAFETY NOTES: PlUG AT 11076' I WELLHEAD: FMC Gen 1 03-07 ACTUA TOR: AXB...SON KB. B...EV : 61' BF. B...EV : KOp: 3200' Max Angle: 48 @ 8800' Datum MD : 10989' DatumTVD: 8800' SS e -- l 2166' 1---1 7" CAMeO BAL-O SSSV NIP, ID: 5.937" I 13-3/8" CSG, 72#, MN-80, ID: 12.347" I 2699' I J ~ I 7" TBG-IPC, 26#, L-80, 0.0383 bpf , ID: 6.276" I 10569' I 10569' 1---1 7" X 5-1/2" XO I TOPOF 5-1/2" TBG-IPC I 10569' I . 10571' 1--1 5-1/2" OTIS X NIP, ID - 4.562" I Minimum ID = 4.455 @ 10618' , ~ 10578' --1 5-1/2" BAKER DB-1 SEAL ASSY I 5-1/2" XN NIPPLE ~ Z ~ 10587' 9-5/8" X 5-112" BAKER FB-1 PKR, ID: 6.000" I 10618' 1---1 5-1/2" OTIS XN NIP NOGO, ID - 4.455" I I 5-112" TBG-IPC, 17#, L-80, 0.0232 bpf , ID: 4.892" I 10623' ~ t-- 10623' ---1 5-1/2" TUBING TAIL I PERFORA TION SUMMARY I 10618' 1---1 B...MD TT LOGGED 10/17/91 I REF LOG: BHCS on 10/07/76 ANGLE AT TOP PERF: 42 @ 10765' [ Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE ~ 3-3/8' 4 10765-10802 0 05/10/87 3-1/2" 4 10914-10958 0 06/27/97 3- 3/8" 4 1 0965-11 006 0 09/09/85 ~ 3-3/8" 4 11010-11032 0 11/21/94 3-318" 4 11035-11055 0 11/21/94 ~ 3-1/8" 4 11098-11103 C 02/20/92 2-7/8" 4 11114-11130 C 02/20/92 ~ 2-7/8" 4 11130-11139 S 08/30/85 2-7/8" 4 11154-11179 S 08/30/85 ITOPOF 4-1/2" TBG-IPC I 11070' I I 11070' 1---1 9-5/8" X 4-1/2" BAKER FB-1 PKR I W IPBTDI 11076' I H 11076' 4-1/2" OTIS XN NIP ID: 3.725" I W/PXN PlUG SET 2-20-92 14-1/2" TBG-IPC, 12.6#, L-80. 0.0152 bpf, ID: 3.958" I 11078' 11077' 1--1 4-112" TUBING TAIL I I I I 1 9-5/8" CSG, 47#, MN-80. ID: 8.681" I 11669' I ~ ~ 11695' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 10/20/76 ORIGINAL COMPlETION WELL: 03-07 06/15/91 LAST WORKOVER PERMIT No: 76-053 12/19/00 SIS-QAA CONVERTED TO CANVAS API No: 50-029-20220-00 01/05/00 SIS-MD FINAL SEC11 T10N R15E4171.95 FEL 1461.57 FNL OS/21/01 RNlTP CORRECTIONS BP Exploration (Alaska) 03-07 P.t Rig Operation / 19 5/8" FO Cementer 1-1 2325' 19 5/8" FO Cementer l-i 2446' 13-3/8" CSG, 72#, 1 2699' MN-80, 10 = 12.347" 7" TBG-IPC, 26#. L- 13 80,0.0383 bpf , ID 10569' = 6.276" 1 Pre rig Chernicai cut l---i 8,100' 1 Pre rig cement P&A 1-1 10,500' 7" X 51/2" XO; TOPOF 1 10569' 5-1/2" TBG-IPC 1 10623' ITOPOF 4-1/2" TBG-IPC 1-1 11070' 5-112" TBG-IPC, 17#, L-80 11070' 9-5/8" X 4-1/2" BA KER FB-1 PKR 11076' I 4-112" OTIS XN NIP ID = 3.725" W/PXN Rug set 2/20/92 9-5/8" CSG, 47#, MN----1 11669' 80, ID = 8.681" I ~-i 11695' DATE REV BY COMMENTS 10/20/76 ORIGINAL COMA...ErION 06/15/91 LAST WORKOVER 12/19/00 SIS-QAA CONVERTED TO CANVAS 01/05/00 SIS-MO FINAL OS/21/01 RNITP CORRECTIONS - 2166' 7" CAMCO BAL-O SSSV NIP, ID = 5.937" TREE = McEVOY WELLHEAO= FMC GEN 1 ·~"~?V^-M~"M.·.'~,~._.·.·.·.·uu ACTUA TOR= AXELSON KB. ELEV = 61.0' -~~M"~~~'~A_·_~~_'WAW~·~~~~~u CB. ELEV = Assumed 27.0' KÕP;'~~~~~~~32ÖO' Max' Añg¡e~'48 @ 8ã¡Yo' Batum MD = ~~-~'-1Õ989; Datum 1VD= 8800' SS I SA FETY NOTES: A...UG AT 11076' Minimum ID = 4.455 @ 10618' 5-1/2" XN NIPPLE 10571' 1---1 5-1/2" OTIS X NIP, 10 = 4.562" I 10578' l-i 5-112" BAKER OB-1 SEAL ASSY 10587' l-i 9-5/8" X 5-1/2" BAKER FB-1 PKR, 10 = 6.000" 10618' l-i 5-112" OTIS XN NIP NOGO, ID = 4.455" 1 PERFORA TION SUMMARY REF LOG: BHCS on 10/07/76 ANGLE AT TOP PERF: 42 @ 10765' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8' 4 10765-10802 0 05/10/87 3-1/2" 4 10914-10958 0 06/27/97 3-3/8" 4 10965-11006 0 09/09/85 3-3/8" 4 11010-11032 0 11/21/94 3-318" 4 11035-11055 0 11/21/94 3-1/8" 4 11098-11103 C 02/20/92 2-7/8" 4 11114-11130 C 02/20/92 2-7/8" 4 11130-11139 S 08/30/85 2-7/8" 4 11154-11179 S 08/30/85 DATE REV BY COMMENTS 01/26/04 dew Proposed pre rig work. PRUDHOE BAY UNfT WELL: 03-07 PERMfT No: 76-053 API No: 50-029-20220-00 SEC11 T10N R15E4171.95 FEL 1461.57 FNL BP Exploration (Alaska) 03-07 A Pr~osed Comple 19 5/8" FO Cementer 19 5/8" FO Cementer 1-1 l-i 1 2325' 2446' 13-3/8" CSG, 72#, MN-80, ID = 12.347" 2699' 41/2" 12.6# L-80 TC-II Tubing E 7" X 51/2" XO; TOPOF -1 10569' I 5-112" TBG-IPC I 1 10623' ITOPOF 4-112" TBG-IPC l-i 11070' 5-112" TBG-IPC, 17#, L-80 11070' 9-518" X 4-112" BA KER FB-1 PKR I 11076' 4-1/2" OTIS XN NIP ID = 3.725" W/PXN Plug set 2/20/92 9-5/8" CSG, 47#, MN- -1 11669' 80, ID = 8.681" I ~-i 11695' DA TE REV BY COMMENTS 10/20/76 ORIGINAL COMPLETION 06/15/91 LAST WORKOVER 12/19/00 SIS-QAA CONVERTED TO CANVAS 01/05/00 SIS-MD FINAL OS/21/01 RN/TP CORRECTIONS // TREE = McEVOY WELLHEAD= FMC GEN 1 ~m~h·,.~·.·~~mmm'~.~·,··" ACTUA TOR= AXELSON ~~~=~~="=,w,, ·'~"W·'~'",~m'Wm~W,'W KB. ELEV = 61.0' .·"_~~m~~h~~~mmmm,~.w."m_·_.·'mm'_·mmmmµmA_U__'A~~U'NN CB. ELEV = Assumed 27.0' "Kop,;;"···········································s:oõo·, -.wµm.·,·~""".,wm.w.~,·.'.w^W."M'W,mWm"w=m,'w~w.w.wm=',',~.__ Max Angle =90°+ @ 10,955' Dalum·M5;;·"···.."·:¡õ:4Ifò"';" v~,,=""""=''''~my,',w,'^~~y,W,'~y,Wm^~_' Datum TVD= 8800' SS . 11 4 1/2" SSSV Nipple 2200' 7,850' I 9 5/8" X 7" Baker HMC Lnr hngr and ZXP pkr with TBS . ~()O" 10,055' H4 1/2" 'X' landing nipple, ID = 3.813" I 10,075' 1-i7" X 41/2" Baker S-3 packer 10,095' H4 1/2" 'X' landing nipple, ID = 3.813" 10,110' 1-14 1/2'''XN' landing nipple, ID = 3.725" I 10 120' I 7" X 5" Baker HMC Liner hngr , and ZXP pkr with TBS I 10,271' H7", 26.0#, L-80, BTC-M liner 1 14,000' H4 1/2", 12.6#, L-80, IBT-M liner DATE REV BY COMMENTS 02/26/04 PGS Proposed completion Wp07 PRUDHOE BA Y UNIT WELL: 03-07A ÆRMIT No: API No: 50-029-20220-01 SEC11 T10N R15E4171.95 FEL 1461.57 FNL BP Exploration (Alaska) REFERENCE INFORMA nON SURVEY PROGRAM Plan: OJ-07A wp07 (OJ-07/Plan OJ-07 A) Co-ordinate (N/E) Reference: Well Centre: 03-01, True North Depth Pm Deplh To SurvcyiP an Tool Crealcd By: Ken Allen Date: 2/25/2004 V~t~~T~? ::~=~; ~¡~~:~¡~I,~~~:gOOE) 8000.00 14000.58 Platmed: 03-o7A wp01 V5 MWD Checked: Date:_ Meas~a~~k~o'::~~~~ ~~~~~t~·50 Reviewed: Date:_ CASING DETAILS WELL DETAILS N= +N/-S +EI-W Northing Easting Latitude Lúngitude Slot No. TVD MD Name Size OJ-01 -1889.99 