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Home My WebLink About204-037Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date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y Samantha Carlisle at 2:43 pm, Apr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aitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/07/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU P1-07A (PTD 204-037) Memory Production Profile 10/24/2021 Please include current contact information if different from above. Received By: 12/07/2021 37' (6HW By Abby Bell at 4:30 pm, Dec 07, 2021 . • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519-6612 RECFIVPr January 6, 2012 JAN P 2'01 Masks On & Ivo ;r;,. . Mr. Tom Maunder (rr r ; ? Alaska Oil and Gas Conservation Commission l 333 West 7th Avenue a04_- 0 37 Anchorage, Alaska 99501 P — 0 f7/ Subject: Corrosion Inhibitor Treatment of P1 -07A (PTD # 2040370) Dear Mr. Maunder, Enclosed please find a spreadsheet with details of the corrosion inhibitor treatment in the surface casing by conductor annulus of well P1 -07A. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatment took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. tnc Mehreen Vazir BPXA, Well Integrity Coordinator g, i ,A • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) GPMA PM1 Date: 11/1/2010 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal P1 -01 1900270 50029220180000 P1 -02A 2020650 50029217790100 _ P1 -03 1890130 50029219120000 P1 -04 1930630 50029223660000 P1 -05 1930870 50029223780000 P1 -06 1961370 50029226950000 P1 -08A 2021990 50029223840100 P1 -09 1961540 50029227040000 P1 -11 1920860 50029222840000 P1 -12 1910130 50029221340000 P1 -13 1930740 50029223720000 P1 -14 1930160 50029223380000 P1 -16 1930340 50029223490000 P1 -17 1930510 50029223580000 P1 -18A 2020760 50029229530100 P1 -20 1920940 50029222880000 P1 -21 1930590 50029223630000 P1 -23 1961240 50029226900000 P1 -24 1961490 50029227030000 P1 -25 1890410 50029219370000 P1 -131 1921130 50029222980000 03/30/11 Schlumberger NO. 5715 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD r P1 -07A BJGT -00020 PRODUCTION PROFILE <96 44--031- 03/05111 1 ,} 5J f 1 S -18B BL65 -00020 MEMORY DDL ( .- • 02/22/11 1 _ _ 1 13 -09 BG4H -00035 LDL t 1'7 .C, I `b — / 02/20/11 1 '7T_. 1"f 1 09 -02 BBSK -00052 I RST ro - 0 10 02116/11 1 a pyi rd 1 13-16A BG4H -00034 RST 2 ng _ n as- 02/19/11 1 AvykG 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • l ,„„. APR 0 4 ZO " a. tri g,; STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPOT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon IN Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ® Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory ` 204 -037 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 o 50 -029- 21996 -01 -00 7. Property Designation: 8. Well Name and Number: ADL 028197 *- PBU P1 - 07A 9. Field / Pool(s): Prudhoe Bay Field / Point McIntyre Pool 10. Present well condition summary Total depth: measured 10671 feet Plugs (measured) None true vertical 9207 feet Junk (measured) None Effective depth: measured 10560 feet Packer. measured 9637 & 9808 feet true vertical 9120 feet true vertical 8367 & 8511 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 113' 113' Surface 4272' 13 -3/8" 4272' 4091' 3450 1950 Intermediate Production 7341' 9 -5/8" 7341' 6426' 6870 4750 Liner 3475' 7" 7169'- 10644' 6300'- 9186' 7240 5410 Perforation Depth: Measured Depth: 10162'- 10498' y True Vertical Depth: 8810' - 9072' O i & Gad Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# 13Cr -80 9890 8560' TVD Packers and SSSV (type, measured and true vertical depth): 7" x 4 -1/2" Baker TNT Packer 9637' MD 8367' TVD 7" x 4 -1/2" Baker S -3 Prod Packer 9808' MD 8511' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 9744'. Cut and pull 9 -5/8" casing from 3957'. Run 9 -5/8" (47 #, L -80) tieback to surface. Cement w/ 260 bbls Class 'G' w/ Gas -Blok (1460 cu ft / 1258 sx). Clean out and run new Chrome tubing. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 20 1273 Subsequent to operation: 652 12616 8988 1911 728 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ® Daily Report of Well Operations r ® Development ❑ Service ❑ Exploratory ❑ Stratigraphic ® Well Schematic Diagram 15. Well Status - ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 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: Contact Hank Baca, 564 -5444 310 -221 Printed Name Sondra Stewman Title Drilling Technologist �' ( Pre Sigeature 9 Phone 564 -4750 Date ' l �-{ U Sondra Stewman 564 -4750 Form 10 -404 Revised FOOMS yt�u ,90tIH1 ,1 Submit / Original Only �"IJ'W TREE Cw HORIZONTAL WELL '� bkkEk P 1 -07A F 0 FRmm *TPE KB. El EV 42' —D7-14 09 ST MD TVD DEV TY PE VLV LATCH PORT DATE FM63SM9351 0 27 MMG DOME RKP 16 08/29/10 5 5471 5028 38 MMG so RK 20 08/29/10 TV 2EB256 7204 27 KBG-2 DMY RK 0 04119104 4-1/2" HES XN NIPPLE 81 [4- TBG STUB (07127110) 9744� PERFORATION SUMMARY REF LOG: SPERRY SUN MWD ON G4114/04 Note: Refer to Production DB for historical perf data 2-71a" 6 10208 - 10213 0 08/01104 DA TE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTY RE UNIT 03116/90 OPJGINAL COMPLETION WELL. PI-07A 04/18/04 KAK RIG SIDErRACK (1 PERMIT No: r 204O370 \ P1 -07A, Well History Date Summary 20 -Jul -2010 ** **WELL SHUT -IN ON ARRIVAL * * * *(E -LINE SET PLUG) T /I /O = 2990/0/0 PSI SET HALLIBURTON 4.5" OBSIDIAN BRIDGE PLUG AT 9827' MIDDLE ELEMENT FINAL T /I /O = 2990/0/0 PSI FINA VALVE POSITIONS: MASTER, SSSV, VALVES TO GAUGES OPEN. SWAB, WING, SSV CLOSED. * ** *JOB COMPLETE. WELL LEFT SHUT -IN, DSO NOTIFIED OF DEPARTURE * * ** 23 -Jul -2010 T /IA/OA= SSV /0/0 Temp =Sl PPPOT-T (PASS) PPPOT -IC (PASS) (Pre RWO) PPPOT -T : RU 1 HP BT onto THA test void 1300 psi bled to 0 psi, flushed void till clean returns achieved. Pressure void to 5000 psi for 30 minute test, 4900/ 15 minutes, 4900/ 30 minutes. Bled void to 0 psi, RD all test equipment. Cycle LDS "Standard" all moved with no problems and are in good visual condition. Spacer spool x tubing spool : RU 1 HP BT onto IC test void 0 psi. Pressure void to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi. PPPOT -IC x Spacer spool : Cycle LDS "N style" all moved with no problems and are in good visual condition. Unable to test at this time job not complete will continue on 7 -24 -10 ** *Job not complete * ** 24 -Jul -2010 T /1 /0= 2920/7/5. Temp =Sl. Bleed TBG to -100 psi (pre -rig MIT's). AL SI @ casing & lateral valves, ALP =psi. TBG FL Q 9827' (Obsidian bridge plug) 150 bbls. IA FL Q 7148' (SO sta #3) 385 bbls. Bled TBG pressure from 2920 psi to 80 psi in 1.5 hrs. Monitor for 30 mins, TBG pressure increased 20 psi, IAP & OAP unchanged. Final WHPs= 100/7/5. Job completed. SV, WV= Closed. SSV, MV =Open. IA,OA =OTG. T /IA/OA= SSV /0 /0 Temp =Sl PPPOT-1C (PASS) Continued from 7/23/10 (Pre RWO) PPPOT -IC x Spacer spool : RU 1 HP BT onto IC test void 0 psi. Pressure void to 3500 psi for 30 minute test, 3500/ 15 minutes, 3450/ 30 minutes. Bled void to 0 psi. LDS "N style" cycled and torqued previous day, all good. * ** Job complete * ** 25 -Jul -2010 T /I /0= 100/0/0 Temp= SI MITT FAILED to 3500 psi, (RWO prep) Pumped 3 bbls 60/40 MW spear followed with 144.4 bbls 110* crude down TBG to reach test pressure, TBG lost 20 psi in 1 st 15 min and 40 psi in 2nd 15 min for a total loss of 60 psi in 30 min test, RD TBG & RU IA, Pumped 321 bbls 110* crude down IA in attempt to pressure up for CMIT TxIA, Started getting fluid in cellar through known SC leak, Vac out cellar and flutes, Pumped an additional 65 bbls 85* crude down IA, TBG pressure not tracking with IAP, Equalize TAA pressure, - - - -- -Job In Progress - - - - -- ** *WSR Continued on 07- 26 -10 * ** 26 -Jul -2010 ** *WSR Continued from 07- 25 -10 * ** Temp= SI CMIT TAA PASSED to 3500 psi (RWO prep) Pumped a total of 386 bbls 85* crude down IA to reach test pressure, TAA lost 40/20 psi in 1 st 15 min and 20/10 psi in 2nd 15 min for total loss of 60/30 psi in 30 min test, Tried bleeding T /IA pressure down FL, IAP not tracking TBG pressure, Bleed T /IA pressure with jumper hose, Bleed back - 10 bbls, Final WHP's 20/0/0 "Valve position @ departure- Swab, Wing= SI / SSV, Master, IA & OA= Open" Page 1 of 3 11 -07A, Well History Date Summary T /I /O = 3200/0/0. Temp = SI. Assist FB w /CMIT -T x IA PASSED. LRS rigged up to well ( see LRS log for MIT details). ALP @ 0 psi & SI @ IA casing valve. Open bleed on OA. Crude and clear fluid in cellar is 23" deep. Crude flowing out of circ port during pump operations. Water inflowing from sides of cellar. Inserted 1/2" stinger vac hose into circ port to mitigate fluids from SC. FL in SC dropped to 57" during LRS loading IA and remained there for the duration of the test. Final W HP's= 20/0/0. Job Complete. SV& WV = C. MV & SSV = C. IA & OA = OTG. NOVP. 27 -Jul -2010 ** *WELL SHUT -IN ON ARRIVAL * ** (JET CUT TBNG) SSV OPEN, INITIAL PRESSURES 0/0/0. JET CUT TUBING AT 9744' WITH 3.65" SCP POWER CUTTER. PRESSURED UP TBG TO 400 PSI PRIOR TO SHOOTING, TBG DROPPED TO 300 PSI AFTER SHOOTING. WELL LEFT SHUT -IN, HAND OVER WITH DSO PRIOR TO DEPARTURE 28 -Jul -2010 T /1 /0= 170NAC /0 +. Temp= SI. WHPs (post CMIT - TxIA). ALP= 0 psi, SI @ casing valve. TBGP increased 150 psi, IAP unchanged, OAP increased to 0+ from 7/26/10. SV, WV= C. SSV, MV= O. IA, OA= OTG. NOVP. 29 -Jul -2010 T /1 /0= 175 /vac /0+ Temp =Sl Circ -out F- protect TxIA F- protect F -line CMIT TxIA 1000 psi PASS (RWO prep) Pumping down IA up TBG down F -Line Spear in to IA w /5bbls of 60/40 meth H2o followed by 863 bbls of 120* sea H2o followed by 140 bbls of 55* diesel F- protect F -Line w/5 bbls of neat meth. U -tube for TxIA F- protect. CMIT -TxIA: pumped 1 bbl diesel down IA to test list 15 min T /IA +20/ -30, 2nd 15 min T /IA 0 / -0 for a total T /IA +20/ -30 in 30 min test. Bled TxIAP down. Tags hung on MV,IA. Valve postitions upon departure:SV,WV,SSV= closed, MV,IA,OA =open. DHD &vac truck monitoring well upon departure, operator notified. FWHP's =0/0/0 T /1 /0= 175 /VAC /0 +. Temp= SI. Assist fullbore with cellar watch during circ out (RWO prep). AL SI @ casing valve. ALP= 0 psi. OA FL @ surface. Monitor cellar while LRS performs circ out and MIT. Bleed OAP as needed. Vac out cellar as needed. See log for details. ** JOB CONTINUED ON 07/30/10 ** SV,WV,SSV =C. MV =O. IA,OA =OTG. NOVP. 30-Jul-201 0 T /1 /0= SSV /0 /0. Temp= SI. Assist Fullbore with cellar watch during circ -out (RWO prep). * *CONTINUED FROM 07- 29 -10 * *. Monitored cellar inflow post CMIT TxIA. See log for details. VAC'ed cellar fluid to expose circ port. No flow visible from conductor, fluid is inflowing from sides of cellar box. Cellar box fluid appears to have stopped inflowing @ 64" below top of grating. * *Job complete 5-Aug-201 0 * ** WELL SHUT IN ON ARRIVAL * ** (pre rwo) DRIFT TO SVLN @ 2158' SLM W/ 3.85" GAUGE RING ** *CONTINUE ON 8/6/10 WSR * ** 6- Aug -2010 ** *CONTINUED FROM 8/5/10 WSR * ** (pre rwo) SET 4 -1/2" X -HOLD OPEN SLEEVE (OAL 11'2" / 2.10" ID)) @ 2158' SLM/2177' MD ** *WELL S/I ON DEPARTURE * ** T /1 /0= 0/0/0; Set 4- 1/16" CIW "H" BPV #252 for Doyon 16 pre -rig; 1 -2' ext. used, tagged @ 102" 13- Aug -2010 T /1 /0= 30/0/0 Pulled 4" CIW BPV #252 thru tree for Doyon 16 to decomplete. 1 -2' ext used tagged @108 ". No problems Page 2 of 3 P1 -07A, Well History 11 Date Summary 1 D Sc 25- Aug -2010 The well was worked over during August 2010 for surface casing leak. (08 -10- 2010 -08 -25 -2010) Basically, the 13 -3/8" casing was cut right below the casing spool and the spool was then removed. The new 9 -5/8" casing was run from surface to 3957'.It was cemented to the surface. The 9 -5/8" has become the starting head and now there is no OA. There is another spool below this spool but it is connected to the 9 -5/86 spool. PUMP BOTH DIRECTIONS THROUGH SHEAR VAVLE TO ENSURE VALVE WAS SHEARED. N/D BOPE. N/U ADAPTER AND PREP CONTROL LINES. N/U TREE AND TEST TREE AND ADAPTER TO 5000 PSI. LUBRICATE OUT TWC. FREEZE PROTECT WELL WITH 150 BBLS DIESEL. SECURE WELL. SET BPV RDMO. Post -Rig 26- Aug -2010 T /1 /0 =0/0/0 Pressure tested lubricator w/each break for 5 min. against S/V @ 300 psi (low) w /no loss - 3500 psi (high) for 5 min. w /no loss; Pulled 4" CIW TWC #257 @ 110" w /1 -1' ext.; Pressure tested S /V- M/V (barriers) thru W/V for 5 min. (507 -512) @ 500 psi (low) w /20 psi loss -3500 psi (high) for 5 min. (516- 521) w/25 psi loss; Set 4" CIW BPV #150 @ 110" w /1 -1' ext.; Doyon 16 RDMO. 28- Aug -2010 TWO= 0 /0 /0 Verified barriers SSV /Swab /Wing : Pass... Pressure tested lubricator - Low: 300 PSI - 5 Min./ Pass High : 3500 PSI - 5 Min. /Pass. Pulled 4- 1/16" CIW "H" BPV # 150 thru tree 1 -1' ext. used ...tag @ 108" .Removed lubricator installed tree cap..Pressure tested to 500 PSI - 5 Mind Pass. Installed 2 - 1/16" FMC 120 valve on O/A, shell tested to 5000 PSI 5 Mind Pass ... Pulled 2" FMC WR Plug .... post - Doyon 16 ... no problems. 29- Aug -2010 After the workover slickline tagged TD at 10,212,which indicated only two sets of perforation are NOT covered. The well tested at about 9500 bfpd with a 95% watercut from a shake out. * **WELL SHUT IN ON ARRIVAL * ** PULLED DSSSV FROM 2202' SLM/2225' MD PULLED BALL AND ROD FROM 9636' SLM PULLED DGLV FROM STA #5 @ 5452' SLM/5471' MD & SHEAR VALVE FROM STA #6 @ 3529' SLM/3549' MD SET LGLV IN STA# 6 & OGLV IN STA# 5 PULLED RHC PLUG BODY FROM 9644' SLM/9673' MD RAN IN W/ A 3.50" CENT, T.E.L, 2.50 SAMPLE BAILER. TAGGED BTM @ 10183' SLM /10212' MD(SAMPLE OF SAND /MUD, 286' OF FILL COVERING PERFS) ** *CONTINUED ON WSR 08- 30 -10 * ** 30- Aug -2010 ** *JOB CONTINUED FROM 8- 29 -10 * ** (post RWO) SET 4.5" WRDP (SN= HKS -44) @ 2202' SLM/2225' MD (2 SETS OF STANDARD PKG) PERFORMED CLOSURE TEST (GOOD) ** *WELL LEFT SHUT IN, NOTIFY DSO TWO= 500/780/780. Temp= SI. WHPs (Eval IAxOA comm). ALP= 780 psi, open @ casing valve. IC spool has external checks. Slickline on location setting safety valve. Slickline is bleed OAP has needed. Page 3 of 3 North Arrlerlea= ALASKA Pg I `�f ?' C}p�aratior► Summary Report _ - � . Common Well Name: P1 -07 AFE No Event Type: MOBILIZATION (MOB) Start Date: 8/10/2010 End Date: 8/13/2010 X4- OOQV8 -E (800,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10 : 07 2/2/1990 00:00 @42.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/10/2010 12:00 - 13:00 1.00 MOB P PRE PJSM -LOWER DERRICK AND MOVE OFF WELL 13:00 - 15:00 2.00 MOB P PRE PUT BOPE ON TRANSPORT STAND. INSTALL FRONT AND REAR BOOSTERS, AND FUNCTION 115:00 - 22:30 7.50 MOB P PRE MOVE THE RIG FROM Q -PAD TO J -PAD. WAIT j ON RIG MATS TO BE PICKED UP FROM Q -PAD ACCESS ROAD. -WHILE WAITING, MAKE WELDING REPAIRS TO REAR BOOSTER WHEEL. - 1'715 -hrs GIVE 24 -HR NOTICE TO AOGCC REP JOHN CHRISP OF BOP TEST, WOULD LIKE AN UPDATE IN THE AM, 22:30 - 00:00 1.50 MOB P PRE PREPARE TO MOVE OFF J -PAD. -WAIT ON RIG MATS TO BE PLACED ON ROAD AHEAD OF RIG. 8/11/2010 00:00 - 09:30 9.50 MOB P PRE CONTINUE TO MOVE RIG FROM Q -PAD ACCESS ROAD TO WEST DOCK STAGING AREA. - 0230 -hrs RIG MOVED PAST FRONTIER CORNER, CONTINUING DOWN SPINE ROAD. - - 0430 -hrs, RIG TURNED ONTO K,E,G -PAD ACCESS ROAD JUST PAST GC-1. 09:30 - 16:00 6.50 MOB P PRE STAGE RIG AT WEST DOCK STAGING AREA, WAITING FOR MATS TO BE PLACED ON PT MAC 1 ACCESS RD. - CHANGE OUT 13 -5/8" TUBING SPOOL THAT WAS SENT IN ERROR FOR THE NEEDED 11" TUBING SPOOL. -SPOT WELLHEAD EQUIPMENT BEHIND THE WELL. 16:00 - 00:00 8.00 MOB P PRE BEGIN MOVE FROM WEST DOCK STAGING PAD TO PT MAC 1, LEAPFROGGING MATS. - 1700 -hrs CALLED AOGCC JOHN CHRISP WITH UPDATE. WOULD LIKE UPDATES DAILY. 8/12/2010 00:00 00:00 24.00 MOB P PRE CONTINUE MOVING RIG DOWN PT MAC 1 ACCESS ROAD, LEAPFROGGING MATS. - PERFORM LIGHT RIG MAINTENANCE - PERFORM HOUSEKEEPING. - 1812 -hrs CALL AOGCC REP JOHN CRISP WITH UPDATE ON RIG MOVE. 8113/2010 00:00 - 03:00 3.00 MOB P PRE CONTINUE MOVING RIG DOWN PT MAC 1 ACCESS ROAD, LEAPFROGGING MATS. -PULL ONTO PAD. 03:00 06:00 3.00 MOB P PRE STAGE IN THE CENTER OF THE PAD. -RD REAR BOOSTERS - INSTALL BOPE STACK IN SUB -SPOT RIG OVER WELL. 06:00 - 09:00 3.00 MOB P PRE RAISE DERRICK. -SPOT MUD PUMP #2 AND GENERATOR MODULES, SLOP TANK, AND ARCTIC GRADE FUEL TRAILER. - BRIDLE DOWN BLOCKS. -RU RIG FLOOR. -BEGIN TO TAKE ON 120 - DEGREE 8.5 -PPG SEAWATER. Printed 9/20/2010 4:13:08PM N©rt[�mtca "ALASKA BP _s. _ _ A M, — �parmimary ;Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10 07 2/ @42.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/13/2010 09:00 - 11:00 2.00 WHSUR P DECOMP RU ALL CIRCULATING LINES IN CELLAR. -BRING ON 120 - DEGREE 8.5 -PPG SEAWATER TO PITS. -STAGE FLUIDS HAULING TRUCKS ON LOCATION. -OPEN OA LINE TO SLOP TANK. 11:00 - 12:00 1.00 WHSUR P DECOMP HOLD PJSM WITH DSM LUBRICATOR CREW. REMIND CREW THAT DSM WILL BE RESPONSIBLE FOR THE FUNCTIONING OF THE MASTER VALVE AND HIGHLIGHT OVERHEAD WORK AND PRESSURE TESTING. -PU DSM LUBRICATOR AND MU TO TREE. -TEST LUBRICATOR TO 250 -PSI LOW AND 3500 -PSI HIGH. HOLD AND CHART EACH TEST FOR 5- MINUTES. GOOD TESTS. _DSM PUL QPV. 30-PSI LINUERNEATH PI 1](1 LD LUBRICATOR AND BPV. 12:00 13:00 1.00 KILLW P DECOMP HOLD PJSM WITH RIG CREW AND CH2MHILL TRUCK DRIVERS. DISCUSS PUMPING SEQUENCE, POSITIONS OF PEOPLE, SPILL POTENTIALS AND STRESSED THE IMPORTANCE OF GOOD COMMUNICATION. -RU LINES TO TOP OF TREE TO CIRCULATE OUT WELL. -TEST LINES TO 3500 -PSI. GOOD TEST. 13:00 - 16:30 3.50 KILLW' P DECOMP T -BPM WITH 250 -PSI. -PUMP 51 -BBLS TO GET DIESEL FREE RETURNS. -SWAP OVER AND CIRCULATE CONVENTIONALLY AT 3 -BPM WITH 120 -PSI. - CIRCULATE UNTIL CLEAN 8.5 -PPG SEAWATER RETURNS TO SURFACE. - SLIGHT AMOUNT OF CRUDE IN RETURNS. -NO RETURNS NOTED IN WELL CELLAR BOX OR FROM OA LINE. 16:30 - 17:30 1.00 KILLW P DECOMP MONITOR WELL - STATIC. -BLOW DOWN AND REMOVE LINE FROM TOP OF TREE. 17:30 - 21:00 3.50 WHSUR P DECOMP C AMERQjN REP T-BAR IN TWC. -TEST FROM BELOW TO 250 -PSI LOW FOR 5 -MIN CHARTED AND 1000 -PSI HIGH FOR 10 -MIN CHARTED. GOOD TEST -TEST FROM ABOVE TO 250 -PSI LOW FOR 5 -MIN CHARTED AND TO 3500 -PSI HIGH FOR 10 -MIN CHARTED. - 1900 -hrs TROUBLESHOOT NOT BEING ABLE TO GET HIGH TEST. ACTUATE VALVES AND INSTALL DOUBLE BLOCK NEEDLE VALVES ON TEST PUMP HOSE. GOOD TEST - 1830 -hrs TALK WITH AOGCC REP JOHN CRISP. WOULD LIKE AN UPDATE ON BOPE TEST PROGRESS AT 6AM. 21:00 - 21:30 0.50 WHSUR P DECOMP RD TEST EQUIPMENT AND BLOW DOWN LINES Printed 9/20/2010 4:10:30PM ° rth Amer ica ALASKA BP _2 0 2 AIR gp C3peca# ©r�ummaryRepor R ANZ Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10: 07 2/2/1990 00:00 @42.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 22:30 1.00 WHSUR P DECOMP PJSM - CAMERON BLEED TUBING HANGER AND CONTROL LINE TOO-PSI. -2-BARRIERSFORND ARE TESTED FASDRILL PLUG AN (2),TESTED TWC. - 2200 -hrs, ND TREE AM ADAPTER FLANGE. 22:30 00:00 1.50 BOPSUR P DECOMP CLEAN WELLHEAD. FUNCTION LOCKDOWN SCREWS IN= 3.5 ", OUT = 4.25 ". CHECK HANGER THREADS WITH 4.5" TC II OX. = 6 -RIGHT HAND TURNS. INSPECT BRIDGE CRANE. NU BOPE STACK. 8/14/2010 00:00 - 04:00 4.00 BOPSUR P DECOMP CONFIGURATION - ANNULAR, 3 -1/2" X 6" VBRs, BLIND SHEARS, MUD CROSS, 2 -7/8" X 5" VBRs. - CHANGED THE RAM CONFIGURATION SETUP FROM THE PREVIOUS WELL TO THE ONE BEING USED FOR THIS WELL. -0300 -hrs FUNCTION TEST BOPE. RU TEST EQUIPMENT 04:00 08:00 4.00 BOPSUR P DECOMP_ PERFORM INITIAL BOPE TEST. -TEST TO 250 -PSI LOW AND 3500 -PSI HIGH ON ALL TESTS. HOLD AND CHART EACH TEST FOR 5- MINUTES. -TEST 3 -1/2" X 6" VBRS WITH 4" AND 4 -1/2" TEST JT. TEST 2 -7/8" X 5" VBRS USING 4" P� AND 4 -1/2" TEST JT. TEST ANNULAR USING f (� 4" TEST JT. b -TESTS WITNESSED BY WSL AND TOOLPUSHER. -AOGCC REP JOHN CRISP WAIVED STATE'S RIGHT TO WITNESS THE TEST. 08:00 - 08:30 0.50 BOPSUR P DECOMP BLOW DOWN ALL LINES AND RD TEST EQUIPMENT. 08:30 - 09:00 0.50 BOPSUR P DECOMP PU AND MU DUTCH RISER. -RILDS ON DUTCH RISER. 09.00 - 10.00 1.00 WHSUR P DECOMP PU DSM LUBRICATOR AND MU TOOLSTRING. -MU LUBRICATOR TO DUTCH RISER. - PRESSURE TEST LUBRICATOR TO 250 -PSI AND 3500 -PSI. HOLD AND CHART EACH TEST FOR 5- MINUTES. GOOD TESTS. -PULL TWC. -LD LUBRICATOR, TWC, AND DUTCH RISER. 10:00 12:00 2.00 PULL P DECOMP HOLD PJSM WITH RIG CREW AND CAMERON REPS ON PULLING TUBING HANGER. -MU LANDING JT WITH 4 -112" TCII XO TO TUBI - CAMERON REPS BOLDS. -PULL HANGER FREE AND PULL UP HOLE AT 155K -LBS. - BREAKOUT AND LD LANDING JT AND HANGER. 12:00 - 13:30 1.50 PULL P DECOMP RU TO CIRCULATE. - CIRCULATE SURFACE TO SURFACE AT 6.5 -BPM WITH 450 -PSI. -CLEAN RETURNS. - MONITOR WELL. NO FLOW 13:30 - 14:00 0.50 PULL P DECOMP RU CONTROL LINE SPOOLER. -BLOW DOWN LINES. -RU 4 -1/2" TUBING HANDLING EQUIPMENT. Printed 9/20/2010 4:10:30PM �lor ifAmerica - ALASKA BP "Page 3 Qpra #rur Summary; Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datu 10 : 07 2/2 00:00 @ (above Me Se Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 00:00 10.00 PULL P DECOMP PUL AND LD 4 -1/2" 12.6# 13CR80, VAM TOP TUBING FROM 9744' TO 7704' -SPOOL 1/4" BARE CONTROL LINE. - COLLECTED 52 -SS BANDS OF THE 53 -SS BANDS REPORTED IN THE WELL. - 1700 -hrs, RD CONTROL LINE SPOOLER -1730 -hrs, CONTINUE TO PULL AND LD 4 -1/2" TUBING FROM 7704' - 2000 -hrs, CONTINUE TO PULL AND LD 4 -1/2" TUBING FROM 5767' - 2300 -hrs , CONTINUE TO PULL AND LD 4 -1/2" TUBING FROM 2897' - 0000- hrs,` TO PULL AND LD 4 -1/2" TUBING TO 2104' 8/15/2010 00:00 - 01:30 1.50 PULL P DECOMP PULL AND LD 4 -1/2" 12.6# 13CR80, VAM TOP TUBING FROM 2104' TO SURFACE. CUT JOINT 9.24' FL ARED OUT TO 4.875" OD. CLEAN SMOOTH CUT. NORM TEST TUBING JOINTS, GLM, CUT OFF JOINT TESTED HOT. TESTED WITH MORE CONTAMINATION THE DEEPER THE TUBING WAS. -SSSV TESTED WITHIN LIMITS 01:30 02:00 0.50 PULL P DECOMP RD TUBING HANDLING EQUIPMENT. -CLEAR RIG FLOOR 02:00 - 03:30 1.50 EVAL P DECOMP PJSM RU E -LINE USIT LOG EQUIPMENT 03:30 - 05:30 2.00 EVAL - P' DECOMP USITLO FRQM4500 SURFACE, , LOOKING FOR CEMENT IN 13 -3/8" X 9 -5/8" ANNULUS. 05:30 - 06:30 1.00 EVAL P DECOMP RD E -LINE UNIT. 06:30 - 07:30 1.00 DHB P DECOMP PU 9 -5/8" HES RBP AND MU PER HES REP. 07:30 - 08:30 1.00 DHB P DECOMP SERVICE IRON ROUGHNECK, DRAWWORKS AND TOP DRIVE. 08:30 - 13:30 5.00 DHB P DECOMP RIH WITH 9 -5/8" RBP ON 4" XT39 DP FROM PIPE SHED TO 4112'. -AT 0 845 -HRS, RIG CREW HELD KICK WHILE TRIPPING DRILL. OBSERVATIONS INCLUDED THAT ONCE THE WELL WAS SECURE, SOME HANDS RUSHED TO THEIR STATION. ALSO, IF A CHAIN TONG HAD BEEN USED TO TIGHTEN THE TIW VALVE BEFORE TORQUING WITH THE ROUGHNECK, IT WOULD HAVE TAKEN SLIGHTLY LESS TIME TO FULLY TORQUE THE VALVE. THE FLOOR HANDS COMMUNICATED WELL AND THE CREW RESPONDED SWIFTLY AND SAFELY. -PU WT = 100K -LBS, SO WT = 100K -LBS 13:30 - 15:00 1.50 DHB P DECOMP SET RBP AT 411 R HES REP -COE AT 4117' -SET 20K -LBS DOWN AND THEN PU 1 OK -LBS OVER PU WT TO CONFIRM SET. -SLACK OFF TO NEUTRAL WEIGHT AND RU TO PRESSURE TEST RBP. -TEST RBP TO 250 -PSI FOR 5- MINUTES AND THEN 3500 -PSI FOR 10- MINUTES. GOOD TESTS. -RD TEST EQUIPMENT. Printed 9/20/2010 4:10:30PM Norkh America. ALASKA = °BP Par�4 of ration 5u _ tea �`_R` Q _f L Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10 : 07 2/2/1 00:00 @42.