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202-123
By Grace Christianson at 10:26 am, Jan 30, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.29 16:12:13 - 09'00' Sean McLaughlin (4311) 325-044 A.Dewhurst 10FEB25 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. 10-407 JJL 2/5/25 DSR-1/31/25*&: 2/10/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.10 15:24:43 -09'00' RBDMS JSB 021325 12,319' To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: January 29, 2025 Re:D-08A Sundry Request Sundry approval is requested to set a whipstock and mill a window in the D-08A wellbore as part of the drilling and completion of the proposed D-08B CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN- nipple. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2" packer whipstock. A single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Ivishak and land in Ivishak Zone 2. The lateral will continue in Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2- 7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in Feb 15th, 2025) 1. Slickline : Pull dream catcher & tubing patch, drift for whipstock 2. E-Line : Mill XN nipple @ 9,259' & Set Baker 4-1/2" Packer Whipstock at 9,510' MD 160 degrees ROHS 3. Coil : Mill 3.80" Window 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse & level pad Rig Work: 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,399 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~701' (18 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2106' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 36 bbls, 14.8 ppg Class G, 1.33 (ft3/sk), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Liner Lap test, Post rig RPM (rush process), CBL, Perforate ~20-40' of 2" guns 3. Slickline : Contingent LTP set (dependent on Liner lap test) & set GLV's Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-08A Dump Bail Cement Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-123 50-029-20372-01-00 10180 Conductor Surface Intermediate Liner Liner 9171 78 2638 6874 2686 915 9863 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8902 32 - 110 31 - 2669 29 - 6903 6744 - 9430 9262 - 10177 32 - 110 31 - 2669 29 - 6204 6081 - 8521 8369 - 9169 None 2670 4760 5410 7500 9863, 9894, 9900 4930 6870 7240 8430 9426 - 10016 4-1/2" 12.6# 13Cr80 27 - 9272 8518 - 9032 Structural 4-1/2" Baker S3 Packer 9214 8326 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285 27 - 8378 9863 - 9884'MD Dump Bail 15.8-gallons of 17-ppg Neo cement. 319 441 30600 39883 18 64 600 200 1300 1100 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 9214, 8326 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:50 pm, Dec 12, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.12.12 12:32:07 - 09'00' Torin Roschinger (4662) DSR-12/16/24 RBDMS JSB 122624 WCB 2-6-2025 ACTIVITY DATE SUMMARY 11/30/2024 ***WELL S/I ON ARRIVAL*** PULLED DREAMCATCHER FROM X-NIPPLE @ 9,194' MD DRIFTED & TAGGED TOP OF CBP @ 9,900' MD W/ 33' x 2" (2.16" RINGS) DMY GUNS W/ DIFFICULTY (see log) ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 12/2/2024 T/I/OA= 2200/0/250 Assist E-Line in TBG Load. Pumped 3 bbls of 60/40 and 220 bbls of crude down TBG. E-Line Left in control of well upon departure. FWHP=850/0/250 12/2/2024 ***WELL SHUT IN ON ARRIVAL*** T/IA/OA=1900/0/250 RIG UP AKE PCE FUNCTION TEST WLV'S STANBY FOR THUNDER BIRD TO PUMP PT 250L 3000H RIH WITH 30' OF 2" BAILER FILLED WITH SAND SET DOWN WITH BAILER AT TOP OF PATCH UNABLE TO WORK THROUGH CHANGED BAILER BOTTOM RIH WITH EMPTY BAILER THROUGH PATCH TO BOTTOM TAGGED @ 9894' T/IA/OA=320/0/250 JOB TO BE CONTINUED 3-DEC-2024 ***WELL SHUT IN ON DEPARTURE*** 12/3/2024 ***WELL SHUT IN ON ARRIVAL*** T/IA/OA=750/0/250 RIG UP AKE PCE PT 250L 3000H RIH WITH 30' OF 2" BAILER FILLED WITH SAND DUMP TWO RUNS OF SAND ON PLUG. ESTIMATED TOP OF SAND=9884' T/IA/OA=1200/0/250 JOB TO BE CONTINUED 4-DEC-2024 ***WELL SHUT IN ON DEPARTURE*** 12/4/2024 ***JOB CONTINUED FROM 03-DEC-2024*** (CEMENT DUMP BAILER) T/IA/OA 1500/0/250 RIG UP AKELINE PT 250L 3000H RIH W/ 1"FISHING NECK ON CABLEHEAD/7' 2" WB/ 1 11/16 CCL/30' 2" BAILER DUMP ONE RUN OF CEMENT ON SAND T/IA/OA 1500/0/250 WELL SECURED FOR THE NIGHT TREECAP TESTED ***JOB TO BE CONTINUED ON 05-DEC-2024*** Daily Report of Well Operations PBU D-08A Daily Report of Well Operations PBU D-08A 12/5/2024 ***JOB CONTINUED FROM 04-DEC-2024*** (CEMENT DUMP BAILER) T/IA/OA 2000/0/250 RIG UP AKELINE PT 250L 3000H RIH W/ 1"FISHING NECK ON CABLEHEAD/7' 2" WB/ 1 11/16 CCL/30' 2" BAILER DUMP 1 RUN OF CEMENT ONCE BACK TO SURFACE LAID LUBE DOWN TO CHECK BAILERS BEFORE NEXT RUN FOUND CEMENT PLUG INSIDE. MAX OF ONE GAL DUMPED. PLAN TO RUN 3 MORE BAILER RUNS BEGAN CLEANING AND WILL FINSIH CLEANING AT THE SHOP T/IA/OA 2000/0/250 ***JOB TO CONTINUE ON 06-DEC-2024*** 12/6/2024 ***JOB CONTINUED FROM 05-DEC-2024*** (CEMENT DUMP BAILER) T/IA/OA 2400/0/250 RIG UP AKELINE PT 250L 3000H DUMP 3 RUNS OF 17 PPG NEO CEMENT. TOTAL OF 15.8 GALLONS WITH AN ESTIMATED TOC OF 9863.4' T/IA/OA 2400/0/250 WELL SHUT IN ON DEPARTURE ***JOB COMPLETED*** 12/8/2024 ***WELL S/I UPON ARRIVAL*** (profile modification) R/U HES 759 SLICKLINE UNIT ***CONT WSR ON 12/9/24*** 12/9/2024 ***CONT WSR FROM 12/9/2024*** TAGGED 4 1/2" XN-NIPPLE W/ 3.75" G-RING @ 9,232' SLM / 9,259' MD (27' corr) ATTEMPTED TO TAG TD W/ 2.25" CENT, 1.75" SAMPLE BAILER. SD IN PATCH @ 9,544' SLM / 9,571' MD (lower patch, metal marks on cent) TAGGED HARD CEMENT W/ 1.79" CENT, 1.75" SAMPLE BAILER @ 9,848' SLM / 9,875' MD (no sample) SET 4 1/2" DREAM CATCHER IN X-NIPPLE @ 9,194' MD (verified w/ check set) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** TOTAL OF 15.8 GALLONS WITH AN ESTIMATED TOC OF 9863.4' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-08A Patch Perforations Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-123 50-029-20372-01-00 10180 Conductor Surface Intermediate Liner Liner 9171 78 2638 6874 2686 915 9870 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8908 32 - 110 31 - 2669 29 - 6903 6744 - 9430 9262 - 10177 32 - 110 31 - 2669 29 - 6204 6081 - 8521 8369 - 9169 None 2670 4760 5410 7500 9870, 9900 4930 6870 7240 8430 9426 - 10016 4-1/2" 12.6# 13Cr80 27 - 9272 8518 - 9032 Structural 4-1/2" Baker S3 Packer 9214 8326 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285 27 - 8378 N/A N/A 552 319 53660 30600 70 18 750 600 1160 1300 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 9214, 8326 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 12:33 pm, Oct 14, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.10.14 12:28:05 - 08'00' Torin Roschinger (4662) DSR-10/14/24WCB 2-7-2025 RBDMS JSB 101724 ACTIVITY DATE SUMMARY 9/25/2024 ***WELL S/I ON AARIVAL*** DRIFTED KJ, 3' x 1-7/8'' STEM, 3.70'' CENT, DRIFTED FREELY TO 9844' SLM ***WSR CONT ON 9-26-24*** 9/26/2024 ***WSR CONT FROM 9-25-24*** DRIFTED 4-1/2'' GR, 45KB UPPER DRIFT 25' SPACER PIPE 45KB LOWER DRIFT (oal 35' ) DRIFTED CLEAN TO S/D @ 9850' SLM (1100# p/u weight off btm) ***JOB COMPLETE, WELL LEFT S/I*** 9/28/2024 ***WELL S/I ON ARRIVAL*** (ADPERF W/ 2 3/4'' GEO RAZOR ) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH PERFORATE INTERVAL 9608'-9625' WITH 2 3/4'' GEO RAZOR 6spf 60 DEG PHASE CCL TO TOP SHOT=8.2' CCL STOP DEPTH= 9599.8'. CONFIRM SHOTS FIRED. GUN CORRELATE TO HES RMT3D LOG DATED 22-DEC-2016 LAID DOWN LUBRICATOR FOR THE NIGHT ***JOB WILL CONTINUE ON 9-29-2024*** 9/29/2024 ***JOB CONTINUE FROM 9/28/2024*** (SET NS PATCH) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH SET 3.68" OD X 40.25'NS PATCH TOP ELEMENT AT 9536' CCL TO MID ELEMENT=15.1' CCL STOP DEPTH= 9520.9'. GR-CCL CORRELATE TO HES RMT3D DATED 22-DEC-2016 (Top of patch at 9,533', bottom of patch at 9,573', 2.38" min id, 40.25' oal) JOB COMPLETE ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU D-08A (Top of patch at 9,533', bottom of patch at 9,573', PERFORATE INTERVAL 9608'-9625' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU D-08A (PTD 202-123) PERF 2/16/2022 Please include current contact information if different from above. PBU 202-123 T36393 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.04 09:50:59 -09'00' 3URSHUW\'HVLJQDWLRQ /HDVH1XPEHU 2SHUDWLRQV 3HUIRUPHG 2SHUDWRU1DPH $GGUHVV :HOO&ODVV%HIRUH:RUN 3HUPLWWR'ULOO1XPEHU $3,1XPEHU :HOO1DPHDQG1XPEHU /RJV /LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$& )LHOG3RRO V $EDQGRQ 6XVSHQG 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 3HUIRUDWH 3OXJ3HUIRUDWLRQV 5HHQWHU6XVS:HOO 2WKHU6WLPXODWH )UDFWXUH6WLPXODWH $OWHU&DVLQJ 3XOO7XELQJ 5HSDLU:HOO 2WKHU &KDQJH$SSURYHG3URJUDP 2SHUDWLRQVVKXWGRZQ 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ &DVLQJ /HQJWK 6L]H 0' 79' %XUVW &ROODSVH ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH $WWDFKPHQWV UHTXLUHGSHU$$& :HOO6WDWXVDIWHUZRUN ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGFRUUHFWWRWKHEHVWRIP\NQRZOHGJH 2,/ *$6 :,1- :$* *,1- :'63/ *6725 6XVSHQGHG 63/8* $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $XWKRUL]HG7LWOH &RQWDFW1DPH &RQWDFW(PDLO &RQWDFW3KRQH 3%8'$ +LOFRUS1RUWK6ORSH//& &HQWHUSRLQW'U6XLWH$QFKRUDJH$. &RQGXFWRU 6XUIDFH ,QWHUPHGLDWH /LQHU /LQHU [ 1RQH &U 6WUXFWXUDO %DNHU63DFNHU 6WDQ*ROLV 6U$UHD2SHUDWLRQV0DQDJHU 1RHO1RFDV 1RHO1RFDV#KLOFRUSFRP 358'+2(%$<358'+2(2,/ 7RWDO'HSWK (IIHFWLYH'HSWK PHDVXUHG WUXHYHUWLFDO IHHW IHHW IHHW IHHW PHDVXUHG WUXHYHUWLFDO PHDVXUHG PHDVXUHG IHHW IHHW IHHW IHHW PHDVXUHG WUXHYHUWLFDO 3OXJV -XQN 3DFNHU 0HDVXUHGGHSWK 7UXH9HUWLFDOGHSWK IHHW IHHW 3HUIRUDWLRQGHSWK 7XELQJ VL]HJUDGHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 3DFNHUVDQG6669 W\SHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 6WLPXODWLRQRUFHPHQWVTXHH]HVXPPDU\ ,QWHUYDOVWUHDWHG PHDVXUHG 7UHDWPHQWGHVFULSWLRQVLQFOXGLQJYROXPHVXVHGDQGILQDO 5HSUHVHQWDWLYH'DLO\$YHUDJH3URGXFWLRQRU,QMHFWLRQ'DWD 2LO%EO *DV0FI :DWHU%EO &DVLQJ3UHVVXUH 7XELQJ3UHVVXUH 3ULRUWRZHOORSHUDWLRQ 6XEVHTXHQWWRRSHUDWLRQ :HOO&ODVVDIWHUZRUN ([SORUDWRU\ 'HYHORSPHQW 6HUYLFH 6WUDWLJUDSKLF'DLO\5HSRUWRI:HOO2SHUDWLRQV &RSLHVRI/RJVDQG6XUYH\V5XQ (OHFWURQLF)UDFWXUH6WLPXODWLRQ'DWD 6XQGU\1XPEHURU1$LI&2([HPSW $'/ 1R6669,QVWDOOHG 1$ 1$ 1$ 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 5(32572)681'5<:(//23(5$7,216 6U3HW(QJ 6U3HW*HR )RUP5HYLVHG6XEPLW:LWKLQGD\VRU2SHUDWLRQV 6U5HV(QJ By Samantha Carlisle at 4:52 am, Feb 22, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1 FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV $&7,9,7<'$7(6800$5< :(//6+87,121$55,9$/ -2%6&23( 3(5)25$7( : *(2 5$=25*81 581 ; *(25$=25*8163)'HJ3+$6( &255(/$7('72+$//,%85721507'/2*'$7(''(& 3(5)25$7,21,17(59$/ &&/727236+27 &&/6723 '(37+ 3HUIRUDWHGZLWK5D]RU;'3(+'3HQHWUDWLRQ :(//6+87,121'(3$5785( 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8'$ 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-08A Set CBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-123 50-029-20372-01-00 10180 Conductor Surface Intermediate Liner Liner 9171 78 2638 6874 2686 915 9870 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8908 32 - 110 31 - 2669 29 - 6903 6744 - 9430 9262 - 10177 32 - 110 31 - 2669 29 - 6204 6081 - 8521 8369 - 9169 None 2670 4760 5410 7500 9870, 9900 4930 6870 7240 8430 9426 - 10016 4-1/2" 12.6# 13Cr80 27 - 9272 8518 - 9032 Structural 4-1/2" Baker S3 Packer 9214, 8326 Stan Golis Sr. Area Operations Manager Noel Nocas Noel.Nocas@hilcorp.com 907.564.5278 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285 No SSSV Installed 27 - 8378 N/A N/A 271 94 25217 5431 1924 0 621 3070 871 1470 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 9214 8326 By Meredith Guhl at 9:24 am, Nov 12, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.11.11 14:48:47 -09'00' Stan Golis (880) MGR28DEC2021 RBDMS HEW 11/12/2021 SFD 11/15/2021 DSR-11/12/21 ACTIVITY DATE SUMMARY 11/6/2021 ***WELL FLOWING ON ARRIVAL*** (Plug Set) MIRU HES E-LINE RIH & SET HES 4-1/2" OBSIDIAN CBP @ 9870'. CORRELATED TO HES RMT3D LOG 22-DEC-2016. RDMO E-LINE ***JOB COMPLETE / TURN OVER TO PAD-OP TO POP*** Daily Report of Well Operations PBU D-08A 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-08A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-123 50-029-20372-01-00 10180 Conductor Surface Intermediate Liner Liner 9171 78 2638 6874 2686 915 9900 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8934 32 - 110 31 - 2669 29 - 6903 6744 - 9430 9262 - 10177 32 - 110 31 - 2669 29 - 6204 6081 - 8521 8369 - 9169 None 2670 4760 5410 7500 9900 4930 6870 7240 8430 9426 - 10016 4-1/2" 12.6# 13Cr80 27 - 9272 8518 - 9032 Structural 4-1/2" Baker S3 Packer 9214, 8326 Stan Golis Sr. Area Operations Manager Noel Nocas Noel.Nocas@hilcorp.com 907.564.5278 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285 No SSSV Installed 27 - 8378 N/A N/A 271 25217 1924 621 871 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 9214 8326 442 18367 2008 1899 507 By Samantha Carlisle at 1:51 pm, Oct 20, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.20 12:19:55 -08'00' Stan Golis (880) SFD 10/20/2021 DSR-10/20/21 RBDMS HEW 10/21/2021 MGR20OCT2021 ACTIVITY DATE SUMMARY 10/16/2021 ***WELL S/I ON ARRIVAL*** (perforating) DRIFTED W/ 3.70" LIB TO TOP OF LOWER PACKER @ 9,924' MD (clean impression of fishing neck) DRIFTED W/ 30' x 3 3/8" DUMMY GUNS (3.66" swell rings) TO TOP OF LOWER PACKER @ 9,924' MD SET NORTHERN SOLUTIONS COMPOSITE BRIDGE PLUG @ 9,900' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** 10/18/2021 ***WELL SHUT IN UPON ARRIVAL*** Job Scope: Adperf INITIAL T/I/O = 1900/1350/250 PSI PERFORATE INTERVAL: 9426' - 9448' W/ 3-1/8" GEO RAZOR PERF GUN CCL TO TOP SHOT = 10.3', CCL STOP DEPTH = 9415.7' FINAL T/I/O = 2050/1350/250 PSI ***JOB COMPLETE / TURN OVER TO POP*** 10/18/2021 T/I/O = 2290/1360/300. Temp = SI. Drawdown test (eline). ALP = 1900 psi, SI @ CV. T FL @ 9360' (540' above bridge plug). Bled TP to BT to 1970 psi in 2 hrs. T FL inflowed 200' to 9160' (740' above bridge plug). Monitored for 30 min. TP increased 10 psi, IA FL unchanged. Extended monitor for 30 min. TP & T FL unchanged. Final WHPs = 1980/1360/300. T FL @ 9160' (740' above bridge plug, 140 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:00 10/18/2021 T/I/O= 1900/1350/250 (Assist E-line) 1 bbl 60/40 and 9 bbls Crude pumped down TBG. FWHP= 2000/1350/250, E-line still on well upon departure. Daily Report of Well Operations PBU D-08A 9426' - 9448' Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellInte rit Coordinator b .com> Sent: Wednesday, August 19, 2015 10:30 AM g To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad DG; Bailey, Denise G; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: OPERABLE: Producer D-08A (PTD #2021230) MIT-IA Passed All, Producer D-08A(PTD#2021230) passed a MIT-IA on 08/17/2015 following gas lift valve work. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed • A SSSV is not required Please use caution while placing well on production due to fluid packed annuli and the potential for annular fluid expansion. Thank you, Kevin Parks 006 ASG 2 4 2015 (A�tpr'liaj p- I��"1/t llr'VPi itu, BP Alaska -Well Integrity Coordinator GWY Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From,---D&C Well Integrity Coordinator Sent: Saturda r, August 08, 2015 7:36 PM To: AK, OPS GC1 OSM; A1C;QHS GC1 Field O&M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel; an; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad DG; Bailey, Denise G; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.regg@alaska.gov); Pettus, Whitney Subject: UNDER EVALUATION: Producer D-08A (PTD #2021230) Sustained Inner Annulus Casing Pressure over MOASP All, �. 1 N Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, August 08, 2015 7:36 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad DG; Bailey, Denise G; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA); Pettus, Whitney Subject: UNDER EVALUATION: Producer D-08A (PTD #2021230) Sustained Inner Annulus Casing Pressure over MOASP All, Producer D-08A (PTD #2021230) was reported to have sustained inner annulus casing pressure above MOASP on August 05, 2015. The pressures were reported to be TBG/IA/OA= 2070/2070/400 psi. A cold TIFL subsequently failed on August 06, 2015 indicating a lack of potential barriers downhole. At this time the well has been reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Downhole Diagnostics: Cold TIFL—FAILED 08/06/15 2. Slickline: Dummy valves 3. Fullbore: MIT-IA 4. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMM' iN REPORT OF SUNDRY WELL OPERA1 _S ' 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Straddle Patch Perfs Ed 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-123 3. Address: P.O.Box 196612 Anchorage, Development I Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20372-01-00 7 Property Designation(Lease Number): ADL 0028285 8. Well Name and Number: PBU D-08A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: 9 E ' x E D Total Depth: measured 10180 feet Plugs measured feet 4�F true vertical 9171 feet Junk measured feet I UL 3 0 n15 Effective Depth: measured 10095 feet Packer measured See Attachment feet true vertical 9099 feet Packer true vertical See Attachment feet A C)f3 CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 33-113 33-113 0 0 Surface 2641 13-3/8"72#L-80 32-2674 32-2673 4930 2670 Intermediate 6874 9-5/8"47#L-80 30-6904 30-6204 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9937-9947 feet 9950-9955 feet 9966-9980 feet 9996-10016 feet True vertical depth: 8965-8974 feet 8976-8980 feet 8990-9002 feet 9015-9032 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr8 28-9272 28-8378 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary' Intervals treated(measured): SCANNED ;.� 2.1H Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 430 27521 1540 1400 877 Subsequent to operation: 384 19435 1586 1380 1360 14.Attachments:(required per 20 AAc 25 070 25 071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Ed Exploratory 0 Development I! Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Id Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature xfQ,s, „ Phone +1 907 564 4424 Date 7/30/15 Form 10-404 Revised 5/2015_1Y VT_- 1/7/ 15— Submit O nal Only i4 A - RBDMSct AUG - 2 2015 Packers and SSV's Attachment PBU D-08A SW Name Type MD TVD Depscription D-08A PACKER 6752.6 6088.05 7" Baker ZXP Top Packer D-08A PACKER 9215.34 8326.79 4-1/2" Baker S-3 Perm Packer D-08A PACKER 9270.12 8376.1 5" Baker ZXP Top Packer D-08A PACKER 9958 8982.99 4-1/2" Lower Straddle Packer O000O ca � m � oo c0 N- in 1n C N LO ti N- U N O O O O O i M I� M M 000N `Cr 'Cr Ca CO 00 00 M N O CO M N N. ti CO N LO r M N CO CO O) CO f" N O) M N O 00 CO CO M M CO O CO N CO CO 4.0 QDM d r, N O M r-- co O) p N N CO O) O) C.) i I i i i i Qc0 to co u M N O N. CO co 01 ' M M M (0 N N 0 CO a7 L� ^m A O 00 OOLO C° 00 0 U _ J J M 00 C N � N *k J 4* 4* Cl) X N- N *k CO CO CO N O 00 N O M N t C 00 CO co CO N G1 N CO N O O) W C O0 U W W U 0 L I Z Z r W W W m 0 D H Z_ Z_ D U) Z J J I- O W F- U) Lu_1 2 2 2 (1) �\ J cn ❑ O N O V O 00) * co M N 2 O U) II Z cC O U) D Lu O < XOX I z � Co Q ❑ Q U) 1 0") cn N W b - W Il _i F_ * O U) R W O > 0- O W * /:J� 0 II N LU \ CL: W Q O ❑ CC QO 0 ❑ � O C W o < � L� Y W LU Orn �� � m � Q C� � � .> u) - I- LL' m U) N = m 0_ U) aa) a) W oc _ U) U) b < Y2 Ci.. 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(_- � w _1c=n � w2DQ_ ocn `-" clWZz °0- J W 1-- Z � O N � cj � w c----' al—Z Z Y Y ❑ J J J Q 2 CC I- U -1 = -1 °6 Z Z � � W W :3 0 C) Mmm`roM0) v � 00oCct � W WQmI-- < C) wva) CD CD iW � c� Uv ¢ QQQoQ � wE- UvwwE- � ,' ~ ww1Z74w "o) wQUv = = * * LL * * W' cc 0 W' W' 0 U) IZ * * co co a_ * * Z co ❑ ❑ IL * * U) a) U) 2 * * W W * W F- Q In in In in in LU a O O O O O O F- N_ N N N N N r lit) co N- 5 O N N N N N I O CO CO CO CO CO 0 Q U O E - a_ Q W 0 Q 5 L O Mo W L a 0 0. a) LCL �JY U) 0 N N 0 a 23 co TREE= ¢'/8- ,FLS D 08A 11VaLHtAD= MCEI/OY � NOTES: 4-1/2"CHROME LNR. .ACTUATOR= awC OKB.ELEV= 71.5 - I BF.ELEV= 44.84' KOP= _ 6900' I s � 2212' --14-1/2'HES X LANDING NIP,D=3.813' Max Angle= 42"r'5603' ' I Datum MD= 9831' 2544' —{9-5'8"DV PKR Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,ID=2.347' — 2669' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 6 3450 3440 16 MMGM DOME FE 16 06/21/15 9-5/8"X 8-114'BKR TEBACK SLV,D=7.50" H 6744' , 5 4276 4170 35 MMGM OW RK 0 07/06/02 9-5/8"X 7"BKR ZXP LTP w/HGR,D=6.25" —( 6752' 1 -k [ Q� 4 6693 6043 40 MMGM SO FE 20 06/21/15 3 7602 6812 16 KBG-2 OW BK 0 07/06/02 2 8385 7573 22 KBG-2 DW BK 0 07/06/02 TOP OF WHPSTOCK I-1 6903' 1 9125 8246 26 KBG-2 OW BK 0 07/06/02 9-5/8"CSG,47#,L-80,D=8.681' H —6903 +��,,,.esite s$9 \ MLLOUT WINDOW(D-06A) 6903'-6919' I 9194' H4-1/2"OTIS X NP,D=3.813" Minimum ID =2.38" @ 9919' $ 9214' H7"X 4-1/2"BKR S-3 PKR D=3.875" 4-1/2" TBG STOP 9238' H4-1/2"I-ES X NP,E)=3.813" 9259' —1 4-1/2"HES XN NIP,D=3.725" 4-1/2"LNR,12.6#,13CR-80, 9270' .0152 bpf, D=3.958" 9262' 7"X5'BKR Z?P LIP w/TEBACK Sly,ID=4.39? 7"LNR,26#,L-80 BTC,.0383 bpf,D=6.276" 9430' 9271' 14-1/2"WLEG,ID=3.958" PERFORATION SUMMARY Gl X 9919' 4-1/2"D&D PACKOFF w/TBG STOP,D=2.38" REF LOG:GR/CCL ON 07/15/02 LY (9921'D&D PACKOFF FN)(06/27/15) ANGLE AT TOP PERF: 32©9937' Note:Refer to FToduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SI-DT SW 3-3/8" 6 9937-9947 C 01/26/09 9958' I—4-1/2"LOWER BKR STRADDLE PKR 3-3/8" 6 9950-9955 C 01/26/09 D=2.38"(6/25/15) 3-3/8" 6 9966-9980 0 08/31/02 3-3/8' 6 9996-10016 0 07/15/02 10095' HPBTD 4-1/2"LNR,12.6#,13CR-80, H 1017T .0152 bpf,D=3.958' DATE REV BY C RMENTS DATE REV BY C OMVBJTS PR DHOE BAY UNIT 02/26/90 ORIGINAL COMPLETION 04/06/15 DLYJMO TREE 00(03/27/15) WELL D-08A 07/07/02 DAV/KK RIG SIDETRACK 07/13/15 ELYJMD GLV C/O(06/21/15) REMIT No: 2021230 02/05/09 /SV GLV TVD OORR 07/30/15 DJS/JMD SET PKR/D&D PACKOFF w/MG STOP AR No: 50-029-20372-01 08/14/11 NW PJC GLV C/O(8/11/11) SEC 23,T11N,R13E,1910'FSL&1068'FEL 10/07/14 OHS/PJC FISH LEFT DH 12/09114 RK/PJC RILL FISH(KB FKR) BP Exploration(Alaska) ") ") Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O~- f~3 Order File Identifier Organizing (done) 0 Two-sided 1111111111111111111 0 Rescan Needed 1111111111111111 RES CAN DIGITAL DATA ~iskettes, No.1 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Color Items: 0 Greyscale Items: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: 0 Other: OVERSIZED (Non-Scannable) 0 Logs of various kinds: NOTES: Scanning Preparation BY: Helen ¡;:;::;) ,a x 30 = toð + 0 Other:: Date: '? P4- Ü If Isl VVfP 1111111111111111111 /5/ n1 P J 1 = TOTAL PAGES 7/ (Count d.o~s not)nclUde cover sheet) /) Date: ?t/;)..l.f / b If /5/ \111, 1111111111111111111 , Date:~,áLl. D~ BY: Helen~ Project Proofing BY: Helen~ BY: Production Scanning Stage 1 Page Count from Scanned File: 7 ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES , ¡ Helen~ Date: ß a. '5"' DLf Is! VVlfJ I I YES NO NO Stage 1 BY: If NO in stage 1 page(s) discrepancies were found: Helen Maria Date: /5/ Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111 BY: Helen Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Orders File Cover Page.doc p It b- -ot3.4 • • i ' " 202 ( 3o Regg, James B (DOA) From: Regg, James B (DOA) 1611,4[0./ Sent: Wednesday, October 24, 2012 11:43 AMC�f To: 'Redmond, Randy' Cc: Williams, Bruce J; Kruger, Dale 0; AK, OPS GC1 OSM; AK, OPS Full Field OSS; Daniel, Ryan Subject: RE: GPB Defeated GC -1 D -08 SVS (INC &-06A) Mr. Redmond — AOGCC commends BPXA for notification — on its own initiative — of the defeated well safety valve system (SVS), and the initiative to immediately implement corrective actions, retest the SVS, and investigate tha5e. AOGCC will not issue a Notice of Violation for this defeated SVS component because of the proactive effort exhibited by BPXA. AOGCC will send BPXA a closeout letter upon receipt of the investigation findings and description of actions taken to mitigate recurrence. Jim Regg AOGCC NNEJ AFR 9 9 2013 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Redmond, Randy [mailto:RedmonRF @BP.com] Sent: Wednesday, October 24, 2012 10:13 AM To: Regg, James B (DOA) Cc: Williams, Bruce J; Kruger, Dale 0; AK, OPS GC1 OSM; AK, OPS Full Field OSS; Daniel, Ryan Subject: FW: GPB Defeated GC -1 D -08 SVS Dear Mr. Regg, This memo is to inform the AOGCC that on October 23, 2012, BPXA encountered a production well, GC -1 Well Pad D -08, with its safety valve system (SVS) temporarily defeated by way of blocking open the SSV hydraulically. This condition was discovered during a miscellaneous testing of the D -08 SVS system and witnessed by the AOGCC Inspector. There has been a recent history of the wing valve failure on this well, which had been incapable of holding pressure, subsequently leading to a no test for the SVS beginning October 14, 2012. Upon discovery of the SSV blocked o •en and corrective actio . , - • • - • - 0 • • been tested and passed. BPXA takes this matter very seriously and it is currently under investigation and BPXA will notify AOGCCoLtliaaclings and proactive actions to mitigate this incident from re- occurring. Sincerely, Randy Randy Redmond, PE BPXA, Operations Full Field OSM RedmonRF@BP.com 907 -564 -4889 cell 907 -529 -2689 1 OPERABLE: Producer D -08A (PTD 21230) Tubing Integrity Restored Page • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator ©bp.com] )e iv 5( Ill Sent: Friday, August 12, 2011 3:49 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Reynolds, Charles (ALASKA); Phillips, Patti J Subject: OPERABLE: Producer D -08A (PTD #2021230) Tubing Integrity Restored All, Producer D -08A (PTD #2021230) passed an MIT -IA on 08/11/2011 after dummy gas lift valves were set. The passing test confirms two competen barriers and the well has been reclassified as Operable. Please be aware of the potential for thermal expansion when placing the well back online as the IA is liquid packed. Thank you, Mehreen Vazir (Alternate,. Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Sunday, July 24, 2011 10:38 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; , OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismo , Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB W- t Wells Opt Engr; AK, D &C Well Integrity Coordinator Cc: Stone, Christopher; Grey, Leighton (CH2M Hill); Townsend, S. Eliot •eynolds, Charles (ALASKA) Subject: UNDER EVALUATION: Producer D -08A (PTD #2021230 All, Producer D -08A (PTD #2021230) has c• firmed sustained IA casing pressure due to TxIA communication during proration. The 'ellhead pressures were tubing /IA/OA equal to SSV/2380/220 on 07/21/11. The well has been reclas • ied as Under Evaluation to allow the well to warm up prior to conduct a TIFL. The plan forward • as follows: 1. DHD: TIFL 2. Slickline: Set Dummy G 's (If TIFL fails) 3. Fullbore: MIT -IA A TIO plot and wellbore schematic have been included for reference. 8/25/2011 UNDER EVALUATION: Producer VA (PTD #2021230) • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] p„ 7 / Sent: Sunday, July 24, 2011 10:38 AM Z � To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, D &C Well Integrity Coordinator Cc: Stone, Christopher; Grey, Leighton (CH2M Hill); Townsend, S. Eliot; Reynolds, Charles (ALASKA) Subject: UNDER EVALUATION: Producer D -08A (PTD #2021230) Attachments: D -08A TIO Plot.doc; D -08A Schematic.pdf All, Producer D -08A (PTD #2021230) has confirmed sustained IA casing pressure due to TxIA communication during proration. The wellhead pressures were tubing /IA/OA equal to SSV/2380/220 on 07/21/11. The well has been reclassified as Under Evaluation to allow the well to warm up prio t o conduct a TIFL. The plan forward is as follows: 1. DHD: TIFL _ 2. Slickline: Set Dummy GLV's (If TIFL fails 3. Fulibore: MIT -IA Whet- c)& f , C�)4'3z A TIO plot and wellbore schematic have been included for reference. «D -08A TIO Plot.doc» «D -08A Schematic.pdf» Please call if you have any questions or concerns. • Thank you, Taylor Taylor Wellman filling in for Mehreen Vazir /Jerry Murphy Office: 659 -5102 Pager: 659 -5100 x 1154 !f JUL 2B2 7/28/2011 PBU D -08A PTD 2021230 7/24/2011 TIO Pressures Plot Wet 0-08 4,000 i 3,000 -4- Tbg -M IA —BOA 004 2.000 • ----* 000.4 giiii 1 On 1,000 1 1 • •.. 1 00/03/ 10 00/03 /10 10/04/70 11/04/10 12/05/10 01!0511} 02!05111 03109!17 04/08/11 05/09/11 Gb/09111 07/10/11 • TREE = 4" CIW • 4-1/2" CHROME LNR. SAFETY IOS: WELLHEAD = MCEVOY ACTUATOR= BAKER D-08A ... KB. ELEV = 74.5' BF. ELEV = 44.84' - KOP = 6900' Max Angle = 42 @ 5603' — nr2 7- 1 - 14-1/2" HES X LANDING NIP, ID = 3.813" Datum MD = 9831 0 Datum TVD = 8800' SS GAS LIFT MANDRELS •■• 2544' H9-5/8" DV PKR 13-3/8" CSG, 72#, L-80, ID = 2.347" ii 2669' I ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3450 3440 16 MMGM DOME RK 16 07/06/02 5 4276 4170 35 MMGM DMY RK 0 07/06/02 4 6693 6043 40 MMGM SO RK 20 07/08/04 3 7602 6812 16 KBG-2 DMY BK 0 07/06/02 Minimum ID = 3.725" @ 9259' 2 8385 7573 23 KBG-2 DMY BK 0 07/06/02 4-1/2" HES XN NIPPLE 1 9125 8246 26 KBG-2 DMY BK 0 07/06/02 MILLOUT WINDOW 6903' - 6919' 9-5/8" X7" BKR ZXP LNR TOP PKR —I 6744' I zip .. , W/ TIEBACK SLV, ID = 6.250" 9194' H4-1/2" OTIS X NIP, ID = 3.813" 1 9214' —17" X4-1/2" BKR S-3 PKR, ID = 3.875 TOP OF WHIPSTOCK —I 6903' I 9238' —14-1/2" HES X NP, ID = 3.813" ... . ... . . s,'....'. —. 4,%,.. 9259' —14-1/2" HES XN NIP, ID = 3.725" .. H 6920' CIBP 6920' 1 62' I— 9262' 7" X5" BKR ZXP LTP .i.■..---- N 'N.Ir al 1 e :CI .11 \ w/TIEBACK SLV, ID = 4.391" TOP OF CEMENT 1 CTM ocir . vsoimo III • 11 9271' —14-1/2" WLEG, ID = 3.958" 9-5/8" X4-1/2" BKR PERM PKR, ID = 4.75" H 8714' 9430' — 7" CSG, 26# VP L-80, ID = 6.276" #N# • • r" *t4 * • *V 4 1.1 *- % -1.4 • *I ,. t• •• * ! . . % M,• . Ai 9-5/8" CSG, 47#, L-80, ID = 8.681" I-1 9483' 1 10 • **I 10095' —IPBTD g k A 4, ittayr = 6467ors; , ,r-f. - 4 4-1/2" LNR, 12.6# —I 9270' I 1,4, • A I PERFORATION SUMMARY 13-CR-80, .0152 bpf, 3.958" REF LOG: GR/CCL ON 07/15/02 I # # 1 ID = ■ .4 ANGLE AT TOP PERF: 32 @ 9937' 4 •••4 -1., Note: Refer to Production DB for historical perf data 0* ••4 . Akio. SIZE SPF INTERVAL Opn/Sqz DATE 4* ••• I ■■• *44 A • 'li 3-3/8" 6 9966 - 9980 0 08/31/02 i■ 1 I'l* 3-3/8" 6 9996 - 10016 0 07/15/02 / #, •• Al 3-3/8" 6 9937 - 9947 0 01/26/09 / V 41 4-1/2" LNR, 12.6#, 13-CR-80, '-- 10177' 14 ••• I 3-3/8" 6 9950 - 9955 _ 0 01/26/09 0* **4 !* *I .0152 bpf, ID = 3.958" t.. •• 4! 0 • A it, • 1 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ]—J 10570' 14■14I 4 44 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/26/90 ORIGINAL COMPLETION 09/16/03 CMO/TLP DATUM MD/TVD, PERF ANGLE WELL: D-08A 07/07/02 DAV/KK RIG SIDETRACK 02/13/04 ROY/TLH XN NIPPLE CORRECTION PERMIT No: g 021230 08/31/02 CWS ADD PERF 07/08/04 JLJ/KAK GLV C/O API No: 50-029-20372-01 01/23/03 JK/TP GLM CORRECTIONS TO KBG-2 02/05/09 JKD/SV ADPERF (01(26/09) SEC 23, T11N, R13E 1067' WEL & 1910' NSL 06/01/03 MAH/TLP PERF CORRECTION 02/05/09 /SV GLV TVD CORR 07/04/03 CMO/TLP KB ELEVATION & MAX ANGLE -- BP Exploration (Alaska) • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 AOa 1 D" r Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 fki,c ka l & tiCans p ° s � iS$IU �"�EryIDOt�p� Subject: Corrosion Inhibitor Treatments of GPB D Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad 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, Jerry Murphy, 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: 03/04/11 Corrosion Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal D -01 A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A _ 2021230 50029203720100 _ NA 0.5 NA 3.40 2/9/2011 '� D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 0-10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 0-11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 0-20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000 .. NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 0-24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 D -33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 10/15/08 ~~ ~~~1'~~b~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 1 nn I'1u¢rrinfinn N0.4931 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnkeni 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n..~.. el 07-306 12005233 SCMT - U ~ 09/22/08 1 v 1 W-31 12031513 USIT .,- (~[{ 09/18/08 1 1 05-35A 11975794 USIT t 09/11/08 1 1 M-08 12096917 PRODUCTION PROFILE - 10/06/08 1 1 P2-46 11970849 INJECTION PROFILE 10/09/08 1 1 D-08A 11962617 RST _. Og/21/pg 1 1 05-02A 12103674 RST ~ ~ (~ 08/24/08 1 1 07-306 12005233 MCNL 09/23/08 1 1 13-14 11978482 RST - '~ 09/13/08 1 1 OI CACG Af~llAlA\IIII CI1f+r n __- _ -_._-__ .-___--~ ..~~~.. ~ . ~. M.~..~M r..~v ,.r, v~n~n~M VIAL. vvr l VNlill I V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503- 8 ATTN: Beth Received by: • • 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: ~ . STATE OF ALASKA ...Þ/$*tP7 MAR 1 4 7001 ALASKA OIL AND GAS CONSERVATION COMMISSION . . ..'. REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & GilS COOS. \,;QfMH5S:;)(, o o o Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimulate [2] Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1230 ~ .. P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Exploratory Service 6. API Number: 50-029-20372-01-00 / 3. Address: 9. Well Name and Number: 74.54 KB ¿ PBU D-08A .f 8. Property Designation: ADLO-028285 ¡ 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool) Total Depth measured true vertical 10180 < feet 9171, feet Plugs (measured) Junk (measured) None None Effective Depth measured 10095 feet true vertical 9099 ( feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 31' - 111' 31' - 111' 1490 470 Surface 2639' 13-3/8" 72# L-80 30' - 2669' 30' - 2669' 5380 2670 Production 6874' 9-5/8" 47# L-80 29' - 6903' 29' - 6204' 6870 4760 Liner 2686' 7" 26# L-80 6744' - 9430' 6081' - 8521' 7240 5410 Liner 915' 4-1/2" 12.6# 13CR80 9262' - 10177' 8369' - 9169' 8440 7500 Perforation depth: Measured depth: 9966'-10016' True Vertical depth: 8990'-9032' - - ~~EO MAR 1 (i 2007 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 27' - 9270' Packers and SSSV (type and measured depth) 9-5/8" DV Packer 7" Baker ZXP Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 2544 6752 9215 9269 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 330 308 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 5897 625 0 7008 777 0 15. Well Class after croposed work: Exploratory Development P 16. Well Status after proposed work: Oil ¡;¡ Gas WAG Tubing pressure 182 177 13. Service x Contact Gary Preble WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. !t-St,.;- Signature Title Data Management Engineer Printed Name Phone 564-4944 Date 3/12/2007 ORIGINAL RBDMS 8Ft MAR 1 (; 2nD7 Submit Original Only D-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CTU /Heat diesel pup - Heat diesel pup to 85* for Wells Support hardline crew PT of hardline RU 3/5/2007 CTU #8, Acid Off weather standby @ 15:00, wait for to rig up and pressure test. Call for LRS to heat diesel for pressure testing. Pressure test ground iron. Cant' on WSR 3/06/07 ... 3/6/2007 CTU #8, Acid Stim; Cant' from WSR 3/05/07... Finish pressure testing of rig up. Wait for pump truck from Schlumberger. Bleed down lAP. Load well with 110 bbls NH4CL followed by 120 bbls diesel. Pump 65 bbls of 50/50 Diesel/ylene. Pump 76 bbls of 12 % HCI with 10% L066.0.5% A261, 4ppt A 179, 8 ppt A153, 20 ppt L58, 0.2& F103, 0.5% W54, 0.2% W60. Continued on 03/07/07 3/7/2007 CTU #8, Acid Stim; Cant' from WSR 3/06/07. Pump 76 bbls of 12 % HCI with 10% L066.0.5% A261, 4ppt A179, 8 ppt A153, 20 ppt L58, 0.2& F103, 0.5% W54, 0.2% W60. Got differentially stuck, Worked free and finished pumping job, Final injection rate going down backside was 4.2 bpm @ 2050 psi =12.1 % HCL, IRON <22 pm ed acid, 6 hour soak, well with AL 3/7/20 FLUIDS PUMPED BBLS 110 NH4CL 120 DIESEL 65 50/50 DIESEUZYLENE 76 12% HCI WITH 10% L066.6.5% A261 371 TOTAL P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): /p¿ 7)/()/~ a STATE OF ALASKA A AlA~ Oil AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS JUL 0 6 2006 o Stimulate 0 Other 0 . o WaiverD A~OO.~ Gons. (;orrvT\Isslon o Re-enter Suspended WeAfiChora e 5. Permit to Drill Number: 202-1230 6. API Number: 50-029-20372-01-00 9. Well Name and Number: RECEIVED 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development R1 Stratigraphic D Exploratory Service 74.54 KB D-08A ADL-028285 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool 8. Property Designation: Total Depth measured 10180 feet Plugs (measured) None true vertical 9171.24 feet Junk (measured) None Effective Depth measured 10095 feet true vertical 9099.4 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 31 - 111 31 - 111 1490 470 Surface 2639 13-3/8" 72# L-80 30 - 2669 30 - 2668.95 5380 2670 Production 6874 9-518" 47# L-80 29 - 6903 29 - 6203.52 6870 4760 Liner 2686 7" 26# L-80 6744 - 9430 6081.47 - 8521.38 7240 5410 Liner 915 4-1/2" 12.6# 13CR80 9262 - 10177 8368.76 - 9168.7 8440 7500 Perforation depth: Measured depth: 9966 - 9980 True Vertical depth: 8989.8 - 9001.72 9996 - 10016 9015.34 - 9032.35 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 27 - 9270 Packers and SSSV (type and measured depth) 9-5/8" DV Packer 7" Baker ZXP Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 2544 6744 9214 9262 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8FL JUL I 1 20D6 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 8369 322 700 8379 440 700 15. Well Class after proposed work: Exploratory Development R1 16. Well Status after proposed work: Oil R1 Gas WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 493 508 Tubing pressure 174 177 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service x WDSPl Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Title Data Mgmt Engr Signatu Phone 564-4424 Date 6/28/2006 Form 10-404 Revised 04/2004 Submit Original Only ~ e e D-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 130 Meth 110 Diesel 370 2% KCL 72 50/50 Diesel/xylene 60 Safe lube 742 TOTAL I ACTIVITYDA TE I SCfMMARf' 4/16/2006 T/I/O=180/1110/700. Temp=90*. TIFL PASSED, (pre-acid) ETA 4/22. InitiallA FL @ 6693' (sta 4)(SO)(358 bbls). Stacked out TBG from 180 psi to 1400 psi in 1.5 hours. Bled lAP from 1430 psi to 450 psi in 2 hours. No change in IA FL during IA bleed, TP increased 260 psi. Monitored for 1 hour, lAP and IA FL remained unchanged, TP increased 20 psi. Final WHP's=1680/450/680. (Note: NL SI @ IA gate valve with 1910 psi and no indications of leaking by, FO notified OK to POP). 4/26/2006 MIRU CTU #5. Shut in lift gas keep well flowing till ready to PT Surface equipment. PT to 4000 psi Close wing & start bleeding IA to tiger tank RIH w. 2.125" JSN kill well while running hole. Pump 60 bbls Safe Lube cocktail to prep well bore for CT intervention. Washed perf interval from 9966'-10016' w. 72 bbls diesel xylene. Soak for 1 hour, jet across perfs riciping. Wash perfs with 50 bbls 12% DAD Acid and over flush to formation w/ 100 blls of 2% KCL. POOH. POP through ASRC test unit. RDMO. *** Job Complete*** 4/29/2006 ASRC Well Test (post acid flowback) 250.7 bopd 76.8% W/C .033 mmscf/d 3.20 mm G/L 133 GOR 176 beans e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ¡ ~ A-\ j'\J~ u, DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021230 Well Name/No. PRUDHOE BAY UNIT D-08A Operator BP EXPLORATION (ALASKA) INC ~)rl ~'- tL À q J(M .kt~ '1 API No. 50-029-20372-01-00 MD 10180-"' TVD 9171,/ Completion Date 7/15/2002'-~ UIC N ---- REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ,-------- : Rpt LlSVerification ~. 0 c.Dif'êctional Survey ¡ I I I I I ¡ i , Rpt ~/C Directional Survey 1~'Gamma Ray ~~J) I I i I I I ):~ u¡\ED 1=0 LfD ~LlS Verificáti(l" C Asc j11743 LIS Verification C Pdf 11743 Rate of Penetration C Pdf 11743 Induction/Resistivity C Pdf 11743 Density C Pdf 11743 Neutron -- Well Cores/Samples Information: Name Completion Status 1-01L Current Status 1-01L Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received Comments 6582 10135 Case 2/18/2003 6803 1 0180 Open 8/1/2002 ~ A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 6/11/2002. 6803 1 0180 Open 8/1/2002 5680 10066 Case 10/1/2002 Also includes digital data of the Casing Collar Log 6582 1 0135 ~ 2/18/2003 ~ò An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 6/11/2002. -~-'"" 2-3 68710 1 0180 25 2-3 6903 10180 Open ROP, DGR, EWR 25 2-3 6903 10180 Open ROP, DGR, EWR 25 1-3 6903 10180 Open DGR, SLD, CTN 25 1-3 6903 10180 Open DGR, SLD, CTN Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021230 MD 10180 Well Name/No. PRUDHOE BAY UNIT D-08A Operator BP EXPLORATION (ALASKA) INC TVD 9171 Completion Date 7/15/2002 Current Status 1-01L Completion Status 1-01L Well Cored? ADDITIONAL INFORMATION Y~ Daily History Received? ~N QxN Chips Received? ~¥-1-N- Analysis Received? - Comments: Formation Tops Y/N L~ Compliance Reviewed By: Date: API No. 50-029-20372-01-00 UIC N '- I~ ~ ~'1 ~~ ) STATE OF ALASKA } ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D ,,' Operation Shutdown 0 Perforate D 4. Current Well Class: Stimulate ŒI OtherD WaiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1230 Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 74.54 8. Property Designation: ADL-0028285 11. Present Well Condition Summary: Total Depth measured 10180 feet true vertical 9171.2 feet Effective Depth measured 10095 feet true vertical 9099.4 feet Casing Length Size Conductor 80 20" 91.5# H-40 Liner 2684 7" 26# L-80 Liner 915 4-1/2" 12.6# L-80 Production 6874 9-5/8" 47# L-80 Surface 2639 13-3/8" 72# L-80 Perforation delJth: Measured depth: 9966 - 9980,9996 -10016 True vertical depth: 8989.8 - 9001.72, 9015.34 - 9032.35 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 Development [!] Stratigraphic D 9. Well Name and Number: D-08A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory D Service D 6. API Number 50-029-20372-01-00 Plugs (measured) Junk (measured) None None MD TVD 31 111 31.0 111.0 6744 - 9428 6081.5 - 8519.6 9262 - 10177 8368.8 - 9168.7 29 - 6903 29.0 - 6203.5 30 - 2669 30.0 - 2669.0 Burst Collapse 470 5410 7500 4760 2670 1490 7240 8430 6870 4930 @ 27 I?~C~¡fA ' 9272 ¡J¡ f. 1:2D Aß ':..;1., " ""?/~lttL 'j f) ~'Ol&Ges ., ,P171- ~~,. ~ ~¡~ Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 7" Baker ZXP Liner Top Packer 9-5/8" DV Packer Daily Report of Well Operations" ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature ß~. (~a;t¿1Y\ Form 1 0-404 Revise~ 4/2004 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl 489 717 14. Attachments: Copies of Logs and Surveys run- @ 9215 @ 9269 @ 6752 @ 2544 Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 2.2 193 625 Tubing Pressure 190 181 3.6 904 1100 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] Service 0 16. Well Status after proposed work: Oil [!] Gas D WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Phone 564-4657 ~é.. é1~.. '~', 81;~/W'1 ~\ut, J, ~..,-,.j -~:~~¡ ,~~~~~ç :.:,-~ ) ) D-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/17/04 ACID TREATMENT I CTU #8. MIRU. SHUT IN WELL AND AIL. BLEED IA DOWN AND FLUID PACK WITH CRUDE. RIH WI 2.3311 JSN. TAG INITIALLY AT 9685' CTM. WORKED DOWN THRU SCALE BRIDGES TO 9696". PUMPED 50 BBLS 12% * 10% DAD ACID. TRIED BULLHEADING AND JETTING TAKING RETURNS. GOT DOWN TO 97801 CTM. TOP PERF AT 99661. UNABLE TO GET DEEPER AND INJECTIVITY WAS.1 BPM @ 2000 PSI WHP. IA AND TUBING PRESSURES TRACKING. KEEP 1900 PSI WHP WHILE POOH AND FILLING VOID. DID NOT SEE ANY BREAKS. FREEZE PROTECT COIL WITH 60/40. RDMO. PUT WELL BACK ON PRODUCTION WI AIL. NOTIFY PCC AND REQUEST WELL TEST IN 24 HRS. **COIL UNIT UNAVAILABLE UNTIL TUESDAY. WILL RETURN THEN TO RUN MOTOR AND MILL.** 04/29/04 (WELL FLOWING ON ARRIVAL). DRIFT WI 3.60 CENT & 3.50 LIB TO 198' SLM ( TOOLS COVERED IN PARRAFIN NEEDS BRUSH & FLUSH). DRIFT WI 3.60 G-RING & 4 1/2" BLB TO 90941 SLM. DRIFT WI 2.25 CENT & SAMPLE BAILER TAG @ 97751 SLM- MfT BAILER. DRIFT WI 2.50 CENT & 2.25 LIB TAG @ 97751 SLM ( LIB SHOWS HARD SCALE ON FACE OF LIB). PERFS @ 9966-100161. *** GAVE WELL BACK TO PAD OP HE WILL POP ***. 05/23/04 RIH WI WEATHERFORD 2-7/8" MOTOR & 3.70" THREE BLADE JUNK MILL. TAG @ 88421 CTM. WITH WELL FLOWING ON GASLlFT, MILL FROM 88421 TO 92801 CTM @ AN AVERAGE OF 1.5 FPM WI STALLS EVERY 10 -15'. (MILLED TOTAL OF 4401 OF HARD SCALE, 7701 LEFT TO MILL.) FLO-PRO SWEEP OFF BOTTOM, POOH TO OGLV AT 800/0. LDFN. WELL LEFT FLOWING. 05/24/04 CONTINUE FROM 5123104: RIH WI NEW WEATHERFORD 2-71811 MOTOR AND 3.70" CHOMPES MILL. MAKE GOOD PROGRESS FROM 9284 TO 93031, THEN BIT SEEMED TO DULL. WORK DOWN TO 93211 (REPEATED STALLS). POOH TO CHANGE BITS. RIH WI 3.625" SIX BLADE CONCAVE JUNK MILL. AVERAGE 2.3 FPM WITH SIX BLADE MILL. MILL TO 95401 WI SUBSTANTIAL BREAKTHRU TO 97691. CONTINUE MILLING TO FINAL DEPTH OF 97761 (MILLED -500' FOR THE DAY). FLO-PRO SWEEP OFF BTM CHASED BACK TO OGLV AT 80%. LDFN. WELL LEFT FLOWING. 05/25/04 CONTINUED FROM 05/24/04: RIH WI WEATHERFORD 2-7/811 MOTOR & 3.62511 CONCAVE SIX BLADE JUNK MILL. WELL FLOWING ON GASLlFT. START MILLING AT 9777' CTM, MILL THRU EXTREMELY HARD SCALE TO 9947' (1701 MILLED TODAY). 201 MORE TO MILL TO TOP SET OF PERFS....WILL CONTINUE IN THE AM AFTER RIG MOVE PASSES LOCATION. WELL LEFT FLOWING ON GASLlFT. 05/26/04 JOB CONTINUED FROM 05/25/04: RESPOT EQUIPMENT SO RIG CAN PASS. MAKEUP NEW WEATHERFORD 2-7/811 MOTOR. RIH WI NEW 3.5" STEP MILL WI CARBIDE BOTTONS (SMOOTH ON OD). FIND SCALE AT 9948" HARD MILLING (0.5 FPM) TO 99781 CTM, THEN BREAKTHRU AND RUN FREE TO 100501 (STOP). FLO-PRO SWEEP OFF BOTTOM & POOH @ 80% WI WELL FLOWING ON GASLlFT. SII WELL, RIH WI 2.45" JSN AND TREAT SCALE INTERVAL WITH DIESEL I XYLENE (PRE ACID). LOAD IA WI 1 % KCL (100 BBLS) AND CRUDE (270 BBLS). CIRC OUT DIESEUXYLENE AND KILL WELL WI 150 BBLS 2% KCL (CT ANNULAR VOLUME). SII RETURNS. TREAT PERFS WI 52 BBLS 12% DAD ACID. INJECTIVITY PRE ACID OF 390 PSI @ 2 BPM & POST ACID OF 510 PSI @ 2.3 BPM. OVERDISPLACE WI 100 BBLS 2% KCL. POOH & POP. REQUESTED TEST IN 48 HOURS. Page 1 BBLS 87 610 581 44 780 220 72 3021 60 52 5527 ) D-OBA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED 60/40 Methanal Crude 20/0 KCL 12-10 DAD Acid 2% XS KCL 50/50 Methanal Fla-Pro XS 1 % KCL Diesel/Xylene 120/0 DAD Acid TOTAL Page 2 ) ') TREE = WELLHEA D = 'A'CTÜÁ'fÖR';;;'m' 'kääEV"';""''''m "Sï=:'ËiEVm;'... 'köÞ";;"""""'''''' "'m ............,.."".. . ........... ,~~,,~~,!i1I~_,==, ,m Datum rvÐ = DatumTVD = 4"CIW MCBI OY """'BÄ'kER '...mj4~'t'V ""'44:84ï "'''''''69ïjöï' ......,n ..... ...m......... """~,?,,~,,.,?~.9.~":. 