1132.12 5931318.76 114013.07 10013'54.620N 148°16'18.421W 07 6773.55 8000.00 9518" 9.625 TARGET DETAILS 8700.50 10271.16 7" 7.000 9047.50 14000.57 4 112" 4.500 N= TVD +N/-S +EI-W Northing Easting Shape 3-01A Tgt3a 9041.50 -2116.82 -6066.63 5934431.01 708081.99 Point 3-07A TglJa 9051.50 -3254.49 -3331.95 5934031.00 710828.99 Point FORMATION TOP DETAILS 3-o7APoly 9051.50 -1346.12 -2121.51 5935956.00 111390.99 Polygon 3-07A Tgt2a 9057.50 -3520.16 -511530 5933115.01 709059.99 Point No. TVDPath MDPath Fonnation SECTION DETAILS I 6865.50 8130.74 CM3 2 7363.50 8730.47 CM2 See MD Ine Azi TVD +NI-S +EI-W DLeg TFaee VSee Target 3 8083.50 9560.16 CMI 4 8459.50 9993.45 THRZ I 8000.00 47.12 241.91 6773.55 -1792.36 -2574.95 0.00 0.00 3087.31 5 8636.50 10197.41 BHRZIJKU 2 8020.00 47.37 238.66 6787.13 -1799.64 -2587.70 12.00 -85.00 3101.93 6 8655.50 10219.31 LCUrrJA 3 8567.10 29.80 192.37 7221.73 -2043.81 -2794.41 6.00 -138.49 3391.51 7 8700.50 10271.16 TSGR 4 10314.87 29.80 192.37 8738.43 -2892.18 -2980.41 0.00 0.00 3913.72 8 8715.50 ¡ 0288.45 TSHNrSHU 5 10955.20 90.00 240.00 9057.50 -3254.49 -3337.95 11.00 51.64 4389.62 3-07A Tgt 1a 9 8805.50 10394.64 TSAD 6 11327.76 90.00 262.35 9057.50 -3373.93 -3688.36 6.00 90.00 4757.95 10 8843.50 10442.78 45N 7 12471.99 90.00 262.35 9057.50 -3526.18 -4822.42 0.00 0.00 5852.48 11 8908.50 10533.22 42N 8 12766.10 90.00 280.00 9057.50 -3520.16 -5115.30 6.00 90.00 6116.29 3-07A Tgt 2a 12 8995.50 10687.44 TZ3 9 13388.28 90.61 317.33 9054.05 -3226.98 -5651.63 6.00 88.99 6481. 94 10 14000.58 90.61 317.33 9047.50 -2776.82 -6066.63 0.00 0.00 6671.94 3-07A Tgt 3a COMPANY DETAILS ISpeI"'r'\,I-!llUn Q1'i:r¡';'~!~:~:~:,!;!~.~:i SP Ainoco Calcullltiou Method: Minimum Curvature Error System: JSCWSA Scan Method: Trav Cylinder North Error Surface: Elliptiall+Casing Wamin Method: Rules Based :F '" o ~ -" õ. Ö "5 t, > " ~ f: .,/' 800 850 900 3000 3500 4000 4500 5000 5500 Vertical Section at 245.41" [500ftlin] '/<q, ,f' ,'~ # -" °3.:~::::,,:1'.'>2m 000 6000 7500 7000 spar>r>y-s..n ';rJ!\ïJ';:j,:JJ¡.W:::J_JO'ÌVJt:..~ BP Amoco REFERENCE INFORMA nON SURVEY PROGRAM PI"", 03-07A wp07 (03-07/PI"" 03-07A) Co-ordinate (N/E) Reference: Well Centre: 03-07, True North Depth I'm Depth To Survey/Plan Too] Created By: Ken Allen Date: 2/2512004 Vertical (TVD) Reference: 03-07A plan 55.50 SectiOl1 (VS) Reference: Slot - 07 (O.OON,O.OOE) 8000.00 14000.58 Plannod: 03-ú7A wp07 V5 MWD Checked; Date Measured Depth Reference: 03·07 A plan 5550 Calculation Method: Minimum CUlVdture Reviewed: Date' WELL DETAILS FORMATION TOP DETAILS Nmno +N/-S +E/·W Northing Eastillg Latitude umgitude Slot No. TVDPath MDPath F onnation 03-07 -1889.99 1732.72 5937378.76 714073.07 7Qo13'54.620N 148°16'18.427W 07 1 6865.50 8130.74 CM3 TARGET DETAILS 2 7363.50 8730.4 7 CM2 Name TVD +N/-S +EI-W 3 8083.50 9560.16 CMI Northing EasLing Shape 4 8459.50 9993.45 THRZ 3-07A TgtJa 9047.50 -2776.82 -6066.63 5934431.01 708087.99 Poil11 5 8636.50 10197.41 BHRZ/JKU 3-07A TgI la 9057.50 -3254.49 -3337.95 5934031.00 710828.99 Point 3-07APoly 9057.50 -1346.12 -2721.51 5935956.00 711390.99 Polygon 6 8655.50 10219.31 LCUrrJA 3-07A Tgt2a 9057.50 -3520.16 -5115.30 5933715.01 709059.99 Point 7 8700.50 10271.16 TSGR 8 8715.50 10288.45 TSHAffSHU SECTION DETAILS 9 8805.50 10394.64 TSAD 10 8843.50 10442.78 45N See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target II 8908.50 10533.22 42N 12 8995.50 10687.44 TZ3 I 8000.00 47.12 241.91 6773.55 -1792.36 -2574.95 0.00 0.00 3087.31 2 8020.00 47.37 238.66 6787.13 -1799.64 -2587.70 12.00 -85.00 3101.93 CASING DETAILS 3 8567.10 29.80 192.37 7221.73 -2043.81 -2794.41 6.00 -138.49 3391.51 4 10314.87 29.80 192.37 8738.43 -2892.18 -2980.41 0.00 0.00 3913.72 No. TVD MD Name Size 5 10955.20 90.00 240.00 9057.50 -3254.49 -3337.95 11.00 51.64 4389.62 3-07A Tgt la 6 11327.76 90.00 262.35 9057.50 -3373.93 -3688.36 6.00 90.00 4757.95 6773.55 8000.00 95/8" 9.625 7 12471.99 90.00 262.35 9057.50 -3526.18 -4822.42 0.00 0.00 5852.48 8700.50 10271.16 7" 7.000 8 12766.1 0 90.00 280.00 9057.50 -3520.16 -5115.30 6.00 90.00 6116.29 3-07A Tgt 2a 9047.50 14000.57 41/2" 4.500 9 13388.28 90.61 317.33 9054.05 -3226.98 -5651.63 6.00 88.99 6481.94 10 14000.58 90.61 317.33 9047.50 -2776.82 -6066.63 0.00 0.00 6671.94 3-07A Tgt 3a COMPANY DETAILS Calculation Method: Minimum Curvature Eoor System: ISCWSA Scan Method: Trav Cylinder North Eoor Surface: Elliptical + Casing Wamin Method; Rules Based I I I I I I 1,/ I I I l" ',X , "<'" ,.>.../:.":> ., ,,'¿-'/ . , ';'<, , .. -140 : : . i · . . , / ; : : · , -k .// 10- .. .....,......,...... ..... . IPY I : 5/~ . I Di / Dir 10- / / / /,> ,vV' '0 <'T{[ / . ¿-::[ / j"' .// ~ / 7' /8 // ~ // 'V . \ ~ ~\," \. / ita )ifl 1100' : ~ ~ ~-~ ~. . "00 '0' rVD ~ /// . . / . // 'V . , // --:: -~. · n;,¡;/100' --------- ---. --------. ..--- .-- I , , , -210 £' ¢: o Ë :£ .<: t: ~ ..c -280 Eí o '" -350 -6300 -5600 -4900 -4200 -3500 West(-)lEast(+) [700ft/in] -2800 -2100 -1400 5ipE!""""~-5iun DRILLING SERVices . . Sperry-Sun - Draft Copy KW A Planning _~ HAlLllIllHO~ cO).IPA.....:'\.' Yes Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB OS 03 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5939219.13 ft 712287.91 ft Latitude: 70 14 Longitude: 148 17 North Reference: Grid Convergence: 13.210 N 8.774 W True 1.61 deg Well: 03-07 Slot Name: 07 03-07 Well Position: +N/-S -1889.99 ft Northing: 5937378.76 ft Latitude: 70 13 54.620 N +E/-W 1732.72 ft Easting : 714073.07 ft Longitude: 148 16 18.427 W Position Uncertainty: 0.00 ft Wellpath: Plan 03-07A 500292022001 Current Datum: 03-07 A plan Magnetic Data: 3/15/2004 Field Strength: 57603 nT Vertical Section: Depth From (TVD) ft 28.50 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 03-07 8000.00 ft Mean Sea level 25.51 deg 80.87 deg Direction deg 245.41 Height 55.50 ft Casing Points 8130.74 6865.50 CM3 0.00 0.00 8730.47 7363.50 