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 19:30 4.50 DHB P DECOMP PULL 2 -STDS OF DRILL PIPE AND RU SAND HOPPER ON TOP OF DP STUMP. - DUMP 2200# OF 20/40 MESH RIVER SAND AT - 1845 -hrs, PUMP A DRILLPIPE VOLUME (42 -BBLS) AT 1.5 -BPM TO CLEAR SAND FROM DRILLPIPE. -RD CIRCULATING EQUIPMENT. 19:30 - 20:30 1.00 DHB P DECOMP POH RACKING BACK DP. -LD RBP RUNNING TOOL 20:30 - 00:00 3.50 WHSUR P DECOMP BLOW DOWN LINES -PULL MOUSE HOLE -ND BOPE STACK -ND TUBING SPOOL -ND CASING SPACER SPOOL. - 2300 -hrs, UNABLE TO REMOVE CASING SPACER SPOOL. WAIT ON CAMERON TO GET FLANGE SPREADERS FROM SHOP. -STAGE NEW WELLHEAD EQUIPMENT IN CELLAR. -2330 -hrs, CONTINUE TO ND CASING SPACER SPOOL. 8/16/2010 00:00 - 02:30 2.50 BOPSUR P DECOMP CHANGE OUT CASING SPACER SPOOL. -NU BOPE. - 0230 -hrs, TEST BREAKS TO 250 -PSI LOW AND 3500 -PSI HIGH FOR 5 -MIN CHARTED. - 0250 -hrs, RD TEST EQUIPMENT BLOW DOWN LINES 02:30 - 03:00 0.50 BOPSUR P DECOMP TEST BOP AND SPACER SPOOL BREAKS TO 250 -PSI LOW AND 3500 -PSI HIGH FOR 5 -MIN CHARTED. GOOD TESTS. -RD TEST EQUIPMENT AND BLOW DOWN LINES 03:00 - 04:30 1.50 CLEAN P DECOMP PJSM 8" MULTISTRING CUTTER BHA #1 -BHA CONSISTS OF 8 -1/4" MULTI - STRING CUTTER, XO, 8 -1/2" OD STABILIZER, AND XO. 04:30 - 06:00 1.50 CLEAN P DECOMP RIH WITH 9 -5/8" CUTTER BHA ON 4" DP FROM DERRICK TO 4023'. -PU WT = 100K -LBS, SO WT = 100K -LBS 06:00 07:00 1.00 CLEAN P DECOMP RIH AND TAG SAND AT 4058' -PU AND TURN PUMPS ON TO LOCATE COLLAR AT 3987'. -SHUT PUMP OFF AND PU AGAIN. -TURN PUMPS ON AND LOCATE SECOND COLLAR AT 3947'. -SHUT PUMPS OFF AND P ciTirlN CUTTER AT 3957' TO MAKE CUT. 07:00 - 08:00 1.00 CLEAN P DECOMP HOLD PJSM WITH LRS, CH2MHILL TRUCK DRIVERS AND RIG CREW. DISCUSS POSITIONS OF PEOPLE, SPILL POTENTIALS AND IMPORTANCE OF GOOD, CLEAR COMMUNICATION. -LRS PREHEAT DIESEL TO 90- DEGREES AND THEN SPOT. -RU LRS. - PRESSURE TEST LINES TO 3500 -PSI. Printed 9/20/2010 4:10:30PM North erica - ALASKA BP. _F?age(f ©peration Summary Report - L Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) -Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datu 10: 07 2/211990 00:0 @42.00ft ( above Mean Sea Leve Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 08:30 0.50 CLEAN P DECOMP CUT 9 -5/8" CASINIr. AT 3957' - ROTATE AT 80 -RPM WITH 2.5K TO 6K -FTLBS OF TORQUE. ROT WT = 104K -LBS. -STAGE PUMPS FROM 3 -BPM TO 6 -BPM WITH 250 TO 710 -PSI. - OBSERVE PUMP PRESSURE DROP TO 500 -PSI AND SEE 50 -PSI ON OA GAUGE INDICATING CUT. 08:30 09:30 1.00 CLEAN P DECOMP LRS PUMP 40 -BBLS OF 90- DEGREE DIESEL DOWN DRILLPIPE AT 2 -BPM WITH 600 -PSI. -SHUT DOWN AND CLOSE UPPER PIPE RAMS. OPEN LINE FROM OA TO FLOWBACK TANK.' -LRS PUMP 20 -BBLS OF 90- DEGREE DIESEL AT2 -BPM WITH 750-PSI. -PUMP 40 -BBLS OF 120- DEGREE 9.8 -PPG BRINE. SEEING CRUDE RETURNS AT FLOWBACK TANK. 09:30 - 10:30 1.00 CLEAN P DECOMP -SHUT IN AND ALLOW DIESEL TO SOAK IN OA FOR 1 -HR. 10:30 - 13:30 3.00 CLEAN P DECOMP'` OPEN UP OA TO FLOWBACK TANK AND PUMP 250 -BBLS OF 120 - DEGREE 9.8 -PPG BRINE AT 2 -BPM WITH 110 -PSI. -WHEN DIESEL RETURNS AT SURFACE, STAGE PUMPS UP TO 6 -BPM WITH 1060 -PSI. -PUMP 40 -BBL SAFE SURF O SWEEP. -CHASE WITH 80- DEGREE SEAWATER FROM PITS AT 2 -BPM WITH 280 -PSI. -WHEN SOAP RETURNED TO TANK, BRING PUMP UP TO4 -BPM WITH 470 -PSI. -CLEAN FLUID RETURNS TO FLOWBACK TANK AT END OF CIRCULATION. -DURING TUE CIRCULAIION THIN ARCTIC. PACK RETURNS WERE SEEN., - MONITOR WELL - STATIC. 13:30 15:30 2.00 CLEAN P DECOMP OPEN UPPER PIPE RAMS AND CLOSE OA TO FLOWBACK TANK. - CIRCULATE BOTTOMS UP THROUGH 9 -5/8" X 4" ANNULUS. -THIN CRUDE/DIESEL RETURNS, CLEANING UP TO CLEAN SEAWATER. - MONITOR WELL - STATIC. -BLOW DOWN TOP DRIVE. 15:30 - 16:30 1.00 CLEAN P DECOMP POH FROM 3957', STANDING BACK 4" DP IN DERRICK. 16:30 - 17:00 0.50 CLEAN P DECOMP LD CASING CUTTER BHA. -GOOD WEAR INDICATION ON CUTTER BLADES. 17:00 - 17:30 0.50 CASING P DECOMP PU 8 -1/4" SPEAR ASSY DRESSED TO CA 9 -5/8" 47# CASING. -DRAIN STACK. 17:30 - 18:00 0.50 CASING P DECOMP RIH AND ENGAGE SPEAR. -PU 1 OK -LBS TO CONFIRM CATCH. - CAMERON REP BOLDS. - CASING PULLS FREE AT 220K -LBS. -PULL HANGER ABOVE FLOOR. HANGER INTACT. - POSITON HANGER BELOW ROTARY TABLE. Printed 9/20/2010 4:10:30PM North- ALASKA - �BP _ Wage 6 X 26 y ©perati „n 5�ammary Report , Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10: 07 2/2/19 00 :00 @42.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 20:30 2.50 CASING P DECOMP CBU AT 6 -BPM WITH 0 -PSI. - 135 -BBLS OF THICK ARCTIC PACK RETURNS DURING CIRCULATION. -PUMP HI VIS SWEEP AND CHASE AT 7 -BPM WITH 0 -PSI PUMP PRESSURE. -VERY CLEAN RETURNS THROUGHOUT CIRCULATION. -SWEEP BROUGHT BACK SMALL AMOUNT OF ARCTIC PACK. 20:30 - 21:30 1.00 CASING P DECOMP PJSM WITH DOYON CASING, RIG CREW, WSLL: VERY GOOD DISCUSSION; DISCUSSED PREVIOUS LESSONS LEARNED FROM KICK WHILE TRIPPING DRILL ABOUT THE NEED TO MAKE SURE POWER TONGS ARE SET UP OR ABLE TO BE'' CHANGED TO THE CORRECT HEADS IF WE TAKE A -KICK IN ORDER TO TORQUE UP TIW VALVE. AS WELL AS THE NEED TO HAVE DOYON CASING TO REPORT TO A SPOT ASSIGNED ON THE RIG FLOOR TO OVERSEA THE CORRECT MAKE -UP OF THE TIW WHEN STABBED INTO THE CASING EITHER FOR A DRILL OR THE ACTUAL EVENT. CONVEYED THAT DOYON CASING REP NEEDS TO VERIFY THE OD ON THE CROSSOVER TO MAKE SURE THE HEAD IN THE POWER TONGS WILL GRAB AND MAKE UP TO THE CASING. IF IT WILL NOT MAKE IT UP THEY NEED TO HAVE AN ADDITIONAL SET OF HEADS FOR THE POWER TONGS TO BE ABLE TO CHANGE OUT. -PULL HANGER TO FLOOR AND LD. TOOK 30K -LBS TO BREAK OUT HANGER. -LD SPEAR ASSEMBLY. 21:30 00:00 2.50 CASING P DECOMP PULL AND LD 9 -5/8” L -80 CASING , - AVERAGE BREAKOUT 26K -LBS. -LD CASING FROM CUT AT 3957' TO 3000' 8/17/2010 00:00 04:30 4.50 CASING P DECOMP CONTINUE PULL AND LD 9 -5/8" L -80 CASING FROM 3000' - AVERAGE BREAKOUT 26K -FT -LBS. - 0245 -hrs, PULL AND LD CASING FROM 1500' - 0400 -hrs, PULL AND LD CASING FROM 500' - 0430 -hrs, OUT OF HOLE -91- JOINTS 9 -5/8" 47# CASING, 17- CENTRALIZERS -CUT JOINT 10.36', CLEAN CUT FLARED OUT TO 10.25" 04:30 - 05:30 1.00 CASING P DECOMP RD CASING HANDLING EQUIPMENT. -CLEAR AND CLEAN RIG FLOOR. 05:30 - 07:30 2.00 CLEAN P DECOMP MU DRESS OFF BHA AND 6 -JTS OF 4 -3/4" DRILL COLLARS. 07:30 09:00 1.50 CLEAN P DECOMP RIH WITH DRESS OFF BHA ON 4" DR PIPE TO 3946'. -PU WT = 107K -LBS, SO WT = 102K -LBS - SCRAPE PACKER SETTING DEPTH FROM 3925' TO 3830'4-TIMES. Printed 9/20/2010 4:10:30PM Noah Ar`e�ioa - ALASKA "BP Page T 2 Operation Summary' Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Activ Datum: 10 : 07 2/2/ 1990 00:00 @ 42.00ft (a bove Mean Sea Leve Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 10:00 1.00 CLEAN P DECOMP WASH DOWN AT 4.5 -BPM WITH 60 -PSI. -TAG 9 -5/8" STUB AT 3587'. -PU AND OBTAIN PARAMETERS. ROTATE AT 40 -RPM WITH 2 TO 3K -FTLBS FREE TORQUE. ROT WT = 102K -LBS. - ROTATE AND WASH OVER STUMP WITH 5 -9K -FT -LBS OF TORQUE TO TAG WITH INNER MILL AT 3964'. - REPEAT WASHING AND ROTATING OVER STUMP 3- TIMES. -WASH OVER STUMP WITHOUT ROTATION OR PROBLEM. 10:00 - 12:30 2.50 CLEAN P DECOMP . PUMP 20 -BBL HI VIS SWEEP AND CHASE AT 11 -BPM WITH 650 -PSI. -AFTER SWEEP TURNS THE CORNER, PU OFF OF STUMP_ -SEE TRACE, "DRIED" ARCTIC PACK RETURNS JUST AHEAD OF BOTTOMS UP AND THROUGH THE SWEEP. DUMPED 55 -BBLS TO THE CUTTINGS TANK. PUMP 40 -BBL SAFE SURF 0 SWEEP AND CHASE AT 11 -BPM WITH 650 -P SI.- 12:30 - 13:00 0.50 CLEAN P DECOMP MONITOR WELL. PUMP DRY JOB TO PREPARE TO POH. 13:00 15:30 2.50 CLEAN P DECOMP POH FROM 3957' AND S/B DP IN DERRICK, LEAVING TOP OF STUB AT 3957'. - 1300 -Hrs, SEND 100 -Bbls OF SEAWATER WITH A TRACE AMOUNT OF ARCTIC PACK LUMPS TO DISPOSAL. - 1400 -Hrs, FLUID ON -BOARD = 380 -Bbls OF 2 %KCI. - 1430 -Hrs, UD DRESS -OFF BHA. BAKER FISHERMAN DESCRIBED GOOD WEAR PATTERN INSIDE THE DRESS -OFF MILL. 15:30 - 16:00 0.50 BOPSUR P DECOMP PJSM TO N/D BOP AND 5' SPOOL N/D eOP AND SET BACK ON THE BOP STUMP. N/D 5' SPOOL AND WINCH IT OUT OF THE CELLAR. 16:00 - 17:30 1.50 WHSUR P DECOMP PJSM TO USE WACHS CUTTER WITH CAMERON TECHS, RIG CREW, AND WSL. WE DISCUSSED THE CONGESTED AREA IN THE CELLAR AND HOW THE CAMERON TECH WOULD SET UP THE CUTTER, THEN LET IT RUN WITHOUT HAVING TO BE NEXT TO THE SPOOL AS IT WAS BEING CUT. -USE RIG VAC SYSTEM TO SUCK OUT 13 -3/8" CASING TO ENSURE NO LEAKAGE DURING CUTTING OPERATIONS. -R/W W ACHS 1 3 -3/8" CASING IMMEDIATELY BELOW THE SPOOL. -R /U 4 -PART SLING TO THE 13 -3/8" FLANGE AND PULL A SLIGHT TENSION ON THE TUGGER LINE. - 1700 -Hrs, BEGIN CUTTING OPERATION. CUT COMPLETELY THROUGH AT 1720 -Hrs. - 1730 -Hrs, UD THE CUTOFF CASING HEAD AND DRAG IT OUT OF THE CELLAR. -R/D THE WACHS CUTTER AND AIR LINE. 17:30 - 18:30 1.00 CASING P DECOMP R/U 9 -5/8" CASING RUNNING EQUIPMENT_ -BRING CENTRALIZERS TO RIG FLOOR -R/U STABBING BOARD. -BRING HES CEMENT HEAD TO RIG FLOOR Printed 9/20/2010 4:10:30PM NOftIi,4rne11G RE:ASKA = Bp Page 8 Qf 26 ©peration Summary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:0O:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active D at u m: 10: 07 2/2/ 00 @4 2.00ft ( above Mean Sea L Date From - To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 18:30 - 19:00 0.50 CASING P DECOMP SERVICE RIG FLOOR EQUIPMENT. 19:00 - 20:00 1.00 CASING P DECOMP CALIBRATE POWER TONGS DUMP VALVE. 20:00 - 00:00 4.00 CASING P DECOMP PJSM WITH BAKER FISHING, BAKER COMPLETIONS, HES CEMENTER, RIG CREW, TOOL PUSHER, WSL. DISCUSSED HAZARDS ASSOCIATED WITH RUNNING CASING, AND LOCATION THAT WILL BE CONGESTED WHEN FLUID, TRUCKS START ARRIVING. ALSO DISCUSSED THE NEED FOR GOOD COMMUNICATION IN THE CELLAR WHILE RUNNING CASING SINCE ALL RETURNS WILL BE COMING TO THE CELLAR. -RUN 9-5/8" 47 #, L80 HYDRIL 563 CASING. -BAKER LOK ALL CONNECTIONS BELOW THE ES CEMENTER. -RUN 1 -FREE FLOATING CENTRALIZER EVERY JOINT ABOVE THE ES CEMENTER. -M /U JOINTS TO 15,800 FT -LBS TORQUE. USE JET LUBE SEAL GUARD ON ALL HYDRIL 563 THREADS - COLLARS AND CENTRALIZERS CATCHING ON 13-3/8" CASING TOP. HAVE TO USE COME -ALONG TO CENTER PIPE ON ALL :JOINTS. - 0000 -hrs, RUN CASING FROM SURFACE TO 1024'. 8/18/2010 00:00 - 10:30 10.50 CASING P DECOMP - CONTINUE RUNNIN 9 -518° 47# Ian HvnRu 563 CASING FROM 1024'. RUN 1 -FREE FLOATING CENTRALIZER EVERY JOINT ABOVE THE ES CEMENTER. -M /U JOINTS TO 15,800 FT -LBS TORQUE. -USE JET LUBE SEAL GUARD ON ALL HYDRIL 563 THREADS COLLARS AND CENTRALIZERS CATCHING ON 13 -3/8" CASING TOP. HAVE TO USE COME -ALONG TO CENTER PIPE ON ALL JOINTS. - 0300 -hrs, RUN IN HOLE TO 2060'. - 0415 -hrs, RUN IN HOLE TO 2608'. - 0530 -hrs, RUN IN HOLE TO 3153'. - 0630 -Hrs, P/U JT #83 AND RIH. - 0800 -Hrs, M/U THE CROSSOVER PUP JOINT, 9 -5/8" BTC BOX x HYDRIL 563 PIN TO 9.85' HYDRIL 563 PUP JOINT AND UD IN PIPE SHED. - 0830 -Hrs, P/U JT #99, RIH. P/U 19.87' PUP JOINT AND RIH. - 0900 -Hrs, CHANGEOUT BAILS. - 0945 -Hrs, P/U JT #100, RIH. P/U WT 205K -Ibs, S/O WT 205K -Ibs. - 1000 -Hrs, P/U 9.85' PUP JOINT AND THE 2.90' XO PUP JOINT PREVIOUSLY MIU. TORQUE UP TO 15,800 -FT -LBS AND RIH. BAKER FISHERMAN RECOMMENDED NOT ROTATING WHILE RIH TO TAG THE STUB AT 3957'. SEE STACK OUT WITH 7K -Ibs AND P/U TO 225K -Ibs TO VERIFY GRAPPLES HAVE ENGAGED. SLACK OFF TO 180K -Ibs, THEN P/U TO 350K -Ibs TO PULL TEST THE CASING FOR A PERFECT TEST. Printed 9/20/2010 4:10:30PM lUr rth°America - ALASKA BP operation Summary Report€ Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10: 07 2/2/1990 00:00 @42.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 11:00 0.50 CASING P DECOMP R/U HALLIBURTON CEMENTING HEAD AND CIRCULATING LINES TO HEAD. R/U CHART RECORDER. 11:00 - 12:30 1.50 CASING P DECOMP PRESSURE TEST CA SING TO 1000 FOR 10 -mins RECORDED ON CHART. P/U TO 225K -lbs TO PREVENT CASING PATCH FROM COMPRESSING FURTHER DOWN ONTO STUB WITH AN INCREASE IN PRESSURE INSIDE THE CASING, PER INSTRUCTIONS FROM BAKER FISHERMAN. INCREASE PRESSURE TO 1200-psi AND STABILIZE, THEN TO 1400 -psi TO STABILIZE, THEN TO 1600 -psi AND SEE A -50 -psi BLEED -OFF IN PRESSURE. CONTINUE TO PRESSURE UP TO 2000 -psi AND HOLD FOR 10- mins' RECORDED ON CHART FOR SOLID TEST. BLEED OFF PRESSURE TO 0 -psi. -1130 -Hrs, WRAP HERCULITE AROUND 9 -5/8" CASING AND 4' UP FROM THE BOTTOM OF THE CELLAR TO PREVENT ANY POSSIBLE SPRAY FROM LEAVING THE CELLAR. - 1145 -Hrs, HOLD PJSM WITH CREW, HALLIBURTON, MI, BAKER, SCHLUMBERGER LEAD, TOOLPUSHER, AND WSL TO DISCUSS THE OPENING OF THE ES CEMENTER. DISCUSSED POSSIBILITY OF A RUSH OF WATER UP THE 9 -5/8" x 13 -3/8" ANNULUS. - 1215 -Hrs, GET ONE VAC TRUCK READY TO SUCK FLUID OUT OF THE CELLAR THEN SLOWLY INCREASE PRESSURE IN 9 -5/8" CASING AND ES CEMENTER OPENS AT 2600 -psi WITH A RUSH — 3 -Bbls OF 2 %KCI WATER RELEASED INTO CONTAINMENT INTO THE CELLAR, WHICH THE VAC TRUCK PICKED UP IN LESS THAN A MINUTE. 12:30 - 14:00 1.50 CASING P DECOMP HOLD PJSM WITH RIG WELDER AND FLOORHANDS TO PREPARE TO WELD THE CENTRALIZING WEDGES IN PLACE AROUND THE 13 -3/8" CASING TO CENTRALIZE THE 9 -5/8 ". - 1240 -Hrs, THE WELDER ASKED FOR A T -LONG x 1/2" DIAMETER LOOPED STEEL CABLE TO PLACE AROUND THE 9 -5/8" CASING, WHICH HE DROPPED DOWN THE 9 -5/8" x 13 -3/8" ANNULUS. WSL CALLED RWO SUPERINTENDENT AND IT WAS AGREED THAT WE COULD CONTINUE WITH DISPLACING THE WELLBORE TO CLEAN 2 %KCI IN PREPARATION FOR THE CEMENT JOB. WSL LEFT MESSAGE ON THE RWO ENGINEER'S CELL PHONE AND ALSO ON THE RWO ENGINEERING TEAM LEAD'S TELEPHONE. - 1300 -Hrs, WELDER INSTALLING THE 4 -ea x 1/2" THICK STEEL PLATE WEDGES TO CENTRALIZE THE 9 -5/8" CASING INSIDE THE 13 -3/8" CASING. Printed 9/20/2010 4:10:30PM North America- ALASKA - BP 3 Page 10 cif 26 ®peratian Summary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) P roject: Point McInty Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10 : 07 2/2/1990 0 0:00 @42.0 (above Mean Sea Lev Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 16:00 2.00 CASING P DECOMP CIRCULATE WELLBORE TO DISPLACE CLEAN, 80F 2 %KCI AT 6 -BPM AND 170 -psi, TAKING ALL RETURNS TO THE CELLAR WHICH ARE SUCKED OUT BY VAC TRUCK. THE CIRCULATION STARTED WITH THE FOLLOWING TRUCKS ONSITE: 3 FULL VAC TRUCKS CARRYING 11 OF DEGREE 2 %KCI, 4 -EA DIRTY VACS, 1- SUPERSUCKER. - 1435 -Hrs, WITH 262 -Bbls PUMPED, TEMPERATURE OF FLUID PUMPED IS 95F AT 8.4 -ppg- HEAVY. TEMPERATURE OF RETURNS IN THE CELLAR IS 84F, WEIGHT IS 8.5 -ppg. -1545 -Hrs; LOAD OUT 2 -FULL TRUCKLOADS OF RETURNS TO DISPOSAL. 16:00 16:30 0.50 CASING P DECOMP PJSM FOR CEMENT JOB WITH SCHLUMBERGER, MI CH2MHILL, RIG CREW, TOOLPUSHER AND WSL TO DISCUSS THE CEMENT JOB STEPS AND THE SAFETY ASPECTS. OF PRIMARY CONCERN IS TRAPPED PRESSURE AND LEAKS IN ALL THE LINES. THERE ARE THREE VAC TRUCKS, A SUPERSUCKER, AND THE RIG CELLAR PUMP RIGGED INTO THE CELLAR TO TAKE ALL RETURNS. ANOTHER CONCERN IS THAT THE CEMENT INSIDE THE CASING WILL CAUSE A RAPID INCREASE IN FLOW RATE OF THE RETURNS TO THE CELLAR. COMMUNICATION PROTOCALS WERE REVIEWED AND EVERYONE WAS REMINDED OF THE REQUIREMENT TO STOP THE JOB IF A PROBLEM OCCURS. -THE TOOLPUSHER ALSO HELD AN AFTER ACTION REVIEW WITH RESPECT TO THE FLUID DISPLACEMENT AND THE FACT THAT THE WELDER DROPPED A Tx 1/2" CABLE STRAP DOWN THE 9 -5/8" x 13 -3/8" ANNULUS, REMINDING EVERYONE THAT ALL HOLES MUST BE COVERED BEFORE ANY WORK IS PERFORMED. A GOOD POINT WAS THAT A FLOORHAND WAS DESIGNATED TO MARK ALL HOSES WITH A NUMBER CORRESPONDING TO THE TRUCK IT WAS ATTACHED TO, SPECIFICALLY, HE USED CHALK TO MARK AT EACH END OF EACH HOSE. Printed 9/20/2010 4:10:30PM I Nd,rth' A61 rlca - ALASKA -BP' " :Page 1 of2s 00ration Summary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10 : 07 2/2/1990 00:00 @42.0 (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 19:30 3.00 CASING P DECOMP SCHLUMBERGER LINES ARE HOOKED UP AND READY TO TEST. - SCHLUMBERGER PUMP 5 -Bbls OF FRESHWATER TO TEST THE LINES AT 3500 -psi. TEST RECORDED ON CHART. - 1648Hrs, START PUMPING 260 -Bbls OF 15.8 -ppg, CLASS G GASBLOK CEMENT AT 3,5 -BPM AND 330 -psi. WORK UP TO 4.5 -BPM AND 550 -psi, PUMPING DENSITY 15.76 TO 15.80 -ppg• 1720-Hrs, 145 -Bbls PUMPED, 15.98 -ppg, 5:0 -BPM, 696 -psi. - 1745 -Hrs, SCHLUMBERGER FINISH PUMPIN 260 -Bbls OF 15.8 -ppg, CLASS G, GASBLOK CEMENT. - - rs, FIALLIBURTON DROPPED THE ES CEMENTER CLOSING PLUG AND �5 SCHLUMBERGER CHASED THE PLUG OUT WITH 10' Bbls OF FRESHWATER. -1752 -Hrs, SWAP OVER TO RIG PUMP TO DISPLACE CEMENT OUT OF 9 -5/8" AND INTO 9 -5/8" x 13 -3/8" ANNULUS. PUMP AT 6 -BPM, 160 -psi. TAKES 130 -Bbls TO CATCH THE PLUG. PRESSURE INCREASES TO 640 -psi WITH 200 -Bbls AWAY. - 1835 -Hrs, SLOW PUMP RATE TO 2 -BPM AT 3000 -STKS (254 - Bbls). - 3100 -STKS, SLOW RATE TO 1.2 -BPM, 1520 -psi. - 1847 -Hrs, 3294 -STKS, PLUG BUMPS; CONTINUE TO INCREASE PRESSURE TO CLOSE THE ES CEMENTER. ES CEMENTER CLOSES AT 2500 -psi AND 3311 -STKS (280- Bbls). - 1849 -Hrs, CEMENT IN PLACE. BRING PRESSURE UP TO 2800 -psi AND HOLD, RECORDING ON CHART. - 1908 -Hrs, CHECK FOR FLOW AND NO FLOW IN EITHER DIRECTION. -BLOW DOWN CEMENT LINES. SUPERSUCKER HAULED OFF 30 -Bbls OF CEMENT RETURNS, AND VAC TRUCKS HAULED OFF —10 -Bbls ALONG WITH 2 %KCI RETURNS FROM CELLAR. 40 -Bbls OF CEMENT WERE RETURNED TO SURFACE BASED ON THE STROKE COUNT FOR THE RIG PUMP. - 1930 -Hrs, THE TOP OF CEMENT HAD SLUMPED TO ABOUT 10' BELOW THE TOP OF THE 13 -3/8" CUTOFF. 19:30 - 00:00 4.50 CASING P DECOMP WAIT ON CEMENT - PERFORM GENERAL HOUSEKEEPING, LIGHT MAINTENANCE AND PAINTING. Printed 9/20/2010 4:10:30PM North America ALASKA BP Page 1z 26 Operation Summary Report Dvt Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Acti Datum: 10 : 07 2/2/1990 00:00 @42.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/19/2010 00:00 - 10:00 10.00 CASING P DECOMP WAIT ON CEMENT - PERFORM GENERAL HOUSEKEEPING, LIGHT MAINTENANCE AND PAINTING. -BRING DRILL -OUT BHA TO RIG FLOOR. - PREPARE BOPE TEST EQUIPMENT. - 0640 -Hrs, WSL CALLED AOGCC WITH AN UPDATE FOR IMPENDING WEEKLY BOP TEST. - 0645 -Hrs, CHUCK SCHEVE, AOGCC INSPECTOR, RETURNED CALL AND WAIVED WITNESS OF THE WEEKLY BOP TEST. - 0900 -Hrs, SUCK OUT 9 -5/8" CASING TO, PREPARE FOR WACHS CUT IN THE CELLAR. - 0900 -Hrs USE TAPE MEASURE TO TAG CEMENT INSIDE THE 9 -5/8" x 13 -3/8" ANNULUS AT 10'-3" DOWN FROM THE 13 -3/8" STUB. 10:00 - 11:30 1.50 CASING P DECOMP EMC M/U THE'WACHS CUTTER TO 9 -5/8" TO P REPARE FOR CI ITTING THE 9 -518" HOLD PJSM WITH RIG CREW, FMC TECHS, AND WSL TO DISCUSS THE CUTTING OPERATION. FMC PERSONNEL REVIEWED THE DOYON 16 REQUIREMENT FOR AN ALTERNATE ENTRY PERMIT FOR THE CONGESTED CELLAR. WE ALSO REVIEWED THE HEIGHT CALCULATIONS FOR CUTTING THE 9 -5/8" TO ENSURE THAT THE NEW WELLHEAD TIE -IN REQUIREMENTS WERE AS CLOSE AS POSSIBLE TO THE OLD WELLHEAD. WE ALSO NEEDED TO ENSURE THAT WE HAD SUFFICIENT CLEARANCE TO N/U THE BOP STACK. - 1100 -Hrs, DRILLER RELIEVED PULL ON THE ELEVATORS, LEAVING — 1200 -lbs TENSION FOR THE CUT. - 1105 -Hrs, BEGIN CUTTING OPERATIONS. THE CUT WAS CLEAN AT 1130 -Hrs. 11:30 - 15:00 3.50 WHSUR P DECOMP PJSM TO INSTALL THE FMC CASING HEAD. WE DISCUSSED THE STEPS NECESSARY TO ENERGIZE THE SEAL ASSEMBLY WHICH REQUIRED TWO OR MORE ROTATIONS OF TORQUEING THE UNDERSIDE AND OVERHEAD BOLT PATTERNS TO 400- FT -LBS. - 1345 -Hrs, R/U TO PT THE SEAL TO 1425 -psi OR 30% OF THE 9 -5/8" CASING COLLAPSE. H/U THE CRYSTAL N- VISION REFERENCE PRESSURE RECORDER TO THE PORTA -POWER PUMP LINE TO THE SEAL TEST PORT. THIS HAND -HELD RECORDER IS EASY TO USE AND APPEARS TO BE ROBUST AND ACCURATE ENOUGH FOR THIS TYPE OF PRESSURE TESTING AND SUBSEQUENT REPORTING REQUIREMENTS. TEST STARTED WITH 1515 -psi AND FINISHED WITH 1466 -psi FOR GOOD TEST. 15:00 - 16:00 1.00 WHSUR P DECOMP PJSM TO P/U AND INSTALL THE TUBING HEAD. INSTALL FMC TUBING HEAD. 16:00 19:00 3.00 BOPSUR P DECOMP N/U TUBING SPOOL AND BOPE. Printed 9/20/2010 4:10:30PM AS North America: - f�LASKA - BP' Q� 22' C ,penAW Summary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00 ) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 212/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Act ive Datum: 10 : 07 2/2 00:00 @42 .00ft (above Mean S Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 21:00 2.00 BOPSUR P DECOMP R/U TEST EQUIPMENT. - INSTALL LOWER TEST PLUG. - 1930 -hrs, TEST CASING WELLHEAD BREAK TO 250 -PSI LOW AND 3500 -PSI HIGH FOR 5 -MIN EACH CHARTED. - 2000 -Hrs, PULL AND LID LOWER TEST PLUG -SET UPPER TEST PLUG. - 2030 -hrs, R/U BOPE TEST EQUIPMENT. 21:00 - 00:00 3.00 BOPSUR P DECOMP PJSM - PERFORM WFFKI Y ROPF TFST -TEST TO 250 -PSI LOW AND 3500 -PSI HIGH ON ALL TESTS. HOLD AND CHART EACH TEST FOR 5- MINUTES. -TEST 3 -1/2" X 6" VBRS WITH 4" AND 4- 1/2 "�� TEST JT. TEST 2 -7/8" X 5" VBRS USING 4" AND 4 -1/2" TEST JT. TEST ANNULAR USING 1 fry 4" TEST JT. -TESTS WITNESSED BY WSL AND TOOLPUSHER. -AOGCC REP CHUCK SCHEVE WAIVED STATE'S RIGHT TO WITNESS THE TEST. 8/20/2010 00:00 - 03:00 3.00 BOPSUR P DECOMP - PERFORM WEEKLY BOPE TEST -TEST TO 250 -PSI LOW AND 3500 -PSI HIGH ON ALL TESTS. HOLD AND CHART EACH TEST FOR 5- MINUTES. -TEST 3 -1/2" X 6" VBRS WITH 4" AND 4 -1/2" TEST JT. TEST 2 -7/8" X 5" VBRS USING 4" AND 4 -1/2" TEST JT. TEST ANNULAR USING 4" TEST JT. -TESTS WITNESSED BY WSL AND TOOLPUSHER. -AOGCC REP CHUCK SCHEVE WAIVED STATE'S RIGHT TO WITNESS THE TEST. 03:00 - 04:00 1.00 BOPSUR P DECOMP -BLOW DOWN LINES, R/D BOPE TEST EQUIPMENT -PULL TEST PLUG - INSTALL WEAR RING. -R /U BAILS AND ELEVATORS. 04:00 - 12:30 8.50 CLEAN P DECOMP PJSM - 0420 - hrs, M/I I g - ., /g" .FMFNT DRII I 011T RHA #4. -P /U DP BY SINGLES FROM THE PIPE SHED. -M /U 51- JOINTS, THEN POH RACKING BACK. - CONTINUE IN HOLE WITH REMAINING PIPE FROM THE PIPE SHED TO TOC. I I l Printed 9/20/2010 4:10:30PM North America - ALASKA - BP Page 14 6626 ff 3 Operation Summary Report ,3.. �a Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Datefrime: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Da tum: 10: 07 2/2/1990 00:00 @42.00ft (abo Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 21:30 9.00 CLEAN P DECOMP -SLOW PUMP RATES: #1 - -30 -SPM AT 40 -psi; 40 -SPM AT 90 -psi. #2 - -30 -SPM AT 50 -psi; 40 -SPM AT 100 -psi. -GET PARAMETERS: P/U WT 105K -Ibs, S/O WT 103K -Ibs, ROT WT 105K -Ibs, 70 -RPM, FREE TORQUE 2K -ft -Ibs, 7 -BPM AT 400 -psi. - 1300 -Hrs, STOP ROTATING AND PUMPING AND RIH TO TAG ON CEMENT AT 3894' WHICH CORRESPONDS TO THE TOP OF THE 19' LONG 9 -5/8" HYDRIL 563 box XO TO 9 -5/8" BTC pin. CONTROL DRILLING WITH 1 -2K -Ibs WOB, 90- 100 -RPM, 6 -7 -BPM AT 350 - 400 -psi. -1410 -Hrs MAKE 20' TO 3914', WHICH IS THE TOP OF THE ES CEMENTER. CONTINUE TO CONTROL DRILL AT SAME PARAMETERS. - 1700 -Hrs, MAKE IT THROUGH TO 3926', WHICH IS THROUGH THE PUP JOINT BELOW THE ES CEMENTER. - 2003 -Hrs, DRILL CEMENT TO 3990'. -2100 -Hrs, TAG SOLID AT 4055'. DRILL DOWN TO 4062' 2112-Hrs, DRY DRILL ON SAND FROM 4062' TO 4064' WITH 1- 2K -LBS WOB. 21:30 - 23:00 1.50 CLEAN P DECOMP CIRCULATE HI -VIS SWEEP. 