9831' 8800'SS 113-318" CSG, 72#, L-80, ID = 2.347" 1-1 2669' Minimum ID = 3.725" @ 9259' 4.1/2" H ES XN NIPPLE 9-5/8" X 7" BKR ZXPLNR TOPPKR -I 6744' W/TIEBAO< SLY, ID= 6.250" ITOPOFWHIPSTOO< 1-1 6903' 1 CIBP 1-1 6920' I TOP OF CEMENT 1,8700' CTM 19-5/8" X4-1/2"BKRPERMPKR, ID=4.75" 1-1 8714' 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9483' ÆRFORA TON SUMMARY REFLOG:G~CCLONO~1&02 ANGLE AT TOP PERF: 32 @ 9966' Note: Refer to Production DB for historical perf da SIZE SA= NTERVAL Opn/Sqz DA 3-3/8" 6 9966 - 9980 0 08/31 3-3/8" 6 9996- 10016 0 07/15 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 10570 DATE 02/26190 07/07/02 08/31/02 01/23/03 06/01/03 07/04/03 COMWENTS ORIGINAL COMPLETION DAV/KK RIG SlDErRACK CWS ADD PERF JKffP GLM CORRECTIONS TO KBG-2 rv\<\ HffLP PERF CORREC110N CMOffLP KB ELEVA TON & rv\<\XANGLE REV BY D-08A = ..!. L ) I SAÆTYNOTES: 4-1/2" CHROMELNR. ~ 2212' 1-14-112" I-ES X LANDING NIP, ID = 3.813" 1 2544' 1-19-518" rN A<R I j II I x x ~x ~ ~ I ~ ( ~ < i! ~ ~ w. ('"' '- 1 "ex < ~ ::: < c: < ~ < - c < c < .:: < ta TE L ~ /02 ... /02 ç,.., .¡ c < c: < ... < 0 c: < c: 1( ..7 .. ' .-;:): ~ ST rvÐ 6 3450 5 4276 4 6693 3 7602 2 8385 1 9125 GAS LIFT MANDRELS TVD DBI TYPE VL V LATCH 3027 9 MM3M OOME RK 3800 30 MM3M DI\t1Y RK 5976 40 MM3M SO RK 6750 13 KBG-2 DI\t1Y BK 7503 24 KBG-2 DI\t1Y BK 8188 24 KBG-2 DI\t1Y BK PORT DA. TE 16 07/06/02 0 07/06/02 20 07/08/04 0 07/06/02 0 07/06/02 0 07/06/02 MILLOUTWINDOW 6903'- 6919' . 9194' 1-14-1/2"011S X NIP, ID= 3.813" I 9214' 1-17" X4-1/2" BKR &3 A<R, ID= 3.875" 1-14-1/2" HES X NP, ID = 3.813" 1 9259' H4-1/2" I-ES XN NIP,ID =3.725"1 9271' 1-14-112" WLEG, D =3.958" 1 9262' 1-7" X 5" BKRZXPLNR TOP A<R, ID = 4.391" 1- 7" CSG, 26# L-80, ID = 6.276" ~ 4-1/2" LNR, 12.6# -1 9270' 13-CR-80, .0152 bpf, ID = 3.958" I 10095' I-iPBTD 4-112" LNR, 12.6#, 13-CR-80, -1 10177' .0152 bpf,lD =3.958" DATE REV BY COM'v1ENTS 09/16/03 CMO/TLP ()A. TUM MD'TVD, ÆRF ANGLE 02/13/04 ROYITLH XN NlPFLE CORRECTION 07/08/04 JLVKAK GLV C/O PRUŒiOE BAY UNIT WB..L: D-08A ÆRMT No: 2021230 API No: 50-029-20372-01 SEC23, T11N, R13E1067' WEL& 1910' NSL BP Exploration (Alaska) ') ) áD a - I d.-3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage, Alaska 99501 May 08, 2003 RE:MWD Formation Evaluation Logs: D-08A, AK-MW-22 I 05 D-08A: Digital Log Images 50-029-20372-01 1 CD Rom 1114 3 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ,Anchorage, Alaska 99518 BP Exploration ( Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: (0 . , D . (J3 Signedl2~1h- 6~ ~~ r= C;;:: 'Vt:.', D" ""'= v LI f;; MAY 13 2003 I'\ì¿;¡~r.a Uiï & i ~~s Con'" f'^, va is. vv~ AnChorage -."'~ ) ') ~Da-/~3 I 15/( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 3 33 West 7t11 Avenue, Suite 100 Anchorage, Alaska February 17, 2003 RE: MWD Formation Evaluation Logs D-08~ AK-MW-22105 1 LDWG fonnatted Disc with verification listing. PùPI#: 50-029-20372-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 HP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: si4,~ fÞ~ E""..: C'~;ç: j \ 1 ~, f1 ~ -, 2....~~. "if ~.,.., ,'''''' FF"B (. ('\ ì~,- 1 ({ "f;', J" ... v .:...l'... '..I AJaata O:i & Gas GJiìS. Gomm¡~vði-on Anch~Je 10-407, D-08A, PermH #202-123 ) ) Subject: 10-407, D-08A, Permit #202-123 Date: Wed, 23 Oct 2002 17:50:19 -0500 From: "Hubble, Terrie L" <HubbleTL@BP.com> To: "McMains, Steve (AOGCC) (E-mail)..<Steve_McMains@admin.state.ak.us> Hi Steve, We have found an error in the top perf depth for this well. The information in box 24 of the 10-407 should read: MD 9996 I - 10016' TVD 9015 I - 9032 I will it be sufficient for you to just pencil in this change? Thanks! Terrie Hubble GPB Drilling & Wells 564-4628, MB7-5, Cube 718 ~~ :\~~ 09/30/02 Schlumberger NO. 2449 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job# Log Description Date Blueline Sepia Prints CD ~./ MPS-11 ~Qd. - J ~ 22443 SCMT (PDC) 07/01/02 1 ~PS-13 ~O d-JJLj 22444 SCMT (PDC) 07/02/02 1 D-08A atJ~-};:). ~ 22434 GRlCCL (PDC) 07/15/02 1 D-17B ~f€f- J 11 22433 GRlCCL (PDC) 07/12/02 1 D.S. 14-33 ~- / d S 22386 RST -SIGMA 07/21/02 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 -"---D . Dale Delivered: ~ ~ (Å OCb~ Schlumberger GeoQuest 3940 Arctic Blvd I Suite 300 Anchorage, AK 99503-5711 ATTN: Beth RECEIVED Received by: OCT 0 1 2002 AIIIke Oil & Gal Cons. CommIUlJA* Anchcøge \) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well iii Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L~~:g~~~L~~~~~ ~~~~~EC. 23, T11N, R13E, UM rëò¡;J~!~:¡ô~j'lJOCÅ~f~ At top of productive interval ~7' /$"éfZ-~,..~EflI" ' ~; 4368' SNL, 2528' WEL, SEC. 23, T11N, R13E, UM ~ " flED ~ ~ '.'. ~ At total depth ~ t> ~ ~ ~~~y~ 4224' SNL, 2436' WEL, SEC. 23, T11N, R13E, UM '~~:.-¡ l~:^~ 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 74.54' ADL 028285 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6/29/2002 7/4/2002 7/15/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MO+TVO) 19. Directional Survey 10180 9171 FT 10095 9100 FT iii Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, DEN, NEU 23. CASING SIZE 2011 X 3011 13-3/811 9-5/8" 7" 4-1/2" Classification of Service Well 7. Permit Number 202-123 8. API Number 50- 029-20372-01 9. Unit or Lease Name Prudhoe Bay Unit 1 O. Well Number D-08A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2212' MD 1900' (Approx.) WT. PER FT. Insulated 72# 47# 26# 12.6# GRADE Conductor L-80 L-80 L-80 13Cr80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 36" 14 cu yds Arcticset concrete Surface 2669' 17-1/2" 4506 cu ft Permafrost II Surface 6903' 12-1/4" 1323 cu ft Class 'G', 130 cu ft PF 'C' 6744' 9430' 8-1/2" 556 cu ft Class 'G' 9262' 10177' 6-1/8" 146 cu ft Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/811 Gun Diameter, 6 spf MD TVD '~~' '9007' 90~2' q 1q£o~ \ OO(Jo C¡G g;- 903 ~ S~ ~ $J,t/ £. /W1M1] 25. SIZE 4-1/2", 12.6#, 13Cr80 MD TVD 26. AMOUNT PUllED TUBING RECORD DEPTH SET (MD) 9272' PACKER SET (MD) 9215' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected w/ 155 Bbls of Diesel 27. Date First Production July 15, 2002 Date of Test Hours Tested 7/25/2002 3 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR Oll-BBl TEST PERIOD 102 GAs-McF 2493 GAs-McF WATER-BBl 168 WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-BBl CHOKE SIZE 960 OIL GRAVITY-API (CORR) 25.7 GAS-Oil RATIO 24,512 28. CORE DATA {' - '; \ '\ I Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core c1i(is~¡'~' ,\, ~""~, \;" ~t "~,,~ "C .", -- No core samples were taken. ,'v'''or'' !J~aslca on ð{ t¡à~; {;OdS. L;miHYIISS¡':.h Anchoraç8 . ~ lln~G!¡'¡ 1\ L b ./ i'\ ! J ! I \i f-\ R B D M S B FL AUG I 3 20~ubmitln Duplicate Form 10-407 Rev. 07-01-80 ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Sag River 9424' 8516' Shublik A 9457' 8546' Shublik B 9500' 8584' Shublik C 9517 8600' Sadlerochit 9552' 8631' Zone 3 9755' 8810' Zone 2C 9856' 8896' T23SB 99591 8984' T22TS 9990' 9010' HOT 10021' 9037' T21TS 10049' 9060' Zone 1 B 10130' 9129' ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. IF M,"" ~~::: ~ (!'riI<~ ¡t", iì I,) !ii,\îa,;lta ri!a & LDmlii¡~SS¡Üt; , l\nctmragø Summary of Daily Drilling Reports and Post-Rig Work, Surveys, Leak-Off Test Summary 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~JJÙ..t , ~ J ~ Title Technical Assistant D-08A 202-123 Well Number Permit No. / Approval No. INSTRUCTIONS Date 08"o9.o~ Prepared By NameINumber: Terrie Hubble, 564-4628 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinentto such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 ("'~ t-~, I~ l'''t ~ f:\ I , f I. ,t, Ii ;""'; Legal Name: 0-08 Common Name: 0-08 Test Date 6/28/2002 7/3/2002 FIT FIT Test Type Test Depth (TMD) 6,903.0 (ft) 9,430.0 (ft) BPEXPLORATION Leak-Qff'.Test.".SUI11rnary Test Depth'(TVD) 6,201.0 (ft) 8,518.0 (ft) AMW 9.80 (ppg) 8.40 (ppg) SUrfácePl"essure 870 (psi) 710 (psi) Leákpff pressure (BHP) 4,027 (psi) 4,427 (psi) EMW 12.50 (ppg) 10.00 (ppg) '~ '--- Printed: 7/10/2002 12:22:52 PM ') ) , BP EXPLORATION Operations. Summary 'Report Page.1 Öf,10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-08 0-08 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Spud Date: 10/19/1979 End: 7/7/2002 Date From ,-" Tö Hours Task Code NPT Phase Description of Operations 6/25/2002 04:00 - 15:00 11.00 MOB P DECOMP Turnkey rig move. Mob rig & camp from 0-17 B to D-08A. Wait on DSM to install BPV, 1 hour; Accept rig at 14:00 hours on 6/25/02 15:00 - 15:30 0.50 RIGU P DECOMP Pre Spud meeting. 15:30 - 22:00 6.50 RIGU P DECOMP Take on seawater. Install second annulus valve. RU DSM. Pull BPV. Set TWC. Test TWC from below to 1000 psi. NO Tree. Check LOS. Inspect threads in tubing hanger and screw in Landing Jt X/O 8.5 turns. Back out X/O. NU BOP stack. 22:00 - 00:00 2.00 RIGU P DECOMP Test BOPE to 250 psi 1 low & 3500 psi 1 high for 5 min each test. Test waived by AOGCC John Crisp. 6/26/2002 00:00 - 04:00 4.00 RIGU P DECOMP Finish BOPE Test. Stack, Top Drive, Choke manifold, Stand pipe manifold, & floor valves to 250 psi low 1 5 min, 3500 psi high 1 5 min. Had trouble with blinds. Wash debris from blinds and then tested. 04:00 - 07:00 3.00 PULL P DECOMP RU DSM. Attempt to pull TWC without success. Flush top of TWC with DP. Redress retrieving tools. Pull TWC. RD DSM. 07:00 - 08:00 1.00 PULL P DECOMP PU Hanger pulling jt. BOLDS. Pull hanger to rig floor. No over pull. String wt = 104 K. 08:00 - 09:00 1.00 PULL P DECOMP Circulate around Barascrub pill @ 13 bpm, 440 psi. 09:00 - 09:30 0.50 PULL P DECOMP LD Tubing hanger. 09:30 - 10:00 0.50 PULL P DECOMP RU 4.5" tubing equipment & control line equipment. 10:00 - 17:30 7.50 PULL P DECOMP POOH with 4.5" completion string. Recovered all 27 control line clamps. SLM tubing (7010'). 17:30 - 18:30 1.00 PULL P DECOMP RD tubing equipment & clear rig floor. 18:30 - 21 :00 2.50 BOPSUR P DECOMP MU test plug and 4" DP jt. Plug leaking. Change out test plug. Test Hydril & bottom pipe rams to 250 psi low 1 5 min & 3500 psi high 1 5 min. Attempt to test blind rams again but test failed. 21 :00 - 23:30 2.50 BOPSUR N DECOMP Change out Blind 1 Shear rams to New Blind rams. Found seal rubber damaged, some 3/8" insert buttons from insert bit on top of rams and upper ram plate scarred. Test blind rams to 250 psi low 1 5 min & 3500 psi high 15 min. 23:30 - 00:00 0.50 BOPSUR N DECOMP Install Wear Bushing. Prepare to PU clean out BHA #1. 6/27/2002 00:00 - 02:30 2.50 CLEAN P DECOMP PU Clean out BHA #1: Mill bit, Lower Mill, Upper Mill, Obi pin XO, Scraper, Bit sub, Bumper Jar, Oil Jar, 9 DC's, 21 HWDP, XO. 02:30 - 03:30 1.00 CLEAN P DECOMP TIH picking up 4" DP from pipe shed. 03:30 - 04:00 0.50 CLEAN P DECOMP H2S Drill & Critique. 04:00 - 07:30 3.50 CLEAN P DECOMP Continue TIH picking up 4" DP to 4.5" Tubing stub. Tag stub @ 7038'. Up Wt = 175 K, Own Wt = 145 K, RTW = 157 K. TQ = 4.5 K. 07:30 - 08:30 1.00 CLEAN P DECOMP Pump high vis sweep around @ 13 bpm, 1500 psi. Flow check. Pump Slug. 08:30 - 11 :00 2.50 CLEAN P DECOMP POOH rack back DP. 11:00 - 12:00 1.00 CLEAN P DECOMP Change out elevators. Stand back BHA #1. LD mills & scraper. Clear Rig floor. 12:00 - 13:00 1.00 CLEAN P DECOMP Service Top Drive. 13:00 -14:00 1.00 CLEAN P DECOMP RU electric line. 14:00 - 16:30 2.50 CLEAN P DECOMP RIH with EZSV. Run correlation log. Set EZSV @ 6920' (ELM). POOH. 16:30 - 17:30 1.00 CLEAN P DECOMP RD Electric line. 17:30 - 18:30 1.00 CLEAN P DECOMP Test casing to 3000 psi against Blind Rams for 30 minutes. 18:30 - 21 :30 3.00 STWHIP P INT1 PU Whipstock BHA #2: Btm Trip, Whipstock, Starter mill, lower Printed: 7/10/2002 12:22:58 PM ') ) BP EXPLORATION Operations Su.mmary' Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-08 0-08 REENTER+COMPLETE NABORS NABORS 2ES Page2of.10 Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Spud Date: 10/19/1979 End: 7/7/2002 Date From - To Hours Task Code NPT Phase Descri ption of, Operations 6/27/2002 18:30 - 21 :30 3.00 STWHIP P 21 :30 - 00:00 2.50 STWHIP P 6/28/2002 00:00 - 01 :00 1.00 STWHIP P 01 :00 - 01 :30 0.50 STWHIP P 01 :30 - 02:30 1.00 STWHIP P 02:30 - 12:00 9.50 STWHIP P 12:00 - 13:30 1.50 STWHIP P INT1 13:30 - 14:00 0.50 STWHIP P INT1 14:00 - 15:30 1.50 STWHIP P INT1 15:30 - 17:30 2.00 STWHIP P INT1 17:30 - 19:30 2.00 STWHIP P INT1 19:30 - 20:30 1.00 DRILL P INT1 20:30 - 23:30 3.00 DRILL P INT1 23:30 - 00:00 0.50 DRILL P INT1 6/29/2002 00:00 - 03:00 3.00 DRILL P INT1 03:00 - 03:30 0.50 DRILL P INT1 03:30 - 00:00 20.50 DRILL P INT1 6/30/2002 00:00 - 03:00 3.00 DRILL P INT1 03:00 - 04:00 1.00 DRILL P INT1 04:00 - 05:00 1.00 DRILL P INT1 05:00 - 06:00 1.00 DRILL P INT1 06:00 - 07:00 1.00 DRILL P INT1 07:00 - 07:30 0.50 DRILL P INT1 07:30 - 00:00 16.50 DRILL P INT1 7/1/2002 00:00 - 01 :00 1.00 DRILL P INT1 INT1 INT1 INT1 INT1 INT1 INT1 mill, upper mill, 1 Jt HWDP, Float sub, MWD, UBHO, Bumper Jar, 9 De's, 21 HWDP, XO. Orient Whipstock with MWD (off set 27 .9 Deg). Initialize MWD. TIH wI Whipstock BHA #2 to 6841'. Up Wt = 165 K, Own Wt = 132 K. Orient whipstock @ 6841'. Up Wt = 175 K, Own Wt = 145 K. Circulate @ 505 gpm, 1630 psi. TIH tag EZSV @ 6924'. Set Whipstock @ 87 deg Right. Shear off whipstock @ 100 K (45 dwn wt). Top @ 6903'. Displace well with 9.8 ppg LSND HT mud system. Mill 8.5" window in 9 5/8" casing 6903' - 6919'. Up Wt = 175 K, Own Wt = 140 K, Rt Wt = 150 K. Rot 95 rpm, TQ = 9.5 K Ibs. 478 gpm, 1930 psi. Initially high Tq @ 15.5 K Ibs, add EZ glide + BDF-263 to reduce Tq. Drill formation f/6919' - 6935'. Top of window @ 6903' MD (6201' TVD), Bottom of window @ 6919'. Work window, circulate sweep around, and condition mud. Recovered 253 Ibs of metal cuttings. Pull into 9 5/8" casing and perform FIT to 12.5 ppg EMW. 870 psi, 6201' TVD, 9.8 ppg MW. Slip & Cut Drill line. Service top drive. Slug DP. Flow check. POOH. Stand back HWDP in Derrick. LD DC's, mills, bit, 1 jt HWDP. PU stabilizer, DC pup jt, mud mtr, & stand back in derrick. Pull wear bushing. Function rams. Circulate through Kill & Choke lines to flush. PU wash tool and flush stack, Flush flow line, possum belly, and shakers. Install wear bushing. PU BHA #3 from derrick. MU Bit. Adjust mtr to 1.5 deg & orient. Initialize MWD. Shallow Test MWD. TIH wI BHA #3: Bit, Mud Mtr, Stabilizer, Pony DC, NM Float Sub, MWD, 3 Flex DC's, 3 HWDP, Jars, 18 HWDP, & XO. Picking up DP from pipe shed to TO hole section. Continue TIH picking up 4" DP from pipe shed to 3573' (87 jts). TIH wI DP stands from derrick to 6838'. Install blower hose. Orient @ 86 deg Right and RIH thru window not pumping. Tag undergauge hole @ 6923'. Window slick. Wash and Ream to TO @ 6935'. Directionally drill fl 6935' - 8075'. Up Wt = 175 K, Own Wt = 150 K, Rt Wt = 165 K. AST:10.4 hr, ART: 4.9 hr, ADT:15.3 hr. ECD = 10.78 ppg. Directionally drill f/8075' - 8242'. Up WT = 190 K, Own Wt = 150 K, Rot Wt = 175 K. Circulate high vis sweep around. Wiper trip to 9 5/8" casing shoe @ 6903'. Hole slick. Service Top Drive. Run Geological correlation log in 9 5/8" casing f/6850' - 6650'. TIH f/6850' - 8242' (TD). Hole slick. Directionally Drill f/8242' - 9375'. Up Wt = 200 K, Own Wt = 160 K, Rt Wt = 175 K. WOB 15 -18 K, ROT = 100 RPM, 200 SPM @ 3500 psi. AST: 5.7 hr, ART: 5.8 hr, ADT: 11.5 hr. Directionally drill f/9375' - 9431'. TO 8.5" hole section. Control drill to check formation top of Sag River. Up Wt = 225 K, Own Wt = 175 K, Rt Wt = 150 K. ECD = 11.0 ppg. Rot = 100 spm, WOB = 10 K, 200 spm @ 3500 psi. AST: 0.4 hr, ART: 0.5 hr. Printed: 7/10/2002 12:22:58 PM ') ') BPEXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-08 D-08 REENTER+COMPLETE NABORS NABORS 2ES Date From - To Hours Task Code NPT Phase 7/1/2002 01 :00 - 03:00 2.00 DRILL P INT1 03:00 - 04:30 1.50 DRILL P INT1 04:30 - 05:00 0.50 DRILL P INT1 05:00 - 06:30 1.50 DRILL P INT1 06:30 - 08:00 1.50 DRILL P INT1 08:00 - 09:00 1.00 DRILL P INT1 09:00 - 11 :00 2.00 DRILL P INT1 11 :00 - 15:00 4.00 DRILL P INT1 15:00 - 16:30 1.50 DRILL P INT1 16:30 - 17:00 0.50 DRILL P INT1 17:00 - 18:00 1.00 DRILL P INT1 18:00 - 20:30 2.50 CASE P INT1 20:30 - 21 :00 21 :00 - 00:00 0.50 CASE P 3.00 CASE P INT1 INT1 7/2/2002 00:00 - 01 :30 LNR1 1.50 CASE P 01 :30 - 02:30 1.00 CASE P LNR1 02:30 - 05:30 3.00 CASE P LNR1 05:30 - 06:00 0.50 CASE P LNR1 06:00 - 07:00 1.00 CASE P LNR1 07:00 - 09:30 2.50 CASE P LNR1 Page 3 of 10 Spud Date: 10/19/1979 End: 7/7/2002 Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Description of Operations Circulate bottoms up for sample. Geologist confirm top of Sag River. Circulate weighted high vis sweep around. Wiper trip to 9 5/8" casing shoe @ 6903'. Minimal over pull during trip to +1- 25 K over pulling wt. @ 7270', 7230', 6971'. Service Top Drive. TIH. Tag up @n 8930'. Wash through didn't see anything. 5' fill on bottom. Circulate and condition mud. Pump weighted sweep around. Wiper trip to 8520'. Hole slick. Circulate and condition mud. Pump High vis sweep around and spot liner running pill. Drop ESS with 2.50" drift. POOH for 7" liner to 6853'. SLM. ESS check shots @ 9108', 9014', & 8734'. Hole slick. Flow check. Slug pipe. Finish POOH to BHA. LD BHA #3. Down load MWD data. Finish LD BHA #3. Clear Rig Floor. Pull Wear Bushing. Change out upper pipe rams to 7". PU test jt and install test plug. Test Upper Rams to 250 psi low 15 min & 3500 psi high I 5 min. RD test equipment. Install wear bushing. PJSM with all personnel. RU to run 7" liner. MU 7" shoe track. Baker-Lok. Check floats. TIH with 7", 26 #/ft, L-80, BTC-M Liner. Held PJSM. M I U and RIH wI 66 Joints 7" 26# BTC L-80 Liner. M I U Torque 7,500 ftIIbs. Filled Liner every 5 Joints. Baker Locked First 3 Joints. Float Shoe on Pin end of Jt #1, Float Collar on Pin end of Jt #2, Insert Landing Collar at Pin end of Jt #3. Total Length of Liner 2,663.09'. M I U Baker HMC Liner Hanger ZXP Liner Packer and C2 Running Tool to Liner. R I U Circulating Head and Lines. Circulated Liner Volume, 103 bbls. Pump Rate 7 bpm, 350 psi. R I U 4" Handling Equipment. RIH wI 7" Liner on 4" DP to 6,891', Filled DP every 10 Stands. Note: High Winds 50 - 65 MPH. R I U Circulating Head and Lines. Circulated DP and Liner Volume, 145 bbls. Pump Rate 7 bpm, 1,000 psi. RIH wI 7" Liner on 4" DP from 6,891' to 9,431', Filled DP every 10 Stands. M I U Cement Manifold, Slowly Broke Circulation. Pump Rate 3 BPM, SPP 450 psi. Washed Down Liner as a Precaution. Circulated while Reciprocating Liner. Circulated to Cool and Clean Hole. Pump Rate 7 BPM, SPP 1,000 psi. 7" Liner Assembly Set As Follows: ITEM LENGTH Float Shoe 1.65' 1 Jt 7" 26# BTC Liner 39.74' Float Collar 1.00' Landing Collar Insert 65 Jts 7" 26# BTC Liner 2,620.70' HMC Liner Hanger 9.18' ZXP Liner Packer 6.06' Liner Tie Back Sleeve 7.61' DEPTH 9,430.00' 9,388.61 ' 9,387.61 ' 9,346.00' 6,766.91 ' 6,757.73' 6,751.67' 6,744.06' Printed: 7/10/2002 12:22:58 PM ') ') EXPLORATION Summary Report Legal Well Name: 0-08 Common Well Name: 0-08 Event Name: REENTER+COMPLETE Contractor Name: NABORS Rig Name: NABORS 2ES Date From - To Hours Task Code NPT Phase Description of Operations 7/2/2002 09:30 - 11 :00 1.50 CEMT P LNR1 Held PJSM wI Rig Crew, Halliburton, Baker and Peak Truck Drivers. Shut Down Rig Pumps and Switched over to Halliburton. Pumped 5 bbls of Water to flush lines. Shut in Cement Manifold and Tested Lines to 4,000 psi, OK. Pumped 50 bbls of Alpha Spacer at 5.5 bpm, 1,100 psi. Pumped 100 bbls (488 sx) 15.8 ppg Premium Cement wI 0.35% bwoc HALAD-344, 0.20% bwoc CFR-3, 0.15% bwoc HR-5. Pumped Cement at the Following Rates: Pumped Rate Pressure 25.0 bbls 5.70 bpm 1,090 psi 50.0 bbls 5.70 bpm 1,260 psi 75.0 bbls 4.30 bpm 800 psi 100.0 bbls 4.10 bpm 755 psi Cleaned up and Flushed Cement Lines. Switched to Rig Pumps, Dropped DP Dart and Displaced wI 166 bbls of Mud at the Following Rates: Pumped Rate Pressure 30.0 bbls 9.25 bpm 600 psi 80.0 bbls 7.00 bpm 800 psi 140.0 bbls 7.00 bpm 2,000 psi 166.0 bbls 3.25 bpm 1,500 psi Pressured up to 3,000 psi to Bump Plug. Cement in Place @ 1100 Hrs. 11 :00 - 11 :30 0.50 CEMT P LNR1 Increased Pressure to 4,500 psi to Set Baker Liner Hanger. Set Down 30,000# to Confirm Hanger Set. Released Pressure and Checked Floats, Floats Held. Released Halliburton, Switched back to Rig Pumps. Rotated Drill String 20 Turns to Release Running Tool from Liner. Pressured up on Liner to 1,000 psi. Picked up on Drill String, Pressure dropped to 0 psi, indicating Running Tool Released from Liner. Pumped 25 bbls at 6 bpm to Contaminate Cement and Move Cement Up Hole. Set Down 45,000# on Liner Hanger and Set ZXP Packer. Spudded on ZXP Packer wI 45,000# Twice to Ensure Packer Set. 11 :30 - 13:30 2.00 CEMT P LNR1 Circulated Bottoms up to Clear Hole of Excess Cement. Pump Rate 12 bpm, SPP 2,300 psi. Circulated back 15 bbls of Cement. 13:30 - 14:00 0.50 CEMT P LNR1 Broke out and LID Cement Manifold and Lines. Flushed Flow Line and Possum Belly. 14:00 - 14:30 0.50 CEMT P LNR1 POOH wI 5" DP to 5,785'. String Wet. 14:30 - 16:00 1.50 CEMT P LNR1 Held PJSM. Slipped and Cut Drilling Line, Adjusted Brakes. Serviced Top Drive. 16:00 - 17:30 1.50 CEMT P LNR1 POOH wI 5" DP. 17:30 - 18:00 0.50 CEMT P LNR1 Broke Out and LID Liner Running Tool. Printed: 7/10/2002 12:22:58 PM Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Spud Date: 10/19/1979 End: 7/7/2002 ) ".) BP EXPLORATION Operations Surrlmary Réport Page 50f1 0 LegalWell Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-08 0-08 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Spud Date: 10/19/1979 End: 7/7/2002 Date From.. To Hours Task Code NPT Phase Description of Operations 7/2/2002 18:00 - 19:00 1.00 BOPSUR P PROD1 Held PJSM. Changed out Top 7" Rams to 3-1/2" x 6" Variable Rams. 19:00 - 19:30 0.50 BOPSUR P PROD1 Held PJSM. M I U Retrieving Tool. Pulled Wear Bushing, Set Test Plug. 19:30 - 22:00 2.50 BOPSUR P PROD1 Tested BOPE. Tested Upper and Lower Pipe Rams, Blind Rams, Annular Preventer, Valves, HCR, Kill Line, Choke Line to 3,500 psi High I 250 psi Low. Choke Manifold was Pressure Tested While Tripping out of the Hole. Manifold was Tested to 3,500 psi High 1250 psi Low. All Tests Held f/5 Min. All Pressure Tests Held wI No Leaks or Pressure Loss. Jeff Jones wI AOGCC Waived Witnessing Test. 22:00 - 22:30 0.50 BOPSUR P PROD1 Pulled Test Plug, Ran and Set Wear Bushing. 22:30 - 00:00 1.50 DRILL P PROD1 Held PJSM. M I U SMITH 6-1/8" XR20 Bit, Ser# L Y8105, to Sperry's 4.75" SperryDrill Lobe 7/8 2.0 Stg Mud Motor. Set Pad Offset and Bent Housing to 1.15 deg. M I U MWD Tools and Oriented to Motor. M I U Pulsers and Inserted into MWD. 7/3/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Held PJSM. Finished Loading Pulsers into MWD. Downloaded Data into MWD Memory. Lowered MWD through Rotary Table. Broke Circulation and Tested MWD. Pump Rate 250 gpm, 500 psi, Good Pulse. 01 :30 - 03:00 1.50 DRILL P PROD1 Held PJSM. Cleared Rig Floor, Sperry MWD Hands Loaded Radioactive Sources into Tools. Lowered Tools through Rotary Table below BOP stack. Finished M I U Directional BHA. 03:00 - 03:30 0.50 DRILL P PROD1 RIH wI 6-1/8" Directional BHA, PI U 15 joints of 4" DP from Pipe Shed. 03:30 - 07:00 3.50 DRILL P PROD1 RIH wI 6-1/8" Directional BHA on 4" DP from Derrick to 9,340'. Tagged Cement at 9,340'. 07:00 - 07:30 0.50 DRILL P PROD1 M I U Top Drive, Drilled Cement from 9,340' to 9,346', Top of Landing Collar. WOB 5,000#, RPM 50, Motor RPM 83, Pump Rate 275 gpm, 1,500 psi. String Weight Up 200,000#, String Weight Down 130,000#, String Weight Rotating 160,000#. 