CM2 0.00 0.00 9560.16 8083.50 CM1 0.00 0.00 9993.45 8459.50 THRZ 0.00 0.00 10197.41 8636.50 BHRZ/JKU 0.00 0.00 10219.31 8655.50 lCU/T JA 0.00 0.00 10271.16 8700.50 TSGR 0.00 0.00 10288.45 8715.50 TSHA/TSHU 0.00 0.00 10394.64 8805.50 TSAD 0.00 0.00 10442.78 8843.50 45N 0.00 0.00 10533.22 8908.50 42N 0.00 0.00 10687.44 8995.50 TZ3 0.00 0.00 Targets 3-07A Tgt 3a 3-07A Tgt 1a 9047.50 -2776.82 -6066.63 5934431.01 708087.99 70 13 27.286 N 148 19 14.638 W 9057.50 -3254.49 -3337.95 5934031.00 710828.99 70 13 22.605 N 148 17 55.375 W spa""""y-sun DRIL.L.ING SeRvlc:es . . Sperry-Sun - Draft Copy KW A Planning _" lL\l-LI81'RTON COMPAl'I:\' 3-07 A Poly 9057.50 -1346.12 -2721.51 5935956.00 711390.99 70 1341.376 N 148 17 37.491 W -Polygon 1 9057.50 -1346.12 -2721.51 5935956.00 711390.99 70 1341.376 N 148 17 37.491 W -Polygon 2 9057.50 -2274.14 -1326.22 5935068.00 712811.99 70 13 32.252 N 148 16 56.951 W -Polygon 3 9057.50 -3705.29 -3281.72 5933582.00 710897.99 70 13 18.171 N 148 17 53.736 W -Polygon 4 9057.50 -3960.24 -4485.50 5933293.00 709701.99 70 13 15.658 N 148 18 28.692 W -Polygon 5 9057.50 -3556.69 -5731.61 5933661.00 708444.99 70 13 19.618 N 148 19 4.890 W -Polygon 6 9057.50 -2794.22 -6546.33 5934400.00 707608.99 70 1327.111 N 148 19 28.571 W -Polygon 7 9057.50 -2453.82 -5850.36 5934760.00 708294.99 70 13 30.464 N 148 19 8.363 W -Polygon 8 9057.50 -3038.61 -5373.74 5934189.00 708787.99 70 13 24.716 N 148 18 54.507 W -Polygon 9 9057.50 -2768.62 -3431.20 5934514.00 710721.99 70 13 27.383 N 148 17 58.090 W 3-07A Tgt 2a 9057.50 -3520.16 -5115.30 5933715.01 709059.99 70 13 19.982 N 148 18 46.991 W Plan Section Information 8000.00 47.12 241.91 6773.55 -1792.36 -2574.95 0.00 0.00 0.00 0.00 8020.00 47.37 238.66 6787.13 -1799.64 -2587.70 12.00 1.28 -16.25 -85.00 8567.10 29.80 192.37 7221.73 -2043.81 -2794.41 6.00 -3.21 -8.46 -138.49 10314.87 29.80 192.37 8738.43 -2892.18 -2980.41 0.00 0.00 0.00 0.00 10955.20 90.00 240.00 9057.50 -3254.49 -3337.95 11.00 9.40 7.44 51.64 3-07A Tgt 1a 11327.76 90.00 262.35 9057.50 -3373.93 -3688.36 6.00 0.00 6.00 90.00 12471.99 90.00 262.35 9057.50 -3526.18 -4822.42 0.00 0.00 0.00 0.00 12766.10 90.00 280.00 9057.50 -3520.16 -5115.30 6.00 0.00 6.00 90.00 3-07A Tgt 2a 13388.28 90.61 317.33 9054.05 -3226.98 -5651.63 6.00 0.10 6.00 88.99 14000.58 90.61 317.33 9047.50 -2776.82 -6066.63 0.00 0.00 0.00 0.00 3-07A Tgt 3a Survey 8000.00 47.12 241.91 6773.55 6718.05 5935514.13 711550.15 3087.31 0.00 0.00 0.00 95/8" 8020.00 47.37 238.66 6787.13 6731.63 5935506.49 711537.61 3101.93 14.69 12.00 275.00 MWD 8050.00 46.04 237.00 6807.71 6752.21 5935494.35 711519.47 3123.58 36.52 6.00 221.51 MWD 8100.00 43.87 234.07 6843.09 6787.59 5935473.56 711490.92 3158.37 71.84 6.00 222.64 MWD 8130.74 42.57 232.15 6865.50 6810.00 5935460.46 711474.45 3178.94 92.89 6.00 224.72 CM3 8150.00 41.78 230.90 6879.77 6824.27 5935452.13 711464.56 3191.49 105.82 6.00 226.12 MWD 8200.00 39.78 227.47 6917.64 6862.14 5935430.12 711440.45 3222.84 138.48 6.00 227.04 MWD 8250.00 37.90 223.75 6956.58 6901.08 5935407.58 711418.67 3252.34 169.83 6.00 229.64 MWD 8300.00 36.14 219.71 6996.51 6941.01 5935384.58 711399.28 3279.91 199.94 6.00 232.54 MWD 8350.00 34.53 215.33 7037.31 6981.81 5935361.19 711382.32 3305.46 228.85 6.00 235.77 MWD 8400.00 33.09 210.60 7078.86 7023.36 5935337.45 711367.84 3328.93 256.67 6.00 239.34 MWD 8450.00 31.84 205.52 7121.05 7065.55 5935313.45 711355.88 3350.26 283.51 6.00 243.27 MWD 8500.00 30.80 200.10 7163.77 7108.27 5935289.25 711346.49 3369.39 309.50 6.00 247.56 MWD 8550.00 30.01 194.38 7206.90 7151.40 5935264.90 711339.67 3386.26 334.81 6.00 252.19 MWD 8567.10 29.80 192.37 7221.73 7166.23 5935256.56 711337.93 3391.51 343.33 6.00 257.13 MWD 8600.00 29.80 192.37 7250.28 7194.78 5935240.50 711334.89 3401.34 359.68 0.00 0.00 MWD 8700.00 29.80 192.37 7337.06 7281.56 5935191.68 711325.63 3431.22 409.37 0.00 0.00 MWD 8730.47 29.80 192.37 7363.50 7308.00 5935176.80 711322.80 3440.32 424.51 0.00 0.00 CM2 8800.00 29.80 192.37 7423.84 7368.34 5935142.86 711316.37 3461.10 459.07 0.00 0.00 MWD 8900.00 29.80 192.37 7510.62 7455.12 5935094.04 711307.11 3490.97 508.76 0.00 0.00 MWD 9000.00 29.80 192.37 7597.40 7541.90 5935045.22 711297.85 3520.85 558.45 0.00 0.00 MWD 9100.00 29.80 192.37 7684.18 7628.68 5934996.40 711288.59 3550.73 608.14 0.00 0.00 MWD 9200.00 29.80 192.37 7770.95 7715.45 5934947.58 711279.33 3580.61 657.84 0.00 0.00 MWD 9300.00 29.80 192.37 7857.73 7802.23 5934898.76 711270.07 3610.49 707.53 0.00 0.00 MWD 9400.00 29.80 192.37 7944.51 7889.01 5934849.94 711260.81 3640.37 757.22 0.00 0.00 MWD 5pe~~~-5un DRIL.LING SERVI'=ES . . Sperry-Sun - Draft Copy KW A Planning _" IMlUOnnQ" COMPA]'.,\, 9500.00 29.80 192.37 8031.29 7975.79 5934801.12 711251.55 3670.25 806.91 0.00 0.00 MWD 9560.16 29.80 192.37 8083.50 8028.00 5934771.75 711245.98 3688.22 836.81 0.00 0.00 CM1 9600.00 29.80 192.37 8118.07 8062.57 5934752.30 711242.29 3700.13 856.61 0.00 0.00 MWD 9700.00 29.80 192.37 8204.85 8149.35 5934703.48 711233.03 3730.00 906.30 0.00 0.00 MWD 9800.00 29.80 192.37 8291.63 8236.13 5934654.66 711223.77 3759.88 955.99 0.00 0.00 MWD 9900.00 29.80 192.37 8378.41 8322.91 5934605.84 711214.51 3789.76 1005.69 0.00 0.00 MWD 9993.45 29.80 192.37 8459.50 8404.00 5934560.22 711205.86 3817.68 1052.12 0.00 0.00 THRZ 10000.00 29.80 192.37 8465.19 8409.69 5934557.02 711205.25 3819.64 1055.38 0.00 0.00 MWD 10100.00 29.80 192.37 8551.97 8496.47 5934508.20 711195.99 3849.52 1105.07 0.00 0.00 MWD 10197.41 29.80 192.37 8636.50 8581.00 5934460.64 711186.97 3878.62 1153.48 0.00 0.00 BHRZ/JKU 10200.00 29.80 192.37 8638.75 8583.25 5934459.38 711186.73 3879.40 1154.76 0.00 0.00 MWD 10219.31 29.80 192.37 8655.50 8600.00 5934449.95 711184.94 3885.17 1164.36 0.00 0.00 LCU/T JA 10271.16 29.80 192.37 8700.50 8645.00 5934424.64 711180.14 3900.66 1190.13 0.00 0.00 7" 10288.45 29.80 192.37 8715.50 8660.00 5934416.20 