2230-Hrs, BOTTOMS UP WITH SWEEP HAD A LOT OF SAND AND PLUG PIECES. CONTINUE CIRCULATE UNTIL RETURNS CLEANED UP WITH MINIMAL SAND RETURNS. - 2240 -Hrs, FLOW CHECK. NO FLOW. -PUMP DRY JOB, PREPARE TO POH. 23:00 00:00 1.00 CLEAN P DECOMP POH RACKING BACK DP FROM 4060' TO 3194' 8/21/2010 - CLEAN - P DECOMP 00:00 - 02:00 2.00 CLEAN P DECOMP POH RACKING BACK DP FROM 3194' TO SURFACE. - 0100 -Hrs, LD OIL JARS, PUMP OUT SUB, AND BUMPER SUB. -DUMP OUT BOOT BASKETS. IN BASKETS RECOVERED —8 -GAL OF SAND AND CEMENT, 3 -CUPS OF METAL PIECES RANGING IN SIZES FROM 1 -4" IN DIAMETER. SOME OF THE METAL PIECES WERE FROM A CENTRAL BOW- SPRING CENTRALIZER -2 OF THE 3 BIT JETS WERE COMPLETELY PLUGGED. THE BIT ITSELF WAS 2/3 FULL OF SAND, AND ABOUT TO BE PLUGGED OFF. 02:00 03:00 1.00 CLEAN P DECOMP PJSM -MU CLEAN OUT RCJB AND 9 -5/8" CASING SCRAPER BHA #5. 03:00 - 05:00 2.00 CLEAN P DECOMP RIH WITH 4" DP FROM THE DERRICK. TO 4044' 05:00 - 06:00 1.00 CLEAN P DECOMP SLIP AND CUT DRILL LINE Printed 9/20/2010 4:10:30PM NOrth 1�1t�Ok - ALASM _ BP Page 15 of26 IUEN Operation = Report Common Well Name: P1 -07 AFE No Event Type: WORKOVIER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000-00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active D atum: 10 : 07 2/2 /1990 00:00 @42.00ft (abov Me an Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 09:00 3.00 CLEAN P DECOMP OBTAIN DRILLING PARAMETERS: P/U WT 112K -Ibs, S/O WT 107K -Ibs, ROT WT 11 OK -Ibs, 4 -1/2 -BPM AT 190 -psi. STOP PUMP AND SLOWLY RIH TO TAG AT 4069'. - 0615 -Hrs, P/U TO 4044', BREAK OFF TOPDRIVE AND DROP BALL TO REVERSE THE FLOW THROUGH THE RCJB. M/U TO TOPDRIVE, START PUMP AND BRING UP TO 9 -BPM AT 990 -psi. SLOWLY RIH TO 4069'. - 0645 -Hrs, PUMP 20 -Bbl HI-VIS SWEEP AT 9 -BPM, 1000 -psi. - 0705 -Hrs, MAKE IT TO 4084' IN 5' TO 10' BITES AS WELL AS SLOWLY RECIPROCATING THE STRING FOR 20'. SEE LOTS OF SMALL ( -1/4 ") BALLS OF SAND AND CEMENT COME ACROSS SHAKERS. -0720 -Hrs, ALL OF THE SWEEP HAS PASSED THROUGH THE SHAKERS AND SMALL BALLS OF SAND AND /OR CEMENT CONTINUE TO COME ACROSS SHAKERS. CONTINUING TO CIRCULATE AT 9 -BPM, 1000 -psi. 0725-Hrs, MAKE IT TO 4102' OR 10' ABOVE THE RBP AT 4112'. PUMP ANOTHER 20 -Bbl NI-VIS SWEEP. CONTINUE TO RECIPROCATE PIPE IN 20' STROKES. DO NOT EXPERIENCE ANY DRAG DURING RECIPROCATION, AND DIDN'T SEE ANYTHING HARD WHILE WORKING DOWN IN 5' TO 10' BITES. GET A LOT OF SAND ACROSS THE SHAKERS WHEN THE SWEEP GETS TO SURFACE. - 0815 -Hrs, DECIDE TO MIX ANOTHER 20 -Bbl SWEEP AND PUMP IT AROUND. THE SHAKERS ARE FILLED WITH SAND JUST MINUTES AFTER THE SWEEP IS PUMPED. THE RETURNS ALSO CHANGE TO INCLUDE CLABBERED, VISCOUS STRINGS CONTAINING SAND AND /OR CEMENT. THE CUTTINGS TANK HAS A MOUND OF SAND AND CEMENT FORMING BELOW THE CUTTINGS CHUTE. 09:00 - 12:00 3.00 CLEAN P DECOMP POH AND S/B DP IN DERRICK. BREAK OUT AND UD RCJB BHA. EMPTY BOOT BASKETS AND GET BACK 4- GALLONS OF SAND, CEMENT, AND METAL SHAVINGS. EMPTY THE RCJB AND FIND 7 -LARGE CHUNKS (2 WERE FIST - SIZED) OF CEMENT AND SOME SMALLER (< 1/2" TO 1 ") PIECES OF ALUMINUM. SEND 175 -Bbls OF 2 %KCI WATER AND 12 -yds OF SAND AND CEMENT TO G &I DISPOSAL. 12:00 13:00 1.00 CASING P DECOMP R/U TO PRESSURE TEST CASING TO 3500 si. CLOSE THE BLIND /SHEAR RAMS AND TEST FROM THE 9 -5/8" RBP AT 4112' TO THE SURFACE FOR 30- MINUTES, CHARTED. PRESSURE HELD ROCK SOLID. Printed 9/20/2010 4:10:30PM North America ALASKf�BP Page 16 26 ©perat�on- Surnrnary Report i Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10 : 07 2/2/1990 00:00 @42.00ft (above M ean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 15:30 2.50 CLEAN P DECOMP PJSM WITH RIG CREW AND HALLIBURTON TECH TO RIH WITH RBP RETRIEVAL TOOL. -M /U RBP RETRIEVAL TOOL AND RIH. - 1430 -Hrs, TAG SAND AT 4102'. P/U AND START PUMP, BRING UP TO 7 -1/2 -BPM, 280 -psi. HALLIBURTON REQUESTED WE CIRCULATE THE LONG WAY TO GET SAND OFF THE RBP. INCREASE PUMP RATE TO 8 -1/2 -BPM AT 550 -psi. PUMP 20 -Bbl HI-VIS SWEEP AND WAIT ON RETURNS. SEE BALLING SAND AND CEMENT AND SOME CLABBERED VISCOUS FLUID ACROSS SHAKERS. 15:30 16:00 0.50 DHB P DECOMP PER INSTRUCTIONS FROM HALLIBURTON TECH, SET DOWN SLOWLY ONTO RBP AT 4112' STACK OUT WITH 15K -Ibs DOWN, P/U AND DO NOT HAVE RBP. SET DOWN WITH 25K -Ibs, P/U AND DO NOT HAVE RBP. REPEAT WITH 15K -Ibs DOWN AND AGAIN WITH 20K -Ibs DOWN, BUT WITH NO SUCCESS. HALLIBURTON TECH CALLED HIS LEAD TO REQUEST TO GO TO 30K -Ibs. TRY SETTING DOWN WITH 30K -Ibs, BUT NO SUCCESS. DECIDE TO MAKE ANOTHER RCJB RUN AFTER GETTING AGREEMENT FROM RWO SUPERINTENDENT WHO CALLED THE RIG DURING THE RIG FLOOR DISCUSSION BETWEEN THE HALLIBURTON TECH, TOOLPUSHER, AND WSL. 16:00 17:30 1.50 CLEAN P DECOMP POH AND S/B DP IN DERRICK. - 1700 -Hrs, BREAK OUT AND L/D THE RBP RETRIEVAL TOOL. SEE NO DAMAGE INSIDE THE TOOL OR INDICATION THAT THE TOOL HAD ENGAGED THE RETRIEVAL NECK. 17:30 - 18:30 1.00 CLEAN P DECOMP M/U NEW RCJB WITH 4' EXTENSION. RIH WITH 4 -ea BOOT BASKETS. BHA # 6 18:30 - 20:00 1.50 CLEAN P DECOMP RIH WITH DP FROM THE DERRICK TO 4110' 20:00 - 22:30 2.50 CLEAN P DECOMP TAG AT 4110' - OBTAIN PARAMETERS P/U 107K -LBS, S/O 105K -LBS, ROTATING AT 60 -RPM 105K -LBS WITH 2K FT -LBS TORQUE. -PUMP AT 7.6 -BPM WITH 570 -PSI BEFORE BALL DROP. -DROP BALL. WHEN BALL ON SEAT AT 7.6 -BPM HAVE 1810 -PSI. -WASH DOWN TO 4112' TAG TOP OF RBP. -CLEAN RECIPROCATING AND ROTATING WITH VARIOUS PUMP PARAMETERS. WHILE PUMPING NOTICED SAND AND PIECES OF PLUG RUBBER ACROSS SHAKERS. - 2130 -Hrs, CIRCULATE HI-VIS SWEEP. SOME SAND IN RETURNS. - CIRCULATE AT 7.6 -BPM WITH 1840 -PSI. 22:30 - 22:30 0.00 CLEAN P DECOMP FLOW CHECK. NO FLOW -PUMP DRY JOB. BLOW DOWN TOP DRIVE. 22:30 - 00:00 1.50 CLEAN P DECOMP POH RACKING BACK DP FROM 4112' TO SURFACE. Printed 9/20/2010 4:10:30PM North America - ALASKA BP, Page [z of z6�' Operation Summary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datu 10: 07 2/2/19 00 :00 @42.00ft (a bove Mean S Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/22/2010 00:00 01:00 1.00 CLEAN P DECOMP LD BHA. IN RCJB RECOVERED 2- PIECES OF A BOW- SPRING CENTRALIZER BANDS 1- 3" LONG AND 1- 2" LONG. - BOOT BASKETS 1 AND 2 RECOVERED 3 -GAL OF SAND AND METAL SHAVINGS. - BOOT BASKET 3 RECOVERED HALF A GALLON OF SAND AND LARGE CEMENT CHUNKS. - BOOT BASKET 4 RECOVERED HALF A GALLON OF SAND AND A 1" LONG PIECE OF A'BOW- SPRING CENTRALIZER. 01:00 - 05:30 4.50 DHB P DECOMP RIH WITH RBP R ETRIEVA L TOOL - 0230 -Hrs, "TAG AT 4112'. P/U 102K -LBS. - WORK PIPE TO FREE RBP. - 0300 -Hrs, CIRCULATE BOTTOMS UP. DID NOT SEE ANY DEBRIS OR GAS AT BOTTOMS UP. - 0400- Hrs,'FLOW CHECK WELL. NO FLOW AND NO LOSSES. -0415 -Hrs, POH RACKING BACK DP. 05:30 08:00 2.50 CLEAN P DECOMP CLEAR RIG FLOOR -PICK UP AND M/U DRILL -OUT / DRESS -OFF (MAGNUM) BHA: 3 -5/8" CONVEX JUNK MILL, BIT SUB, 5 -JTS OF 2 -7/8" PAC HT DP, 3 -1/8" PONY COLLAR WITH 3 -7/8" BLADE, INNER DRESS -OFF MILL, ROTARY DRESS -OFF SHOE 3 -ea 5 -3/4" WASHPIPE EXTENSIONS, WASHOVER BOOT BASKET, XO SUB, 7" CASING SCRAPER, BIT SUB, BUMPER SUB, OIL JAR, PUMP -OUT SUB, AND 6 -ea 4 -3/4" DCS. 08:00 - 12:30 4.50 CLEAN P DECOMP R WITH THE MAGNUM BHA ON DP F ROM DERRICK. STOP EVERY 20 -STDS TO PUMP THROUGH THE BIT TO ENSURE IT'S OPEN. -STOP AND PUMP THROUGH BIT EVERY 20- STANDS. - 1120 -Hrs, RIH SLOWLY WITH STAND #71 AND SEE THE TOP OF THE 7" LINER, BUT THE STRING EASILY DROPS THROUGH. - 1210 -Hrs, RIH WITH STAND #85. PERFORMING FLUID SWAP OUT OF PITS FROM 8.5 -ppg 2% NaCl BRINE TO 9.0 -ppg BRINE. FILLING DRILLPIPE WITH 9.0 -ppg BRINE WHILE RIH. 12:30 - 14:30 2.00 CLEAN P DECOMP 1230 -Hrs, RIH WITH STAND #97, STOP AND SWAP ALL WELLBORE FLUID TO 9.0 -ppg BRINE IN ANTICIPATION OF 0131 .1 JSOUT, THE HALLIBURTON4 -1/2" FASDRIL PLUG. CIRCULATE IN 9.0 -ppg BRINE FROM PITS AT 5- 1 /2 -BPM AND 1700 -psi. - 1430 -Hrs, FINISH WELLBORE DISPLACEMENT TO 9.0 -ppg BRINE WITH FULL PITS (450 -Bbls) AND 325 -Bbls IN TWO VAC TRUCKS ON LOCATION. Printed 9/20/2010 4:10:30PM North America - ALASKA - BP Page�18 t�f 2f" Qperation Summary Report Common Well Na P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10: 07 2/2/1990 00:00 @42.00ft (above Mean Sea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 17:30 3.00 CLEAN P DECOMP HOLD PJSM WITH RIG CREW, MI MUD ENGINEER, ADP STUDENTS, TOOLPUSHER AND WSL TO DISCUSS FASDRIL PLUG �£ MILLING OPERATION. IMPORTANT ITEMS DISCUSSED: -WELL KILL SHEET MUST BE FILLED IN, WHICH THE DRILLER AND FLOORHANDS HAD ALREADY COMPLETED; -SI STEPS FOR TAKING A KICK WHEN THE PLUG IS PENETRATED WITH THE CONVEX BIT. THE FLOORHANDS, PITWATCHER, AND DRILLER EXPLAINED THEIR POSITIONS TO RESPOND TO A KICK. -HOW TO BLEED OFF TORQUE TO PREVENT BACKING OFF OF THE 2 -7/8" HT PAC DP; -HOW TO GET THE CORRECT OVER - TORQUE SETTING FOR MILLING ON THE FASDRIL PLUG; - 1500 -Hrs, SLOW PUMP INFO: PUMP #1 30 -SPM @ 300 -psi, 40 -SPM @ 600 -psi; PUMP #2 30-SPM @ 520 -psi, 40 -SPM @ 890 -psi. - 1505 -Hrs, P/U STD # 98 AND SLOWLY RIH TO TAG TOP OF 4 -1/2" STUB AT 9744', BUT SLIPPED THROUGH WITHOUT SEEING A BOBBLE. - 1530 -Hrs, P/U STD #99 AND WU TO TOPDRIVE. BRING ON PUMP TO 2 -BPM, 170 -psi. GET PARAMETERS: FREE TORQUE AT 20 -RPM IS 6K -FT -LBS, FREE TORQUE AT 50 -RPM IS 8K. DECIDE TO CHECK FREE TORQUE WITH 2 -7/8" HT PAC ABOVE THE 4 -1/2" STUB. S/B STD #99 IN DERRICK. - 1600 -Hrs, M/U TO STD #98 AND GET FREE TORQUE WITH THE SAME RESULTS. P/U STD #99 AND CONTINUE SLOWLY RIH WITH 20 -RPM, 7K -FT -LB TORQUE, 2 -BPM, 170 -psi. KEEP WOB AT —2K -Ibs, BUT MAKE STEADY HEADWAY THROUGH JUNK OR SEEING 7" CASING SCRAPER DRAG IN THE 7 ". - 1630 -Hrs, INCREASE RPM TO 40 -RPM, THEN TO 50 -RPM WITHOUT SEEING AN INCREASE IN TORQUE - 1655 -Hrs, TAG PLI JG AT 9R ?4' I PM KE —2K -Ibs WOB, 50 -RPM, AND TORQUE VARIES FROM 5K -FT -LBS TO 9K -FT -LBS. - 1700 -Hrs, D RILL THROUGH FASDRIL PLUS. L AND WELL STARTS LOSING A CALCULATED 10 -13PH. CONTINUE ROTATING AND PUSH PLUG TO 9855'. - 1710 -Hrs START GETTING SLIGHT GAIN TO PITS AND DECIDED TO SI THE WELL. P/U DP TO GET THE TOOL JOINT ABOVE THE RIG FLOOR. /I WI AND THE CHOKE. PIT GAIN IS 4.5 -Bbls. SICP = 50 -psi; SIDP = 10 -psi. THE BIT IS AT 9828'. - 1720 -Hrs, WSL CALL RWO SUPERINTENDENT TO REPORT WELL SI, THEN CALL RWO ENGINEER TO LEAVE MESSAGE ON ANSWERING MACHINE. Printed 9/20/2010 4:10:30PM North America , ALASKA - BP Page 1 of 26 = , qw Oration Summary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datu 1 0: 07 2/2/1990 00:00 @42.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 21:00 3.50 CLEAN P DECOMP BEGIN WELLKILL OPERATION WITH A PLANNING MEETING. FILL OUT A KILL SHEET AND HAVE A SHORT AAR TO DISCUSS THE WELL S/I THAT WAS JUST ACCOMPLISHED. WE COMPARED IT TO THE S -100 S/I THAT THE SAME CREW HAD PERFORMED AND THEY FELT MORE COMFORTABLE WITH THE STEPS THEY HAD TAKEN. - 1750 -Hrs, SICP 10 -psi, SIDP 20 -psi. BEGIN CIRCULATING OUT THE INFLUX AT 2 -BPM AND IT TAKES 12 -Bbls TO FILL LINES AND GAS BUSTER. - 1800 -H'rs, INCREASE RATE TO4 -BPM WITH 590 -psi ON THE DP AND 0 -psi ON THE CASING - 1950 -Hrs, AT 5000 -STKS BEGIN SEEING OIL IN THE RETURNS, BEGIN OVERBOARDING RETURNS UNTIL RETURNS CLEAN UP. PUMP 127 -BBLS OVERBOARD. CURRENT LOSS RATE OF 110 -BPH TO THE WELL. - 2025 -Hrs, COMPLETED CIRCULATION WITH ADDITIONAL CIRCULATING TO ACCOUNT FOR LOST FLUID DURING WELL KILL. LOST 175 -BBLS. -S /D PUMPS TO FLOW CHECK WELL. NO FLOW. - 2047 -Hrs, OPEN ANNULAR. FLUID LEVEL DROPPING. MONITOR WELL FOR 10 -MIN - 2057 -Hrs< FILL HOLE WITH 16 -BBLS ESTABLISH STATIC LOSS RATE OF 96 -13PH. 21:00 22:00 1.00 CLEAN P_ DECOMP R TO DRESS -OFF 4.5" TUBING STUB. D ID NOT SEE ANY INDICATION OF PLUG REMAINS WHEN THE PAC DP EXITED THE TUBING STUB AT 9864'. -TAG STUB AT 9740'. - ESTABLISH PARAMETERS. AT 50 -RPM 8K- FT -LBS TORQUE. PUMPING AT 2 -BPM WITH 80 -PSI. -DRESS STUB WITH OUTER DRESS -OFF MILL, CONTINUE IN HOLE TO DRESS -OFF WITH INNER MILL. DRESS -OFF ABOUT 3 ". -FLOW CHECK WELL. LOSING FLUID BUT SEE A LOT OF BUBBLING AT SURFACE. 22:00 - 00:00 2.00 CLEAN P DECOMP CIRCULATE BOTTOMS UP. 5 -BPM WITH 900 -PSI 48 -BPH LOSS RATE. - 2345 -Hrs, FLOW CHECK WELL. NO FLOW, LOSING FLUID WITH NO BUBBLING SEEN AT SURFACE. Printed 9/20/2010 4:10:30PM North America - ALASKk _ BPPage 20 Operation Summary `Report E Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10 : 07 2/2/1990 00:00 @42.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/23/2010 00:00 12:30 12.50 CLEAN P DECOMP POOH LDDP FROM 9700' -RUN SCRAPER ACROSS PACKER SET DEPTH 4- TIMES. - 0230 -Hrs, POOH LDDP FROM 6800' - MAINTAIN HOLE FILL RATE AT 60 -BPH LOSS RATE. - 0330 -Hrs, POOH LDDP FROM 5884'. MAINTAIN HOLE FILL WITH 43 -BPH LOSS RATE. - 0450 -Hrs, POOH LDDP FROM 4834'. MAINTAIN HOLE FILL WITH 40 -BPH LOSS RATE. -0630 -Hrs, UD JT #207. - 0700 -Hrs, CALL AOGCC TO ALERT THEM OF BOP TEST FOR THE ANNULAR PREVENTER AND THE CHOKE HCR VALVE. -0730 -Hrs, CHUCK SCHEVE CALLED TO WAIVE WITNESS OF THE BOP TEST. - 0930 -Hrs, B/O AND UD DRILL COLLARS. 1000-Hrs, B/O AND UD THE OVERSHOT. THE SHOE ON THE OVERSHOT HAD A 1" CHUNK MISSING FROM THE EDGE, BUT IT WAS BENT UP INSIDE THE EDGE OF THE SHOE. CHECK WITH BAKER FISHERMAN AND HE SAID THEY MADE 6- PASSES OVER THE STUB. THE 3RD AND 4TH APPEARED TO HAVE A LITTLE DRAG ( -1 K- 2K -lbs) WHEN THEY WERE PULLING THE WASHOVER PIPE ABOVE THE STUB. THEY MADE TWO MORE RUNS DOWN OVER THE STUB AND HAD TO ROTATE A FEW DEGREES TO GET OVER THE STUB, BUT DOWN AND BACK UP MOVEMENT HAD NO DRAG IN OR OUT. - 1100 -Hrs, BREAK OUT THE UPPER DRESS -OFF SHOE AND IT HAD PERFECT WEAR MARKS FROM DRESSING OFF THE 4 -1/2" STUB. -LOSS RATE AT END OF NIGHT TOUR WAS 42 -BPH. -1130 -Hrs, LOSS RATE AT BEGINNING OF DAY TOUR IS 38 -13PH. 12:30 - 14:30 2.00 WHSUR P DECOMP PULL WEAR RING. -FMC TECHNICIAN INSTALL 7" ISOLATION SLEAVE IN THE 9 -5/8" CASING HEAD. THIS SLEAVE HAS BEEN BORED TO 7.25" ID. TEST TO 5000 -psi FOR SOLID CHARTED 30- MINUTE TEST. 14:30 - 15:30 1.00 BOPSUR P DECOMP I NSTALL TEST PLUG TEST BOP ANNI n A& , AND THE CHOKE HCR VALVE TO 250 -psi LOW AND 3500 -psi HIGH, RECORDING EACH TEST FOR 5- MINUTES ON A CHART. -BRING DOYON CASING TORQUE TURN EQUIPMENT TO RIG FLOOR. i Printed 9/20/2010 4:10:30PM Nai America - f� 'ASKA - BP Page 21 of 26 Operation Summary Common Well Name: P1 -07 AFE No • 8/13/2010 V R W Start Date. End Date: X4- OOQV8 -E (2,850,000.00) v n : WORKO E O Event Type: Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10 : 07 2/2/1990 00:00 @ (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 00:00 8.50 RUNCOM P RUNCOP R/U DOYON CASING TORQUE TURN EQUIPMENT TO RIH W ITH 4-1/2", 12.6 #, 13Cr80. VAM TOP TUBING. - 1530 -Hrs, FLUID ON HAND: 365 -Bbls IN PITS, 135 -Bbls IN VAC TRUCK #1, AND 290 -Bbls IN VAC TRUCK #2 FOR 790 -Bbls TOTAL. 40 -BPH LOSS RATE. 1615-Hrs TO 1630 - Hrs - -PJSM WITH RIG CREW, TOOLPUSHER, HALLIBURTON TECHS, AND WSL TO DISCUSS THE COMPLETION ACTIVITIES. PINCH POINTS (SINGLE JOINT ELEVATORS, TORQUE TURN TONGS, AND ROLLING TUBING IN THE PIPE SHED) AND DROPPED OBJECTS (PARTS OUT OF THE TOPDRIVE, STABBING BOARD OPERATOR, TUBING HANGING IN SINGLE JOINT ELEVATORS) WERE PRIMARY FOCUS. - 1645 -Hrs, P/U UNIQUEMACHINE OVERSHOT ASSEMBLY AND RIH. USE DOG COLLAR AS BACKUP. -1650 -Hrs, P/U FULL JT "A" AND WU TO OVERSHOT WITH BAKERLOK. USE DOG COLLAR BACKUP. -17700 -Hrs, P/U X- NIPPLE W/ RHC -M PLUG AND M/U TO JT "A" WITH BAKERLOK; USE DOG COLLAR BACKUP. WON'T M/U TO EXACT TORQUE. BACK OUT AND CLEAN CONNECTION, REAPPLY BAKERLOK AND M/U AGAIN. USE DOG COLLAR BACKUP. - 1730 -Hrs, P/U HES 4 -1/2" x 7" TNT PACKER, APPLY BAKERLOK AND WU TO THE X -NPL W/ RHC -M PLUG ASSY. USE DOG COLLAR BACKUP. - 1740 -Hrs, P/U 2ND X- NIPPLE ASSY AND SLOWLY RIH THROUGH THE 7.25" ISOLATION SLEAVE. OD OF THE PACKER IS 5.875" - CONTINUE TO MAINTAIN HOLE FILL WITH 40 -BPH LOSS RATE. - 0000 -Hrs, CONTINUE TO RUN 4 -1/2" TUBING TO 3466' -M /U TORQUE TO 4440- FT -LBS -USE JET LUBE SEAL GUARD ON ALL CONNECTIONS - CONTINUE TO MAINTAIN HOLE FILL WITH 40 -BPH LOSS RATE. Printed 9/20/2010 4:10:30PM f� o thAfxlerlc� ALASKA - BP � � Page 22 of .Operation Summary Report,. Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10 : 07 2/2/199000:00 @42.00ft (above Mean S Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/24/2010 00:00 - 11:00 11.00 RUNCOM P RUNCMP CONTINUE TO RUN 4 -1/2" 12.6# VAM TOP TUBING FROM 3466' -M /U TORQUE TO 4440 -FT -LBS -USE JET LUBE SEAL GUARD ON ALL CONNECTIONS - CONTINUE TO MAINTAIN HOLE FILL WITH 40 -BPH LOSS RATE. -0110 -Hrs, RUN 4 -1/2" COMPLETION TUBING FROM 5032' - 0230 -Hrs, RUN 4 -1/2" COMPLETION TUBING FROM 6262' - 0430 -Hrs, RU 4 -1/2" COMPLETION TUBING FROM 7588' 0530-Hrs, RU DUAL CONTROL LINE WITH 1/4" SS CONTROL LINE. PURGE LINES WITH HYDRAULIC OIL. PRESSURE TEST TO 5000 -PSI FOR 10 -MIN. BLEED DOWN PRESSURE TO 3500 -PSI. - CONTINUE TO MAINTAIN HOLE FILL WITH 30 -BPH LOSS RATE. - 0600 -Hrs; DO NOT SEE ANY INDICATION OF THE 7" LINER TOP AT 7812' WHEN THE U/M OVERSHOT IS RUN THROUGH IT. -0630 -Hrs, P/U JT #197 (8091' RIH). - 0830 -Hrs, P/U JT #238 (9678' RIH). P/U WT 162K -Ibs, S/O WT 120K -Ibs. - 0900 -Hrs, TAG STUB AT 9748', WHICH IS 33' IN ON JT #241. SET DOWN TO 12K -LBS, BUT NO PROGRESS. P/U AND AND SLOWLY SET DOWN TO 20K -Ibs, NO PROGRESS. REPEAT 3 TIMES AND NO PROGRESS. - 0915 -Hrs, WORK 1/2 TURN INTO STRING AND CANNOT GET OVER STUB. P/U AND WU JOINT #242 AND WORK ANOTHER 1/2 TURN INTO STRING. P/U AND RIH TO SET DOWN 20K -Ibs AND REPEAT 4- TIMES, NO PROGRESS. CALL RWO SUPERINTENDENT AND RWO ENGINEER TO DISCUSS OPTIONS. PARK ABOUT 8' ABOVE THE STUB AND DISCUSS OPTIONS WITH RIG CREW, TOOLPUSHER, AND HALLIBURTON TECHS. CURRENT LOSS RATE IS 24 -BPH WITH 280 -Bbls ON BOARD AND 290 -Bbls COLD AND 290 -Bbls HOT 9.0 -ppg IN TWO VAC TRUCKS STANDING BY. - 1010 -Hrs, START TO RIH AND SEE THE OVERSHOT DROP OVER THE STUB. CONTINUE RIH AND SEE FIRST SET OF PINS SHEAR AT 5K -Ibs. CONTINUE RIH AND SECOND SET OF PINS SHEARS AT 7K -Ibs AT VIN. REACH NO -GO AND STACK OUT WITH 10K -Ibs. BOTTOM OF U/M OVERSHOT AT 9761'. - 1045 -Hrs, CALCULATE SPACE -OUT AND DECIDE TO USE 9.84' AND 7.84' PUP JOINTS TO SPACE -OUT THE U/M OVERSHOT WITH ABOUT T OF SWALLOW OVER THE STUB. Printed 9/20/2010 4:10:30PM North America - ALASKA - BP Page; f 26 Operation Summary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 1 : 07 2/2/1990 00:00 @42.0 (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 15:00 4.00 RUNCOM P RUNCMP POH AND UD JT #242, #241, AND #240. P/U AND WU 7.84' AND 9.84' PUP JOINTS AND RIH. P/U AND M/U JT #240 AND RIH. P/U AND M/U THE HANGER TO #240. - 1200 -Hrs, LOSS RATE IS 24 -13PH. R/D TORQUE TURN EQUIPMENT AND SEND OUT THROUGH BEAVALATOR. FLUID ON HAND: 230 -Bbls ON BOARD, 290 -Bbl VAC WITH AMBIENT TEMP, AND 290 BBL VAC OF HOT. -1230 -Hrs, FMC AND HALLIBURTON M/U 1/4" CONTROL LINES TO HANGER PORTS. FMC TEST LINES FROM HANGER TO THE SSSV ASSEMBLY TO 5000 -psi FOR 10- MINUTES, EACH, SOLID. HALLIBURTON TEST LINES FROM HANGER THROUGH THE SPOOL TO 5000 -psi FOR 10- MINUTES EACH, SOLID. -1330 -Hrs, PJSM TO LAND HANGER. DISCUSS THE FACT THAT WE HAD DIFFICULTY IN SWALLOWING THE STUB TO GET THE SPACE -OUT, AND IT COULD BE THE SAME THING FOR LANDING THE HANGER. 1345 -Hrs, P/U WT 165K -Ibs, S/0 WT 125K -Ibs. PULL ROTARY TABLE BUSHINGS, WIPER PLUG, AND SUPPORT FRAME. - 1400 -Hrs, SLOWLY RIH AND TAG OUT ON THE STUB AT 9751'. P/U AND TRY 6 -TIMES TO GET OVER THE STUB WITH 1OK -Ibs. P/U AND SET 112 ROTATION INTO STRING AND WORK THE TORQUE DOWN. MAKE 5- ATTEMPTS AND NO PROGRESS. RIH SLIGHTLY FASTER AND THE U/M OVERSHOT SLIPS OVER. LAND THE HANGER, WHICH PLACES THE BOTTOM OF THE U/M OVERSHOT AT 9858.8' FOR A 7.8' SWALLOW OVER THE STUB. 15:00 - 20:30 5.50 RUNCOM P RUNCMP PJSM TO REVERSE CIRCULATE THE PACKER FLUID. -R /U TO REVERSE CIRCULATE 150 -Bbls OF 110 TO 120 DEGREES F 9.0 -ppg NaCl BRINE FOLLOWED BY 430 -Bbls OF 110 -120 DEGREES F 9.0 -ppg NaCl BRINE. START REVERSE CIRCULATION WITH NON - INHIBITED BRINE AND BRING UP TO 2.3 -BPM, 450 -psi, PER INSTRUCTIONS FROM HALLIBURTON TECHS. - 1710 -Hrs, START PUMPING THE CORROSION INHIBITED, HOT 9.0 -ppg NaCl BRINE. - 2030 -Hrs, FINISH PUMPING CORROSION INHIBITOR LOSSING 65 BBLS THROUGHT THE CIRCULTATION. Printed 9/20/2010 4:10:30PM Notthr America - ALASKA - BF' Page 2a of 2s O eration -Summary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Da tum: 10 : 0 7 2/2/1990 00:00 @ 42.00 ft (above Mean Sea Lev Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 00:00 3.50 RUNCOM P RUNCMP DROP BALL AND ROD AND WAIT 10 MIN TO FALL ON SEAT. -BRING PUMPS ON LINE PUMPING DOWN TUBING AND PRESSURING UP TO 500 PSI ON BALL AND SEAT. HOLD PRESSURE FOR 2 MIN. -WHILE BRINGING PRESSURE UP PACKER SET AT 1950 PSI. -BRING TUBING PRESSURE UP TO 3600 PSI AND HOLD FOR 10 MINUTES SEEING A STEADY DROP OF 125 PSI AND NO SIGN OF FLATLINE. - PRESSURE BACK UP TO 3600 PSI AND MONITOR FOR 15 MINUTES. PRESSURE AGAIN DROPPED TO 2950 PSI AT A STEADY RATE. - INSPECT SURFACE EQUIPMENT FOR LEAKS AND SUCK FLUID OFF OF TOP OF HANGER TO MONITOR. SAW SMALL LEAK WHERE HANGER AND LANDING JOINT WHERE MADE UP. TIGHTEN UP LANDING JOINT INTO HANGER WITH 1/4 TURN. -2145 Hrs - BRING TUBING PRESSURE UP AND MONITOR FOR LEAKS ON LANDING JOINT AND TUBING HANGER. STILL SEEING FLUID LEAKING ON HANGER. -2200 Hrs - BREAK OUT LANDING JOINT FROM HANGER AND INSPECT THREADS ON HANGER. THREADS WHERE WORN. RAN LANDING JOINT BACK IN HOLE, STABBED BACK INTO HANGER AND TORQUED BACK UP. (COULD NOT CLOSE THE SHEAR RAMS AND TEST BECAUSE OF CONTROL LINES) -2230 Hrs - PRESSURE TUBING BACK UP TO 3675 PSI AND MONITORED FOR LEAKS AROUND HANGER, NONE SEEN. HOLD TEST FOR 30 MIN. -GOOD TEST. -2310 Hrs - BLEED TUBING DOWN TO 1500 PSI. RIG UP AND PRESSURE UP BACK SIDE TO 3600 PSI. HOLD FOR 30 MIN. GOOD TEST. -2345 Hrs - BLEED DOWN TUBING AND SHEAR OUT DCR VALVE AT 1000 PSI. -PUMP DOWN TUBING AT 3 BPM AND 230 PSI FOR 5 BBLS OF VOLUME. RIG UP AND PUMP DOWN IA AT 3 BPM AND 220 PSI FOR 5 BBL OF VOLUME. 8/25/2010 00:00 01:30 1.50 RUNCOM P RUNCMP L/D LANDING JOINT. -DRY ROD IN TWC. -P /U LANDING JOINT AND RIH TORQUING TO HANGER. -TEST TWC FROM BELOW TO 1000 PSI FOR 5 MIN. GOOD TEST. -TEST TWC FROM ABOVE TO 3500 PSI FOR 5 MIN. GOOD TEST. -L /D LANDING JOINT. -BLOW DOWN CIRCULATION LINES. DRAIN ar BOPE. 1r` 01:30 03:00 1.50 BOPSUR P WHDTRE PJSM FOR N/D BOPE. -N /D BOPE - BARRIERS ARE BALL ROD ON SEAT WITH KILL WEIGHT FLUID AND TWC. Printed 9/20/2010 4:10:30PM North' America - ALASKA - BP Page 25f 26 ; �Operati - wSummary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000-00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 10: 07 2/2/19 00 :00 @42. (above Mea Sea L evel) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 08:30 5.50 WHSUR P WHDTRE PJSM. -PREP CONTROL LINES. N/U ADAPTER FLANGE AND TREE. M/U AND TEST SSSV CONTROL LINES. -TEST ADAPTER FLANGE AND TREE TO 5000 PSI. TESTED TWICE; TEST LOST 100 -psi FROM 5100 -psi TO 5000 -psi IN 7- MINUTES WITH NO VISIBLE LEAKS ON THE TREE. 08:30 14:30 6.00 WHSUR P WHDTRE PJSM FOR FREEZE PROTECTING THE WELL WITH LIL RED AND THE RIG CREW. -P /U DSM LUBRICATOR, INSTALL ON TREE, AND TEST TO 3500 -psi. PULL TWC. BREAK -OUT AND UD LUBRICATOR. 