07:30 - 08:00 0.50 DRILL P PROD1 Circulated Bottoms Up. Pump Rate 250 gpm, 1,500 psi. 08:00 - 08:30 0.50 DRILL P PROD1 Held PJSM. Closed Pipe Rams and Pressure Tested Liner and Liner Top to 3,000 psi fl 30 Minutes, OK. Bled Down Pressure, Opened Pipe Rams. 08:30 - 11 :00 2.50 DRILL P PROD1 Drilled Float Equipment and Cement from 9,346' to 9,429', Top of Float Shoe. WOB 5,000# -10,000#, RPM 60, Motor RPM 83, Pump Rate 275 gpm, 1,525 psi. 11 :00 - 14:00 3.00 DRILL P PROD1 Held PJSM wI Rig Crew, Baroid Mud Engr and Peak Truck Drivers. Displaced Hole to New 8.4 ppg QuikDriln Mud. Pump Rate 275 gpm, 1,525 psi. 14:00 - 14:30 0.50 DRILL P PROD1 Drilled out Float Shoe and 20' of New Formation from 9,429' to 9,451'. WOB 15,000# - 20,000#, RPM 90, Motor RPM 83, Pump Rate 275 gpm, 1,525 psi. 14:30 - 15:00 0.50 DRILL P PROD1 Held PJSM. Closed Pipe Rams and Performed FIT. Held Test f/10 minutes wI No Pressure Loss. MW 8.4 ppg, Csg Shoe TVD 8,518', Pressure 710 psi = 10.0 ppg EMW. Bled down Pressure, Opened Pipe Rams. 15:00 - 00:00 9.00 DRILL P PROD1 Drilled 6-1/8" Directional Hole by Rotating and Sliding from 9,451' - 9,965'. WOB 15,000# - 25,000#, RPM 90, Motor RPM 83, Torque Off Bottom 8,000 ft Ilbs, Torque On Bottom 9,500 ft Ilbs, Pump Rate 275 gpm, SPP Off Bottom 1,650 psi, On Bottom 1,850 psi. Pumped 3 bbl Lo-Vis I 5 bbl Hi-Vis Sweeps Printed: 7/10/2002 12:22:58 PM ) ') BP EXPLORATION Operations Summary Report Page 6 .of 1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-08 0-08 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Spud Date: 10/19/1979 End: 7/7/2002 Date From - To Hours Task Code NPT Phase Description of Operations 7/3/2002 15:00 - 00:00 9.00 DRILL P PROD1 Every 90'. ART = 6.75 hrs. AST = 0.75 hrs. KRevs = 80.0 7/4/2002 00:00 - 03:30 3.50 DRILL P PROD1 Held PJSM. Drilled 6-1/8" Directional Hole by Rotating and Sliding from 9,965' to 10,180'. WOB 15,000# - 25,000#, RPM 90, Motor RPM 83, Torque Off Bottom 8,000 ft Ilbs, Torque On Bottom 9,600 ft Ilbs, Pump Rate 275 gpm, SPP Off Bottom 1,650 psi, On Bottom 1,900 psi. Pumped 3 bbl Lo-Vis I 5 bbl Hi-Vis Sweeps Every 90'. ART = 2.60 hrs. Total KRevs = 105.5 03:30 - 05:30 2.00 DRILL P PROD1 Pumped and Circulated Around 25 bbl Hi-Vis Barafiber Sweep. Pump Rate 275 gpm, 1,700 psi. Circulated until Returns over Shaker were Clean. 05:30 - 06:00 0.50 DRILL P PROD1 Held PJSM. Made Wiper Trip from 10,180' to 7" Shoe at 9,430'. No Drag. 06:00 - 06:30 0.50 DRILL P PROD1 Serviced Top Drive. 06:30 - 07:00 0.50 DRILL P PROD1 RIH after Wiper Trip from 9,430' to 10,180'. No Fill. 07:00 - 08:30 1.50 DRILL P PROD1 Pumped and Circulated Around 30 bbl Hi-Vis Barafiber Sweep. Pump Rate 275 gpm, 1,700 psi. Circulated until Returns over Shaker were Clean. 08:30 - 09:00 0.50 DRILL P PROD1 Pumped and Spotted 35 bbl Liner Running Lube Pill on Bottom. Dropped 1.75" ESS. 09:00 - 14:00 5.00 DRILL P PROD1 POOH wI 4" DP. Took 3 Check Shots wI ESS. Drill String Pulled Wet. 14:00 - 15:30 1.50 DRILL P PROD1 POOH, Broke out and LID Directional BHA to MWD Tools. 15:30 - 16:30 1.00 DRILL P PROD1 Held PJSM wI Rig Crew and Sperry MWD. Cleared Floor, Sperry removed Radioactive Sources. Downloaded MWD Data. 16:30 - 17:30 1.00 DRILL P PROD 1 Finished Breaking out and LID Directional BHA. Cleaned and Cleared Rig Floor. 17:30 - 18:30 1.00 CASE P PROD1 Held PJSM wI Rig Crew, Casing Crew and Baker. R I U Equipment to Run 4-1/2" Liner. 18:30 - 21 :00 2.50 CASE P PROD1 M I U and RIH w/21 Joints 4-1/2" 12.6# VAM-ACE 13Cr Liner. M I U Torque 3,600 ftllbs. Filled Liner every 5 Joints. Baker Locked First 3 Joints. Float Shoe on Pin end of Jt #1, Float Collar on Pin end of Jt #2, Landing Collar on Pin end of Jt #3. Total Length of Liner 890.01'. 21 :00 - 22:30 1.50 CASE P PROD1 R I U 4" Handling Equipment. M I U Baker HMC Liner Hanger ZXP Liner Packer and C2 Running Tool to Liner. Total Length of Liner and Hanger I Packer 915.27'. Circulated One Liner Volume, 14 bbls. Pump Rate 5 BPM, SPP 100 PSI. Liner Weight Up 11,000#, Liner Weight Down 11,000#. RID Liner Running Equipment. 22:30 - 00:00 1.50 CASE P PROD1 RIH wI 4-1/2" Liner on 4" DP to 2,700' 7/5/2002 00:00 - 03:30 3.50 CASE P PROD1 Held PJSM. RIH wI 4-1/2" Liner on 4" DP to 7" Casing Shoe at 9,430'. Broke out and LID 1 Jt of 4" DP. 03:30 - 04:00 0.50 CASE P PROD1 Broke Circulation, Pump Rate 7 BPM, SPP 680 psi. String Weight Up 180,000#, String Weight Down 145,000#. 04:00 - 04:30 0.50 CASE P PROD1 RIH wI 4-1/2" Liner on 4" DP to 10,180. 04:30 - 06:00 1.50 CASE P PROD1 M I U Cement Manifold, Slowly Broke Circulation. Pump Rate 3 BPM, SPP 450 psi. Circulated 400 bbls, Pump Rate 7 BPM, SPP 1,200 psi. Reciprocated Liner While Circulating. 4-1/2" Liner Assembly Set As Follows: ITEM LENGTH DEPTH Printed: 7/10/2002 12:22:58 PM ) ') BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-08 0-08 REENTER+COMPLETE NABORS NABORS 2ES Date From - To Hours Task Code NPT Phase 7/5/2002 04:30 - 06:00 1.50 CASE P PROD1 06:00 - 07:00 1.00 CEMT P PROD1 Page 70f 10 Spud Date: 10/19/1979 End: 7/7/2002 Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Float Shoe 10,177.00' 1 Jt 4-1/2" 12.6# VamAce 13Cr Lnr 10,136.21' Float Collar 10,134.77' 1 Jt 4-1/2" 12.6# Va mAce 13Cr Lnr 10,095.74' Landing Collar 10,094.93' 5 Jts 4-1/2" 12.6# Va mAce 13Cr Lnr 209.60' 9,885.33' 4-1/2" 12.6# Va mAce 13Cr Mkr Jt 9,875.03' 14 Jts 4-1/2" 12.6# Va mAce 13Cr Lnr 588.04' 9,286.99' 4-1/2" 12.6# Va mAce 13Cr Pup Jt 9,282.25' HMC Liner Hanger 9,275.57' ZXP Liner Packer 9,269.13' Liner Tie Back Sleeve 9,261.73' Held PJSM wI Dowell Crews, Rig Crews, Baker and Peak Truck Drivers. Shut Down Pumps and Checked String Weight, String Weight Up 185,000#, String Weight Down 145,000#. Switched over to Dowell. Pumped 5 bbls Water to flush lines. Shut in Cement Manifold and Tested Lines to 4,000 psi, OK. Pumped 5 bbl of Water followed by 20 bbls of Alpha Spacer, at 5.0 bpm, 975 psi. Pumped 26 bbls (140 sx) 15.8 ppg Premium Cement wI 0.35% bwoc CFR-3, 1.00% Gel, 3.00 gallsk Latex 2000 Additive, 0.36 gal/sk 434-B and 0.10 gallsk Defoamer. Pumped Cement at the Following Rates: Pumped Rate Pressure 10.0 bbls 5.00 bpm 1,190 psi 20.0 bbls 5.00 bpm 945 psi 26.0 bbls 5.00 bpm 935 psi Cleaned up and Flushed Cement Lines. Dropped DP Dart and Displaced wI 30 bbl Perf Pill and 77 bbls of Mud at the Following Rates: Pumped Rate Pressure 20.0 bbls 5.25 bpm 230 psi 40.0 bbls 5.75 bpm 255 psi 60.0 bbls 5.75 bpm 400 psi 80.0 bbls 5.00 bpm 510 psi 90 bbls Slw'd Pmps 2.25 bpm 410 psi Drill Pipe Dart Latched up wI 95 bbls Pumped, Pressure Increased to 1,700 psi, Wiper Plug Sheared, Pressure Decreased to 420 psi. 100.0 bbls psi 4.00 bpm 1.72' 39.07' 1.44' 39.03' 0.81' 10.30' 4.74' 6.68' 6.44' 7.40' 1,115 Printed: 7/10/2002 12:22:58 PM ) ') BP EXPLORA IION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 0-08 0-08 REENTER+COMPLETE NABORS NABORS 2ES 7/5/2002 From - To Hours Task Code NPT Phase 06:00 - 07:00 1.00 CEMT P PROD1 07:00 - 07:30 0.50 CEMT P PROD1 07:30 - 08:00 0.50 CEMT P PROD1 08:00 - 09:00 1.00 CEMT P PROD1 09:00 - 09:30 0.50 CEMT P PROD1 09:30 - 11 :00 1.50 CEMT P PROD1 11 :00 - 11 :30 0.50 CEMT P PROD1 11 :30 - 13:30 2.00 CEMT P PROD1 13:30 - 14:30 1.00 CEMT N RREP PROD1 14:30 - 17:00 2.50 CEMT P PROD1 17:00 - 17:30 0.50 RUNCOMP COMP 17:30 - 18:30 1.00 RUNCOMP COMP 18:30 - 19:30 1.00 RUNCOMP COMP 19:30 - 20:00 0.50 RUNCOMP COMP 20:00 - 20:30 0.50 RUNCOMP COMP 20:30 - 00:00 3.50 RUNCOMP COMP 7/6/2002 00:00 - 10:30 10.50 RUNCOMP COMP 10:30 - 12:00 1.50 RUNCOMP COMP 12:00 - 13:00 1.00 RUNCOMP COMP 13:00 - 13:30 0.50 RUNCOMP COMP Page 80f 10 Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Spud Date: 10/19/1979 End: 7/7/2002 Description of Operations Wiper Plug Bumped wI 108 bbls Pumped. Pressured up to 2,000 psi to Bump Plug. Cement in Place @ 0700 Hrs. Increased Pressure to 3,500 psi to Set Baker Liner Hanger. Set Down 30,000# to Confirm Hanger Set. Released Pressure and Checked Floats, Bled Back 2.0 bbls, Floats Held. Released Halliburton, Switched to Rig Pumps. Rotated Drill String 20 Turns to Release Running Tool from Liner. Pressured up to 1,000 psi. Picked up on Drill String, Lost Pressure, Indicating Running Tool Released from Liner. Pumped 30 bbls at 13 bpm to contaminate Cement and Move Cement Up Hole. Set Down 50,000# on Liner Hanger, Observed Packer Pins Shearing and Setting ZXP Packer. Spudded on ZXP Packer wI 50,000# Twice to Ensure Packer Set. Circulated Bottoms up to Clear Hole of Excess Cement. Pump Rate 13 bpm, SPP 2,550 psi. Circulated back 5 bbls Cement contaminated Mud. Displaced Well to Clean 8.5 ppg Sea Water. Pump Rate 13 bpm, 2,250 psi. Broke out and LID Cement Manifold and Lines. POOH and LID 4" DP to 7,375. Serviced Top Drive. POOH and LID 4" DP to 4,201'. Repaired Pipe Skate. POOH and LID 4" DP. Cleaned, Broke out and LID Liner Running Tool. M I U Retrieving Tool, Latched and Pulled Wear Bushing. Held PJSM. R I U Equipment to Run 4-1/2" Completion. Closed Blind Rams and Tested Casing and Liner to 3,000 psi fl 30 Minutes, OK. Bled Down Pressure. Held PJSM wI Rig Crew, Baker and Casing Hand on Running 4-1/2" Completion. M I U WLEG - XN Nipple Assembly, X Nipple Assembly, Baker S-3 Packer Assembly wI X Nipple, NSCT Threads, M I U Torque 3,575 ft Ilbs. M I U and RIH wI 4-1/2" 12.6# L-80 Vam Ace 13Cr Tubing. Torque Turned each Connection. M I U Torque 3,650 ft Ilbs. 40 joints ran at Report Time. Held PJSM. Continued to RIH wI 4-1/2" Completion. Ran 213 Jts 4-1/2" 12.6# 13Cr Vam-Ace Tubing and Jewelry. M I U Torque 3,650 ft fibs. Tagged Up in Tie-Back Sleeve at 9,273'. Spaced Out 4-1/2" Tubing. M I U Space Out Pups, M I U Jt #213 on top of Pups. Held PJSM. M I U Tubing Hanger and 1 Jt of 4" DP as a Landing Joint. Landed Tubing Hanger and RILDS. Completion Equipment Set at the Following Depths: Item Length Depth WLEG XN Nipple Assembly 9,271.00' X Nipple Assembly 9,227.80' 22.31' 20.89' Printed: 7/10/2002 12:22:58 PM ') ') BP EXPLORATION Operatlol'1s,'Summary Report Page 9öf,10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-08 0-08 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Spud Date: 10/19/1979 End: 7/7/2002 Date, From - To Hours Task Code NPT Phase ' Description of Operations 7/6/2002 13:00 - 13:30 0.50 RUNCOrvP COMP 7" x 4-1/2 S-3 Packer Assembly 23.41 ' 9,204.39' X Nipple Assembly 20.77' 9,183.62' 1 Jt 4-1/2" 12.6# Va mAce 13Cr Tbg 41.98' 9,141.64' #1 GLM Assembly 26.56' 9,115.08' 17 Jts4-1/2" 12.6#VamAce 13CrTbg 713.94' 8,403.14' #2 GLM Assembly 26.48' 8,374.66' 18 Jts 4-1/2" 12.6# Va mAce 13Cr Tbg 756.10' 7,618.56' #3 GLM Assembly 26.43' 7,592.13' 21 Jts4-1/2" 12.6#VamAce 13CrTbg 880.59' 6,711.54' #4 GLM Assembly 28.24' 6,683.30' 57 Jts4-1/2" 12.6# Va mAce 13CrTbg 2,389.05' 4,294.25' #5 GLM Assembly 28.37' 4,265.95' 19 Jts 4-1/2" 12.6# VamAce 13Cr Tbg 797.61' 3,468.34' #6 GLM Assembly 28.30' 3,440.04' 29 Jts 4-1/2" 12.6# Va mAce 13CrTbg 1,217.51' 2,222.53' X Nipple Assembly 21.27' 2,203.26' 50 Jts 4-1/2" 12.6# VamAce 13Cr Tbg 2,098.35' 102.91' 4-1/2" 12.6# Va mAce 13Cr Pup Jt 2.19' 100.72' 4-1/2" 12.6# Va mAce 13Cr Pup Jt 8.16' 92.56' 4-1/2" 12.6# Va mAce 13Cr Pup Jt 10.22' 82.34' 4-1/2" 12.6# VamAce 13Cr Pup Jt 10.23' 72.11' 1 Jt 4-1/2" 12.6# VamAce 13Cr Tbg 42.02' 30.09' 4-1/2" 12.6# Va mAce 13Cr Pup Jt 2.51' 27.58' Tubing Hanger 1.25' 26.33' 13:30 - 17:00 3.50 RUNCOrvP COMP Reverse Circulated 223 bbls Corrosion Inhibited Sea Water down IA. Pump Rate 3 bpm, 400 psi. 17:00 - 18:00 1.00 RUNCOrvP COMP Held PJSM. Dropped BallI Rod Assembly. Pressured up on Tubing to 2,500 psi to set Packer. Tested Tubing to 3,500 psi fl 30 Minutes. OK. Printed: 7/10/2002 12:22:58 PM ') ) BPEXPLORA TION Operations Summary Report Pagë 100f10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-08 D-08 REENTER+COMPLETE NABORS NABORS 2ES Start: 6/25/2002 Rig Release: 7/7/2002 Rig Number: Spud Date: 10/19/1979 End: 7/7/2002 Date From - To Hours Task Code NPT Phase Description of Operations 7/6/2002 18:00 - 19:00 1.00 RUNCOMP COMP Bled Tubing Pressure Down to 1,500 psi. Pressure Tested IA to 3,000 psi f/30 Minutes, OK. Bled Down Tubing Pressure , Sheared RP Valve. Bled Down All Pressure. 19:00 - 19:30 0.50 RUNCOMP COMP Set TWC and Tested to 2,000 psi, OK. 19:30 - 20:00 0.50 BOPSUR P COMP Held PJSM. N I 0 BOPE. 20:00 - 22:00 2.00 WHSUR P COMP HELD PJSM. N I U Adapter Flange and Production Tree. R I U and Tested Tree to 5,000 psi, OK. 22:00 - 23:00 1.00 WHSUR P COMP HELD PJSM. R I U DSM. Pulled TWC. RID DSM. 23:00 - 00:00 1.00 WHSUR P COMP Held PJSM. R I U Little Red Hot Oil. Tested Lines to 3,000 psi, OK. 7/7/2002 00:00 - 01 :30 1.50 WHSUR P COMP Held PJSM. Pumped 155 bbls of Diesel down IA to Freeze Protect. Pump Rate 2.5 bpm, 500 psi. 01 :30 - 03:00 1.50 WHSUR P COMP R I U and U-Tubed Diesel between Tubing & IA. Freeze Protected IA & Tbg to 2,200'. 03:00 - 04:00 1.00 WHSUR P COMP Set BPV. Removed 2nd Annulus Valve, Installed Tree Cap & Gauges. Installed Blind Flange on Annulus Valve. 04:00 - 04:30 0.50 WHSUR P COMP Secured Well. Released Rig @ 04:30 Hrs, 07 I 07 I 2002. Printed: 7/10/2002 12:22:58 PM ) ) D-08A Prudhoe Bay Unit 50-029-20372-01 202-123 Rig Accept: 06/25/02 Rig Spud: 06/29/02 Rig Release: 07/07/02 Nabors 2ES POST RIG WORK 07/11/02 PULL B&R, INSTALL GENERIC GIL DESIGN IN STA'S#6 AND #4, PULL RHC, Drr @ 9820' MD CORRECTED W/3 3/8" D/GUN. WORK 5' X 2-1/2 PUMP BAILER TO 9986' MD CORRECTED. LEFT WELL SHUT IN AND NOTIFIED PAD OPERATOR. 07/13/02 RIH WITH 2.5" JSN. SAW SOME RESISTANCE TO RIH AT 10054' CTMD. JET WASH LINER FROM 9900' TO PBTD @ 10117' CTMD. PUMP 20 BBL BIOZAN SWEEP. POOH AT 80%. 07/14/02 POOH AT 80%. FP TUBING WITH 50/50 METHANOL TO 2000'. SECURE WELL. RD. WELL IS SHUT IN AND TAGGED. JOB COMPLETE. 07/15/02 D&T WI 33/8" DIGUN, TTL, AND S/BAILER. TAG BOTTOM AT 10074' SLM. WELL SI. PERFORATED 20' INTERVAL (9996' - 10016') WITH 3-3/8" POWERJET GUN. LOGGED PDC LOG. PERF LOGS CORRELATED TO MWDI PDC GAMMA RAY CCL LOGS CORRELATED TO OPEN HOLE LOGS PRE SIDETRACK. WELL LEFT SHUT-IN AND TURNED BACK TO DSO TO POP. AOGCC 333 W, 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well D-08A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,803.04' MD Window / Kickoff Survey 6,903.00' MD (if applicable) Projected Survey: 10,180,00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) dOð- !¿)3 31-Jul-02 RECEIVED AI ;(~ O.~ "002 .J',:) l L AIa8ka Oil & Gas Cons. Commission Anchorage North Slope Alaska BPXA PBU_WOA D Pad, Slot D-OB D-OBA Job No. AKMW22105, Surveyed: 4 July, 2002 - SURVEY REPORT 23 July, 2002 Your Ref: API 500292037201 Surface Coordinates: 5957631.00 N, 654123.00 E (70017' 28.1670" H, 148045' 08.0651" W) Kelly Bushing: 74. 54ft above Mean Sea Level =:tj...IE!!I'r'Y-SUf1 DRIL.L.ING 'SEFtVICES A Halliburton Company Survey Ref: svy11250 Sperry-Sun Drilling Services . Survey Report for D-OBA Your Ref: API 500292037201 Job No. AKMW22105, Surveyed: 4 July, 2002 BPXA North Slope Alaska PBU_WOA D Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6803.04 39.850 229.790 6052.19 6126.73 1439.91 S 1493.97 W 5956160.77 N 652658.86 E 2037.86 Tie On Point MWD Magnetic --- 6903.00 39.760 230.100 6128.98 6203.52 1481.09 S 1542.95 W 5956118.59 N 652610.74 E 0.218 2101.38 Window Point 6941.59 39.550 233.720 6158.70 6233.24 1496.27 S 1562.33 W 5956103.01 N 652591.68 E 6.010 2125.91 6976.01 37.740 237.150 6185.58 6260.12 1508.47 S 1580.01 W 5956090.45 N 652574.24 E 8.146 2147.39 7007.38 36.530 240.460 6210.59 6285.13 1518.29 S 1596.20 W 5956080.31 N 652558.26 E 7.446 2166.31 7036.74 35.590 243.700 6234.33 6308.87 1526.38 S 1611.47W 5956071.90 N 652543.17 E 7.241 2183.51 7070.20 34.040 247.580 6261.80 6336.34 1534.27 S 1628.85 W 5956063.66 N 652525.94 E 8.078 2202.39 7098.43 33.130 251.220 6285.32 6359.86 1539.77 S 1643.46 W 5956057.86 N 652511.45 E 7.826 2217.63 7130.02 32.300 255.570 6311.90 6386.44 1544.65 S 1659.81 W 5956052.65 N 652495.20 E 7.891 2233.99 7162.46 31 .300 255.700 6339.4 7 6414.01 1548.89 S 1676.37 W 5956048.07 N 652478.73 E 3.090 2250.18 7194.54 31.110 254.710 6366.91 6441.45 1553.13 S 1692.44 W 5956043.50 N 652462.75 E 1.705 2265.96 7222.83 31 .1 00 255.590 6391.13 6465.67 1556.88 S 1706.57 W 5956039.46 N 652448.71 E 1.607 2279.84 7317.42 29.410 251.610 6472.85 6547.39 1570.29 S 1752.28 W 5956025.12 N 652403.28 E 2.772 2325.45 7409.96 23.170 257.330 6555.79 6630.33 1581.46 S 1791.64 W 5956013.14 N 652364.15 E 7.270 2364.53 7503.68 18.670 260.840 6643.31 6717.85 1587.90 S 1824.46 W 5956006.03 N 652331.48 E 4.982 2395.54 7596.66 16.030 260.410 6732.05 6806.59 1592.41 S 1851.82 W 5956000.96 N 652304.22 E 2.843 2420.92 7691.86 11 .780 261.480 6824.44 6898.98 1596.04 S 1874.40 W 5955996.87 N 652281.72 E 4.472 2441.82 7783.77 9.920 284.070 6914.74 6989.28 1595.50 S 1891.36 W 5955997.06 N 652264.74 E 5.008 2455.74 7878.30 7.380 301.920 7008.21 7082.75 1590.31 S 1904.42 W 5956001.98 N 652251.58 E 3.879 2463.84 "-"', 7971.85 8.580 333.770 7100.89 7175.43 1580.87 S 1912.61 W 5956011.25 N 652243.20 E 4.827 2465.54 8064.00 11.410 358.060 7191.68 7266.22 1565.59 S 1915.96 W 5956026.4 7 N 652239.54 E 5.445 2460.00 8158.67 15.050 15.870 7283.86 7358.40 1544.39 S 1912.91 W 5956047.72 N 652242.15 E 5.730 2445.87 8252.13 16.690 29.590 7373.78 7448.32 1521.04 S 1902.96 W 5956071.27 N 652251.62 E 4.368 2424.79 8344.71 20.610 40.720 7461.51 7536.05 1497.118 1885.76 W 5956095.55 N 652268.33 E 5.702 2397.31 8437.87 24.930 43.620 7547.39 7621.93 1470.46 S 1861.50 W 5956122.69 N 652292.04 E 4.790 2362.43 8530.61 23.600 43.040 7631.94 7706.48 1442.74 S 1835.35 W 5956150.94 N 652317.62 E 1.457 2325.39 8622.63 23.790 42.290 7716.20 7790.74 1415.54 S 1810.29 W 5956178.64 N 652342.11 E 0.387 2289.54 8715.08 24.300 40.930 7800.63 7875.17 1387.38 S 1785.28 W 5956207.31 N 652366.54 E 0.815 2253.21 8809.18 25.370 41.310 7886.03 7960.57 1357.61 S 1759.28 W 5956237.61 N 652391.92 E 1.150 2215.18 8902.81 24.920 41.720 7970.78 8045.32 1327.82 S 1732.91 W 5956267.94 N 652417.67 E 0.515 2176.82 -----~--~- ------------._- 23 July, 2002 - 11 :01 Page 20f4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for D~08A Your Ref: API 500292037201 Job No. AKMW22105, Surveyed: 4 July, 2002 BPXA North Slope Alaska PBU_WOA D Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8996.31 25.310 41 .480 8055.44 8129.98 1298.14 S 1706.57 W 5956298.15 N 652443.40 E 0.431 2138.54 9089.86 25.530 40.090 8139.94 8214.48 1267.74 S 1680.34 W 5956329.08 N 652469.00 E 0.680 2099.96 -' 9183.67 27.200 39.820 8223.99 8298.53 1235.80 S 1653.59 W 5956361.56 N 652495.09 E 1.785 2060.12 9276.74 25.000 38.400 8307.56 8382.10 1204.05 S 1627.75 W 5956393.84 N 652520.28 E 2.457 2021.13 9347.54 23.590 39.860 8372.09 8446.63 1181.45 S 1609.38 W 5956416.81 N 652538.18 E 2.165 1993.39 9427.17 26.230 39.860 8444.31 8518.85 1155.70 S 1587.88 W 5956442.99 N 652559.15 E 3.315 1961.33 9456.45 26.560 40.080 8470.53 8545.07 1145.73 S 1579.52 W 5956453.13 N 652567.30 E 1.176 1948.88 9549.17 25.080 40.820 8553.99 8628.53 1114.99 S 1553.33 W 5956484.40 N 652592.86 E 1.634 1910.15 9641.98 27.850 40.150 8637.07 8711.61 1083.53 S 1526.48 W 5956516.40 N 652619.05 E 3.002 1870.48 9736.43 31.170 39.230 8719.26 8793.80 1047.72 S 1496.79 W 5956552.81 N 652648.00 E 3.548 1826.05 9829.19 31.260 35.110 8798.60 8873.14 1009.44 S 1467.76 W 5956591.69 N 652676.24 E 2.304 1780.83 9922.49 31.590 33.410 8878.21 8952.75 969.23 S 1440.38 W 5956632.44 N 652702.79 E 1.014 1735.94 1 0016. 13 31.710 33.130 8957.93 9032.47 928.15 S 1413.43 W 5956674.07 N 652728.89 E 0.203 1690.92 10108.45 32.240 31.230 9036.24 9110.78 886.78 S 1387.40 W 5956715.97 N 652754.07 E 1 .232 1646.52 10122.96 32.340 30.780 9048.51 9123.05 880.13 S 1383.41 W 5956722.69 N 652757.93 E 1.794 1639.55 10180.00 32.340 30.780 9096.70 9171.24 853.92 S 1367.79 W 5956749.22 N 652773.00 E 0.000 1612.15 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. '- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 236.900° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10180.00ft., The Bottom Hole Displacement is 1612.46ft., in the Direction of 238.023° (True). ------- --~-~-------- 23 July, 2002 - 11:01 Page 3 0'4 DrillQuest 2.00.08.005 North Slope Alaska Comments Measured Depth (ft) 6803.04 6903.00 10180.00 Sperry-Sun Drilling Services Survey Report for D-OBA Your Ref: API 500292037201 Job No. AKMW22105, Surveyed: 4 July, 2002 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6126.73 6203.52 9171.24 1439.91 S 1481.09 S 853.92 S Survey tool program for D-OBA From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 6803.04 23 July, 2002 - 11:01 Comment 1493.97 W 1542.95 W 1367.79 W Tie On Point Window Point Projected Survey Survey Tool Description 0.00 6803.04 6126.73 10180.00 6126.73 AK-1 BP _HG - BP High Accuracy Gyro (0-08) 9171.24 MWO Magnetic (0-08A) Page 4 0'4 . BPXA PBU_WOA D Pad '- -'- --------- ---- ----~--------~--_.----- ----~---- --- ---- ---------- Dril/Quest 2.00.08.005 ) ~J~:~ ~i~ ~i!Æ~æ~ AI~ASIiA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR f I 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit D-08A BP Exploration (Alaska), Inc. Permit No: 202-123 Surface Location: 3370' SNL, 1067' WEL, Sec. 23, T11N, R13E, UM Bottomhole Location: 1014' NSL, 2441' WEL, Sec. 23,T11N, R13E, UM Dear Mr. Crane: Enclosed is the approved application for pennit to redrill the above referenced development oil well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from 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 elToneously 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~~~ Chair BY ORDER OF THE COMMISSION DATED thiS~ day of June, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA l " STATE OF ALASKA )AND GAS CONSERVATION COMML )ON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 73.34' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028285 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number Ii D-08A 9. Approximate spud date 07/04/02 ../ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10147' M D I 9172' rvD 0 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 42 Maximum surface 2400 psig, At total depth (TVD) 8800' I 3250 psig Setting Depth T OD Bottom Lenath MD rvD MD rvD 2684' 6750' 6086' 9434' 8520' 863' 9284' 8386' 10147' 9172' ¡¡J6,{ 6~ll¿lo L ~'~113 '(t \ " ~ 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3370' SNL, 1067' WEL, SEC. 23, T11 N, R13E, UM At top of productive interval 893' NSL, 2537' WEL, SEC. 23, T11 N, R13E, UM At total depth 1014' NSL, 2441' WEL, SEC. 23, T11N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028286, 1014' MD D-31A is 477' away at 9662' MD 16. To be completed for deviated wells Kick Off Depth 6900' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couolina 7" 26# L-80 BTC-M 4-1/2" 12.6# 13Cr80 Vam Ace 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 8-1/2" 6-1/8" Quantitv of Cement (include staae data) 556 cu ft Class 'G' 146 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 1 0580 feet 9375 feet 1 0367 feet 9183 feet Length Plugs (measured) Junk (measured) Size Cemented MD rvD 14 cu yds Arcticset 110' 110' 4506 cu ft Permafrost II 2669' 2669' 1323 cu ft Class 'G', 130 cu ft PF 'C' 9483' 8393' 110' 20" x 30" 2669' 13-3/8" 9483' 9-5/8" 1780' 7" 525 cu ft Class 'G' R E EË'j \tÉOD JUN 11 2002 7773' - 9366' 20. Attachments Open: 10135' - 10150', 10150' - 10165', 10172' - 10193' Closed: 10075' - 10120', 10130' - 10135' true vertical Open: 8975' - 8988', 8988' - 9001', 9008' - 9027' Closed: 8921' - 8961', 8970' - 8975' II Filing Fee 0 Property Plat 0 BOP Sketch II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis Contact Engineer Name/Number: Dave ~sley, 564-5773 21. I hereby certify that the fore ing is t,r,u,Je;n07rre,and C"", rr,e, ct to th,. e"". best of,."m"", y ~n,o" WI,~", d,' ge . Signed Lowell Crane ~~( !~ Title Senior Dnlllng Engineer I ", .