711178.54 3905.82 1198.72 0.00 0.00 TSHAlTSH 10300.00 29.80 192.37 8725.53 8670.03 5934410.56 711177.47 3909.28 1204.46 0.00 0.00 MWD 10314.87 29.80 192.37 8738.43 8682.93 5934403.30 711176.09 3913.72 1211.85 0.00 0.00 MWD 10350.00 32.32 198.04 8768.53 8713.03 5934385.71 711171.81 3925.33 1229.97 11.00 51.64 MWD 10394.64 35.85 204.15 8805.50 8750.00 5934362.17 711163.43 3943.25 1254.98 11.00 46.78 TSAD 10400.00 36.29 204.81 8809.84 8754.34 5934359.26 711162.20 3945.64 1258.14 11.00 41.71 MWD 10442.78 39.93 209.64 8843.50 8788.00 5934335.49 711150.76 3966.41 1284.54 11.00 41.18 45N 10450.00 40.57 210.38 8849.01 8793.51 5934331.39 711148.54 3970.21 1289.20 11.00 37.37 MWD 10500.00 45.07 215.04 8885.68 8830.18 5934302.34 711130.96 3998.81 1323.18 11.00 36.81 MWD 10533.22 48.15 217.73 8908.50 8853.00 5934282.53 711117.20 4019.92 1347.31 11.00 33.39 42N 10550.00 49.73 219.00 8919.52 8864.02 5934272.38 711109.62 4031.20 1359.97 11.00 31.54 MWD 10600.00 54.52 222.45 8950.22 8894.72 5934241.80 711084.72 4067.05 1399.43 11.00 30.71 MWD 10650.00 59.38 225.50 8977.48 8921.98 5934210.86 711056.48 4106.06 1441.32 11.00 28.59 MWD 10687.44 63.07 227.59 8995.50 8940.00 5934187.64 711033.31 4137.11 1474.13 11.00 26.92 TZ3 10700.00 64.32 228.26 9001.07 8945.57 5934179.86 711025.17 4147.85 1485.39 11.00 25.91 MWD 10750.00 69.30 230.80 9020.75 8965.25 5934149.08 710991.07 4192.04 1531.34 11.00 25.62 MWD 10800.00 74.31 233.18 9036.36 8980.86 5934118.80 710954.50 4238.23 1578.82 11.00 24.62 MWD 10850.00 79.35 235.44 9047.75 8992.25 5934089.30 710915.79 4285.99 1627.49 11.00 23.87 MWD 10900.00 84.41 237.63 9054.81 8999.31 5934060.86 710875.30 4334.88 1676.98 11.00 23.36 MWD 10950.00 89.47 239.78 9057.48 9001.98 5934033.74 710833.41 4384.45 1726.89 11.00 23.05 MWD 10955.20 90.00 240.00 9057.50 9002.00 5934031.00 710828.99 4389.62 1732.09 11.00 22.93 3-07A Tgt 1 11000.00 90.00 242.69 9057.50 9002.00 5934008.42 710790.31 4434.30 1776.89 6.00 90.00 MWD 11050.00 90.00 245.69 9057.50 9002.00 5933985.38 710745.94 4484.29 1826.89 6.00 90.00 MWD 11100.00 90.00 248.69 9057.50 9002.00 5933964.70 710700.43 4534.26 1876.89 6.00 90.00 MWD 11150.00 90.00 251.69 9057.50 9002.00 5933946.42 710653.89 4584.08 1926.89 6.00 90.00 MWD 11200.00 90.00 254.69 9057.50 9002.00 5933930.61 710606.47 4633.61 1976.89 6.00 90.00 MWD 11250.00 90.00 257.69 9057.50 9002.00 5933917.31 710558.28 4682.72 2026.89 6.00 90.00 MWD 11300.00 90.00 260.69 9057.50 9002.00 5933906.54 710509.46 4731.28 2076.89 6.00 90.00 MWD 11327.76 90.00 262.35 9057.50 9002.00 5933901.67 710482.13 4757.95 2104.65 6.00 90.00 MWD 11400.00 90.00 262.35 9057.50 9002.00 5933890.03 710410.84 4827.05 2176.89 0.00 0.00 MWD 11500.00 90.00 262.35 9057.50 9002.00 5933873.92 710312.15 4922.71 2276.89 0.00 0.00 MWD 11600.00 90.00 262.35 9057.50 9002.00 5933857.80 710213.46 5018.36 2376.89 0.00 0.00 MWD 11700.00 90.00 262.35 9057.50 9002.00 5933841.69 710114.78 5114.02 2476.89 0.00 0.00 MWD 11800.00 90.00 262.35 9057.50 9002.00 5933825.58 710016.09 5209.68 2576.89 0.00 0.00 MWD 11900.00 90.00 262.35 9057.50 9002.00 5933809.47 709917.40 5305.33 2676.89 0.00 0.00 MWD 12000.00 90.00 262.35 9057.50 9002.00 5933793.35 709818.71 5400.99 2776.89 0.00 0.00 MWD 12100.00 90.00 262.35 9057.50 9002.00 5933777.24 709720.02 5496.65 2876.89 0.00 0.00 MWD 12200.00 90.00 262.35 9057.50 9002.00 5933761.13 709621.33 5592.30 2976.89 0.00 0.00 MWD 12300.00 90.00 262.35 9057.50 9002.00 5933745.02 709522.64 5687.96 3076.89 0.00 0.00 MWD spe""""y-sun DRILL.ING SERVIc:eS . . Sperry-Sun - Draft Copy KW A Planning _~ HALUDlCII.TQ", COMPAI'':Y 12400.00 90.00 262.35 9057.50 9002.00 5933728.90 709423.96 5783.62 3176.89 0.00 0.00 MWD 12471.99 90.00 262.35 9057.50 9002.00 5933717.31 709352.91 5852.48 3248.88 0.00 0.00 MWD 12500.00 90.00 264.03 9057.50 9002.00 5933713.20 709325.20 5879.15 3276.89 6.00 90.00 MWD 12550.00 90.00 267.03 9057.50 9002.00 5933707.89 709275.49 5926.09 3326.89 6.00 90.00 MWD 12600.00 90.00 270.03 9057.50 9002.00 5933705.20 709225.58 5972.07 3376.89 6.00 90.00 MWD 12650.00 90.00 273.03 9057.50 9002.00 5933705.12 709175.58 6016.95 3426.89 6.00 90.00 MWD 12700.00 90.00 276.03 9057.50 9002.00 5933707.65 709125.66 6060.62 3476.89 6.00 90.00 MWD 12750.00 90.00 279.03 9057.50 9002.00 5933712.80 709075.93 6102.96 3526.89 6.00 90.00 MWD 12766.10 90.00 280.00 9057.50 9002.00 5933715.01 709059.99 6116.29 3542.98 6.00 90.00 3-07A Tgt 2 12800.00 90.04 282.03 9057.49 9001.99 5933720.54 709026.54 6143.85 3576.89 6.00 88.99 MWD 12850.00 90.09 285.03 9057.44 9001.94 5933730.85 708977.63 6183.18 3626.89 6.00 88.99 MWD 12900.00 90.14 288.03 9057.33 9001.83 5933743.71 708929.32 6220.83 3676.89 6.00 88.99 MWD 12950.00 90.19 291.03 9057.19 9001.69 5933759.08 708881.75 6256.72 3726.89 6.00 89.00 MWD 13000.00 90.25 294.03 9057.00 9001.50 5933776.92 708835.05 6290.73 3776.89 6.00 89.01 MWD 13050.00 90.30 297.03 9056.76 9001.26 5933797.18 708789.34 6322.78 3826.89 6.00 89.02 MWD 13100.00 90.35 300.03 9056.48 9000.98 5933819.80 708744.76 6352.78 3876.89 6.00 89.03 MWD 13150.00 90.40 303.03 9056.16 9000.66 5933844.73 708701.43 6380.65 3926.89 6.00 89.05 MWD 13200.00 90.44 306.03 9055.79 9000.29 5933871.88 708659.46 6406.30 3976.88 6.00 89.07 MWD 13250.00 90.49 309.03 9055.38 8999.88 5933901.20 708618.96 6429.68 4026.88 6.00 89.09 MWD 13300.00 90.54 312.03 9054.94 8999.44 5933932.59 708580.06 6450.70 4076.88 6.00 89.12 MWD 13350.00 90.58 315.03 9054.45 8998.95 5933965.98 708542.86 6469.33 4126.88 6.00 89.14 MWD 13388.28 90.61 317.33 9054.05 8998.55 5933992.83 708515.58 6481.94 4165.16 6.00 89.17 MWD 13400.00 90.61 317.33 9053.92 8998.42 5934001.22 708507.40 6485.57 4176.88 0.00 0.00 MWD 13500.00 90.61 317.33 9052.85 8997.35 5934072. 