1000 -Hrs, R/U CIRCULATING LINES AND MANIFOLD IN CELLAR. R/U LI RED AND PRESSURE TEST LINES TO 3500 -psi. -1030 -Hrs; PUMP 150' -Bbls OF 85- DEGREES F DIESEL DOWN ANNULUS AT 1.75 -BPM AND 250 -psi. FINAL CIRCULATING PRESSURE ON THE DIESEL IS 450 -psi. - 1200 -Hrs; REALIGN VALVES ON CIRCULATING MANIFOLD AND UJUBE THE DIESEL FREEZE PROTECT FLUID. PRESSURE ON THE IA IS 300 -psi AND TUBING IS 280 -psi. BLEED OFF 10 -Bbls, BUT STOP BLEEDING TO PREVENT ANY MORE DIESEL LOSS IN TUBING. IA PRES = 140 -psi, TUBING PRES = 40 -psi. - 1400 -Hrs, CALL RWO SUPT TO DISCUSS AND AGREE TO CALL RWO ENGINEER TO DISCUSS NEXT STEP. CALCULATE HYDROSTATIC PRESSURE ON BALL AND ROD OF 3672 -psi VERSUS RESERVOIR PRESSURE OF 4088 -psi. - 1430 -Hrs, CALL WIRELINE AND COMPLETIONS COORDINATOR AND RWO LEAD ENGINEER TO DISCUSS AND BOTH GAVE THE GO -AHEAD TO SET THE BPV. 14:30 - 18:00 3.50 WHSUR N WHDTRE - 1435 -Hrs, CALL RWO SUPT TO LET HIM KNOW WE'LL SET THE BPV UNDER PRESSURE. THE DSM PERSONNEL ARE ONSITE AND WILL PROCEED WITH THE PTs THEY NEED TO PERFORM TO CONFIRM BARRIERS UNDER THE STP FOR PRESSURE CONTROL. -LRS PERFORM PT ON THE TREE FOR BOTH THE MASTER VALVE AND SWAB VALVE. THE MASTER VALVE WOULD NOT HOLD ON TEST, SO DSM CALLED THE GREASE CREW TO WORK ON THE VALVE. - 1630 -Hrs, GREASE CREW ARRIVED AND LUBRICATED TREE VALVES. REALIGN VALVES ON CIRCULATION MANIFOLD TO ENSURE RIG VALVES ARE NOT INVOLVED IN THE TREE TEST. - 1700 -Hrs, TEST THE MASTER AND SWAB VALVES WITH RIG TEST PUMP. DSM CREW SAID TEST WAS SOLID AND THEY WANT TO INSTALL AND TEST THEIR LUBRICATOR. - 1730 -Hrs, INSTALL AND TEST DSM LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. Printed 9/20/2010 4:10:30PM North America - ALASKA - �R Page 2fi.26 Qpera #ionn Summary Report Common Well Name: P1 -07 AFE No Event Type: WORKOVER (WO) Start Date: 8/13/2010 End Date: X4- OOQV8 -E (2,850,000.00) Project: Point McIntyre Site: Pt Mac 1 Rig Name /No.: DOYON 16 Spud Date/Time: 2/2/1990 12:00:OOAM Rig Release: 8/25/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292199600 Active Datum: 1 07 2/2/1990 00:00 @4 2.00ft (above Mean Sea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 19:30 1.50 WHSUR P WHDTRE DSM INSTALLED THE BPV WITH THE LUBRICATOR. -TEST BPV FROM BELOW TO 1000 PSI FOR 10 MIN. GOOD TEST. 19:30 20:00 0.50 WHSUR P WHDTRE B/D AND R/D CELLAR LINES. - SECURE WELL. - RELEASE RIG AT 2000 Hrs. Printed 9/20/2010 4:10:30PM • • Page 1 of 1 Regg, James B (DOA) From: Willingham, James M [James. Willingham@bp.com] Sent: Monday, August 23, 2010 10:33 AM To: DOA AOGCC Prudhoe Bay Cc: Crane, Lowell R; Engel, Harry R; Kilfoyle, Jeffery A Subject: P1-07A Well Shut In Attachments: BOPE 8-22-10 (3).doc 1 ~ Zpl`-~r3~ ~Px,~ ~1- Q~.4 8/23/2010 • ~~ Blow Out Preventer Equipment (BOPE) ~~~~ I ~ Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of awn rr BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: James Willingham Wellsite Leader Name: Mike Rooney Contact Number: 907-659-5329 Contact Number: 907-659-4168 Traction Number: IR-3595303 Well Location & Name: PBU P1-07A Permit To Drill PTD Number: 204-037 Date and Time of Incident: 8/22/10, 1710-Hrs Original Scope of Work: Mill composite bridge plug at 9827', push to tubing tail at 9864' and bullhead 50-bbls to formation. Operational Description Leading up to Well Control Event: After milling plug, the well was on a 10-bph loss rate. Began pushing plug to tubing tail. At 9855' noticed a slight gain and decided to close annular. Total pit gain 4.5-bbls. SICP 50-psi, SIDP 10-psi. BOPE Used and Reason: The annular was shut in to control the flow of gas and oil that had built up under the plug that was set pre-rig. Is a BOPE Test Required after use (Yes / No): If no, why? Yes, we will test the annular and associated choke valves when we pull out of the hole 24 hour notice required to NS AOGCC Inspectors prior to testing BOPS components. Plan Forward: Circulate the influx out through the choke and gas buster. After circulation complete, flow check well. The well was on a vac with a loss rate of 96-bph. Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bayCa~alaska.gov Email CC List BP WSL Har En el Wells Team Leader Jeff Kilfo le En ineerin Team Leader O erations Drillin En ineer- Well File Wells O erations Mana er Drillin & Com letions En ineer Mana er Wells Intervention Mana er BOPE Usage Report for AOGCC August 2, 2010 HRE • • ~~Q~C~ 0[~ aL~a~~Q /,~...~ua,~~. David Reem Engineering Team Leader ,,, i £,~ ? ~1~a BP Exploration (Alaska), Inc. ~,~~~:`~yl~cp."` `~~`~`" ~~ P.O. Box 196612 ~ ~ ~ ~ 3 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Point McIntyre Pool, PBU P1-07A Sundry Number: 310-221 Dear Mr. Reem: 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. t, Jr. DATED this Z~y of July, 2010. Encl. STATE OF ALASKA ~C~~ Y ~D.,~;~`"" ALASK~L AND GAS CONSERVATION COMMIS~I ~.~?/~O APPLICATION FOR SUNDRY APPROVAL JUL ~ ~ 20101 20 AAC 25.280 1. Type of Request: ~iiiCh~l'1~8 ^ Abandon ^ Plug for Redrill ^ Perforate New Pool ®Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate - ®Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate .® Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. . ®Development ^ Exploratory 204-037 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21996-01-00 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: PBU P1-07A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028297 - Prudhoe Bay Field /Point McIntyre 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): 10671 9207 - 10560 9120 ~ None None Casin Len Size MD ND Burst Colla se Structural Conductor 11 11 11 ' Surface 4272' 13-3/ " 4272' 4091' 3450 1950 Intermediate 7341' 9-5/8" 7341' 6426' 6870 4750 Production Liner 3475' 7" 7169' - 10 44' 630 ' - 9186' 7240 10 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10162' - 10498' 8810' - 9072' 4-1/2", 12.6# 13Cr 9865' Packers and SSSV Type: 7" x 4-1/2" Baker S-3 Packer Packers and SSSV 9808' / 8511' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 1, 2010 ~ ®Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned ^ WAG ^ SPLUG ^ Suspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Nam avid Reem Title Engineering Team Leader Prepared ey Name/Number: Phone 564-5743 Date 'T Z ~ ~ Prv Terrie Hubble, 564-4628 Signature ~- ~ ~ Commission Use Onl Conditions of approva~l: N tify Commission so that a representative may witness Sundry Number: l O ^ Plug Integrity L/J BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ 3Soo P s~ ~oP S-F- ) Other: .rF Z S6U ~os~- ~^ •, ~-u '~s ~" ~ v,~,._ / 'a.r-cam `~o... t v v~ /~-~L c4,Sy~1 o,b.El`~b~,- - f t ~ ~~r'j'L~ A~Jd ! G'on ~i ~ / ~ ~ Z ~ 5 ~ J (((JJJ Z ~ ~~ ~ Z S. ' Subsequent Form Required: ~ b ~ c//~ APPROVED BY IZ• ~ v~~ ~ Approved B : COMMI R THE COMMISSION Date 77 Form 10-4 20~~1 ~ ,~ ZQ W O R G I N a L Submit In D li 7-zz io ~.~~ ~~ ~~~ Ik6~}- o7(Yz(zolo C 1[~ P1-O7A Rig Workover (Repair surface casing) • Scope of Work: Pull 4.5" 13Cr-80 completion. Run USIT log to find TOC, cut and pull 9-5/8" casing as deep as possible. Wachs cut 13-3/8" casing just below wellhead. Tie back 9-5/8" casing and cement to surface. Install new 9-5/8" slip lock wellhead. Run 4.5"13Cr-80 completion. Engineer: Hank Baca MASP: 3177 psi / Well Type: Producer Estimated Start Date: August 1st, 2010 Pre-Rig Work Request: S 1 Memo bottom hole ressure sunre to 10,330' MD mid erf E 2 Set com osite bride lu at 9,827' MD. Reference tubin tall dated 4/16/2004. F 3 MIT-T to 3500 psi for 30 minutes. MIT -IA to 3500 psi for 30 minutes. Surface casing leak, no need to MIT - OA. E 4 Power Jet cut 4-'/z" 13Cr-80 tubing at ~9,747'MD, ~10' down first full joint above acker Reference tubin tall dated 4/16/2004 . F 5 Circulate well with kill weight fluid as determined by BHPS + 75psi. Freeze protect to 2000'. Account for diesel in INVF calculation ~ F 6 CMIT T x IA to 1,000 si for 10 minutes ost cut. ~ V 7 Check 9-5/8" & 4.5" lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 8 Set a BPV in the tubin han er. O 9 Rhino liner cellar Proposed Procedure 1. MIRU. ND tree. NU 4 preventer BOP stack consisting of annular, 4-1/2" x 7" VBRs, 2-7/8" x 5" VBRs, blind/shear. Test to 250 psi low/3500 psi high. Circulate out freeze protection and circulate '~ K1NF. 2. Pull and LD tubing string to the cut. • 3. RU wireline and run USIT from 4300' to surface. 4. Run 9-5/~.t36P and set 100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Dump ~50 ft of sand on RBP. 5. Mechanically cut 9-5/8" casing in 1St full joint above top of cement. Pull casing through stack. Dress 9-5/8" stub in preparation of casing oversFiot. Rams will not be changed to 9-5/8" as 2 barriers to. the reservoir are present (TTP/packer & 9-5/8" BP) 6. ND BOPs, tubing spool, and spacer spool 7. Wachs cut 13-3/8" wellhead off at surface. - 8. Run 9-5/8", 47#, L-80 Hydril 563 casing and tie-into dressed stub. 9. Cement new 9-5/8" casing to surface. 10. Install 9-5/8" slip lock wellhead & test seals to 3800psi. 11. NU BOPs on 9-5/8" base flange and test to 250/3500psi per AOGCC • • 12. Drill out 9-5/8"float equipment. 13. Cleanout above 9-5/8" RBP. Test tieback to 3500 psi for 30 minutes. Pull RBP. 14. Dress tubing stub & drill up composite bridge plug C«~ 9,827' 15. Run 4-'/z" 13Cr-80 stacked packer completion 16. Displace the IA to packer fluid and set the packer. 17. Test tubing and IA to 3500 psi for 30 charted minutes. Freeze protect to 2,000' MD. 18. Set TWC. ND BOPE. NU and test tree. Pull TWC and. set BPV. RDMO. TREE _ 4=1 /16" WELLHEAD- CALICO-CM//MCEVOY ACTUATOR = AXELSON KB.`ELEV = 42' BF. ELEV KOP _ 2900' Max Angle = 44 @ 6596' Datum MD = 8838' Datum TV D = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" Minimum ID = 3.725" @ 9852' 4-1 /2" HES XN NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3546 3507 27 MMG DOME RK 16 04/19/04 5 5460 5019 38 MMG DOME RK 16 04/19/04 4 6326 5688 42 MMG DOME RK 16 04/19/04 3 7148 6285 43 MMG SO RK 24 04/19/04 2 8267 7214 28 KBG-2 DMY RK 0 04/19/04 1 8963 7797 33 KBG-2 DMY RK 0 04/19/04 7182' I-~ 9-5/8" X 7" BKR HMC C2 ZXP LTP, ID = MILLOUT WINDOW (P1-07A) 7341' - 7357' 9-5/8" CSG, 47#, L-80, ID = 8.681" I-~ 9471' I 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: SPERRY SUN MWD ON 04/14/04 ANGLE AT TOP PERF: 36 @ 10162' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10162 - 10167 O 04/14/04 2-7l8" 6 10208 - 10213 O 08/01 /04 2-7/8" 6 10272 - 10277 O 04/14!04 2-7/8" 6 10326 - 10331 O 04/14/04 2-7/8" 6 10377 - 10382 O 08/01/04 2-7/8" 6 10438 - 10443 O 08/01 /04 2-7/8" 6 10493 - 10498 C 04/14/04 ~1-07A SAFETY NOTES: FORMERLY PM-8. TBG HGR: CIW GEN N 2' M D. *** 4-1 /2" CHROME TBG & 7" CHROR. ® 2177' 4-1/2" HES WELLSTARSSSV, ID= 3.813" CHAS LIFE MANDRELS 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" ~~ 9864' I PBTD 10560' 7" LNR, 26#, L-80 / 13CR, .0383 bpf, ID = 6.276" 9865' 4-1/2" WLEG, ID - 3.958" 9857' ELMD TT LOGGED (04/24/04 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/15/90 ORIGINAL COMPLETION 09/29/09 DTR/SV SET PXN PLUG (07/24/09) 04/18/04 KAK RIG SIDETRACK(P1-07A) 05/31/10 OPGPJC PULL PXN PLUG (05/05/10) 04/19/04 JBM/KAK GLV GO 04/24/04 MJA/KAK IPERFS 08/01/04 MDGTLP ADD PERFS 07/02/06 WTS/PA ELMD TT (04/24/04) J7$7' -14-1/2" HES X N~, ID = 3.813" I 9808' 7" X 4-12" BKR S-3 PROD PKR 9832' 4-1/2" HES X NIP, ID = 3.813" 9852' 4-1/2" HES XN NIP, ID = 3.725" POINT MCINTYRE UNIT WELL: P1-07~` PERMIT No; ~L040370 '` API No: 50-029-21996-01 SEC 16, T12N, R14E, 4517.01' FEL & 1354.29' FNL BP Exploration (Alaska) _"~ NaLHEAD= CALIC0. CNJ/M1CB/OV 1-U 7A \CfINTOR= _,_ j-~-AXBSON ~aa~--~ ~_ ---42' _ _ 3F. AEV OPOSED COP= _ 2900' Aax Ante =____ II ~ 6598 ~Nm~D_ -__ ~_~~ 13-3/8" surface casing kdmTVD= 8800'SS cut off and new 9-5/8" wellhead installed 9-5/8" 47#, L-80 from old TOC to surface 13-3/8" CSG, 68#, L-80, ID = 12.415" 4272' Minimum ID = 3.725" @ 9852' 4-1 /2" HES XN NIPPLE 9-5/8" X 7" BKR HMC C2 ZXP LNR TOP PKR MILLOUT WINDOW (P1-07A) 7341' - 7357' -1/2" X nipples ~4-1/2" x 7" HES TNT packer 97$7' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" 12.6#/ft, 13Cr-80 tubing & Unique overshot 9-5/8" CSG, 47#, L-80, ID = 8.681" 9471' 4-1/2" HES X NIP, ID = 3.813" l~J 1/2" BAL SSSV @ 2,000` GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 XXX 5 XX 4 XXX 3 XXX 2 XXXX 1 XXXX 9852' 4-1/2" HES XN NIP, ID = 3.725" PERFORATION SUMMARY REF LOG: SPERRY SUN MWD ON 04/14/04 ANGLE AT TOP PERF: 36 @ 10162' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10162 - 10167 C 04/14/04 2-7/8" 6 10208-10213 C 08!01/04 2-7/8" 6 10272- 10277 C 04/14/04 2-7/8" 6 10326-10331 C 04/14/04 2-7/8" 6 10377 - 10382 C 08/01 /04 2-7/8" 6 10438 - 10443 C 08/01/04 2-7/8" 6 10493 - 10498 C 04/14/04 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I~ 11 I 9865' I ELMD TT LOGGED I~ 9857' ELMD (04/24/04) 4-1/2" TBG, 12.6#, 13-CR, I 9864' .0152 bpf, ID = 3.958" 10560' I 7" LNR, 26#, L-80 / 13-CR, .0383 bpf, ID = 6.276" I 4-1/2" WLEG ID = 3.958" PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 03/15/90 ORIGINAL COMPLETION 09/29/09 DTR/SV SET PXN PLUG (07/24/09) 04I18I04 KAK RIG SIDETRACK(P1-07A) 04/19/04 JBMIKAK GLV GO 04/24/04 MJAJKAK IPERFS 08/01/04 MDGTLP ADD PERFS 07/02/06 WTS/PAG ELMD TT (04/24/04) POINT MCINTYRE UNfr WELL: P1-07A PERMIT No: 2040370 API No: 50-029-21996-01 SEC 16, T12N, R14E, 4517.01' FEL & 1354.29' FNL BP Exploration (Alaska) P1-07A (PTD# 2040370) Plan forward Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, April 05, 2010 12:59 PM To: DeRuyter, Thomas R (DEC) Subject: FW: P1-07A (PTD# 2040370) Plan forward Attachments: P1-07A.pdf ~T~ a o~-0 3 ~ Tom, I talked to Toxin about this well in particular. The 13 3/8" X 20" (OOA) has been strapped and cement was found 60' down meaning leak is most likely somewhere from 0-60' in the 13 3/8" surface casing. He also stated that the 20" conductor is competent and will provide a barrier for the diesel to flow up. The OOA also has ports/slots to allow a snorkel (to a vac truck) to be run down several feet to catch the diesel as it rises up. No diesel will exit containment. This is a fairly common activity on the slope to locate Surface casing leaks. Just to be clear : IA = 4'/z" x 9 5/8" OA= 9 518" x 13 3/8" OOA = 13 3/8" x 20" I'll give you a call after I send this. Regards, Guy Schwartz ~ .`~~~b~"..>` A~;? ~,: ~~ ~':) Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: NSU, ADW Well Integrity Engineer [mailto:NSUADVWVeIIIntegrityEngineer@BP.com] Sent: Monday, April 05, 2010 12:43 PM To: Schwartz, Guy L (DOA) Subject: Pi-07A (PTD# 2040370) Plan forward Guy, The plan forward on P1-07A (PTD# 2040370) is to perform a leak depth determination and establish liquid leak rates. When determining a surface casing leak depth on P1-07, nitrogen will be pumped down the 9-5/8"x13-3/8" annulus (OA). This will displace the fluid in the OA down to the leak at which time the depth can be determined by strapping the OA. The liquid leak rates will be performed by pumping diesel down the OA at a constant pressure taking returns in the conductor. This will be done three times to verify the step change in rate vs pressure for hole size accuracy. Once the rates have been established platelets can be sized appropriately and pumped down the OA the seal off the leak path. Though secondary containment has been installed, both the leak depth determination and liquid leak rate operations will require a vac truck to be on location extracting all fluids being displaced in the conductor with a 6-8 foot stinger. I have attached the weltbore schematic for your reference. «P 1-07A. pdf» I hope the plan forward is clear. Please let me know if you need more information. Thank you, Toxin Roschinger (alt. Anna Dube) 4/5/2010 PI-07A (PTD# 2040370) Plan forward Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 U Page 2 of 2 4/5/2010 ~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~b~~~~~~ J~i~ , ~ 20 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, ~~~p3~ P~~°~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA 0 NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-05 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-O6 1961370. 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-OSA 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 soo292213aoooo NA 0.6 NA s.8o 7/7/2009 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7/6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13/2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 C • ~ ;~ -~ _ MICROFILMED 03/01/2008 DO NOT PLACE .~•' ,. , ~ ~.:~a~' ~- ~; ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Microfilm_Marker.doc Ål-j (Y\~ ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040370 Well Name/No. PRUDHOE BAY UN PTM P1-07A MD 10671 / TVD 9207/ Completion Date 4/24/2004/ ~- REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES / DEN / NEU / PWD, USI Well Log Information: Log/ Data Digital Type Med/Frmt ED D Asc ~ Log Electr Dataset Number Name Directional Survey Directional Survey Production ')~ ~ù~ '-{ ~ Production ~ J.I\~ ~~ '-\ ~ C ;rr L\ '> 12871 Cement Evaluation ~ 12871 Cement Evaluation 4 D 02939 Gamma Ray Æpt 12939 LIS Verification ~ C l'f'l-l ~ 12976 Reservoir Saturation ~ Reservoir Saturation ~ Cement Evaluation JED C Us ~ I S A' 3690 Induction/Resistivity Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L çm~d.- ÚJ (J"J ~ tJ'i API~~. 50-029-21996-01-00 UIC N Samples No 0;"''''0",' S"~> (data taken from Logs Portion of Master Well Data Maint Log Log Scale Media Interval OH I Start Stop CH Received 4/23/2004 4/23/2004 9/22/2004 Run No 5 Blu 10000 10550 Case 5 Blu 10050 1 0550 ~. 8/9/2004 5 Blu 6000 10550 11/29/2004 6000 1 0550 11/29/2004 6606 10625 1/2712005 6606 10625 1/27/2005 9800 10550 3/16/2005 9800 10550 3/16/2005 9850 10544 Case 11/29/2005 7341 10671 Open 2/22/2006 Blu 5 Blu . Comments PRODUCTION PROFILE W/DEFT GHOST GR-CCL- PRESS- TEMP-GRADIO- SPINS-HOLDUP-XY PRODUCTION PROFILE W/DEFT GHOST GR-CCL- PRESS- TEMP-GRADIO- SPINS-HOLDUP-XY USIT/CEMENT AND CASING EVALUATION USIT/CEMENT AND CASING EVALUATION GRlEWR4/CNP/SLD/ROP/ ACAUPWD GRlEWR4/CNP/SLD/ROP/ ACAUPWD RST RST BORAX/CHANNEL DETECTION LOG Cement Mapping Tool Cement BondNariable Density Log 21 April 2004 ROP DGR EWR SLD CTN plus Graphics . DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040370 Well NamelNo. PRUDHOE BAY UN PTM P1-07A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21996-01-00 MD 10671 TVD 9207 Well Cores/Samples Information: Name ADDITIONAL INFOR~ON Well Cored? \~ Chips Received? ~ Analysis Received? ~ Comments: Compliance Reviewed By: Completion Date 4/24/2004 ~ Completion Status 1-01L Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status 1-01L Sample Set Number Comments ~/N ~/N Date: UIC N 1 ~fVL) ~~ Cp . . . . WELL LOG TRANSMITTAL DOl\- -03~{ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 13lPG¡V RE: MWD Formation Evaluation Logs PI-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 PI-07A: LAS Data & Digital Log hnages: 50-029-21996-01 1 CD Rom ~) tj )OQQ~~j) ~/ 9'1/D0 Schlumberger ?;:~\¡~I)·-: ~:-;"i'1-r~w Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ; , ~~ c; 20C5 'c.. (fJnt~.. C;~J[nfnl~JIDD ·,}X¡d1ms£e Well Job # Log Description Date BL PSI-07 40009685 OH LDWG EDIT OF MWD/LWD 10/12/03 PSI-07 40009685 MD VISION DENSITY 10/12/03 1 PSI-07 40009685 TVD VISION DENSITY 10/12/03 1 PSI-07 40009685 MD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 TVD VISION DEN/NEUTRON i Ûil 2¡03 j PSI-07 40009685 MD VISION SERVICE 10/12/03 1 PSI-07 40009685 TVD VISION SERVICE 10/12/03 1 Z-02A 11132059 USIT 10/06/05 S-14A 10987547 USIT 09/13/05 Y-1OA 10889216 SCMT 02/21/05 D.S. 03-33A 10893093 SCMT 03/05/05 C-19B 10928633 SCMT 05/15/05 09-20 10889215 SCMT 02/18/05 D.S.09-31C N/A SCMT 11/05/05 P-06A 11076455 SCMT 07/29/05 2-22A 11084275 SCMT 07/10/05 K-20B 11075899 SCMT 07/04/05 D.S. 06-20 11062630 USIT 06/14/05 C-18A 10621788 SCMT 06/06/04 P1-07A 10621778 SCMT ~ð4. --() ~1 04/21/04 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: \ I /.t;;c, \ 05 NO. 3613 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne pt. Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth R,œ;~dbt~)(j , 11/28/05 . . . . ;{o {-o>7 WELL LOG TRANSMITTAL ~ )t-1>'\ To: State of Alaska Alaska Oil and Gas Conservation COmIll. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska November 19,2003 RE: MWD Formation Evaluation Logs PI-07 A, AK-MW-3016164 1 LDWG formatted Disc with verification listing. API#: 50-029-21996-01 PLEASE ACKNOWLEDGE RECEIYf BY SIGNING AND RETURNING A COpy OF THE TRANSMITIAL LEITER TO THE AITENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ((Z-7 /os ,/// / / SigneLìi;d~ . .¡J~ Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . ?l)l{..r;So W-05A t~~L3-02 !)ð..2.1JI OWDW-SW OWDW-SW ?.ð'f~()j1P1-07 A 7(jf.. rn J-25A Z(),{~/o'f C-25B ) e:¡l{--{)ÎI S-14A ~~(}f 0 E-39A 2Ol{. /1. Õ 07 -32B ''I Q-05A .'=1t.ójf DS 09-41 Well . Job # 10715426 10708048 10563038 10672360 10621778 10715419 10715434 10884020 10728394 10861926 10715356 10563111 CH EDIT (PDC-GR) RST ·SIGMA RST·SIGMA RST·BORAX USIT (PDC) MCNL MCNL MCNL MCNL MCNL MCNL RST-SIGMA 11/23/04 NO. 3277 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 09/02/04 1 02/05/04 1 1 03/30/03 1 1 03/27/04 1 1 04/20/04 1 08/13/04 1 1 10/11/04 1 1 09/18/04 1 1 03/28/04 1 1 08/03/04 1 1 10/26/03 1 1 10/12/03 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: /1 ft9ft Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage,AK 9950}-Z838. ~ ATT~;:Æ. n Re~bY u· I' .. STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS EIVED orT 0 [) 2004 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: Repair Well 0 Pull TubingD Operation Shutdown 0 PluQ PerforationsD Perforate New Pool D Perforate ŒJ CommissÎcm Stimulate 0 OtherO WaiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 204-0370 6. API Number 50-029-21996-01-00 4. Current Well Class: Development 00 BP Exploration (Alaska), Inc. Total Depth measured 10671 feet true vertical 9206.8 feet Effective Depth measured 10560 feet true vertical 9120.0 feet P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 37.50 8. Property Designation: ADL-028297 11. Present Well Condition Summary: Casing Conductor Liner Liner Liner Production Surface Length 80 24 2486 965 7314 4240 Perforation depth: ExploratoryD StratigraphicD ServiceD 9. Well Name and Number: P1-07A 10. Field/Pool(s): pt Mcintyre Oil Field / pt Mcintyre Oil Pool Plugs (measured) None Junk (measured) None Size 20" 91.5# H-40 9-5/8" 47# L-80 7" 26# L-80 7" 26# 13CR80 9-5/8" 47# L-80 13-3/8" 68# L-80 MD TVD Burst Collapse 29 109 29.0 109.0 1490 470 7169 - 7193 6300.2 - 6317.8 6870 4760 7193 - 9679 6317.8 - 8401.6 7240 5410 9679 - 10644 8401.6 - 9185.7 7240 5410 27 - 7341 27.0 - 6425.7 6870 4760 28 - 4268 28.0 - 4088.0 4930 2270 Measured depth: 10162 -10167,10208 -10213,10272 -10277,10326 -10331,10377 -10382,10438 -10443,10493 -10498 True vertical depth: 8810.35 - 8814.35,8846.86 - 8850.78,8896.5 - 8900.36,8938.17 - 8942.03,8977.54 - 8981.41,9024.82 - 9028.71 9067.64 - 9071.55 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 25 9863 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-112" HES Wellstar SSSV 7" Baker ZXP Liner Top Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaqe Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 11 2430 1200 23.6 1527 1200 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )j~~. 