Çommi$SiónÜ$..Only Permit Number API Number Þ,p~~cn1:1 ~te See cover letter Zo? - /./ - ~ 50- 029-20372-01 ÚL1'1/~0') for other reauirements Conditions of Approval: Samples Required 0 Yes þiI No Mud Log Required 0 Yes !XI No Hydrogen Sulfide Measures a Yes 0 No Directional Survey Required ~Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other:Ti'sf- ß'0 PE to '~SOO p~: . Lìk.iv ì?oPt V4.M. ~"e-'Ý~~ YeÕ~r.ed, by order of I I Approved By OnglOal Signed by ,"., \'" ,CQ.Q1rpi$sioner the commission Date (P ¡q 109, Form 10-401 Rev. 12-01QJ1nmy Oechsli Tayh :' " '" ~ :'i, ~ Suömit In Triplicate Alaska Oil & Gas Gons. CommiSSion Anchora,ae 0 Diverter Sketch II Drilling Program 0 Seabed Report 0 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 Perforation depth: measured Date (;~-{O- 6(L \ , II! '( \ ) ) I Well Name: I D-08A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Conventional Sidetrack Producer I AFE Number: 4P1890 I Estimated Start Date: 107/04/02 I I MD: 110,147' I I TVD: 19,172' I Surface Location: Estimated Target Location: Sadlerochit Zone 28 Bottom Hole Location: x = 654,123.00 19101 FSL , 1067' FEL X = 652,675.00 893'FSL,2537'FEL X = 652,769.00 10141 FSL,2441' FEL Y = 5,957,632.00 Sec. 23, T11 N, R13E Umiat Y = 5,956,585.00 TVDss 8750 Sec. 23, T11 N, R13E Umiat Y = 5,956,708.00 TVDss 9097 Sec. 23, T11 N, R13E Umiat I RiQ: I Nabors 2ES / I OperatinQ days to complete: 117.0 I I 173.34' I I I I BF/MS: 144.84' I IRKB: I Well DesiQn (conventional, slim hole, etc.): I Conventional Sidetrack / I Objective: I Zone 2, Sadlerochit CasinglTubing Program Hole Size Csgl WtlFt Grade Conn Length Top 8tm Tbg O.D. MDITVD MDITVD 81/2" 7" 26.0# L-80 STCM -2684' 6750' / 6086' 9434' / 8520' / 61/8" 4 Y2" 12.6# 13Cr-80 Vam Ace -863' 9284' / 8386' 10147'/9172' Tubing 4 Y2" 12.6# 13Cr-80 Vam Ace -9284' GL 9284'/8386' Directional KOP: 16,900' MO Maximum Hole Angle: Close Approach Well: Survey Program: 0-08A Sidetrack -42.0° in original well bore at -5600' MD. -40.0° through intermediate section of planned sidetrack at -6900' MD. There are two close approach issues: The closest well to the 0-08A is 0- 31A with a center-to-center distance of 477' and allowable deviation of 275' at the planned depth of 9,662' MD. All wells pass Major Risk criteria. Standard MWO Surveys from kick-off to TO. Page 1 \ , . ) ( ( Mud Program Window Milling Mud Properties: LSND Density (P39) Viscosity PV 9.8 55 - 70 10 -15 Intermediate Mud Properties: LSND Density (ppg) Viscosity PV 9.8-10.0/ 40-55 10-15 Production Mud Properties: Quickdril-N Density (ppg~ Viscosity PV 8.4 - 8.5 45 - 55 4 - 7 ) I Whip Stock Window 9 5/8" I YP tauO MBT pH API FI 25 - 30 5-9 9.0- 9.5 <15 I 8 1/2" hole section I YP tauO MBT pH API FI 18 - 25 3-8 9.0-9.5 <15 I 6 1/8" hole section I YP tauO MBT pH API FI 22 - 28 4-8 <3 8.5 - 9.0 N/C Logging Program 8 1/2" Intermediate: Sample Catchers - None Drilling: MWD Dir/GRlRes- Real time GR/Res throughout entire interval Open Hole: None Cased Hole: None Sample Catchers - Two, at Company man call out MWD Dir/GR/Res- Real time GR/Res throughout entire interval; Recorded Den/Neu throuQh entire interval. None None 6 1/8" Production: Drilling: Open Hole: Cased Hole: Cement Proç ram Casing Size 7" 26#, L-80 Intermediate Liner I Basis: Lead: None Tail: Based on 80' of 7" shoe track, 2534' of 8 1/2" open hole with 400/0 excess, 150' of 7" x 9 5/8" liner lap, and 200' of ~/8" x 4" DP annulus volume. Tail TOC: -6750' MD (6077'TVD) Liner top. Fluid Sequence & Volumes: Pre 10 bbls Water Flush Spacer Lead Tail Casing Size 25 bbls Alpha Spacer at 11 .0 ppg None /' / 99 bbl I 556 fe I 467 sks of Halliburton 'G' at 15.6 ppg and 1.19 cf/sk, BHST 1900 4 1/2", 12.6#, 13Cr-80 Production Liner Basis: Lead: None Tail: Based on 80' of 4-1/2" shoe track, 713' of 61/8" open hole with 40% excess, 150' of 4 Y2" x 7" liner lap, and 200' of 7"x 4" DP annulus volume. Tail TOC: -9284' MD (8385'TVD) - Liner top. Fluid Sequence & Volumes: Pre 10 bbls KCI Water Flush Spacer Lead Tail D-08A Sidetrack 20 bbls Alpha Spacer at 9.5 ppg None I /' 26 bbl I 146 ft3 I 123 sks of Halliburton 'G' at 15.6 ppg and 1.19 cf/sk, BHST 2100 Page 2 ., . ( I "') ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. / BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- . Maximum anticipated BHP: -3250 psi @ 8800' TVDss - Z2 . Maximum surface pressure: -2400 psi @ surface ,,/ (based upon BHP and a full column of gas from TO @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: . . . . Formation Markers Formation Tops (Wp#5) CM3/K10rrOp COLVILLE CM1/K5 LCU KINGAK T JF I TOP KINGAK F TJD I TOP KINGAK D TJA I TOP KINGAK A SAG RIVER TSHU I TOP SHUBLIK TSAD I TZ4B TCGL I TZ3 BCGL I TZ2C 23SB 22TS THOT 21TS TZ1B TDF I TZ1A MD 3500 psi 8.6 ppg seawater / 7.2 ppg Diesel / TVDss 5858 6955 7394 7394 7650 7987 8366 8446 8487 8919 8750 8878 8888 8923 8960 8980 9055 9110 TD Criteria: Minimum of 150' MD below the HOT. 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. D-08A Sidetrack Comments Est. Pore Pressure 3250psi (-7.1 ppg EMW) <"'" Page 3 . , .' , I ) ), Sidetrack and Complete Procedure Summary RiQ Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawqter. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3500psi. / 4. Pull and lay down 4 1/2" tubing from tubing cut and above. 5. P/U milling assembly and 5" drill pipe. RIH and drift to tubing cut. ~OH and stand back BHA. 6. R/U E-line and M/U 95/8" bridge plug. RIH and set at 6,920' MD. POOH with E-line. 7. Pressure test 9 5/8" casing to 3500psi for 30 minutes. 8. RIH with 95/8" Baker whip stock assembly. Orient whip stock as desired and set on bridge plug. ~ 9. Displace well to 9.8ppg milling fluid. Mill window in 9 5/8" casing at 6,900' MD. Perform FIT to 12.5ppg EMW. POOH. 10. M/U and RIH with 8-1/2" drilling assembly, including Dir/GR/RES to whip stock. Kick-off and drill the 8-1/2" intermediate section to Top Sag -9,434' MD (-8,520' TVD). 11. Run and cement 7",26# intermediate drilling liner to -150' back into window. POOH. 12. M/U and RIH with a 6-1/~ drilling assembly, including Dir/GR/Res/Den/Neu. Test the 7" casing to 3500psi for 30 minutes. ( I 13, Drill 20' new formation and conduct FIT to 10.0ppg EMW. 14. Drill 6-1/8" production section as per directional plan to an estimated TD of 10,147'MD (-9,172' TVD). I 15. Run and cement a 4 Y2", 12.6#, 13Cr-80 production liner throughout the 6-1/8" well bore. Displace well to clean seawater above liner top. POOH. 16. Run a 4 Y2", 12.6#, 13Cr-80 completion;iying into the 4-1/2" liner top. 17. Drop Ball and Rod to set packer and test the tubing and annulus to 3500 psi for 30 minutes. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well to -2200' and secure the well. 20. Rig down and move off. Post-Ria Work: 1. MIRU slick line. Pull the ball and rod / RHC plug from IX' nipple below the production packer and install gas lift valves. Estimated Pre-rig Start Date: 06/20/02 Estimated Spud Date: 07/01/02 D-08A Sidetrack Page 4 .' .' ) ") Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move onto D-08. However, D-31 is 34' to the North. This is the closest neighboring well. Care should be taken while moving onto the well. Spotters will be used at all times. ~ D-Pad is not designated as an H2S site. Standard Operating Procedures for H2S precautions should, however, be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: D-27 0 ppm D-05 0 ppm D-28 0 ppm D-20 10 ppm The maximum level recorded of H2S on the pad was 10 ppm, in 03/2001. / ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells Procedure" SOP ..',""-"",,,",:Wl""'\W;,;':'I,ama~Wm,~¡,I,"¡,:.l.lm,r.l.\\';AI.1,r,l, .rm,:m,:.am~l~r.--¡,I>J,:~;,W.W,I).I,:,l,I.a,I,~^W,¡~,~¡,:,\rml^W"lm.w>,I,:, ¡,lm,:m,:,~;,\I¡,I,\"':.I.',I,:A ,\!A~,r.:,~~:,I.I,I,I.I.:m.I,:,:>,I,:,I.I. ,\a.W. ,\I.\ ¡,:;.am.W.l.I,iIJ,I,, ,\I,I,a.l.:~UW.l.wm.I.I.'m,I¡,I,I.l.I,I.l.I,<lm .I,I,\:t.~ ,:,1,I.1,ir.l.I,\I,I,I,:.am.~r,l.l,il,l. !,IAI,\D,I,:,I.w.c,\,D,Im.l,il,l.W~~~^f#,c,:mm;'I,l.I,\I.l.IAAI,I,I.!,,\.W,:;'I,l.I.o.I¡,I,l.W;';¡¡,I;I:a,I.l.WJJ,:,r,c,I,il,,1,1,1: Job 2: De-complete Well Hazards and Contingencies ~ The perforated intervals and lower section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. ~ The existing wellhead is a McEvoy 2-step and has a tubing hanger with 4 1/2" TDS landing thread. Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP ~-"~'r:":m~...,'m~m .'!'!':¥'t.r" \l"lli'T¥r'I';\""'I''''\';'".\~....A )"\\,,, ,--',..y,,,,m;.,,~,....\,,\,,.,f i," \",...~ 1.\".-.'I'\I!I'1'!T:l.-'n __II." Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whip stock Sidetracks" RP r ... .,,;-;- .'--1011 mr'<.II>I.JL.1. .1-'- .UII. .1..1 ...~ I .:-,1:18- JJU': .I. -I. -, L -'- ..;\ >.-... :"_1..1. .mmun D-08A Sidetrack Page 5 " I. I ) ) Job 5: Drill 8Y2" Intermediate Hole Hazards and Contingencies ~ The well will kick off in the upper Colville Mudstone, and drill the remainder of the Colville and the entire Kingak, into the Sag River formation. Previous D Pad wells drilled the Kingak with 9.7 to 10.2ppg mud weights. For this well, maintain mud weight at 10.0ppg, minimally, to 7" liner point. Follow all shale drilling practices to minimize potential problems. ~ KICK TOLERANCE: In the worst-case scenario of 9.6ppg pore pressure at the Sag River depth, a fracture gradient of 11.5ppg at the 9 5/8" casing window, and 10.0ppg mud in the hole, the kick tolerance is 61.1 bbls. Reference RP .:. "Shale Drilling, Kingak and HRl" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP ,1:1111111111111;:- :nmmllnmmmmn:llmmmll1. _mmmlmmIlII1II11I11'11IIHII;!ml:Q1II::llmam:II:1111:L::lalmll1::lm-II'III:::: -::-- --m-- ':"111;:1::11111111, .llml111 1111111111. 111m. _1:1::11In_mU:I:r:lrl:lm:lllllm:II:III----:mlllmu:nnWIII1: .!III-- .Imm. --1::11;:1111:111. --:' - - 'Iml'~ -m:IIIII-III-lall::m:- - .ml' Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ 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 .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP '1111:111II:,:II:I!mmIlD'mmlmllmll:m¡,~¡lCm:mm rmm::II:'mllll:,l'Im:ml,m,I'.lm:mn,:al,lmlll:1111111IClmlll.IL::aTL.I:_1In~I:I::_:I oI:II:-II I:;--lall~I:I:::-,lm~:-I-I;II-:I ::m:1-::I-llua:llj-mla;I:;II,::lmmlml;lmllU,m:,mmu:a:mr,al:ru:mlaal,mm:ammllmaaalllnmlll:,:l'<l!Ilmlnmlml:mllll,lmllllntllI:llallll'-:I,al_alla::I~:II:I::llm:llla:llm-llal:laa-jnl:a:ma:am:llanl:111:m::I:UII:,:m Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies ~ There are no anticipated fault crossings while drilling D-08A. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP D-08A Sidetrack Page 6 . 1 ') ) Job 9: Install 4Y2" Production Liner Hazards and Contingencies ~ The completion design is to run a 4 Y2" 13Cr-80 liner throughout the production interval. ~ Differential sticking is a concern. The 8.4ppg Quickdril will be -600psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4 Y2" liner will need to be run to extend -150' back up into the 7" intermediate liner, set at -9,434' MD. Reference RP .:. "Modified Conventional Liner Cementing" RP ..;,,"'m~mml,J',-~¡,-AI,g;mm,:¡,:Þ;,:;I.I,:,~;;;,,~ ~m¡Jmmm;,I,t,I;~~~,:;;,:,:~^~:,:~I,I.J'~, '-..-. m,-,llmm,l,-,.'-!\-"-¡';,lw,-,r,-mm:;.AA-m,~}.,»m,I,I~,I,wm:-'lm.;.w','m:"l'im!»iw#i!.mm.-¡..-;,-.-':.-mmm'mwwmAAlm,I"J, mwm'.I;mAAIJ.~:,I} ;.)~~,I¡m,:mm;¡m¡,w,:m¡.mmm,IJAA mmm~,~-,:¡mm Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP :.u.UJ.lJJAI.I,llli~IJ.I;IAlm.l.W,lm,IAl.l.I!\r.l.¡;,I.I. , ;l.I,~;'IA,\I,,-I,-¡,-,-.I.u,I»¡,r.l.a~.l.I.l.IJ, .l.I!\:AA¡m.l.IAA;,I"~~~.I.'J,',I,:.I.I,,I.I.¡,:m!\I.I.~~I!\I,I,I;,I,,-.I.I.IJ.a;.lJ.l.lm,IJ.':,I.I.I!\'!\:!\';'I.l.IAIm." ,\I.w.-m,:;,Im.I,-,!"I,I,~:,-'-.I,I,:.c.:,:,-.-,,\-,l.:A-UIAIAI,\I,I,-m,lml,l.WAI¡"I,I,~~I,:,rAA<r,'''''~,I"I,',r~, ,~rm.I,\~~~,I,I.I,l.rAIm.l,I.lml,\lA1m.1,~:;lm.l.l,\I,I!~I~,Iß,lp,r,~W¡"I¡""";;''' ¡''I,I,I. !,I,I.l.I¡,I,I,I,\I¡'':¡"'AIJ, "I.'-AI.:!"I¡,I.:.a~,I.-.l.I ,I"-,\:m-¡,I,I,I!,I¡""I).W¡"1,I.1,I,!¡..:.w,I,I.I.I.I,l.I.IAAI"I,I.-.l."' ,:!,",:,I¡"I,;,I,I,I,I,IAlA~IAAIA ,\~\IA:mmm,I,I,!;I.:AI...~- Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ There is one close proximity surface issue. Identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig about the pad and while positioning on the hole. Reference RP .:. "Freeze Protecting an Inner Annulus" RP D-08A Sidetrack Page 7 TREE = .. , 4" CrN 'WELLHEAD= MCEVOY 'A'CTUATÖR;""""",,,,,,,,,,,,,wãâker ^KB~-ELËV~;""W'^~'^-"""""^"7f54 "BF:wËlË\r;;-W"^"""""~"'" '44.84 wKõP,;;,-,w---6,9ÒÕ' md "Mã';("A'ngk;';"M"42:"õ';@äsõõ;" 15ãlli"m""MD';;"M","'",ww""-"1õ';õ2'Öï ÕãtUm TV~--'-ã.800' 19 5/8" DV Packer l-i D, J8Pre-Rig ConlJtion / I) 2082' l-i 41/2" OTIS SSSV Nipple, ID=3.813 2544' 1 -0 0 0 0 I-j ~ GAS LIFT MANDRELS ST MD lVDDEV ìYPE SIZE L TCH COMMENTS 5 2977 2903 r OTIS 1 1/2 RA 4 1/2 X 1 1/2 L 4 5168 4817 39° OTIS 1 1/2 RA 4 1/2 X 1 1/2 3 7157 6327 38° OTIS 1 1/2 RA 41/2X 11/2 2 8291 7265 30° OTIS 1 1/2 RA 4 1/2 X 1 1/2 1 8596 7530 29° OTIS 1 1/2 RA 4 1/2 X 1 1/2 113-3/8" 72#, L80 BTC Casing l-i 2669' 14 1/2" 12.6# L-80 Tubing. I Pre-rig tubing cut 1-1 7,000' 1- I Top of Cement P&A plug 1-1 -8,700' 1 I Baker 95/8" X 41/2" Packer; 4.75" I.D. 1-1 8714' TOP of 51/2" Liner Tie-Back Sleeve l-i 8,790' 1 TOp 7" Liner l-i 8,925' I l-i 9,483' I 19-5/8" 47#, L80, BTC Casing 1 PBID l-i 10,367' I I 7" 29#, L-80. BTC Liner I--{ 10,570' I DATE REV BY COMMENTS 04/22/02 DEW Proposed 0-08 Pre-Rig Condition ~ ./ zr. :,', J,~ I 8,654' l-i 41/2" PKR SWS Nipple, ID=3.813" I 8,766' 1-141/2" PKRSWS Nipple, ID=3.813" I 8,783' l-i 41/2" PKRSWN Nipple, ID=3.725" I 8,796' l-i 41/2" WLEG, ID=3.854" ~ ..~, . ....~ ¡~~ :i , ¡~ ~ I ~ ,~ «; t .:=-- =-- . ; ,. s=- b ns:.. :g. s=- s=:- ¡ 1òI ~ '" ~, .~ ¡,,' Jr.'. .I~ PRUDHOE BA Y UNIT WELL: 0-08 PERMIT No: 79-0360 API No: 50-029-20372-00 Sec.23,T11N,R13E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 TREE= .. . 4" CrN WELLHEAD= MCEVOY 'Â'cTOÄ'fõ'R;^"'-"""'''''''''''-^'ëake"r' KB~'äEV = """ "~7i34" .,,,--........,,,,.""W>',VH,,......'.........~...w.-,,,,.......... BF. ELEV = 44.84 KOP"~-^--~6,90Õ'm(r ,,,,,,,,,,,,,,,-,,,,,,,,,,,,,',',',,,",',',"''''''''''.....'.w,'.w.....,,.,',',,,,,.'','bW.'<0'1...','=',','.......','........"....'.,.....",...'..,.,..'..,.,.."" Max Angle = 42.0° "Bãtumrv1D;'--"^"'''-"''-'-''''''g';''9Õ7' Datum TVDSs= -~â 195/8" DV Packer 1-1 D-08~) Proposed Cor Jpletion 113-3/8" 72#, L80 BTC Casing 2544' I g 1-1 2669' 1- .4 141/2" 12.6# 13Cr-80 Tubing. 9 5/8" X 7" Baker 'ZXP Liner top pkr with Tie - back sleeve; 'HMC' Liner hanger 6,750' I Top of Whip-stock / 1-1 6,900' 1 1 Bridge Plug 1 Pre-rig tubing cut 1-1 6,920' I 1-1 7,000' 1- I Top of Cement P&A plug 1-1 -8,700' I I Baker 95/8" X 41/2" Packer; 4.75" I.D. 1-1 8714' TOp 51/2" Liner 1-1 8,790' 1 TOp 7" Liner 1-1 8,925' I 19-5/8" 47#, L80, BTC Casing 1-1 9,483' 1 I PBTD 1-1 10,367' 1 I 7" 29#, L-80, BTC Liner 1-1 10,570' I I) I ~:~ '", -. :8" @ >';1 . .. . \!) . >"'" .. L s=- ~ ~ 5:- DA TE REV BY COMMENTS 04/22/02 DEW Proposed Sidetrack w I a Solid Chrome liner and Chrome Completion ,¡ . ;t.. '',!:I . ' 0 s::... š:- s::... :{} 2200' 1-1 4 1/2" X Landing Nipple, 10=3.813 'õ 0 ST MD 5 4 3 2 1 GAS LIFT MANDRELS TVD DEV ìYÆ SIZE LTCH #° RP Shear 4 1/2 RA #° DV 4 1/2 RA #° DV 4 1/2 RA #° DV 4 1/2 RA #° DV 4 1/2 RA COMMENTS 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 1/2 ~ I 9,195' 9,220' 9,245' 9,270' 9,284' 1---14-1/2" 'X' Nipple, I IID=3.813 1---1 Baker 7" X 4 1/2" I I S-3 Packer 1---14-1/2" 'X' Nipple, 1 IID=3.813 1---14-1/2" 'XN' I I Nipple; 10=3.725 - Baker 5 X 7" ZXP Liner top pkr HMC Hanger I 9 434'../1---17" 26~, L-80, I ' I BTC Liner I 10,147' 1-141/2" 12.6#, 13Cr-80 Liner 1 ~"., .,~ ~/ PRUDHOE BA Y UNrr WELL: [}.08A ÆRMrrNo: API No: 50-029-20372-01 Sec. 23, T11N,R13E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 ö c ;¡: 0 0 ~ 7500 .c ë. Ö ] t: > 2 !- COMPANY DETAIlS BP Arncxo Calculation McIhod: Minimum CUMnac ~; ~fc=~ ~~v~~~ North Em>< Surface: Elliptical' Casing W.mi~ Method: Rules BaS<d 6000 REFERENCE INFORMATION Co-ordinaIC (N/E) Reference: Well Ccotre: [).OS, True Nonh Vertic31 (1VD) Relèreocc: 74.84 74.84 Section (VS) Reference: SIoI. (O.OON,O.OOE) M""SIJred Dcplh Reference: 74.84 74.84 Cakulation Method: Minimum c..vature '" , - s.mD"l2I1OC~6*' MP. 620124m ~.S¡"'TI¡nillOO'-."O'''D. 62l6.s6m \~ StartDif 5'100'; 7050' MD, 6316.66TVD 7l1!lIi~ ','''' _n"'",. m_n-'- 6500 7000 8000 I 1;"-- -TJD""""-è"""- ,~, ,¡ 'J'll'J' , '",0 /' p--- T 1,\ - -iff.- I Mj {!WIJ-TMIJ 7" ~ WD.TsHU........_.. /1 , 9000 :~Fí~==if~i¿~ - '. '412"""TotaIDcplh'IOI.n07'MD. 8500 1500 2000 Vertical Section at 236.89° [500ft/in] 2500 I 3000 SURVEY PROGRAM Plan: D-08A WP04 (D-08IPlan D-08a) .. Depth Fm Depth To Sun"ylPlan 6900.00 10147.07 Planned: D-08A WP04 VI Tool Created By: Ken Allen Checked: Date: Date: 111161200 1 MWD Reviewed: Date: WEll DETAIlS Name +N/oS +F./.W Easling Latito:le Longitude 5101 654123.00 700\1'28,I67N 148"45'08.065W N/A Nonbing D-08 2000.77 1998.98 5957631.00 TARGET DETAILS Name +N/oS Easling Shape 65271028 Point 65271026 Point 65267528 Polygon +FJ-W Northing TVD D-08A 1'2 9034.84 .102227 .1434.08 5956579.62 D-08A D 8824.84 -94228 -1432.46 5956659.62 D'()8A Polygon 8824,84 .101656 .1468.98 5956584.61 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +Fl- W DLeg TFace VSec Target I 6900.00 39.85 229.79 6201.24 -1479.90 -1541.26 0.00 0.00 2099.40 2 6920.00 40.12 233.50 6216.56 -1487.87 -1551.34 12.00 85.00 2112.19 3 7050.00 39.39 245.66 6316.66 -1529.85 -1622.70 6.00 100.00 2194.90 4 8281.25 24.02 38.40 7467.64 -1490.62 -1844.76 5.00 167.76 2359.47 5 9767.15 24.02 38.40 8824.84 -1016.56 -1468.98 0.00 0.00 1785.75 D-08A Polygon 6 9997.07 24.02 38.40 9034.84 -943.21 -1410.83 0.00 0.00 1696.97 7 10147.07 24.02 38.40 9171.85 -895.35 -1372.90 0.00 0.00 1639.06 / ..-- CASING DETAILS All TVD depths are ssTVD plus 74.84' for RKBE. No. TVD Name Size MD 8520.84 943432 7" 9171.84 10147.06 4 1/2" 7.000 4.500 1 2 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 7029.84 7827.46 CMl 2 7468.84 8282.55 1HRZ1LCU 3 7724.84 8562.83 TJF 4 8061.84 8931. 79 TJD 5 8440.84 9346.74 TJA 6 8520.84 943432 TSGRIWD-TSAD 7 8561.84 9479.21 WD-TSHU 8 8824.84 9767.15 WD- TZ3 9 8952.84 9907.29 WD-TZ2C 10 8962.84 9918.24 WD-23SB 11 8997.84 9956.56 WD-22TS 12 9034.84 9997.07 mOT 13 9054.84 10018.97 WD-2lTS 14 9129.84 10101.08 WD-TZIB .....-" It! ,I I I I' I -I ,I , I¡ II II , ~ ';V# ;' ~~~~ ~ ~ # :s 4= 0 0 [:!. + :E 1:: ! :; 0 (/J ð COMPANY DETAII.~ liP Amo<o REFERENCE INFOIU.IA TlON Co-m!inate (NIE) Reference: Wen Centæ: D-08, True Nonh Vert~ (lVD) Relerence: 74,84 74.84 Section (VS) Relerence: 5101 - (O.OON,O.OOE) Measm:d Depth Reference: 74,84 74.84 Calculation Method: Minimum C"""""" Calculation M."hoJ: MinÍltlll1l eur.~ture ~ ~e:::J~ ~~:~~~ind<r North Enur Surface: Elliptical' Casing W.mj~ MCfhoJ: Rub a.,,:d No. TVD All TVD depths are ssTVD plus 74.84' for RKBE. CASING DErAILS MD 8520.84 9434.32 7" 9171.84 10147.06 4 1/2" SURVEY PROGRAM Plan: D-08A WP04 (D-08/P1an D-08a) Depth Fm Depth To S"""ylPlan 6900.00 10147.07 PIanœd: D-ŒA WPß4 VI Tool Created By: Ken Allen Checked : Dale: Date: 11116/2001 MWD Reviewed: Date: NaIœ +NI-S WELL DETAILS Easting Latitude Loogitude Slot 654123.00 70"1T28.167N 148"45'OS.06SW NIA +Fl-W Northing Name Size D-08 2000.77 1998.98 5957631.00 7.000 4.500 TARGET DETAILS NaIœ TVD +Nf-S EasIing Shape 652710.28 Point 652710.26 Point 652675.28 Polygon +Fl-W Northing FORMATION TOP DErAILS D-08A 12 9034.84 .1022.27 -1434,08 5956579.62 D-08A n 8824.84 -942.28 -1432.46 5956659.62 D-08A Polygon 8824.84 -101656 -1468.98 5956584.61 I 2 3 4 5 6 7 8 9 10 Ul mer 13 '-14m )II."J 84 7827.46 7 h,'i 84 8282.55 i 7:.¡ 84 8562.83 ;"11.. 1 84 8931. 79 "nil 84 9346.74 "'.~II 84 9434.32 ;",r.184 9479.21 ;'''-''¡ 84 9767.15 ;,'J',.' 84 9907.29 ,,'Jr.'84 .991&.24 S',., '7 84 :995ä56 . '11 \.. 84mn-!I}i)iil,:'õ1' ,.II','¡ 84 iOOlg.97 OJ 1 ~'J 84mmlOloq:0& No. TVDPath MDPath Formation -600- -800 -1000 -1400 -1600 _tart Dif 51I00': 7050"MD, 6316.(56'1 V'j) I' """""""""""""r','n"""'l""""" """-"""',.""'" I I -1600 -1400 West(-)Æast(+) [200ft/in] -2000 -1800 CMI THRZJLCU TJF Till TJA TSGRIWD-TSAD WD-TSHU WD-TZ3 WD-TZ2C WD-23SB WD-22TS TIIOT WD-2ITS WD-TZIB SECTION DErAILS See MD Ine Azi TVD +N/-S +EI-W DLeg TFaee VSec Target I 6900.00 39.85 229.79 6201.24 -1479.90 ~~~~U~ ~:gg 0.00 2099.40 2 6920.00 40.12 233.50 6216.56 -1487.87 85.00 2112.19 3 7050.00 39.39 245.66 6316.66 -1529.85 ~~~~:~~ -1:gg 100.00 2194.90 4 8281.25 24.02 38.40 7467.64 -1490.62 167.76 2359.47 5 9767.15 24.02 38.40 8824.84 -1016.56 -1468.98 0.00 0.00 1785.75 D-08A Polyy 6 9997.07 24.02 38.40 9034.84 -943.21 -1410.83 0.00 0.00 1696.97 7 10147.07 24.02 38.40 9171.85 -895.35 -1372.90 0.00 0.00 1639.06 '-- ( [" )th : ¡0147t07' MD, 9171.85' TVD --- I' I I I ¡1 ~ I , ,I " II rI ~ "'-./ II t}jT , # # l' <> (;/-.;:~ .JI"" -" /' I -1000 j.- \. . BP Amoco Planning Report - Geographic ') ) . . ÇO~p~i1y,; Fieid: ' site; '.' 'w~m'" : Wellpatb: ' Field: , B,RAmoco, 'Pr~qh()éB~Y , ,~B'DPad ' ' , ' 'D~08", ..',' Plan'Q;.08å Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level , " "" , "'" " Date: 1111,612001. " "" Thuë:, 17:12:26 " Co~rdinate~)l{ef~r~ìtc~:' Wøll :P~P~i Tr(JeNorti'l VertiCal )~~féren~ë: 14;8474.8 '."'.", , . Seêt1Qn( êf~renêe:" We!l~Ö;9QN',Q.QQEi236;89AZI) , PI;.n: ' , ' " "D~oaAWp04' ,,'. "" Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 PB 0 Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5955590.34 ft 652165.06 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 8.492 N 148 46 6.316 W True 1.16 deg 0-08 0-08 Surface Position: +N/-S 2000.77 ft +E/-W 1998.98 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S 2000.77 ft +E/-W 1998.98 ft Slot Name: Well: Northing: 5957631.00 ft Latitude: 70 17 28.167 N Easting: 654123.00 ft Longitude: 148 45 8.065 W Northing: 5957631.00 ft Latitude: 70 17 28.167 N Easting : 654123.00 ft Longitude: 148 45 8.065 W Measured Depth: 34.34 ft Inclination: 0.00 deg Vertical Depth: 34.34 ft Azimuth: 0.00 deg +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 0-08 6900.00 ft Mean Sea Level 26.48 deg 80.78 deg Direction deg 236.89 Wellpath: Plan D-08a Current Datum: Magnetic Data: Field Strength: Vertical Section: 74.84 10/25/2001 57493 nT Depth From (TVD) ft 0.00 Height 74.84 ft Plan: D-08A WP04 Date Composed: 11/16/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Azim TVD +N/~S +E/- W DLS Build Turn TEO Target ft gag deg ft ft ft deg/1 OOft, deg/100ftdeg/10OO deg 6900.00 39.85 229.79 6201.24 -1479.90 -1541.26 0.00 0.00 0.00 0.00 6920.00 40.12 233.50 6216.56 -1487.87 -1551.34 12.00 1.34 18.56 85.00 7050.00 39.39 245.66 6316.66 -1529.85 -1622.70 6.00 -0.56 9.35 100.00 8281 .25 24.02 38.40 7467.64 -1490.62 -1844.76 5.00 -1.25 12.41 167.76 9767.15 24.02 38.40 8824.84 -1016.56 -1468.98 0.00 0.00 0.00 0.00 D-08A Polygon 9997.07 24.02 38.40 9034.84 -943.21 -1410.83 0.00 0.00 0.00 0.00 10147.07 24.02 38.40 9171.85 -895.35 -1372.90 0.00 0.00 0.00 0.00 Section 1: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 deg 6900.00 39.85 229.79 6201.24 -1479.90 -1541.26 2099.40 0.00 0.00 0.00 0.00 6920.00 40.12 233.50 6216.56 -1487.87 -1551.34 2112.19 11.99 1.35 18.55 84.96 Section 2: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/1000 deg/1000 deg 6950.00 39.84 236.27 6239.55 -1498.96 -1567.10 2131.45 6.00 -0.93 9.23 100.00 7000.00 39.52 240.94 6278.04 -1515.58 -1594.34 2163.35 6.00 -0.64 9.35 97.88 7050.00 39.39 245.66 6316.66 -1529.85 -1622.70 2194.90 6.00 -0.26 9.44 94.35 " I . . ') BP Amoco Planning Report - Geographic ') . . . . . . . ... ,D,ate. .'... 11/16/2001' ,'" " ,TiÔ1Ø: ",17:12:26' ; ",' ,,' Ç(j..()rdin~~~tN~)~~f~~~riçe:;W~U:;Q~Q~. True Nþrth ,yédi~~I('TVJ)jI{~feÏ"él>çe: ' . 