78 708437.56 6516.60 4276.87 0.00 0.00 MWD 13600.00 90.61 317.33 9051.78 8996.28 5934144.34 708367.73 6547.63 4376.86 0.00 0.00 MWD 13700.00 90.61 317.33 9050.72 8995.22 5934215.91 708297.90 6578.66 4476.86 0.00 0.00 MWD 13800.00 90.61 317.33 9049.65 8994.15 5934287.47 708228.06 6609.69 4576.85 0.00 0.00 MWD 13900.00 90.61 317.33 9048.58 8993.08 5934359.03 708158.23 6640.72 4676.85 0.00 0.00 MWD 14000.57 ~0.61 317.33 9047.50 8992.00 5934431.00 708088.00 6671.93 4777.41 0.00 0.00 41/2" 14000.58 90.61 317.33 9047.50 8992.00 5934431.01 708087.99 6671.94 4777.43 0.00 0.00 3-07A Tgt 3 . . Winton, The DS03-07Ai permit application incorrectly states the cubic-feet and sacks volume for the 4 1/2" production liner. The correct figures are: 539 ft3 and 465 sacks. 96 bbls is the correct volume as stated. Thanks, Phil . DS3-07 Ai Area Review . . Here are the wellbores within 1320' of the planned 3-07A sidetrack: .3-15 ¡)~A- ~ 3 - 15A I ~ 11 0 I\"· II., / 3-15AL1 Cf7()'~'. .~~.þtGQ "'3 -34B ~"" ~ "->lM 17-07A Z'c:>t(OI/ v17-11 '-N·l.l.lt! /17-14 ric.l'''(" Thanks, Phil 1 of 1 3/2/200410:15 AM p055226 DATE 1/6/2004 CHECK NO. 055226 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 1/6/2004 PR010504J PERMIT TO DRILL H 03..0ì It r ,ECEIVE MAR 0 1 2004 Alaí.)ka )íl ~l Gas Cons Cnmrm: sion Anchorage: . THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL JÞ- 111055 2 2 bill ':0 L. ~ 20:iS e¡ 5.: 0 ~ 2 ?Be¡ bill . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fJßU C).3-e>7A PTD# :2c>tf - 0 lf3 Development X Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI The permit is for a new weJlboresegment of LATERAL existing well , Permit No, API No. . (If API num ber Production. should continue to be reported as last two (2) digits a function 'of tbe original API number. stated are between 60-69) above. PILOT BOLE In accordance with 20 AAC 25.005(1), an (PH) records, data and logs acquired for the pilot hole must be dearly differentiated In both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ex ception. (Companv Name) assumes tbe liability of any protest to tbe spacing exception that may occur. DRY DITCH All dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals tbrough target zones. PTD#: 2040430 Administration o o Appr Date RPC 3/2/2004 Engineering Appr Date WGA 3/3/2004 Geology Appr RPC Date 3/2/2004 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 03-07A Program SER Well bore seg Company BP EXPLORATION (ALASKA) INC Initial ClassfType SER I WAGIN GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 1 Pß(mitfee. attaçhe~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yes ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 2 Leasß ~numbe.raPRrORriate ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Vßs ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3 _U_nique weltnarnß~a[1d r:)l!mb~er ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeU located ina define_d ppol _ _ _ _ ~ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ 5 WeJUocaled prpper _distance_ from driJling unilbound_ary~ ~ _ _ _ Vßs _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ ~ _ 6 We.IUocatßd pr_ope.r _distance_ from Qtbe.r wells_ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ Vßs _ _ _ _ _ _ ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ 7 _S_uffiçienLaçrea~eaYaitable indriUilJg unjL ~ _ _ _ _ _ _ ~ _ ~ _ _ _ _ _ _ _ ~ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 ItdßviÇlted, js wellbore plÇltincJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ Vßs _ ~ _ _ _ _ _ 9 Operator onl}' affected party _ ~ _ _ _ _ _ _ ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ V~es _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ ~ ~ _ _ _ _ _ _ ~ 10 _Operator bas_apprppriateJlond inJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Vßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Pß(mit c~a[1 be issued wjtbout conse.rvaJion Qrder _ _ _ ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ No_ _ _ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ ~ _ ~ _ ~ _ _ _ _ _ _ _ _ _ _ _ ~ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ ~ _ 12 Pß(milcalJ be i_sSlJ.ed wjtbout Çlctministratille_apprpval _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ ~ _ ~ _ Yes ~ _ _ _ _ _ _ ~ _ _ _ _ _ ~ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ 13 Can permit be approved before 15-daywait Yes 14 WeUloc¡¡tßd within area Çlndstrat¡¡ _authorized by_l[1jectiplJ Ordß( # (puUO# inßPmrnßlJts>-(forYßS _ _ AIO~3_ _ _ _ _ _ ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ 15 AJlwel!s_withinJl4Jl1ite_area_ofreyiewjdß[1t[fied(FprseNjCß-"'{e[lonl}'L _ _ _ _ _ _ _ _ _ _ _ _ _ _ Vßs_ _ _ _ _ _ _3-:I5,3-:I5A,3-:I5ALL3:~6.J7-01A,1(-1tt7ot4_ _ _ ~ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ __ 16 Pre-produced injeçtor; ~uration_of pre-pro~uctipn Ißss than 3 montbs (For_service welt QnJy) _ _No _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ ~ _ ~ _ _ _ _ _ ~ ~ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ 17 ACMPF:inding9fCQn_si.stençy~hasbeeJ1jssued_forJbi$pr_olect _ _ _ _ _ ~ _ _ _ _ _ ~ _ ~ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ __ 18 ~C~o[1ductor st(ing~prQvided _ _ _ ~ _ _ _ _ _ _ _ _ _ ~ _ _ NA _ _ _ ~ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19SudaCßcÇlsing_prQtects alLknown USDWs _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ ~ _ _ _NA _ _ _ _ _ _ ~ ~ _ _ _ _ _ _ _ ~ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTv_otadeQlJ.ateJo çirc~utateoJ1_Cond_uctor~& SUJtc.sg _ _ _ _ _ _ _ _ _ _ _ ~ _ _ ~NA _ _ _ _ ~ ~ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21CMT vpl adeQuateJo tie-inJQngstri[1g to_sud ~g _ _ ~ _ ~ ~ _ _ _ _ _ _ ~ _ _ NA _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ ~ _ _ _ _ _ _ _ _ 22CMTwill coyer_aU koownproductiye bori~Qn_s_ _ _ _ _ _ _ _ ~ _ _ _ _ _ . _ _ Vßs _ _ _ _ _ _ ~ _ _ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ ~ 23 _C_asiDg designs actequaJe fp( CoT, B&perruafr_ost ~ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yßs ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ 24 AdequateJan_kÇlge_oJ re_SeIYe pit _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ ~ YßS _ ~ ~ _ f'llÇlb9rs~2~ES, _ _ _ _ ~ _ _ _ _ _ _ ~ _ ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ 25 Ifare-~rilt bas~a~ to-403 for abandonment beß[1 apPJQved _ _ ~ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ ~ _ 26 _AdequateweUbore separatjon_proposest _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Vßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdiverte.r required, does jt meet regulations_ _ _ _ ~ ~ ~ _ _ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ ~ _ _NA _ _ _ _ _ _ _ Sidetrack. _ _ _ _ _ _ _ _ _ ~ _ ~ _ _ _ _ _ _ _ _ _ _ _ ~ 28 _DJilJilJgfluidprogramschematic_&e~uiplistadequatß _ _ _ _ _ _ ~ _ _ YßS_ ~ _ _ _ _ _MaxMWJØA_PP!k _ _ _ ~ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ ~ ~ _ _ _ _ _ _ __ 29 _BOPEs,~dpthey meelreguJation _ _ _ _ _ _ _ _ _ _ _ _ _ ~ ~ ~ _ _ _ _ _ _ YßS _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 ~BOPEpress ra_tiog approp(iate;Je.stto(put psig incomments)~ ~ _ _ _ _ _ _ _ _ _ _ _Yßs _ _ _ _ _ Te.stt04000_psLMSfl2470 psk ~ _ _ _ _ _ ~ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ _ _ _ _ ~ _ ~ _ 31ChokellJanjfold cQmplies w/APtRfI-53 (May 64)_ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ Yßs _ ~ _ _ _ _ _ _ ~ ~ _ _ _ _ ~ _ _ _ _ _ ~ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ 32 Work will oçc_ur withputoperç¡tionsbutdown_ ~ _ _ _ Yes _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ ~ ~ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ ~ 33 Is presence~ of H2S gÇls_ prob.able _ _ _ _ _ _ _ _ _ _ _ ~ _ _ ~ _ _ _ _ ~ _ _ _ ~ _Yßs DS 03 is _aD H2S pact. _ ~ ~ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ ~ _ ~ _ 34 MeçbanicaLcsmctitio[1pfweUs within AOR verified (Fors_ervice wel! onl}') _ _ _ Yßs ~ _ _ _ _ _ Cmtng recor~s of.aJI AORweJls indiçate. 1\I1t. ~ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ ~ . - - - - - - . - - - - - - - ~ 35 Pßrmil caD be isslJ.ed wlo hydrogen s_utfide measures ~ _ _ _ _ _ _ _ _ _ _ _ _ No_ 36 Datapre.seoted on pole_ntial pverpres_sure _zone.s _ _ _ _ _ ~ _ _ _ _ _ _ ~ ~ ~ _ _ _ _ _ ~NA 37 _Sßismicanalysjs_ Qf shallow !; as_zPlJes _ _ _ _ _ ~ _ _ _ _ _ ~ _ _ _ _ _ ~ _ _ NA 38SßÇlbed :conditipo survey (if off-sho(e) ~ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ ~ _ _NA 39 _ Contact namelphoneJor_weßkly progress_reports [explorç¡tpryonIYl _ _ _ _ NA - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - ~ - ~ - - - - - - - - - - - - - - - - - - - - Geologic Commissioner: Date ,píS Date: 3/5/1- Engineering Commissioner: Public Commissioner Date e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information 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. e ur~ e c;(olf --otfs Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 25 16:16:21 2005 j'). g~ö Reel Header Service name.. .... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/25 Origin... ............. ...STS Reel Name... ............ . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services Tape Header Service name........... ..LISTPE Date.................... .05/01/25 Origin.................. .STS Tape Name. ............ ...UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments.. .......... .....STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3-07A 500292022001 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 25-JAN-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 MW0002978518 J. SACK J. RALL / L. MWDRUN 2 MW0002978518 J. BOBBITT J. RALL / D. MWD RUN 3 MW0002978518 J. SACK R. BORDES / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 MW0002978518 J. SACK R. BORDES / MWDRUN 5 MW0002978518 J. SACK R. BORDES / MWD RUN 6 MW0002978518 J. SACK R. BORDES / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0002978518 J. SACK R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 11 10N 15E 1316 812 55.50 27.00 # WELL CASING RECORD 1ST STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 7968.0 - e 2ND STRING 3RD STRING PRODUCTION STRING 6.125 7.000 10280.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 3-07 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 7968'MD/6752'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS; PRESSURE WHILE DRILLING (PWD). UPHOLE MAD SGRC TIE -IN DATA ACQUIRED WHILE RIH FOR RUN 2 WERE MERGED WITH RUN 1 MWD SGRC DATA. 5. MWD RUNS 3 - 7 COMPRISED DIRECTIONAL; DGR; ELECTROMAGNETIC WAVE RESISTIVITY- PHASE 4 (EWR4); PWD; AND AT-BIT INCLINATION (ABI). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A GAMMA RAY RUN IN 3-07, PROVIDED BY W. TIFENTAL (SIS/BP) ON 20 JANUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 7 REPRESENT WELL 3-07A WITH API#: 50-029-20220-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13841'MD/9052'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name..... .... ....STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX " 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7821. 5 7976.5 10238.0 10238.0 10238.0 10238.0 10238.0 STOP DEPTH 13 791. 0 13847.5 13798.0 13798.0 13798.0 13798.0 13798.0 e e # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 7821. 5 7813.5 7831.0 7823.0 7837.5 7829.5 7851.5 7842.5 7853.0 7844.5 7878.0 7871.0 7889.0 7879.5 7900.0 7891.5 7908.0 7902.0 7918.5 7911.0 7923.0 7916.5 7935.0 7926.0 7943.0 7934.0 7959.5 7952.0 7967.5 7961.0 13847.5 13841. 0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 7813.5 7999.0 MWD 2 7999.0 10280.0 MWD 3 10280.0 11037.0 MWD 4 11037.0 11774.0 MWD 5 11 774.0 12216.0 MWD 6 12216.0 13281. 0 MWD 7 13281.0 13841.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units....... ....Feet Data Reference Point............. . Undefined Frame Spacing..................... 