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ Signature Form 1 0-404 Revised 4/2004 @ 9808 @ 2177 @ 7181 Oil-Bbl 2026 1124 Tubing Pressure 1071 1719 ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil ŒI GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: NIA Development ŒJ ServiceD Title Production Technical Assistant OR!GIÑÃr6S7~LW' Date 9/29/04 r, óCî u () tUu1 . . P1-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/01/04 Perforate 10208'-10213' 6 SPF, 10377'-10382' 6 SPF, 10438'-10443' 6 SPF FLUIDS PUMPED BBLS No Fluids Pumped o ITOTAL Page 1 TREE = WB..U"EAD = AcrUATOR = KB. ELEV ;; BF. ELEV = KOP= Max Angle =" DatumMD= ,~~~,~- DatumTVD = . 4=1/16' CA LlCo.CW /WCB! OY AXELSON 42' 2900' 44 @ 6596' 8838' .~ 8800' SS 113-3/8" CSG, 68#, L-80, ID = 12.415" H 4272' I Minimum ID = 3.725" @ 9852' I 4-1/2" HES XN NIPPLE 9-5/8" CSG,47#, L-80, ID= 8.681" H 9471' r- PERFORATION SUWMARY REF LOG: SPERRY SUN MOO ON 04/14/04 Af\K3LEATTOPÆRF: 36@ 10162' I\bte: Refer to Production DB for historical perf data SIZE SPF INTERV AL OpnlSqz 1)/\ TE 2-7/8" 6 10162-10167 0 04/14104 2-7/ff' 6 10208-10213 0 08101104 2-7/ff' 6 10272 - 10277 0 04/14104 2-7/ff' 6 10326 - 10331 0 04/14104 2-7/8" 6 10377 - 10382 0 08101104 2-7/8" 6 10438.. 10443 0 08101104 2-7/8" 6 10493 - 10498 0 04/14104 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 11098' DA ìE REV BY COMWENTS 03115/90 ORIGINAL COMPLErION 04/18/04 KAK RIG SIDEr RAC K (P1-07A) 04/19/04 JBM/KAK GLV 00 04/24/04 MJA/KAK IPERFS 08101/04 MJCITLP AID ÆRFS P1-07 A . - µ L ~ :;g:'VVV:g;: I' I '" ---- SAFETY NOTES: FORMERLY PM-So TBGHGR: CIW Ge.I r.¡ @ 32' MD. *** 4-1/2" CHROME TBG & 7" CHROM E LNR. 2177 H 4-1/2" I-ESWB..LSTAR SSSV,ID=3.813" I GAS LIFT IW\f'.ÐRELS ŒV TYÆ VLV LATa-! 27 MMG DOME RK 38 MMG DOME RK 42 MMG DOME RK 43 MMG SO RK 28 KBG-2 DMY RK 33 KBG-2 DMY RK ~ ST MD lVD 6 3546 3507 5 5460 5019 4 6326 5688 3 7148 6285 2 8267 7214 1 8963 7797 PORr DATE 16 04/19/04 16 04/19/04 16 04/19/04 24 04/19/04 o 04/19/04 o 04/19/04 7182' H 9-518" X 7' BKR I-fv1C C2 ZXP LNR TOPPKR 1 I MILLOur WINDOW 7341' - 7357' H4-1/2" HES X NlP,ID = 3.813" 1 H 7" X 4-1 Z' BKR 8-3 PROD A<R I ~ H4-1/2" I-ESX NIP,ID =3.813" I " H 4-1/2" HES XN NP, I ID= 3.725' H 4-1IZ' WLEG, I I ID = 3.958" 14-1f2" 1BG, 12.6#, 13-CR, H .0152 bpf, ID = 3.958" I I 7" LNR. 26#, L-80 /13-CR, .0383 bpf, ID = 6.276" H 10644' 1 DATE REV BY OOWMENTS POINT MCNTYREUNT WELL: P1-07A ÆRMT I\b: 2040370 APII\b: 50-029-21996-01 SEe 16, T12N, R14E, 4517.01' FEL & 1354.29' FN... BP Exploration (Alaska) .. STATE OF ALASKA I ALASKA~L AND GAS CONSERVATION COMM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1449' NSL, 722' WEL, SEC. 16, T12N, R14E, UM Top of Productive Horizon: 3804' NSL, 2398' WEL, SEC. 16, T12N, R14E, UM Total Depth: 4024' NSL, 2073' WEL, SEC. 16, T12N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 674332 y- 5994579 Zone- ASP4 TPI: x- 672598 y- 5996895 Zone- ASP4 Total Depth: x- 672918 y- 5997123 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR / GR / RES / DEN / NEU / PWD, USI One Other 5. Date Comp., Susp., or Aband. 4/24/2004 6. Date Spudded 4/10/2004 7. Date T.D. Reached 4/13/2004 8. KB Elevation (ft): 37.5' 9. Plug Back Depth (MD+ TVD) 10560 + 9120 10. Total Depth (MD+TVD) 10671 + 9207 11. Depth where SSSV set 2177' MD 19. Water depth, if offshore N/A MSL WT. PER FT. 91.5# 68# 47# 26# CASING, LINER AND CEMENTING RECORD SETrINGDEPTH MD SETTING DEPTH TVD HOLE lOP BOTTOM ToP BOTTOM SIZe Surface 113' Surface 113' 30" Surface 4272' Surface 4092' 17-1/2" Surface 7341' Surface 6426' 12-1/4" 7169' 10644' 6300' 9186' 8-1/2" 22. CASING Size 20" 13-3/8" 9-5/8" H-40 K-55/ L-80 L-80 7" L -80 I 13Cr80 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state 'none"): 2-7/8" Gun Diameter, 6spf MD TVD MD TVD 10162' - 10167' 8810' - 8814' 10272' -10727' 8897' - 9251' 10326' -10331' 8938' - 8942' 10493' - 10498' 9068' - 9072' 26. Date First Production: April 26, 2004 Date of Test Hours Tested PRODUCTION FOR 5/3/2004 14 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 817 1,608 24-HoUR RATE 27. 24. SIZE 4-1/2", 12.6#, 13Cr80 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 204-037 13. API Number 50- 029-21996-01-00 14. Well Name and Number: P1-07A 15. Field / Pool(s): Prudhoe Bay Field / Point Mcintyre Ft Ft 16. Property Designation: ADL 028297 17. Land Use Permit: LAS 12554 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 2150# Poleset 2750 sx CS III, 500 sx Class 'G' 1425 sx Class 'G' 328 sx Class 'G' TUBING DEPTH SET (MD) 9865' PACKER SET (MD) 9808' AÇIl;),FfVo.ÇTURE,CEMENT DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 152 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Oll-BBl 1,525 Oll-BBl 2,614 GAs-McF 6,293 GAs-McF 10,788 W A TER-BBL 762 CHOKE SIZE I GAS-Oil RATIO 1760 4,127 Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". -f~~ Form 10-407 Revised 12/2003 W A TER-BBl 1,306 fØ)MS8fL ORIGINAl M~~ ~ () CONTINUED ON REVERSE SIDE RECEIVED MAY 11 2004 Alaska Oil & Gos Gons. CommÎ$$ion Anchorage G J:: 28. e GEOLOGIC MARKERS 29. e FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". West Sak 7599' 6622' None Colville / K-12 7779' 6771' HRZ 9859' 8554' Kalubik 9973' 8652' Kuparuk 10028' 8698' RECE\VEO MAY 11 2.004 Commission 0·\ & Gas Cens. Maska ¡ ~nchofage 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble ~ ~ Title Technical Assistant Date OS,{{..õL( P1-07 A 204-037 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Rob Tir.pack, 564-4166 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Name: P1-07(08) Common Name: P1-07A 4/9/2004 4/15/2004 FIT FIT 7,341.0 (ft) 10,644.0 (ft) 6,425.0 (ft) 9,206.0 (ft) 9.60 (ppg) 10.10 (ppg) 468 (psi) 3,500 (psi) 3,672 (psi) 8,330 (psi) 11.00 (ppg) 17.42 (ppg) tit It Printed: 4/19/2004 12:09: 13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-07(08) P1-07A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/6/2004 Rig Release: 4/17/2004 Rig Number: Spud Date: 2/2/1990 End: 4/17/2004 4/5/2004 14:00 - 19:00 5.00 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 03-07A - Hold PJSM wI Security, CPS, And Rig Team 19:00 - 00:00 5.00 MOB P PRE Move sub from DS 03-07Ai to P1-07A. 4/6/2004 00:00 - 06:30 6.50 MOB P PRE Move sub from DS 03-07Ai to P1-07A. 06:30 - 10:30 4.00 RIGU P PRE Pin sub cellar doors, Lay Herculite - Spot sub over Point Mac P1-07 - Close up cellar doors 10:30 - 12:00 1.50 RIGU P PRE Raise Derrick and pin, Raise Cattle chute and pin 12:00 - 15:00 3.00 RIGU P PRE Spot mud pit complex and cutting box - Spot camp and welding shop - Prepare rig for acceptance - Rig accepted at 1400 hrs 4/6/04 - Back up rig acceptance one hour due Central Power Station personnel measuring rig height before rig move. 15:00 - 15:30 0.50 RIGU P PRE Pre-Spud meeting with all personnel 15:30 - 17:00 1.50 WHSUR P DECOMP Install double annulus valve, Rig up drill site maintenance Lubricator and pull CIW 3" BPV - no pressure on well, Rig down lubricator 17:00 - 20:30 3.50 KILL P DECOMP Rig up surface lines and test to 4000 psi - attempt to reverse circulate out tubing freeze protection, no go, pressure up - check lines, all ok - Circulate by pumping down tubing taking return out annulus to cutting tank - no problem -Displace well bore by pumping 50 bbl SafeKleen pill followed 8.4 filtered seawater until clean seawater at surface - Monitor well - No pressure 20:30 - 21 :30 1.00 BOPSUF P DECOMP Install CIW 3" Two way check valve with dry rod - Test to 3500 psi from above - Blow down surface lines 21 :30 - 23:30 2.00 BOPSUP P DECOMP Nipple down CIW 11" x 3 1/8" 5000# tubing head adapter and 3 1/8 Tree - Stand back and secure tree in cellar 23:30 - 00:00 0.50 BOPSUF P DECOMP Nipple up 11" x 13 5/8 5000# DSA 4/7/2004 00:00 - 04:30 4.50 BOPSUF P DECOMP Nipple up 3' 13 5/8 x 13 5/8 5000# spacer spool - Nipple up 13518 Bop stack - 2 7/8 x 5" Varaible rams in bottom, 3 1/2 x 6" varaible rams in top 04:30 - 10:00 5.50 BOPSUF P DECOMP Test Bop: Test all rams, lines and valves to 250 low, 3500 high, Test hydrill, floor valves, top drive manual & IBop to 250 and 3500 psi- 5 minutes each test- all ok 10:00 - 11 :00 1.00 BOPSUP P DECOMP Rig up drill site maintenance lubricator and pull two way check 11 :00 - 12:30 1.50 PULL P DECOMP Make up 3 1/2 8rd crossover to jt. of drill pipe, screw into tubing hanger, back out lock down screw and pull tubing hanger to rig floor with no problems, P/U wt. 86k - Rig up tubing tongs - Lay down tubing hanger 12:30 - 14:30 2.00 PULL P DECOMP Rig up Camco spooling unit, Pooh lay down 71 jts 31/29.3# L-80 8rd ¡PC tubing, Lay down AVA sssv, Recovered 75 SS bands (two short of tubing detail)- Rig down spooling unit and clear rig floor 14:30 - 22:00 7.50 PULL P DECOMP Continue pooh laying down 3 1/2 tuibing - Lay down total 241 jts, SSSV, 2-GLM, 3-pup jts & 15' cut jt. - Norm tubing, all ok- Rig down tubing tong and clear, clean rig floor 22:00 - 22:30 0.50 WHSUR P DECOMP Install wear bushing 22:30 - 00:00 1.50 CLEAN P DECOMP Make up Baker window milling assembly with 8.5 od upper mill, difficulty getting past wear bushing - Pull wear bushing and leave out, TIH picking up milling BHA 4/8/2004 00:00 - 06:00 6.00 CLEAN P DECOMP Continue make up BHA, Pick up 9 - 61/4" drill collars & 21 - 5" Hwt drill pipe - TIH picking up 4" 15.7# S-135 HT-40 drill pipe Printed: 4/19/2004 12:09:24 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-07(08) P1-07A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/6/2004 Rig Release: 4/17/2004 Rig Number: Spud Date: 2/2/1990 End: 4/17/2004 4/8/2004 00:00 - 06:00 6.00 CLEAN P DECOMP from pipe shed.- Tag tubing stub at 7,580' dpm - stand back one stand in derrick 06:00 - 08:00 2.00 CLEAN P DECOMP Slip and cut 153' of drill line, Adjust brakes - Service top drive 08:00 - 09:00 1.00 CLEAN P DECOMP Make up Halliburton 9 5/8 Rtts and Storm valve, Set top storm valve 2' below casing head, Test to 1000 psi from above 09:00 - 12:00 3.00 WHSUR P DECOMP Nipple down and set back bop stack - Nipple down and remove spacer spool, DSA, & CIW gen 4 13518 x 11" 5000# tubing head 12:00 - 16:30 4.50 WHSUR P DECOMP Verify all pressue off 9 5/8 x 13318 annulus - change out mandrell hanger pack-off - Nipple up 3 It 13518 x 135/85000# spacer spool wi 6" intergal 9 5/8 stub out top of spool - Nipple up McEvoy SSH 13518 x 13 5/8 5000# tubing head - Test both pack-off to 5000 psi - ok 16:30 - 18:00 1.50 WHSUR P DECOMP Nipple bop stack - Test all breaks to 3500 psi - ok 18:00 - 18:30 0.50 WHSUR P DECOMP Install wear bushing 18:30 - 19:30 1.00 CLEAN P DECOMP Retrieve & lay down storm packer - Clear rig floor 19:30 - 23:00 3.50 CLEAN P DECOMP Pump slug, Pooh 23:00 - 00:00 1.00 CLEAN P DECOMP Rig up Schlumberger E-line - Make up Halliburton 9 5/8 Bridge Plug & RIH 4/9/2004 00:00 - 01 :30 1.50 DHB P DECOMP Continue RIH with 9 5/8 bridge plug on E-Line, Tag tubing stub at 7583' elm - Log up, casing collar at 7,373' - Set top of Bridge plug at 7,368' elm - bottom of plug 2' above casing collar- Pooh - RID E-line 01 :30 - 02:30 1.00 DHB P DECOMP Test casing to 3500 psi for 30 minutes on chart - ok 02:30 - 06:00 3.50 STWHIP P WEXIT Pick up Baker 9 5/8 Window Master whipstock and make up to milling assembly, Make up MWD, orient and program - Continue make BHA out of derrick 06:00 - 09:30 3.50 STWHIP P WEXIT Shallow test MWD ok, TIH with drill pipe slowly to 7,238' 09:30 - 10:00 0.50 STWHIP P WEXIT Service top drive - Install blower hose, fill pipe 10:00 - 10:30 0.50 STWHIP P WEXIT Orient whipstock to 82 deg right of high side, tag bridge plug at 7,366' dpm, set whipstock anchor & verify with 20k plu, Shear off whipstock with 45k down wt. 10:30 - 11 :30 1.00 STWHIP P WEXIT Displace seawater with 9.6 ppg LSND mud at 550 gpm 1600 psi 11 :30 - 15:30 4.00 STWHIP P WEXIT Mill 81/2" window in 9 5/8 casing 7,341 to 7,357' with 500 gpm, 100 rpm's, 4-6 wob . starter mill depth 7,370' 15:30 - 16:30 1.00 STWHIP P WEXIT Circulate around high vis sweep at 500 gpm, 1600 psi - Work mill over slide, clean 16:30 - 17:00 0.50 STWHIP P WEXIT Test formation to 468 psi at 6,425' TVD with 9.6 ppg mud in hole for 11.0 ppg EMW - ok 17:00 - 22:30 5.50 STWHIP P WEXIT Monitor well, Pump slug, Blow down top drive - Pooh, Lay down mills, Top mill in gauge - Clear rig floor 22:30 - 23:30 1.00 STWHIP P WEXIT Pull wear bushing, wash out and function bop, Install wear bushing 23:30 - 00:00 0.50 STWHIP P WEXIT Make up drilling BHA 4/10/2004 00:00 - 02:00 2.00 STWHIP P WEXIT Continue make up Bha: Pick up Hughes RR 8112 HCM 605 PDC bit, Sperry 7" motor set at 1.22 deg, Adjustable gauge stablizer, MWD/GR/RES/ Den/Neutron/PWD logging tools - Test and verify adjustable stablizer operational pressure - Load source 02:00 - 04:30 2.50 STWHIP P WEXIT TIH picking up 102 jts of 4" drill pipe from pipe shed 04:30 - 05:00 0.50 STWHIP P WEXIT Continue TIH with stands out of derrick to 6,660 05:00 - 06:00 1.00 STWHIP P WEXIT Mad Pass 6,620 to 6,965' in recorded mode for Tie in log Printed: 4/19/2004 12:09:24 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-07(08) P 1-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/6/2004 Rig Release: 4/17/2004 Rig Number: Spud Date: 2/2/1990 End: 4/17/2004 4/10/2004 06:00 - 07:00 1.00 STWHIP P WEXIT TIH 6,965 to 7,237' - Install blower hose - Fill pipe and orient to 85 deg right - Shut down pumps, pass thru window 7,341 to 7,357 with no problem - Tag under gauge hole at 7,361' - Ream 9' to bottom at 7,370' 07:00 - 00:00 17.00 DRILL P PROD1 Directional drill 7,370 to 8,264' at 2400 hrs - Ast 8.42 hrs, Art 1.39 hrs, Average Rop 91 ft/hr - Turn well bore to right from 302 to 20 deg, Drop angle 43 degree to 22 degree and strart building back up as per directional plan - Pumping 565 gpm at 2900 psi, with 5 -12 K wob - Maintain mud wt 9.6 - 9.7 ppg, ECD 10.5 ppg - survey every 30' for JORPS 4/11/2004 00:00 - 06:30 6.50 DRILL P PROD1 Directional drill 8,264 to 8,637 ' - Continue turning well bore right to 53 deg azimuth and builing angle back to 33 degrees as per directional plan - finish turn and build section at 8,560' - Rotate ahead to 8,637'- Pumping 565 gpm at 3200 psi, 100 rpm's with 8 -1 Ok torque, 10 -15K wob - Ast 3.12 hrs, Art .97 hrs, Average Rop 91 ft/hr 06:30 - 07:30 1.00 DRILL P PROD1 Pump high vis sweep, circulate around - shakers clean 07:30 - 08:30 1.00 DRILL P PROD1 Pooh for planned short trip - No problem - Max drag 5K - Pick up wt off bottom 215k 08:30 - 09:00 0.50 DRILL P PROD1 Service top drive and grease crown 09:00 - 10:00 1.00 DRILL P PROD1 TIH -Fill pipe and wash 90' to bottom at 8,637' - No problem on TIH, no fill-s/o wt 155k 10:00 - 17:00 7.00 DRILL P PROD1 Drill tangent section 8,637 to 9,317' - Ast .58 hrs, Art 3.76 hrs, Average Rop 156 ft/hr- Pumping 565 gpm at 3500 psi, Rotate at 120 Rpm's with 1 0-12K torque - plu 205, slo 165, rlt 185 - While drilling at 9,317' wash out occured on #1 mud pump pulsation dampner flange - Shut in and lock out #1 mud pump 17:00 - 18:30 1.50 DRILL P PROD1 Circulate hole clean at 7.0 bpm 1200 psi - Monitor well 18:30 - 19:30 1.00 DRILL P PROD1 Pooh into 9 5/8 casing - plu wt off bottom 225k - No problem, max drag 5k 19:30 - 21 :30 2.00 DRILL P PROD1 Slip and cut drill line, Service top drive - Clean mud pits, Take on new 9.9 ppg 3% kcl LSND mud system 21 :30 - 00:00 2.50 DRILL N RREP PROD1 Repair mud pump #1: Weld new ends on Goose neck, Replace pulsation dampner 4/12/2004 00:00 - 03:30 3.50 DRILL N RREP PROD1 Continue Rig Repair of mud pump #1 wash out on pulsation dampner - Replace Goose neck and pulsation dampner, Charge pulsation dampner and pressure test mud pump to 4000 psi- ok 03:30 - 04:30 1.00 DRILL P PROD1 TIH to 9,317' - Pump sweep & Displace drill pipe with New 3% KcI LSND mud - Start drill after new mud out bit 04:30 - 10:00 5.50 DRILL P PROD1 Drill ahead 9,317 to 9,662' - Shaker loading up with cutting and wall cake, Screens will not handle load. Change shaker screens from 200 mesh to 180 & 150 mesh. Torque(8-9000 ft-Ibs to 1-12000 ftlbs) and drag increasing, Hole wanting to pack-off, Pick up wt. increased from 205 to 235k Art 1.98 hrs, Ast 1.34 hrs, Average rop 104 ft/hr - Pumping 525 gpm at 3250 psi, rotating at 120 rpm's with 12 -16 ft/# torque 10:00 - 12:00 2.00 DRILL P PROD1 Circulate -pump high vis sweep at 510 gpm 3000 psi to clean up hole - Rotate at 100 rpm's - Shakers cleaning up 12:00 - 00:00 12.00 DRILL P PROD1 Drill 9,662 to 10,314' - Art 2.8 hrs, Ast 4.33 hrs, Average rop 91 ft/hr - Pumping 525 gpm at 3300 psi, ECD 10.6 ppg, Rotate at 100 rpm's with 14k torque - Maintain mud wt at 9.9 ppg- -Control drill +1- 125 ft/hr keep from loading up wellbore - angle Printed: 4/19/2004 12:09:24 PM e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-07(08) P1-07A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 4/6/2004 Rig Release: 4/17/2004 Rig Number: Spud Date: 2/2/1990 End: 4/17/2004 4/12/2004 12:00 - 00:00 12.00 DRILL P PROD1 dropping 3 to 4 degree per stand as rotating in shale section, Slidling about 50% of time - After drillling into Kuparuk formation BHA angle drop stopped. 4/13/2004 00:00 - 11 :00 11.00 DRILL P PROD1 Directional drill 1 0,314 to 10,671 TD. Pump Sweep. Art 5.06 hrs, Ast .82 hrs, PU wt 270K, SO wt 165K, RT wt 205K, TO on btm 12/17K, TO off btm 14/14K 11 :00 - 12:00 1.00 DRILL P PROD1 Ream underguage hole from 10,596 to 10,671. Pump sweep. 12:00 - 12:30 0.50 DRILL P PROD1 Circulate hole clean, rotate and reciprocate pipe 12:30 - 15:00 2.50 DRILL P PROD1 PJSM. POOH from 10,671 to 10,590. Pulled 60K over - PU stand and MU TDS. Break circulaiton and rotate to break free. RIH to bottom, LD top single. POOH from 10,671 to 7,295. 10,671 to 10,314 had over pulls 15-30K. 15:00 - 15:30 0.50 DRILL P PROD1 Service TDS 15:30 - 18:30 3.00 DRILL P PROD1 RIH from 7,295 to 10,671. Work through ledges at 8,626 and 9,035. Took weight at 10,240, ream from 10,220 to 10,360. Precautionary ream last 100'. 18:30 - 20:30 2.00 DRILL P PROD1 Circulate HV sweep at 12-1/2 bpm at 3,500 psi. Spot liner running pill in open hole. Drop ESS. 20:30 - 22:30 2.00 DRILL P PROD1 POOH from 10,671 to 7,291. 50K overpull at 10,590, 25K overpull at 7960. ESS shots at 10,647, 10,553, and 10,459 22:30 - 23:00 0.50 DRILL P PROD1 Pump dry job, blow down TDS 23:00 - 00:00 1.00 DRILL P PROD1 POOH from 7,290 to 4,156 4/14/2004 00:00 - 01 :30 1.50 DRILL P PROD1 POOH from 4,156' to 275'. Stand back HWT DP 01 :30 - 06:00 4.50 DRILL P PROD1 Change elevators, LD DC's, Retrieve ESS, PJSM-Unload sources. LD MWD tools, break off bit, flush, drain and LD motor. Clean and clear rig floor 06:00 - 07:00 1.00 DRILL P PROD1 RIH with HWDP and jars. LD same. 07:00 - 09:00 2.00 P COMP Remove saver sub & RU compensator. RU double stack power tongs,single joint elevators & install 75T YC elevators 09:00 - 11 :00 2.00 CASE P COMP PJSM. MU shoe track, check floats OK. Run 23 joints 7" 26# 13 Cr Vamtop casing to 965' 11 :00 - 11 :30 0.50 CASE P COMP RD computer controls, RD compensator and reinstall saver sub on Top drive 11 :30 - 15:30 4.00 CASE P COMP Pick up 60 joints 7" 26# L-80 BTM-Mod liner 2,486' 15:30 - 16:00 0.50 CASE P COMP MU Baker 9-5/8" X 7" HMC liner hanger with ZXP liner top packer. Change out handling equipment. RIH with one stand 4" DP to 3,590'. 16:00 - 17:00 1.00 CASE P COMP Circulate liner volume at 5.5 BPM 320 PSI 17:00 - 19:00 2.00 CASE P COMP Run liner on DP from 3,590' to 7,324' 19:00 - 20:00 1.00 CASE P COMP Circulate Dp and liner volume 5 BPM @ 520 psi. Up wt = 165K, down wt = 130K 20:00 - 22:30 2.50 CASE P COMP Run liner on DP in open hole from 7,324' to 10,626' without problem. Tag fill at 10,629'. Break circulation 2BPM @ 500 psi. Wash down staging up circ to 5 BPM @ 850 psi, 85 SPM. Work pipe from 10,629' to 10, 644' (PBTD = 10,562). Up wt = 260-285K, down wt = 145K Unable to wash further. Shoe 27' off bottom. 22:30 - 23:00 0.50 CASE P COMP MU cement head, blow down Top Drive 23:00 - 00:00 1.00 CASE P COMP Reciprocate pipe and circulate at 5 BPM, 850 psi while batching up cement 4/15/2004 00:00 - 00:30 0.50 CEMT P COMP Reciprocate pipe and circulate 5 BPM @ 850 psi. while Ip batching up for cement job. 00:30 - 02:00 1.50 CEMT COMP Pump 3 bbl water ahead. Pressure test lines to 4,000 psi. I I ! ! Printed: 4/19/2004 12:09:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-07(08) P1-07A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/6/2004 Rig Release: 4/17/2004 Rig Number: Spud Date: 2/2/1990 End: 4/17/2004 4/15/2004 00:30 - 02:00 1.50 CEMT P COMP Pump cement job as follows: 35 bbls Mudpush spacer at 11.0 ppg followed by 328 sacks 70 bbls 15.8 Class G with .35% Dispersant TIC D65, .19% Retarder D800, 3% Hi Temp Expanding Agent D176, 2 gal/sk GASBLOC gas migration control additive, .2 gal/sk Antifoam agent D47, 5 BPM. Wash out lines. Drop dart with 9.9 ppg drilling mud. Observed latch up at calculated strokes. Pumped calculated casing volume and shoe joints. Did not bump plug. Cement in place @ 02:03 Reciprocated pipe throughout cement job. Full returns at surface. 02:00 - 02:30 0.50 CEMT P COMP Set liner on bottom. Rotate 15 RH turns to release running tool. Pressure up to 1,000 psi with rig pumps. PU and observe release from seals. 02:30 - 09:30 7.00 CEMT P COMP Circulate btms up @ 8 BPM /1,500 psi. No cement returns observed. COntinue circ @ 4 BPM 550 psi. Wait on cement to reach 500 psi compressive strength. 