74;8474:8:" ',"".'.. . , . Šectiôn(Y$)à.eferençe: ' " , ' 'We f(q.;OÞN,ŒOOE;2~6;~9Äži) Plan:,"'" ,', ' ,. ,'Q..08AWP04 .,. "", ' 'ëol11påny: BPAmóco, , . Fiêld:, . Ar~dhë>e;B(lY . "Site:. .. ' , FiSD Pâd ' . , We,a: ' " D~08 .." , "Wem~ath: PlànD"-.ÖSa. Section 3: Start ~D . ' .Ioca ' ft . dØg 7100.00 36.95 7200.00 32.09 7300.00 27.28 7400.00 22.55 7500.00 17.95 7600.00 13.62 7700.00 9.93 7800.00 7.83 7900.00 8.59 8000.00 11.66 8100.00 15.74 8200.00 20.23 8281.25 24.02 Section 4: Start MD ft 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9767.15 InCl , deg 24.02 24.02 24.02 24.02 24.02 24.02 24.02 24.02 24.02 24.02 24.02 24.02 24.02 24.02 24.02 24.02 Section 5: Start MD ft 9800.00 9900.00 9997.07 InCl deg 24.02 24.02 24.02 Section 6: Start MD ft 10000.00 10100.00 10147.07 Survey MD ft 6900.00 6920.00 6950.00 7000.00 7050.00 Incl deg 24.02 24.02 24.02 Incl deg 39.85 40.12 39.84 39.52 39.39 7100.00 36.95 7200.00 32.09 Aiim, " dØg 246.54 248.65 251.41 255.23 260.93 270.23 287.02 316.96 352.14 15.00 27.35 34.53 38.40 Adm . d~9, 38.40 38.40 38.40 38.40 38.40 38.40 38.40 38.40 38.40 38.40 38.40 38.40 38.40 38.40 38.40 38.40 Adm deg 38.40 38.40 38.40 38.40 38.40 38.40 Adm deg 229.79 233.50 236.27 240.94 245.66 6355.97 6438.34 6525.19 6615.86 6709.67 6805.89 6903.80 7002.64 7101.68 7200.15 7297.30 7392.40 7467.64 TVD, ft 7484.77 7576.11 7667.45 7758.79 7850.13 7941.47 8032.81 8124.15 8215.49 8306.83 8398.17 8489.51 8580.85 8672.19 8763.53 8824.84 TVD ft 8854.85 8946.19 9034.84 TVD ft 9037.52 9128.86 9171.85 TVD ft 6201.24 6216.56 6239.55 6278.04 6316.66 +N/-S " ft, ' -1542.37 -1564.03 -1581.02 -1593.22 -1600.54 -1602.93 -1600.36 -1592.85 -1580.46 -1563.29 -1541.47 -1515.16 -1490.62 , +N/-S .ft -1484.64 -1452.74 -1420.84 -1388.94 -1357.04 -1325.14 -1293.23 -1261.33 -1229.43 -1197.53 -1165.63 -1133.73 -1101.83 -1069.93 -1038.03 -1016.56 +N/-S ft -1006.08 -974.18 -943.21 +N/..S ft -942.28 -910.37 -895.35 +N/-S ft -1479.90 -1487.87 -1498.96 -1515.58 -1529.85 +E/~W ft -1650.95 -1703.29 -1749.79 -1790.07 -1823.85 -1850.85 -1870.88 -1883.78 -1889.45 -1887.86 -1879.00 -1862.96 -1844.76 +E/~W, ft -1840.02 -1814.74 -1789.45 -1764.17 -1738.88 -1713.60 -1688.31 -1663.03 -1637.75 -1612.46 -1587.18 -1561.89 -1536.61 -1511.33 -1486.04 -1468.98 +E/-W ft -1460.67 -1435.39 -1410.83 +E/-W ft -1410.09 -1384.81 -1372.90 +E/-W ft -1541.26 -1551.34 -1567.10 -1594.34 -1622.70 VS (t 2225.40 2281.07 2329.30 2369.71 2402.00 2425.92 2441.29 2447.99 2445.98 2435.26 2415.93 2388.12 2359.47 VS ft. 2352.23 2313.62 2275.02 2236.42 2197.81 2159.21 2120.60 2082.00 2043.39 2004.79 1966.18 1927.58 1888.97 1850.37 1811 .77 1785.75 vs ft 1773.07 1734.46 1696.97 VS ft 1695.84 1657.24 1639.06 Map Northing ft 5956119.92 5956111.75 5956100.34 5956083.16 5956068.32 , DtS.. . .B~itd .." ,rrll~I1" ,," deg(100ft..ï:I~g/1Qptt ,(f eg/10qff 5.00 -4.88 1.76 5.00 -4.86 2.10 5.00 -4.81 2.76 5.00 -4.74 3.83 5.00 -4.60 5.70 5.00 -4.33 9.30 5.00 -3.69 16.79 5.00 -2.10 29.95 5.00 0.76 35.18 5.00 3.07 22.86 5.00 4.08 12.35 5.00 4.49 7.18 4.99 4.66 4.77 DLS BÜild , Tùrl1 deg/1 00ftd~g/10Oftdegl1 000 ' 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 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 DLS Build Turn deg/100ft deg/100ft degl1000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 DLS Build Tùrn deg/100ft deg/10OOdeg/1 000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Map Easting ft 652612.51 652602.60 652587.07 652560.18 652532.12 TFO ,de9: 167.76 167.07 165.33 162.93 159.46 154.11 145.15 128.70 99.09 64.25 41.73 29.73 22.87 TFO deg 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 TFO ,deg 0.00 0.00 0.00 TFO deg 0.00 0.00 0.00 <-- Latitude --> <- Longitude -> Deg Min See Deg Min Sec 70 17 13.611 N 148 45 52.969 W 70 17 13.532 N 148 45 53.263 W 70 17 13.423 N 148 45 53.722 W 70 17 13.260 N 148 45 54.515 W 70 17 13.119 N 148 45 55.342 W 246.54 6355.97 -1542.37 -1650.95 5956055.22 652504.14 70 17 12.996 N 148 45 56.165 W 248.65 6438.34 -1564.03 -1703.29 5956032.50 652452.25 70 17 12.783 N 148 45 57.689 W ., . ~ . (l:QD1PItIJY':' lilPAmoco ' , Fiëld:', ,Prq( hoëB~Y: Sit~: ' PBI:'tPåd ' Wëll:' , ,,' Q~08..' .'. ,,' WØUp*tb:' , Plár1D,;08a ' Survey MD it 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 Iud dØg 27.28 22.55 17.95 13.62 9.93 7.83 8.59 11.66 8100.00 15.74 8200.00 20.23 8281.25 24.02 8300.00 24.02 8400.00 24.02 8500.00 24.02 8600.00 24.02 8700.00 24.02 8800.00 24.02 8900.00 24.02 9000.00 24.02 9100.00 24.02 9200.00 24.02 9300.00 24.02 9400.00 24.02 9500.00 24.02 9600.00 24.02 9700.00 24.02 9767.15 24.02 9800.00 24.02 9900.00 24.02 9997.07 24.02 10000.00 24.02 10100.00 24.02 10147.07 24.02 ) ') BP Amoco Planning Report - Geographic . .. .. . ,001 ,',,' 1;tDiØ: ' '17:12:26, " , )~~(ere~fë; '11:Q-08;rrllØN°rth ,Reference: ..8474;8' , ",' " "", ëtërenêê:. .", eU(().()PN;();OOE,23~h8~AZI) , , ";08AWP04', , " " , " ~ag~: . .. . .D.atë,: ,. '. 11/1 ëo~ördi:O ' . Vertical S,ettiòJ{( Plan: ' , , ~~~Latitu4ë .' ~~., ,<:+IJò~gitu()e ,~~ ' pegMht ,'See.,' "gëg'Mi~ "See .. .M:~P Northing' ft ' , 5956014.56 5956001.53 5955993.52 , lVl~P '. Ea~til1g , 652406.12 652366.09 652332.48 251.41 6525.19 255.23 6615.86 260.93 6709.67 +Nl-S . ft: -1581.02 -1593.22 -1600.54 -1749.79 -1790.07 -1823.85 70 17 12.616 N 148 45 59.044 W 70 17 12.496 N 148 46 0.218 W 70 17 12.424 N 148 46 1.201 W 270.23 6805.89 -1602.93 -1850.85 5955990.58 652305.53 70 17 12.400 N 148 46 1.988 W 287.02 6903.80 -1600.36 -1870.88 5955992.74 652285.46 70 17 12.425 N 148 46 2.572 W 316.96 7002.64 -1592.85 -1883.78 5955999.98 652272.41 70 17 12.499 N 148 46 2.948 W 352.14 7101.68 -1580.46 -1889.45 5956012.25 652266.48 70 17 12.621 N 148 46 3.113 W 15.00 7200.15 -1563.29 -1887.86 5956029.45 652267.73 70 17 12.790 N 148 46 3.067 W 27.35 7297.30 -1541.47 -1879.00 5956051.45 652276.13 70 17 13.004 N 148 46 2.809 W 34.53 7392.40 -1515.16 -1862.96 5956078.08 652291.63 70 17 13.263 N 148 46 2.342 W 38.40 7467.64 -1490.62 -1844.76 5956102.99 652309.32 70 17 13.505 N 148 46 1.812 W 38.40 7484.77 -1484.64 -1840.02 5956109.06 652313.94 70 17 13.563 N 148 46 1.673 W 38.40 7576.11 -1452.74 -1814.74 5956141.47 652338.56 70 17 13.877 N 148 46 0.937 W 38.40 7667.45 -1420.84 -1789.45 5956173.88 652363.18 70 17 14.191 N 148 46 0.201 W 38.40 7758.79 -1388.94 -1764.17 5956206.29 652387.81 70 17 14.505 N 148 45 59.464 W 38.40 7850.13 -1357.04 -1738.88 5956238.70 652412.43 70 17 14.819 N 148 45 58.728 W 38.40 7941.47 -1325.14 -1713.60 5956271.11 652437.05 70 17 15.132 N 148 45 57.991 W 38.40 8032.81 -1293.23 -1688.31 5956303.52 652461.67 70 17 15.446 N 148 45 57.255 W 38.40 8124.15 -1261.33 -1663.03 5956335.93 652486.30 70 17 15.760 N 148 45 56.518 W 38.40 8215.49 -1229.43 -1637.75 5956368.34 652510.92 70 17 16.074 N 148 45 55.782 W 38.40 8306.83 -1197.53 -1612.46 5956400.75 652535.54 70 17 16.388 N 148 45 55.045 W 38.40 8398.17 -1165.63 -1587.18 5956433.16 652560.17 70 17 16.701 N 148 45 54.309 W 38.40 8489.51 -1133.73 -1561.89 5956465.57 652584.79 70 17 17.015 N 148 45 53.573 W 38.40 8580.85 -1101.83 -1536.61 5956497.98 652609.41 70 17 17.329 N 148 45 52.836 W 38.40 8672.19 -1069.93 -1511.33 5956530.39 652634.04 70 17 17.643 N 148 45 52.100 W 38.40 8763.53 -1038.03 -1486.04 5956562.80 652658.66 70 17 17.957 N 148 45 51.363 W 38.40 8824.84 -1016.56 -1468.98 5956584.61 652675.28 70 17 18.168 N 148 45 50.866 W 38.40 8854.85 -1006.08 -1460.67 5956595.26 652683.36 70 17 18.271 N 148 45 50.624 W 38.40 8946.19 38.40 9034.84 38.40 9037.52 38.40 9128.86 38.40 9171.85 -974.18 -1435.39 5956627.67 652707.99 70 17 18.585 N 148 45 49.888 W -943.21 -1410.83 5956659.14 652731.90 70 17 18.889 N 148 45 49.172 W -942.28 -1410.09 5956660.09 652732.63 70 17 18.898 N 148 45 49.151 W -910.37 -1384.81 5956692.50 652757.25 70 17 19.212 N 148 45 48.414 W -895.35 -1372.90 5956707.76 652768.84 70 17 19.360 N 148 45 48.067 W Name .Nt.S WEI.L DET AII.S ANTI-COLLISION SETIINGS COMPANY DETAIT.S .r-¡.w Northing Easting Lalitude loogitOOe Slot BP Amoco Calculation Method: Minimum CUlvature EIror System: ISCWSA Scan Method: T ray Cylinder Nor1h Error Surfuœ: EDipIicaJ + Casing Warning Method: Rules Based D-08 2000,77 1998.98 5957631.00 654123,00 70"17'2.8,167N 148°45'08,06SW NtA Interpolation Method:MD Interval: 25.00 Depth Range From: 6900.00 To: 10147.07 Maximum Range: 12 I 1.27 Reference: Plan: D-08A WP04 -64 -60 -SO -40 -30 -20 -10 -0 270 -10 -20 -30 -40 -SO -60 -64 Colour \_:''''-~-:::: ~ ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4500 5500 7000 10000 SURVEY PROORAM Depth Fm Depth To Su""yiPIan Tool 6900.00 10147.07 Planned: D-08A WPß4 VI MWD WELLPA 111 DETAILS Plan D-Œa Paræt WeUpath: Tie on MD: D-08 6900.00 Rig: Ref Datum: 74.84 74.84/1 V.5",,1ion ~ Starting From NO 0,00 Origin Origin +W-S +E/.W 236.89° 0.00 0.00 LEGEND - O-OIA(D-OIA),~ Risk - D~I (D-OI), - 0-08 (0-08), - 0-16 (O-16), Major Risk - 0-31A{O-31A),MajorRisk - 0-31 (O-31), Major Risk - PIan~ - D-08A WPß4 ~ - SECTION DETAILS See MD Inc Azi lVD +W-S +E/-W DLeg TFace vSee Target 6900.00 39.g5 229.79 620124 -1479.90 -1541.26 0.00 0.00 2099.40 6920.00 40.12 23350 621656 -1487.87 -155134 12.00 85.00 2112.19 7050.00 3939 245.66 6316.66 -1529.85 -1622.70 6.00 loo,()() 2194.90 8281.25 24.02 38.40 7467.64 -1490.62 -1844.76 5.00 161.76 2359.47 9767.15 24.02 38.40 8824.84 -101656 -1468,98 0.00 0.00 1785.75 0-08A Polygon 9997.07 24.02 38.40 9034.84 -943.21 -1410,83 0.00 O,()() 1696.97 10147.07 24.02 38.40 9171.85 -89535 -1372.90 0.00 0.00 1639.06 18 &4 . : :.::::-;:.-v~ }/ /£ ft/in] ...'~ .. . . ') BP Amoco Anticollision Report ') 'çólDpany: , E1P Amoco, , , Fièld: , " prudhoeßay , Rêf~~~nêé Site. , pBpPåd. ' , ReferêncéWëll:, . D~08'" ,~~fëatênç~.Wellp!'tll: PlänD~08a. GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There arERHæJtJèlft'ells in thfillaetcID-08A WP04 & NOT PLANNED PROGRA Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 6900.00 to 10147.07 ft Scan Method: Trav Cylinder North Maximum Radius: 1211.27 ft Error Surface: Ellipse + Casing , Date; '. . " n116/2001 ,', , ,Tinie:16i3?:48, ' .. ..... . Ço~()r().inåte<N~j J{~fereJîce; Verfical('tVD)Referêncç:. " Casing Points ,MD TVD, Uiarnefër ,HolëSize ft ft ih In 9434.32 8520.84 7.000 8.500 7" 10098.15 9127.16 4.500 6.125 41/2" Plan: 0-08A WP04 Date Composed: 11/16/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary Reference Offset Ctr..Ctr "No~Go' MD MD Distance Arëa ,ft ,ft ft ft PB D Pad 0-01 A D-01A V3 Out of range PB D Pad 0-01 0-01 V1 Out of range PB D Pad 0-08 0-08 V6 6978.09 6975.00 4.07 610.01 -605.58 FAIL: Major Risk PB D Pad 0-16 0-16 V3 9147.15 9025.00 682.97 674.97 9.13 Pass: Major Risk PB D Pad 0-31 A D-31A V1 9662.15 8850.00 477.05 376.79 274.79 Pass: Major Risk PB D Pad 0-31 0-31 V1 8775.69 8450.00 529.60 400.14 130.53 Pass: Major Risk Site: PB 0 Pad Well: 0-08 Rule Assigned: Major Risk WelIpath: 0-08 V6 Inter-Site Error: 0.00 ft Refërence Offset Seö1i~Major }\xis Ctr~Ctr ", Nó..Go , Allowable MD TVD MD TVD Ref Offset TfO+AZI.TJj'()~HS .Çasing, ,Di!itanceArea' Devlatiói1 Warning' ft ft ft ft ft ft deg cj~g in ft ,ft ft 6903.34 6203.80 6900.00 6200.51 95.39 95.43 343.73 113.32 9.625 0.18 605.40 -548.46 FAIL 6928.33 6222.94 6925.00 6219.74 95.41 96.00 120.55 246.28 9.625 0.57 606.48 -580.04 FAIL 6953.25 6242.05 6950.00 6239.02 95.18 96.59 132.83 256.26 9.625 2.01 608.77 -603.99 FAIL 6978.09 6261.16 6975.00 6258.34 94.86 97.11 137.39 258.50 9.625 4.07 610.01 -605.58 FAIL 7002.82 6280.22 7000.00 6277.70 94.53 97.57 140.20 258.99 9.625 6.75 610.50 -603.87 FAIL 7027.39 6299.19 7025.00 6297.10 94.10 97.96 142.18 258.66 9.625 10.04 609.86 -600.36 FAIL 7051.80 6318.05 7050.00 6316.56 93.71 98.32 143.66 257.97 9.625 13.98 608.79 -596.13 FAIL 7076.44 6337.28 7075.00 6336.06 93.73 99.14 145.18 259.07 9.625 18.19 611.39 -593.39 FAIL 7101.04 6356.79 7100.00 6355.62 93.76 99.95 147.30 260.74 9.625 22.46 614.44 -589.56 FAIL 7125.59 6376.58 7125.00 6375.23 93.79 100.77 149.74 262.71 9.625 26.80 617.39 -584.14 FAIL 7150.08 6396.62 7150.00 6394.87 93.82 101.58 152.36 264.83 9.625 31.24 620.27 -577.04 FAIL 7174.49 6416.87 7175.00 6414.55 93.85 102.39 155.07 267.01 9.625 35.81 623.06 -568.23 FAIL 7198.79 6437.31 7200.00 6434.27 93.88 103.20 157.81 269.19 9.625 40.56 625.77 -557.76 FAIL 7222.98 6457.92 7225.00 6454.03 93.91 104.01 160.54 271.33 9.625 45.51 628.55 -545.64 FAIL 7247.03 6478.66 7250.00 6473.83 93.95 104.83 163.25 273.40 9.625 50.68 631.12 -531.91 FAIL 7270.94 6499.52 7275.00 6493.65 93.99 105.64 165.89 275.38 9.625 56.09 633.57 -516.86 FAIL 7294.67 6520.45 7300.00 6513.52 94.02 106.44 168.46 277.23 9.625 61.77 635.89 -500.69 FAIL 7318.23 6541.44 7325.00 6533.43 94.06 107.25 170.94 278.93 9.625 67.74 638.12 -483.31 FAIL 7341.59 6562.47 7350.00 6553.39 94.11 108.05 173.29 280.46 9.625 74.01 640.09 -465.09 FAIL 7364.76 6583.50 7375.00 6573.40 94.15 108.85 175.53 281.81 9.625 80.60 641.84 -446.43 FAIL 7387.70 6604.52 7400.00 6593.47 94.19 109.65 177.65 282.97 9.625 87.51 644.52 -427.52 FAIL 7410.42 6625.49 7425.00 6613.57 94.23 110.45 179.66 283.95 9.625 94.76 647.86 -407.94 FAIL 7432.90 6646.40 7450.00 6633.72 94.27 111.25 181.58 284.74 9.625 102.36 650.96 -387.55 FAIL 7455.12 6667.21 7475.00 6653.90 94.31 112.04 183.39 285.33 9.625 110.31 653.74 -367.23 FAIL 7477.08 6687.92 7500.00 6674.12 94.36 112.82 185.10 285.72 9.625 118.61 656.18 -347.15 FAIL 7500.00 6709.66 7525.00 6694.39 94.40 113.62 186.73 285.81 9.625 127.27 658.21 -327.39 FAIL 7520.20 6728.93 7550.00 6714.69 94.44 114.40 188.26 285.83 9.625 136.23 659.60 -305.71 FAIL 7541.36 6749.20 7575.00 6735.04 94.48 115.18 189.72 285.54 9.625 145.54 662.16 -284.34 FAIL >' 1 .' . ) BP Amoco Anticollision Report ) . . .. . c;QDt¡>;tPY: ' 'BPArnOëO , Fiëld: ' ., , 'f'r~dhoea~y ,Refè..ênteSite: ,PB,DPad. Reférenê~Well: D~Ö8 ", . Rè(ër~nce'Welipatli:,.. PI~n D-()8a ' Site: PB 0 Pad Well: 0-08 Wellpath: 0-08 V6 , R,efért\nce MD, TV» fift ' 7562.23 6769.30 7582.83 6789.21 Date: .',11/16/2001 . THne: .'16:3:7:48', ço.;or(:Unatê(NJDJ~eferè~ëê: ' Vertic'al (TVD) Refér~nëe: ' , Offset' , " , MD TV» ft ' ,ft . 7600.00 6755.43 7625.00 6775.88 "Semi;;l\{âjQI"^xis. . " 'I{ë{ 'OffsètTFO+AZr''rFmHS ". CaSing ft, 'ft' deg d~gin '. 94.52 115.96 191.09 284.98 9.625 94.56 116.74 192.40 284.15 9.625 Rule Assigned: Inter-Site Error: Ctr-Ctr .' Nô';Go Distarite .' Mea ,ft ft' 155.16 665.71 165.10 668.50 Major Risk 0.00 ft Allowable 'Deviåtiori . . . 'Yarning. ft -263.71 FAIL -244.01 FAIL 7600.00 6805.88 7650.00 6796.37 94.60 117.50 193.62 283.40 9.625 175.37 670.51 -225.33 FAIL 7623.17 6828.44 7675.00 6816.91 94.64 118.28 194.81 281.57 9.625 185.87 671.41 -201.08 FAIL 7642.91 6847.73 7700.00 6837.51 94.68 119.04 195.92 279.75 .9.625 196.69 675.48 -179.06 FAIL 7662.37 6866.80 7725.00 6858.16 94.72 119.80 196.97 277.54 9.625 207.80 677.59 -158.65 FAIL 7681.55 6885.63 7750.00 6878.87 94.76 120.55 197.97 274.90 9.625 219.17 678.50 -140.07 FAIL 7700.00 6903.78 7775.00 6899.63 94.80 121.30 198.92 271.91 9.625 230.81 682.74 -123.41 FAIL 7719.07 6922.58 7800.00 6920.46 94.83 122.04 199.82 268.23 9.625 242.71 683.18 -98.50 FAIL 7737.39 6940.67 7825.00 6941.33 94.87 122.79 200.68 264.17 9.625 254.89 687.24 -75.97 FAIL 7755.40 6958.48 7850.00 6962.22 94.90 123.53 201.48 259.64 9.625 267.38 687.11 -55.64 FAIL 7773.11 6976.00 7875.00 6983.15 94.94 124.26 202.25 254.70 9.625 280.18 691.85 -37.33 FAIL 7790.51 6993.23 7900.00 7004.09 94.97 124.99 202.98 249.43 9.625 293.27 692.85 -20.70 FAIL 7800.00 7002.63 7925.00 7025.08 94.99 125.70 203.64 246.69 9.625 306.73 696.44 -3.72 FAIL 7824.46 7026.86 7950.00 7046.11 95.03 126.44 204.33 238.37 9.625 320.18 698.55 15.09 Pass 7841.02 7043.27 7975.00 7067.20 95.06 127.17 204.97 232.88 9.625 333.97 699.14 33.73 Pass 7857.31 7059.41 8000.00 7088.33 95.09 127.88 205.58 227.58 9.625 347.96 703.29 52.95 Pass 7873.33 7075.28 8025.00 7109.51 95.12 128.59 206.17 222.59 9.625 362.18 703.78 73.20 Pass 7900.00 7101.67 8050.00 7130.73 95.17 129.33 206.76 214.63 9.625 376.80 705.36 97.87 Pass 7900.00 7101.67 8075.00 7152.00 95.17 129.99 207.25 215.12 9.625 391.27 707.36 116.41 Pass 7919.80 7121.23 8100.00 7173.31 95.20 130.70 207.78 209.98 9.625 406.06 712.01 131.71 Pass 7934.76 7136.00 8125.00 7194.66 95.23 131.40 208.27 206.58 9.625 421.11 712.69 149.64 Pass 7949.46 7150.49 8150.00 7216.03 95.25 132.09 208.73 203.56 9.625 436.38 715.52 169.05 Pass 7963.88 7164.69 8175.00 7237.42 95.28 132.78 209.18 200.88 9.625 451.87 718.39 189.81 Pass 7978.05 7178.61 8200.00 7258.84 95.30 133.47 209.61 198.50 9.625 467.57 719.26 211.75 Pass 8000.00 7200.14 8225.00 7280.31 95.34 134.17 210.04 195.05 9.625 483.55 722.16 237.54 Pass 8000.00 7200.14 8250.00 7301.82 95.34 134.81 210.39 195.40 9.625 499.53 724.10 256.49 Pass 8019.13 7218.85 8275.00 7323.38 95.36 135.50 210.79 192.83 9.625 515.67 726.69 274.27 8032.39 7231.78 8300.00 7345.00 95.38 136.17 211.15 191.33 9.625 532.00 728.19 293.34 8045.42 7244.47 8325.00 7366.66 95.40 136.83 211.50 190.00 9.625 548.48 729.10 313.08 8058.21 7256.90 8350.00 7388.33 95.42 137.50 211.84 188.80 9.625 565.15 730.85 333.42 8070.77 7269.08 8375.00 7410.03 95.44 138.15 212.17 187.72 9.625 581.98 733.98 354.28 Pass Pass Pass Pass Pass 8083.11 7281.00 8400.00 7431.75 95.46 138.81212.48 186.76 9.625 598.99 736.61 375.59 Pass 8100.00 7297.29 8425.00 7453.49 95.48 139.48 212.80 185.46 9.625 616.19 738.86 398.32 Pass 8100.00 7297.29 8450.00 7475.26 95.48 140.11 213.05 185.71 9.625 633.55 740.76 417.86 Pass 8118.79 7315.34 8475.00 7497.04 95.50 140.77 213.36 184.38 9.625 650.96 742.46 437.48 Pass 8130.26 7326.32 8500.00 7518.84 95.52 141.42 213.63 183.73 9.625 668.59 744.00 457.52 Pass 8141.54 7337.08 8525.00 7540.67 95.53 142.07 213.90 183.15 9.625 686.35 745.40 477.84 Pass 8152.61 7347.63 8550.00 7562.52 95.54 142.71 214.17 182.62 9.625 704.23 746.68 498.45 Pass 8163.51 7357.97 8575.00 7584.40 95.56 143.35 214.43 182.13 9.625 722.22 748.27 519.31 Pass 8174.21 7368.11 8600.00 7606.30 95.57 143.99 214.68 181.70 9.625 740.33 750.79 540.40 Pass 8200.00 7392.39 8625.00 7628.23 95.60 144.66 214.98 180.46 9.625 758.81 753.99 563.79 Pass 8200.00 7392.39 8650.00 7650.17 95.60 145.28 215.19 180.67 9.625 776.95 755.84 583.81 Pass 8200.00 7392.39 8675.00 7672.12 95.60 145.89 215.40 180.88 9.625 795.43 757.70 604.09 Pass 8200.00 7392.39 8700.00 7694.09 95.60 146.50 215.59 181.07 9.625 814.24 759.53 624.60 Pass 8224.98 7415.74 8725.00 7716.08 95.62 147.17 215.88 180.02 9.625 832.73 762.09 645.85 Pass 8234.60 7424.69 8750.00 7738.08 95.63 147.80 216.10 179.77 9.625 851.56 764.11 666.89 Pass 8244.06 7433.45 8775.00 7760.09 95.64 148.42 216.32 179.54 9.625 870.51 766.06 688.08 Pass 8253.35 7442.04 8800.00 7782.12 95.65 149.05 216.54 179.33 9.625 889.55 767.96 709.40 Pass 8262.50 7450.46 8825.00 7804.19 95.66 149.67 216.75 179.13 9.625 908.68 769.80 730.80 Pass 8281.25 7467.64 8850.00 7826.31 95.68 150.30 216.99 178.58 9.625 927.95 771.55 753.20 Pass " .. ') BP Amoco Anticollision Report C9.IJ'tP~ny: BPNrioèp, F.i~hi:; " FrLJdhpéB~y Rêfêrence.Site: FB (fPad ,', ,RêferencêWêll:" 'D~08 . ,."" , Refetèncê;Wêllpa~h:PI.anD';08a Site: PB D Pad Well: 0-08 Wellpath: 0-08 V6 D~te: 11/16/2001 " , , TJnie:16:37:4S. ') . .. . . . . . . . . . 'Co--órdiliat~(NE) i{èfereJice:. VVell:Q~Q~;'True North Vërtiêål (¡YP)Reference: ' 74.a474;8" , , Rule Assigned: Inter-Site Error: Major Risk 0.00 ft , , ' Reference 'Offset'. Sêßlii.Majo..~xis ' " ' cti<ctr ..NoLGo ,. AlloWable, , MD . ," " 'TVD , MD . , ',' 'TVD , ' "Ref.. ".offset" TF.o+AztT);tOi.~SCasirig 'DistaliceÀrea" "Dêviätion, ' ft ' ft ' .ft ' 'ft. ft ' ' ft degdeg.in ft ft .ft:' , 8281.25 7467.64 8875.00 7848.48 95.68 150.90 217.16 178.75 9.625 947.09 773.35 773.85 Pass 8295.55 7480.71 8900.00 7870.70 95.68 151.49 217.32 178.92 9.625 966.32 775.13 794.58 Pass 8311.36 7495.15 8925.00 7892.97 95.68 152.08 217.48 179.08 9.625 985.49 776.90 815.19 Pass 8327.24 7509.65 8950.00 7915.27 95.67 152.66 217.64 179.23 9.625 1004.62 778.64 835.71 Pass 8343.17 7524.21 8975.00 7937.60 95.67 153.24 217.79 179.38 9.625 1023.70 780.37 856.15 Pass 8359.17 7538.82 9000.00 7959.97 95.67 153.82 217.93 179.53 9.625 1042.72 782.10 876.50 Pass 8375.22 7553.48 9025.00 7982.37 95.67 154.38 218.08 179.68 9.625 1061.70 783.81 896.74 Pass 8391.34 7568.21 9050.00 8004.80 95.67 154.95 218.22 179.82 9.625 1080.63 785.50 916.90 Pass 8407.53 7582.99 9075.00 8027.27 95.66 155.52 218.36 179.96 9.625 1099.50 787.22 936.97 Pass 8423.77 7597.82 9100.00 8049.76 95.66 156.08 218.50 180.09 9.625 1118.32 788.90 956.97 Pass 8440.02 7612.67 9125.00 8072.26 95.66 156.65 218.63 180.23 9.625 1137.12 790.61 976.90 Pass 8456.25 7627.49 9150.00 8094.74 95.66 157.22 218.77 180.36 9.625 1155.95 792.31 996.85 8472.43 7642.27 9175.00 8117.19 95.66 157.78 218.90 180.50 9.625 1174.80 794.01 1016.84 8488.58 7657.02 9200.00 8139.61 95.66 158.35 219.04 180.64 9.625 1193.67 795.70 1036.86 Site: PB D Pad Well: 0-16 Wellpath: 0-16 V3 Referenc,e MD TVD ,ft ft 8365.38 7544.49 8379.14 7557.06 8392.94 7569.67 8406.78 7582.31 8420.67 7594.99 S~mii.Major AXis , Rèf '.offset TFO+AZI T,F'O~HS' Casing' ft Jt ' deg dèg in 95.67 92.06 54.44 16.04 7.000 95.67 92.78 55.03 16.62 7.000 95.67 93.49 55.62 17.22 7.000 95.66 94.19 56.24 17.83 7.000 95.66 94.90 56.87 18.46 7.000 Rule Assigned: Inter-Site Error: Ctr,;Ctt ,'Noi.Go , Distance ,'Area' ft ft 1202.07 573.12 1185.06 575.17 1168.20 577.22 1151.50 579.23 1134.95 581.24 .offset MD TVD ft ft 7700.00 7077.93 7725.00 7098.53 7750.00 7119.15 7775.00 7139.80 7800.00 7160.48 Pass Pass Pass Major Risk 0.00 ft Allowable Deviation ft 928.60 905.69 882.75 859.81 836.85 Pass Pass Pass Pass Pass 8434.59 7607.70 7825.00 7181.18 95.66 95.61 57.52 19.11 7.000 1118.57 583.28 813.87 Pass 8448.56 7620.46 7850.00 7201.91 95.66 96.31 58.18 19.78 7.000 1102.37 585.30 790.89 Pass 8462.57 7633.26 7875.00 7222.67 95.66 97.01 58.87 20.47 7.000 1086.35 587.31 767.94 Pass 8476.62 7646.10 7900.00 7243.45 95.66 97.71 59.58 21.17 7.000 1070.53 589.30 745.01 Pass 8490.72 7658.97 7925.00 7264.26 95.66 98.41 60.30 21.90 7.000 1054.89 591.32 722.07 Pass 8504.84 7671.87 7950.00 7285.09 95.66 99.11 61.05 22.65 7.000 1039.45 593.30 699.15 Pass 8519.00 7684.81 7975.00 7305.95 95.65 99.81 61.82 23.42 7.000 1024.21 595.29 676.28 Pass 8533.20 7697.77 8000.00 7326.82 95.65 100.50 62.62 24.21 7.000 1009.18 597.27 653.45 Pass 8547.44 7710.78 8025.00 7347.73 95.65 101.19 63.43 25.03 7.000 994.36 599.26 630.67 Pass 8561.76 7723.86 8050.00 7368.69 95.65 101.88 64.26 25.86 7.000 979.75 601.23 607.96 Pass 8576.15 7737.00 8075.00 7389.70 95.65 102.57 65.12 26.72 7.000 965.36 603.19 585.33 Pass 8590.60 7750.20 8100.00 7410.77 95.65 103.25 66.00 27.59 7.000 951.19 605.14 562.80 Pass 8605.10 7763.44 8125.00 7431.86 95.65 103.93 66.90 28.49 7.000 937.24 607.09 540.34 Pass 8619.60 7776.69 8150.00 7452.96 95.65 104.61 67.82 29.42 7.000 923.52 609.05 517.96 Pass 8634.11 7789.94 8175.00 7474.06 95.65 105.29 68.78 30.37 7.000 910.05 610.99 495.68 Pass 8648.63 7803.20 8200.00 7495.18 95.65 105.96 69.76 31.35 7.000 896.83 612.93 473.52 Pass 8663.17 7816.48 8225.00 7516.30 95.65 106.65 70.77 32.36 7.000 883.87 614.89 451.47 Pass 8677.74 7829.79 8250.00 7537.45 95.65 107.33 71.80 33.40 7.000 871.21 616.85 429.60 Pass 8692.35 7843.14 8275.00 7558.63 95.65 108.00 72.87 34.47 7.000 858.85 618.79 407.92 Pass 8706.99 7856.51 8300.00 7579.82 95.65 108.68 73.96 35.56 7.000 846.80 620.70 386.46 Pass 8721.66 7869.91 8325.00 7601.04 95.65 109.36 75.09 36.69 7.000 835.08 622.65 365.22 Pass 