60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR Max 13847.5 306.12 419.66 296.39 944.48 2000 1893.85 67.31 Min 7821.5 0.11 14.17 1. 25 0.99 0.84 0.8 0.34 Mean 10834.5 100.92 70.5886 8.81682 8.57541 23.3304 19.9486 2.95984 Nsam 12053 11743 11940 7121 7121 7121 7121 7121 MWD MWD MWD MWD MWD MWD MWD First Reading For Entire File......... .7821.5 Last Reading For Entire File.......... .13847.5 First Reading 7821. 5 7976.5 7821.5 10238 10238 10238 10238 10238 Last Reading 13847.5 13847.5 13791 13798 13798 13798 13798 13798 e File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record. .65535 File Type........... .....LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.......05/01/25 Maximum Physical Record..65535 File Type... . . . . . .. . . . ., .LO Previous File Name. . . . . . .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 e header data for each bit run in separate files. 1 .5000 START DEPTH 7813.5 7970.0 STOP DEPTH 7963..0 7999.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 22-MAR-04 Insite 66.37 Memory 7999.0 7968.0 7999.0 .0 .0 TOOL NUMBER 103770 8.500 7968.0 LSND 9.80 65.0 8.7 3350 4.5 .000 .000 .000 .000 .0 114.0 .0 .0 e e HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.. .............. .Down Optical log depth units...... .....Feet Data Reference Point. ........ .....Undefined Frame Spacing..................... 60 .1IN Max frames per record. . . . ........ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7813.5 7999 7906.25 372 7813.5 7999 ROP MWD010 FT/H 0.11 20.62 9.11466 59 7970 7999 GR MWD010 API 29.3 60.19 43.5791 300 7813.5 7963 First Reading For Entire File. ........ .7813.5 Last Reading For Entire File... ....... .7999 File Trailer Service name..... .... ....STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record. .65535 File Type. . . . .... . ... . . . .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .....STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 7963.5 7999.5 STOP DEPTH 10244.5 10280.0 # LOG HEADER DATA DATE LOGGED: 24-MAR-04 e SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type. ....0 Logging Direction....... ...... ....Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ... .Undefined Absent value...................... - 999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Insite 66.37 Memory 10280.0 7999.0 10280.0 27.1 47.3 TOOL NUMBER 103770 8.500 7968.0 LSND 10.30 48.0 9.7 1900 3.9 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 143.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7963.5 10280 9121.75 4634 7963.5 10280 ROP MWD020 FT/H 1. 54 266.77 129.389 4562 7999.5 10280 GR MWD020 API 23.72 419.66 134.02 4563 7963.5 10244.5 First Reading For Entire File......... .7963.5 Last Reading For Entire File.......... .10280 File Trailer e Service name. ........... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/01/25 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...... .05/01/25 Maximum Physical Record..65535 File Type.... . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET GR ROP $ 4 e header data for each bit run in separate files. 3 .5000 START DEPTH 10231.5 10231.5 10231.5 10231.5 10231.5 10245.0 10280.5 STOP DEPTH 10988.0 10988.0 10988.0 10988.0 10988.0 10981.0 11037.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA Electromag RAY 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: 28-MAR-04 Insite 66.37 Memory 11037.0 10280.0 11037.0 27.2 91. 2 TOOL NUMBER 87225 167218 6.125 10280.0 Flo-pro 8.40 57.0 9.0 3350 8.6 1.500 .824 1. 400 1. 550 70.0 133.0 70.0 70.0 e e # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ...... ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point.... ..... .....Undefined Frame Spacing..................... 60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Cha=el DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10231. 5 11037 10634.3 1612 10231. 5 11037 ROP MWD030 FT/H 0.24 193.12 53.6885 1514 10280.5 11037 GR MWD030 API 16.12 402.87 56.0114 1473 10245 10981 RPX MWD030 OHMM 1. 25 296.39 14.1831 1514 10231.5 10988 RPS MWD030 OHMM 0.99 944.48 14.6416 1514 10231. 5 10988 RPM MWD030 OHMM 0.84 2000 84.9611 1514 10231. 5 10988 RPD MWD030 OHMM 0.8 1893.85 68.5586 1514 10231.5 10988 FET MWD030 HOUR 0.94 67.31 6.65394 1514 10231.5 10988 First Reading For Entire File..........10231.5 Last Reading For Entire File... ...... ..11037 File Trailer Service name.. . . . . .' . ... .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record..65535 File Type... . . . . . . . . . . . . . LO Next File Name....... ... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name... ....STSLIB.004 Comment Record FILE HEADER e FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS FET RPD RPX RPM ROP $ 5 e header data for each bit run in separate files. 4 .5000 START DEPTH 10981.5 10988.5 10988.5 10988.5 10988.5 10988.5 11037.5 STOP DEPTH 11719.0 11 726.0 11726.0 11726.0 11 726.0 11726.0 11774.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... .......... ....0 Data Specification Block Type.....O Logging Direction............ .... . Down Optical log depth units.......... .Feet Data Reference Point.. ........ ....Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 29-MAR-04 Insite 66.37 Memory 11 774.0 11037.0 11774.0 87.8 90.7 TOOL NUMBER 87225 167218 6.125 10280.0 Flo-pro 8.40 49.0 9.8 2900 6.4 1. 500 .785 1. 400 1.500 70.0 140.0 70.0 70.0 e e Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10981.5 11774 11377.8 1586 10981. 5 11774 ROP MWD040 FT/H 7 259.6 118.389 1474 11037.5 11774 GR MWD040 API 14.17 35.24 22.8148 1476 10981.5 11 719 RPX MWD040 OHMM 3.86 8.69 6.38177 1476 10988.5 11 726 RPS MWD040 OHMM 3.75 8.5 6.07567 1476 10988.5 11726 RPM MWD040 OHMM 3.62 7.88 5.84493 1476 10988.5 11 726 RPD MWD040 OHMM 4.02 8.06 6.02318 1476 10988.5 11 726 FET MWD040 HOUR 0.34 14.73 1.59379 1476 10988.5 11726 First Reading For Entire File......... .10981.5 Last Reading For Entire File...........11774 File Trailer Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record..65535 File Type...... . . . . . . . . . . LO Next File Name.... ...... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.. .... .05/01/25 Maximum Physical Record. .65535 File Type................LO Previous File Name.... ...STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 11 719.5 11 726.5 11726.5 11726.5 11726.5 11726.5 11774.5 STOP DEPTH 12161.0 12168.0 12168.0 12168.0 12168.0 12168.0 12216.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 30-MAR-04 Insite 66.37 Memory e TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.... ............ .Down Optical log depth units.... .., ....Feet Data Reference Point...... ....... .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value...................... - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e 12216.0 11 774.0 12216.0 88.7 91. 9 TOOL NUMBER 87225 167218 6.125 10280.0 Flo-pro 8.40 49.0 9.7 3000 6.6 1.700 .912 1. 500 1. 700 70.0 136.4 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11719.5 12216 11967.8 994 11719.5 12216 ROP MWD050 FT/H 4.22 306.12 65.5354 884 11774.5 12216 GR MWD050 API 15.25 38.27 22.5319 884 11719.5 12161 RPX MWD050 OHMM 3.45 10.52 7.79258 884 11 726.5 12168 RPS MWD050 OHMM 3.29 9.28 7.14818 884 11726.5 12168 RPM MWD050 OHMM 3.24 8.85 6.70258 884 11726.5 12168 RPD MWD050 OHMM 3.69 8.94 6.87407 884 11726.5 12168 FET MWD050 HOUR 0.66 18.18 3.08544 884 11726.5 12168 e e First Reading For Entire File......... .11719.5 Last Reading For Entire File....... ....12216 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record..65535 File Type...... . . . . . . . . . . LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name........... ..STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...05/01/25 Maximum Physical Record..65535 File Type..... . . . . . . . . . . . LO Previous File Name. . . . . . .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX RPM RPD FET ROP $ 7 header data for each bit run in separate files. 6 .5000 START DEPTH 12161. 5 12168.5 12168.5 12168.5 12168.5 12168.5 12216.5 STOP DEPTH 13225.0 13231.5 13231. 5 13231. 5 13231. 5 13231. 5 13281.0 # 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: 01-APR-04 Insite 66.37 Memory 13281.0 12216.0 13281.0 87.5 92.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 87225 167218 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 10280.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: Flo-pro 8.40 48.0 9.7 e e 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: 3000 6.6 1.700 .828 1. 500 1.700 70.0 150.8 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.. ...0 Logging Direction........... ..... . Down Optical log depth units. . . . . . . . . . .Feet Data Reference Point............. . Undefined Frame Spacing........ ............ .60 .1IN Max frames per record.. ...... .....Undefined Absent value... . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12161.5 13281 12721.3 2240 12161.5 13281 ROP MWD060 FT/H 1. 39 168.07 76.9662 2130 12216.5 13281 GR MWD060 API 15.76 78 .25 25.6509 2128 12161.5 13225 RPX MWD060 OHMM 4.26 16.28 8.32708 2127 12168.5 13231. 5 RPS MWD060 OHMM 4.46 15.05 7.82825 2127 12168.5 13231. 5 RPM MWD060 OHMM 4.28 14.02 7.59827 2127 12168.5 13231.5 RPD MWD060 OHMM 4.49 14.03 7.73016 2127 12168.5 13231.5 FET MWD060 HOUR 0.46 14.54 1. 52033 2127 12168.5 13231.5 First Reading For Entire File......... .12161.5 Last Reading For Entire File.......... .13281 File Trailer Service name............ .STSLIB.007 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name... ........STSLIB.008 Physical EOF File Header Service name... ......... .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 e Date of Generation..... ..05/01/25 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . . LO Previous File Name..... ..STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 8 e header data for each bit run in separate files. 7 .5000 START DEPTH 13225.5 13232.0 13232.0 13232.0 13232.0 13232.0 13281. 5 STOP DEPTH 13784.5 13791.5 13791.5 13791.5 13791.5 13791.5 13841.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ .Down 02-APR-04 Insite 66.37 Memory 13841.0 13281.0 13841. 0 88.2 90.6 TOOL NUMBER 87225 167218 6.125 10280.0 FLO-PRO 8.40 44.0 9.3 2500 6.8 1.500 .720 1.400 1. 600 69.0 151.0 69.0 69.0 e e Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spac ing. . . . . . . . . . . . . . . . . . . . . 60 .1IN 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 MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13225.5 13841 13533.3 1232 13225.5 13841 ROP MWD070 FT/H 9.89 292.54 104.133 1120 13281.5 13841 GR MWD070 API 15.58 57.11 24.7947 1119 13225.5 13784.5 RPX MWD070 OHMM 2.95 11.98 6.51026 1120 13232 13791.5 RPS MWD070 OHMM 2.93 12.33 6.21491 1120 13232 13791.5 RPM MWD070 OHMM 2.95 14.98 6.06312 1120 13232 13791.5 RPD MWD070 OHMM 3.26 13.11 6.11384 1120 13232 13791.5 FET MWD070 HOUR 0.35 20.12 2.40114 1120 13232 13791.5 First Reading For Entire File......... .13225.5 Last Reading For Entire File...........13841 File Trailer Service name............ .STSLIB.008 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/25 Maximum Physical Record..65535 File Type.. . . . . ......... .LO Next File Name....... ....STSLIB.009 Physical EOF Tape Trailer Service name.. . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/25 Origin.... ........ ...... .STS Tape Name.... ..... ...... . UNKNOWN Continuation Number..... .01 Next Tape Name....... ....UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.. ...........LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/25 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.. ... .01 Next Reel Name.......... .UNKNOWN Comments...... ...... .....STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File e e