09:30 - 10:00 0.50 CASE P COMP Set top liner packer. RID cement hoses and head. Pump dry job 10:00 - 14:00 4.00 CEMT P COMP POOH from 7,169'. Service break running tool and LD same 14:00 - 14:30 0.50 P COMP Change out handling equipment, M/U clean out BHA, change out handling equipment 14:30 - 19:00 4.50 CLEAN P COMP PU 27 jts 4" DP. RIH to 10,456'. Connect top drive and wash down to 10,560'. Tag landing collar with 5K set down to verify depth. 19:00 - 20:00 1.00 CLEAN P COMP Circulate btms up 12 BPM @ 2180 psi 200K up wt, 140K down wt. 20:00 - 21 :00 1.00 CLEAN P COMP Test 7" x 9-5/8" casing to 3,500 psi for 30 minutes, good test. Took 126 stks (7.5 bbls) to achieve pressure. Got back 7.4 bbls. 21 :00 - 23:00 2.00 CLEAN P COMP Pump 150 bbl Hi Vis sweep. Displace well with 2% KCI at 12 BPM @ 2200 psi. Rotate and reciprocate pipe during displacement. 23:00 - 00:00 1.00 CLEAN P COMP POOH laying down 4" DP. Midnight depth = 9'428'. 4/16/2004 00:00 . 03:30 3.50 CLEAN P COMP POOH LD DP to 4,000' 03:30 - 05:00 1.50 CLEAN P COMP Slip & cut drill line, service top drive 05:00 - 07:00 2.00 CLEAN P COMP Continue POOH LD DP to BHA 07:00 . 07:30 0.50 CLEAN P COMP LD BHA 07:30 - 08:00 0.50 CLEAN P COMP Remove wear bushing 08:00 - 09:30 1.50 RUNCOMP COMP RU to run completion 09:30 . 10:30 1.00 RUNCOMP COMP PJSM. Make up tail pipe assy. Baker lock all connections below production packer. 10:30 . 19:30 9.00 RUNCOMP COMP MU and run 4-1/2", 12.6#, 13Cr80, VAM TOP tubing string to 7,688'. Make up torque - 4,440 fVlbs. Jet lube seal guard thread compound. 19:30 - 21 :00 1.50 RUNCOMP COMP PJSM. RU control line unit. MU and test control line to 5,000 psi for 15 minutes. Good test. 21 :00 - 00:00 3.00 RUNCOMP COMP Continue running tubing. Install 1 SS control line band per joint. Midnight depth = 9,670 4/17/2004 00:00 - 01 :00 1.00 RUNCOMP COMP RIH with 4-1/2",12.6#, 13Cr80 completion tubing. Total 288 jts run. Total 53 SS control line bands installed. PU wt = 147K, SO wt = 1 08K 01 :00 - 03:00 2.00 RUNCOMP COMP MU landing joint and tubing hanger. MU control line to tubing hanger and test same to 5,000 psi for 15minutes. Good test. Printed: 4/19/2004 12:09:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-07(08) P1-07 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/6/2004 Rig Release: 4/17/2004 Rig Number: Spud Date: 2/2/1990 End: 4/17/2004 4/17/2004 01 :00 - 03:00 2.00 RUNCOMP COMP 03:00 - 08:00 5.00 RUNCOMP COMP 08:00 - 10:30 2.50 RUNCOMP COMP 10:30 - 11 :00 0.50 RUNCOMP COMP 11 :00 - 12:00 1.00 RUNCOMP COMP 12:00 - 13:00 1.00 RUNCOMP COMP 13:00 - 14:00 1.00 RUNCOMP COMP 14:00 - 16:00 2.00 RUNCOMP COMP 16:00 - 18:00 2.00 RUNCOMP COMP 18:00 - 19:00 1.00 RUNCOMP COMP 19:00 - 20:00 1.00 RUNCOMP COMP 20:00 - 23:00 3.00 RUNCOMP COMP 23:00 - 00:00 1.00 RUNCOMP COMP Land tubing hanger. Run in lock down screws. Reverse circulate 433 bbls 3% KCI water with 25 gall 100 bbl of corrosion inhibitor (2 drums). Displace corrosion inhibitor to the GLM at 3,5000' with 3% KCI water. Drop ball & rod.Pressure up on tbg to 3,500 psi to set packer. Test tbg to 3,500 psi for 30 minutes. Bleed pressure back to 1,500 psi. Pressure up on annulus to 3,500 psi and hold for 30 minutes. Bleed pressure down to shear DCR valve. * Note: 1-7/8" ball and rod on RHC seat in XN nipple Pull landing joint and LD same. Run TWC and test same to 1,000 psi Blow down all lines. LD control line spool ND BOPE PJSM. Prepare control line/hanger neck while RU to bring tree and adapter into cellar. PJSM. NU 13-5/8" x 4-1/16" , 5K McEvoy SSH tubing head adapter and CIW 4-1/16" 5K Tree Test tubing hanger pack off to 5,000 psi for 30 minutes - good test. Test control line termination to 5,000 psi for 10 minutes - good test. RU and test tree to 5,000 psi for 10 minutes RU lubricator and pull TWC RU Little Red Hot oil and displace 152 bbls diesel freeze protect down annulus @ 3 BPM. Allow diesel to U-Tube for freeze protection to 2,200'. Install BPV with dry rod and test to 1,000 psi from below. Secure well. Rig released at 0000 hrs (Midnight) Printed: 4/19/2004 12:09:24 PM e e Well: Field: API: Permit: P1-07A Prudhoe Bay Unit / Point Mcintyre 50-029-21996-01-00 204-037 Accept: Spud: Release: Rig: 04/06/04 04/10/04 04/17/04 Nabors 2ES POST RIG WORK 04/18/04 PULLED BALL & ROD FROM 9830' SLM. 04/19/04 PULLED DGLV FROM STATIONS 3,4,5. PULLED DCR SHEAR VALVE FROM STA # 6. SET DOME GLV (2186#) IN STA 6. SET DOME GLV (2216#) IN STA 5. SET DOME GLV (2208#) IN STA 4. SET S/O IN STA 3. PULL EMPTY RHC PLUG BODY. DRIFT TBG WI 3 3/8 DUMMY GUN TAGGED BOTTOM @ 10552' SLM. 04/20/04 RAN USI FOR CEMENT EVALUATION WITH NO PRESSURE ON WELL. 70 BBL 15.8 PPG CLASS G CEMENT PUMPED UP ANNULUS. USIINDICATED POOR CEMENT AND LACK OF ISOLATION OVER ZONES OF INTEREST, SO SCMT WAS RUN TO VALIDATE. SCMT MATCHED USI VERY CLOSELY IN IMAGE AND VDL. 10125' TO 10140' APPEARS TO HAVE DECENT CEMENT. 10010' TO TUBING TALE IS ALSO GOOD CEMENT. MOST OTHER AREAS ARE QUESTIONABLE. 10375' TO 10360' APPEARS TO BE DECENT CEMENT WITH POSSIBLY SMALL CHANNELS. PLAN TO PERFORATE 175' OF WELL ON NEXT TRIP. WELL LEFT SHUT IN. 04/21/04 USI RUN PREVIOUS EVENING SHOWED POOR CEMENT, SO SCMT WAS RUN FOR VERIFICATION. SCMT REPEATED USI READINGS INDICATED IN PREVIOUS DAYS AWGRS REPORT. WELL LEFT SHUT IN. 04/24/04 PERFORATED 10493'-10498',10326'-10331',10272'-10727' AND 10162'-10167' WITH 2 7/8" 34J CS 6 SPF, 17.7" PENE, 0.27" EH, 19 GMS. CORRELATED TO SPERRY SUN MWD DATED 4-14-2004. 04/25/04 LOC TT @ 9707' SLM -13' = 9694' ELMD (SBHPS IN PROGRESS). 04/26/04 SBHPS COMPLETE (GOOD DATA). 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 P1-07A 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: 7,323.00' MD 7,341.00' MD 10,671.00' 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:<) ayM-r\.( Signed 1W ðáJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager íO '--l-~ D'3 7 AUachment(s) Halliburton Sperry-Sun North Slope Alaska BPXA Point Mcintyre Pad 1, Slot P1-07 dd P1-07A Job No. AKMW3016164, Surveyed: 13 April, 2004 Survey Report 16 April, 2004 Your Ref: API 500292199601 Surface Coordinates: 5994578.63 N, 674331.75 E (70' 23' 27.1269" N, 148' 34' 54.1937" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 994578.63 N, 174331.75 E (Grid) Surface Coordinates relative to Structure Reference: 92.08 S, 329.69 E (True) Kelly Bushing Elevation: 37.50ft above Mean Sea Level Kelly Bushing Elevation: 37.50ft above Project V Reference Kelly Bushing Elevation: 37.50ft above Structure Reference SP,E!ï'Ï'\I-E5UI1 ORILLING SERVn::eS A Halliburton Company DEFINITIVE e e Survey Ref: svy4256 Halliburton Sperry-Sun Survey Report for Point Mcintyre Pad 1- P1-07A Your Ref: AP/500292199601 Job No. AKMW3016164, Surveyed: 13 April, 2004 BPXA North Slope A/aska 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) 7323.00 43.330 302.800 6374.51 6412.01 1373.51 N 2245.13 W 5995899.41 N 672055.21 E -175.02 Tie On Point MWD Magnetic 7341.00 43.330 302.570 6387.61 6425.11 1380.18 N 2255.53 W 5995905.84 N 672044.66 E 0.878 -175.58 Window Point 7413.42 41.580 308.040 6441.05 6478.55 1408.37 N 2295.41 W 5995933.10 N 672004.13 E 5.640 -175.59 7442.72 41.300 310.390 6463.02 6500.52 1420.63 N 2310.43 W 5995945.00 N 671988.82 E 5.393 -174.25 7476.21 40.580 313.180 6488.32 6525.82 1435.25 N 2326.79 W 5995959.23 N 671972.12 E 5.867 -171.77 e 7507.48 39.800 315.880 6512.21 6549.71 1449.39 N 2341 .18 W 5995973.04 N 671957.41 E 6.104 -168.53 7535.81 38.680 318.410 6534.15 6571.65 1462.52 N 2353.37 W 5995985.88 N 671944.92 E 6.894 -164.84 7570.07 37.240 321.560 6561.17 6598.67 1478.65 N 2366.92 W 5996001.69 N 671930.99 E 7.045 -159.50 7601.09 36.780 324.500 6585.94 6623.44 1493.57 N 2378.15 W 5996016.34 N 671919.42 E 5.894 -153.81 7629.31 35.960 327.250 6608.66 6646.16 1507.41 N 2387.54 W 5996029.96 N 671909.71 E 6.468 -147.92 7662.93 34.660 328.950 6636.10 6673.60 1523.91 N 2397.81 W 5996046.21 N 671899.06 E 4.847 -140.39 7693.91 33.740 330.960 6661.72 6699.22 1538.98 N 2406.53 W 5996061.08 N 671889.99 E 4.703 -133.12 7721.70 33.300 333.510 6684.89 6722.39 1552.55 N 2413.68 W 5996074.48 N 671882.53 E 5.308 -126.17 7755.68 32.120 335.650 6713.48 6750.98 1569.13 N 2421.57 W 5996090.87 N 671874.25 E 4.862 -117.18 7787.16 31.170 338.510 6740.28 6777.78 1584.34 N 2428.00 W 5996105.92 N 671867.47 E 5.641 -108.48 7815.56 30.290 340.530 6764.70 6802.20 1597.93 N 2433.08 W 5996119.39 N 671862.07 E 4.776 -100.32 7848.96 27.970 342.750 6793.87 6831.37 1613.35 N 2438.21 W 5996134.69 N 671856.58 E 7.662 -90.69 7880.06 26.820 345.060 6821.48 6858.98 1627.10 N 2442.19 W 5996148.34 N 671852.29 E 5.035 -81.76 7908.28 25.570 347.260 6846.80 6884.30 1639.19 N 2445.17 W 5996160.36 N 671849.03 E 5.609 -73.61 7941.89 23.570 350.310 6877.37 6914.87 1652.89 N 2447.90 W 5996174.00 N 671845.98 E 7.044 -64.01 7973.06 22.080 352.860 6906.10 6943.60 1664.85 N 2449.68 W 5996185.91 N 671843.92 E 5.737 -55.27 e 8001.80 21.930 356.050 6932.75 6970.25 1675.56 N 2450.72 W 5996196.59 N 671842.63 E 4.191 -47.12 8035.99 21.970 1.150 6964.46 7001.96 1688.33 N 2451.03 W 5996209.35 N 671842.02 E 5.575 -36.88 8067.11 21.610 5.680 6993.36 7030.86 1699.85 N 2450.35 W 5996220.89 N 671842.44 E 5.525 -27.08 8094.23 21.990 9.120 7018.54 7056.04 1709.83 N 2449.05 W 5996230.90 N 671843.50 E 4.914 -18.18 8128.26 22.800 14.360 7050.01 7087.51 1722.51 N 2446.40 W 5996243.63 N 671845.85 E 6.329 -6.30 8159.84 23.420 17.770 7079.05 7116.55 1734.42 N 2442.97 W 5996255.62 N 671849.01 E 4.670 5.40 8188.71 24.550 20.990 7105.43 7142.93 1745.48 N 2439.07 W 5996266.77 N 671852.65 E 5.988 16.69 8223.04 26.380 24.660 7136.43 7173.93 1759.07 N 2433.33 W 5996280.49 N 671858.06 E 7.036 31.10 8254.54 27.130 28.410 7164.56 7202.06 1771.75N 2426.99 W 5996293.31 N 671864.11 E 5.863 45.11 16 April, 2004 - 16:48 Page 2 of4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Point Mc/ntyre Pad 1 - P1-07A Your Ref: API 500292199601 Job No. AKMW3016164, Surveyed: 13 April, 2004 BPXA North Slope A/aska 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) 8282.88 28.080 30.850 7189.67 7227.17 1783.16N 2420.50 W 5996304.87 N 671870.33 E 5.210 58.18 8316.06 28.990 33.640 7218.82 7256.32 1796.56 N 2412.04 W 5996318.46 N 671878.48 E 4.863 74.00 8347.41 29.460 36.120 7246.18 7283.68 1809.11 N 2403.29 W 5996331.22 N 671886.93 E 4.143 89.30 8376.36 30.450 37.590 7271.27 7308.77 1820.68 N 2394.61 W 5996342.98 N 671895.33 E 4.257 103.75 8409.38 31.140 40.100 7299.63 7337.13 1833.84 N 2384.01 W 5996356.38 N 671905.63 E 4.417 120.62 e 8439.98 32.200 42.020 7325.67 7363.17 1845.95 N 2373.46 W 5996368.74 N 671915.90 E 4.780 136.60 8468.72 32.790 44.290 7349.92 7387.42 1857.21 N 2362.90 W 5996380.24 N 671926.19 E 4.713 151.89 8501.86 33.850 48.200 7377.61 7415.11 1869.79 N 2349.75 W 5996393.12 N 671939.05 E 7.226 169.75 8533.12 34.610 51.520 7403.46 7440.96 1881.12 N 2336.31 W 5996404.76 N 671952.22 E 6.449 186.76 8562.53 35.240 53.460 7427.57 7465.07 1891.36 N 2322.95 W 5996415.32 N 671965.33 E 4.341 202.84 8653.23 35.130 53.370 7501.70 7539.20 1922.51 N 2280.98 W 5996447.44 N 672006.56 E 0.134 252.51 8745.69 34.440 52.130 7577.64 7615.14 1954.44 N 2239.00 W 5996480.33 N 672047.79 E 1.069 302.82 8839.70 33.660 50.960 7655.53 7693.03 1987.17 N 2197.77 W 5996514.01 N 672088.24 E 1.083 353.34 8933.07 32.810 51.910 7733.63 7771.13 2019.07 N 2157.77 W 5996546.84 N 672127.49 E 1.068 402.49 9026.01 31.850 51.850 7812.16 7849.66 2049.75 N 2118.66 W 5996578.43 N 672165.87 E 1.034 450.12 9120.22 30.930 50.700 7892.58 7930.08 2080.44 N 2080.38 W 5996610.00 N 672203.43 E 1.165 497.28 9213.99 30.130 51.410 7973.35 8010.85 2110.39 N 2043.33 W 5996640.80 N 672239.77 E 0.936 543.12 9307.44 32.300 55.390 8053.28 8090.78 2139.20 N 2004.44 W 5996670.52 N 672277.97 E 3.203 589.11 9400.06 31.850 55.230 8131.76 8169.26 2167.20 N 1964.00 W 5996699.44 N 672317.75 E 0.494 635.31 9493.80 33.210 54.780 8210.79 8248.29 2196.11 N 1922.71 W 5996729.31 N 672358.36 E 1.474 682.76 9587.72 35.530 55.910 8288.31 8325.81 2226.24 N 1879.09 W 5996760.45 N 672401.26 E 2.562 732.55 9679.90 33.550 56.030 8364.23 8401.73 2255.49 N 1835.78 W 5996790.70 N 672443.88 E 2.149 781.44 e 9773.76 31.490 56.940 8443.37 8480.87 2283.36 N 1793.72 W 5996819.54 N 672485.28 E 2.256 828.48 9867.38 30.900 56.230 8523.46 8560.96 2310.06 N 1753.25 W 5996847.18 N 672525.12 E 0.743 873.65 9959.90 32.150 57.650 8602.32 8639.82 2336.44 N 1712.70 W 5996874.50 N 672565.04 E 1.571 918.60 10054.32 30.740 57.960 8682.87 8720.37 2362.68 N 1671.02 W 5996901.71 N 672606.10 E 1.503 964.09 10146.65 36.140 56.380 8759.89 8797.39 2390.30 N 1628.31 W 5996930.31 N 672648.15 E 5.924 1011.30 10241.15 39.410 55.150 8834.58 8872.08 2422.88 N 1580.48 W 5996964.00 N 672695.21 E 3.551 1065.52 10334.46 39.560 55.810 8906.59 8944.09 2456.50 N 1531.59W 5996998.75 N 672743.30 E 0.478 1121.20 10428.00 39.080 55.540 8978.96 9016.46 2489.92 N 1482.64 W 5997033.31 N 672791.46 E 0.545 1176.75 10522.46 38.550 55.760 9052.56 9090.06 2523.33 N 1433.76 W 5997067.84 N 672839.55 E 0.580 1232.25 10597.37 38.570 55.580 9111.14 9148.64 2549.66 N 1395.20 W 5997095.07 N 672877.48 E 0.152 1276.02 10671.00 38.570 55.580 9168.70 9206.20 2575.61 N 1357.33 W 5997121.89 N 672914.74 E 0.000 1319.07 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. 16 April, 2004 - 16:48 Page 3 of4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Point McIntyre Pad 1 - P1-07 A Your Ref: API 500292199601 Job No. AKMW3016164, Surveyed: 13 April, 2004 BPXA North Slope Alaska Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 35.2700 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10671.00ft., The Bottom Hole Displacement is 2911.38ft., in the Direction of 332.2110 (True). Comments e Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7323.00 7341.00 10671.00 6412.01 6425.11 9206.20 1373.51 N 1380.18N 2575.61 N 2245.13 W 2255.53 W 1357.33 W Tie On Point Window Point Projected Survey Survey too/prOgram for P1-07 A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 7323.00 0.00 6412.01 7323.00 10671.00 6412.01 BP High Accuracy Gyro (P1-07) 9206.20 MWD Magnetic (P1-07A) e 16 April, 2004 - 16:48 Page 4 of4 Dril/Quest 3.03.06.002 , 4272'~ - P1.-7A Proposed c.. pIdeA P 1 -01 A ·f'\)r'C) \)r~1lRfE" waUEAD .. AC11JA TOR" .1<8: e..E:V .. SF. eµ:v .. KOP= Max~= DIWm M).. Datum lVO" 2900' 44.68OÓ' 10272- 8800' SS 4·1/16" CALr:;o.aNNt.::SlOY AxaSON 42' O· ......... ;2J7? 14.112" HESWellStar SS8Vat~MO f ...... -.J .~ 13-3/8",68#. L-80 , _ -Jù GL"ð D~9n; .3S""n #6 - 3500'TVD.. 4-112" X 1-1/2" $"'CU3 #5.. 5000' TVO .. 44/2" X 1-1/Z' .$"""?9-#4 - 5700' TVO.. 4-1/2" X 1-1/Z' (,)..~t> #3... 6400' TVe.. 4-112" X 1..1/2" 721'1 #2.. 7100' TVe.. 4..1/2" Xi" 7gð;J... #1-7800' TVe.. 4..1/2" Xi" ........ t - _---;41-112", 12.6#, 13Cr-80. VAM.-Top Tubing I t - '711Þ' :J < }"ØJ- ¡I/,e¡ I 7,2ØO' &. ..... 9-518" X 7" HMC Uner Hanger with ZXP Uner Top Packer and C2 Running Tool" Top of Window at ~ 1Y+( BP set at 7/Jfff "'}3.G.g x J- 9471' ~ E 11 ,Oga' ~ Date 1-13-04 . "..,. .....,.n... ,t' "t__7'ii1t· ~~ ..,,~ t \, ". T.Ubinç¡ TAIt: ..1 O'Pup Joint -X Nipple (3.813") -2 x 10' Pup Joint -Packer -2 x 10' Pup Joint -X Nipple (3.813") -2 x 10' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG -<::::: x ~TOC @ 8,540'1 '1'7c; 7", 26# Cross..over L..80 to 13CrBO @ ~ I r X 4-1/2" 8..3 Permanent Packer @ 9,646!1 fWð& !.: .. ~ .. 9...5/8", 47#, L-80 2: ~ I t>,I....J¡ t¡ 7',26# @ 10.653' L-80 BTC-M from liner top to -100' above packer and 13..cr80 YAM-Top to TO. t . .. 7", 29#, l-80 Rev By WSI .RBT POINT MCINTYRE UNIT WELL: P1-07 A API NO: 50-029..21996-01 " Pétmlt'NO:~204-V3'i " GPB Rotary Drilling Comments Proposed Completion Design - wp04 ..: ~ Completion Design - wpOS Rob , Per 20 AAC 25.035 (h) (1), alternate BOPE is approved for well P1-07A (PTD No. 204-037). All other permit stipulations apply. Winton Aubert AOGCC 793-1231 Tirpack, Robert B wrote: Winton, For the next well on Nabors 2es, P1-07A (Permit #204-037), it is requested to not change out the VBR's to 7" casing rams during the running of the 7" liner, The statement requesting this in the original drilling permit application was accidentally left out. The well control section should have included: "The VBRs will not be changed to accommodate the 3450-ft 7" production liner. Instead, the current and best practice of picking up a joint of drillpipe, with crossover to the casing thread, will be employed in the event of a kick. This practice provides two rams capable of closing on the pipe across the BOP stack instead of just a single 7" ram." Please call with any questions. Regards, Rob Tirpack GPB Rotary Drilling 564-4166 office 440-8633 cell tirpacrb@bp.com · '" FRANK H. MURKOWSKI, GOVERNOR A 14A.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" 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: Point McIntyre P1-07 A BP Exploration (Alaska) Inc. Permit No: 204-037 Surface Location: 1449' NSL, 722' WEL, SEe. 16, Tl2N, R14E, UM Bottomhole Location: 4022' NSL, 2139' WEL, SEC. 16, Tl2N, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill 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 witness any required test. Contact the Commission's North Slope petroleum field' tor t -3607 (pager). S' c BY ORDER OF THE COMMISSION DATED thisð':>day of February, 2004 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encI. \rJ 6Þ\ Z-/zc.J{z,ooL \;:J4I\ 1 a. Type of work 0 Drill JlI Redrill ORe-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: 1449' NSL, 722' WEL, SEC. 16, T12N, R14E, UM Top of Productive Horizon: 3818' NSL, 2415' WEL, SEC. 16, T12N, R14E, UM Total Depth: 4022' NSL, 2139' WEL, SEC. 16, T12N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-674332 y-5994579 Zone-ASP4 16. Deviated Wells: Kickoff Depth a STATE OF ALASKA . ALASKA OlrJND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 ideA- 1b. Current Well Class 0 Exploratory m Development Oil 0 Multiple Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 P1-07A/ 6. Proposed Depth: 12. Field / Pool(s): MD 10652 TVD 9206 Point Mcintyre 7. Property Designation: ADL 028297 8. Land Use Permit: 13. Approximate Spud Date: April 19, 2004 ,/ 14. Distance to Nearest Property: 3400' 9. Acres in Property: 2560 7350 ft Maximum Hole Angle 44° 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): Plan 37.5' feet P1-12 is 301' away at 9708' 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 4291 psig Surfac· 3374/ psig To:ettin~iC.~ MD TVD MD TVD 1,..5 '; includinç¡ staç¡' 7200' 6323' 9700' ~416' ~sx C . 9700' 8416' 10652' 9206'. '11~:~~~o; 7 9 '004 N1,.. ,:; Cons. ('.nn.,) . "'i·'!"J9~ '""''U IIdIriIDn Hole 8-1/2" 8-1/2" Casinç¡ 7" 7" Weight 26# 26# Grade L-80 13Cr80 Coupling Lenç¡th BTC-M 2500' VAM-ACE 952' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD 11100 9623 10354 10354 8919 Structural Conductor 113' 20" 2150# Poleset 113' 113' Surface 4272' 13-3/8" 2750 sx CS III, 500 sx Class 'G' 4272' 4092' Intermediate 9471' 9-5/8" 1425 sx Class 'G' 9471' 8094' Production Liner 1973' 7" 425 sx Class 'G', 50 sx Class 'G' 9125' -11098' 7782' - 9621' 20. Attachments 181 Filing Fee 0 BOP Sketch 181 Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8065' - 8745' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 MC 25.050 Requirements Perforation Depth MD (ft): 9440' - 10168' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Date: Contact Rob Tirpack, 564-4166 Phone 564-5521 Date -z./IIf/Ø·' Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill Number:.zo'Y- 0 ~ '7 50-029-21996-01-00 Conditions of Approval: Samples Required Hydrogen fj Measures E 0 pç{'. DYes ~No ~Yes DNo Permit Approval_ /. j Date: ;;2/dl-'l. 0 Mud Log Required Directional Survey Required See cover letter for other requirements D Yes g No ~Yes D No ,~ BY ORDER OF ~~~~ THE COMMffB'N~ ' '¡~ tb~ r<~¡.. -=- · . IWell Name: P1-07A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer .- ,- Surface Location: As built Target Location: Top Kuparuk Bottom Hole Location: x = 674,332 Y = 5,994,582 3828' FNL 724' FEL Sec. 16, T12N, R14E Umiat /' X = 672,581 Y = 5,996,909 TVDss 8,660' 1462' FNL 2415' FEL Sec. 16, T12N, R14E Umiat X = 672,852 Y = 5,997,119 TVDss 9,169' 1258' FNL 2139' FEL Sec. 16, T12N, R14E Umiat /' I AFE Number: I PMD5L 1048 I I Estimated Start Date: 1 04/19/04 I MD: 110,652' I I TVD: I 9,206' I I Rig: I Nabors 2ES I Operating days to complete: 115.3 I GL: 19.0' ./ I KB: 128.5' I I KBE: 137.5' I Well Design (conventional, slim hole, etc.): I Single String Sidetrack I Objective: I Kuparuk Zone US 1,2,3,4 Formation Markers (Sperry wp05) Formation Tops MD TVD K-15/Ugnu 5,360' 4,941 ' KOP 7,350' 6,432' TWSK 7,583' 6,611' K-12 (Coleville) 7,756' 6,756' K-10 9,604' 8,337' THRZ 9,868' 8,556' TKLB 9,977' 8,646' TKUP 10,039' 8,698' UC2-3 10,052' 8,709' UC1 10,110' 8,757' UB4 10,152' 8,792' UB3 10,218' 8,847' UB1-2 10,250' 8,873' UA 1-4 10,359' 8,964' LC3 10,428' 9,021' LB2-4 10,562' 9,132' LB1 10,616' 9,177' TD 10,652' 9,206' TMLV N/A N/A TD Criteria: Based on 135' MD below OWC P1-07A Drilling Permit TVDss 4,903' 6,394' 6,573' 6,718' 8,299' 8,518' 8,608' 8,660' 8,671' 8,719' 8,754' 8,809 8,835' 8,926' 8,983' 9,094' 9,139' 9,169' 9,245' Comments 8.9 ppg 8.9 ppg 8.9 ppg 8.9 ppg 8.9 ppg 8.9 ppg 8.9 ppg 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing 9.0 ppg Hydrocarbon bearing Not Penetrated q·9 ~ Page 1 . . Directional (Sperry wp05) KOP: 7,350' MD Maximum Hole Angle: _440 at KOP and -340 in 8-1/2" hole Close Approach Wells: There are no close approach issues. Closest Well: The closest well is p1-12, which has a 301' center to center distance. This occurs at 9,708' MD at P1-07A and at 9,300' MD at P1-12. /' Survey Program: MWD Nearest Property Line: 3,400' CasinglTubing Program Hole Size CsglTbg O.D. WtlFt Grade COJJP Length Top Btm / MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 2,500' 7,200'/6,323' 9,700'/8,416' 8-1/2" 7" 26# 13-Cr80 V AM-ACE 952' 9,700'/8,416' 10,652'/9,206' Tubing 4-1/2" 12.6# 13-Cr80 V AM-ACE 9,788' GL 9,825'/8,520' Mud Program Intermediate Mud Properties: 3% KCL Polymer I Depth Density Viscosity PV Milling 9.6 40-60 15-25 KOP to THRZ 9.6 / 30-40 8-15 THRZ to TD 9.9 30-40 8-15 YP 40+ 30-40 30-40 8-1/2" hole section I MBT Chlorides <20 <1000 <20 <500 <20 <500 PH 9.0-9.5 9.0-9.5 9.0-9.5 API FI 4-6 4.6 4-6 Logging Program 8-1/2" Intermediate: Sample Catchers - through Kuparuk Drilling: Dir/GRlRes/Dens/Neu/PWD- Real time Open Hole: None Cased Hole: None Cement Program I Casing Size I 7" 26#, L-80/13-Cr80 Production Casing I Basis: Lead: None Tail: Based on 1613'þf 7" X 8-1/2" open hole with 40% excess and 80' shoe track. Tail TOC: 9,039' MD (1000' above TKUP). I Total Cement Volume: I Lead I None //'"1 Tail 54 bbls, 304 1t3, g.~CkS Class G @ 15.8 ppg, 1.20 ft3/sack P1-07 A Drilling Permit Page 2 . . 