8736.35 7883.33 8350.00 7622.26 95.65 110.03 76.25 37.84 7.000 823.71 624.60 344.25 Pass 8751.06 7896.76 8375.00 7643.50 95.65 110.70 77.43 39.03 7.000 812.71 626.53 323.60 Pass 8765.79 7910.22 8400.00 7664.75 95.65 111.37 78.65 40.25 7.000 802.10 628.45 303.29 Pass 8780.55 7923.70 8425.00 7686.01 95.65 112.05 79.90 41.50 7.000 791.87 630.39 283.31 Pass >' I . .' ) ) BP Amoco Anticollision Report çQmp~ny: ; i3PAr¡nocq Date: ".".11116/2001 , , Time: 1.6:37:48 " ,'Field: , , , Arughöeßay, ' .. ' , Rêfeten~eSite:' ÞSDPad' Co';Q~(t@,t~~J$)Jl~fêrêriç~:' Rêfêr~nceWêli: ' 'DL.o8'", Vertitål(TVi)Rêfêreltce:. '. ,'Refeh~i1ce Wellpatll: Plan Dt08ä " Site: PB 0 Pad Well: 0-16 Rule Assigned: Major Risk Wellpath: 0-16 V3 Inter-Site Error: 0.00 ft " Reference Offset' .Se~i';MaJorAxis ' " , Ctt-Ctt;' No~GÒ. Allowable " 'MD tVD MD Tvn ,Ref.' Offset.. TfO'fJ\Zi TfO-'IIS (Jåsing' 'DiståncêAr~a Deviation '. ft ft ft ,ft ,ft. ft deg 'deg" in ¡ft: "ft ft , , 8795.33 7937.20 8450.00 7707.28 95.65 112.73 81.19 42.78 7.000 782.05 632.33 263.74 Pass 8810.14 7950.72 8475.00 7728.57 95.65 113.40 82.50 44.09 7.000 772.65 634.24 244.62 Pass 8824.97 7964.27 8500.00 7749.87 95.65 114.06 83.84 45.44 7.000 763.68 636.15 226.00 Pass 8839.81 7977.82 8525.00 7771.19 95.65 114.74 85.22 46.81 7.000 755.15 638.10 207.86 Pass 8854.66 7991.39 8550.00 7792.50 95.66 115.42 86.62 48.22 7.000 747.07 640.03 190.27 Pass 8869.52 8004.96 8575.00 7813.82 95.66 116.09 88.06 49.65 7.000 739.44 641.96 173.29 Pass 8884.38 8018.54 8600.00 7835.15 95.66 116.75 89.52 51.12 7.000 732.28 643.87 156.96 Pass 8899.30 8032.16 8625.00 7856.51 95.66 117.42 91.01 52.60 7.000 725.59 645.78 141.32 Pass 8914.32 8045.88 8650.00 7877.95 95.66 118.08 92.51 54.11 7.000 719.32 647.66 126.38 Pass 8929.44 8059.69 8675.00 7899.47 95.66 118.73 94.03 55.63 7.000 713.50 649.55 112.18 Pass 8944.67 8073.60 8700.00 7921.06 95.66 119.39 95.57 57.17 7.000 708.12 651.43 98.76 Pass 8959.96 8087.57 8725.00 7942.70 95.66 120.03 97.13 58.72 7.000 703.19 653.29 86.17 Pass 8975.32 8101.59 8750.00 7964.39 95.67 120.67 98.70 60.29 7.000 698.73 655.14 74.43 Pass 8990.72 8115.66 8775.00 7986.11 95.67 121.30 100.28 61.88 7.000 694.75 656.98 63.55 Pass 9006.18 8129.78 8800.00 8007.88 95.67 121.93 101.88 63.48 7.000 691.24 658.78 53.57 Pass 9021.68 8143.94 8825.00 8029.68 95.67 122.56 103.49 65.09 7.000 688.23 660.62 44.54 Pass 9037.21 8158.13 8850.00 8051.50 95.67 123.19 105.11 66.71 7.000 685.75 662.44 36.49 Pass 9052.77 8172.34 8875.00 8073.34 95.68 123.82 106.74 68.34 7.000 683.80 664.26 29.46 Pass 9068.37 8186.59 8900.00 8095.21 95.68 124.44 108.38 69.97 7.000 682.38 666.06 23.46 Pass 9084.01 8200.87 8925.00 8117.10 95.68 125.06 110.01 71.61 7.000 681.48 667.87 18.51 Pass 9099.71 8215.21 8950.00 8139.04 95.68 125.67 111.65 73.25 7.000 681 .1 0 669.66 14.59 Pass 9115.46 8229.60 8975.00 8161.01 95.69 126.29 113.28 74.88 7.000 681.22 671.43 11.73 Pass 9131.27 8244.04 9000.00 8183.02 95.69 126.90 114.91 76.51 7.000 681.85 673.21 9.91 Pass 9147.15 8258.54 9025.00 8205.08 95.69 127.50 116.53 78.12 7.000 682.97 674.97 9.13 Pass 9163.10 8273.11 9050.00 8227.20 95.69 128.10 118.14 79.73 7.000 684.54 676.72 9.34 Pass 9179.13 8287.75 9075.00 8249.36 95.70 128.69 119.73 81.33 7.000 686.57 678.46 10.53 Pass 9195.23 8302.46 9100.00 8271.57 95.70 129.28 121.31 82.91 7.000 689.05 680.20 12.68 Pass 9211.40 8317.23 9125.00 8293.84 95.70 129.87 122.87 84.47 7.000 691.97 681.88 15.79 Pass 9227.63 8332.05 9150.00 8316.14 95.71 130.44 124.42 86.02 7.000 695.35 683.59 19.84 Pass 9243.92 8346.93 9175.00 8338.48 95.71 131.02 125.94 87.54 7.000 699.18 685.28 24.80 Pass 9260.28 8361.87 9200.00 8360.86 95.71 131.59 127.45 89.05 7.000 703.44 686.97 30.64 Pass 9276.69 8376.86 9225.00 8383.29 95.72 132.16 128.93 90.53 7.000 708.13 688.63 37.34 Pass 9293.16 8391.91 9250.00 8405.74 95.72 132.72 130.39 91.99 7.000 713.23 690.29 44.85 Pass 9309.70 8407.01 9275.00 8428.24 95.72 133.28 131.83 93.42 7.000 718.72 691.92 53.13 Pass 9326.28 8422.16 9300.00 8450.77 95.73 133.84 133.24 94.83 7.000 724.61 693.57 62.05 Pass 9342.89 8437.33 9325.00 8473.32 95.73 134.40 134.62 96.22 7.000 730.90 695.23 71.63 Pass 9359.48 8452.48 9350.00 8495.85 95.74 134.96 135.98 97.58 7.000 737.64 696.88 81.97 Pass 9376.05 8467.62 9375.00 8518.38 95.74 135.51 137.32 98.92 7.000 744.80 698.52 93.03 Pass 9392.61 8482.74 9400.00 8540.89 95.74 136.07 138.63 100.23 7.000 752.39 700.16 104.77 Pass 9409.25 8497.94 9425.00 8563.45 95.75 136.60 139.91 101.51 7.000 760.31 701.73 117.10 Pass 9426.08 8513.31 9450.00 8586.12 95.75 137.14 141.15 102.75 7.000 768.50 703.31 129.88 Pass 9443.11 8528.87 9475.00 8608.90 95.76 137.67 142.36 103.95 7.000 776.93 704.89 143.03 Pass 9460.33 8544.59 9500.00 8631.79 95.76 138.20 143.53 105.12 7.000 785.57 706.46 156.50 Pass 9477.69 8560.45 9525.00 8654.76 95.77 138.70 144.66 106.26 7.000 794.44 707.91 170.40 Pass 9495.16 8576.41 9550.00 8677.78 95.77 139.19 145.76 107.36 7.000 803.55 709.37 184.63 Pass 9512.74 8592.46 9575.00 8700.87 95.78 139.68 146.84 108.43 7.000 812.88 710.70 199.24 Pass 9530.42 8608.61 9600.00 8724.01 95.78 140.17 147.88 1 09.48 7.000 822.43 712.14 214.03 Pass 9548.20 8624.85 9625.00 8747.20 95.79 140.63 148.89 110.49 7.000 832.18 713.52 229.11 Pass 9566.07 8641.18 9650.00 8770.44 95.80 141.10 149.88 111.47 7.000 842.11 714.89 244.41 Pass 9584.04 8657.58 9675.00 8793.73 95.80 141.56 150.83 112.43 7.000 852.22 716.25 259.89 Pass 9602.09 8674.08 9700.00 8817.06 95.81 142.02 151.76 113.36 7.000 862.49 717.59 275.52 Pass \I' 't. ., l' 'w , Comp~ny; p,jeld: ' Rêferënce'Sitë: RëtërenêeWell: ,.~ef~r~nêe Wellpath: Site: PB 0 Pad Well: 0-16 Wellpath: 0-16 V3 Rêference ' MD 'TV» ft ft 9620.22 8690.64 9638.41 8707.25 9656.66 8723.91 9674.96 8740.63 ) BP Amoco Anticollision Report . BPAmoco Rtudt1q~ßay PB'DPåd. <[)..08, ' , Plån D::08a Cöi;Qrdinat~~El J.{efêren~ë: ' W~H:,D';08;'T(~e'North, ' Vertiêål(TVIU>Refeterice:. ' 74';8474.8 " , " , , , Thue: , 16:37:48 Rule Assigned: Inter-Site Error: "ëtrJCtt "Nö::Go ' DistanêêAreå" . , ,ft ' 'ft 872.94 718.91 883.60 720.22 894.45 721.52 905.49 722.82 ) Major Risk 0.00 ft Allowable Deviåtiòn , ,ft , 291.39 Pass 307.44 Pass 323.65 Pass 340.01 Pass 9693.33 8757.41 9825.00 8934.17 95.84 144.22 156.02 117.62 7.000 916.66 724.07 356.49 Pass 9711.80 8774.28 9850.00 8957.70 95.85 144.65 156.80 118.40 7.000 927.89 725.30 372.99 Pass 9730.37 8791.24 9875.00 8981.29 95.85 145.07 157.56 119.16 7.000 939.19 726.55 389.51 Pass 9749.03 8808.29 9900.00 9004.92 95.86 145.49 158.30 119.89 7.000 950.54 727.79 406.03 Pass 9767.73 8825.37 9925.00 9028.57 95.87 145.90 159.02 120.61 7.000 962.00 729.00 422.63 Pass 9786.41 8842.43 9950.00 9052.21 95.88 146.32 159.72 121.32 7.000 973.63 730.21 439.38 Pass 9805.07 8859.47 9975.00 9075.84 95.88 146.73 160.41 122.00 7.000 985.43 731.41 456.24 Pass 9823.71 8876.50 10000.00 9099.45 95.89 147.14 161.08 122.67 7.000 997.39 732.62 473.23 Pass 9842.36 8893.53 10025.00 9123.08 95.90 147.55 161.73 123.33 7.000 1009.48 733.83 490.30 Pass 9861.06 8910.61 10050.00 9146.72 95.91 147.96 162.37 123.96 7.000 1021.66 735.04 507.39 Pass Offset NiD TVI> ftft 9725.00 8840.43 9750.00 8863.83 9775.00 8887.25 9800.00 8910.69 Date: 11/16/2001, Sell1i;,Majeu"AXis ' , , . Rër "Offšet' tFO+~ZI TFO';HSqasirig . ft, ft ' ' , dëg deg in 95.81 142.47 152.67 114.26 7.000 95.82 142.91 153.54 115.14 7.000 95.83 143.36 154.39 115.99 7.000 95.83 143.80 155.22 116.82 7.000 9879.80 8927.73 10075.00 9170.39 95.92 148.37 162.98 124.58 7.000 1033.94 736.25 524.50 Pass 9898.58 8944.88 10100.00 9194.07 95.92 148.78 163.59 125.18 7.000 1046.30 737.45 541.63 Pass 9917.47 8962.13 10125.00 9217.81 95.93 149.18 164.17 125.77 7.000 1058.64 738.59 558.67 Pass 9936.51 8979.52 10150.00 9241.63 95.94 149.57 164.74 126.34 7.000 1070.87 739.75 575.55 Pass 9955.62 8996.98 10175.00 9265.48 95.95 149.95 165.30 126.90 7.000 1083.09 740.88 592.37 Pass 9974.74 9014.44 10200.00 9289.34 95.96 150.32 165.85 127.45 7.000 1095.41 742.00 609.24 Pass 9993.85 9031.90 10225.00 9313.20 95.97 150.70 166.38 127.98 7.000 1107.82 743.12 626.15 Pass 10012.97 9049.36 10250.00 9337.06 95.98 151.08 166.90 128.50 7.000 1120.33 744.23 643.08 Pass 10032.08 9066.82 10275.00 9360.92 95.99 151.47 167.42 129.01 7.000 1132.94 745.38 660.04 Pass 10051.20 9084.28 10300.00 9384.78 96.00 151.86 167.91 129.51 7.000 1145.62 746.52 677.04 Pass 10070.31 9101.74 10325.00 9408.64 96.01 152.24 168.40 130.00 7.000 1158.40 747.67 694.06 Pass 10089.43 9119.20 10350.00 9432.49 96.02 152.63 168.88 130.48 7.000 1171.26 748.81 711.11 Pass Site: PB 0 Pad Well: D-31A Wellpath: D-31A V1 Reference MD TVD ftft 6962.86 6249.44 7028.94 6300.39 7140.26 6388.54 7283.63 6510.69 7437.74 6650.93 Offset MD TVD ft ft 7100.00 6819.14 7125.00 6843.57 7150.00 6868.05 7175.00 6892.58 7200.00 6917.16 Semi-Major Axis Ref Offset TFO+AZI '{FO-HS Casing ft ft deg deg in 95.05 18.80 26.45 148.98 94.07 18.86 28.20 144.53 93.81 18.88 29.36 142.03 94.01 18.91 30.19 139.30 94.28 18.92 30.98 133.89 7598.53 6804.45 7225.00 6941.78 94.60 18.94 31.71 121.67 7760.66 6963.68 7250.00 6966.45 94.91 18.96 32.38 88.89 7918.50 7119.95 7275.00 6991.16 95.20 18.97 32.95 35.51 8067.33 7265.74 7300.00 7015.92 95.43 18.99 33.44 9.37 8204.02 7396.17 7325.00 7040.71 95.60 19.01 33.84 359.09 8289.62 7475.29 7350.00 7065.54 95.68 19.04 33.99 355.58 8311.37 7495.16 7375.00 7090.39 95.68 19.06 33.86 355.46 8333.23 7515.13 7400.00 7115.28 95.67 19.09 33.74 355.34 8355.21 7535.20 7425.00 7140.19 95.67 19.11 33.63 355.23 8377.29 7555.36 7450.00 7165.12 95.67 19.13 33.53 355.12 8399.40 7575.56 7475.00 7190.05 95.66 19.15 33.42 355.02 8421.52 7595.77 7500.00 7214.99 95.66 19.17 33.32 354.91 8443.64 7615.97 7525.00 7239.93 95.66 19.19 33.21 354.81 8465.77 7636.19 7550.00 7264.86 95.66 19.20 33.10 354.70 Rule Assigned: Inter-Site Error: Ctr-Ctr' . No-Go Distarice Area ft ft 1029.33 375.23 1039.16 372.60 1047.94 370.91 1054.50 372.32 1058.49 372.64 Major Risk 0.00 ft AlIöwable Deviation ft 846.26 859.21 874.50 888.77 901.52 Warning Pass Pass Pass Pass Pass 1059.63 373.91 909.36 Pass 1057.80 374.01 921.64 Pass 1053.04 375.94 911.76 Pass 1045.53 375.87 911.15 Pass 1035.58 376.95 908.80 Pass 1023.68 377.72 898.88 Pass 1011.56 377.76 886.08 Pass 999.61 377.82 873.48 Pass 987.85 377.89 861.10 Pass 976.26 377.94 848.94 Pass 964.73 377.99 836.84 Pass 953.22 378.02 824.75 Pass 941.71 378.07 812.65 Pass 930.22 378.12 800.55 Pass ì" ( '. .. ) ) BP Amoco Anticollision Report qo~p~ny: ' BPAmoco Date: 1111.6/2001 'Time:,. 16:37:48 , FieHt:" Pr~dho$ Bay Réfer~nceSitè: PBDPad, ,'.' Co';ortlinåÍç(NE)~eféren,ce:' ' ,ReferenteWèll: ,', D#08 " , Vertic~I(TVJj)R:efereÌtçé:, ," .~e(êJ"(ÚJceWellþ~th: ..'Plän 'D-088, , Site: PB 0 Pad Well: D-31A Rule Assigned: Major Risk Wellpath: D-31A V1 Inter-Site Error: 0.00 ft , Reference ' Offset S~rßH\-1aJor AXis Ctr;.Ctr i No:"Gó ,AUowabJe, 'MO '.' TvD 1\10,". 'TVD' 'Ref Offset TF()fAZI TFO:"H~C~sing DistáöceAréa' Deviation ft ,ft ft ft ft ' , "'ft' dsg dsg , in ' " ft ' ft, , . ft ' 8487.90 7656.40 7575.00 7289.80 95.66 19.22 32.99 354.58 918.73 378.17 788.45 Pass 8510.04 7676.62 7600.00 7314.74 95.66 19.24 32.87 354.47 907.26 378.20 776.34 Pass 8532.17 7696.84 7625.00 7339.68 95.65 19.26 32.75 354.35 895.79 378.25 764.23 Pass 8554.33 7717.08 7650.00 7364.62 95.65 19.27 32.63 354.23 884.37 378.29 752.14 Pass 8576.59 7737.40 7675.00 7389.58 95.65 19.28 32.51 354.11 873.13 378.32 740.25 Pass 8598.95 7757.83 7700.00 7414.54 95.65 19.30 32.39 353.99 862.10 378.36 728.56 Pass 8621.41 7778.34 7725.00 7439.52 95.65 19.31 32.27 353.87 851.27 378.38 717.08 Pass 8643.94 7798.92 7750.00 7464.50 95.65 19.32 32.15 353.75 840.58 378.40 705.73 Pass 8666.48 7819.51 7775.00 7489.49 95.65 19.32 32.03 353.63 829.92 378.42 694.40 Pass 8689.03 7840.10 7800.00 7514.47 95.65 19.33 31.90 353.50 819.28 378.45 683.06 Pass 8711.58 7860.70 7825.00 7539.45 95.65 19.34 31.77 353.36 808.66 378.45 671.72 Pass 8734.18 7881.34 7850.00 7564.44 95.65 19.35 31.63 353.23 798.13 378.4 7 660.45 Pass 8756.85 7902.05 7875.00 7589.42 95.65 19.35 31.49 353.09 787.79 378.48 649.33 Pass 8779.60 7922.83 7900.00 7614.41 95.65 19.35 31.34 352.94 777.62 378.50 638.36 Pass 8802.43 7943.68 7925.00 7639.40 95.65 19.36 31.19 352.79 767.63 378.49 627.55 Pass 8825.28 7964.55 7950.00 7664.39 95.65 19.36 31.04 352.63 757.70 378.50 616.77 Pass 8848.12 7985.42 7975.00 7689.38 95.66 19.36 30.88 352.47 747.77 378.51 605.97 Pass 8870.96 8006.28 8000.00 7714.36 95.66 19.37 30.71 352.31 737.82 378.52 595.14 Pass 8893.80 8027.14 8025.00 7739.35 95.66 19.37 30.55 352.14 727.87 378.53 584.27 Pass 8916.63 8047.99 8050.00 7764.34 95.66 19.37 30.38 351.97 717.92 378.52 573.39 Pass 8939.46 8068.84 8075.00 7789.33 95.66 19.38 30.20 351.80 707.97 378.54 562.48 Pass 8962.29 8089.69 8100.00 7814.32 95.66 19.38 30.02 351.62 698.02 378.55 551.54 Pass 8985.11 8110.54 8125.00 7839.31 95.67 19.38 29.84 351 .43 688.07 378.57 540.59 Pass 9007.94 8131.39 8150.00 7864.30 95.67 19.38 29.65 351.24 678.13 378.56 529.63 Pass 9030.77 8152.25 8175.00 7889.28 95.67 19.39 29.45 351.05 668.20 378.57 518.64 Pass 9053.60 8173.10 8200.00 7914.27 95.68 19.39 29.25 350.85 658.29 378.59 507.64 Pass 9076.44 8193.96 8225.00 7939.26 95.68 19.39 29.05 350.64 648.38 378.60 496.62 Pass 9099.28 8214.81 8250.00 7964.25 95.68 19.39 28.83 350.43 638.49 378.61 485.59 Pass 9122.11 8235.67 8275.00 7989.24 95.69 19.39 28.62 350.21 628.61 378.61 474.53 Pass 9144.95 8256.54 8300.00 8014.23 95.69 19.40 28.39 349.99 618.74 378.62 463.46 Pass 9167.80 8277.40 8325.00 8039.22 95.69 19.40 28.16 349.76 608.89 378.64 452.35 Pass 9190.64 8298.26 8350.00 8064.21 95.70 19.40 27.92 349.52 599.04 378.66 441.22 Pass 9213.48 8319.12 8375.00 8089.20 95.70 19.40 27.68 349.27 589.21 378.66 430.05 Pass 9236.32 8339.99 8400.00 8114.19 95.71 19.40 27.42 349.02 579.39 378.67 418.84 Pass 9259.16 8360.85 8425.00 8139.18 95.71 19.41 27.15 348.75 569.57 378.70 407.60 Pass 9281.99 8381.71 8450.00 8164.17 95.72 19.41 26.88 348.48 559.77 378.72 396.31 Pass 9304.83 8402.56 8475.00 8189.16 95.72 19.41 26.60 348.19 549.96 378.72 384.99 Pass 9327.66 8423.42 8500.00 8214.15 95.73 19.42 26.30 347.90 540.17 378.74 373.62 Pass 9350.53 8444.30 8525.00 8239.14 95.73 19.42 25.99 347.59 530.50 378.76 362.28 Pass 9373.45 8465.24 8550.00 8264.12 95.74 19.42 25.66 347.26 520.99 378.78 350.99 Pass 9396.52 8486.31 8575.00 8289.08 95.74 19.42 25.29 346.89 511.95 378.78 340.00 Pass 9419.83 8507.60 8600.00 8313.99 95.75 19.41 24.88 346.48 503.66 378.74 329.54 Pass 9443.38 8529.12 8625.00 8338.81 95.76 19.39 24.43 346.03 496.29 378.69 319.75 Pass 9467.18 8550.85 8650.00 8363.49 95.76 19.37 23.95 345.54 489.86 378.62 310.75 Pass 9491.17 8572.76 8675.00 8388.01 95.77 19.34 23.43 345.02 484.41 378.53 302.55 Pass 9515.32 8594.82 8700.00 8412.31 95.78 19.30 22.87 344.47 479.99 378.18 295.39 Pass 9539.60 8617.00 8725.00 8436.34 95.79 19.25 22.28 343.88 476.65 378.03 288.95 Pass 9563.99 8639.28 8750.00 8460.03 95.79 19.20 21.67 343.27 474.54 377.84 283.65 Pass 9588.46 8661.62 8775.00 8483.33 95.80 19.14 21.06 342.66 473.63 377.63 279.57 Pass 9612.97 8684.01 8800.00 8506.22 95.81 19.07 20.47 342.06 473.89 377.36 276.77 Pass 9637.53 8706.44 8825.00 8528.75 95.82 18.99 19.92 341.52 475.11 377.09 275.22 Pass t" ) . ..' ,) BP Amoco Anticollision Report . ço...pany~ ' BpAmoco. , Field: ' .' ' PrU( hÖ~ ßay, " Ret~renêeSitê:, ' PB'D Päd , :R:êëêfeiièêWell:" D,~08.' ' :R:efer~l1çeWe~lpåth:' Plårïb:':08ä Site: PS 0 Pad Well: D-31A Well path: D-31A V1 Rêference ,'MD', "TVD ftft Däte: 11/16/2001. ) Time: '. 1,6:37:48 . . . . ()ôS()~4il1*~~~)R~fêrence:,' "wen: Dsöa; TrÜ~ Nói1h . " " Yerticål(TYDJRefé..ence: " '74;84 74Jf ' ,". , ' Rule Assigned: Inter-Site Error: Major Risk 0.00 ft Page: " ' 7. Db:. Oråêlé' Offset' , ' SeIltH\1ajô~Axis , ,CtriètrNò-Go: . Allowäble " MD TVD,'Rer, , 'Offsef"TF:O+A~JT¥O~IIS (jåsing DisfancêAfeâ.,.;. ..D~viatiòn W~rniÏ1g. ft ' ft ft ft' deg 'deg in ,. ft '" "ft ' ,ft 9662.15 8728.93 8850.00 8551.00 95.83 18.90 19.45 341.05 9686.82 8751.46 8875.00 8572.98 95.84 18.80 19.08 340.68 9711.54 8774.05 8900.00 8594.74 95.85 18.70 18.81 340.41 9736.25 8796.61 8925.00 8616.18 95.86 18.59 18.63 340.22 9760.86 8819.09 8950.00 8637.18 95.87 18.47 18.50 340.10 9785.31 8841.43 8975.00 8657.65 95.88 18.35 18.42 340.02 9809.57 8863.58 9000.00 8677.52 95.89 18.22 18.39 339.99 9833.55 8885.49 9025.00 8696.73 95.90 18.09 18.40 339.99 9857.23 8907.11 9050.00 8715.24 95.91 17.95 18.43 340.03 9880.53 8928.40 9075.00 8733.00 95.92 17.81 18.50 340.09 9903.41 8949.30 9100.00 8749.96 95.93 17.66 18.57 340.16 9925.82 8969.76 9125.00 8766.12 95.94 17.50 18.61 340.21 9947.82 8989.86 9150.00 8781.65 95.95 17.34 18.62 340.22 9969.50 9009.66 9175.00 8796.70 95.96 17.18 18.61 340.21 9991.05 9029.34 9200.00 8811.52 95.97 17.03 18.61 340.21 10012.48 9048.92 9225.00 8826.15 95.98 16.89 18.63 340.22 10033.79 9068.38 9250.00 8840.59 95.99 16.74 18.64 340.24 10054.99 9087.74 9275.00 8854.85 96.00 16.59 18.66 340.26 10076.11 9107.03 9300.00 8868.96 96.01 16.45 18.69340.29 10097.15 9126.25 9325.00 8882.94 96.02 16.31 18.73 340.33 Site: PS 0 Pad Well: 0-31 Wellpath: 0-31 V1 Reference MD TVD ft ft 6900.00 6201.24 6920.00 6216.56 6943.34 6234.45 6969.30 6254.39 6995.04 6274.22 Offset MD TVD ft ft 7125.00 6799.72 7150.00 6821.41 7175.00 6843.09 7200.00 6864.77 7225.00 6886.44 Semi:-Major Axis Ref Offset TF.Q+AZI TF();.HS Casing ft ft deg , deg in ' 95.37 18.07 57.50 187.71 95.49 18.10 58.58 185.08 95.28 18.16 59.34 183.69 94.97 18.22 60.19 182.13 94.64 18.26 61.07 180.59 7020.53 6293.89 7250.00 6908.11 94.22 18.29 61.96 179.08 7045.76 6313.38 7275.00 6929.77 93.78 18.31 62.87 177.61 7166.44 6410.16 7300.00 6951.45 93.84 18.52 63.79 175.91 7308.46 6532.71 7325.00 6973.15 94.05 18.79 64.72 173.04 7448.60 6661.09 7350.00 6994.88 94.30 19.06 65.66 167.97 7583.02 6789.40 7375.00 7016.64 94.56 19.33 66.61 158.34 7708.49 6912.15 7400.00 7038.36 94.81 19.59 67.55 138.57 7822.90 7025.32 7425.00 7060.03 95.03 19.82 68.50 103.12 7925.51 7126.87 7450.00 7081.63 95.21 20.03 69.45 70.13 8016.52 7216.29 7475.00 7103.17 95.36 20.23 70.41 52.83 8097.07 7294.47 7500.00 7124.72 95.48 20.41 71.36 44.29 8168.31 7362.53 7525.00 7146.28 95.56 20.58 72.33 39.72 8231.35 7421.67 7550.00 7167.87 95.63 20.73 73.31 37.14 8282.88 7469.14 7575.00 7189.46 95.68 20.89 74.29 35.88 8297.42 7482.42 7600.00 7211.02 95.68 21.04 75.13 36.73 8311.88 7495.63 7625.00 7232.52 95.67 21.20 76.00 37.60 8326.26 7508.76 7650.00 7253.98 95.67 21.35 76.92 38.51 8340.59 7521.84 7675.00 7275.40 95.67 21.50 77.87 39.46 8354.93 7534.94 7700.00 7296.83 95.67 21.66 78.85 40.45 8369.29 7548.06 7725.00 7318.27 95.67 21.81 79.88 41.47 477.05 376.79 274.79 479.59 376.47 275.46 482.51376.12 277.11 486.00 375.77 279.74 490.26 375.41 283.45 495.39 375.03 288.31 501.45 374.61 294.31 508.48 374.20 301.48 516.50 373.77 309.81 525.52 373.31 319.27 535.57 372.82 329.79 546.64 372.32 341.21 558.52 371.79 353.25 570.96 371.27 365.75 583.65 370.78 378.54 596.51 370.28 391.57 609.58 369.80 404.82 622.83 369.33 418.27 636.21 368.87 431.90 649.70 368.42 445.69 Rule Assigned: Inter-Site Error: Ctr-Ctr No.Go Distance Area ft ft 931.11 374.00 936.48 374.54 941.93 374.53 947.31 373.87 952.60 372.81 Major Risk 0.00 ft Allowable Deviation ft 812.64 816.90 820.93 824.70 828.30 957.82 370.99 831.66 962.96 369.73 834.84 967.12 371.18 830.16 968.52 371.56 821.84 967.13 373.97 810.19 963.07 375.26 797.38 Pass 956.50 376.28 782.39 Pass 947.66 378.46 770.86 Pass 936.90 378.81 758.28 Pass 924.57 380.30 736.77 Pass 911.01 381.31 715.96 896.50 382.27 697.64 881.23 383.01 676.56 865.37 382.94 655.18 849.39 383.40 634.61 833.56 383.84 614.04 Pass 817.90 384.29 593.47 Pass 802.43 384.75 572.94 Pass 787.19 385.21 552.50 Pass 772.21 385.67 532.17 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Warning ,-, ¡ '* ') ~ ) BP Amoco Anticollision Report . .... Tifue: ..16:37:46 çOI11P~ny: ,BP Amoco 'Date: 11116/2001 ' Field: ' " prlltlho,eßay COtO[(Ünå~e(N"~rR~fêrence: R:etêr~Dc.e Site: 'PB:DPåd , RefêrènctF\yeU: ' " D~06 '" Vertic,âl' (T'VD)~èfêrerice: Referênce.Wellpatb: 'PlanO;.08a Site: PB 0 Pad Well: 0-31 Rule Assigned: Major Risk Wellpath: 0-31 V1 Inter-Site Error: 0.00 ft , .' 