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. Production Interval Maximum anticipated BHP Maximum surface pressure Planned BOP test pressure Integrity Test - 8-1/2" hole Kick tolerance 9-5/8" Casing/7" Liner Test Planned completion fluids 4,291 psi (9.0 ppg @ 9,169' TVDss) 3,374 psi (.10 psi/ft gas gradient t9 surface) Rams test to 3,500 psi/250 psi. /' Annular test to 2,500 psi/250 psi 11.0 ppg EMW FIT 104 bbls with 11.0 ppg FIT / 3,500 psi surface pressure 8.4 ppg Seawater / 6.8 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-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 DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. P1-07A Drilling Permit Page 3 . . Sidetrack and Complete Procedure Summary Pre-Ria Work: 1. Rig up slick line. Drift the 3-1/2",9.3#, L-80 IPC tubing to the top of the fill in the 7" liner at 10,354' MD. Dummy off all GLM's. 2. Fluid pack the 3-1/2" tubing and 3-1/2" X 9-5/8" IA with seawater. Well currently has Tbg X IA communication. 3. R/U coil tubing unit. Plug and abandon the 7" liner and 3-1/2" production tubing from the top of fill at 1 0,354' to -8,800' MD with 33 bbls of 15.8 ppg class 'G' cement - squeeze with an additional 5 bbls. Use aggregate as necessary to aid in plugging the perfs. Top of cement in not critical. The tubing will be cut at 7,600' MD. 4. Tag and document top of cement and drift 3-1/2" tubing for upcoming tubing cut. 5. Test the integrity of the cement plug and casing by simultaneously pressure testing both the tubing and annulus to 3500 psi for 30 minutes. 6. RIH with a chemical cutter and cut the 3-1/2",9.3#, L-80 IPC tubing at -7,600' MD. This cut will not be fished. 7. Displace the well to seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect top 2200' MD with diesel. 8. Test the 9-5/8" casing pack-off to 3000 psi and tubing hanger seals to 5000 psi for 30 minutes. MIT the OA to 2000 psi. Function all Lock Down Screws. 9. Bleed all pressures. Set BPV. Secure well. 10. Remove the well house. If necessary, level the pad. Provide total well preparation cost on the handover form. RiQ Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. 3. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. ,-/ 4. Pull 3-1/2" tubing from pre-rig cut. " 5. MU window milling BHA and drift to the KOP. Hang-off on storm packer. / 6. ND BOPE and change out tubing head and 9-5/8" pack-off. Add spacer spool between existing casing head and " new tubing head to raise overall wellhead height -3'. NU;Land recover storm packe~. + L ßD ID E w4J\- 7. MU 9-5/8", 47# bridge plug on e-line with CCL. RIH and sel at -7370' MD. é\v\"'Q et,.t 8. RIH with 9-5/8" Baker whipstock assembly. Orient and set on bridge plug.'-/ 9. Displace well to 9.6 ppg 3% KCL milling fluid. / 10. Mill window in 9-5/8" casing at 7350' MD, plus 20' past middle of window. Perform FIT. POOH. 11. MU 8-1/2" drilling assembly with Dir/GR/Res/Dens/Neu/PWD and RIH. 12. Kick off and drill the 8-1/2" production interval, turning and dropping at 5°/100' to a 34° hold angle. 13. Verify that the mud weight is at least 9.9 ppg prior to cutting HRZ. 14. Drill ahead to a planned TD of 10,652' MD. /' 15. Run and cement 7",26# carbon and chrome liner throughout the 8-1/2" hole and back into the 9-5/8" casing vyith 150' liner lap to 7200'. Displace cement with mud. /' 16. Wait on cement to gain 500 psi compressive strength. Set liner hanger and liner top packer. POOH. 17. Pressure test wellbore to 3500 psi for 30 minutes. 18. MU 6-1/8" clean out assembly. RIH to PBTD. Displace well overto 2% KCL water. POOH, LD DP. ~. 19. Run 4-1/2",12.6#, 13Cr80 VAM-ACE completion. Space out to land WLEG -200' above TISUP. 20. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. / 21. Set and test TWC. 22. ND BOPE. NU and test the tree to 5000 psi. 23. Freeze protect the well to -2200' and secure. 24. RDMO Post-Ria Work: 1. Install wellhouse, flowlines and instrumentation. 2. MIRU slickline. Pull thß! ball and rod / RHC plug from 'XN' nipple below production packer. / 3. Run USIT on e-line. / 4. Install gas lift valves. 5. Perforate -130' of Kuparuk interval with 3-3/8" guns. 6. Obtain static BHP. P1-07 A Drilling Permit Page 4 . . P1-07 A Drilling Program Job 1: MIRU Hazards and Contingencies Þ- Three wells will require well house removal and shut-in for the rig move onto P1-07A. The closest neighboring wells are spaced as follows: P1-06 at -14', P1-08A at -17', and P1-05 at -29'. Care should be taken while moving onto the well P1-07 A. Spotters will be used at all times. Þ- Due to well house removal, P1-06, P1-08A, and P1-05 will have to be shut-in at surface during MIRU. All three wells maybe returned to production after MIRU, provided a temporary safety system and barricades are in place. Point Mac wells are sensative to being shut-in for> 12 hours. Make all attempts to minimize the down time for each well. Þ- P1 is not1Jesignated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: #1 Closest SHL with H2S Reading #2 Closest SHL with H2S Reading #1 Closest BHL with H2S Reading #2 Closest BHL with H2S Reading Max Recorded H2S Reading on the Pad Well Name P1-06 P1-08A P1-20 P1-18A P1-13 / H2S Reading 10 ppm 5ppm 8ppm 20 ppm 60 ppm Date 01/07/02 01/10/03 05/17/02 09/12/03 10/01/98 ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies Þ- The perforations in P1-07 have been isolated with a cement plug set during pre-rig operations. Monitor well for any signs of pressure or flows. Þ- Note and record required PU weight to pull tubing at cut point. Þ- NORM test all retrieved well head and completion equipment. Þ- Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP P1-07A Drilling Permit Page 5 . . Job 3: Run Whipstock/Mill Window Hazards and Contingencies )- Once window milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP Job 7: Drill 8-1/2" Production Hole Hazards and Contingencies )- The production section will kick off in the Ugnu sand. )- A pump out sub will be run in the BHA to aid in placing LCM. )- The production section will cut the HRl interval and drill to the base of Kuparuk. For this well, maintain mud weight at 9.9 ppg, from the THRZ to the TD. Follow all shale drilling practices to minimize potential problems. )- There are no fault crossings expected in the production section. )- There are no close approach issues in the production section. )- KICK TOLERANCE: In the worst-case scenario of 9.0 ppg pore pressure in the Ku~~fracture gradient of 11.0 ppg at the 9-5/8" window, and 9.9 ppg mud in the hole, the kick tolerance ~bIS. Reference RP .:. "Shale Drilling, Kingak and HRl" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 9: Install 7" Production Liner Hazards and Contingencies )- Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses or exacerbate HRl instability problems. )- Sufficient 7" liner will need to be run to extend -150' back up into the 9-5/8" casing. )- Condition mud after casing in on bottom prior t pumping cement. A quality cement job is required for zonal isolation. )- Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Production Casing Cementing Guidelines" RP .:. Schlumberger Cement Program P1-07 A Drilling Permit Page 6 · . Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease Riq Hazards and Contingencies ~ Three wells will require shut-in for the rig move off P1-07 A. The closest neighboring wells are spaced as follows: P1-06 at -14', P1-08A at -17', and P1-05 at -29'. Care should be taken while moving off the well. Spotters will be used at all times. ~ Due to wellhouse removal, P1-06, P1-08A, and P1 -os will have to be shut-in at surface during RDMO. Point Mac wells are sensitive to being shut-in for >12 hours. Make all attempts to minimize the down time for each well. Reference RP .:. "Freeze Protecting an Inner Annulus" RP P1-07 A Drilling Permit Page 7 . . P1-07A Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Production Hole Section: · There are no fault crossings expected in the production section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. · There are no close approach issues while drilling the production hole section. · Kick tolerance is 104 bbls with a 11.0 ppg FIT. HYDROGEN SULFIDE - H2S I · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE P1 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION P1-07 A Drilling Permit Page 8 . . lREE = WELLHEAD = ACWA TOR = KB. a.BI = BF. a.EV = KOP= Wax Angle = Datum I\Ð = Datum ïV D = ? CALlCO-CIW/MCEVOY AXa.SON 42' P1-07 SAÆTY NOTES: FORMERLY PM-8. WBING HANGER: CIW GEN N @ 32' MD. 2900' 44 @ 6800' 10272' 8800' S8 . - 2257' H 3-1/2"AVA SIDffiUð.RDTRSSSV,ID=2.812" 13-318" CSG, 68#, l-80, ID = 12.415" H 4272' J À ST MD TVD 1 3809 3735 2 5925 5383 L - 3 7611 6625 4 8571 7335 5 9004 7680 6 9415 8042 7 9525 8144 GAS LIFT MANDRa.S DBI TYPE Vl V LA TCH 34 CA-MrvG RK 39 GA-MrvG RK 43 GA-MrvG RK 40 CA-MrvG RK 34 CA-MM3 BROKEN 23 GA-MrvG RKP 21 CA-MrvG RKP FORT DATE I Minimum ID = 2.75" @ 9684' 3-1/2" OTIS XN NIPPLE :g I TOP OF 7"lNR H 9125' t--,- ~ 9093' H 9-5/8" X 3-112" BAKERSB-3A PKR I 9278' H 3-1/2" 011SXNP,ID=2.813", 9-518" CSG, 47#,l-80, ID= 8.681" H 9471' ~ ~ ~ 9464' H BLAST JOINTS I ~ ~--f 9638' H 7' X3-1/2"BAKERFB-1 A<R , I PBm H 10878' 7" lNR, 29#, l-80, 0.0371 bpf, D = 6.184" H 11098' 9684' H 3-1/2" 011S XN NIP, ID = 2.750" , 9695' H 3-1/2" TLBING TAIUSI-EAROur SUB I ~ 9694' H ElMD TT lOGGB:J 04/08/90 , 10354' H TOPOFCE3\i1ENT , 10360' H FISH - 1.5' RK LA TO; 3-1/2"TBG-If'Ç,9.3#,l-80,0.OO87bpf,ID=2.992" H 9695' J----,. PERFORATION SUMMð. RY REF lOG: Dll/GR ON 03/08/90 ANGLE A TTOP ÆRF: 23 @ 9440' I\bte: Refer to A"oduction DB for historical perf data SIZ E SPF IN1ERII A l OpnlSqz DATE 4" 4 9440-9450 0 03/24/90 2-518" 4 10144-10168 0 04/18/90 2-518" 4 10403-10420 S 04/07/90 2-518" 4 10640-10660 S 03/29/90 2-518" 4 10705-10714 S 03/29/90 2-518" 4 10760-10792 S 03/29/90 I 10526' ~ FISH - 1.5 INCH CA-RKB:J BODY -EST. lOC lOST 11/5/93 10878' H EZSV GMT RETAINER I DATE 03/15/90 01/16/01 02/21/01 07/20/01 REV BY SI&lsl SI&lG RNlTP COMI'vENTS ORIGINAL COM'lEfION CONVERTED TO CANVAS REV IS ION CORRECTIONS DATE REV BY COMvlENTS POINT MONTY RE UNIT WELL: P1-07 ÆRMTNo: 89-134 APII\b: 50-029-21996-00 Sec. 16, T12N, R14E, 4517.01 Fa. 1354.29 FNl 8P Exploration (Alaska) ~ TREE = ? YVELLHEAD = CALlCO-CIW/MCEVOY 'ACTUATOR.;mmmmmmm.mm"mÄXELSOmN m~,__-u~·_·_w'_·m.'""m"'m~~,·~·,w~·.·.·<~·_·.·._·~·_w.~"m.N~~__, w~·w·~.'m,,'~~u KB. ELEV = 42' ~07 Pre-Rig Work '·····m"'.~~um -,-,····.·.·.?NNN~m'm'.·.·_____·.·_·_·.·.·.·NmN.~ KOP = 2900' ^~~~~n~T~:~~=m m~m_m_mm~==~~ @ 6.~gm~.~ Datum MD = 10272' .mNW·.____,__·u~_u -u"N~~N'._'~__.M....mNN'.~'~m__._~u"._ Datum lVD = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" H 4272' Tubing Cut at -7600' MD __ Top of Cement P&A Plug @ -8800' I TOP OF 7" LNR H 9125' Minimum ID = 2.75" @ 9684' 3-1/2" OTIS XN NIPPLE 9-518" CSG, 47#, L-80, ID = 8_681" H 9471' ~ 3-1/2" TBG-IPC, 9_3#, L-80, 0.0087 bpf, ID = 2_992" H 9695' PERFORA TION SUMMARY REF LOG: DLUGR ON 03/08/90 ANGLE AT TOP PERF: 23 @ 9440' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 9440-9450 0 03/24/90 2-5/8" 4 10144-10168 0 04/18/90 2-5/8" 4 10403-10420 S 04/07/90 2-5/8" 4 10640-10660 S 03/29/90 2-5/8" 4 10705-10714 S 03/29/90 2-5/8" 4 10760-10792 S 03/29/90 I PBTD H 10878' 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" H 11098' DATE 03/15/90 01/16/01 02/21/01 07/20/01 12/17/03 REV BY SIS-lsl SIS-LG RNlTP WSI COMMENTS ORIGINAL COMPLETION CONVERTED TO CANVAS REVISION CORRECTIONS Aanned Pre-Rig Work DA TE REV BY . ~ L " ..- -~~ " ... COMMENTS SAFETY NOTES: FORMERLY PM-8_ TUBING HANGER: CIW GEN IV @ 32' MD. 2257' H 3-1/2" AVA SIDEGUARD TR SSSV, ID = 2.812" ~ ST MD lVD 1 3809 3735 2 5925 5383 3 7611 6625 4 8571 7335 5 9004 7680 6 9415 8042 7 9525 8144 GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE 34 CA-MMG RK 39 CA-MMG RK 43 CA-MMG RK 40 CA-MMG RK 34 CA-MMG BROKEN 23 CA-MMG RKP 21 CA-MMG RKP 9093' H 9-5/8" X 3-1/2" BAKER SB-3A A<R 9278' H 3-1/2" OTIS X NIP, 10 = 2_813" I 9464' H BLAST JOINTS I 9638' H 7" X 3-1/2" BAKER FB-1 A<R I 9684' H 3-1/2" OTIS XN NIP, ID = 2.750" I 9695' H 3-1/2" TUBING TAIUSHEAR OUT SUB I 9694' H ELMD TT LOGGED 04/08/90 I 10354' H TOP OF CEMENT I 10360' H FISH - 1.5" RK LATCH I 10526' 11 FISH - 1.5 INCH CA-RKED BODY -EST. LOC LOST 11/5/93 10878' H EZSV CMT RETAINER I POINT MCINTYRE UNIT WELL: P1-07 PERMIT No: 89-134 AA No: 50-029-21996-00 Sec. 16, T12N, R14E, 4517.01 FEL 1354.29 FNL BP Exploration (Alaska) 4272' ~ 7,200' Top of Window at 7,350' BP set at 7,370'/ 9471' j 11,098' Q --L --L --L --L z ---<:::: I.' Date 1-13-04 P1-01k Proposed Com'etion /' 14-1/2" HES WellStar SSSV at 2250' MD I TREE = WELLHEAD = ~_",...."""".'..._·.'.~~M~."...~ ACTUA TOR = KB. ELEV = BF. ELEV = ~,.,,,,.,.~.m.~.c.. KOP= Max Angle = Datum MD = "... ....M......~.~~~M~u.m.~~~^ Datum lVD = 2900' 44 @ 6800' "'''''' , ,-------.---.---....,... 10272' 8800' SS 4-1/16" CALlCO-CIW/MCEVOY . . .. -. uUAXEl..SON 42' ~ 13-3/8",68#, L-80 14-1/2", 12.6#, 13Cr-80, VAM-ACE Tubing GLM Design: #6 - 3500' TVD - 4-1/2" X 1-1/2" #5 - 5000' TVD - 4-1/2" X 1-1/2" #4 - 5700' TVD - 4-1/2" X 1-1/2" #3 - 6400' TVD - 4-1/2" X 1-1/2" #2 - 7100' TVD - 4-1/2" X 1" #1 - 7800' TVD - 4-1/2" X 1" ~ 9-5/8" X 7" HMC Liner Hanger with ZXP Liner Top Packer and C2 Running Tool I TOC @ 9,039' I Tubing Tail: -10' Pup Joint -X Nipple (3.813") -2 x 10' Pup Joint -Packer -2 x 10' Pup Joint -X Nipple (3.813") -2 x 10' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 17" X 4-1/2" S-3 Permanent Packer @ 9,825' 11 ~ 9-5/8",47#, L-80 / 7',26# @ 10,652' L-80 BTC-M from liner top to -100' above packer and 13-Cr80 VAM-ACE to TD. Rev By Comments WSI Proposed Completion Design - wp04 POINT MCINTYRE UNIT WELL: P1-07 A API NO: 50-029-21996-01 Permit NO: GPB Rotary Drilling . . '" o PRUDHOE /.. _\ BAY .f. MJ.:-@{\. THIS SURVEY ~ LEGEND o ~ . EXISTING WELLS AS-BUILT THIS SURVEY " -~-/ I "-.. rP-D \~í'<~t. ?\. \-AC U. . .. T12N, R14E VICINI TY MAP"""·'· N.T.S. NOTES +7 ,. COORDINATES SHOWN ARE REVISED PER PT. MC INTYRE HORIZONTAL CONTROl. SURVEY - NOV. 7-18, 1990. ORIGINAL AS-BUILT FOR PT. UC INTYRE STAl[ NO.3 Ie 4 PER BESSE. EPPSIe POTTS 3/88 AND 1/89 AND WEll 17 Ie 8 PER F.R. BELl. Ie ASSOC. 1/22/90. 2. BASIS OF LOCATION PER MONUMENTS CCP-C AND CCP-D AND DS-LI NORTH AND SOUTH. J. COOROINA TES SHOWN ARE ALASKA STATE PLANE ZONE 4. 4. ELEVATIONS SHOWN ARE ARCO DATUM (M.LLW.). 5. REFERENCE FJELD BOOKS: PB 90-66 (P. 1-5) DA TE OF SU~VEY: 12/14/90 PB 91-02 (P. 43) DATE OF SU~VEY: 1/22/91 .. · 81 . 3~ 16 15 21 22 .u.s. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PRO- PERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY Me: OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMEN- SIONS AND OTHER DETAILS ARE CORRECT AS OF JAN. 24, 1991. i..~ '",¿L- ,Vv 5. :..~y)~ PIS<:- ' :. - ,-'. r_~,.,0c-(....1 N7' ';~/ ).~ ~"'"'''' _-~ OF ~( \\ - ~~........ ~ " ,¡ ;'4",...... ..,:+" . III 't.. _. ..y', 1*_:.91" ~. \., iIt.... .... . ~ ~ ~ .. ....... .... ......... ~ ~ ~.. ,. RaIIIrt III : ~ iI! 'J ~.. ...ma.a ~~jI ..., . .. III , .. ..~ "'" -. .. ~ - .,,~~~-- \"""....... '. . " LoeA TED WI THIN PROTRACTED SECTION , 6. T12N. RI4€:, UMIAT MERIDIAN, ALASKA. C A.S.P. PLANT GEOOETIC COOROS. ~. POSITION 5.994.557.12( N.a~5\. 08· . 70'23·26.896· 6 74.415.69( f. .3~I? ~7·:!'48·34·51. 751" 5.994,599.'6(.\.N,~,CC'. )70"23'27.316" 674.~.38 IE ~.oc /148'34'52.522· 5.994.661.821 AI. 3QX).c,o·: )70"23'27.89.r 674.557.14\ €. ~ð3('48·34'47.538· . , .. ." , 5.994,578.63\ N,-3ÕCC."4ú>'j70"23·27.,27· 674.331.75\....:..:3444. 7(¡i ~ 148'34'54.193· '- ~ . ~: '--- /,þç;.::;,._ ,;:;v IB 31191~ ..~ . "./;,.') <.-; CElLAR LOCA TION BOX IN SECTION ELEV. 6.5' 1424' FSL 641' FEL 8.5' 14ST FSL 66T I'EL 7.5' 1526' FSL 49T I'EL 7.0' 144ð' FSL 724' FEl WELL NO. P\~J F\"~~.4 PI -0 I !.7 f\-o1.8 F, ROBERT BELL & ASSOC. ARCO AI.8k. Ine;, 0; PT. Me INTYRE WELL AS-BUILT WELLS #3: 4,· 7· & 8 1.2.'311 bw"....ofG NAIl£: "bAil.: ...... .. QIU,O<: JAN. 24, 1991 FENTlE ALLISON ~ ~~. I>I~ N.T.S. - JMf' RF A...... ,_ .-1"1II-.- _. DRAWN CHECK NSDP 0000 CEA-4600-11201 _.......IIL: R. BELL CAIN FlU: . PA4007AA '-.. I,,·· 2010r 1 0 o 1/24/91 REV NO. DATE REVISED COORDINATE VALUES REVISIONS .. " . - 20'22'11" ~ -,..- I t' ( I ¡: 8 ao,....fØlÐ......, I I I I I I lLó:lLG:ä:G: .8...8 ~,~ 77 ~~7Y ¡: Ii: ¡: ¡: ¡: ¡: lL ã: ¡: 888 .. ..88 . POINT McJNT'rRE ~ -lOl- I [, I THIS SURIlEY I 1RILLSI~ -:: - I i 21 I - r I t------~----- VICINITY MAP N.T.S. 8 PI-I \ 8 '" , ¡: PT. MciNTYRE ~ PM-1 \... '- LEGEND .. WELLS AS-BUILT THIS SURVEY 8 EXlSllNG WELLS LOCATED WITHIN PROTRACTED SEC1l0N 16, T12N, RHE, UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEOOEllC CELLAR LOCATION NO. COORDS. COORDS. POSITION BOX EL. IN SECllON 5,994,594.31 N 3000.23 70'23'27;271- 1463' FSl P1-04 674,374.65 E 3490.44 148'34'52.927- 9.4 681' FEL P1-05 5,994,588.75 N 3000.02 70'23'27.220- 9.3 1457' FSl 674,360.29 E 3475.04 148'34'53.352- 695' FEL P1 06 5,994,583.63 N 3000.16 70'23'27.173" 9.0 1453' FSl - 674,346.08 E 3459.94 148'34'53.771" 710' FEL P1 08 5,994,573.44- N 3000.43 70'23'27.079- 9.5 144-3' FSl - 674,317.88 E 3429.95 148'34'54.604- 738' FEL P1-13 5,994,547.28 N 3000.4370'23'26.838- 9.1 141g' F~ 674,247.42 E 3354.79 148'34'56.684- 809' F'EL P1-14: 5,994,542.11 N 3000.-43 70'23'26.790- 8.9 1414' FSL 67-4,233.50 E 3339.93 148'34'57.095" 823' FEL P1-16 5:994,531.72 N 3000.51 70'23'26.695- 9.1 1404' FSl 674,205.29 N 3309.87 148'34'57.928- 852' FEL P1-17 5,994,526.H N 2999.94 70'23'26.6-43- 9.5 1399' FSL 674,191.98 E 3295.46 148·34'~.322- 865' FEL o 1/24/93 ORIGINAL AS-BUILT ISSUE KH JJ RFV NO. OA TF RFVlC:;fONC:; ORAWN ~HF~( SURVEYOR'S CERTIFICATE I HEREBY CERTIfY THAT I AM PRO- PERLY REGISTERED AND UCENSED TO PRACTICE LAND SUR\IE'I'ING IN THE STATE OF AlASKA AND THAT THIS PlAT REPRESENTS A SUR\IEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT AlL DIMEN- SIONS AND OTHER DETAILS ARE CORRECT AS OF OCTOBER 12, 1992. 8 PI-GI .-J t1QIES: 1. COORDINATES ARE BASED ON PT, MdNrrRE MONUMENTS PM-1 EAST AND PM-1 WEST AS ESTABLISHED BY f.R.BELL Ie ASSOC. 3/1/92. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE ZONE 4, NAD-27. 3. REFERENèÉ FIELD BOOK: PB93-02 (pp.42-53) 4. DATE ÖF" SURVEY: 1/16/93 Ie 1/24/93 5. MEAN sCÅlE: fAÇTqB_~_Ò.99993446. F, ROI}ËRT BELL & .ASSOC ARCð Aleake Inë. <~ DRAWING NAME: PT, MelNTYRE PM-1 CONDUCTOR AS-BUILT WELLS: P1-4,5,6,8,13,14,16,17 DA r~: DR.6IN: 1/24/93 HAVE 'sçALE: 'to.....,: . QiLCK: AM'I<WAL: JACOBS ," ~,: CAW FlU. f: JOBI: N.T.S. ISUB JOBI:'!)RAWING /I: SK-PM1417AB PM1417AB ~I: \!<t.V' 1or10 CDMPANY [)£TAilS Bf'Affi()Ç{ REFERENCE INFORMATION Start Dk t21tO{)' : 7350' MD. 643 L65'TVD Start Oir 51l00': 7370' MD, 6446.17'TVD " ââ 8 :!:2. ,d Õ, ¿; ~ " ! ~ 7000- . End illr : 8590.47' MD. 7495.68' TVD Vertical Se<:tion at 35.27° [500ft/in] ! ! ! 1500 SURVEY PROGRAM Depth Fm Depth To S~fPIan 7350,00 10652.09 Plmmed; PI-01A wp05 VS T=I MWD Plan: P·01A wp0:5 (PI-07IPlan P¡~07A) Cremed By: Ken Allen Cheeked: Reviewed: wElL DETAILS Nånw ""N!..s +E!·W Northing r~ Latitude Longitude Slot P¡·4J7 3963AO 2217ß1 599458L50 674332.00 70"2."'\.'27.JS5N 148"34'54.!85W 07 TARGET DETAilS """" TVD +NI-S +El;W S@7.50 236821 ~1@5$9 9206.50 157L49 ·1420.52 Nmfuing SECTION DETAILS Eastmg Shape- --1 Date: 1/2312004 f}Ate Date: See MD Inc Azì TVD +N/-S +Ei-W DLq¡ TFac. VSe<: Target I 7350.00 302.46 6431.65 1383.49 -2260.74 0.00 0.00 0.00 2 7370.00 305.92 6446.17 1391.22 -2272.11 y'!2.oo 85.00 -0.26 3 8590.47 53.56 7495.68 1888.23 -2346.02 5.00 14256 362.85 4 10652JJ9 53.56 9206.50 2571.49 -1420.52 0.00 0.00 1455.10 Pl·07A TDr3 CASING DETAILS o ¡r! I' ¡; ..r! I' 6r! I' I' ,I ,I , ¡r! No. TVD MD Name 9206.49 10652.08 7" Size 7.000 FORMATION TOP DETAILS No. TVDPath MDPatb Formation 1 4522.50 482756 2 4940.50 5360.47 3 6610.50 7583.17 4 675550 7755.72 5 833MO 9603.70 6 8555.50 9867.60 7 8645.50 9976.06 8 8697.50 10038.72 9 8708.50 10051.98 10 875650 10109.82 !1 8791.50 10152.00 12 8846.50 10218.27 13 8872.50 10249.60 14 8963.50 10359.26 15 9020.50 10427.95 16 9131.50 10561.71 17 9176.50 10615.94 --------l COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM D...¡rth Fm Depih To SurveylPIan 135JJ.ûO 10652.00 P1annecl: PJ-01A wpH5 V$ Plan: PJ·07A wp05 (PI-ù7/PJa-n PI..Q7A) BP Amoco T=I Created By: Ken Allen Checked: Date: 1123/2004 MWD Date:_ Reviewed: Daœ:_ WELL DETAILS CASING DETAILS FORMATION TOP DETAiLS L_ Slot Nmm cNf-S Nonhìng Ea&tlng L<.mgítude No. TVD MD Name Size No. TVDPath MDPath Formation .,-07 3%3-40 2117.01 599458150 614332.00 7fY'23'2.1J5SN !4M4'54J35W 07 9206.49 10652.08 7" 7.000 1 452250 4827.56 T-3 TARGETDE1AILS 2 4940.50 536M 7 K-151Ugnu "'me TVD +N!oS #Y-W Nmihin. F"""" Shape 3 661050 7583.17 TWSK 4 675550 7755.72 K-12 (Colvil1e) P¡...{I7A 1'KUP 8:69150 236821 -1695.89 _37 672581,41 5 833650 9603.70 K-1O Pj..07A rod 920650 251L49 -142052 5997H9.00 67285UIO 6 855550 9867.60 THRZ 7 8645.50 9976.06 TKL8 SECTION DETAILS 8 8697.50 10038.72 TKUP 9 870850 10051.98 UC2-3 See MD Inc Azì TVD +NI-S +FJ-W DLeg TFace VSee Target 10 8756.50 10109.82 UCI 11 8791.50 10152.00 UB4 1 7350.00 43.33 302.46 6431.65 1383.49 -2260.74 0.00 0.00 0.00 12 8846.50 10218.27 003 2 7370.00 4359 305.92 6446.17 139J.22 -2272.11 12.00 85.00 -(U6 13 8872.50 10249.60 001-2 3 8590.47 33.92 53.56 7495.68 1888.23 ·2346.02 5.00 142.56 362.85 14 8963.50 10359.26 UA14 4 10652.09 33.92 53.56 9206.50 2571.49 ·1420.52 0.00 0.00 1455.10 PI·07A TD r3 15 9020.50 10427.95 LC3 16 9131.50 10561.71 1.824 17 9176.50 10615.94 UU We.t(·)iEast(+) f300ftlìn! {I ¡di' -I 21 ()(T- ¡; " ~ g I' c. ;£ i! I " ~ :JÌr I ;; " '" -I ,I ,¡jP ,I "di' 1200 -2700 · . Sperry-SuD - Draft Copy KW A Planning -.....-. .. 'Y-&Lr1 D...........INII !II."VI~. ,,~ UJMr.fol'('t' ObP 11/19/2003 5 From: Definitive Path Plan: P1-07A wp05 Date Composed: Version: Tied-to: Principal: Yes Field: Point Mac North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: Pt Mac 1 TR-12-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Alaska, Zone 4 Well Centre bggm2003 Map Zone: Coordinate System: Geomagnetic Model: 48.179 N 0.861 W True 1.32 deg Latitude: 70 22 Longitude: 148 36 North Reference: Grid Convergence: 5990567.02 ft 672146.94 ft 07 Well: P1-07 Slot Name: P1-07 Well Position: +N/-S 3963.40 ft Northing: 5994581.50 ft Latitude: +E/-W 2277.01 ft Easting: 674332.00 ft Longitude: Position Uncertainty: 0.00 ft 70 23 27.155 N 148 34 54.185 W P1-07 7350.00 ft Mean Sea Level 25.57 deg 80.92 deg Direction deg 35.27 Wellpath: Plan P1-07A Drilled From: Tie-on Depth: 37.50 ft Above System Datum: Declination: Mag Dip Angle: +EI-W ft -2260.74 37.50' 11/17/2003 57587 nT Depth From (TVD) ft 28.50 Current Datum: Magnetic Data: Field Strength: Vertical Section: Height +N/-S ft 1383.49 Casing Points TVD ft 10652.08 9206.49 Diameter in 7.000 7" 8.500 Formations MD ft 4827.56 5360.47 7583.17 7755.72 9603.70 9867.60 9976.06 10038.72 10051.98 10109.82 10152.00 10218.27 10249.60 10359.26 10427.95 10561.71 10615.94 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4522.50 4940.50 6610.50 6755.50 8336.50 8555.50 8645.50 8697.50 8708.50 8756.50 8791.50 8846.50 8872.50 8963.50 9020.50 9131.50 9176.50 T-3 K-15/Ugnu TWSK K-12 (Colville) K-10 THRZ TKLB TKUP UC2-3 UC1 UB4 UB3 UB1-2 UA1-4 LC3 LB2-4 LB1 .. u.u.uM1IOU'I ~ . . Sperry-SuD - Draft Copy KW A Planning ObP .......... 'I ·Y-&L...n a.ULL.NCI ....v.c.. Targets P1-07A TKUP 8697.50 2368.21 -1695.89 5996909.37 672581.47 70 23 50.444 N 148 3543.860 W -Circle (Radius: 75) -Plan hit target P1-07A TD r3 9206.50 2571.49 -1420.52 5997119.00 672852.00 70 23 52.444 N 148 35 35.796 W -Circle (Radius: 75) -Plan hit target Plan Sedion Information MD ft 7350.00 43.33 302.46 6431.65 1383.49 -2260.74 0.00 0.00 0.00 ' 0.00 7370.00 43.59 305.92 6446.17 1391.22 -2272.11 12.00 1.31 17.34 85.00 8590.47 33.92 53.56 7495.68 1888.23 -2346.02 5.00 -0.79 8.82 142.56 10652.09 33.92 53.56 9206.50 2571.49 -1420.52 0.00 0.00 0.00 0.00 P1-o7A TD r3 Survey MD AzIm 'I'VD ft deg ft 4827.56 38.56 298.47 4522.50 4485.00 5995079.24 673456.91 100.33 0.00 0.00 0.00 T-3 5360.47 38.52 299.47 4940.50 4903.00 5995231.64 673163.62 63.05 332.04 0.12 94.10 K-15/Ugnu 7350.00 43.33 302.46 6431.65 6394.15 5995911.81 672039.77 0.00 1634.95 0.26 23.27 MWD 7370.00 43.59 305.92 6446.17 6408.67 5995919.27 672028.22 -0.26 1648.70 12.00 85.00 MWD 7400.00 42.41 307.28 6468.11 6430.61 5995931.08 672011.51 0.21 1669.16 5.00 142.56 MWD 7500.00 38.59 312.26 6544.16 6506.66 5995971.33 671960.61 5.19 1734.10 5.00 141.58 MWD 7583.17 35.61 317.06 6610.50 6573.00 5996005.67 671924.10 13.30 1784.26 5.00 137.79 TWSK 7600.00 35.03 318.11 6624.23 6586.73 5996012.69 671917.37 15.37 1793.99 5.00 133.95 MWD 7700.00 31.79 325.05 6707.73 6670.23 5996054.87 671882.11 30.68 1849.04 5.00 133.09 MWD 7755.72 30.18 329.46 6755.50 6718.00 5996078.60 671866.02 41.39 1877.73 5.00 127.30 K-12 (Colville: 7800.00 29.01 333.27 6794.01 6756.51 5996097.52 671855.10 50.99 1899.60 5.00 123.51 MWD 7900.00 26.81 342.88 6882.41 6844.91 5996140.34 671836.54 76.16 1946.41 5.00 120.20 MWD 8000.00 25.36 353.78 6972.27 6934.77 5996182.99 671826.58 105.99 1990.38 5.00 111.70 MWD 8100.00 24.79 5.52 7062.91 7025.41 5996225.15 671825.29 140.25 2032.76 5.00 101.91 MWD 8200.00 25.15 17.35 7153.62 7116.12 5996266.50 671832.68 178.69 2074.97 5.00 91.27 MWD 8300.00 26.40 28.50 7243.72 7206.22 5996306.73 671848.71 221.01 2118.45 5.00 80.54 MWD 8400.00 28.44 38.43 7332.53 7295.03 5996345.52 671873.23 266.89 2164.50 5.00 70.49 MWD 8500.00 31.10 46.98 7419.37 7381.87 5996382.59 671906.07 315.98 2214.14 5.00 61.67 MWD 8590.47 33.92 53.56 7495.68 7458.18 5996414.40 671942.74 362.85 2262.75 5.00 54.25 MWD 8600.00 33.92 53.56 7503.59 7466.09 5996417.65 671946.95 367.90 2268.07 0.00 0.00 MWD 8700.00 33.92 53.56 7586.57 7549.07 5996451.83 671991.05 420.88 2323.87 0.00 0.00 MWD 8800.00 33.92 53.56 7669.56 7632.06 5996486.01 672035.15 473.86 2379.67 0.00 0.00 MWD 8900.00 33.92 53.56 7752.54 7715.04 5996520.18 672079.26 526.84 2435.47 0.00 0.00 MWD 9000.00 33.92 53.56 7835.53 7798.03 5996554.36 672123.36 579.82 2491.27 0.00 0.00 MWD 9100.00 33.92 53.56 7918.51 7881.01 5996588.54 672167.47 632.80 2547.07 0.00 0.00 MWD 9200.00 33.92 53.56 8001.50 7964.00 5996622.72 672211.57 685.78 2602.87 0.00 0.00 MWD 9300.00 33.92 53.56 8084.48 8046.98 5996656.89 672255.67 738.76 2658.67 0.00 0.00 MWD 9400.00 33.92 53.56 8167.46 8129.96 5996691.07 672299.78 791.74 2714.47 0.00 0.00 MWD 9500.00 33.92 53.56 8250.45 8212.95 5996725.25 672343.88 844.72 2770.27 0.00 0.00 MWD 9600.00 33.92 53.56 8333.43 8295.93 5996759.43 672387.99 897.70 2826.07 0.00 0.00 MWD 9603.70 33.92 53.56 8336.50 8299.00 5996760.69 672389.62 899.66 2828.13 0.00 0.00 K-10 9700.00 33.92 53.56 8416.42 8378.92 5996793.60 672432.09 950.68 2881.87 0.00 0.00 MWD 9800.00 33.92 53.56 8499.40 8461.90 5996827.78 672476.19 1003.66 2937.67 0.00 0.00 MWD 9867.60 33.92 53.56 8555.50 8518.00 5996850.88 672506.01 1039.47 2975.39 0.00 0.00 THRZ 9900.00 33.92 53.56 8582.38 8544.88 5996861.96 672520.30 1056.64 2993.47 0.00 0.00 MWD . . _......... .. ·Y-SL..r1 Sperry-Sun - Draft Copy ObP a"ILLINQ .."VIC.. A. UUUBl'.II1U1'1 ~Am' KW A Planning Company: BP Amoco Field: Point Mac Site: Pt Mac 1 WeD: P1·07 Wellpatb: PlanP1-07A Survey MD Incl Adm TVD S15 TVD ft d$g deg ft ft 9976.06 33.92 53.56 8645.50 8608.00 5996887.95 672553.84 1096.93 3035.91 0.00 0.00 TKLB 10000.00 33.92 53.56 8665.37 8627.87 5996896.13 672564.40 1109.62 3049.27 0.00 0.00 MWD 10038.72 33.92 53.56 8697.50 8660.00 5996909.37 672581.48 1130.13 3070.87 0.00 0.00 P1-07A TKLF 10051.98 33.92 53.56 8708.50 8671.00 5996913.90 672587.32 1137.15 3078.27 0.00 0.00 UC2-3 10100.00 33.92 53.56 8748.35 8710.85 5996930.31 672608.50 1162.60 3105.07 0.00 0.00 MWD 10109.82 33.92 53.56 8756.50 8719.00 5996933.67 672612.84 1167.80 3110.55 0.00 0.00 UC1 10152.00 33.92 53.56 8791.50 8754.00 5996948.08 672631.44 1190.14 3134.08 0.00 0.00 UB4 10200.00 33.92 53.56 8831.34 8793.84 5996964.49 672652.61 1215.58 3160.87 0.00 0.00 MWD 10218.27 33.92 53.56 8846.50 8809.00 5996970.73 672660.67 1225.26 3171.06 0.00 0.00 UB3 10249.60 33.92 53.56 8872.50 8835.00 5996981.44 672674.49 1241.86 3188.55 0.00 0.00 UB1-2 10300.00 33.92 53.56 8914.32 8876.82 5996998.67 672696.71 1268.56 3216.67 0.00 0.00 MWD 10359.26 33.92 53.56 8963.50 8926.00 5997018.92 672722.85 1299.96 3249.74 0.00 0.00 UA1-4 10400.00 33.92 53.56 8997.30 8959.80 5997032.84 672740.82 1321.54 3272.47 0.00 0.00 MWD 10427.95 33.92 53.56 9020.50 8983.00 5997042.40 672753.14 1336.35 3288.07 0.00 0.00 LC3 10500.00 33.92 53.56 9080.29 9042.79 5997067.02 672784.92 1374.52 3328.27 0.00 0.00 MWD 10561.71 33.92 53.56 9131.50 9094.00 5997088.11 672812.14 1407.21 3362.70 0.00 0.00 LB2-4 10600.00 33.92 53.56 9163.27 9125.77 5997101.20 672829.02 1427.50 3384.07 0.00 0.00 MWD 10615.94 33.92 53.56 9176.50 9139.00 5997106.65 672836.05 1435.94 3392.96 0.00 0.00 LB1 10652.08 33.92 53.56 9206.49 9168.99 5997119.00 672851.99 1455.09 3413.13 0.00 0.00 7" 10652.09 33.92 53.56 9206.50 9169.00 5997119.00 672852.00 1455.10 3413.14 0.00 0.00 P1-07A TD r3 p055220 . DATE 1/6/2004 INVOICE / CREDIT MEMO DESCRIPTION PR010504D PERMIT TO DRILL 'HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE;, PAY: TO THE ORDER OF: GROSS ~\~07fr NATIONAL CITY BANK Ashland, Ohio OF ALASKA 333 WEST 7TH AVENUE ANCHORAGE, AK 99501-3539 .:1 DATE I 1/6/2004 CHECK NO. 055220 VENDOR DISCOUNT NET 56-389 ~ No. P 055220 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT ¡JanUqry 6,30041 **j7t*$100.00******1 NOTr:~:~~:;q~~~:~~~:?::0~·:;~&;},~rf·f§;\::.:~·~~ . . ..····l.r.~::.. ......_...:-t_. c.. ..... ~';~f~~w~tZi{¡;;,~~';~§:~j II- 0 5 5 2 2 0 II- I: 0... ¡. 2 0 ~ B 11 5 I: 0 ¡. 2 'i' B 11 b II- . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME¿"¡ ß-t:4,,-- f 074 PTD# 20 <7'-o-s 7 >< Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic 4'CLUE" Tbe permit is for a new wellboresegment of existing well . Permit No, . API No. Production. sbould continue to be reported as a function· of tbe original API number. stated above. BOLE In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be dearly differentiated in botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of Ii conservation order approving a spacing e:Jception. (Companv Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. AU dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals through target zones. Field & Pool PT MCINTYRE, PT MCINTYRE OIL - 666100 Well Name: POINT MCINTYRE P1-07A Program DEV Well bore seg PTD#: 2040370 Company..6P EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 1 Permit fee attached _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Lease number _appropriate_ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nlque well_n_ame_a!ld Ol!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJUQcated ina defil1e_d pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeJUQcated properdlsta!lce_ from driJIing ul1itb9Ul1da(}l _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WellJQcated pr_oper _distancefrom otlJe.r wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7Sutficiel1tacrea~e_aYailable in_drilliog unjt _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jfdeviated, js_ weJlbQre platil1cJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _Ope(ator OI1I}l affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _Ope(ator lJas_appropriateJ).ond lnJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ 11 Permit c_a!l Þe issl!ed witlJQut conserva_tiOI1 order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 Permit call Þe iSSl!ed witlJQut admil1istratille_appr.ovaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ _ - _ _ _ - - - - - - _ - - - - - - - - - RPC 2/24/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUQcated withil1 area and_strata _authorized by.l!ljectioo Order # (puUO# in_c_omme!lts) (for_ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 _AJI wells_wit!1iD.1l4.ruite_are.a.of review ide!lt!fied (Fou¡ervjeewe[l .only). _ _ _ _ _ _ _ _ _ _ _ _ . _ _NA _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ 16 Pre.-pr.odu.ced i!ljector; .duratiQnof pre-pro.ducti.ol1less than 3 mOl1tlJs_ (For_servlce welt onJy) _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 ACMPF:indjng9f Consiste!lcy_h_as Þeen.issued_ f.or.tlJis pr_oject_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 18 _C_o!lductor string_provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _Surjaeecasil1g_protects all_known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTv_otadeQl!ate.t.o çirc_utateoDC.ol1d_uct.or_& SUJtcsg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _CMT v.ot adeQu_ate.to tie-lnJQngstri!lg to_surf ~g_ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22CMT will coyera]l know_nproductiye IJOrÎzon_s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _C_asi!lg de.sig!ls adeQua_te for C,.T, B _& perruafr_ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 _A.dequateJan_kage_oJ re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ \jabors2_ES, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 JtaJe-orilL has_a_ 10-403 fQr abandonme_nt bee!l apPJoved _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ 2/7/2004, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 Aoequatewellbore.separatjoD_proP.oseo_ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ Yes _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ 27 Jtdiverter req.uire.d, does it meet reguJati.ol1s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ $idetra~. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 _DriUiogfluidprQgramschematic_&eq.uipJistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _MaxMW9,9ppg._ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ WGA 2/24/2004 29 BOPEs,_d_o.they meetreguJati.o11 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ 30 _BOPEpre.ss ra.ti!lg appropriate;.testto(pu.t psig iDC.ommel1ts) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Test t.o3500_ psl.MSf> 33.74 psi. _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 _ChOKeruanjfold cQmpJies w/API Rf>-53 (May 84) _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will OCC_U( withoutoperatjoDshutdown _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yes _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Js presence_ of H2$ gas_ probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 MeçlJanicalcood.itlo!l.otwe.lIswlthinJl.ORverlfied(F.ol"s_ervicewellonJy)_ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ __ Administration Engineering - - - - - - - ~ Geology 35 Permit call Þe issl!ed wfo hyd(ogen sulfide measures 36 _Datapre.seoted on pote_ntial .overpressure .z.ones_ 37 _Seismic_aDalysjs_ of slJaJlow gas_zo!les 38 Seabed _conditioo Sl!rvey _(if off-sh_ore) _ 39 _ Conta_ct namelpJ1oneJor_weekly progress reports [exploratoryonlYl - - - - - - - ~ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _N_A_ _ _. _ __ NA __ _____ __ __ NA _ _ _ _ ______ _ _ _ _ _ _ N_A _ _ .___ ~ - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - Appr RPC Date 2/24/2004 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Commissioner: Engineering Commissioner: Public Commissioner Date: Date Date ~-r7 21¿~t D D . . 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 infoffilation, 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 e :LtJ'f- 03 7 $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 19 09:39:00 2004 :;;f pJ ') " Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name..... ....... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/19 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....... . . . . . . . . . . . . . .04/11/19 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 Point McIntyre MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA P1-07A 500292199601 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 19-NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003016164 J. SACK R. BORDES MWDRUN 2 MW0003016164 J. SACK R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 12N 14E 1448 724 MSL 0) 37.50 9.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 7341.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK - THE TOP e e WAS AT 7341'MD/6425' TVD AND THE BOTTOM WAS AT 7357'MD/6437'TVD. MWD RUN 1 WAS TO POSITION THE WHIPSTOCK AND MILL THE WINDOW - SROP DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO- DENSITY (SLD); PRESSURE WHILE DRILLING (PWD); AND ACOUSTIC CALIPER (ACAL). UPHOLE TIE-IN SGRC DATA WERE ACQUIRED WHILE RIH FOR RUN 2. THESE DATA ARE MERGED WITH RUN 2 MWD DATA. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN P1-07A ON 20 APRIL 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 20 OCTOBER 2004. 6. MWD RUNS 1 & 2 REPRESENT WELL P1-07A WITH API#: 50-029-21996-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10671'MD/9206'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 (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 9.6 & 9.9 PPG MUD SALINITY: 950 - 36500 PPM CHLORIDES FORMATION WATER SALINITY: 20000 - 28000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/11/19 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 FET RPD RPM RPS RPX PEF ROP DRHO RHOB FCNT FCNT NPHI $ e 1 e and clipped curves; all bit runs merged. .5000 START DEPTH 6606.5 7309.0 7309.0 7309.0 7309.0 7309.0 7309.0 7330.5 7333.0 7333.0 7341.5 7341.5 7341.5 STOP DEPTH 10625.5 10617.5 10617.5 10617.5 10617.5 10617.5 10582.0 10668.0 10582.0 10582.0 10568.0 10568.0 10568.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 6606.5 6608.5 6612.5 6620.0 6627.5 6631.0 6635.5 6638.0 6641. 0 6647.5 6652.0 6663.5 6671.0 6674.0 6681.5 6686.5 6694.5 6699.5 6710.0 6714.5 6724.0 6726.5 6734.5 6740.5 6751.5 6755.5 6758.5 6765.5 6778.5 6787.0 6790.5 6793.5 6801. 0 6804.5 6811.0 6818.0 6821.0 6842.0 6847.0 6854.0 6859.0 6876.0 6886.5 6890.5 6892.5 6900.5 6906.5 GR 6618.5 6620.5 6624.0 6631. 5 6640.5 6644.0 6648.0 6651.0 6653.0 6656.5 6659.5 6675.0 6682.5 6684.0 6692.5 6697.5 6707.0 6711. 0 6721.5 6726.5 6735.5 6739.5 6746.0 6751.5 6760.5 6767.0 6768.5 6775.5 6789.5 6797.0 6801. 0 6806.0 6812.0 6814.0 6819.5 6829.5 6833.5 6852.5 6858.5 6863.5 6868.0 6886.0 6894.5 6899.0 6900.0 6909.5 6914.5 e e 7317.0 7328.0 7328.0 7338.5 7329.5 7340.0 7334.5 7344.5 7340.5 7349.5 7347.0 7356.0 7352.5 7361.0 7363.5 7372.5 7375.5 7385.0 7388.0 7398.5 7399.0 7408.5 7403.0 7412.0 7411.0 7420.5 7417.0 7426.0 7424.5 7434.5 7434.0 7443.5 7440.5 7449.0 7453.0 7463.0 7461. 5 7471.5 7468.5 7478.5 7473.0 7484.0 7474.5 7485.0 7485.5 7496.0 7503.0 7513.5 7509.0 7520.5 7517.5 7528.0 7522.5 7531. 5 7529.5 7538.5 7535.0 7544.0 7539.0 7548.0 7549.0 7557.5 7560.5 7569.0 7572.0 7580.5 7590.5 7600.0 7605.0 7614 . 0 7617.5 7626.0 7630.5 7640.5 7638.0 7647.5 7649.0 7657.5 7657.0 7665.5 7659.5 7667.5 7667.5 7675.5 7672.5 7681.5 7677.5 7686.5 7685.0 7691. 5 7705.5 7711.5 771 7.5 7723.0 7723.0 7729.5 7733.0 7740.5 7743.0 7752.0 7746.5 7755.5 7752.5 7762.0 7776.0 7786.5 7872.0 7881. 0 7876.5 7885.0 7886.0 7896.0 7952.5 7958.0 7979.0 7987.5 7998.0 8005.0 8016.5 8024.5 8041.0 8048.5 8086.0 8095.5 8101.5 8109.0 8117.0 8123.0 8151.0 8157.5 8963.0 8970.5 9082.5 9089.5 9119.0 9126.5 9139.0 9146.0 9141.5 9149.0 9194.0 9202.5 9303.0 9310.5 9405.5 9413.5 9490.5 9500.5 9504.5 9513 .0 9555.5 9563.5 e e 9563.5 9577.5 9589.5 9600.0 9608.5 9626.5 9630.5 9632.5 9639.5 9645.5 9647.0 9650.0 9666.0 9670.5 9681.0 9686.5 9691.0 9704.0 9711.0 9752.0 9765.0 9798.5 9824.5 9829.5 9833.5 9838.0 9839.0 9845.0 9850.0 9851.5 9855.0 9859.5 9864.5 9870.5 9874.5 9878.0 9881. 5 9883.5 9888.0 9891. 5 9897.5 9905.5 9906.5 9908.5 9912.0 9920.0 9922.0 9926.0 9931.0 9935.5 9937.5 9951.0 9953.0 9961.0 9964.5 9969.0 9986.5 9991. 5 9995.0 10009.5 10016.5 10017.5 10020.5 10025.0 10027.5 10037.0 10046.5 10048.5 10051.0 10061.0 10069.0 10084.0 10086.0 10091.0 10100.5 10109.0 9572.0 9584.5 9597.0 9607.5 9616.0 9633.0 9637.0 9639.0 9646.5 9653.0 9654.5 9657.5 9673.0 9678.5 9688.5 9693.0 9698.0 9711.5 9719.0 9762.0 9774.5 9811.0 9833.0 9838.0 9842.5 9846.0 9848.0 9853.5 9857.5 9859.5 9863.0 9867.5 9872.0 9878.5 9882.5 9886.0 9888.5 9891.0 9895.5 9898.5 9902.5 9910.5 9912.0 9913.5 991 7.0 9925.5 9927.5 9931. 5 9936.5 9940.0 9943.0 9956.5 9958.5 9967.0 9970.5 9977.0 9993.5 9998.5 10002.5 10017.0 10023.5 10025.5 10028.0 10033.0 10035.0 10044.5 10053.5 10055.5 10057.5 10067.0 10075.5 10090.0 10093.0 10098.0 10106.5 10114.5 e 10118.0 10126.5 10135.0 10144.5 10154.0 10161.5 10167.0 10176.0 10179.0 10185.5 10199.5 10235.5 10260.5 10277.0 10302.5 10320.0 10323.5 10339.0 10341.0 10350.0 10379.0 10392.5 10414.5 10418.5 10454.0 10464.0 10476.0 10480.5 10497.0 10504.5 10668.0 $ 10123.5 10133.0 10140.5 10146.5 10159.5 10166.0 10171.5 10180.0 10182.5 10188.5 10202.5 10239.0 10265.5 10280.0 10307.0 10325.0 10328.0 10342.0 10345.0 10355.5 10384.0 10396.0 10419.5 10422.0 10455.5 10466.0 10479.0 10484.0 10499.5 10507.5 10671.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 7341.0 7370.0 MERGE BASE 7370.0 10671.0 # 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. ..0 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 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD FT/H Min 6606.5 0.08 Max 10668 451.52 Mean 8637.25 121.75 Nsam 8124 6676 e First Reading 6606.5 7330.5 Last Reading 10668 10668 e e GR MWD API 20.48 326.68 97.4261 7224 6606.5 10625.5 RPX MWD OHMM 0.86 1792.18 5.61292 6618 7309 10617.5 RPS MWD OHMM 0.88 1792.38 7.284 6618 7309 10617.5 RPM MWD OHMM 0.87 1834.1 8.55211 6618 7309 10617.5 RPD MWD OHMM 0.39 2000 15.2884 6618 7309 10617.5 FET MWD HOUR 0.1986 21.8722 1.48045 6618 7309 10617.5 NPHI MWD PU-S 13 .42 55.67 30.3641 6454 7341. 5 10568 FCNT MWD CNTS 616.8 2198.7 1078.02 6454 7341.5 10568 NCNT MWD CNTS 110758 173510 135577 6454 7341. 5 10568 RHOB MWD G/CM 1.844 3.211 2.47362 6499 7333 10582 DRHO MWD G/CM -0.421 0.61 0.0621094 6499 7333 10582 PEF MWD BARN 1. 65 16.5 4.27107 6547 7309 10582 First Reading For Entire File..........6606.5 Last Reading For Entire File...........10668 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/11/19 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...... .04/11/19 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAWMWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 7341.0 STOP DEPTH 7370.0 # 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: 09-APR-04 Insite 66.37 Memory 7370.0 7341.0 7370.0 .0 .0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ TOOL NUMBER # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 7341.0 # BOREHOLE CONDITIONS , ' e MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..... . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 LSND 9.60 66.0 9.2 1000 6.5 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 7341 0.08 Max 7370 14.77 First Reading For Entire File......... .7341 Last Reading For Entire File.......... .7370 File Trailer Service name.... .... .....STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. . . . . . .04/11/19 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...... .04/11/19 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 Mean 7355.5 8.35644 Nsam 59 59 e .0 .0 .0 .0 First Reading 7341 7341 Last Reading 7370 7370 e RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX PEF DRHO RHOB NCNT FCNT NPHI ROP $ e header data for each bit run in separate files. 2 .5000 START DEPTH 6618.5 7320.0 7320.0 7320.0 7320.0 7320.0 7320.0 7343.0 7343.0 7350.5 7350.5 7350.5 7370.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ STOP DEPTH 10628.5 10620.5 10620.5 10620.5 10620.5 10620.5 10585.0 10585.0 10585.0 10571.0 10571.0 10571.0 10671.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # 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 13-APR-04 Insite 66.37 Memory 10671.0 7370.0 10671.0 8067.1 41. 6 TOOL NUMBER 155789 157645 120993 185457 8.500 7341.0 LSND 9.90 43.0 9.2 30600 3.3 1. 960 1.130 1.950 2.600 80.0 143.6 80.0 80.0 , ' e e Optical log depth units.... ...... . Feet Data Reference Point............. .Undefined Frame Spacing..................... 60 .1IN Max frames per record........ .... .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6618.5 10671 8644.75 8106 6618.5 10671 ROP MWD020 FT/H 0.38 451. 52 122.919 6602 7370.5 10671 GR MWD020 API 20.48 326.68 97.537 7200 6618.5 10628.5 RPX MWD020 OHMM 0.85 1792.18 5.34698 6602 7320 10620.5 RPS MWD020 OHMM 0.81 1792.38 7.02655 6602 7320 10620.5 RPM MWD020 OHMM 0.78 1834.1 8.29066 6602 7320 10620.5 RPD MWD020 OHMM 0.39 2000 14.7733 6602 7320 10620.5 FET MWD020 HOUR 0.1986 21.8797 1.46631 6602 7320 10620.5 NPHI MWD020 PU-S 13.42 56.62 30.3479 6442 7350.5 10571 FCNT MWD020 CNTS 616.8 2198.7 1078.65 6442 7350.5 10571 NCNT MWD020 CNTS 110758 173510 135599 6442 7350.5 10571 RHOB MWD020 G/CM 1.844 3.211 2.47365 6485 7343 10585 DRHO MWD020 G/CM -0.421 0.61 0.0621312 6485 7343 10585 PEF MWD020 BARN 1. 65 16.5 4.26312 6531 7320 10585 First Reading For Entire File..........6618.5 Last Reading For Entire File...........10671 File Trailer Service name.. ....... ....STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/19 Maximum Physical Record..65535 File Type...... ...... ....LO Next File Name. ....... ...STSLIB.004 Physical EOF Tape Trailer Service name..... ....... .LISTPE Date.................... .04/11/19 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. . . . . . . . . . . . . . . . . . . . .04/11/19 Origin.... ...............STS Reel Name............... . UNKNOWN Continuation Number......01 if \ e e Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File