'ReCetence ' Offset Senii-:-MajorAxis ' , Ctr~Ctr '.No-'Go' Allowabiê ,'MD' TVD" 'MD .TVD Ref '.OCfset TFO+~ZI.TFO:JlS Casing. , J)jstanceArea' Deviation Warning ft, ' ,ft,. ,ft ft, ft '" ft" deg " 'deg, in ft ft " ,ft ' 8383.67 7561.20 7750.00 7339.73 95.67 21.97 80.94 42.54 757.48 386.13 511.96 Pass 8398.05 7574.33 7775.00 7361.18 95.66 22.12 82.04 43.64 743.02 386.60 491.87 Pass 8412.36 7587.40 7800.00 7382.60 95.66 22.28 83.20 44.79 728.82 387.05 471.87 Pass 8426.62 7600.42 7825.00 7403.97 95.66 22.44 84.39 45.99 714.89 387.52 452.01 Pass 8440.81 7613.38 7850.00 7425.31 95.66 22.59 85.64 47.24 701.27 387.98 432.30 Pass 8454.96 7626.31 7875.00 7446.62 95.66 22.77 86.94 48.54 687.97 388.50 412.75 Pass 8469.09 7639.22 7900.00 7467.92 95.66 22.94 88.29 49.89 675.02 389.02 393.42 Pass 8483.21 7652.11 7925.00 7489.21 95.66 23.11 89.69 51.29 662.45 389.54 374.37 Pass 8497.30 7664.99 7950.00 7510.48 95.66 23.28 91.15 52.74 650.28 390.05 355.62 Pass 8511.39 7677.86 7975.00 7531.76 95.66 23.45 92.66 54.25 638.52 390.54 337.22 Pass 8525.49 7690.73 8000.00 7553.03 95.65 23.62 94.22 55.82 627.19 391.04 319.21 Pass 8539.58 7703.60 8025.00 7574.31 95.65 23.79 95.84 57.44 616.32 391.54 301.63 Pass 8553.67 7716.47 8050.00 7595.58 95.65 23.95 97.51 59.11 605.93 392.04 284.54 Pass 8567.73 7729.31 8075.00 7616.83 95.65 24.12 99.25 60.84 596.08 392.54 267.99 Pass 8581.73 7742.10 8100.00 7638.05 95.65 24.29 101.04 62.64 586.81 393.04 252.06 Pass 8595.69 7754.85 8125.00 7659.24 95.65 24.45 102.89 64.49 578.14 393.54 236.83 Pass 8609.60 7767.55 8150.00 7680.40 95.65 24.62 104.80 66.40 570.10 394.04 222.33 Pass 8623.49 7780.24 8175.00 7701.54 95.65 24.80 106.77 68.37 562.70 394.57 208.63 Pass 8637.36 7792.91 8200.00 7722.68 95.65 24.98 108.79 70.38 555.95 395.09 195.81 Pass 8651.21 7805.56 8225.00 7743.80 95.65 25.15 110.85 72.44 549.88 395.62 183.94 Pass 8665.05 7818.20 8250.00 7764.91 95.65 25.33 112.96 74.55 544.52 396.15 173.08 Pass 8678.88 7830.84 8275.00 7786.02 95.65 25.50 115.10 76.70 539.89 396.68 163.32 Pass 8692.71 7843.47 8300.00 7807.13 95.65 25.68 117.28 78.88 536.02 397.21 154.72 Pass 8706.54 7856.10 8325.00 7828.23 95.65 25.85 119.49 81.08 532.91 397.71 147.33 Pass 8720.36 7868.72 8350.00 7849.34 95.65 26.02 121.72 83.32 530.59 398.21 141.24 Pass 8734.19 7881.35 8375.00 7870.44 95.65 26.18 123.97 85.56 529.10 398.70 136.49 Pass 8748.01 7893.98 8400.00 7891.55 95.65 26.34 126.22 87.82 528.44 399.19 133.11 Pass 8761.85 7906.61 8425.00 7912.66 95.65 26.50 128.48 90.08 528.62 399.68 131.12 Pass 8775.69 7919.26 8450.00 7933.78 95.65 26.65 130.73 92.33 529.60 400.14 130.53 Pass 8789.57 7931.94 8475.00 7954.92 95.65 26.80 132.97 94.56 531.37 400.59 131.28 Pass 8803.48 7944.64 8500.00 7976.08 95.65 26.95 135.19 96.78 533.92 401.03 133.37 Pass 8817.42 7957.38 8525.00 7997.25 95.65 27.10 137.38 98.97 537.23 401.48 136.76 Pass 8831.38 7970.13 8550.00 8018.45 95.65 27.25 139.54 101.14 541.31 401.93 141 .43 Pass 8845.36 7982.89 8575.00 8039.65 95.66 27.39 141.66 103.26 546.14 402.38 147.36 Pass 8859.35 7995.67 8600.00 8060.86 95.66 27.54 143.75 105.34 551.72 402.82 154.48 Pass 8873.36 8008.47 8625.00 8082.08 95.66 27.69 145.78 107.38 558.00 403.27 162.74 Pass 8887.39 8021.28 8650.00 8103.32 95.66 27.83 147.77 109.37 564.97 403.72 172.06 Pass 8901.44 8034.11 8675.00 8124.57 95.66 27.98 149.71 111.30 572.58 404.15 182.38 Pass 8915.50 8046.96 8700.00 8145.83 95.66 28.13 151.59 113.19 580.82 404.60 193.64 Pass 8929.58 8059.82 8725.00 8167.10 95.66 28.28 153.42 115.02 589.65 405.07 205.73 Pass 8943.66 8072.68 8750.00 8188.36 95.66 28.44 155.20 116.79 599.02 405.56 218.59 Pass 8957.72 8085.52 8775.00 8209.62 95.66 28.60 156.92 118.51 608.92 406.05 232.18 Pass 8971.78 8098.36 8800.00 8230.88 95.67 28.76 158.58 120.18 619.31 406.53 246.45 Pass 8985.82 8111.19 8825.00 8252.12 95.67 28.93 160.20 121.80 630.17 407.05 261.29 Pass 8999.84 8123.99 8850.00 8273.35 95.67 29.10 161.76 123.36 641.47 407.58 276.69 Pass 9013.83 8136.77 8875.00 8294.57 95.67 29.27 163.27 124.87 653.19 408.08 292.61 Pass 9027.83 8149.56 8900.07 8315.82 95.67 29.44 164.74 126.34 665.34 408.61 309.04 Pass 9041.73 8162.25 8925.00 8336.94 95.67 29.62 166.15 127.75 677.82 409.15 325.81 Pass 9055.64 8174.96 8950.00 8358.10 95.68 29.79 167.51 129.11 690.74 409.69 343.06 Pass 9069.52 8187.64 8975.00 8379.25 95.68 29.97 168.83 130.42 704.04 410.23 360.69 Pass f" , :, .. ) ) BP Amoco Anticollision Report .. .., .. ,ç~lDp~ny: ' BPAmoco 11116/20()1 TilDe: .,16:37':48 Page: , ,Field: , PrWqhoeßay Ço~oï-dinat~<NEj}{~(erênce: " .... .. . . ,'Refeï-encêSitè:' , PBO. Pad' . Well; DLQ~.Tr~èNorth .' RefèrericeW~iI: DT08,', Yedicâl(1:'YD)R~fere~êe: 74.847'4;8,' ' , . ,~êfe..enêeW ellpat~: ÞlarFD~08a, Site: PB 0 Pad Well: 0-31 Rule Assigned: Major Risk Wellpath: 0-31 V1 Inter-Site Error: 0.00 ft , ',Reference ,Offset sêmj.;MajorAxis ,Ctr~CtrNo;'Go' Allowable ,MD ,TVÞ MD TVD', Ref , 'Offset T]J'()+AZITF)OJ:USCaSirig 'Dista.ncê:Area.'" Deviation. ft ft ft ft ft . ft " deg . dØg " in' ft ' "ft ft ' 9083.37 8200.29 9000.00 8400.37 95.68 30.15 170.09 131.69 717.69 410.79 378.66 Pass 9097.16 8212.88 9025.00 8421.45 95.68 30.33 171.31 132.91 731.68 411.35 396.95 Pass 9110.88 8225.41 9050.00 8442.49 95.68 30.51 172.50 134.09 745.99 411.88 415.54 Pass 9124.53 8237.88 9075.00 8463.49 95.69 30.69 173.64 135.23 760.61 412.44 434.41 Pass 9138.13 8250.30 9100.00 8484.45 95.69 30.86 174.74 136.33 775.53 412.97 453.55 Pass 9151.70 8262.70 9125.00 8505.39 95.69 31.03 175.79 137.39 790.75 413.50 472.92 Pass 9165.10 8274.94 9150.00 8526.23 95.69 31.21 176.81 138.41 806.35 414.03 492.61 Pass 9177.98 8286.70 9175.00 8546.71 95.70 31.39 177.80 139.40 822.58 414.59 512.85 Pass 9190.13 8297.80 9200.00 8566.70 95.70 31.58 178.74 140.34 839.59 415.18 533.77 Pass 9201.54 8308.23 9225.00 8586.17 95.70 31.78 179.65 141.25 857.34 415.77 555.33 Pass 9212.33 8318.08 9250.00 8605.20 95.70 31.99 180.52 142.11 875.67 416.40 577.36 Pass 9222.27 8327.15 9275.00 8623.60 95.70 32.21 181.35 142.95 894.62 417.06 599.91 Pass 9231.31 8335.41 9300.00 8641.33 95.71 32.44 182.16 143.76 914.11 417.76 622.93 Pass 9239.48 8342.88 9325.00 8658.40 95.71 32.68 182.95 144.55 934.04 418.49 646.31 Pass 9246.96 8349.71 9350.00 8674.92 95.71 32.93 183.72 145.31 954.28 419.25 669.96 Pass 9254.20 8356.31 9375.00 8691.26 95.71 33.18 184.46 146.05 974.71 420.01 693.71 Pass 9261.30 8362.81 9400.00 8707.50 95.71 33.42 185.17 146.76 995.36 420.75 717.58 Pass 9268.11 8369.02 9425.00 8723.49 95.71 33.67 185.84' 147.44 1016.27 421.49 741.61 Pass 9274.35 8374.72 9450.00 8739.03 95.72 33.93 186.49 148.09 1037.47 422.27 765.82 Pass 9279.80 8379.70 9475.00 8753.93 95.72 34.20 187.13 148.73 1058.93 423.08 790.23 Pass 9284.35 8383.86 9500.00 8768.08 95.72 34.47 187.75 149.34 1080.65 423.91 814.82 Pass 9287.90 8387.10 9525.00 8781.38 95.72 34.76 188.35 149.95 1102.54 424.77 839.56 Pass 9290.45 8389.43 9550.00 8793.83 95.72 35.05 188.95 150.54 1124.54 425.67 864.37 Pass 9292.11 8390.95 9575.00 8805.49 95.72 35.35 189.54 151.13 1146.59 426.59 889.22 Pass 9292.94 8391.70 9600.00 8816.42 95.72 35.66 190.11 151.71 1168.70 427.52 914.07 Pass 9293.37 8392.10 9625.00 8826.99 95.72 35.98 190.67 152.27 1190.90 428.48 938.95 Pass T~EE,:::r' t 4" CrN WELLHEAD= MCEVOY Ã'êTUÃTÕR:;""'^"""""""""šãke'¡: ^KB:"ËlEV",;--'''''''~'~7r54^ "BF~"'E[EV-';'""",-"W"-,,",,,w-44:ã4' KOp-;__WM~___,_w6~9ÕÕïñ1d "Max"AñgIë";'''''"42~õõ'@'6šöõ;'' Dãtûrñ"Mõ-';'''--'''''''-''''''1'õ~õ2õ~ "õãiüm 1VDs~"~"-8,80'õo' 19 5/8" DV Packer 1-1 D-tJ Current Comt-Jetion 113-3/8" 72#, L80 BTC Casing 1-1 14 1/2" 12.6# L-80 Tubing. I Baker 95/8" X 41/2" Packer; 4.75" 1.0. 1-1 8714' 2669' 2544' I g I-~ I Top of 5 1/2" Liner Tie-Back Sleeve 1-1 8,790' 1 I Top 7" Liner 1-1 8,925' 1 1-1 9,483' 1 19-5/8" 47#, L80, BTC Casing Perforation Summary Size SPF Interval Open/Sqz 31/8" 4 10075-10120 S 31/8" 4 10130-10135 S 21/8" 6 10135-10150 0 33/8" 6 10150-10165 0 33/8" 4 10172-10193 0 Date 04/05/80 04/05/80 06/19/96 06/19/96 05/17192 I PBTD l-i 10,367' 1 I 7" 29#, L-80, BTC Liner 1-1 10,570' I DATE REV BY COMMENTS 04/22/02 DEW Recreation of 0.08 Current Condition <I L ,~ /"\,J/ ~r. " ,W ~:~? :?: *' : I:. ~: ;. .~ .. ~5:- ~ ,~--- =-- --- =-- ==- =-- ! ; Jr-.''''. ~. ", 2082' 1-i4 1/2" OTIS SSSV Nipple, 10=3.813 0 0 ~ GAS LIFT MANDRELS ST MD 1VD DEV TYPE SIZE L TCH 5 2977 2903 7° OTIS 1 1/2 RA 4 5168 4817 39° OTIS 1 1/2 RA 3 7157 6327 38° OTIS 1 1/2 RA 2 8291 7265 30° OTIS 1 1/2 RA 1 8596 7530 29° OTIS 1 1/2 RA COMMENTS 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 1/2 8,654' 1-i4 1/2" PKR SWS Nipple, ID=3.813" 8,766' 1-i41/2" PKRSWS Nipple, ID=3.813" 8,783' 1-i41/2" PKRSWN Nipple, ID=3.725" 8,796' 1-i4 1/2" WLEG, 10=3.854" PRUDHOE BAY UNrr W8..L: 0.08 ÆRMrr No: 79-0360 API No: 50-029-20372-00 Sec.23,T11N,R13E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 'III ':ii" 'to t .1 D-08A Kick Tolerance ) Page 1 of 2 ) 6/6/2002 11 :07 AM b KICK TOLERANCE CALCULATOR For Vertical, Deviated or Horizontal Wells Well: Version 6.0, December 2000 Units (UK/US): Kick Zone Parameters: 1 Openhole Size? 2 Measured Depth? 3 Vertical Depth? 4 Horizontal Length (>87 deg) ? 5 Tangent Angle Above Horizontal? 6 Min Pore Pressure Gradient? 7 Max Pore Pressure Gradient? 8 Kick Zone Temperature? Weak Point Parameters: 9 Measured Depth? 10 Vertical Depth? 11 Section Angle «87 deg) ? 12 Min Fracture Gradient / EMW ? 13 Max Fracture Gradient / EMW 14 Weak Point Temperature? Other Parameters: 15 Drill Collar 00 ? 16 Drill Collar Length? 17 Drillpipe 00 ? 18 Surface Pressure Safety Factor? 19 Mud Weight in Hole? (inch) (ft) (ft) (ft) (deg) (ppg) (ppg) (deg.F) (ft) (ft) (deg) (ppg) (ppg) (deg.F) (inch) (ft) (inch) (psi) (ppg) (bbl/ft) (bbl/ft) Annular Capacity Around BHA: Annular Capacity Around DP: At Min Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/ft) (ft) (bbl) (ft) (bbl) At Max Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/ft) (ft) (bbl) (ft) (bbl) Input Error Messages: .'9430." 8520. Non-Horizontal 6900 6200 , 1t.500 12.500 185 6.75 200 150 10;000 0.02592 0.05464 Comments: 333 0.0635 3350 Extends above weak point Infinite 1118 61.1 654 0.0679 4096 Extends above weak point Infinite 1842 104.4 . 1,01')'" t'I" 0-08A Kick Tolerance ) Page 2 of 2 ') 6/6/2002 11 :07 AM I-tr-Min Fracture Grad -<>-Max Fracture Grad I 300 250 - :ã a. 200 Q) CJ c t!! 150 Q) Õ I- ~ 100 S2 50 0 0.00 2.00 4.00 6.00 Pore Pressure Gradient APPENDIX: 8.00 10.00 12.00 Maximum Allowable Gas Influx Volume Based on Casing Burst & Surface Equipment Rating Max Allowable Surface Pressure? (psi) Near Surface Casing 10 ? (inch) Near Surface Annular Temperature? (deg.F) Gas Gradient at Max Surface Pres: (psi/ft) Near Surface Annular Capacity: (bbl/ft) At Minimum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) At Maximum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) - 4500 :g 4000 - ~ 3500 :.1 Õ 3000 > ~ 2500 " Q) 2000 :ã ; 1500 g 1000 <C ~ 500 :æ 0 0.00 I I I I 2.00 4.00 i 6.00 5000 12.347 32 0.113 0.13253 Comments: 14862 Extends to hole TO infinite 12361 Extends to hole TO infinite 0. "" \) 8.00 10.00 12.00 Pore Pressure Gradient 'll (,.' ,~ 'kT THIS NOTICE IN THE DOGHOUSE) D-08A Rig site Summary of Drilling Hazards ./ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 10 ppm, March 2001. ./ NORM test all retrieved well head and completion equipment. ./ All wells pass major risk criteria. The closest neighboring well, at surface, is D- 31, which is approximately 34' to the North. No shut-in will be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ./ There are no fault crossings expected, during the drilling of this well. There are several nearby small faults. The closest is a small northeast - southwest fault -180 feet to the southeast of the well, with a throw of -15'. No significant losses are expected, but due attention to the possibility should be paid. ./ Lost circulation may also be experienced while drilling. Though not expected to be a problem, potential lost circulation demands awareness. The SSD lost circulation tree should be followed if lost fluid returns are encountered. ./ Differential sticking may be encountered in this depleted reservoir. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./ 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. CONSULT THE D- PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. D-08A H 206918 DATE INVOICE / CREDIT MEMO OS/23/02 CK052302A RECEI\JED JUN oj 1 2002 Alaska Oil & Gas Gon~. ")V:;I"li,~.::ijOI AnchoraQe THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY DESCRIPTION GROSS Permit to Drill Fee PIs call Terrie Hubble X4628 c> og f} TOTAL ~ DATE OS/28/02 CHECK NO. H206918 VENDOR DISCOUNT NET $100.00 $100.00 No. H 206918 FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND. OHIO 56-389 ~ B P r;~" ','/or ,lilli, ¡11I1r1 ,I''',. '''''1' (/., I.i" '1...> UI' 1/" 0' . - ",[ 1111" 1111" .",.. ."'"'...,. CONSOLIDATED COMMERCIAL ACCOUNT DATE AMOUNT ***May 28,2002**** *****$100.00****** NOT VALID AFTER 120 DAYS TO THE ORDER OF Alaska Oil & Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage, AK 99501 III 2 0 b g . a III I: 0 L. . 2 0 3 8 9 5 I: 00 8 L. L. . 9 III V-c ~ J}ßfn'LL... H _/ ,. - ) ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL V EXPLORA TION INJECTION WELL INJECTION WELL RED RILL Rev: 5/6/02 C\jody\templates WELL NAME (l"fC1 !J-CJ<?A CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD l-> SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY~..fJ 1-' WELL NAME ~/Jbf /)-ct¡A PROGRAM: Exp - Dev,¥ Redrll ~ Se~ - Wellbore seg - Ann. disposal para req- FIELD & POOL b 7'ð,/...J 0 INIT CLASS L)t!W~ / -o~ï GEOL AREA Pf 1'1 UNIT# ~C:S-,-.:. ON/OFF SHORE OV ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . '. . . . . . ¡Y) N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~ ...Q~~%z. 12. Permit can be issued without administrative approval.. . . . . Y N I)/T f-i/!é:r (:1 13. Can permit b~ approv~d before 15-day wait.. . . . . . . . . . ~y N ENGINEERING 14. Conductor stnng provided. . . . . . . . . . . . . . . . . . . - 15. Surface casing protects all known USDWs. . . . . . . . . . . / N - I 16. CMT vol adequate to circulate on conductor & surf csg. . . . . - Y NAIl 'A- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . .¥-N- 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N Á:tÍLþ (lut--f' 6WJ -Rç <:. ' 19. Casing designs adequate for C, T, B & permafrost. . . . . . . Y N r 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N NfA. b,orS 2£ ç 21. If a re-drill, has a 10-403 for abandonment been approved. .. -* Y N 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . (! N 23. If diverter required, does it meet regulations. . . . . . . . . . '¥-N' NIA-- 24, Drilling fluid program schematic & equip list adequate. . . . . Ci2 N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ~N APPR DATE; 26. BOPE press rating appropriate; test to ~SOO psig. N ¡'.Ilc; P "24CJL? Y'S /. 'f¡JGPr &- I nl 0 L 27. Choke manifold complies wi AP I RP-53 (May 84). . . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . @N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y & 30. Permit can be issued wlo hydrogen sulfide measures. . . . . yc:::W 31. Data presented on potential overpressure zones. . . . . .. %N.., /I ~A 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / l/d J I)JJ~~ j)~TE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N .If?(: ~~ 34. Contact namelphone for weekly progress reports [exploratory on Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UIC/Annular: COM RPcÆ- JDH (J¡J- COT WGA We-A- DTS CX>/ Jr þ (. GEOLOGY APPR DATE )~ h'JÄ G:\geology\permits\checklist. doc ( ( Com mentsll nstructions: ) ) Well History File APPENDIX Inforrnation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplrty finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) ') c??oa-/;¡3 //5/'6 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LlsLlb $Revlslon: 4 $ Thu Jan 30 10:36:49 2003 Reel Header Service name.............LISTPE Oat e. . . . . . . . . . . . . . . . . . . . . 03/01/30 Origin. . . . . . . .. . . . . . . . . . . STS Reel Name....... - . . . - . . . . UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNÖWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Oat e. . . . . . . . . . . . . . . . . . . . . 03/01/30 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Commen t s . . . . . . . . . . . . . . . . . ST S LI S Writing Library. Scientific Technical Services Physical EOr Comment Record TAPE HEADER Prudhoe Bay Unì.t MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # J'OB DATA D-08A 500292037201 BP Exploration Sperry Sun 29-LTAN-03 ,JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: mwd RUN 2 AK-MW-22105 R. MCNEILL R. BORDES I mwd RUN 3 AK-MW-22105 R. MCNEILL J. RALL I C. # SURFACE LOCATION SECTION: TOWNSHI P: RANGE: FNL: FSL: FBL: FWL: ELEVATION (FT FROM MSL 0) KELLY RUSHING: DERRICK FLOOR: GROUND LEVEL: 23 UN 13E 1910 1067 .00 74.54 44.54 # 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 6903.0 6.125 7.000 9430.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. WELL KICKED OFF FROM 0-08 WITH TOP OF WHIPSTOCK SET ) ) AT 6903' MD, 6203.5' TVD. 4. MWD RUNS 1 AND 2 W.ERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNE'I'IC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. MWD RUN 3 WAS DIRECTIONAL WITH DGR, EWR-4, STABILIZED LI'I'HO-DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 6. MWD DATA WAS DEPTH SHIFTED '1'0 THE SCHLUMBERGER GAMMA RAY LOG OF 7/15/2002, PER THE 10/'712002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). HEADER DATA RETAIN DRH,TÆR' S DEPTH REFERENCES. 7. MWD RUNS 2-3 REPRESENT WELL D-08A WITH API # 50-029-20372-01. THIS WELL REACHED A TOTAL DEPTH (TO) OF 10180' MD I 9171' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS SEXP = SMOO~rHED PHASE SHIFT DERIVED RESIS'rrVITY ( EXTRA SHALLOW SPACING) SESP == SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOO'I'HED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE == SMOOTHED FORMATION EXPOSURE TIME SBD2 == SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 == SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS == SMOOTHED THE,RMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) PARAMETERS USED IN NEUTRON I POROSITY LOG CALCULATIONS: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 - 8.5 PPG MUD FILTRATE SALINITY: 400 - 900 FORMATION WATER SALINI'rY: 10,990 FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE PPM CHLORIDE PPM CHLORIDE $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.. .....03/01/30 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.OOO Comment Record FI LE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR 1 clipped curves~ all bit runs merged. .5000 START DEPTH 6582.5 STOP DEPTH 10135.0 ) ) ROP RPX RPS RPM RPD FET rCNT NPHI NGNT PEF DRHO RHOB $ 6617.5 6876.5 6876.5 6876.5 6876.5 68'76.5 9309.5 9310.5 9310.5 9429.0 9429.0 9429.0 101'79.0 10142.0 10142.0 10142.0 10142.0 10142.0 10098.5 10098.5 10098.5 10113.5 10113.5 10113.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 6667.5 6670.5 7302.5 '7308.0 7535.0 7539.5 7657.5 7662.0 77 37.0 7742.5 8010.5 8014 .5 8062.0 8066.0 8110.0 8116.5 8268.0 8273.0 8335.0 8340.0 8588.5 8590.5 8997.0 8998.5 9058.0 9059.5 9~238.5 9239.0 9424.5 9426.5 9459.0 9462.5 9500.0 9503.0 9504.0 9507.0 9551.0 9552.5 9581. 0 9581.0 9600.0 9601. 5 9629.0 9630.0 9642.0 9642.0 9698.5 9700.5 9~/54.0 9754.5 9864.0 9865.5 9986.5 9987.5 10010.0 10010.0 10135.0 10136.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 6871. 0 9131. 0 MWD 3 9431. 5 10180.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Se,r.-vice Order Units Size Nsam Rep Code Offset Channel DEPT F'T 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 ') ') RP8 HWD OHMH 4 .1 68 16 5 RPM HWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 RHOB MWD Glee 4 1 68 32 9 DRHO MWD GICC 4 1 68 36 10 PEF MWD B/E 4 1 68 40 11 NPHI MWD PU 4 1 6[i 44 12 NCNT MWD CP30 4 .1 68 48 13 FCNT MWD CP30 4 1 68 52 14 First. Last Name 8ervice Unit Min Max Mean Nsam Reading Reading DEPT FT 6582.5 10179 8380.75 7194 6582.5 10179 ROP MWD FT/H 1. 44 301. 51 125.843 6895 6647.5 10179 GR MWD API 13.45 57'7.06 107.'734 6936 6582.5 10135 RPX MWD OHMM 0.12 1743.14 8.98906 6532 6876.5 10142 RP8 MWD OHMM 0.16 1746.27 9.56038 6532 6876.5 10142 RPM MWD OHMM 0.23 2000 41.4463 6532 6876.5 10142 RPD MWD OHMM 0.19 2000 35.7761 6532 6876.5 10142 FET MWD HR 0.25 62.863 2.86552 6532 6876.5 10142 RHOB MWD G/CC 2.088 2.903 2.33306 1370 9429 10113.5 DRHO MWD G/CC -0.17 6 0.215 O. 036~)416 1370 9429 10113.5 PEE' MWD B/E 1.4 6.56 2.21718 1370 9429 10113.5 NPHI MWD PU 4.47 64.21 25.0627 1565 9310.5 10098.5 NCNT MWD CP30 13058.3 51299.7 27705.6 1565 9310.5 10098.5 FCN'r MWD CP30 95.1 3588.4 716.288 1579 9309.5 10098.5 First Reading For Entire File..........6582.5 Last Reading For Entire File...........10179 File Trailer Service name. .......... ..8T8LIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/01/30 Maximum Physical Record..65535 File Type................ LO Next File Name...........8TSL1B.002 Physical EOF File Header 3ervice name.......... ...3T8L18.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/01/30 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOl Comment Record E'ILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SU)v¡NARY VENDOR TOOL CODE GR RPX RPS FET RPD RPM ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 6871.0 6880.5 6880.5 6880.5 6880.5 6880.5 6935.5 STOP DEPTH 9366.0 9376.0 9376.0 9376.0 9376.0 9376.0 9431.0 ) # LOG HEADER DATA DATE LOGGED: SOFTWARE SUR.fACE SOFTWAR.E VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOl.., CODE DGR EWR4 $ BOTTOM) 'POOL TY PE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 if 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 PI!: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERí'\TURE (MT): MUD AT MA."\( CIRCULATING TERM PERATURE : MUD FILTRA'I'E AT MT: MUD CA.KE AT MT: # NEUTRON TOOL MATRIX: Ml~~l'fUX DENSITY: HOLE CORRECTION (IN): If TOOL STANDOFF (IN): EWR FREQUENCY (HZ): If REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction............. ....Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.... .........Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O 01-JUL-02 lnsite 6.02 Memory 9431.0 6903.0 9431. 0 7.4 39.6 TOOL NUMBER 126027 136749 8.500 6903.0 LSND 9.90 56.0 9.1 500 4.8 3.400 .1. 580 4.000 5.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 :2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RP1'1 1'1WD020 OIlMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HRS 4 1 68 28 8 Name Service Unit Hin Max Hean Nsam ) 70.0 158.0 70.0 70.0 First Reading Last Reading ) ') DEPT FT 6871 901 8151 5121 6871 ROP MWD020 FT/H 1. 44 301. 51 125.362 4992 6935.5 GR MWD020 API 27.79 387.35 129.321 4991 6871 RPX MWD020 OHMM 0.7 1'743.14 2.65103 4992 6880.5 RPS MWD020 OHMM 0.67 1746.2"7 2.70016 4992 6880.5 RPM MWD020 OHMM 0.6 2000 11.8341 4992 6880.5 RPD MWD020 OHMM 0.65 2000 18.9072 4992 6880.5 FET MWD020 HRS 0.25 55.28 2.19809 4992 6880.5 First Reading For Entire F11e..........6871 Last Reading For Entire Fi1e...........9431 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/01/30 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.OO3 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/01/30 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.002 Comment Record f'ILE [-lEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMB.ER: DEPTH INCREMENT: II fILE SUMMARY VENDOR TOOL CODE FCNT NPHI NCNT GR RPD RPX RPM FET RE'S RHOB DRHO PEF ROP $ 3 9B1 9431 9366 9376 9376 9376 9376 9376 header data for each bit run in separate files. 3 .5000 START DEPTH 9310.5 9311 . 5 9311.5 9366.5 9376.5 9376.5 9376.5 9376.5 9376.5 9431.0 9431.0 9431.0 9431.5 II 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): RIT ROTATING SPEED (RPM): HOLE INCLINATION (OEG MINIMUM ANGLE: MAXrtvIUM .~GLE: STOP DE.PTH 10099.0 10099.0 10099.0 10136.0 10143.0 10143.0 10143.0 10143.0 10143.0 10114.5 10ll4.5 1 Oll 4 . 5 10180.0 04-JUL-02 Insite 0.43 Memory 10180.0 9431.0 10180.0 25.1 32.3 I» ) TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOT 'I' OM ) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 11 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 11 BOREHOLE CONDI'rIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVrry (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATUEE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: if NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): if REMARKS: $ # Data Format Specification Record Dat:a Record Type......... - . . . . . . . .0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O ) TOOL NUMBER 91360 150253 10054'ì 162742 6.125 9430.0 QUICKDRILL 8.40 50.0 9.1 550 10.2 2.550 1.120 2.800 3.150 80.0 190.0 80.0 80.0 Name Service Order Units Size Nsam Rep Code Offset Channel OF. P'r FT 4 1 68 0 1 ROP MWD030 FT/H <1 1 6£3 <1 ? GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 RHOB MWD030 G/CC 4 1 68 32 9 DRHO MWD030 G/ce 4 1 68 36 10 PEF !v1WD030 B/E 4 1 68 40 11 NPHI MWD030 PU 4 1 68 44 12 NCNT MWD030 CP30 4 1 68 48 13 FCNT MWD030 CP30 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9310.5 10180 9745.25 1740 9310.5 10180 ROP l'H^ID030 FT/H 6.06 250.89 94.2389 1498 9431.5 10180 GR. lviWD030 API 13.45 577.06 50.3533 1540 9366.5 10136 RPX WI'JD030 OHMM 0.12 1017 . 8 29.2773 1534 9376.5 10143 RPS MWD030 OHMM 0.16 1018.07 31. 6819 1534 9376.5 10143 RPM MWD030 OHMM 0.23 2000 139.136 1534 9376.5 10143 R2D Mvmo 3 0 OHHH 0.19 2000 91.1042 1534 9376.5 10143 ) PET MWD030 HR 0.2761 62.8633 5.08648 1534 RHOS MWD030 G/ec 2.088 2.903 2.3326 1368 DRHO MWD030 GICC -0.176 0.215 0.036595 1368 PEF MWD030 SIE 1.4 6.56 2.2148 1368 NPHI HWD030 PU 4.47 64.21 25.0998 1564 NCNT MWD030 CP30 13058.3 51299.7 27682.4 1564 FCNT MWD030 CP30 95.1 3588.4 715.685 1578 First Reading For Entire File..........9310.5 Last Reading For Entire File..... ......10180 File Trailer Service name.............STSLIS.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/01/30 Maximum Physical Record..65535 ril e Type................ LO Next File Name...........STSLIS.OO4 Physical Eor crape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/01/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......01 Nezt 'l'ape Name........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trails.!:' Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ 01/ 30 Origin. . . . . . . . . . . . . . . . . . . 81'S Reel Name................ UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments.... .............STS LIS ) 9376.5 9431 9431 9431 9:n1.5 9311. 5 9310.5 10143 10114.5 10114.5 10114.5 10099 10099 10099 Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
